bluuebunny/crossref_metadata_2025_split huggingface dataset:
Microfluidic-Based Optimization of Polymer flooding for Heavy Oil Recovery
Authors: Qi Zhenbang , Fan Xingyu , Abedini Ali , Raffa Duilio 
Published: March 2023

AbstractPolymer flooding has been implemented in Western Canada, specifically in Saskatchewan and Alberta since 2000s. Flooding with polymer has been more effective than with water in heavy oil reservoirs due to a more favorable mobility ratio, resulting in more a stable front and less fingering. Optimization of polymer flood strategies is essential for successful implementation of field-scale operations. Core and sand-pack flood testing have been a reliable method for laboratory evaluation of different injection methods and chemicals as the cores are representative of the reservoir geometries and rock chemistries. However, few drawbacks exist such as long turnaround time when multiple strategies need to be compared and inconsistency in pore geometry. Most importantly, this approach cannot resolve the pore scale displacement mechanisms, falling short to compare injection cases in which the recovery factors are similar, but pore-scale dynamics are different. In this study, a microfluidic-based platform was developed to visually evaluate the performance of different polymer flood cases in heavy oil recovery. Two secondary injection tests were performed with water and polymer. A tertiary polymer injection test was also performed with the waterflood followed by the polymer flood. Recovery factors and pore-scale flow behaviour and dynamics of the displacement processes were quantified. The results reported here demonstrate that the microfluidic system is a unique screening tool that can be potentially implemented in conjunction to the traditional core-flooding method to provide more efficient and reliable information to optimize the polymer flooding parameters and inform the operators.
Oil in Water Emulsion Formation in SAGD with Chemical Additives
Authors: Ghoreishi S. Ali , O. Sanchez Javier , D. Ortiz Arango Julian , D. Gates Ian , Hejazi S. Hossein 
Published: March 2023

AbstractThe in-situ formation of oil in water emulsions can contribute to the oil mobilization when combined with Steam-Assisted Gravity Drainage (SAGD). The produced fluids in SAGD operations and sand pack SAGD experiments often show the existence of both oil in water and water in oil emulsions. Due to the opaque nature of sand packs, however, it is unclear whether the emulsions are formed in-situ during the flow through porous media or in the production tubing.This study aims at understanding the impact of a surfactant known as "High-temperature Emulsifying Agent" (HEA) as an additive on the SAGD process and the possibility of forming preferred oil in water emulsions. The high-temperature fluid flow experiments are performed in 2.5D glass micromodels which are placed in a custom built compact high pressure-high temperature (HPHT) visual cell. Hot water and HEA solution (3000 ppm concentration) at 82 °C are injected at a constant rate of 5 μl/min. The injected fluid first displaces bitumen in the form of an advancing finger, forming a condensate-bitumen interface which is slowly advancing towards the production port at the bottom end of the model.Hot water initially displaces bitumen from the pores leaving a film of bitumen on the grain surfaces which is eventually removed as the injection continues. Water droplets dispersed in bitumen are observed at the areas experiencing high shear forces, i.e., near the main two-phase front and close to the production port. In contrast to the hot water process, no oil film is observed during the HEA injection. In the presence of HEA solution, oil in water emulsion is formed at the condensate-bitumen interface and ahead of the interface deep in the oil zone. The latter could be the result of corner flow which promotes the fast distribution of HEA solution throughout the model, ahead of the main water-oil interface.This work provides insights on the role of surfactants in forming oil in water emulsions in steam-based bitumen production. A novel HPHT visual cell enables the rapid assessment of solvent-surfactant-steam recovery processes and a better understanding of the active emulsifying mechanism in this system.
Static Gradient Survey Reveals Temperature Anomaly in the CaMI CO2 Injection Well
Authors: Behmanesh Hamid , Cooper Joanna , Macquet Marie , Kolkman-Quinn Brendan , Lawton Donald , Osadetz Kirk , Maidment Greg 
Published: March 2023

