bluuebunny/crossref_metadata_2025_split huggingface dataset:
Shift Handover: A Key Link to Process Safety and Operation Integrity
Authors: Viswanathan Rajesh , Mohamed Saleem Babar , Longford William , Kumar Anil , Hamad Al Saeedi Tareq , Al Harbi Mosleh , Hamad Al Shamsi Marwan , Hamad Al Junaibi Bader , Bamazahem Faizal Ahmad , Janahi Mohammed Ibrahim 
Published: November 2020

Abstract
Shift handover is one of crucial process of process plant operations and historical data revealed many of the industrial accidents resulted due to incomplete and poor handover. ADNOC Onshore recognized the need for digitalizing the shift handover. In 2017, Bab Gas operation conceived the idea to be implemented within one control room and later in 2018 the idea was expanded by TC-Integrity & Operation Excellence (TC I&OE) to standardize and implement the E-log in all fifteen ADNOC onshore control rooms to assure the safety of its people and assets, in compliance with ADNOC COP-Operating Integrity. TC I&OE, BAB GAS asset and IT collaboratively worked together in a structured approach to develop a tailor made in-house application. This would improve the shift handover communication, ease of retrieving historical logs at minimum time, enable analysis of information, and. The E log solution was developed with in-house resources and helped saving considerable cost of buying third party application.
Take Back Control of Your Capital Project with an EPC 4.0 Strategy
Authors: Sabharwal Amish , Pada Greg Pada 
Published: November 2020

Abstract

Objectives/Scope:
CapEx Project delivery in the Oil and Gas industry is markedly underperforming other industries. McKinsey and IHS have reported that for projects over $1BN:98% of Projects incur cost overruns or delaysThe average cost increase is 80% of the original valueThe average slippage is 20 months behind original schedule
The advent of "Industry 4.0" is highlighted by the adoption of integrated technology and software tools that focus on management of data across entire projects teams. This has enabled a leap in project execution performance in Aerospace, Manufacturing, and Agriculture. This paper investigates how the current Oil and Gas project execution methodologies can also be enhanced to leverage an Industry 4.0 strategy. This approach has been dubbed EPC 4.0.

Methods, Procedures, Process
Through a process of dissecting existing workflows, business processes, contracting strategies, organizational structures, and information management practices used in capital project execution, the authors have proposed revised practices leveraging digital technology capabilities. These practices take advantage of systems that bring true data integration between all project tools, leveraging a single source of truth that can be visualized in 1D (data), 2D (schematics) or 3D (model), 4D (time) and 5D (cost) enabling project analytics and collaboration between all project disciplines, project teams and project stakeholders.

Results, Observations, Conclusions
The result is an EPC 4.0 blueprint. A series of recommended best practices that are enabled by moving to a unified data centric strategy that will enhance project outcomes. The paper will cover the impact that EPC 4.0 has onContracting Methodologies and Project Team StructuresData Management and data centric workflows/business processesConceptual/Front End Design MaturityEnhanced project oversight, reporting and managementProject collaboration within teams and between organizationsEnhanced Change ManagementPreparation for handover to operations
Early adopters of an EPC 4.0 strategy are seeing immediate results. Typical savings are a 50% reduction in engineering in costs or 5% reduction in CapEx. In addition, higher quality output from engineering flows through to procurement, construction, and commissioning yielding a further 10% CapEx savings. More importantly, predictability in project outcomes have significantly increased with teams more effectively able to mitigate and manage cost overruns and schedule delays.

Novel/Additive Information
The key innovation at the heart of the of EPC 4.0 strategy is the stripping away of the project practices that have built up over the years to mitigate the complexity and volume of information generated during capital project execution. By centralizing and simplifying data management, project contributors can focus on their principal role. For example, engineers can focus on engineering tasks, not on information management tasks.
Analytical Methods for Estimating Hydraulic Diffusivity in Heterogeneous Reservoirs Influenced by Ocean Tides
Authors: El Faidouzi Mohamed Mehdi 
Published: November 2020

Abstract
In offshore wells, the pressure fluctuations caused by the ocean tide can be used to inform on the mechanical properties of the reservoir, in particular its compressibility. Such phenomena is not associated with water movement, except at the microscopic level. In heterogeneous reservoirs, these pressure oscillations can cause macroscopic movement of water, which can serve as the basis for the estimation of reservoir flow properties. The purpose of this study is to develop a set of analytical solutions that describe the pressure variations in a heterogeneous reservoir, in terms of amplitude ratio and phase shift. The solutions were developed using the coupled fluid flow-geomechanics equation for a reservoir under uniaxial tidal loading. This study looks in particular at three geometries of inhomogeous diffusion—radial composite, linear composite and composite slab.
Reservoir Characterisation of Low Resistivity- Low Contrast Pays from a Deepwater Field Using Integrated Analysis
Authors: Shiwang Rahul , Varghese Christeen , Panchakarla Anjana 
Published: November 2020

