bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluation of Directly Simulated WAG Hysteresis at Pore Scale and its Effect on Injectivity Index
Authors: Fager Andrew , Crouse Bernd , Sun Guangyuan , Xu Rui , Freed David 
Published: August 2019

Abstract
Water Alternating Gas (WAG) injection is a widely practiced EOR method for many reservoirs. One drawback of WAG is the decreased injectivity when gas, often CO2, is injected into a previously water-flooded reservoir, and a further decline of injectivity is observed as water and gas injection are alternated. We present a workflow which allows the estimation of injectivity decline using pore scale displacement simulations and reservoir simulations.
In this approach, we use a multiphase Lattice Boltzmann method to directly simulate the alternating water-gas injection at pore scale resulting in a relative permeability curve for each injection phase. The simulation input accounts for injection rate, fluid properties and spatially varying wettability for each cycle during WAG. The final distribution of fluid phases in pore space of each displacement test is used as the starting point for the next displacement cycle. This enables the simulation of imbibition-drainage cycles. Any hysteresis effects present are typically captured in the resulting relative permeability curves. These are then used in a reservoir model to obtain an injectivity index for each injection phase.
We observe a strong decline of water relative permeability after the first gas injection cycle in an oil-wet rock. Detailed analysis of the fluid phases, in particular the water phase, shows that water is well connected after the initial water flood before gas injection. As gas is injected large water blobs are partially displaced and their size significantly reduced. For this wettability scenario, water and gas are competing for the large pore system. We find that capturing the hysteresis effect in a WAG requires the direct simulation of the displacement process, in particular known pore scale phenomena such as trapping and retraction.
The novelty of this approach is to directly capture the hysteresis effect of a WAG workflow in a direct simulation of displacement at pore scale. Emphasis is put on a detailed analysis of the multiphase displacement, including visualizations and an explanation for why the injectivity during WAG is reduced, namely, water and gas are competing for the same pore space. The presented workflow enables an a priori estimate for injectivity losses in a WAG EOR approach.
Adaptation Strategies of Oil and Gas Workers in the Arctic on a Shift Basis
Authors: Korneeva Yana , Simonova Natalia 
Published: August 2019

Abstract
The study was carried out with the financial support of the Russian Foundation for Basic Research in the framework of the research project No. 18-013-00623. The development of mineral deposits in the regions of the Far North and the Arctic is a priority for the Russian Federation. The result of the adaptation of shift workers in the Far North should be considered as the formed adaptation strategies. The environmental and personal resources determine the adaptation strategies in the professional activities of shift workers. The optimal personal resource of adaptation strategies of shift workers corresponds to: adoption of others, moderate internality, integral indicator of adaptation, and programming as a regulatory process.
Saving Lives with Statistics - An Introduction to Data Science in Workplace Safety
Authors: Danis Marek 
Published: August 2019

Abstract
Workplace safety is a main objective of any company working in the oil and gas business. The processes have been developed and established over the past decades based on individual experiences and causal pathways. The exhaustion of technical and administrative barriers has led to the introduction of behavioral safety. Recent advances in data technology and machine learning have disrupted many businesses and processes and can lead to a new paradigm in workplace safety as well.
In this case study we demonstrate the application of data science and predictive analytics to aid the HSE function and prevent accidents. We have analyzed operational and accident data from the past 10 years at a leading oil and gas company to quantify the effectiveness of their safety programs.
We have determined how many accidents each program actually prevents, and is able to prevent in an optimal setting. We have determined the optimal level of engagement for each program, and at what level diminishing returns set in.
We have further developed a predictive model to forecast the occurrence of accidents one month ahead of time. In this way the HSE function is able to focus on 15% of locations to control 69% of the accidents. The forecast was also able to predict accidents at locations where one would traditionally not expect accidents to happen, such as locations with low activity.
This paper shows the potential for improvement that is possible with the emerging big data, artificial intelligence and machine learning tools specifically in the field of workplace safety.
Deep Science Ideation to Create the Next Generation of Energy Sector Technology Start-Ups
Authors: Millar David , Owen Alistair , Falcâo Dominic 
Published: August 2019

