bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evolution of Ethics Frameworks in the Oil and Gas Organizations and Professional Societies
Authors: Capello Maria Angela , Howes C. Susan 
Published: September 2022

Abstract
The term "ethics" as a set of rules is used in the professional world as well as in professional societies to establish what is acceptable or not, in terms of ethical professional behavior. This paper explores how the practices and codification of practices related to professional practice have evolved in the Oil and Gas sector, with emphasis on professional societies.
The analysis was performed summarizing the history of ethics in general, as applicable to the Oil and Gas sector. Then, research was conducted on how the several important corporations in the upstream or downstream of oil and gas initiated and evolved their own ethical codes. We also explored how the academic world has engaged in issuing Codes of Ethics that govern the behavior of both students and faculty members at the institutional and department level. A special emphasis was placed in the investigation of the evolution of the Code of Ethics of the main professional societies and organizations related to the Oil and Gas Sector, centered on SPE, and including AAPG (the American Association of Petroleum Geologists), SEG (the Societu of Exploration Geophsyicists), EAGE (the European Association of Geoscientists and Engineers) and other relevant ones.
The conclusions point to a realization that the ethical codes analyzed evolved, following societal changes, in relation to under-represented groups in terms of gender, race, nationality, age, religion and ethnicity, as well as in relation to the expansion of the industry to more and new geographical areas. Currently, almost all organizations and professional societies have a Code of Ethics that profiles their main values and sets a frame for what is or not appropriate in advancing their activities. The Code of Ethics were gradually expanded, spelling out further specific rules, often called "Statements" like "Sexual Harassment," "Bribery" and "Human Rights" statements, aiming to address a variety of specific issues. The Code of Ethics, along the specific self-disclosure statements, are the ethical framework of organizations in Oil and Gas for guiding employees and stakeholders towards:
– Alignment with Corporate and/or Academic Values. – Clarification of the Value Proposition for employees and/or prospective students. – Response to societal trends like "MeToo," "BlackLivesMatter," and others. – Rejection of modern issues affecting some industrial segments like Modern Work Slavery. – Enhancement of the corporate prestige and rankings in ESG (environmental, Society and Governance) grounding disclosures useful for investment decisions
Our paper is a contribution to share information and raise our collective awareness in the profession about what is the current practice in Oil and Gas regarding Codes of Ethics of Corporations and Professional Societies, how they have evolved, and what are the current and future challenges and opportunities, to expand solid and useful ethics frameworks in the context of the present rapid social transformation.
Design and Qualification of a New Erosion Resistant Sand Control Screen
Authors: Malbrel Christophe , Blackburne Edward 
Published: September 2022

Abstract
The issue of screen erosion is a complex problem that doesn't lend itself very easily to modeling and computer aided design, particularly when it comes to metal mesh screens. Interactions between solid and liquid (settling/suspension) and between the solids and the screen material (plugging) are complex and evolving over time due to wear and fluctuations associated with multiphase flow or other reservoir related changes over the life of the well. As a result, screen development is best performed using pilot testing to simulate downhole conditions and optimize the design. In that regard, the setting of standard performance tests is essential.
A series of time lapse erosion tests performed on mesh screens recently highlighted the benefits of shielding the screen from the basepipe perforations to improve erosion resistance. This new feature provided several fold improvements in the mesh screen erosion resistance and was implemented in a novel screen design. It consists in placing a partially perforated inner shroud underneath a regular screen cartridge, with blind spots precisely located over the basepipe holes to prevent direct line of sight flow and reducing local velocity by diffusing flow across the entire screen area.
An extended continuous erosion test was used to validate the design and qualify metal meshes, and mechanical testing as per the new API19ss standard for sand control screens was performed to qualify the new screen and demonstrate its reliability.
Comparing the performance of the new screen design against similarly built screens confirmed that the addition of the new diffusion shroud does not adversely impact the mechanical performance of the screen while imparting improved erosion resistance to the screen.
Laboratory Investigation of Chemical Tracers vs. DNA Tracers
Authors: Asadi Mahmoud , Blair Tyler , Comstock Sarah 
Published: September 2022

