bluuebunny/crossref_metadata_2025_split huggingface dataset:
Journey to Zero Lifting & Minimum Congestion for Rigless Activities in Block 61 bp Oman
Authors: Al Shidhani Taimur , Al Harrasi Sultan , Al Darai Asma , Al Sulaimani Ishaq , Al Juma Marwa , Najwani Mohamed , Al Fadhli Khalid , Al Abri Sultan 
Published: October 2022

Abstract
Rig-less activities, such as well-work, stimulation and testing (S&T) in bp Block 61, in Oman, often include rig-ups that typically involve lifting wide and heavy loads. These activities, if not mitigated against, can pose significant safety risks, such as dropped objects and suspended loads. The team's main safety objective was to eliminate as many risks as possible while executing these activities. Therefore, intensive focus was placed on the well testing package, as it is present in most of routine rig less well operations in Block 61. As a result, a major improvement to the package design was identified and implemented in Q2 2021, by "trailerizing" routine intervention resources, including well testing equipment and service camp.
Furthermore, at the start of the rig less journey in Block 61, each service provider supplied their own logistical resources. These resources included cranes, forklifts, flat-bed trucks and prime movers. However, this often led to multiple unnecessary vehicles on site, introducing the risk of congestion on the well site. Adding to that, having non-necessary vehicles previously caused collision incidents. To mitigate said risks, the team introduced the logistic hub concept, where each service provider utilized the relevant vehicles whenever required, instead of supplying their own. This initiative had further reduced congestion on site and ultimately lowered the probability of collisions and incidents.
Consequently, the new design resulted in 85% reduction of lifting activities. This led to minimal utilization of cranes and forklifts, which resulted in lower fuel consumption and ultimately lower indirect carbon emissions. Operational and capital efficiency were also improved as rig up / rig down durations have been approximately halved, and minimum time would be wasted on waiting for a forklift or crane. Due to the optimization of the logistic resources, there are no longer any idle vehicles on site, which reduced the emissions, as well as decreased the third-party costs associated to logistics. The unique aspect of this initiative is that a single supplier provides all required vehicles to the site as per demand directly with no commitment necessary. Having a single supplier provided stronger control of work in terms of lifting plans and procedures.
The rigid bp safety process guidelines ensured that all challenges and optimization opportunities were fulfilled in a safe manner. The purpose of this paper is to detail how the team pushed the technical envelope to introduce such initiatives and share the journey entailing the improvements made to achieve an inherently safer environment.
Game Changer in Subsurface Flare Reduction
Authors: Al Rahbi Moosa Salim , Al Sidairi Nada Abdullah , Al Ghafri Amal Mohammed , Al Ismaili Sultan Ahmed , Al Rashidi Ahmed Sulaiman , Awan Kamran Fahmeed 
Published: October 2022

Abstract
In the fast-changing world of energy transition, The Subsurface (SS) Flare reduction project in the Gas Directorate (GD) of Petroleum Development of Oman (PDO) was kicked off beginning of 2021 to ensure continuity in growing our business and generating revenue while reducing the carbon footprint of our operations. The two main value drivers of this project were firstly to minimize HSE impact and reduce GHG emissions, in line with PDO goal towards net zero by 2050, and secondly to maximize hydrocarbon recovery. This is a first of a kind project in PDO as the GD is leading the way towards addressing subsurface flaring. We started the journey by mapping out the different flare contributors (post-frac, well testing, Flow Back Loop (FBL) units and Halite Clean out), quantifying their impact and identifying the big actors. Then, we worked with the different teams from Engineering, Well Services and Operations to build a 5-year work plan with a clear roadmap to reduce subsurface flaring by 60% in 5 years. In the first year (2021), we managed to reduce SS flaring by 37%. This reduction was accomplished by introducing two efficiency improvements which included a successful Flareless Halite Cleanout trail with a full-scale implementation plan, and the utilization of test separators in line with SMS units to verify the flared figures. This resulted in a 50% correction factor to the data on hand. Going forward, the focus will be on maturing the new technologies that will further reduce SS flare such as Green Completion, Well Head Compression (WHC) units, mobile flare gas recovery, etc. Given the complex nature of this project and the multidisciplinary efforts from Petroleum Engineers, Operations, Engineering, Well Services and New Technology, constructing a successful working plan to address this issue required effective collaboration and thinking outside of the box to find innovative solutions. As a result, we constructed a funnel of efficiency opportunities with a clear timeline including Green Completion, WHC, pre frac hook up, and mobile flare gas recovery units. Additionally organizational tools for enhancing efficiency were applied such as PPS (practical problem solving) and Goal Deployment methodologies.
Such energy efficiency projects that reduce the GHG emissions with a streamlined process and identified involved stakeholders, help to better position the organizations to tackle the climate challenges. Moreover, they help to establish a better understanding of the current impact on climate and keeps an open eye for any new technology opportunity that can be materialized to reduce or eliminate GHG emissions. (Robinson & I. Russo, 2013)
Effective Front-End Loading Management - Most Occurred Flaws in FEL Execution
Authors: Manokaran Padmanaban , Al Rumaithi Fahad , Adi Mohamad Bara , Al Suwaidi Saeed Khalfan 
Published: October 2022