AbstractIn view of the complex wellbore dynamics associated with liquid/vapor CO2 in the Containment and Monitoring Institute (CaMI) of Carbon Management Canada (CMC) CO2 injection wellbore, a Static Gradient Survey was conducted with the focus on the verification of in-tubing pressures and temperatures at various depths in the wellbore. Specifically, the knowledge sought was to learn about the temperature profile in the regions above and below the gas-liquid interface as well as the temperature profile below the Distributed Temperature Sensing (DTS) fiber termination point in the well, where there is no temperature measurement.For the static gradient survey, four surveys (passes) were conducted over a span of 6 hours, using tandem pressure/temperature recorders. For the first and second passes, lowering and raising the wireline string in and out of the well at a steady rate was undertaken. The third pass involved stopping the gauges at specified depths for approximately 10 minutes prior to extracting them out of the wellbore. Recognizing that the responses of the gauges to temperature were much slower than to pressure, the duration of the stops varied at different depths, depending on the location of interest. The final pass took place some 6 hours after the initial run.The location of the liquid level in the well was identified, not only by the change in pressure gradients but also by a change in temperature gradients. At the gas-liquid interface, the liquid was boiling and caused localized cooling around the interface. This cooling event was registered in the DTS data where the temperature departed from the baseline temperature gradient. Another cooling event was observed near the base of the wellbore where the recorded temperature profile cooled before it again approached the normal thermal gradient. We interpreted the cause of this cooling event to be that some of the injected CO2 has migrated up-section into the shallower formation. The corresponding decrease of pressure caused a phase change and evaporation of CO2 which resulted in a reduction in the CO2 temperature.The temperature anomaly at the base of the injection well is consistent with the geophysical monitoring results from vertical seismic profiles (VSP) and the borehole electrical resistivity tomography (ERT) surveys.Understanding of the thermal processes related to Geologic Carbon Storage(GCS) is crucial for a successful deployment of projects. Our observations of temperature anomalies within the reservoir will contribute to the feasibility of employing temperature signals as a monitoring tool for the subsurface migration of the CO2 plume.
Could the Post-SAGD Heat Recovery Supply the Direct Air CO2 Capture (DAC) Energy in a Net Negative Carbon Emission Environment?
Authors: Bashti Shima , Sadeghi Asghar , McCoy Sean , Mahinpey Nader 
Published: March 2023

AbstractDirect Air CO2 Capture (DAC) is a promising negative emission technology. The main challenge associated with DAC is the high energy and material requirements, which results in a relatively high cost and may limit its environmental benefit. Steam-Assisted Gravity Drainage (SAGD), most established in situ recovery approach for Alberta oil sands reservoirs, leave a considerable amount of energy under the ground at the end of their life. The objective of this work is to investigate the energy and environmental viability of exploiting the abandoned thermal energy from oil sands reservoirs to generate DAC energy requirements. This work focuses on a unique concept of integrating DAC with SAGD after the cessation of bitumen recovery to recover energy from the reservoir and use this to supply energy for DAC. The retained energy in reservoirs can be extracted by water circulation. The recovered hot water is sent to surface energy extraction unit to generate power and heat energy. CO2 captured from the atmosphere is then transported by pipeline and sequestered in a suitable geologic reservoir. To conduct our analysis, we create an energy balance on the coupled system and calculate the life cycle carbon balance with the goal of creating a stand-alone, carbon-negative CO2 capture system.We consider the electrical and thermal energy for CO2 capture in the range of 100-600 tCO2/day using a solid-based DAC process, in which the loaded sorbents are regenerated at a temperature of 90-105 °C. An isobutane Organic Rankine Cycle (ORC) is utilized to generate electricity from a geofluid circulated in post-SAGD heat recovery process with the temperature varying from 130 to 170 °C. The heat required by the DAC is extracted directly from the produced geothermal fluid. The analysis uncovers that Direct Air Capture and post-SAGD reservoir can be combined in a stand-alone power island to capture up to 284.5 tCO2/d at 130°C and 427 tCO2/d at 170 °C geofluid surface temperature assuming deploying the technique in 40 production wells.Furthermore, our modelling results show that CO2 capture efficiency for abovementioned ranges of capture rate and geofluid temperature varies between 70-99%. For no external energy demand, CO2 capture efficiency touches 99% but as the external sources of energy is being involved, the efficiency declines to a minimum of 70%. This study presents a novel concept for using the waste heat in oil sands reservoirs to provide DAC energy.
Real-Time Drilling Engineering and Data-Driven Solutions for Upstream Cost Savings: Coupling Earth Models, Digital Twins, Data & Drilling Automation
Authors: Amin Muhammad Rizky , Baruno Agung , AitAli Rachid , De Vreugd Joost , Forshaw Matthew , Mahmoud Mohamed Yehia 
Published: March 2023

