bluuebunny/crossref_metadata_2025_split huggingface dataset:
Risk Mitigation Measures Implemented by Use of Expandable Liner to Prevent Alpha-beta Gravel Pack Failure When Unstable Shale Formation is Exposed
Authors: Ioan Tiberiu , Essmat Nooruldeen Zeyad , Moroni Gianluigi , Sallis Jonathan Neil 
Published: September 2022

Abstract
Current oil and gas volatile market environment and the increase focus towards sustainability, it is essential to develop more economically and ecofriendly technologies in oil and gas industry environment. Maintain well integrity is mandatory towards developing oilfields to contain the reservoir fluids within the wellbore, however it becomes more critical in developing new underground gas storage reservoir in Italy. During construction phase of gas production and storage wells, one goal, besides hydraulic isolation of the production casing with cement, is the sand production containment during production cycle of the field. Sand production, even in small quantities, will eventually erode downhole and surface equipment leading to potential catastrophic scenarios of uncontrol reservoir fluid reaching surface. These can have significant health, environmental, and economic impact. Additionally, the impending need for well intervention, along with high re-entry costs, will further weaken revenue margins.
In high permeability reservoirs required for underground gas storage projects, the injection and production cycles can lead to stresses applied in nearby wellbore formation which will destabilize the sandstone grains leading to sand production. To mitigate the sand production into the wellbore, a gravel pack operation will support the wellbore, consolidating the space behind the production screens.
In this field, a high-risk failure was identified for traditional alpha-beta gravel pack methodology. This could lead to expensive recovery operations for the client and service provider to restore the well and re-perform the gravel pack. To tap different part of the reservoir, one well in particular had to be sidetracked from 9-5/8in casing resulting in a long clay interval being exposed susceptible of instability. It was required to isolate this interval to avoid disturbing the clay interval during gravel pack operations, however, to accommodate the completion, the optimum solution was to use expandable liner. Using this zonal isolation technique to regain well integrity, along with redesign of gravel pack carrier fluid technology led to a successful job securing client position as a reliable field operator. The field operator was committed for high level of safety during operations, starting from design phase through the execution, to achieve long-term well integrity and performance.
Reservoir Fluid Geodynamics using Logging-While-Drilling Downhole Fluid Analysis: A North Sea Case Study
Authors: Betancourt Soraya S. , di Primio Rolando , Blanco Yon , Stirø Øyvind , Lopes Velerian S. , El-Khoury Jules , Dykes Thomas A. , Mullins Oliver C. 
Published: September 2022

Abstract
We present a case study of the application of Fluid Mapping While Drilling (FMWD) to acquired logging-while-drilling downhole fluid analysis (FMWD-DFA) in the development stage of a North Sea reservoir. An extensive Wireline DFA (WL-DFA) dataset and Reservoir Fluid Geodynamics (RFG) study helped characterize fluid variations in the exploration and appraisal stages of this field revealing a complex reservoir charge history that results in fluid variations throughout the field and furthermore revealing connections between reservoir quality/productivity and in-situ fluid properties. In the development stage, knowledge acquired in the previous field phases guided well placement decisions and FMWD-DFA was used actively in well construction to validate and enhance the fluid model in this field.
FMWD pressure and DFA measurements were acquired in five development wells in the field: three horizontals and two high-angle pilots. DFA measurements provide fluid composition and optical density, which correlates directly with the asphaltene content of the oil. Asphaltene gradients are modeled to assess thermodynamic equilibrium conditions and investigate lateral and vertical connectivity. DFA and other data streams integrated by the RFG analysis provided the base model: a relatively recent secondary migration of light hydrocarbon into the reservoir that resulted in different realizations of the mixing process depending on distance from the charge plane and rate of mixing. Well trajectories were designed to target sweet spots based on appraisal data; however, some level of uncertainty remains when entering the development stage. FMWD-DFA was used to understand fluid property variations throughout the field that may be associated to geological factors or resulting from fluid mixing processes that may yield localized asphaltene instability. FMWD pressure and mobility measurements complement this model and enable an assessment of current levels of pressure depletion from production in a neighboring field in hydraulic communication through a shared aquifer.
This field example shows integration of DFA technology from different acquisition platforms at different stages of the life of the field. It illustrates how this technology is used to improve the understanding of the complex fluid variations in this field and make development decisions such as optimizing well design by ensuring placement within reservoir sweet spots.
Finally, a Low Cost and Autonomous Method of Generating Corrected Mechanical Specific Energy for Improved Decision Making, Drilling Performance, and Rock Property Characterization
Authors: Kilb Justin , Brame Brandon , Anderson Kaleb 
Published: September 2022

