bluuebunny/crossref_metadata_2025_split huggingface dataset:
Cost-Effective and Environmentally Sustainable Permanent Magnet Motor for Artificial Lift
Authors: Li Yong , McManus Joseph , Thompson Howard 
Published: September 2022

Abstract
The challenge of climate change and the imperative of moving to a low carbon economy has intensified and added to traditional objectives of affordable, safe, and clean energy in oil and gas production. Recycling parts from artificial lift equipment has been an industry-standard practice for decades. Equipment component reclaim has been a way to deliver high-quality, cost-effective products to our customers, especially in tough market times. It will be a critical best practice to reduce carbon emissions and enhance environmental sustainability.
With customer cooperation, service companies develop procedures to re-use the most significant components of an Electrical Submersible Pump (ESP) system. These include the pump, cable, seal chamber section, and motor. The motor stator, bearings, and rotors are a high percentage of reclaimable parts in an ESP system. Reclaiming the induction motor (IM) rotors has been standard practice for decades. However, with the advent of permanent magnet motors (PMM) and the change in rotor construction, the current process does not apply. The driving force for PMM application is to improve energy efficiency and lower cradle to grave carbon emissions. We could not fully realize the vision of environmental sustainability and reduced carbon footprint if PMM rotors were not part of the reclaim process. Therefore, recycling the PMM rotors strengthens the justification for replacing IMs with PMMs, especially given that the value of magnetic material is highly variable and has doubled in the past year.
The PMM rotors from a recovered motor may suffer from de-magnetization or be contaminated with production fluids or metal debris. Like IM rotors, the most effective method to remove contaminants from the PM rotor is to bake at high temperatures for a period. However, baking the PMM rotor magnets at elevated temperatures will be at least partially de-magnetized during the process and result in the PMM rotors no longer meeting performance specifications. This paper will present innovative technology and apparatus to re-magnetize the de-magnetized rotors for reclaiming.
The research has developed a process where, without disassembling the rotor, the magnets in the rotor are re-magnetized in-situ by a specific apparatus. Testing has proven that PMMs assembled with reclaimed rotors have the same performance-rated power and torque as those built with new rotors. On the other hand, since magnets in PMMs account for more than 50% of total carbon emission of all reclaimable parts in PMMs, factoring in mining, manufacturing, logistics, and processing of magnets that generates toxic by-products to the environment, PMM rotor recycling contributes to corporate responsibility and our overall ESG (Environmental, Social, and Governance) rating. Furthermore, reclaiming PMM rotors can enable us to build PMM more cost-effectively, gain competitiveness in the market, and keep our PMM supply chain more stabilized.
Proppant Fluid Compatibility: Maximize Fracturing Efficiency
Authors: Malekahmadi Fatee , Moringo Nicole Carrejo , Adams Lance , Venugopal Rupa , Price Brian , Li Yifan 
Published: September 2022

Abstract
Many additives are used in unconventional resources fracturing to enhance performance of the fracture. Chemical additives are carefully chosen after stringent compatibility testing in the lab. Proppant is selected based on API/ISO procedures for quality control methodologies or simply by availability. However, the current procedures view proppant as a material and fail to address its compatibility with friction reducers (FRs) and other chemical additives in fracturing applications.
After chemical compatibility was confirmed via flow loop and viscosity testing, an FR was selected for field trial. Operators successfully placed Proppant 1 (Northern White) utilizing FR-A. However, when operators attempted to replace Proppant 1 with three other proppants, high surface pressure was seen, and operators could not maintain suitable pumping pressure. Operators initially concluded that FR-A was incompatible with the formation. Further review and discussion led to chemical compatibility testing of FR-A with each proppant. FR-A combined with field water and proppants shows the compatibility of FR-A with Proppant 1 and incompatibility of the other three proppants due to swelling or flocculation.
We demonstrate traditional compatibility testing of water and FR via flow loop and viscosity and quantifying proppant performance through API/ISO procedures are inadequate. Proppant selection should include mechanical and chemical testing to ensure well production is maximized while costs are minimized, ultimately achieving the desired outcome.
Incorporating Geothermal Curricula into Petroleum Classes: A Ten-Year Experience
Authors: Teodoriu Catalin 
Published: September 2022

