bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of a Digital Twin for Well Integrity Management in Underground Gas Storage Fields
Authors: Busollo Carlo , Mauro Stefano , Nesci Andrea , Scimmi Leonardo Sabatino , Baronio Emanuele 
Published: September 2021

Abstract

Objective
Digitalization is offering several chances to improve performance and reliability of Underground Gas Storage (UGS) infrastructures, especially in those sites where ageing would require investment improvement for maintenance and monitoring. In that context, well integrity management can benefit from the implementation of a well digital twin, integrated with real time monitoring.
The work proposes a digital model of the well that can provide a valuable tool to analyse its non stationary states in order to evaluate the integrity of the barriers and its health state.

Methods, Procedures, Process
The key points on well integrity management are barriers testing/qualification and annular pressure monitoring, and in UGS operations it’s crucial the selection of the timing of barrier assessment and of diagnostic test execution to correctly evaluates the results.
The digital model can provide a tool to help the well engineer to understand the health state of the well and to plan maintenance activities. It considers a physical model of the well composed by gas and liquid filled chambers in the annuluses and in the tubing case and all the potential leak paths that could connect the annuluses, the tubing case, and the reservoir to the external environment.
Each chamber is modelled considering its mass and energy balance, while fluid resistances describe fluid leakage across the barriers. Appropriate models, selected according to the geometry and type of each well barrier, describe each fluid resistance.
The input parameters are the well architecture, flowing tubing temperature and pressure and gas flow rate. The model provides pressure and temperatures trends and estimates of leak rates trends or annular liquid level movements during the observation time window.
The fine tuning of the model of each well is carried out by seeking for the values of the parameters that best describe each single leak path, such as size and position of the leaking point, with a genetic algorithm.

Results, Observations, Conclusions
The model has been customised and validated over several wells, some of which with perfect integrity status and others with some integrity issues. Results showed a very good fit with field data, as well as high precision in identifying leak position and size.
The tool can also be applied to forecast well behaviour after the application of mitigating action or to simulate the evolution of the leak. Example applications are the evaluation of the correct time to top up a casing with liquid or nitrogen or the effect on annular pressure of limiting withdrawal or injection flow rate.
Ultralow Concentration of Amphiphilic Molybdenum Disulfide Nanosheets for Enhanced Oil Recovery-Research and Field Application
Authors: Qu Ming , Liang Tuo , Hou Jirui , Wu Weipeng , Wen Yuchen , Xiao Lixiao 
Published: September 2021

Abstract
Recently, spherical nanoparticles have been studied to enhance oil recovery (EOR) worldwide due to their remarkable properties. However, there is a lack of studies of nanosheets on EOR. In this work, we synthesize the amphiphilic molybdenum disulfide nanosheets through a straightforward hydrothermal method. The octadecyl amine (ODA) molecules were grafted onto the surfaces of molybdenum disulfide nanosheets due to the presence of active sites over the surfaces of MoS2 nanosheets. The synthesized amphiphilic molybdenum disulfide nanosheets (ODA-MoS2 nanosheets) are approximate 67 nm in width and 1.4 nm in thickness. The effects of ultralow concentration ODA-MoS2 nanosheets on the dynamic wettability change of solid surfaces and emulsion stability were also studied and discussed. Besides, the core flooding experiments were also conducted to reveal the adsorption rules and the oil displacement effects of ultralow concentration ODA-MoS2 nanosheets. Experimental results indicate that the oil-wet solid surface (a contact angle of 130°) can transform into the neutral-wet solid surface (a contact angle of 90°) within 120 hrs after 50 mg/L ODA-MoS2 nanosheets treatment. In addition, micro-scale emulsions in size of 2 µm can be formed after the addition of ODA-MoS2 nanosheets by adsorbing onto the oil-water interfaces. The desorption energy of a single ODA-MoS2 nanosheet from the oil-water interface to the bulk phase is proposed. When the concentration of ODA-MoS2 nanosheets is 50 mg/L, the emulsions are the most stable. Core flooding results demonstrate that the ultimate residue of ODA-MoS2 nanosheets in porous media is less than 11%, and the highest increased oil recovery of around 16.26% is achieved. Finally, the production performance of ultralow concentration of ODA-MoS2 nanofluid (50 mg/L) in the application of Daqing Oilfield is summarized and discussed.
Ultrasonic Slowness Images for Geological Interpretation: Investigating Field Test Examples of a New LWD Technology
Authors: Shrivastava Chandramani , Blyth Matthew , Sakiyama Naoki , Yamamoto Hiroaki , Haecker Adam 
Published: September 2021

