bluuebunny/crossref_metadata_2025_split huggingface dataset:
Teaching the Teachers of Montana about the Oil and Gas Industry
Authors: Hoffman Todd , Decker Neil , Lynch Richard , North-Abbott Mary 
Published: October 2023

Abstract
It is vital to increase awareness and knowledge of petroleum engineering and the petroleum industry to the next generation of potential workers. This paper provides information about a program to educate Montana middle and high school math and science teachers about the oil and gas industry. We desire that stakeholders from other states can use this program as a model to create similar courses.
The Montana Tech Petroleum Engineering Department organized and implemented a one-week short course with (1) classroom material, including hands-on examples to showcase various aspects of developing and producing oil and gas reservoirs, and (2) field trips to observe field production operations, a CO2 flood, and a refinery. Montana Tech joined with industry partners and regulatory agencies to provide relevant and meaningful content. The various aspects of the petroleum industry were discussed, including exploration, drilling, completions, production, facilities, artificial lift, and reservoir management. In addition, we covered sustainability, energy sources and uses, climate change, and potential solutions (e.g. CO2 sequestration).
A previous version of this course ran from 2006-2015 and was supported by our state's oil and gas commission. In 2022, it was restarted and updated with funding from Hess Corporation. It was hosted on the university campus with educational materials, field trips, and room and board provided at no cost to the participants. The new short course was an overwhelming success. The teachers learned about the oil and gas industry and took this knowledge back to their classrooms across the state of Montana. Another benefit for the teachers is that they received continuing education credits, which they need to keep their teaching certificates current. The value for Montana Tech and the petroleum industry is that young adults entering college or the workforce will have more knowledge about oil and gas operations since their teachers are better informed and pass on their experience. Based on the success from 2022, the program is scheduled again for the summer of 2023 and expanded to include high school guidance counselors.
This paper will expand awareness of our Teacher's Workshop so it can be easily implemented in other regions where this program could be beneficial. The paper contains the content, workflows, and potential pitfalls so anyone implementing a similar course can use what we have learned as a starting point.
A Data-Driven Approach for Stylolite Detection
Authors: Cheng Jingru , He Bohao , Horne Roland. N. 
Published: October 2023

Abstract
Stylolite is a specific geopattern that can occur in both sedimentary rocks and deformed zones, which could change porosity of the reservoir, modify the permeability, and even result in horizontal permeability barriers. Though there are many related studies to characterize this issue, most of them focused on experimental methods. In this work, we proposed a new approach for recovering geometrical information of the stylolite zone (including its size and location) based on neural network architectures including convolutional neural network (CNN), recurrent neural network (RNN) and attention, which could serve as a preliminary data-driven solution to the problem.
To simplify the problem, we first conducted simulation by building three-dimensional multilayer reservoir models with one stylolite zone. We considered both simplified cases with only a few homogeneous layers, and cases with heterogeneous layers to generalize our work. For the heterogeneous case, we extracted the permeability from SPE10 model 2, a commonly used public resource. Producing and observation wells in the model are at different locations and provide pressure and production rate data as inputs for the deep learning models, in the form of multivariant time series data. For homogeneous cases, after zero-padding and standardizing our inputs to tackle different-length data and features with different scales, we passed our dataset to a CNN-LSTM model. The two subnetworks are connected in parallel to combine the advantages of CNN in extracting local temporal features and the strengths of LSTM in capturing long-time dependency via self-loops. Models containing only a few CNN and LSTM models are also covered in our work as baseline models. For heterogeneous cases, a CNN-based model U-net and an attention-based model SeFT were introduced to enhance the performance.
On the homogeneous dataset, our CNN-LSTM model achieved a satisfactory performance and could predict the locations and sizes of the stylolite zone and outperformed the two baseline models. On the more challenging heterogeneous dataset, our baseline and CNN- LSTM models failed to deliver meaningful results. In contrast, SeFT and U-net showed success in the sense that we could successfully predict the locations of the stylolite zones.
Crisis Management Holistic Training with Immersive Technologies for Awareness and Preparedness of Oil and Gas Professionals
Authors: Kokkinos N. C. , Mitropoulos A. C. 
Published: October 2023

