bluuebunny/crossref_metadata_2025_split huggingface dataset:
Stuck Pipe Prediction in Utah FORGE Geothermal Wells
Authors: Montes Abraham C. , Ashok Pradeepkumar , van Oort Eric 
Published: October 2023

Abstract
Four stuck pipe events occurred during the construction of six geothermal wells in the Utah FORGE field, causing several hours of non-productive time (NPT). All of them could have been avoided if effective preventive measures and tools had been used. This paper provides an analysis of these events with the publicly available Utah FORGE dataset and discusses their predictability using a new hybrid approach that can in future be used to avoid stuck pipe incidences at Utah FORGE.
Our analysis is primarily based on physics-based simulations combined with well information, such as trajectory, lithology, and the position of the drillstring (specifically the contact points) with respect to the geometry during the time the events occurred. Based on this detailed analysis, we implemented anomaly detection techniques in the time window before each stuck pipe event to automatically identify root causes. Following this, we formulated guidelines that combine the developed early stuck pipe event detection capability with accepted industry operational practices, to prevent similar stuck events in the future.
The Utah FORGE stuck pipe events were found to be primarily related to wellbore geometry (i.e., mechanical stuck pipe) and use of non-optimum operational drilling practices. The incidents, analyzed in time domain after dimensional transformations, show clear early signs of anomalies in the time frame before their occurrence. This means they could have been detected and potentially prevented. The guidelines include recommendations for acting pro-actively on early stuck pipe indicators identified by real-time data analysis, as well as making appropriate additional changes during well planning and execution phases, such as changing the bottom hole assembly to be less sensitive to mechanical sticking. The work shows the high value of robust predictive models for stuck pipe prevention.
The work will help reduce geothermal well construction (which is expected to expand significantly in the near future) cost by enabling better stuck pipe NPT avoidance. However, the approach is not specific to geothermal well construction and can be expanded to all drilling applications as well as stuck pipe incidents that are non-geometrical in origin. This paper therefore provides a new real-time data analysis system and effective guidelines which, if implemented, will enable better mitigation of stuck pipe risks on future wells.
Oil and Gas Skills for Low-Carbon Energy Technologies
Authors: Tayyib D. , Ekeoma P. I. , Offor C. P. , Adetula O. , Okoroafor J. , Egbe T. I. , Okoroafor E. R. 
Published: October 2023

Abstract
This paper aims to demonstrate the transferable skills of oil and gas professionals relevant to the energy transition and low-carbon technologies. We examined both core technical and non-core technical skills.
The approach to this study involved using the SPE competency matrix for oil and gas professionals and mapping it against the different concepts related to decarbonization and renewable energy sources. We covered core technical and non-core technical oil and gas skills, and how they related to concepts such as carbon capture and sequestration, underground energy storage, rare earth elements, and renewable energy. We graded each item in the oil and gas competency matrix to demonstrate how relevant they were to the low-carbon technologies. We referenced case studies in research where oil and gas skills are being used in several aspects of the energy mix.
The results showed that the technical competencies of oil and gas professionals were most useful in areas such as carbon storage, underground energy storage, and geothermal energy. The study also showed that geoscience skills cut across almost every aspect of low-carbon technologies and other concepts related to the energy transition. We also observed that non-technical competencies such as project management, HSE (health, safety, and environment), and business development skills cut across all low-carbon technologies and were very relevant for renewable energy resources like solar, wind, and hydro. Data science and digital skills were seen to be applicable to all low-carbon energy technologies. Using the case studies, we discuss the required upskilling, reskilling, and cross-skilling.
The novel deliverable of this study is a comprehensive skillset map that shows where the oil and gas skills fit within low-carbon energy technologies. Professionals with skills in geosciences, reservoir engineering, production engineering, drilling, and wells engineering can see what areas they can easily transfer their skills, where they require reskilling, and where upskilling will be required. This could help organizations design a reskilling and upskilling strategy to help oil and gas professionals remain relevant in the energy transition.
Real-Time Performance Optimization Using Temperature Derived Rates to Prevent Productivity Decline
Authors: Izgec Bulent 
Published: October 2023