Abstract
Over the years, petroleum curricula have been enjoying a continuous update to keep up with technology and industry progress, whereas geothermal is still working on establishing itself as an independent engineering study program. Recently, SPE has created the SPE Geothermal Technical Section, a strong signal towards expanding existing interest areas and strengthening the position of geothermal as a renewable energy resource. Geothermal is undoubtably the closest to oil and gas operations, as it needs, among others, drilling, well construction and completion, reservoir modeling and understanding, geology assessment and geophysics. Consequently, many authors have repeatedly asked for an acceleration of the technology transfer from oil and gas to geothermal. However, this technology transfer is still very slow and irregular. With this in mind, the main question is whether there is a need of fully dedicated courses to teach geothermal or we should rather slowly incorporate geothermal into established courses.
This paper is proposing an intensive discussion about how a petroleum-based program can promote and support the needs of future geothermal engineers through curriculum adaptations. As an example, ten years of teaching experience on two continents under different program concepts, layouts, requirements, and expectations will be summarized and presented here.
One of the main findings of this study is that unlike a class fully dedicated to geothermal, adding geothermal aspects into drilling and completion classes is more likely to facilitate the absorption of geothermal knowledge and enhance the desired technology transfer from oil and gas to geothermal.
Creating an Auto-Encoder Based Predictive Maintenance Tool for Offshore Annulus Wells
Authors: Jain A. , Morgenthal A. , Aman M. , Horton M. , Khan S. 
Published: September 2022

Objectives/Scope
A key component of well integrity is annular integrity. Much of the focus on this has been on establishing maximum and minimum pressure limits and designing envelopes under various well conditions encountered during well construction and subsequent production and injection operations. Many operators have established systems for operating wells within this design envelope to monitor for pressure excursions. However, abnormal annulus pressure behavior within the design envelope could be overlooked using a system that relies on limit monitoring and excursions.

Methods, Procedures, Process
We propose a modeling workflow that combines novel deep learning techniques with statistical analysis to create online models which predict potential asset failures and alert on abnormal behavior such as abrupt pressure build up in producer and water injection wells’ A-Annulus. The model uses autoencoder architecture to learn the behavior of the wells during normal operating periods and generates alerts when it encounters new or abnormal behavior.
The autoencoder architecture outputs a risk score aggregated over the residuals from all input features. Sequential Probability Ratio Test (SPRT) is performed on the risk score to determine abnormal regime during operation to raise alerts. These alerts can be used for root cause analysis based on the top contributors to the risk score. In our approach, we use feature thresholds as filters to determine normal operating periods for training the model. To simulate live conditions during model training, the historical time series data is divided into training and prediction windows. The model is trained on each training window and risk scores are created for the prediction window using a sliding window technique. To find the optimum model, a grid search is performed over a wide distribution of autoencoder and SPRT hyper-parameters. The models are scored based on recall, precision and lead time provided before a failure.

Results, Observations, Conclusions
We demonstrate this workflow using annulus pressure, downhole pressure, upstream choke pressure and upstream choke temperature as input to the model. The model does not require the physical properties of a well but uses historic well data lending itself to be applicable to already existing well stock. Next, we demonstrate using engineered features and synthesized data to efficiently train and score the models. During our experiments, we have explored several engineered features across multiple platforms and found that the correct set of engineered features can deliver a model that accurately alerts on asset abnormalities and potential failures.