Abstract
A deepwater turbidite formation from Eastern Offshore, India, is a major focus for hydrocarbon exploration. The reservoirs in this field are primarily of low resistivity and low contrast and consist of thinly laminated shale-sand laminae with overlying thick shales. Conventional logs do not sufficiently distinguish between the overlying shales against the laminated reservoir intervals- owing to poor vertical resolution of the tools to characterize the thin beds properties. A standard practice followed by the operating company was acquisition of conventional logging data along with tensor resistivity measurement for a laminated-shaly sand analysis (LSSA) followed by formation testing. While multiple new pay sands were discovered through this method, the sand-shale-fluid model of LSSA is insufficient to provide fluid typing. Furthermore, fluid sampling using formation testers in these unconsolidated formations are risky due to relatively high SOBM invasion and therefore high clean-up time is required to collect samples. Due to the similar properties between the SOBM and formation oil, it is difficult to conclude between the two fluids during real-time monitoring. Thus, it was essential to delineate the formation fluid using methods other than formation testing.
The acquisition of magnetic resonance data and an integrated interpretation involving conventional logging, tensor resistivity and NMR data helped overcome these challenges, prior to formation testing. The electrical anisotropy and borehole image data helped identify thin beds. LSSA outputs based on conventional and tensor resistivity data indicated hydrocarbon bearing intervals. A continuous magnetic resonance measurement acquiring the longitudinal relaxation (T1), transverse relaxation (T2) and the diffusion coefficient (D), helped derive a lithology independent fluid typing in these wells to provide insights before formation testing.
Hydrocarbon bearing sands were identified as per the results of the integrated analysis, and the formation testing intervals were optimized. Conventional resistivity inversion, LSSA saturation and flushed zone saturation from magnetic resonance provided an understanding of the invasion. The hydrocarbon bearing intervals delineated from integrated formation evaluation using LSSA and 2D NMR analysis were successfully tested and proven using formation testing and sampling. Subsequently, the exploratory well logging programs were modified to include the magnetic resonance in future wells and the workflow explained herein was adopted field-wide.
This paper provides a framework for integrated data interpretation using multi-component induction, magnetic resonance, acoustic data and resistivity imager logs to quantify reservoir fluids and subsequently provide an alternative to formation testing and provides a workflow for exploratory wells for Eastern Offshore, India.
Well Construction Process in a Digital Era: Data Driven Approach to Support Well Operations
Authors: Cappuccio Pasquale , Dal Forno Luca , Mutidieri Luigi , Spitaleri Alessandra , Dalla Costa Riccardo , Tuosto Salvatore , Ricci Maccarini Giorgio , Rinaldi Francesca , Gravante Elpidio , Pizzo Anna , Siciliano Lorenzo , Vivi Valentina , Iannantuono Pietro 
Published: November 2020

AbstractWay of working is continuously changing in O&G field thanks to digital solutions and the possibility to have consistent data driven analysis to support decision-making process.Well Construction cycle from planning to execution and post well analysis is evolving as well, since data are at the base of all the analyses allowing higher operational safety, more efficient engineering, better real time optimization and more effective comparison of performances at the end of operations.Eni Well Operations Department has invested a lot in advanced analytics tools able to extract value from historical and real time data focusing the attention first of all on data coverage, quality and reliability, that are extremely important enablers to let the tools work and perform analyses, and then on proper data transmission system from different rig site locations towards a centralized database.High frequency performance measurement and data intelligence tools allow reaching the technical limit, predictive analytics help in reducing downtime while drilling and well simulation software enhances not only planning phase but also operational real time follow up activities.Applications of digital solutions have run in 2019 on most challenging activities with tangible results in terms of safety improvement, operational efficiency and time and cost savings. Almost 50 wells (more than the totality of most complex wells as per Eni classification) have been analysed in real time with both advanced analytics and predictive algorithms achieving: avoidance of specific Non Productive Time events (about 25% of NPT reduction), with a major impact on operational safetybetter performances throughout development projects, thanks to an improved learning curve and a reduction of Invisible Lost Time (average of 2,5% of time saving per well)enhanced real time monitoring and early detection of well events, leading to a faster decision making and adoption of corrective actions (anticipated actions by average 6 hours)The development and the application of these tools have been made possible thanks to a proper Data Management System. In fact, several initiatives have been put in place to provide proper data gathering, data transmission, data quality check and assurance and data storage.This paper will show in details how the results have been obtained starting from creating an appropriate data infrastructure up to real case of application along 2019 Eni drilling activity.The extensive use of digital tools, both in Geographical Units and Headquarters, has been proven to provide effective support to plan, monitor and evaluate performances during all well operation activities.
Pitfalls of Open Ended Front End Engineering Design
Authors: Chehab Helmi , Singh Sunil , Singh Harendra , Kamal Faris , Takieddine Oussama 
Published: November 2020