Abstract
This work presents a well performance analysis technique that identifies formation damage and/ or productivity loss real-time using rates derived from measured well temperatures. It also provides insights into expected damage mechanisms enabling efficient stimulation treatments.
The analytical technique recognizes damage patterns at inception. The diagnostics to drive operational decisions are then presented as simple cartesian plots that grant easy access to users of all levels of experience. Data driven temperature-to-rate models provide continuous conversion of flowing well temperatures to production rates that help automate diagnostics for optimum daily surveillance.
Case studies from several deepwater wells demonstrate how the technique has been successfully operationalized to eliminate productivity losses, gain early insight into damage mechanisms, and investigate the impact of well interventions. Evaluations and comparisons using pressure transient analysis (PTA), rate transient analysis (RTA) and numerical history matching studies conducted with and without temperature derived rates corroborate the robustness of the method. Temperature derived rates exhibit less than 3 % error when compared to well tests, multi-phase, and ultrasonic flow meters.
Shutting in the wells is not required for the analysis, therefore lost production and additional stress cycles on the completion are eliminated. The analysis identifies the maximum drawdown limit, thereby helping the operator optimize well performance real-time. In addition, a data driven approach is outlined for estimating PTA equivalent skin values without shutting-in the wells. Data driven temperature-to-rate models can be developed and maintained with little effort to improve rate allocations, cut back on metering costs, and reduce operational complexities associated with increased number of tests.
Multibarrier Integrity Evaluation in a Field with Active Faulting – A Case Study
Authors: Kotlar N. , Castro Chacon A. , Jimenez Gomez J. A. 
Published: October 2023

Abstract
The producing basins located in Los Andes region of Colombia are often subject to active tectonic stresses and severe faulting. This is exacerbated by uneven formation pressure due to preferential depletion or injection. Due to the large horizontal stresses, the casing often deforms plastically, resulting in buckling, shearing and ovalization. Consequently, the ability to re-entry the well may be compromised, the production can be impacted, and the mechanical properties of the tubulars can also be affected.
The well presented in this study was evaluated using Multifinger Caliper, Electromagnetic thickness measurements and Segmented cement tools. The presence of casing deformation is sometimes masked by the processing steps involved in the data conditioning of the internal radius measurements. Multifinger caliper data automatically corrected for eccentricity does not show obvious signs of deformation, although the pipe tortuosity can be severe. In this well, different deformation mechanisms are identified, and a procedure is proposed to characterize the type and magnitude of these events. Apart from corrosion and internal casing wear, the remnant mechanical properties of the pipe are also impacted by deformation and might result in reduced burst and collapse ratings. Electromagnetic thickness data is used to evaluate this aspect.
Integrating the multifinger caliper results with the cement evaluation logs show that the main deformed intervals lack of annular cement isolation. This was key to understanding the nature of the faults, that not only contribute to well deformation, but are also conductive pathways that lead to fluid and cement losses.
Correlating the deformed intervals and sections with poor cement with the geological descriptions of the field allows identifying, and sometimes predicting, problematic faults and potential high-stress regions of the formation. This has an immediate impact on the field development plans, well design and surveillance programs. Moreover, by establishing a clear workflow to identify and characterize deformation through internal radius evaluation (multifinger caliper or ultrasonic logs), the analysts are better equipped to face similar situations in future evaluation jobs, and also capable to re-analyze existing logs in the field.
This study highlights the value of data integration in cased hole logging integrity evaluation. The combination of the casing integrity and cement logs leads to a deeper understanding of the fields' faulting and stresses, which allows identifying wells that require interventions and integrity evaluation, and is vital information for the management of the reservoir and future well placing.
Beyond API: How to Evaluate Industry Standards for Practical Applications Improving Cementing Fluid Designs and Testing Accuracy
Authors: Shine J. M. , Harris K. L. 
Published: October 2023

Abstract
A standard can represent the foundational instruction for performing any task consistently and enabling repeatable results. Laboratories as well as personnel can apply the practices and techniques documented in standards without the knowledge of the intent – how it relates to managing the risk at the wellsite and achieve the execution success. Within standards there can be instructions which resulted from field experience helping to improve the representative test conditions in the laboratory to overcome risks previously identified. As well operations evolve, cement placement and the resulting laboratory testing evolve aligning with standard organizations using a reaffirmation process for documents over time. As standards tend to omit acceptance or evaluation criteria due to differences of opinion across the industry or potential misinterpretation by regulatory agencies, the manuscript serves as a complimentary document helping to identify risks during wellsite execution and a means to optimize designs with suggested evaluation criteria as well as test method modifications when applicable.
Thin Bed Analysis Workflow for Low Resistivity Pay in Clastic Reservoirs in the Permian
Authors: Allen D. , Kostinovsky A. , Wang H. , Lujan V. , Laronga R. , Wang G. , Chertova A. 
Published: October 2023