Abstract
A new and robust tracer technology is introduced based on encapsulated Nano-sized synthetic DNA. This cutting-edge technology enables bonding of synthetic DNA strands with unique sequences to a magnetic core particle and encapsulating them with silica making it possible to have unlimited number of identifiable tracers, each with a unique signature. Each manufactured batch of DNA tracer is then coated with a special chemical to make the batch water-wet or oil-wet. The presented novel technology of encapsulated Nano-sized DNA tracers is shown to be superior to the currently used water chemical tracers, fluorobenzoic acid or FBA, in many ways both in the applications of EOR and flowback analyses in hydraulic fracturing. Unlike the chemical tracers, the DNA tracers don't partition, don't chemically react with the formation minerology, don't disintegrate with time, are stable at high reservoir temperatures and don't lag flood front velocity if used in secondary recovery projects such as waterflooding. In addition, unlike the available limited number of chemical tracers, there are unlimited number of identifiable DNA tracers. In waterflooding, the DNA tracers are used to characterize fluid flow accurately and precisely in a reservoir and to identify heterogeneity of the reservoir. The technology can also be used to evaluate flowback analyses in hydraulic fracturing to fully understand fracture behavior, pipeline leakage identification, groundwater movement, contamination tracking in water streams, etc.
Transient Analysis of Sandface and Wellbore Temperature in Naturally Fractured Geothermal Reservoirs: Numerical and Analytical Approaches
Authors: Wei Cao , Cheng Shiqing , Shi Dengke , Liu Dawei , Liu Xiuwei , Gao Ruilian , Wang Yang , Yu Haiyang 
Published: September 2022

Abstract
This work presents the numerical and analytical temperature solutions that couple the transient reservoir/wellbore thermal models to analyze the temperature measurements recorded at producing horizon or at a certain gauge depth above it for estimating the physical and thermal properties of naturally fractured geothermal reservoir (NFGR) during drawdown and buildup periods. The NFGR is replicated by a more general triple-porosity system adopted from Abdassah and Ershaghi model. We first develop numerical and analytical solutions to predict the sandface temperature in NFGRs, accounting for the Joule-Thomson (J-T) effect, adiabatic heat expansion/compression effect, heat convection and conduction. The developed numerical solution is verified and found to agree with the proposed analytical solutions. Then, the wellbore heat flow model adopted from Hasan and Kabir model is coupled with NFGR model to predict the wellbore temperature at a certain gauge depth above producing horizon.
The results show that three heat radial flow regimes and two thermal inter-porosity regimes have been identified. It is demonstrated that the early-time heat flow is dominated by the adiabatic heat expansion/compression effect, and the intermediate- and late-time heat flows are dominated by J-T heating/cooling effect. It is demonstrated that thermal properties such as J-T coefficient, adiabatic heat expansion coefficient and fracture intrinsic porosity can be estimated through temperature transient analysis, which are not accessible by pressure data. The results also show that when the gauge location is near the producing horizon, the heat transfer regimes keep almost identical to sandface during drawdown period. As the distance between the gauge location and producing horizon increases, drawdown-wellbore temperatures are more dominated by wellbore heat loss, thereby may miss some information contents from reservoir. Moreover, buildup-wellbore temperatures are usually dominated by wellbore heat loss and do not exhibit any discernable flow regimes even though gauge location is near the producing horizon. It is demonstrated that wellbore temperature derivative exhibits unit slope at early times for drawdown and buildup periods. Finally, we develop an integrated semilog-straight-line analysis workflow of combining sandface pressure and temperature data to estimate NFGR properties. Synthetic test example is interpreted to demonstrate the applicability of the developed workflow.
An Experimental Study on Two-Phase Downward Flow of Medium Viscosity Oil and Air
Authors: Ualiyeva Gulnur , Pereyra Eduardo , Sarica Cem 
Published: September 2022