Abstract
Many previous technological accidents were primarily caused by human factor. The oil and gas (O&G) industry is interested in new methods for improving human response and safety. The scope of the current study is to assess the use of immersive technologies in awareness and preparedness of oil and gas industry's staff in emergencies and in crisis management. The training methodology based on a holistic sevenfold approach. In the beginning, the oil and gas professionals familiarize themselves with fundamental physicochemical phenomena of the O&G sector in a research laboratory. In the second stage, the examining phenomena are modelled and simulated. Then, the model is verified, validated and tested taking into account the real feedback from the laboratory experiments. Thus, the entire developed system turns into a process. The next step is the use of immersive technologies in order to scale-up the process by developing a virtual reality (VR) environment of the real field. The produced VR environment is then simulated into high-tech full-size facilities including a virtual control room, a drilling simulator, a virtual dispatch center and a VR onshore or/and offshore oilfield with wearable equipment. The sixth stage of the holistic training is the dynamic overall financial audit of the oil and gas plants implemented in real time. Finally, evaluation and certification of O&G professionals take place. O&G trainees were tested in various emergency what-if scenarios that were not friction products, but rather the results of long-term interviews with industry executives, field operators and control room operators, who involved in past dangerous incidents, near-misses, and accidents. The study found that human factor played a significant role in the outcomes of emergencies, with careless or negligent behavior often causing problems. In some cases, the teamwork of the participants was excellent, but in others, communication problems led to emergency shutdowns or evacuation alarms. To our knowledge, an in situ holistic approach of crisis management training using immersive technologies for awareness and preparedness of O&G professionals has been studied for the first time.
Downhole Temperature Estimation of a Growing High-Temperature Wellbore Using a Modified Drift Flux Modeling Approach
Authors: Wang N. , S. Khaled M. , Luu A. , Ashok P. , van Oort E. 
Published: October 2023

Abstract
Downhole temperature (DHT) estimation is very important for heat management while drilling high-pressure, high-temperature (HPHT) and geothermal wells to prevent premature bit and downhole tool failure. Existing transient models neglect the impact of wellbore growth / deepening on the downhole temperature, treating the wellbore). as having fixed dimensions. This leads to inaccurate temperature estimation, especially when drilling at a higher rate of penetration (ROP This paper presents a new modeling approach to overcome this shortcoming.
A coupled model of thermohydraulic flow in a growing wellbore was created based on a drift-flux model. It incorporates three key features. First, a dynamic, real-time meshing method appends new calculation cells to the bottomhole location as the well is deepened. Second, geometry and drilling fluid physical properties near the interfaces between drillstring sections and wellbore sections are updated dynamically as the drillstring moves forward. Finally, the drift-flux equation is adjusted to account for the well geometry changes associated with a moving drillstring.
The new model was validated using the open-source Utah FORGE field dataset and a previously validated model in a non-growing static wellbore. The DHT results from the new model converged to those from a well-calibrated model without wellbore growth when the rate of penetration (ROP) approached zero. Simulation results for a growing wellbore show that the DHT is generally higher compared to a static / non-growing wellbore and that this difference increases with higher ROP. The new model also provides new insights into the impact of the ROP relative to the pump rate on the DHT. When DHT estimation is needed for multiple wellbore sections, the new model only requires one set of input data to analyze the DHT at different well depths during the drilling operation. This is a major advantage in comparison to static-well models which require multiple input datasets, one for each wellbore section, with each input requiring carefully selected initial conditions to obtain realistic results.
This work provides a new modeling tool, validated against a static-wellbore solver and field data, to estimate and manage the DHT in higher-temperature oil, gas and geothermal wells. The model, which has the potential to run in real time and thereby digitally twin the drilling operation, may contribute to preventing premature temperature-related failures of bits and downhole tools while drilling future wells in high-temperature environments.
A New Polymer Based Multifunctional Fracturing Fluid With Enhanced Proppant Transport Capability
Authors: Lin Genyao , Huang Jiangshui , Song Lulu , Richardi Bryant , Li Jianshen , Liu Fuchen , Lin Lijun 
Published: October 2023