Abstract
Despite decades of research focused on Mechanical Specific Energy (MSE), drilling operations still fail to operationalize MSE as the primary drilling-based performance indicator. This is partly because the availability of MSE in Electronic Drilling Recorders is usually calculated with surface measurement, which fails to isolate energy spent solely at the bit. Removing energy spent along the drill string is important because it allows operators to establish an expectation of the total energy necessary to overcome the confined compressive strength (CCS) of the rock. Once this baseline is established, an increase in MSE versus the CCS can be recognized as wasted energy and therefore, inefficient drilling.
Methods to correct MSE exist but are time-consuming when done manually and may require specialized software. As a result, scaling corrected MSE can be challenging. To address these issues, this paper presents an accessible MSE at Scale workflow that provides a fully automated, physics-based drilling efficiency and design platform for full-fleet implementation. The methods included explore a wide breadth of optimization techniques that can be utilized by operational personnel and autonomous drilling rigs, thus also supporting the future of physics-based intelligent drilling systems.
After discussing the data pipelines and methods of calculation, drilling results from over half a million lateral feet are presented. This analysis is separated into two workflows: Big Data MSE for design optimization and rock characterization, and real-time MSE streaming for operational guidance. A new MSE versus rate of penetration process is introduced, which will allow operators to determine a bit’s maximum formation specific performance (MFP), in one run, regardless of operating conditions. Additionally, generating high-resolution corrected MSE, per foot, provides an alternative and in-situ solution for CCS that does not require petrophysical software or log data. Lastly, a new Cumulative MSE process is introduced to offer a change of perspective in the way we understand and measure bottom hole assembly (BHA) durability.
The latter half of this paper discusses derivations of the MSE equation to offer power-based metrics that are more intuitive than MSE and therefore, may be easier to adopt in field-operations. This is because BHA power, which is a function of rotational energy, presents a consistent and predictable diminishing of ROP returns. This relationship appears to behave similarly to the founder point, yet it is predictably adaptive to drilling parameters beyond solely weight on bit. Finally, this paper discusses a machine learning technique to detect real-time drilling performance that can potentially indicate failing or weakening BHA equipment.
Remediation of On-Bottom Stability (OBS) Issue During Offshore Installation of Light Weight Structure (LWS) at Malaysia Water
Authors: Helmi Bin Ngadiman , Szaini Zainal Abidin , Faizal Shahudin , Nur Dalila Alias 
Published: September 2022

Abstract
This technical paper presents the strategy adopted by COMPANY for Remediation of On-Bottom Stability (OBS) Issue during offshore installation of Light Weight Structure (LWS) at Malaysia Water at water depth of 54m. The knowledge sharing is based on the successful remediation work in managing the OBS issue where the substructure experience excessive tilting.
The LWS is designed with minimal mudmat. In addition to that, the subsea pin pile is designed to improve substructure on bottom stability issue during substructure installation. However, during actual offshore installation of substructure, the behavior of the substructure upon setting down on seabed was not as per the intended design where the substructure tilting is observed after substructure landing onto pin pile.
As mitigation, the following approaches have been implemented to safeguard the substructure from toppling:
Safeguard of Substructure Risk assessment and immediate action have been taken by temporary safe holding the substructure by connecting holdback lines between substructure and installation barge bollards. Revisit OBS engineering study and analysis Revisit on bottom stability engineering study and lifting analysis considering changes to procedure/method by increasing the initial pile length (82m) to allow for early self-penetration. Revisit pile installation and sequence The piles have been re-fabricated onboard installation barge by utilizing the chaser rack at DB portside. The chaser rack was fabricated at site with available surplus material onboard DB. Once the revised pile fabrication completed, the piles were installed into the substructure leg for self-penetration. Result of Remediation Work After successfully securing the substructure by installing the 82m pile length at one (1) leg of substructure, it has resulted that the substructure OBS has been improved to allow the COMPANY to proceed with original installation plan sequence as per installation procedure. Ultimately, COMPANY has managed to avoid catastrophic event.
Despite all the challenges, the installation of LWS were completed successfully, no damage to property and most importantly with Zero Lost Time Injury (LTI).
Geological Storage of Carbon Dioxide and Hydrogen in Jordanian Shale Formations
Authors: Samara Hanin , Von Ostrowski Tatjana , Jaeger Philip 
Published: September 2022