Novel/Additive Information
Our approach combines the strengths of deep learning techniques, statistical analytics and subject matter expertise to provide a framework that has demonstrated efficient scaling across multiple assets and sites and has potential application on a variety of oil and gas equipment.
First-Hand Perspectives of the Pro-Female Notion in the Oil and Gas Industry in the Gulf
Authors: Retnanto Albertus , Mohsin Anto , Shaikh Afsha , Shaikh Insha , Pinontoan Darrell 
Published: September 2022

Abstract
The oil and gas industry in the Gulf has been vital in contributing to Qatar's economy. With the industry's rapid growth, there was a need for an exponentially larger workforce. Gender imbalance still remains one of the industry's challenges in a largely male-dominated field. However, the good news is that the female workforce has gradually increased. The rise in female engineers and scientists in the industry has resulted in, among other things, better opportunities to access higher education and training in the oil and gas field. However, there remain some obstacles that aspiring female engineers face. Based on interviews conducted with several engineers who work in multinational oil and gas companies in the Gulf states, we discuss existing challenges and issues many women engineers still encounter today. The interviewees also noted some improvements and provided helpful advice for the females aspiring to be engineers.
We interviewed several female and male engineers, some of whom occupy managerial positions while others work in the fields. The interviews were conducted on Zoom over several weeks, and we then transcribed the interviews. We then analyzed the interview transcripts using a corpora analysis software, LancsBox, with each transcript separated as its own corpus. KWIC (keyword in context) tool was used to isolate a single keyword (for example, "female" or "girl") to find out how often those keywords were used and in what context in a sentence for each corpus, which helped identify the various themes that were discussed during the interview, such as gender and the workplace, challenges in the workplace, barriers to work and life balance, to list a few.
The interviewees recounted their experiences, and from that data, we describe their challenges, successes, and recommendations to make the oil and gas industry in the Gulf accommodating for both genders. The challenges they describe include a lack of appropriate facilities for women on the field; sexist or difficult treatment from male counterparts, managers, and family members; a gender pay gap; and a lack of policies or incentives that support women to achieve executive positions in their companies. Some of the successes they shared include strides being made to encourage women to enter STEM programs in schools and STEM careers, a changing environment for the prevalence and inclusion of women in the oil and gas industry, and a change of culture in the world surrounding the image of women in the STEM industry. Several female interviewees mentioned familial support in their educational pursuit, suggested the creation of mentorship programs and recommended having more female role models in the industry.
A Visual-Learning Project to Enhance the Understanding of Petrophysical Properties Using Pore-Scale Simulation
Authors: Alyafei Nayef , Zia Muhammad Farooq , Rabbani Harris 
Published: September 2022

Abstract
This paper aims to showcase a visual-learning project to enhance the understanding of petrophysical concepts through the use of pore-scale flow simulation. Open-source Field Operation and Manipulation (OpenFOAM) is used to simulate fluid flow through six unique pore structures and postprocessing of numerical results was conducted using Paraview. The images and data of each flow sequence (drainage and imbibition) is captured and available for analysis. In this paper, we discuss how each parameter is used and calculated. The data to calculate are porosity, fluid saturation, throat size distribution, capillary pressure, and relative permeability. The data of this project is open access and can be adopted by any institution. The project utilizes six cases where it enables visual demonstrations of both drainage and imbibition and highlights the effects of pore geometry over each of these processes. The students use open-access image analysis software to analyze the image output from the simulation data and calculate the properties above. Providing students with strong visual cues to otherwise abstract multiphase fluid processes occurring within hydrocarbon reservoirs strongly enhances their learning process. The project provides a unique learning experience to enhance the understanding of petrophysical concepts. The visual elements of this project make the understanding of the microscopic processes much simpler and more engaging. All the data associated with this project will be open access.
Monitoring Hole-Cleaning during Drilling Operations: Case Studies with a Real-Time Transient Model
Authors: Arévalo Pedro J. , Forshaw Matthew , Starostin Alexander , Aragall Roger , Grymalyuk Sergiy 
Published: September 2022