Abstract
Multifunctional fracturing fluid is desirable in the oil and gas industry as it can reduce operational complexity and footprints during hydraulic fracturing. Traditional slickwater fracturing fluid has limited proppant transport capability and lacks other functionalities. Most reported publications and practices on proppant transport enhancement were largely realized via increasing the viscosity of the fracturing fluid by using high viscosity friction reducer (HVFR) or simply increasing dosages. Recent multifunctional fracturing fluid research has also demonstrated that the combination of HVFR with nano-emulsion can provide the effect of spontaneous imbibition oil displacement to improve oil recovery (IOR) and thus achieving the goal of combining both hydraulic fracturing and IOR. While fracturing fluid with high viscosity has been used to increase its proppant carrying capability, it comes with the compromise of reduced fracturing length, fewer secondary fractures as well as requiring multiple additives to achieve multifunctionalities.
In response to the industrial needs of multifunctional fracturing fluids with reduced operational footprints, we report a multifunctional fracturing fluid based on a novel single polymer system containing oil-displacement surfactant. The new polymer based fracturing fluid was characterized in terms of friction reduction, proppant settling, rheological properties and Amott cell spontaneous imbibition tests.
The flow loop results showed that the new polymer system based fracturing fluid can achieve friction reduction of more than 70% in both fresh water and 55K brine. Remarkably, the new fracturing fluid at 0.4wt% can suspend the 20-40 mesh ceramic proppant for an extended period without apparent settling. Breaker studies and rheological properties of the fluid were performed using traditional breaker ammonium persulfate at various dosages. The spontaneous imbibition test on the broken fluid showed a significant increase in oil recovery as compared to the control sample.
The results showed that the novel multifunctional fracturing fluid can be used as a traditional friction reducer at low dosages with over 70% friction reduction; while at high dosages, the fracturing fluid exhibits superior proppant carrying capability due to the formation of three-dimensional structures facilitated by hydrophobic association. Additionally, the multifunctional fracturing fluid can be easily broken by traditional peroxide breaker to release the oil displacement surfactant to enhance oil recovery as demonstrated by the spontaneous imbibition test. The presented multifunctional fluid can reduce the number of additives needed in the field and its enhanced proppant transport capability can result in less freshwater usage and less environmental impact.
Evaluation and Study of Dissolvable Frac Plugs on Horizontal Well Fracturing, Plug and Perf Completions
Authors: Almulhim Bassam Khalid , Ashby Scott , Alobaid Hashem , Alyousef Abdulmuin 
Published: October 2023

Abstract
The paper focuses on the use of dissolvable plugs in plug and perf completions, which allows the frac operations to be carried out, isolating between stages, and when the job is complete, the well can be flowed-back immediately. The need to mill out as with conventional plug is eliminated as each plug is disintegrated to a fine powder, not generating any flow restriction. Risks associated with milling and potential casing damage is eliminated, resulting in safer operations and operational savings. It also reduces the possibility of filling the open fractures with debris or chips from the milling process, minimizing damage to the fracture permeability. The focus of this paper will be on the dissolvable plug used to isolate the stages, which holds pressure for enough amount of time accordingly to the well operations. The design of these plugs also allows them to be used in long horizontal or extended reach wells without concern regarding the mechanical limitations of the coiled tubing during milling phase. The plug performance supports increasing the number of stages in these wells which resulting in higher well productivity while minimizing the well integrity aspect as the milling operation is not required.
Real-Time 3D Imaging of Neat, and Viscosified CO2 in Displacement of Brine-Saturated Porous Media
Authors: Ding Boxin , Kantzas Apostolos , Firoozabadi Abbas 
Published: October 2023

Abstract
CO2 storage in saline aquifers may contribute to a 95% share in preventing emissions to the atmosphere. The process is inefficient due to low CO2 viscosity at the subsurface conditions. Most of the injected CO2 will spread quickly at the formation top and increase the probability of leakage. This work is aimed to demonstrate improved CO2 storage in saline aquifers by effective viscosification/thickening of the sc-CO2 at very low concentrations of engineered polymers and by slug injection. We also present results from X-ray CT imaging to advance the understanding of two-phase CO2-brine flow in porous media and firmly establish the transport mechanisms.
X-ray CT imaging of displacement experiments is conducted to quantify the in-situ sc-CO2 saturation spatiotemporally in brine-saturated Berea sandstone cores. In neat CO2 injection, gravity override and viscous fingering result in early breakthrough and low sweep efficiency. Cumulative brine production is approximately 30% (from fraction collector) and 35% (from X-ray CT imaging) at 2 PVI. The difference between the two is attributed to the solubility of the produced water in the produced CO2 at atmospheric pressure which has been neglected in the past. We show that when the forgotten effect is accounted for, there is a good agreement between direct measurements and in-situ saturation results.
In the past, we have demonstrated that effectiveness of an oligomer of poly(1-decene) in displacement of brine by CO2 at a concentration of 1.5 wt.%. In this work, we show that the same polymer is effective at low concentration of 0.6 wt.%. The oligomer slows the breakthrough by 1.6 times and improves the brine production by 35% in horizontal orientation. Such a large effect is thought to be from the increase of the interfacial elasticity, based on the X-ray CT imaging of displacement experiments. We also show that there is no need for continuous injection of the oligomer. A slug of 0.3 PVI viscosified CO2 followed by neat CO2 injection has the same effectiveness as the continuous injection of the neat CO2. In this work, we also demonstrate the effectiveness of an engineered new molecule at 0.3 wt.% that may increase residual trapping by about 30%. The new molecule has much higher effectiveness than our recent molecule. The combination of mobility control and residual brine saturation reduction is expected to improve the CO2 storage in saline aquifers by effective viscosificaiton with low concentrations of oligomers.
The Traditional Drilling Optimization Conceptually Deadlocked for Realtime Well Engineering: An Alternate Solution
Authors: Samuel Robello 
Published: October 2023