Abstract
Innovation is critical to the future success of the oil and gas industry (Wood, 2014), particularly when addressing the challenges that the industry is facing. However, the sector has a reputation for being conservative, insular in its collaborative efforts and reluctant to adopt new technology.
As a way of addressing this, the TechX programme at the Oil & Gas Technology Centre has launched TechX Ventures in July 2018 – a partnership with Deep Science Ventures (DSV) – that combines deep science with engineering to create the next generation of start-up companies with technologies that will position the oil and gas industry for a sustainable future in a low carbon economy.
The start of the programme was a workshop held with industry, academia and the scientific community, to identify areas where new thinking and technology could open up significant opportunities. Three challenge themes were developed, each of which became an opportunity areas for DSV to address. These are:
Carbon negative operations - Effective, large scale, affordable carbon capture and storage solutions are essential to meet global emissions targets. TechX Ventures seeks to create new technologies that will allow the capture of carbon at source, safe storage and conversion to other useful products such as graphene and hydrogen.
Automated oil and gas - Oil and gas is playing catch-up with other industries, such as automotive and aerospace, when it comes to adopting robotics, automation and artificial intelligence. TechX Ventures aims to apply recent advances in these areas to North Sea operations to improve safety, enhance production efficiency and automate the decommissioning process.
Energy movement/storage - Extracting, transporting, storing and using oil and gas presents many challenges. TechX Ventures wants to revolutionise the movement and storage of energy from well to customer by creating technologies which convert the reserves to electrical energy at source, store and transport electrical energy and convert currently wasteful processes e.g. gas flaring to electrical energy.
As part of the TechX Ventures programme, DSV recruited thirty scientists and engineering experts from across the world to tackle the opportunity areas and at the end of the nine-month programme a total of six new start-up companies with new intellectual property were created and invested in by DSV. Of these six, two were selected to join the coveted TechX Pioneer accelerator programme run by OGTC in Aberdeen. These companies are called Eltera and Optic Earth.
Alternative High Density Brines
Authors: Champeau Mathieu , Wei Xia , Jackson Phillip , Sui Changping , Zhang Joyce , Okhrimenko Albert 
Published: August 2019

Abstract
Brines are preferred to solids-laden fluids for completion operations due to their solids-free nature, which helps preserve formation permeability. Salt selection is mostly driven by the density that must be reached to match downhole pressure requirements. When density must be above 14.2 lbm/gal (1.7 s.g.), and crystallization must be prevented, previous options were limited to calcium bromide brines, zinc bromide brines and cesium formate. These brines have severe limitations: zinc brines can be harmful to oilfield personnel and the environment, cesium formate brines are cost-prohibitive and not readily available and calcium brines cannot meet deepwater crystallization requirements.
A new brine technology has been developed, that is zinc-free and extends the density of conventional bromide brines beyond their theoretical limits. This new technology addresses the limitations listed above, while providing low True Crystallization Temperature (TCT) and Pressurized Crystallization Temperature (PCT) to perform in deepwater and cold weather applications.
This paper summarizes the completion fluid properties, laboratory qualification and verification, and summarizes recent successful field applications of the new high-density zinc-free brine.
When to Go with Cloud or Edge Computing in Offshore Oil and Gas
Authors: Settemsdal Stig Olav , Bishop Ben 
Published: August 2019

Abstract
This paper will discuss when it is advantageous (in the context of an offshore oil and gas environment) to process data at the network edge (in close proximity to equipment assets) or to stream data to a cloud-based Internet of Things (IoT) platform for analysis. It will offer an objective assessment of both approaches and provide recommendations for securing data in both cases, as part of an overarching cybersecurity strategy.
IoT has opened the door to significant efficiency gains in the oil and gas industry. This is particularly the case in the offshore sector, where there is a pressing need to reduce costs and maximize equipment availability. In some cases, it is advantageous to process data in close proximity to equipment assets (i.e., at the edge). In others, it makes more sense to securely stream data to a cloud- based IoT platform and harness artificial intelligence (AI) to aid in decision making. In certain cases, both architectures can be utilized in compliment to one another.
Many factors need to be taken into consideration when evaluating an edge or cloud-based approach. Some of these include data volume, transmission and processing speed, control of data, cost, etc. Edge computing can be used to streamline and enhance the efficiency of data analytics. In certain applications, this can mean the difference between analyzing a performance failure after the fact, and pre-empting it in the first place, which in the offshore environment could potentially translate into millions of dollars per day.
On the other hand, there are situations where it is beneficial to store large volumes of data on a cloud-based platform. For example, if the goal is to leverage advanced IoT-based industrial analytics to optimize an entire fleet of a certain type of equipment, the cloud may be the best solution. Cybersecurity is another consideration. Attacks on critical infrastructure have risen significantly over the course of the past year. As more Intelligent Electronic Devices (IEDs) are deployed in the oil and gas industry to optimize efficiency, Industrial Control Systems (ICSs) are increasingly vulnerable. As a result, the threat extends beyond proprietary data to mission-critical operational technology (OT) assets and equipment.
Cybersecurity standards and layered, defense-in-depth models have grown in response to the frequency and sophistication of cyber attacks. Additionally, recent advances in cyber defense technology incorporate small, kilobit-sized embedded software agents to monitor networks for anomalies that could signal an intrusion. This paper will explore new cybersecurity threats to oil and gas assets, as well as strategies operators can employ to defend against them, whether using an edge or cloud-based platform, or both.
How to Achieve Project and Operational Certainty Using a Digital Twin
Authors: Douglas Alistair , Rios Vicente 
Published: August 2019