Abstract
Steady-state hole-cleaning models used to monitor cuttings during well construction rely on static parameters that portrait specific drilling scenarios disconnected from each other. This paper presents the integration of transient hole-cleaning models validated in the field into a digital twin of the wellbore deployed while drilling. Thus, enabling the monitoring of the evolution of cuttings, which reduces uncertainty around the state of hole-cleaning procedures and minimizes the associated risk.
A digital twin of the wellbore equipped with physics-based transient models is prepared in the planning phase, and later deployed to a real-time environment. While drilling, smart triggering algorithms constantly monitor drilling parameters at surface and downhole to automatically update the digital twin and refine simulation results. The physics-based transient model continuously estimates cuttings suspended in the drilling mud and cuttings deposited as stationary beds, which enables evaluation of cuttings distributions along the wellbore in real time. Automation systems consume the predicted results via an aggregation layer to refine fit-for-purpose hole-cleaning monitoring applications deployed at the rig.
The transient hole-cleaning model has been integrated into digital twins used during pre-job planning as well as in real-time environments. The system deployed in real-time successfully tracks the state of cuttings concentration in the wellbore during all operations (drilling, tripping, off-bottom circulation, connections) considering the effects of high-temperature and high-pressure on the drilling fluid. Moreover, since the model uses previous results as starting point for the next estimation cycle, it creates a dynamic prediction of how the cuttings evolve while drilling. Fit-for-purpose automation and monitoring services predict drilling issues related to hole-cleaning, downhole pressure, among others. Drillers and drilling optimization personnel receive actionable information to mitigate hole-cleaning issues and avoid detrimental effects for operations. The user interface (UI) presents how the cuttings distribution change with evolution of input parameters (rate of penetration, string rotation, and flow rate).
A set of case studies confirm the effectiveness of the approach and illustrate its benefits. One case study from the North Sea illustrates the reaction of the model to changing operational parameters, while another combines along-string-measurements of density with the cuttings predictions to confirm the trend established by the predicted cuttings concentration.
Insights From Benchmarking Methane Emissions of Oil & Natural Gas Production in the United States
Authors: Curry Tom , Russell Pye , Hellgren Luke 
Published: September 2022

Abstract
The U.S. Environmental Protection Agency (USEPA) collects emissions data each year from oil and natural gas operators in the U.S. through the Greenhouse Gas Reporting Program (GHGRP). While studies have indicated that these emissions are underestimated, the data are reported using a consistent methodology across operators, providing an opportunity to better understand operational differences and trends. The largest methane emissions source category for onshore oil and gas production is pneumatic devices, which make up 56% of methane emissions. From 2018 to 2020, reported emissions from pneumatic devices declined 16%. The drivers of this change include fewer high-bleed pneumatic devices in operation and fewer operating hours reported per intermittent bleed pneumatic device.
Drilling the Deepest High-Pressure High-Temperature (HPHT) Onshoreexploration Well Using a Combination of Mud Cooling and Managedpressure Drilling (MPD) Techniques: A Field Case Study from the Nile Deltaof Egypt Targeting Mesozoic Carbonate Platform
Authors: El-Husseiny Mahmoud , Elfakharany Taher 
Published: September 2022