Abstract
Project Management team aims to strive for 100% success all the time. it's no secret that sometimes projects fail due to various reasons. But a project failure doesn't have to be the end of the story. Project failures can often offer valuable lessons for future project planning.
Given the magnitude of investment observed in an Upstream Projects, it is necessary to adopt appropriate methods and processes to ensure the economic viability of the projects, as well as to effectively control the fulfilment of scope, schedule, quality and risk mitigation. The oil and gas industry has consistently used the combination of both methodologies of the PMI and IPA in the development of major projects, with particular attention on the front-end loading methodology (FEL), which combines an approach of so-called "rolling wave planning", with a vision of technical and cost integration in the light of other Project execution techniques.
Certainly, most of Capital projects had fulfilled all the mandatory Front-End Loading (FEL) requirements set by an organization. However, at sanction gate only very few projects are allowed to proceed for execution, and rest are directed to redo or retrofit the FEL's. This Paper aims to capture the most occurred flaws in FEL execution of Upstream Oil & Gas Projects as below: Over Design & Gold PlatingIncomplete Technology SelectionPoor definition of Brownfield Works & Lack of Interface ManagementUnderstating Infrastructure RequirementsLow Stakeholder EngagementUnresolved Risks & UncertaintiesEstimating ErrorsOverly Optimistic Economics
In addition, it also presents recommendations to improve the FEL execution and minimize the potential design changes during Project execution. It can be seen clearly all the above issues are often occurring in most of the Capital projects during FEL execution. These findings can be viewed as a lesson learned approach for all Oil & Gas Upstream capital Projects. This will guide Owners Project Management team better understanding of FEL issues at upfront while developing new projects or executing the FEL phase within budget, on schedule with desired quality.
Improving Organizational Culture : High Reliability Organization
Authors: Al Ali Ali Ahmed Abdulla 
Published: October 2022

Abstract
Positive safety culture is key in a generative organisation where individuals anticipate what could potentially go wrong and accept bad news as opportunity for improvement. During the last several decades, numerous process safety related events have occurred impacting people's lives and companies' financial integrity. The underlying causes of the poor safety culture that resulted in major incidents is due to organisational and safety management failures, inadequate communication, and lack of cultural leadership responsibility.
Utilizing LNG Stochastic Model for Better Cost Predictability and Faster Decision Making During Front End Loading Stage
Authors: Rahmat Roszie Yanty , M Jais Ir Mashitah , Mohd Rahim Mohd Hamim , Azli Mohd Azwan , Veloo Sominidevi , Nawawi Noradnin Hafeeza 
Published: October 2022