Abstract
The success of large-scale geological storage of gases highly depends on the interfacial properties and gas adsorption capacity of the formation in question. To infer a clear understanding of the behavior of hydrogen (H2) and carbon dioxide (CO2) at conditions relevant to their storage, a systematic study relating pressure to the gas adsorption capacity of Jordanian shale formations is conducted. Additionally, the pendant drop method and the Axisymmetric Drop Shape Analysis technique are used to measure and evaluate brine-gas interfacial tension (IFT) as a function of pressure and salinity at 333 K. The wettability of Jordanian shale is also measured using the sessile drop method at different gas pressures and varying salinities. The results show that the adsorption capacity of shale is positively correlated with pressure. CO2 adsorption capacity is found to be orders of magnitude higher than that of H2 under similar conditions. Conversely, the measured CO2 diffusivity is an order of magnitude lower than the diffusivity of H2. The results also show that IFT increases with increasing salinity in both brine-gas systems and decreases with pressure, nevertheless, the reduction in IFT is much more evident in brine-CO2 systems. Additionally, the initially water-wet shale becomes highly CO2-wet at elevated pressures, while for H2, the shale remains water wet under all experimental conditions.
Apply Reduced-Physics Modeling to Accelerate Depletion Planning Optimization Under Subsurface Uncertainty
Authors: Sanaei Alireza , He Shuai , Pope Joshua , Verma Santosh , Mifflin Rick , El-Bakry Amr 
Published: September 2022

Abstract
Robust decision-making regarding reservoir management using model-based strategies requires a large number of evaluations which can be enormously time-consuming if incorporating the full-field simulation. This challenge becomes more acute when dealing with subsurface uncertainty represented by multiple geologic scenarios. Various reduced-physics and reduced-order models such as streamlines and upscaling are commonly applied to accelerate the optimization process by reducing the computational burden of each evaluation. In this paper we propose an innovative integrated workflow that applies Flow Diagnostics, a reduced-physics modelling tool, to accomplish this acceleration and the mesh-adaptive direct search (NOMAD) algorithm to efficiently optimize well location.
Flow Diagnostics (FD) is a reduced-physics approach that characterizes key flow behaviors and reservoir heterogeneity by combining a single-phase pressure solution with a time-of-flight estimator based on steady-state flux. The time-of-flight values for each grid cell can subsequently be combined with initial reservoir conditions to estimate saturation-weighted 3-phase production using 1D Buckley-Leverett fractional flow relationships. Our testing of this technique on a 2-phase, water flooding asset showed that, while it does not accurately predict exact volumes, there is a strong rank-order correlation with the full numerical simulator. Thus, this technique is an efficient one to assist in the decision-making and optimization process.
To demonstrate this workflow, we applied this strategy to a synthetic base model of a deep water reservoir. Synthetic uncertainty was added to the base case to generate multiple subsurface scenarios. Representative P10, P50 and P90 cases were selected to represent low-, middle-, and high-side cases based on cumulative distribution function (CDF) of NPV. Different well placement optimization studies using high fidelity models and reduced order models were then performed on these cases (optimization of each single scenario on its own and optimization across all representative scenarios simultaneously) to compare solutions and effectiveness. Results indicated that, when the optimized well plans were run on the simulator, optimization under uncertainty provided a solution more robust across the uncertainty space. The results of the full study successfully demonstrate the efficacy of our workflow.
Effect of Supercritical CO2 on the Poroelastic Characteristics of Poorly Cemented Sandstone Reservoirs During Depletion and Injection
Authors: Hashemi Sam S , Kovscek Anthony R , Zoback Mark D 
Published: September 2022

Abstract
While there is continuing interest in geologic CO2 storage, experimental studies on poroelastic characteristics of reservoir rocks during depletion and subsequent CO2 injection are scarce. Rock stiffness, confining stress, and pore pressure control the poroelastic response of saturated rocks. Also, the stress and pore pressure evolution during injection is a key parameter to understanding operations thresholds for CO2 storage projects. As depleted fields in the Gulf of Mexico have been identified as strong candidates for CO2 storage projects, it is important to understand if the poroelastic characteristics from such fields have been altered due to depletion. Among rock properties, Young’s modulus (E), bulk modulus (Kb) and Biot coefficient (α) are of particular importance.
In this study, the poroelastic deformation of a core from the West Delta field in the Gulf of Mexico is characterized experimentally and the impacts of supercritical CO2 (scCO2) on the specimen are investigated. The experimental program simulated reservoir stress changes due to production-induced depletion and scCO2 injection through cycling both the confining pressure (Cp) and pore pressure (Pp). We measured the deviatoric stress, volumetric strain, derived the corresponding Young’s (E), bulk moduli (Kb) and Biot coefficient (α). The results show that the effect of scCO2 on E is more significant at greater confining pressures during the injection phase than depletion at a constant simple effective stress. Interaction of scCO2 with clay minerals caused rock frame dehydration and led to an increase in E. The bulk modulus increased with increasing the confining pressure at a given Pp and decreased with Pp at a certain Cp. α rose with Pp during both depletion and injection phases. Interaction with scCO2 limited the variation of α and the effect of Pp and Cp on α decreased in significance during the depletion phase. Longer interaction time with scCO2 increased α from 10-25% at different Pp values compared to argon during the injection stage. However, the influence of effective stress in reducing the α weakened.
Developing a Fit-For-Basin Novel Solution with the First Application of iCore Behind Cased Borehole in a Complex Heterogeneous Miocene Carbonate Reservoir: Bakr Oil Field, Central Province of Gulf of Suez
Authors: Salim Sadek , Sayed Mayada , Abdo Ibrahim , Abdel Hakim Emad , Farouk Mohamed , Hegazy Amr , El Araby Abdelmoniem , Ghanim Mohamed , Saleh Khaled , ElZahaby Omar , ElNahrawi Mariam , ElKaragi Alaa 
Published: September 2022