Abstract
The industry has seen several methods of drilling optimization over the years. One of optimization's advantages—namely, its innate mathematical rigor—can also be seen as a disadvantage because of the downhole unknown and uncertain conditions. As a result, the traditional mathematical based models suffer from the optimum drilling parameters being inaccurate and more specifically in a non-convergence deadlock in real time and render useless and may lead to infeasibility when used in real time. To address the issue, in this paper, an opto-satisficed time-optimal batch methodology is proposed that brackets the feasible solution space using various engineering models.
The analysis results have shown that the convergence optimal bound space was very quick in obtaining an optimal drilling parameter in realtime and the predictability in the test wells has shown the best solution results under uncertainty. It has also been found that the results provide reasonable threshold values when more data is used as the well is drilled. As long as the driller stays within the operational region, the results have shown that the operating parameters are satisfying and good enough for the desirable outcome. In other words, a near-normal engineering solution is achieved. It has been found that the methodology can adapt the operating condition by combining the theoretical engineering models with the realtime measurements. The actual results from drilling several wells are used to illustrate the efficiency of this method over the traditional drilling optimization algorithms. Comprehensive results are presented in the paper with various examples with derived operational parameters when the well is drilled in realtime that satisfy the drilling engineers as well.
A Fast and Reliable Network Solver Using Numerical Proxy for Reservoir Simulation
Authors: Yang Yahan , Davidson Jeffrey E. , Verma Kaushal 
Published: October 2023

Abstract
Reliable and efficient modeling of subsea production systems is critical for predicting performance of offshore reservoirs. Iterative numerical procedures are typically required if the production system includes flow networks where wells may compete and interact with each other. The network problem can become challenging since production constraints, hydraulic flow stability, and other issues need also to be considered when solving for numerical values of pressure and rates.
In this work, a new technique, called stability proxy, for solving flow network problems in reservoir simulation has been developed by generalizing the concept of inflow performance relationship (IPR). IPR is traditionally used for representing the quantitative relationship between flow rate and bottom-hole pressure (BHP) or tubing head pressure (WHP) of a well. With stability proxy, IPR-like relationships are constructed for the entire production network, including wells and facilities downstream to wellheads. This approach handles production constraints and hydraulic stability and employs approximation techniques for computational efficiency.
Stability proxy offers several advantages compared to traditional techniques for solving flow network problems. First, stability proxy method determines pressure/rate operating ranges for wells and locations downstream in a flow network. Given a pressure or rate boundary condition, the computational procedure identifies wells that are open to production and wells which cannot flow due to lack of pressure support, flow instability, and other reasons. After well state is determined, rates and pressure anywhere in the flow network can be easily determined from the stability proxy dataset. In contrast, traditional methods for solving the facility network problem start computations assuming wells are open and often require good initial guess to converge successfully. The stability proxy method does not require initial guess, eliminating numerical artifacts from the solution process. Second, performance of traditional iterative approach often degrades when wells are operating near the stability limit, and multiple network calls are often required to ensure that well production allocation is consistent with the network model downstream to wells. With the proxy algorithm, computational efficiency is significantly improved since proxies can be reused in many situations without compromising accuracy. Using stability proxy results, a semi-analytical method is derived for obtaining derivatives of production rates with respect to flow control variables, which provides a fast and convenient tool for quantifying well interference. Effective gas-oil ratio (GOR) and water-cut (WCUT) accounting for well interference are defined for flow networks based on the derivative results. Tests show that effective GOR and WCUT can be used as a more realistic basis for production allocation in field management.