Abstract
In the race towards greener energy, Liquified Natural Gas (LNG) stands out as an excellent alternative to reduce greenhouse gas emissions and help combat global warming. Over the years, the LNG cost has become increasingly competitive. With the proposed aspirational liquefaction capacity of 892.4 Million Ton per Annum (MTPA) against existing capacity of 452.9 MTPA, as February 2021 in International Gas Union (IGU) 2021 World LNG Report, the future of LNG market is becoming more and more robust, and cost competitiveness with faster decision-making process, is the key success factor to realize it. This paper will focus more about the process in developing this stochastic cost model encompassing various technologies to assist the project in front end loading stage to evaluate the proposed concept of the LNG plant and provide the sensitivity to the overall plant investment cost. This model utilizes the technical input such as plant capacity and number of trains, gas composition, various concepts of technology selection, project specific requirements, location and propose offsite facilities concept, to generate the high-level deterministic cost estimate. Compilation of technical data from completed LNG project from all over the world, alongside with high level process simulation for each process unit, are utilized as the backbones of the model simulation. Based on that, it will be integrated with the normalized cost data, to reflect the current market. This LNG cost model is tested and benchmarked technically and commercially against completed LNG projects, both internal and external company, with inclusion of one's corporate memories, to increase the predictability of the model. Post internal and external benchmarking analysis, the accuracy of the model is within the anticipated range. Utilization of this model will provide simplified concept select process, thus minimizing the front-end loading duration and enable agile engineering for technical and commercial evaluation.
Industrial Facility Top-Down Green House Gas Emissions Quantification Using in-House Gas Analyzer AUSEA Deployed by Drone
Authors: Donnat Ludovic , Huet Nicolas 
Published: October 2022

Abstract
The company became a multi-energy company in 2021. A new name for a new ambition to become a major player in the energy transition, engaged towards getting to net zero by 2050, together with society.
This vision is based on measurable objectives to reduce the company greenhouse gas emissions in the short (2025), medium (2030) and long (2050) term, covering own industrial operations (Scope 1+2) and the emissions generated by customers’ use of our energy products (Scope 3). The company affirms its ambitious target of a more than 30% reduction in greenhouse gas emissions related to sales of petroleum products (Scope 3 Oil) by 2030 compared to 2015
To that, the company has set phased targets for reducing methane emissions (50% from 2020 levels by 2025 and 80% from 2020 levels by 2030), to move towards zero methane and an objective of less than 0.1 million cubic meters per day for routine gas flaring at operated assets by 2025, before eliminating flaring completely by 2030.
Assessment of Integrated MMV Plan for CCS Projects in Depleted Gas Reservoir and Saline Aquifer Offshore Malaysia: From 4D Time Lapse Seismic Perspective
Authors: Tiwari Pankaj Kumar , Das Debasis Priyadarshan , C Mat M Noor Fajarimi , Leite Renato Jordan , Chidambaram Prasanna 
Published: October 2022

Abstract
There are many gas fields associated with large amount of CO2 concentrations (&gt;50 mol%) in offshore Malaysia. Development of the contaminated gas fields is only possible if a geologically safe storage site is identified for the storage of produced CO2. The critical component of CCS project field development plan is monitoring of the storage site for the long-term containment and conformance security. 4D time- lapse seismic is key in monitoring, measurement, and verification (MMV) plan as it can demonstrate the periodic movement of stored CO2 within storage reservoir. Time-lapse seismic response depends on several parameters ranging from reservoir rock properties, initial fluid and saturation of CO2 during injection period. This study focuses on the different characteristics on 4D seismic attributes for carbonate and clastic reservoirs and discusses to effectively utilize for MMV.
The time-lapse 4D seismic has been traditionally used to identify the potential threats associated with reservoirs with enhanced oil recovery plan. The application of 4D seismic would benefits CCS project for monitoring CO2 plume migration along existing or induced fractures. The study was conducted on identified CO2 storage sites in both depleted carbonate gas reservoir and clastic saline aquifer. It highlights two methods applied in the 4D AVO analysis, that quantifies the changes in CO2 saturation within reservoir during injection. The Aki and Richards' approximation were analyzed for the effect of changes in gas saturations on the seismic amplitudes and the Smith and Gidlow's approximation for the reflection coefficient relationship between the AVO gradient/intercept attributes and reservoir fluid/properties.
The application of 4D seismic would benefits CCS project for monitoring CO2 plume migration along existing or induced fractures. The study was conducted on identified CO2 storage sites in both depleted carbonate gas reservoir and clastic saline aquifer. It highlights two methods applied in the 4D AVO analysis, that quantifies the changes in CO2 saturation within reservoir during injection. The Aki and Richards' approximation were analyzed for the effect of changes in gas saturations on the seismic amplitudes and the Smith and Gidlow's approximation for the reflection coefficient relationship between the AVO gradient/intercept attributes and reservoir fluid/properties. This study focuses on the different characteristics on 4D seismic attributes for carbonate and clastic reservoirs and discusses to effectively utilize for MMV.
South Oman Cluster GHG and Carbon Footprint Reduction Journey - Achievements and Aspirations
Authors: Muthalaly Mathen , Kumar Kamlesh , Agarwal Pankaj , Mihajlov Rodoljub , Kindi Zeyana , Harthy Fatma , Quraini Aiman , Hadhrami Abdullah 
Published: October 2022