Abstract
A Digital Twin is a software representation of a facility which can be used to understand, predict, and optimize performance to help to achieve top performance and recover future operational losses. The Digital twin consists of three components: a process model, a set of control algorithms, and knowledge.
Usually the time for commissioning a project exceeds the initial estimations, therefore delays in project completion are quite common. This is often because ICSS testing is done on a static system which does not account for how the system will react dynamically to certain scenarios such as start-ups and shutdowns. Issues such as configuration errors, loop behaviors, start-up over-rides, dead-lock inter-trips and sequence logic are difficult to predict and are impossible to anticipate during static testing. Such delays lead to higher costs and therefore reduced revenue.
This paper aims to describe the most innovative approach to Project & Operational Certainty, which addresses these issues by using a Digital Twin for commissioning support and training. One successful use of this approach was in the Culzean project, an ultra-high-pressure high temperature (UHP/HT) gas condensate development in the UK sector of the Central North Sea. A high-fidelity process model was built and fitted to the actual plant performance based on equipment data sheets. This was connected to ICSS database and graphics, offering a realistic environment, very close to the one offshore, which had the same look and feel for the operators.
Dynamic tests conducted on the Digital Twin predicted issues on the real system, which enabled potential solutions to be tested, leading to a significant decrease in the time spent and cost during commissioning. All the operating procedures were dynamically tested, which enabled us to correct errors, saving time before First Gas. Additionally, all CRO (Control Room Operators) and field technicians were trained and made familiar with the system months in advance, aiming to avoid future unnecessary trips during First Gas.
Finally, all the control loops were fine tuned in the Digital Twin and parameters were passed to off shore, to be used as first starting point. It is expected that these parameters will be very close to fine operational points, as the model used is high fidelity model and very close to real system offshore.
Utilizing Real-Time Downhole and Along String Measurements During Drilling and Cementing Operations to Improve Managed Pressure Operations in a Complex High Pressure, High Temperature North Sea Well
Authors: Brian Tom , Hawthorn Andy , Groves Duncan 
Published: August 2019

Abstract
Several mature fields in the North Sea experience significant challenges relating to high pressures and temperatures accompanied with the infill drilling challenge of very narrow margins between pore and fracture pressures. To navigate these narrow mud weight windows, it is critical to understand the bottom hole pressure. However, in the cases of fractured formations above the target zones, severe losses can be encountered during drilling and cementing operations often leading to the inability to maintain a full mud column at all times and even threaten the ability to reach TD.
The operator therefore decided to investigate the use of a new acoustic telemetry system that could provide internal and external pressure measurements, (along with other downhole measurements) independently of traditional mud pulse telemetry in the drilling assembly. Real-time distributed pressure data essential to understanding the downhole conditions could therefore be provided regardless of circulation, even under severe losses or during tripping and cementing operations.
This acoustic telemetry network was deployed on several wells through multiple hole sizes and including losses management, liner running and cementing operations.
The initial primary purpose of running the network was the ability to monitor the top of the mud at all times, even in significant loss situations. As real-time data was acquired it became apparent that the data could also be used in real-time to aid and help quantify the actual downhole pressures. The use of this downhole data was modified and new calculations designed for simpler visualization of equivalent circulating densities at the shoe, bit and identified weak zones in the well at depths beyond the acoustic tools themselves. This data was used to manage the bottom hole pressure within a 300 psi mud weight window to ultimately enable the well to be delivered to planned TD.
The tool and calculations helped verify managed pressure connections and subsequent pump ramp up and down operations to minimize pressure fluctuations in the well. Additionally the data was used during dynamic formation integrity testing and to measure and calculate ECD at various positions along the drillstring and casing when downhole PWD measurements were unavailable.
This paper will describe how the implementation of new technology through the downhole acoustic network was deployed and the lessons learned in how the real-time data was used, changed and adapted in this particular well. Due to this deployment the acoustic telemetry network will now be used on upcoming equally challenging wells and its range of operations expanded to include drilling, tripping and liner cementing operations.
Major Accident Hazards – Own Your Barrier
Authors: Simpson Gillian , FitzGerald Fiona , Taylor Stuart 
Published: August 2019