Abstract
Borehole images have long been used for various applications related to geological interpretation, geomechanics and well-placement objectives. Based on the physical measurement used, the resolution and detection limit of the image logs vary considerably thereby limiting or enhancing the applications envelope against specific objectives. A new logging-while-drilling (LWD) technology of pitch-catch (PC) ultrasonic is under development, that can also provide borehole images of compressional and shear slowness in anisotropic and / or heterogenous formations both in water and oil-based-mud. Geological application of these images (which have inch-scale resolution) is being assessed and investigated with respect to the already established ultrasonic pulse-echo (PE) LWD images. While PE images show details of the borehole wall and are thus subject to the effects of drilling practices, the PC images reflect the rock mechanical properties of the formation at the depth of investigation of the measurement, in the same fashion as density images.
Two case-studies are presented to assess the quality and application of these images; with one vertical and one horizontal well. The PC images are shown to provide a lot of meaningful information in addition to PE images, though the PC images lose out on detailed information related to texture and subtle structural features. In fact, the gross geological features of bedding and some sedimentation sequences have been imaged with confidence, with manifestation of the features available across the entire azimuthal coverage with the new-technology images and confident dips with sinusoidal fits are picked for gross geological variations. The horizontal well PC images have picked up higher confidence low-angled features than the vertical well PC images due to the longer intersection with borehole wall. The slowness images are found to provide confident bed-boundaries, also some fracture-traces are visible only on the slowness images. However, major vertical fractures and drilling-induced fractures (DIF) are more prominent on the PE amplitude images. The results show that slowness images offer the capability to understand gross structural dip and facies variability at a better resolution than conventional LWD images of similar resolution, and with the benefit of not needing to utilize a chemical source in the drilling bottom-hole assembly (BHA) for density images. Although the slowness measurements azimuthally have been developed to investigate near wellbore geomechanical concerns, such as stress, heterogeneity, and anisotropy, it is clear that the resultant images also have geological applications that is demonstrated by the datasets shown. These applications mean that the images could offer a more sustainable geosteering capability if delivered in real-time.
Development and Evaluation of a New Electrical Submersible Pump for High Viscosity Environments
Authors: Matheus Laura , Anaya Oscar , Izquierdo Sebastián , Garzón Miguel , Lee Woon 
Published: September 2021

Abstract
Conventional methods of Heavy Oil production have either delivered low recovery factors or have involved costly thermal projects. With low oil prices the new norm, Operators need to maximize their recovery factors whilst controlling CAPEX required to exploit their assets. This paper presents a new approach to lifting heavy/viscous oil with a Pump design that will allow Operators to increase overall field production with reduced energy consumption.
A trial was conducted in Colombia in a harsh field (high viscosity, low water cut, high temperature and high gas production) that had challenged conventional artificial lift systems as Electrical submersible pumps and progressive cavity pumps. Several strategies (light oil injection, high capacity equipment, solvents injection at surface) had been implemented to overcome fluid viscosities 6,000 cP @ 150 °F at dead oil conditions and a mean of 250 cp inside the pump, with excellent short and medium-term results but system hydraulic efficiency and energy consumption were still below expectations.
A new pump has been specially designed for the fluid conditions previously described, with the main objective of reduce the friction losses inside the pump stage increasing the overall efficiency and reducing energy consumption. Initial trial results have fulfilled the study's objectives, overcoming the issues previously experienced with ESP operations in this field.
Designed to handle heavy, high viscosity oil, this study has demonstrated that there is significant economic benefit through savings and improved efficiencies and, in addition, ESP capital cost savings. Previously, oversized units were routinely used to deliver the required flow and pump power but by optimizing the sizing of the ESP system, it is possible to select pumps with fewer stages and lower horsepower motors to suit the new requirements.
Data from the field tests have delivered encouraging results. The pump has operated smoothly since installation and, in comparison to standard pump, has reduced energy consumption (savings of 10-15%) and shown a 15-20% increase in pump efficiency. The Operator has reasonable optimistic expectations for future installations in this field in all applicable wells.
It's Not the End of Petroleum Engineering
Authors: Meehan D. Nathan 
Published: September 2021