Abstract
Gulf of Suez basin is one of the most complex areas of exploration that requires a fit-for-basin solution to reveal the true potential of the carbonate reservoirs. The multi-domain integration of the interpreted lithology from high-resolution imaging tools recorded in the open hole section with electrofacies integrated with NMR and cased hole elemental spectroscopy data provides the 1st time application to derive synthetic core with high-resolution facies in the drilled wells with complex heterogeneity challenges. 3D seismic attributes, stratigraphical and structural analysis, revealed a potential three-way dip closure with an expected high-quality carbonate reservoir. An automated processing workflow converts gamma-ray yields from the energy spectrum measured behind casing into the dry weight and mineral fractions. The computed mineralogical outputs are then described based on a standardized ternary diagram approach to generate dry-weight mineralogy-based lithofacies. The synthetic high-resolution lithofacies are integrated with MDT, NMR, and spectroscopy to capture mobility, type of fluid, and saturation associated with lithofacies changes which is integrated with well integrity analysis to plan, design, and execute of innovative technique for carbonate stimulation.
This paper demonstrates reviving exploration activity in one of the brownfields and the first application for borehole imaging integrated with cased hole spectroscopy on the recent discovery well to select perforation. Once a robust lithofacies classification is obtained, this is used for detailed stratigraphic analysis, well to well correlation, cross-sections, mapping or refined static reservoir modeling, and perforation zones selection which represents the first success story for this innovative technique. This multi-domain integration helped to design a customized acidizing technique to reveal the true reservoir potential that had a 3 fold increase in productivity index compared to offset fields in the same basin.
The workflow can be applied to multiple cases as a cost-effective solution in multiple scenarios and different formation types especially if there is no core available in old wells. Furthermore, the innovative acidizing technique can effectively stimulate any carbonate reservoir.
Evaluation of Image-Matching Analysis to Compute Downhole Drilling Distance for Directional Drilling Automation
Authors: Mansour Ahmed , Zerpa Luis , Sampaio Jorge 
Published: September 2022

Abstract
Drilling technology has been rapidly evolving over the past few decades, and currently, the main focus has been on enabling drilling automation. Multiple components on a drilling rig have been automated to make drilling operations safer, more efficient, and less costly. The invention of new directional drilling tools, such as Rotary Steerable Systems (RSS), has allowed directional wells to be drilled in less time and have decreased torque and drag. Directional drilling tools, in general, use inclination, azimuth, and depth measurements to locate the bit. As a result, the directional driller can orient the bit towards the desired location. While azimuth and inclination can be measured downhole, depth measurements are obtained using the pipe tally installed on the surface. As a result, it is difficult to automate current directional drilling tools because they still depend on surface measurements, manual input, and human guidance.
A continuous downhole measurement system that uses inclination, azimuth, and measured depth to determine the drilling bit's location would facilitate directional drilling automation. A downhole computer would compute all calculations in the bottomhole, allowing the bit to follow a preprogrammed trajectory rather than depending on surface instructions. Minimizing surface dependence allows smoother well paths, thus decreasing torque, drag, drilling time, and costs even further. Therefore, this paper introduces a technique that computes the drilling distance using multiple imaging sensors spaced at known distances. The sensors capture images of the same formation location at different but synchronized times. The method includes an image-matching algorithm that identifies each image's fingerprint and registers similar images according to those fingerprints. It then uses the timestamps of the matched images and the distance between the sensors to compute the local average rate of penetration and the distance traveled. Here, we explain the mechanism of the image-matching analysis and introduce the concept through experiments made on sceneries that imitate the wellbore wall. Additionally, we analyze the effect of controllable variables on the accuracy of the distance calculation.