Abstract
The Health and Safety Executive's analysis shows poor hazard identification and risk analysis is a causal factor in 12 out of 14 recent major hydrocarbon releases, demonstrating that major accidents could be prevented if workers had a better understanding of major accident hazards (MAHs). Therefore, it is proposed that improving awareness of MAHs across the workforce, both onshore and offshore, would lead to better MAH management and a reduction in major accidents.
Once the domain of process engineers, major accident hazard management has been largely overlooked by much of industry. It was acknowledged as a problem but ignored in the hope that specialists had it under control.
Step Change in Safety's Major Accident Hazard Understanding workgroup responded to this by identifying different job roles (onshore and offshore), evaluating the resources to develop MAH understanding already available and creating a suite of resources to fill the gaps.
These resources include an e-learning tool for onshore (office-based) personnel, bowtie lunch and learn sessions, gap analysis tools to identify training requirements of offshore jobs, senior leaders' workshops and a MAH Awareness programme. The MAH Awareness programme, consisting of short films and presentations which can be customised to suit specific worksites and job roles. Each of the four packs explores different aspects of major accident management including MAH identification and analysis, bowties and safety and environmental critical elements, barrier maintenance, assurance and verification and the importance of taking responsibility of ‘owning’ your barrier.
Analysis of questionnaires completed before and after exposure to the programme demonstrates that knowledge of MAH management increased by approximately 30%. Additionally, the data demonstrates that elected safety representatives have a greater base knowledge of MAHs than the general offshore workforce, as do technical staff compared to non-technical and those employed by operators compared to contractor employees.
Whether this increased knowledge gained through taking part in the MAH Awareness programme is retained or impacts the number of major accidents has not yet been analysed but data such as the number of major accidents, including hydrocarbon releases, will be examined over forthcoming years to evaluate the effectiveness of the resources developed.
Offshore Infrastructure Reuse Contribution to Decarbonisation
Authors: Pearson Hayleigh , Pearson Christopher , Corradi Luca , Almeida Ana 
Published: August 2019

Abstract
The UK and the international community have an increasing interest in the benefits of a hydrogen-based economy. Existing and emerging technologies that are inherently carbon-neutral and potentially carbon-negative are increasingly attractive, given the challenge of meeting climate targets to prevent climate change and build a clean growth strategy. The integration of clean energy technologies across the UK Continental Shelf (UKCS) can increase the flexibility of the energy system, driving efficiency, cost reduction and enhancing the value of natural resources.
There are over 250 platforms and 45,000 kilometres of pipeline installed within the United Kingdom Continental Shelf (UKCS). As these assets near the end of their economic life oil and gas operators are planning to decommission these facilities in an efficient and cost-effective manner. Current cost forecasts for this activity exceed £58bn with approximately 50% borne by the operators and 50% borne by UK taxpayers.
The Hydrogen Offshore Production (HOP) project identifies an alternative to decommissioning by providing re-use options for offshore infrastructure while addressing the national challenge of a low carbon energy supply. In doing so, the project will prove the feasibility of several decentralised hydrogen generation, storage and distribution options that collectively provide a scalable offshore hydrogen production solution, whilst offsetting a portion of decommissioning costs that are currently forecast for all offshore assets and infrastructure.
HOP will tackle the challenge of bulk hydrogen production by (1) proposing viable environmental and economic technology solutions to be deployed offshore, (2) developing a new Industrial Hydrogen Production test site to both prove the industrial benefits and to aid commercialisation of emerging technology and, (3) conducting market analysis and producing the business case for the transformation of existing offshore infrastructure, re-purposing assets and demonstrating the viability for decentralised generation of hydrogen.
As part of the project, an Industrial Hydrogen Production test site will be established with Flotta (Orkney Islands) being proposed as the location. This will provide a test bed for technology, fast-tracking its development and providing a route for accelerated commercial deployment. Within a region of considerable renewable energy generation, the island of Flotta is ideally placed to benefit from local expertise, existing supply chain and advanced technology solutions. For example, the Industrial Hydrogen Production test site would greatly benefit from lessons learnt at the nearby Orkney Water Testing Centre.