Abstract
Is this the end of petroleum engineering as we know it? This prescient question led to the most downloaded paper from onepetro.org in 2019. The events of 2020 resulted in massive layoffs, decreased hiring and many fewer students studying petroleum engineering. In the 2019 paper the authors claimed that the future would hold fewer petroleum engineering jobs and very different types of jobs. This paper incorporates a broader range of data and proposes some specific ways to improve prospects for the discipline of petroleum engineering.
The opportunity for a near-term recovery is very high as the world overcomes COVID-19 issues, oil demand recovers and the impact of chronic underinvestment in oil and gas production looms. The world's largest producers have very different abilities to respond to a near-term uptick in demand. Energy transition pressures continue to cap growth in demand; however, demand for petroleum engineers is expected to grow under almost every scenario, but not to pre-2015 levels. Increased demand in CCUS and jobs that improve sustainability of oil and gas will continue to outpace conventional jobs. Data analytics will play an increasingly large role in engineering activities.
The "Is it the end?" paper started with a question, a question that I first heard asked in 1977 at the SPE Annual Fall Technical Conference and Exhibition in Denver to 1972 SPE President M. Scott Kraemer. I have heard it many times since then and asked it many times. "Would you recommend that your son or daughter study petroleum engineering?" The answer to that question was pretty easy and unanimously positive in 1977. Keep this question in mind as we review what has happened since the prior paper came out.
The True Market Value of a Good Petroleum Engineer: A Technical Perspective
Authors: Michael Andreas 
Published: September 2021

Abstract
Defined by SPE as the application of basic and engineering sciences to the finding, development, and recovery of oil, gas and other resources from wells, petroleum engineering (PE) has been throughout the years falsely thought of as an amalgamation of other disciplines applied to the exploration and recovery of hydrocarbons. Integrating all PE subdisciplines in a manner efficient for teaching and learning is essential for securing the abundance of well-rounded market-attractive professionals. This paper discusses advantages individuals with PE background experience should exhibit in their employment in the oil and gas industry and academia. There is no point for students in going to school for a degree that will not hand them a competitive edge within their discipline.
For graduate PEs, the job market is dependent on the quality of their respective academic programs and by extension to the quality of the teaching faculty. A steady oil and gas job market may not necessarily warrant robust employment opportunities, particularly straight after graduation. In a discipline like PE, where almost everything that matters takes place thousands of feet underground, apportioning credit for successes or responsibility for failures is itself a challenge. Decreases in student enrollments in PE programs reported by various universities during times of low oil and gas prices poses questions about the future of the PEs discipline, despite the steady demand for oil and gas in the world's energy mix. Academic programs interested in facilitating a smooth transition of their graduates into the industry should work in conjunction with practitioners to provide the correct balance between theory and practice in their coursework ensuring that once employment opportunities are created, they get filled with candidates of relevant education and training.
PE degree-holding candidates should be the natural first choice for PE positions. This means that their educational and professional backgrounds should be providing them with an undisputed advantage which places them a leg above candidates from other disciplines. For instance, for a well completions job opening, there should not be a better alternative than a good PE specialized in well completions. If every PE graduate comes out of his or her program with a skillset which is superior to that of his or her competition, he or she will be the preferred choice for an oil and gas job.
Application of Dynamic Risk Management Approach To Mitigate Major Accidents
Authors: Onazi Adai 
Published: September 2021

ABSTRACT
As industries continue to grow, complexities and uncertainties associated with process systems tend to increase, and so are the potential major industrial accidents with corresponding catastrophic consequences. To combat these industrial accidents around the worldwide, there is a need for a more dynamic approach to hazard identification and risk management that proactively mitigates potential exposures in real-time. Evidence suggests that a dynamic approach to risk management can identify and assess developing and increasing industry risks and prevent unwanted outcome. The Piper Alpha investigation and the derivation and adoption of safety case framework in the UK is a proven approach to mitigate major accident hazards for the front-end design of high-risk process facilities, throughout their lifespan. With the increasing complexity of process systems, dynamic risk management as a next-generation risk management approach is required to ensure operational safety. This study aims to stimulate discussions on the novel dynamic risk management approach, leveraging advanced technologies such as artificial intelligence and the 4th Industrial Revolution as a new risk management pathway for industrial accident prevention.
PACT - One Step Closer to Well Control Autonomy
Authors: Petersen Christian , Strand Ola , Johansen Espen , Hansen Dag Almar , Fredheim Dag Ketil , Ohlckers Per 
Published: September 2021