AbstractDespite the market up-cycle efficient use of CAPEX for upstream well construction projects remain a key topic for E&Ps. Therefore, non-productive-time and invisible-lost-time (NPT & ILT) reduction continue to be paramount.Wells of such complexity require the introduction of new drilling automation technology to meet the challenge associated with inadequate hole cleaning, vibrations and connections practices resulting of the implementation of the i-Tral real-time monitoring used to mimic manual torque and drag parameters through artificial intelligence and machine learning allowing extrapolation, alarming and therefore early warning onset of friction and stuck-pipe, continuously supply required flowrate and visualize cuttings concentration along the wellbore and real-time multi parameters optimization for drilling dysfunction and penetration rate increasing tool longevity, trips for tool failure hence reduction in section delivery time.This paper details the features of the i-Trak torque and drag, Dynamic management and hole cleaning models capable of drive efficiencies to execute effectively and consistently each operations while meeting the goals set in the AFE.The technology was first deployed in Abu Dhabi (UAE) in xx Field, a producing conventional oil field located onshore and operated by ADNOC ONSHORE. In total 27083ft was achieved combining Well-I and Well-II where the objectives behind these 2 horizontals wells were to maximize reservoir contact, improve productivity and accelerate delivery while minimize construction costs by implementing mitigations in addressing concerns which helped in streamlining the drilling operations while reducing any potential risks. These wells were drilled in collaboration by ADNOC and Baker Hughes and considered to be the first maximum reservoir contact (MRC) project in this area.For primary mitigation, the output of cuttings mass existing in the wellbore (static and mobile) can give a clear indication of the amount of cuttings downhole which corresponds to 50% of the criteria analysis for an inclination range. Secondary mitigation is from the high-resolution torque and drag samples plotted real-time and compared against theoretical pre-well plan broomstick model for different frictions factors measuring the deviations to concisely convey the end users to apply the required procedures to alleviate risks of well constructions operations.Finally, the integration of dynamic management provides a unified user interface which combines ROP and VSS measurements in a single place to minimize maintenance and repair costs while driving higher ROP's.
Talent Management Practices at United Energy Pakistan
Authors: Bashir Muhammad Farhan 
Published: March 2023

Abstract
As an E&P company in the upstream sector, United Energy Pakistan (UEP) heavily relies on the skills of its employees to produce expected business results. At the group level, UEP is credited for producing / nurturing the best of talent who have continually supported the group in strengthening its footprint in other parts of the world.
UEP's success in the past decade (since UEG acquired BP assets) is largely attributed to its people. UEP's focus has always been in hiring the right talent, grooming and nurturing them through the best of ‘on the job (OJT)’ experiential learning and classroom / virtual trainings. In 2019, the TLC framework was established to build the technical competence, leadership ability and to infuse a UEP way framework, of doing things (cultural relativism) in all employees.
The application of the TLC framework was backed by data fetched from multiple systems such as the competency management system (CMS) and the performance management system, which led to identifying the right technical / leadership gaps at an individual level and helped in working towards the overall employee and leadership development.
The framework also considers the development of emerging leaders. Employees are calibrated on a 9-box grid and review discussions take place from the potential, performance and progression stand point. The talent review forums also incapsulates discussion around development and succession.
Without an enabling environment, the best of talent / processes cannot flourish. UEP's core values & leadership behaviors & the code of conduct are the fundamentals on which employee bases his / her overall conduct and day to day doing. These core values & etiquettes of working are termed as the UEP way framework. There is an engagement survey which is conducted once in two years and acts as a check and balance mechanism between management and employees.
The paper will discuss in detail how the TLC framework has helped UEP in managing talent by building technical competence, a leadership mindset and to operate with a UEP mindset in a fast-paced dynamic environment.
Operational Excellence Through Implementation of Data Governance Policies and Procedures Covering Data Retention, Disposal and Archival: A Collaborative Case Study Between HQ and Group Company, Abu Dhabi, United Arab Emirates (U.A.E)
Authors: Khan Zeeshan , Lee Changhwan , Girinathan Sajith , Mohammad Usman Fareed Mohammad , Ferreira Sebastien , Al Saeedi Fahad , Bishnoi Sandeep , Al Maareef Ayman , Khwaja Nadeem , Bamakhramah Adel 
Published: March 2023