Abstract
Several essential parameters, that often form the basis of design activities performed during Front End Engineering Design (FEED), are oftenly modified at late stages of the FEED process resulting in the transfer of various critical activities to the subsequent Engineering, Procurement and Construction (EPC) stage, rendering the FEED open-ended. This paper presents the impact of an open-ended FEED on EPC projects, and provides an approach to enhance the overall effectiveness of Oil and Gas project execution.
Basic Engineering, performed during FEED, comprises of various critical design activities such as Simulations, Material Selection and Sizing Calculations. Process simulations are prepared based on the extreme governing cases such as maximum flowrates extracted from the production forecast. Moreover, equipment material is selected to suite the specified reservoir composition since different chemical component combinations exhibit varying properties and behaviors. Furthermore, equipment size is calculated to satisfy the defined battery limits’ conditions such as Temperature and Pressure.
The critical activities that are carried forward from FEED stage impose amplified risks of design variations during EPC stage, which may have significant schedule and cost implications on the EPC project. In recently executed EPC projects, the reservoir composition, production forecast, and battery limits conditions were modified after the completion of the FEED, which resulted in the reworking of various basic engineering activities that caused significant delays in the issuance of detailed engineering deliverable and the procurement of critical Long Lead Items (LLI). The alterations to the production forecast such as elevated water flowrate resulted in the reverification of the governing cases and the mitigation of the impact on the facility design. Additionally, the changes to the fluid composition such as increased Hydrogen Sulphide content led to numerous adjustments to equipment material specifications and coating requirements. Furthermore, the revision to the battery limits conditions such as Maximum Deadhead Pressure required several amendments to the size of control instrumentation and safety equipment. Clients are recommended to adopt the strategy of providing fixed and clear essential parameters during FEED stage in order to minimize the reworks/revalidations during EPC stage, enhancing the overall success of the Oil and Gas project.
This paper aims to raise awareness of the risks associated with an open-ended FEED on EPC project execution. This paper also presents valuable suggestions and mitigation strategies that will assist all Oil and Gas project stakeholders in effectively optimizing their resources, enhancing the efficiency and profitability of their projects.
Lessons Learned from Trial Testing Wellhead Gas Compressor Technology in a Challenging High Condensate Sandstone Environment
Authors: Al-Rabeh Majed N. , Ruvalcaba Velarde Salvador A. 
Published: November 2020

Abstract
The objective of this paper is to communicate lessons learned, best practices and process enhancement initiatives identified during an actual implementation of Integral Wellhead Gas Compressor technology. The compressor installation was a technology trial test in a challenging high condensate sandstone environment in a conventional gas field. Several technical lessons learned were identified especially in the areas of liquid handling, produced solids management, as well as downhole well intervention requirements.
The methodology was based on collecting and documenting operational challenges and their root causes and corresponding technical solutions as the project progressed. In addition, a benchmarking study was conducted to identify additional areas of improvement to address the root causes of these challenges. Addressing these challenges by implementing the lessons learned highlighted in this paper will ensure expedited project delivery at a reduced cost. Examples of such challenges include unexpected severe liquid slugging, high amounts of solids production, as well as corrosion resistant alloy (CRA) metallurgy requirements.
The benchmarking study resulted in the identification of several areas of potential improvement and multiple engineering process enhancement initiatives were recommended. Examples of such initiatives include the utilization of integrated Liquid Handling System (LHS) to mitigate severe liquid slugging and reduce assembly lead-time. In addition, the utilization of surface cyclonic sand filter systems to mitigate solids production. In addition, conducting downhole tubing drift runs to ensure no restrictions are present that can reduce compressor performance along with several other relevant initiatives.
In summary, the paper provides a deep dive into several technical operational challenges during the actual implementation of wellhead gas compressor technology in a challenging high condensate sandstone environment. Also, several new initiatives are proposed in this paper with the objective of achieving significant cost savings. It is intended for these initiatives to be adopted as best practices not only to yield cost savings but also to supplement the existing best practice literature in the areas of liquid handling, solid management systems, quality control and well intervention.
Innovative Technology Detecting Formation Collapse on Casing- A Case Study
Authors: Ahmad Fajer , Khairallah Eman , Shuber Hussain , Shastri Mukesh , Al-Othman Ahmad , Ramesh Anish , Al Batani Abdulla , Al Foudari Mahmood , Dutta Tapas , Aly Mahmoud , Fituri Mohamed Aiman , Rebaud Paul , Alhamad Nasser 
Published: November 2020