Abstract
The gas-liquid downward flow is the least studied flow condition, which is critically important in predicting the flow between two platforms in offshore systems and wells for CO2 injection for CCSU applications. These processes require a reliable prediction of pressure drop and phase fraction. This paper focuses on the liquid viscosity effect on downward gas-liquid flow. Flow patterns, pressure drop, and liquid holdup are measured for downward vertical and near-vertical flow. The acquired data are compared with available mechanistic models, and the discrepancies are discussed. The 2-in ID oil/water/gas outdoor facility of The University of Tulsa Fluid Flow Project has been used for this effort. The facility is 22.72 m long and is operated with medium viscosity oil and air. Liquid viscosity is fixed at 40 and 70 cP by controlling the temperature. Superficial liquid and gas velocity ranges are 0.1 – 0.3 m/s and 0.5 – 5 m/s, respectively. The inclination angle is varied between 60 and 90° with a 10° increment. Visual observations and Capacitance Sensor (CS) signals are utilized to determine flow patterns. Facility instrumentation also allows measuring pressure gradient and liquid holdup. Two classic flow patterns observed were: stratified and annular flows. Stratified is further sub-classified as stratified wavy and stratified wavy with a thin film. Annular flow is sub-classified into falling film, liquid slip, and wavy annular. Experimental interfacial shear stress (τI) and wall-liquid shear stress (τWL) were compared to model values. Existing models and commercial simulators show very poor performance in downward flow and need further improvements.
Leveraging SME Knowledge with Big Data Multiply the Value of Both
Authors: Van Kuilenburg Robert , Handels Martijn 
Published: September 2022

Abstract
With Managed Pressure Drilling (MPD) getting more common, its rubber seals increasingly become a source of potential downtime during drilling operations. The common approach is to provide monitoring towards relevant stakeholders via expert consultants and elaborate reporting. This is costly and time-consuming. Next to monitoring and reporting, accurate prediction of the wear and tear on the rubber seal is essential. Within technology partnership, a real-time monitoring and proactive advisory tools have successfully developed and implemented. First, a scalable data infrastructure has implemented, unifying process data from the MPD and drilling systems into a single database. Second, a hybrid seal wear prediction model has been developed, combining a model-based approach with regression analyses. Key to the success was the feedback loop between operation and engineering. This included pre-and post-run inspections and measurements on the seals tied to the operational parameters. Thirdly, repetitive reports got generated automatically for daily operations, connections and seal wear. The advanced MPD condition monitoring solution was successfully developed by combining expertise in operations and engineering with data analytics skills. It emphasizes the fact that big data works best when it is part of a solid data framework, that takes domain knowledge and users into account.
Modeling and Forecasting Enhanced Condensate Recovery from Rich Gas-Condensate Regions in Eagle Ford
Authors: Amini Kaveh , Kazemi Hossein 
Published: September 2022

Abstract
The development of unconventional reservoirs is strongly affected by the reliability of the production forecast and project economics. This paper has addressed these issues by analyzing the performance of several wells using both analytical and numerical modeling. For instance, after history matching a portion of each well's production history, we forecasted the remaining portion of the well's production history using the early history-matched model parameters. Next, using mathematical models, we studied the feasibility of Enhanced Condensate Recovery (ECR) to increase condensate production and to utilize and store CO2.
This research study includes multi-phase rate transient analyses of five wells and a pressure build-up test on one of the wells to calculate the stimulated permeability of the SRV region. Moreover, decline curve analysis of 34 wells in four well-groups (based on their landing zones) indicated that the wells in three landing zones had similar ‘Oil EUR’ while wells landed in the region between Austin Chalk and Eagle Ford had the highest ‘Gas EUR’.
Our Eagle Ford compositional reservoir model consisted of three horizontal wells in the liquid-rich volatile oil region. After matching the production history of the wells, our model correctly forecasted the future performance of the wells. Furthermore, the input permeability of the SRV region in the history match was two orders of magnitude higher than the core permeability—confirming permeability enhancement resulting from hydraulic fracturing.
The history-matched compositional reservoir model was used to study cyclic (Huff-n-Puff) CO2, lean wet gas, and dry gas ECR to evaluate the potential of improved condensate recovery. Each of the three injected compositions indicated considerable enhanced condensate recovery (ECR). The enhanced condensate variability was further studied by changing cycle length, injection rate and injection pressure. The optimum CO2 enhanced condensate recovery was obtained by injecting CO2 for 60 days followed by 180 days of production. The incremental condensate production after 4 cycles increased by 19% above the primary production with a net CO2 utilization of 8550 scf per bbl of incremental condensate.
Frac Optimization by Sand Entry Distribution
Authors: Shan Youngbin , Zeng Bo , Roberts Glyn , Wu Yaoguang , Song Jie , Zhou Dan 
Published: September 2022

