bluuebunny/crossref_metadata_2025_split huggingface dataset:
Meet us Halfway – A Young Engineer's Thoughts on How to Make Petroleum Engineering a Cool Profession
Authors: Rahi Samir 
Published: September 2022

Abstract
Young people don't want to work in oil and gas.
Despite above average salaries and a resurgence in hiring, the industry faces a systemic, immediate risk of talent shortage due to changing public sentiments. This paper seeks to understand why new graduates are eschewing these types of careers, what paths they are currently following, and how alignment with their priorities may improve the industry's hiring prospects.
This paper is in part a response to two previous SPE publications written by 2016 SPE President Dr. Nathan Meehan: 2019's The End of Petroleum Engineering as We Know It and 2021's It's Not the End of Petroleum Engineering. Whereas the previous papers address this problem from the industry's point of view, this new work centers around the perspective and motivations of the young engineering graduates. Claims are also reanalyzed and recontextualized using additional studies and data.
Research and sources are augmented by the authors direct experience as a recent engineering graduate and his current roles with a Texas-based startup accelerator and a hard technology startup, as well as extensive interactions with recent petroleum engineering graduates and oil & gas industry professionals.
The additional data and analysis lead to the identification of four core pillars upon which young engineers base their decisions when selecting a place to work:
Innovativeness Ethicality Proactivity Inclusiveness
From a detailed discussion of these pillars, a three-tiered advocacy is developed to revitalize young graduates’ perception of oil and gas and modify existing recruiting and early career development practices. The recommendations provided can thus serve as a starting point for oil and gas companies to reassess their approach and thinking towards the acquisition and retention of new talent.
Production Technology R&D: Insights from Upstream Research
Authors: Al-Mutairi Saad M. , AlTammar Murtadha J. 
Published: September 2022

Abstract
Worldwide, research and development (R&D) programs have long been an integral part of most oil and gas companies. Large and small oil companies alike continuously perform several R&D activities on some level to improve their operations and services. With the advent of technology in recent years, companies are increasingly recognizing the competitive advantage that R&D provides to their core businesses. In this paper, we share insights from over a decade of R&D experience by the Production Technology Division (PTD) within Saudi Aramco's EXPEC Advanced Research Center (EXPEC ARC). The team has pioneered many technologies that significantly enhanced production operations, and helped in reducing operations’ carbon footprint in oil and gas fields. We highlight how the research team grew over time, and how they interacted and engaged with field proponents in their R&D work while providing several illustrative examples. We also discuss the focus and strategy of the team going forward.
Physics-Based 3-Phase Relative Permeability for Gas-Liquid Counter-Current Flow
Authors: Gupta Subodh 
Published: September 2022

Abstract
The objective of this paper is to present a fundamentals-based, consistent with observation, three-phase relative permeability model to describe flow more accurately in countercurrent movement of gas and liquids situation. While most flooding operations have both gas and liquids flowing in the same direction, in gravity dominated processes such as steam assisted gravity drainage (SAGD) or CO2 storage in water saturated reservoirs, often due to density difference the gases rise above and liquids flow down. This gives rise to a counter-current flow situation. It has been documented by a few researchers including Adebayo et al. (2017) and Prats et al. (2008). At the gas-liquid interface, the shear forces act to oppose movement of gas and liquids resulting in a slowdown in the flow of both. This slow-down or reduced flow is not captured in standard relative permeability curves which are typically generated using co-current flows.
In the current work, the approach adopted by Gupta (2021) for a mechanistic 3-phase flow model is used to develop relative permeability expressions for gravity-incorporated flow. To do this, three-phase core-annular laminar flow expressions are first developed in a single thin tube, then these flow expressions are aggregated for the entire pore volume represented by a bundle of tubes with varying tube sizes mimicking pore-size distribution. An irreducible water saturation, when water is the wetting phase, is also assumed.
The relative permeabilities obtained with counter-current flow considerations are compared with the ones presented in Gupta (2021) for co-current flow to highlight the difference. Additionally, the impact of these modified rel. perms is shown with an example SAGD problem resulting in a slower and more realistic growth of the steam chamber. Similar to the observation of Gupta (2021) this mechanistic model also indicates a natural dependence of rel. perms of the intermediate phase on temperature, which in literature has been a subject of much debate.
The novelty of the work is in development of a three-phase relative permeability model which takes into account gas-liquid countercurrent movement in porous media based on fundamentals of flow in fine capillaries. The significance of the work includes, aside from predicting results more in line with expectations in gravity-dominated processes, an explanation of temperature dependent relative Gupermeabilities of the intermediate phases. Also, unlike Stone-II method, it predicts a more realistic time dependent residual oleic-phase saturation for gravity drainage recovery methods.
Enhanced Reservoir Characterization of Complex Carbonates by Integrating Diagenesis with Petrophysical Properties
Authors: Al Subait Ali , Al-Nasser Kadhem , Alqahtani Najm , Agnia Ammar 
Published: September 2022