Abstract
South Oman Sour Cluster facilities have historically recorded peak total Green House Gas Emission (GHGE) of ~2.1 million tons CO2e in 2019 representing largest volumes within Petroleum Development Oman (PDO). The key contributing factors were lower system availability which resulted in large non-routine flaring and Miscible Gas Injection (MGI) process which requires high power consumption. This paper describes an effective integrated approach undertaken through flaring reduction initiatives, operational excellence and new technology deployments to reduce GHGE footprint within the company/Oman. These initiatives contribute towards a greener hydrocarbon industry and helps in combating climate change.
Non-routine Flaring has been reduced through initiatives to improve system availability (upgrade of control and safeguarding systems, critical parts), focused maintenance campaigns and inline well testing. Critical compressors are being spared where economical and upcoming projects are adopting parallel configurations. Flare Gas Recovery solutions are being deployed with help of new technologies (gas sweetening and flue gas cleaning) to recover all safety flaring and partial non-routine flaring volumes. Local Fuel gas consumption is being phased out. Power grids are being sourced from renewable sources and power plants are being shifted to hydrogen where possible and deployment of CCUS technologies.
As a result of the ongoing initiatives, South Oman Cluster facilities recently in 2021 achieved ~50% reduction in flaring volumes and overall ~25% drop in GHGE compared to 2019 levels. In line with the decarbonization roadmap, total GHGE is predicted to further reduce and reach ~0.7 million tons CO2e (67% lower) by 2030 and ~0.3 million tons CO2e (85% lower) by 2044. These radical impacts were a result of an integrated approach to GHGE issues by identifying all possible sources of emissions, mitigating them as much as possible and addressing the rest through various pragmatic solutions despite the challenges of being critical sour facilities. A core GHGE task force was put in place to continuously evaluate performance, scout for feasible initiatives and pursue its execution to realize its gains. South Oman Sour Cluster GHGE journey, learnings and approach could be replicated elsewhere in the Hydrocarbon industry thereby contributing to a Green Planet.
Cloud-Based Machine Learning System for Large Scale Implementation of Virtual Meters for Production Optimization
Authors: Chen Yujun Johnny , Gulati Nikhil , Annamalai Subbu , Delgoshaie Amir , Jin Zhaoyang Larry , Muradov Riyad 
Published: October 2022