Abstract
Billions of dollars are invested into hydraulic fracturing every year. However, how to optimize frac design parameters such as stage and cluster spacing, fluid and proppant volume into each stage, number of perforations per cluster and temporary isolation is still not clear.
This paper proposes a new method to estimate the volume of proppant penetrating each perforation hole. By aid of high-resolution optical imaging technology, perforation hole size before and after frac treatment can be accurately measured and interpreted. The difference in area before and after Frac is the eroded perforation area. Eroded area represents the sand entry into a perforation. Sand Entry Distribution (SED) determines the frac efficiency. Better SED gives better frac efficiency.
Operators understand that different frac treatment volumes and different cluster versus perforation holes designs will impact the productivity. With the technology proposed in this paper, different frac designs can be measured and calculated using SED. A better SED in a cluster and/or a stage is certainly a better frac design.
The method described in this paper estimates the proppant volume penetrating into each perforation hole after frac. Furthermore, a number of statistics and comparison between clusters and stages are described in the paper to give operators a clear indication of which frac design gives better frac efficiency and more uniform distribution.
Numerical Simulation and Field Verification of the Cutting Efficiency of 3D Shaped PDC Cutters
Authors: Li Chengxi , Ke Xiaohua , Guo Jianhua , Peng Qi , Ma Chi , Yu Jiaqing , Cheng Chris 
Published: September 2022

Abstract
Improving well-drilling technology is increasingly important in the oil and gas industry. Among these efforts, the continuous improvement of the polycrystalline diamond compact (PDC) drill bits is particularly significant. The PDC cutter is a crucial element of a PDC drill bit and the determining factor for the bit performance. Thus, optimizing the design of PDC cutters will improve drilling efficiency and reduce operational costs. Using the finite element method, this paper aims to develop a numerical model to accurately evaluate the cutting efficiency of 3D shaped PDC cutters and, in turn, facilitate the cutter shape design optimization. In this study, we used the Drucker-Prager plastic model with a damage law to simulate the constitutive behavior of the rock. The parameters used in the Drucker-Prager model were obtained by matching the numerical rock unconfined compressive strength (UCS) test results with the actual rock UCS testing data. We simulated the rock cutting process using the developed rock model. We compared the cutting forces, normal forces, and mechanical specific energies (MSEs) of various 3D-shaped cutters with those of the flat cutter. Finally, we verified the accuracy of the numerical model with lab tests and field trials. From numerical results, we found that 3D-shaped cutters’ cutting forces, normal forces, and MSEs are significantly smaller than those of the flat cutter, and such differences become more and more pronounced as the depth of cut (DOC) increases. Specifically, the difference of MSEs between the 3Dshaped cutters and the flat cutter increases from 8% at DOC of0.5mm to 23% at DOC of 4mm. The lab results verified the accuracy of the numerical results. Through field tests, we further compared the performances of the 3D-shaped cutter PDC bits with the flat cutter PDC bit. The 3Dshaped PDC bits had increased footage by 28% and a rate of penetration (ROP) of 9% in real-life applications. In this study, we developed a field-proven rock cutting finite element model which effectively and reliably facilitated the design of 3D-shaped cutters. Compared with lab-based methods, the numerical model can predict the cutting efficiency of 3D-shaped cutters at a much lower cost. By utilizing the numerical model, we can efficiently evaluate and thus quickly optimize the performance of the design of 3D-shaped PDC cutters.
Application of Remote Sensing Techniques to Detect Methane Emissions from the Oil and Gas Sector to Assist Operators with Sustainability Efforts
Authors: Esparza Ángel , Ebbs Michael , Gauthier Jean-François 
Published: September 2022