Abstract
This paper reviews the successful application of a Mud Cooling and Managed Pressure Drilling (MPD) system in a HPHT well to explore the potential of the Mesozoic Carbonate Platform with pressure ramp and Narrow Mud Weight Window (NMWW) in the Nile Delta of Egypt. The Constant Bottom Hole Pressure (CBHP) variation of MPD in combination with mud cooling was used to drill from the middle of the pressure ramp to the target depth, maintaining the mud inlet temperature at around 50°C.
Drilling this well is challenging due to the uncertainty of pressure and temperature regimes and the lack of data in this area. This paper will discuss the application of the MPD and Mud Cooling combination. Also, the challenges encountered while drilling and how they were tackled will be explained, besides the best practices and recommendations for similar applications.
10 in. × 12 in. section completed the pressure ramp, then entered and drilled through the NMWW. The hole was drilled and enlarged simultaneously to 12 in. to section target depth (TD) at 5118 m. Losses at a rate of 3.5 to 5m3/h were encountered (lost 26m3) when circulating to increase mud weight from 2.16 to 2.20 sg to follow the pressure ramp. Then the mud weight was cut back to 2.16 sg, and drilling continued with active use of the MPD system to maintain a CBHP at 2.22 sg. Equivalent Mud Weight (EMW) both equivalent circulation density (ECD) while drilling and with surface back pressure (SBP) during connections. A dynamic formation integrity test (FIT) and a static Pore pressure Test were performed with the MPD to re-assess the drilling window and adjust mud weight accordingly. The mud cooler was running at 100% capacity keeping mud-in temperature 50°C while mud-out temperature ranging from 60 to 70°C and annular temperature from MWD was recorded while drilling at a maximum temperature of 139°C at TD. The 8 in. hole was drilled through the primary objective from 5118 to 5585 m. The MPD detected two well control events early at 5585 m which alleviated their consequences. Difficulties were experienced to regain control of the well, facing a kick and losses scenario due to NMWW. The open hole was plugged back with cement to secure the well after a fragile control was regained. The mud-in temperature was maintained at around 40°C.
T-1 well was the first well to reach that deeply buried Mesozoic carbonate structure. The Mesozoic carbonate platform has never been reached in this area. This paper provides an in-depth study for an innovative combination of utilizing MPD along with mud cooling technique to drill a HPHT exploratory well with a NMWW providing guidance for similar applications.
Applying Survival Analysis to Sand Failure Control Risk
Authors: Yang Huihui , Tallin Andrew , Lu Ligang , Xiao Xiaohui , Valteau Lisa , Wei Jia , Chen Jay 
Published: September 2022

Abstract
Sand production affects safety, reliability, equipment integrity and economics. To help production engineers understand and quantify sand control risks, we built sand control survival application. This application displays how survival is impacted by operating and well parameters as a function of cumulative production, which can help to save oil and gas industry hundreds of millions of dollars per year. Our application uses a dataset that tracks survival status and corresponding cumulative productions for more than 300 completions in GOM. Field data covering water cut, flowing pressure decline, and sand control survival was compiled and analyzed to determine the impact these both single and multiple cofactors on survival, which save time and cost while improving the overall quality of information.
Development and Deployment of Digital Twin for Production and Well Integrity
Authors: Vieira dos Santos Maycon , Menezes Duarte Rosa Rafael , Alves de Oliveira Livia , Newmar Carlos , Rodrigues GonÃ§alves da Silva Fabio , Fasolin Karina , Girardi Vinicius , Iri Nicola Cristofari Rosenbach Leonardo , Nogueira de AraÃºjo JoÃ£o Paulo , Esteves Aranha Pedro , Leibsihn Martins Andre 
Published: September 2022

Abstract
This work presents the development and deployment of a digital twin dedicated to monitor wellbore integrity in real time. Currently, the system is implemented and monitoring in real-time more than 230 production and injection wells. Due to reliable outcomes, the tool is also able to provide virtual well instrumentation to operations that do not have permanent downhole sensors. It consists of the coupling of different numerical simulation software, allowing the calculation of Annulus Pressure Buildup (APB) for confined well annulus and also safety factors for structural integrity analysis. This approach aims to ensure operational efficiency and safety during well interventions and to diagnose unplanned events, by automatically identifying potential operational problems, such as washouts (tubing, packer), reaching of operating limits (pressure and flow rate) per tubing equipment and failures (DHSV and Pack off). Simulations are helpful to predict pressures and temperatures that the well will be exposed to before the execution of specific operations in monitored wells. Different wells were selected and validated in order to corroborate the efficiency of the production digital twin, considering different production scenarios – steady-state and well shut-in (look-ahead), providing a qualitative comparison between calculated data and gauge readings.