Abstract
Low resistivity pay is a perennial challenge in clastic intervals of the Third Bone Spring formation in the Permian Basin. Water saturations from resistivity are high, and it is difficult to identify productive intervals or to assess oil in place. We show that the primary cause is thin water bearing layers interbedded with the productive layers. We propose a new bimodal resistivity anisotropy model and workflow to better characterize the formation.
Amulti-well core-log integration study was conducted to understand the cause of the low resistivity pay and develop a workflow to address it. High resolution core analysis clearly shows the occurrence of beds of varying shaliness on the scale of inches corresponding to intervals of interest with high apparent water saturation. Increased resistivity anisotropy in these intervals indicates the presence of alternating high resistivity and low resistivity layers. Overall lithology, fluid typing and pore size indications from 2D NMR, were integrated to develop a petrophysical model for these formations, leading to a workflow for their evaluation.
Water saturation and inferred lithology of the high resistivity beds are computed, along with quantification of the fraction of interbedded water bearing layers. This more complete analysis forms an improved basis for decision making.
The overall proportion of silt and shale in the formation are estimated from the clay volume from elemental spectroscopy logs. The silt and shale are apportioned between water bearing and resistive beds assuming that the resistive beds are more likely to be silt. We thus obtain an indication of the volume of silt in the resistive layers, a useful indicator of reservoir quality, by the degree to which the overall volume of silt exceeds the fraction of water bearing layers.
Another key step is high resolution inversion of triaxial induction data. This reduces the impact of high resistivity carbonates on the measured vertical resistivity, compared with conventional lower resolution one-dimensional (1-D) inversions.
This model is a departure from resistivity anisotropy analyses previously used to evaluate thinly bedded formations based on a bimodal sand-shale model in other geological environments. The sand-shale model, in which the hydrocarbons are assumed to be in the sand layers, cannot be directly applied to these formations because the shales are often the zone of interest: they can and do contain producible hydrocarbons.
Patented Surface Automatic Valve to Maximize the Recovery of Light Oil, Condensate, and Gas from Depleted Reservoirs with Minimum Manpower Interaction and Without External Energy to be Operated
Authors: Faustinelli J. , Granadillo J. , Correa C. , Sandoval J. , Jardin M. , Genua S. , Rodriguez A. , Diaz I. , Navas S. , Chirinos R. 
Published: October 2023

Abstract
This Surface Automatic Valve (SAV) is designed to recover and optimize the production from light oil, condensate, and gas within depleted reservoirs, which are no longer economically viable with the current technologies on the market. It is manufactured in stainless steel allowing operation in wells with acid and aromatic crudes. The valve's operation demands little maintenance and reduces the exposure of personnel associated with accessing fields located in geographically challenging areas.
The completion design, surface pressures and choke valve use are the initial components analyzed when determining the applicability of the SAV in the well. Some simulations are performed in advance to configure the tool at optimized pressures.
The valve's interior features two sensors that allow the opening and closing of the well at calibration pressures. When the well reaches the high pressure, it contracts and allows the well to produce. As the pressure decreases and until it reaches the low pressure, the valve closes automatically, and the cycle repeats indefinitely.
The installation time of the SAV in the choke spans up to 3 hours, and the well is monitored for its correct operation. The results are obtained using a Barton chart installed in the wellhead to record the opening and closing of the tool by 72 hours (recommended). The curves for each production cycle are analyzed through mathematical equations to recalibrate the tool if necessary.
Among all the results obtained, there was one well to highlight because it was closed by its non-productivity and the impossibility of using other market technologies to operate profitably without external energy.
The well was reactivated by installing the SAV at the opening and closing pressures as per the simulations, working without issues during the testing time, minimizing the presence of field operators to supervise the well, and recording the production at the end of the trial with 20 BOPD and 360 MSCFPD in average, profiting from a well in sequence for plug and abandon.
The SAV has been successfully installed and tested in two countries. Test approval certificates were provided by each OPCO in these cases.
In summary, the SAV, unique in the market and patented with the number 11,473,402, assists in reactivating non-producing and optimizing low production wells. It uses the same energy from the reservoir to be operated without external sources, and refrains from impacting the surface footprint. It can work with corrosive crude and the installation process proves simplistic with minimal human intervention. While the valve's operational risks are minimal, it is being studied for integrity purposes with Sustainable Annulus Pressure (SAP) wells.
Machine Learning Application for CCUS Carbon Storage: Fracture Analysis and Mapping in the Illinois Basin
Authors: Liu G. , Kumar A. , Harbert W. , Siriwardane H. , Crandall D. , Bromhal G. , Cunha L. 
Published: October 2023