Abstract
Carbonate reservoir characterization is often challenging due to variable mineralogy, pore-geometry, texture, and diagenetic processes that modified the rock fabric and its petrophysical properties affecting rock typing, reservoir-potential evaluation, and deliverability prediction. This work implements a multidisciplinary petrophysical discrimination scheme that draws upon the diagenetic history of the rock to resolve such characterization challenges and optimize field development practices.
This study integrates sequence stratigraphy, core description, petrography, diagenetic analysis, mineralogy, routine core analysis (RCA), mercury injection capillary pressure (MICP) and wireline logs to define Diagenesis-Integrated Reservoir Rock Types (DI-RRT). The DI-RRT are established by delineating the continuous mineral phase, flow-dominant pore types, and main diagenetic processes. The data integration facilitated DI-RRT predictions, DI-RRT-constrained permeability and saturation-height modeling in all wells across the field.
This rock typing scheme effectively classifies reservoir potential and delineates the contrast in the reservoir's flow and storage properties. Diagenesis, linked to lithological and pore attributes, serves as an effective discriminant for rocks of similar depositional and lithological settings but contrasting reservoir behavior. This is evident in reservoir intervals of high-energy depositional facies, which showed distinct petrophysical trends due to post-depositional modifications. Calcitic DI-RRT of mainly grain-dominated fabric and moldic porosity exhibits consistently low-to-modest potential that varied in response to the intensity of leaching, cementation and compaction. On the contrary, dolomitic DI-RRT manifest six distinctive behaviors distinguished by pore-type, texture, replacive dolomitization, dissolution and cementation. The reservoir quality is significantly enhanced where replacive dolomitization accompanied intensive dissolution, even with patchy anhydrite cementation. This scheme enabled the identification and mapping of these high-productivity zones in wells across the field. It further granted a good match between log- and core-based predictions of permeability and saturation.
Integrating diagenesis with petrophysical rock types, wireline logs and field observations enhances reservoir characterization in complex carbonate reservoirs. It boosts current intellection of reservoir performance, identifies porosity-permeability and saturation trends with higher precision, and capitalizes on reservoir-quality zones during the field-development cycle. It further provides a roadmap to distribute petrophysical properties in uncored wells and 3D models optimizing subsequent static and dynamic models.
Evaluating Performance and Energy Efficiency of Hybrid Cyclic Steam Stimulation Technologies with a Novel Experimental Setup
Authors: García Hugo , Pérez Romel , Rodríguez Hector , Sequera-Dalton Belenitza , Ursenbach Matthew , Mehta Sudarshan , Moore Robert Gordon , Gutiérrez Dubert , Manrique Eduardo 
Published: September 2022