Abstract
The general concept of sustainability lies in the vision that incorporates the economic, social, and environmental dimensions. The energy sector has been addressed as one of the main contributors to emissions of anthropogenic greenhouse gases. Therefore, sustainability in the oil and gas (O&G) industry is mainly associated with the advancement in environmental and social performance across the industry. Individual firms, particularly those belonging to the O&G sector, are now assessed for their environmental, social, and governance (ESG) performance and their impact on climate change. To meet the different key performance indicators (KPIs) for corporate social responsibility (CSR) and ESG, the planning, development, and operation of O&G infrastructure must be conducted in an environmentally responsible. This paper discusses how methane detection of O&G infrastructure using remote sensing technologies enables operators to detect, quantify, and minimize the emissions while gaining insights and understanding of their operations via data analytics products. The remote sensing platforms accounted are satellite and aerial operating in tandem with data analytics to support sustainability initiatives and ESG metrics. This paper presents examples of measurements at O&G sites taken with GHGSat's satellites and aircraft platforms, showing evidence of methane emissions. A discussion of each platform and how they work together is presented. In addition, this paper discusses how these data can be used to achieve sustainability goals and tools for ESG initiatives through analytical models.
Use of Horizontal Drilling for CO2 Sequestration in Low Storage Capacity Aquifers: from Impossible to Feasible
Authors: Panchal Yashesh , Amirlatifi Amin , Sameh Omar , Mostafa Mahmoud , Ovalle Adriana , Abou-Sayed Omar , Mohamed Ibrahim Mohamed 
Published: September 2022

Abstract
The United States Department of Energy (DOE) Carbon Storage Assurance Facility Enterprise (CarbonSAFE) focuses on developing geological storage sites that can accommodate more than 50 million metric tons of Carbon Dioxide (CO2) over 25 years period. Few formations can accept this volume of CO2 through one classic vertical injection well. Multiple injection wells are usually needed to handle the targeted CO2 volume, with well spacing of several miles to avoid any pressure interference between the injectors.
Nebraska is among the largest ethanol-producing states in the USA, with 25 ethanol plants that produce more than 17 million metric tons of ethanol per year. These plants produce a significant volume of CO2 as a typical ethanol plant produces around 150,000 metric tons of CO2 annually. Several techniques have been proposed to capture and sequestrate the emitted CO2, including mineral carbonation and carbon geological storage. Among these techniques, carbon geological storage is the most feasible option, especially sequestration in deep saline aquifers because of the larger volume that can be stored underground, and lower cost compared to the other techniques.
Most of the ethanol plants are located on the eastern side of the state, while geological evaluation suggests that thick aquifers that can handle the large volume of CO2 are located in the southwest area of the state. Due to the high cost of building more than 100 miles of pipeline to transport the CO2 from the source to the injection point (pipeline costs around one million dollars per mile), thin aquifers have been identified locally near the plants to receive the generated CO2 volume. However, conducting CO2 injection operations through multiple scattered wells will increase the anticipated cost, including pore space rights, well drilling cost, land acquisition, CO2 transportation between sites, multiple injection systems and high-pressure pumps, labor, and injection monitoring.
Drilling horizontal wells can maximize the volume of CO2 that can be injected in a single well at lower injection pressure than a vertical well. The long horizontal section will expose a larger formation volume and increase the surface area available for CO2 to flow through.
St. Peter formation has been identified as one of the thin candidate formations to inject CO2 in the eastern part of Nebraska. The injection modeling conducted in this study shows that a single horizontal well with a lateral of 2,000 to 3,000 ft can replace at least three classic vertical injection wells.