Abstract
A significant volume of anthropogenic carbon dioxide (CO2) is being injected into geological reservoirs at multiple locations throughout the United States. These operations have gained considerable traction in the last decade as a viable option to reduce the long-term environmental footprint of greenhouse gas emissions. However, monitoring the storage reservoir to ensure safe and long-term storage of CO2 for de-risk operations and storage management is undergoing dynamic shifts, expanding opportunities for implementing innovative techniques and applications, especially for the commercial-scale deployment. In this paper, an innovative method comprising multi-tiered analysis has been developed to leverage advanced machine learning (ML) techniques to process passive seismic monitoring data acquired over the two-year injection period along with pumping/injection pressure and rate in the Illinois Basin for potential fracture/fault analysis. Moreover, well log data including imaging logs and core test results are also integrated in the study to add another angle of the understanding for fracture. This study is aimed at contributing to the risk assessment and monitoring design for carbon capture, utilization and storage (CCUS). As a continuation of this effort, we intend to compare the spatial distribution of fractures with the available well logs and core data to deduce a comprehensive understanding of how these fractures correlate with the rock petrophysical properties. The fracture networks obtained from this study would directly benefit field operations and reservoir management decision-making for CCUS, which include the dynamic injection scheduling/workover, risk assessment, and further monitoring design. Furthermore, for ecosystem benefits, the proposed methodology is potentially applicable to oil and gas and renewable assets, such as geothermal development for their fracture-based monitoring and risk reduction as well.
Stress Path of Heterogeneous Rock Layers within the Subsurface
Authors: Su Xing , Mehrabian Amin 
Published: October 2023

Abstract
This paper presents a three-dimensional analytical solution for stress path within and around a porous rock formation upon depletion. The depletion profile is assumed to be axisymmetric, and the depleted rock layer resides in between two impermeable rock layers. The mechanical properties of the porous and confining strata are different. Variations in the in-situ stress value or orientation are obtained and presented. Strong dependencies of the in-situ stress change on stiffness contrast between the depleted and burden rocks, as well as the aspect ratio of depleted rock volume, are discussed. Uniaxial strain models are shown to fall inadequate of predicting the correct reservoir stress path.
Effect of Residual Oil Saturation and Salinity on HPAM Rheology in Porous Media
Authors: Seright R. S. , Azad Madhar Sahib , AlAbdullah Mohammad B. , Delshad Mojdeh 
Published: October 2023

Abstract
During polymer flooding, the velocities where shear-thickening occurs directly impact HPAM injectivity, fracture initiation, and whether viscoelasticity is significant in oil recovery. The onset velocity for shear-thickening in oil-free porous media is known to translate with the square root of permeability-porosity. However, few studies report HPAM rheology with residual oil present, and those conflict and are inconsistent with behavior seen without oil. This paper experimentally clarifies how Sor, salinity, and temperature impact HPAM rheology in rock.
HPAM rheology at 20°C was determined in Berea sandstone for Darcy velocities from 0.01 to 100 ft/d, Sor from zero to 0.55, and krw from 0.03 to 1. In a given experiment, the core was first exposed to the highest pressure-gradient for the test series. After stabilization, resistance factors were recorded and effluent viscosity was measured. Next, the velocity was halved, and the stabilization and measurement processes were repeated. This procedure was extended in steps to the lowest velocities. We also studied the effect of salinity on HPAM rheology in porous media between 0.105% to 10.5% TDS for 0.1% and 0.2% HPAM (at 20°C). Temperature effects on rheology in Berea from 20°C to 60°C were investigated using 0.2% HPAM in 0.105%-TDS water.
This work provides key information that will be crucial to establishing whether HPAM viscoelasticity can play a significant role in recovering oil in field polymer floods. It also provides crucial information for analytical/numerical efforts to establish when fractures will initiate and how far they will extend from the wellbore during polymer flooding field applications.