Abstract
An experimental program has been designed and executed to evaluate the performance of hybrid Cyclic Steam Stimulation (CSS) recovery methods. The overarching goal is to improve the energy efficiency and reduce the carbon footprint of CSS in Colombian heavy oil fields. Specifically, this work compares the impact that adding solvent or flue gas to cyclic steam injection has on the recovery of a recombined heavy live oil at a laboratory scale.
A novel experimental setup was designed to evaluate hybrid CSS methods, which allows displacement of fluids out of the core during injection cycles and the return of those fluids to the core during soaking and production periods, by the use of a ballast system. A CSS baseline test and two hybrid CSS tests were performed at reservoir conditions (RC) with recombined live oil and core material from a Colombian heavy oil field. Each test consisted of four cycles with the same amount of steam injection. The hybrid CSS tests consisted of a steam-solvent and a steam-flue gas hybrid test.
The CSS baseline and the hybrid CSS tests were successfully performed in the core pack with the injection of 0.12 pore volume CWE (Cold Water Equivalent) of steam per cycle, at core pressure near 680 psig and an initial core temperature of 45°C. In addition, steam-solvent and steam-flue gas hybrid tests injected near 0.01 and 0.05 PV (CWE) of solvent and flue gas per cycle, respectively. The steam front location during each cycle was identified with temperature profiles recorded along the core during the tests. Core pressures and fluid volumes displaced to and from the ballast were also recorded. Post-test core analyses allowed to estimate residual liquid saturations after each test. The addition of solvent or flue gas did not hinder the CSS oil recovery process which was in the order of 40% for all tests. The recovery, energy efficiency and carbon footprint of the hybrid CSS tests are compared to the CSS baseline case. Although a small amount of hydrogen sulphide (H2S) was detected at the end of the CSS baseline test, H2S was not detected in the produced gas of the hybrid tests.
The experimental program enhanced the understanding of hybrid steam cyclic methods and the impact of solvent and flue gas addition on the recovery, energy efficiency and carbon footprint reduction of heavy oil CSS recovery processes. These results assist in the quest of improving CSS performance and provide key data for tuning numerical models. This novel experimental apparatus is one of a kind as it captures the cyclic nature of fluid movement during CSS.
Rapid Detection of Super-Emitters Utilizing an IoT-Enabled Continuous Methane Emissions Monitoring System
Authors: Chakrabarti Aditi , Dauphin Mathieu , Andrews A. Ballard , Zielinski Lukasz , Rashid Kashif , Yuan Junyi , Speck Andrew , Huynh Adam , Power Justin , Nicolas Vincent , Gadot Raphael 
Published: September 2022

Abstract
Large methane emissions occur from a wide variety of sites with no discernable patterns thus requiring methodologies to frequently monitor for these releases throughout the entire production chain. To cost-effectively monitor widely dispersed well pads, we describe a continuous monitoring system based on the Internet of Things (IoT) to leverage cost-optimized methane concentration sensors permanently deployed at facilities and connected to a cloud-based interpretation platform. Testing at controlled methane release facilities enabled the validation of the sensor performance; fidelity of the atmospheric dispersion modeling underlying our interpretation; and the overall system performance in detecting, localizing, and quantifying methane releases.
A Systematic Photo Documentation of Drill Bit Forensics Applied to Motor Back-Drive Dynamics Case Caused by Auto-Driller Dysfunction and Formation Effect
Authors: Sugiura Junichi , Jones Steve , Pastusek Paul 
Published: September 2022