Abstract
Pressure control have been going through steps of evolution. In the highlight of safety, reliability and control, the systems have been sturdy withstanding massive pressure and environmental impact to last the time of estimated life of well. Design have been emphasizing on sturdiness rather than intelligence and autonomy. Time moves on, sophistication levels rise in all parts of our industry. Sustainability and lower environmental impact of solutions grow from the young into business planning and democratic policies. Control lines of hydraulic systems posed risks to the environment as well as being costly in structure and maintenance. Condition monitoring helped ensure better maintenance planning and lowered the risk of breakdown, but still left a lot to be desired reaching for self-contained, self learning systems with low installation and maintenance costs, yet the safest approach.
The next steps were taken towards electrification and digitization of pressure control systems, making short and undetermined strides over almost two decades. Still, the standards are not following the pace of technological progress. And when someone dares to pilot or demonstrate modern technology applied, the installations and operational procedures of the systems still need expensive distributed lines of power, of signals and control systems to ensure a swift and safe operation. The fly-by-wire principle applied in oil & gas is the operate-by-costly-technology-and-environmental-impact-lines.
With the introduction of new and breaking technology in energy harvesting and storage, the playing field opens up towards fully automated systems with no need for expensive power lines or hydraulic control lines. The safety will be taken care of also off-grid, fully digitized. Should cabling of instrument signals be damaged, the system of tomorrow will still be up to par with the Safety Integrity Levels needed. New super-capacitors with an extra dense storage capacity being developed in partnership between the industry and the University of southeast Norway combined with an extremely low energy consuming actuation system with the fastest failsafe mechanism ever will ensure safety in all modes of operation, even with all lines down or consumed by flames. The paper aims to show how the technology works and underline why it will take a place in the future of well control and production.
Successfully Optimizing Breakers in Polyacrylamides for Slickwater and High-Viscosity Fluids
Authors: Kakadjian Sarkis , Kitchen Jarrett , Flowers Amanda , Vu John , Gebrekirstos Amanuel , Algadi Otman 
Published: September 2021

Abstract
Polyacrylamide-based friction reducers (FR's) - including viscosifying polyacrylamides, which are designed to decrease proppant settling by increasing molecular weight and/or active material in the FR - are used extensively in high-rate fracture stimulations. However, because polyacrylamides are difficult to break, there have been concerns about how these materials impact fracture conductivity and formation permeability. This study presents the effect of conventional and novel oxidative breakers over the viscosity and colloidal size distribution of the broken polymers.
Breakers tested include conventional persulfates, perborates and patent pending peroxides, all of which generate free radicals to degrade partially hydrolyzed polyacrylamides (PHPAs). Breakers were tested at bottomhole temperatures encountered in the Permian, Bakken, Haynesville and Eagle Ford. Changes to PHPA viscosity were determined using vibrational viscometers. Size distributions and percentage of the broken colloidal PHPA were determined by dynamic light scattering. This method can measure sizes down to 0.6 nanometers, which is within the range of even the smallest pore-throat sizes in shales.
Light scattering revealed surprising anomalies in breaker performance. When aged at temperatures typical of the Permian, each of the tested breakers at each of the varied concentrations caused similar levels of viscosity reduction but different size distributions. Some breakers had the unwanted effect of narrowing the colloidal size fractions to the lower end of the spectrum. At these small sizes, colloids are more likely to overlap with segments of the pore throat distribution in some shales, which could inhibit production. In addition, when the FR was aged at the higher temperatures encountered in the Bakken, Eagle Ford and Haynesville, some breakers were not able to uniformly break the PHPA. In these cases, FR's without breakers delivered superior performance. The results clearly demonstrate that breakers may not always have the desired effect of increasing the formation's permeability. In fact, depending on the type of breaker and the concentration, they can often have detrimental effects that ultimately hinder production.
Blue Hydrogen Economy - A New Look at an Old Idea
Authors: Ehlig-Economides Christine , Hatzignatiou Dimitrios G. 
Published: September 2021

Abstract
Previous efforts to promote hydrogen as an energy carrier described a Utopian world in which renewable resources provided all energy for heating, electricity, transportation, and industrial needs. The elegance of this vision overlooked the cost and the footprint represented by the renewable energy resources required to generate so much electricity, and the additional cost required to employ electrolysis to generate hydrogen for energy storage not possible for electricity. Today an abundance of natural gas offers an option for hydrogen generation from methane that can include capturing and storing CO2 produced from the generation process. This results in blue hydrogen, effectively as ecologically attractive as the green hydrogen from electrolysis, and considerably less expensive. This paper evaluates a New Hydrogen Economy employing blue hydrogen as a bridge to net zero greenhouse gas emissions.
Of particular interest is the observation that depleted natural gas reservoirs offer pore space sufficient to store about 1.5 times the CO2 coming from hydrogen generation from the produced natural gas. The implication of this observation is that blue hydrogen generation need not rely on saline aquifer storage or on CO2 Enhanced Oil Recovery. We find that blue hydrogen cost is comparable to the cost of current crude oil-based transportation fuels. Further, electricity generated using blue hydrogen is less expensive than decarbonized electricity generated from natural gas with post combustion CO2 capture and storage. The infrastructure required for this energy transition can leverage existing natural gas transport and storage and existing petroleum industry skills.
Energy companies committed to net zero emissions need not rely only on renewable energy sources or nuclear power. Further, switching to blue hydrogen reduces or eliminates combustion related pollution including nitrogen and sulfur oxides. Finally, the Blue Hydrogen Economy makes efficient and cost effective use of petroleum engineering core skills, as well as the core skills championed by the petroleum industry.