Abstract
This paper proposes a virtual metering (VM) system using machine learning and well production data for estimation of emulsion, produced gas, and vapors for steam-assisted gravity drainage (SAGD) production system. The system consists of four types of virtual meter models for every well: Emulsion Rate VM, Produced Gas Rate VM, Steam Vapor Rate VM, and Flash Vapor Rate VM. Emulsion Rate VM is used to estimate the oil rate output, while the other three VM types are used as the risk level indicators. For optimal well production and well management, operations need to consider both oil production and risks at the same time. Providing both well rate estimation and ability to assess risk at near-real time is a challenging task for large production fields, especially when the data is sparse and there is uncertainty in the well data. We propose a comprehensive system that utilizes a scalable framework to develop and deploy data-driven but process-informed virtual meters at scale and at near-real time. Specifically, in this paper, we describe a) a robust well data-preprocessing pipeline developed to continuously process the stream of input and target data for online learning. b) a state-of-the-art modeling framework designed to combine and segment large amounts of training data from the production filed. c) a scalable and flexible framework to ensure stable model performance with low data latency. d) a streamlined domain-specific model monitoring and MLOps process to enable tuning and retraining of the models by monitoring the performance and data drift.
Not All Unconventional Reservoirs are Similar MENA Regional Vs Global Anisotropic Rock Index and Mechanical Characterization – Part 2
Authors: Gramajo Eduardo , Rached Rached M 
Published: October 2022

Abstract
Improved understanding of unconventional formations requires advanced mechanical and index assessments to explore their complex geology, fissility, and anisotropic behavior. This publication is an extension of the work presented in (Gramajo and Rached 2022), which presented comprehensive datasets of unconventional rocks from China, the United States of America (USA), Canada, and Saudi Arabia. The datasets include the mineral composition, petrophysical parameters (Total Organic Carbon (TOC), porosity, and permeability), and mechanical properties (elastic parameters and compressive strength values).
This paper extends the analysis to include unconventional formations from the Middle East and North Africa (MENA) datasets, specifically from Bahrain and the United Arab Emirates (UAE).
The study enhances our understanding of the newly added rock formations and defines the rock analogs and initial parameters needed to tailor down-hole tools, fracturing fluids, and engineering processes. The results will help reduce the costs (equipment, sample preparation, and measurement time) associated with the initial experimental assessments and achieve higher production outcomes in the emerging reservoirs.
NEB De-Manning and Digital transformation
Authors: Banihammad Basma Ali , Al Zaabi Abdulla Rashed , Al Kindi Hamoud , Modi Jigar , Rafat Mohannad 
Published: October 2022

Abstract
With objectives of the greatest importance such as people safety, operational excellence, collaborative culture and improved system integrity in mind, ADNOC Onshore has evaluated several business processes and explored possibilities with multiple technology providers. Post this evaluation, ADNOC Onshore initiated the NEB Field (North East Bab) De-manned Operations Initiative, which is considered one of the main pioneer projects patronaged by ADNOC Upstream. The project has achieved anticipated manpower reduction and other planned objectives which in turn has generated direct and indirect benefits. The future technology projects with the same intention will have the strong platform provided by the NEB De-Manning project and continue to build on the success.
Novel Frac Sleeve Technology Designed to Replace Plug N Perf and Improve Efficiencies While Significantly Reducing Time to Production and Environmental Impact
Authors: Gibson Chad Michael Erick 
Published: October 2022

Abstract
The paper aims to describe the design, testing/validation, applications, and field trial results of a 15K Multi-Stage Fracturing (MSF) Intervention-less sleeve system for use in single-point entry or multi-cluster design. Field proven results show efficiencies over plug n perf, coil annular frac and ball drop operations and significant environmental savings.
Today, pad design can depend highly on how fracturing operations will be performed. Time between stages, water usage and services required can determine the optimal design of choice when choosing between a single well or multi well pad. Implementing an intervention-less sleeve system reduces the time and water usage between stages and eliminates the need for zipper operations to achieve surface efficiencies. These systems provide completion efficiencies regardless of the number of wells on a pad. By identifying the critical operational limitations of legacy MSF technologies, this paper demonstrates clear benefits between the new intervention-less system and legacy multistage fracturing tools and methods.
Performance of current dissolvable solutions is dependent on wellbore conditions and highly variable from one well to the next. Using material science and product design, the time to production is significantly reduced by eliminating the variability experienced when using the current dissolvable products.
An operating efficiency and downhole frac performance comparison between the intervention-less system and Plug n Perf applications in single well operations is provided. The elimination of interventions, wireline, pump down, explosives, and drill out prove to provide significant benefits over current completions methods and reduced; cost, time, and environmental impact.