Abstract
North America shale drilling is a fast-paced environment where downhole drilling equipment is pushed to the limits for maximum rate of penetration (ROP). Downhole mud motor power sections have rapidly evolved to deliver more horsepower and torque, resulting in different downhole dynamics, such as motor back-drive drilling dynamics. This paper investigates the root cause of the motor back-drive dynamics and the bit/BHA damage caused by this.
High-frequency (HF) compact drilling dynamics recorders embedded in the mud motor bit box and top sub provide unique measurements to fully understand the reaction of the power section under load relative to the type of rock being drilled. 3-axis shock, gyro and temperature sensors placed above and below the power section measure the dynamic response of power transfer to the bit and associated losses caused by motor back-drive dynamics.
Formations with high interfacial severity pose more of a challenge due to the rapid change in formation strength. The torsional energy stored and released in the drill string can be high due to surface rotation-speed/torque output and downhole mud-motor speed/torque. Torsional drill string energy wind-up and release results in variable power output at the bit, inconsistent ROP and rapid fatigue on downhole equipment. Detailed analysis of the high-frequency embedded downhole sensor data as well as Electronic Drilling Recorder (EDR) data provides an in-depth understanding of mud motor dynamics. In one of the "Delaware Basin" field examples from Loving County, Texas, the root cause of the motor back-drive dynamics was identified.
A systematic photo documentation of drill bit forensics was performed to precisely document the bit damage from this type of drilling dynamics. The auto-driller weight-on-bit (WOB) and ROP setpoints were examined along with the downhole sensor data and EDR to pinpoint the root cause of drilling dysfunction. A drillstring analytical model was used to predict the torsional natural frequencies, which are compared against the sensor-observed torsional oscillation frequencies.
This paper reports a unique case of motor back-drive drilling dynamics caused by auto-driller dysfunction and formation effects. Additionally, a systematic photo documentation of drill bit forensics was applied to thoroughly document motor driven bit damage.
A Case Study on Integrated Downhole Logging Suite to Diagnose Multi-phase Flow and Improve Multi-Reservoirs Flow Allocation
Authors: Abdul Latif Azzad Hafiz , Giniyatullin Artur , Sidek Sulaiman , Mustafa Kamal Mohd Akmal , Zakeria Ahmed Nabil , Mohd Amin Farid , Abdul Rahman Hazrina , Nasron Budi Mawardi 
Published: September 2022

Abstract
This paper discussed Operator's experience on integrated downhole logging suite to diagnose multi-phase flow and to improve multi-reservoirs flow allocation in deviated wells, offshore Borneo Island. Field A is located in the West Balingian geological province of the Sarawak Basin, 140km offshore Bintulu in a water depth of 165ft. It was discovered in by Exploration Well #1 (EW#1), followed by downflank Appraisal Well #2 (AW#2) in 1982 and second Appraisal Well #3 (AW#3) in 2000, to address some of the significant subsurface uncertainties impacting on the field development plan. Phase-1 development wells (e.g. DW#1 and DW#2) was drilled and completed in 2014, with 7″ × 4-1/2″ cemented liner as lower completion across the clastic reservoirs. During pre-development in 2016, additional perforation in DW#1 oil zones were added whereas additional perforations in DW#2 oil zones were added in 2019. The two (2) relatively new wells produce commingled from several oil-bearing and gas-bearing zones. Developing highly compartmentalized multi-stacked reservoirs via simplified well completions, poses a great challenge for subsurface data acquisition when it comes to determining production allocation, managing flow assurance issues, understanding reservoir connectivity, surveillance of individual well performance and generating total field production forecasting.
Conventional production logging result conducted in 2016 was unsatisfactory to explain some of the wellbore and reservoir flow peculiarities. Since it was important to know which zones contributed to the production, diagnostic of wellbore/reservoir flows and coupled with well integrity issues, Spectral Acoustic Logging with Thermo-Hydrodynamic Modeling was conducted to obtain the valuable information and to perform well/reservoir diagnostic. Remote platform location put an additional challenge to the logging campaign, as such the logging program was customized to satisfy the logging objectives while comply with HSE requirement.
The collaborative approach between Operator and Service provider as solution partners, established a new finding for the formulation of remedial treatment to increase production and recovery from the wells by ensuring that each well operates to the maximum of its abilities.
A Revolutionary Advanced Displacement System for the Challenges in the 21st Century
Authors: Detiveaux Joey , Stanford Jack 
Published: September 2022