Abstract
Drilling wells in some locations in the Greater Burgan field in Kuwait, can demonstrate significant challenges across the intermediate section. Part of these challenges are combining the carbonate formations with the weak unstable Ahmadi shaley formations at the bottom of the section. This makes it challenging to drilling engineers and difficult to balance between natural mud losses across the carbonate formations and weak shale that requires higher mud weight. Adding to these challenges, the limited surface locations in the field, that forces the well design trajectory to be deviated, which makes the mud window even smaller and shifts it higher. Zonal isolation across this interval adds an additional challenge, as it will prevent gas and liquid to escape from high pressure deeper zones to shallow lower pressure zones and probably to surface, which potentially may cause well integrity issues in the future.
This paper represents a case of formation collapse on a casing prior to cementing operation, how it was detected, how it was handled and how successfully the well was completed.
Safety Recordable Incident Cost Calculator
Authors: Khan Salman , Yaqoob Shamrose 
Published: November 2020

Abstract
This paper describes a project whose objective was to define a costing methodology that showed indicative costs and impacts of safety recordable incidents in an organization. This project's main aim was to raise awareness, through a cost calculator, of occupational health and safety by placing a measurable dollar value to the safety recordable, similar to the nonconformance cost incurred when a quality incident takes place. The novelty of this costing methodology is that it instills a continuous safety culture that is integrated into the employees’ lives, both inside and outside the workplace, making them realize the financial implications of incidents.
Considering current economic crisis and cost pressures mounting on an organization, it is vital to understand the global financial impact of these incidences. In many cases, most organizations have never measured this impact before. This cost calculator will truly be an indicator that demonstrates how effectively an organization is improving its safety performance. Various groups, including safety professionals, project managers, business unit owners, and field service personnel, will be able to see the impact that safety incidences have on the organization as a whole, beyond how it effects their individual rates alone. Organizations can use the output from the cost calculator to not only cut down on the number of incidences they experience, but to decrease their severity as well. In a nutshell, this will provide true transparency and help organizations more completely embody a vision of achieving a zero harm culture.
This paper summarizes the strategic approach used to develop and support the above idea, from inception to final delivery of a costing calculator. The systematic approach used to collect, analyze, and draw conclusions from relevant data is also discussed. The approach described in this manuscript can be adapted to align to complimentary programs and strategic goals and can be scaled in terms of time and resources. It is therefore applicable to any organization.
Utilizing Formation Tester Discrete Mobility and Borehole Images Secondary Porosity for defining Permeability Distribution in Carbonates
Authors: Molua Lyonga Sammy , Maalouf Janine , Shrivastava Chandramani , Ali Humair , Shasmal Sudipan , Khemissa Hocine , Goraya Yassar , Muhammad Ashraf , Al Dhafari Bader Mohamed , Khaled Islam , Alfelasi Ali Saeed 
Published: November 2020

Abstract
Carbonate reservoirs show huge variations in petrophysical properties resulting from leaching/dissolution, fracturation, cementation and or dolotomization. Permeability anisotropy is one property which if understood properly, helps at different stages of reservoir development especially in cases of substantial density difference between fluids; primary production below the bubble point, gas cycling, gas/or water coning etc. Where the anisotropy is severe, it can also influence fluid injection and production rates. For carbonates, microporosity and fractures make it very challenging to relate porosity and lithofacies to permeability. In addition, thin bedded layers that can enhance production maybe unidentifiable because of the coarse nature of conventional logs, at least using Logging While Drilling (LWD) in wells drilled with Oil base muds (OBM) until recently.
The recently introduced LWD dual physics (ultrasonic and resistivity) imaging service with a resolution of 0.2 inch now opens the door to capture heterogeneity using high definition images at very fine scales in OBM that was not possible earlier. High definition borehole images are used to isolate and quantify secondary porosity features like vugs. The density of the vugs per unit length is plotted and correlated to pretest mobility which is a direct indicator to flowrate.
The vug density shows a positive correlation with pretest mobility. The high-resolution images also show intervals where the mobility is enhanced as a result of the influence of thin bed boundaries or where the mobility is lowered because of dense features like stylolytes. The vug density-mobility (vd-m) plot completes a picture of pretest mobility trends limited by the distance between pressure points stations. With the vd-m, more refined facie analyses are possible, together with a better understanding of the permeability distribution across a well.
The effectiveness of a more refined picture of the permeability heterogeneity is seen in the Lower Cretaceous carbonates in an offshore Middle East well. Known porosity variations from core analysis and petrographic images attest to the heterogeneity seen in the vd-m correlation logs. The resolution of vd-m is helpful in understanding the productivity and injection capabilities of such carbonate reservoirs, for example, for optimizing ICD design. Further integration with other data (advanced mud gas analysis) and work processes (geosteering) provide a way of identifying fluid changes in wells, identifying different litho-types and aid in justifying critical geosteering decisions.