Abstract
Following the 2010 Macondo Prospect oil spill in the Gulf of Mexico, the more stringent regulations for offshore oil and gas operations required an entirely new approach to wellbore cleanout ahead of the completion phase. With all previous practices and chemistries effectively ended, the task was to develop a new, reliable, sufficiently dense, environmentally friendly, clear-brine displacement system that would address the challenges of cleaning out aqueous- and non-aqueous-based drilling fluids as well as perform in the elevated pressures and temperatures of ultra-deepwater operations in the Gulf of Mexico, Brazil, and West Africa.
Experimental Investigation of Acid Job Limit in Fractured Sandstone Formations
Authors: Karazincir Oya , Li Yan , Zaki Karim , Johnson Andrew , Williams Wade , Rijken Peggy , Rickards Allan , Hathon Lori 
Published: September 2022

Abstract
The goal of this study was to assign an operational limit to the number of acid jobs applied to a given well considering the effects of remedial acid treatments on propped fracture conductivity and near-frac face formation permeability, parameters that impact the skin factor. The Frac Face Damage (FFD) conductivity test unit introduced in previous publications was used to assess the change in formation permeability near the fracture face, as well as proppant pack conductivity. First, a test with field core without acid treatment was conducted as a control experiment to display the impact of closure stress on proppant embedment, fines generation, proppant pack compaction. This test showed stable proppant conductivity with slight permeability reduction at the formation face towards the end of the stress hold. Test duration and flow step lengths were kept identical to the acid tests for comparison purposes. Tests with eight acid cycles resulted in permeability gain at the fracture face with the early acid cycles followed by an accelerated drop in frac face permeability and proppant conductivity. Acid tests were conducted using fresh core and pre-damaged core and test results were compared to the control test. Skin value was calculated using a semi-analytical numerical model and the productivity index was estimated following each brine or acid injection cycle. The results clearly display benefit from acid stimulation during the initial acid cycles, followed by a sharp decline in the uplift with increased embedment that marks the acid limit. Post-test analysis of core material support formation of a deeper proppant embedment zone at the fracture face for the system that was acidized eight times, compared to the unacidized propped formation/proppant assembly.
Coining a New Concept: Drilling in Incompatible Conditions
Authors: Brahimi Oussama 
Published: September 2022

Abstract
This paper defines the concept of "Drilling in Incompatible Conditions" and how its identification can help in the inclusion of unconventional drilling fluids and technologies, in the planning phase or as a contingency plan. These technologies include casing and liner drilling, MPD, UBD, HPWBM, and their combination (ex: MPCD). This paper also presents a method to point out whether a given drilled section is compatible with overbalanced conventional rotary drilling – referred to as conventional drilling on this paper.
Identification of drilling incompatibility starts from a basic definition and widens based on field case histories of drilling using unconventional drilling methods (which means fields that have parameters incompatible with conventional drilling) or from cases in which an unplanned contingency casing was used. The parameters influencing the usage of these methods are used as inputs in machine learning. While the technological complexity level of the techniques in use can be divided into as many as four categories based on logistical and cost considerations. Only level 1 - conventional drilling - is in the scope of this work.
Machine learning classification algorithms are used to predict if the conventional drilling method is incompatible with parameters designated as input values, such as heterogeneity of lithologies in a drilled section, the presence of problematic drilling formations (mobile/reactive), presence of weak formations, formation temperature (high, moderate or low), formation pressure (over/under-pressurized), formation permeability and presence of natural fractures, and the ERD value. The outputs will present themselves as a binary value (Compatible/Incompatible). The inputs can be classified into continuous, binary, and ordinal data. This model provides insights on whether geological and operational parameters are too complex for conventional drilling, thereby avoiding drilling based on trial and error.
This work will fill the gap in terms of quantifying the complexity of a drilled section, both operationally and geologically, and deals with it from a relativity point of view with respect to the level of technology implemented through the usage of machine learning. This new concept will help drilling engineers be more efficient by answering complexity issues before the commencement of drilling. This will lead to cost savings and enhanced profitability by designing a wellbore with the least sections possible. Besides, this terminology reflects the definition of sustainability which is of utmost importance not just from the technical point of view.