Abstract
Objectives/Scope: Comprehensive records retention schedules, which are based on records classification structures, are established to reduce costs associated with records growth and duplication, improve access to valuable information, and ensure compliance with applicable laws and regulations.
All digital technical data, including Geology and Geophysics, Reservoir Engineering, Drilling, etc. need to be preserved forever. Data can be re-used, re-interpreted, re-analyzed for many Years later. If data is "well organized", no need to dispose-off anything. Similarly each electronic copy of non-technical data should be preserved.
Methods, Procedures, Process: Before implementation of the mentioned workflow for Data Archival and Retention of documents, physical copies were kept forever and there was no mechanism for end user to easily access the required files. As policy was formalized at Group level, each assigned focal point was assigned with task of converting physical copies to electronic version (by scanning and uploading onto Network drives and Electronic Document Management Systems (EDMS).
On completion of scanning activity below retention policy was applied to preserve the physical data for a defined timeframe (mentioned in below table). As files such as Final Well reports, drilling reports etc. are available online and accessible using Network drives / EDMS system, end user can easily access the required files in a matter of seconds which save the tremendous amount of end user time and increase productivity as an organization.
Since policy is implemented tremendous efforts are placed by focal points to reduce the physical files by coordinating with different physical files sources (internal or external of organization) to provide with Digital copy which is much easier to maintain.
Restoring Integrity and Production on a Well with Compromised Barriers: Use of Crosslinked Polymer Gel to Prevent Fluid Loss Post Well Kill to Enable the Safe Repair of Compromised Christmas Tree Valves
Authors: Bougha Arthur , Ndukauba Godian , Okeke Chinyere , Abudu Rahman 
Published: March 2023

Abstract
Operating Oil and Gas wells safely requires two tested and independent barriers are in place at all times. If a barrier is lost, all efforts should be focused on restoring the lost barrier. This requires a detailed risk assessment is carried out and an approved deviation in place. The objective in this case was to ensure the only barrier, kill fluid, is not lost to the formation and ensure zero damage to the reservoir. In this paper, the detailed planning and execution of a well in the Eastern Delta (Ukos-21L) with compromised tree valves due to a blown-up Wireline Retrievable Surface Controlled Sub-Surface Safety Valve (WRSCSSV) that got stuck across the tree valves are presented. With a reservoir pressure of 4,000psi, this posed serious HSE risks. The intervention involved establishing injectivity through the kill wing valve. The well was bull-headed to 0psi with appropriate kill brine. A crosslinked polymer gel was then pumped to prevent fluid loss of the only barrier (kill brine) and to ensure well remained stable at 0psi throughout the barrier restoration
One of the key project deliverables was to ensure the reservoir was not impaired and the well productivity unchanged during the barrier restoration activity and this was confirmed after the well was successfully put back to production post restoration operation. The crosslinked gel placed across the perforated interval prevented fluid loss without penetrating the formation but due to the introduction of internal chemical breaker, the uncross-linking of the polymer gel was done in-situ after the specified design period elapsed as determined through laboratory test done based on the formation downhole temperature. The well continued to produce ca.880bopd post the integrity restoration. The restored valves were all operable. It was also observed that the installed WRSCSSV was not dressed with the right size of packings, making it possible for the valve to be blown out of its profile.
The use of polymer gel is a safe means of preventing fluid loss under a one barrier condition (fluid barrier). The pre-determined breaking period for the cross-linked polymer gel was considered and very critical to the successful execution of the activity. The execution was achieved four days ahead of the planned time with zero non productive time, NPT recorded. Hence, coiled tubing, CT was deployed to nitrogen lift the well to production post integrity restoration. Production was restored three days ahead of schedule.
An Innovative-Engineered Multipurpose Lifter Solution Resulted in Step Change in Offshore Debris Removal Operation
Authors: Ismail Ahmed Ibrahim , Salama Ayman Mohamed , Abouelmaati Lotfi Ibrahim , Medany Mohamed Hussein 
Published: March 2023

Abstract
Drilling offshore requires debris removal operation to remove any debris or anomalies that have been highlighted or found during any previously remotely operated vehicle (ROV) operations or geophysical surveys for certain location before Rig approaches.
It is important to maintain any subsea structure and its premises clear from any debris that may affect any upcoming operation hence, the structure stability and safety regardless of water depth, which considered as one of the limiting factors.
Debris management is a major concern for all companies operate offshore rigs as offshore debris is responsible for many of the problems and much of the extra cost associated with extreme water depths. The offshore debris usually comes from trash, fishing gear, inadequate waste disposal and management, industrial activities, structure abrasion, construction and illegal dumping and other items lost off vessels or platforms at sea.
This paper discusses procedures and tool systems developed to optimize the efficiencies and economics of debris removal. Issues pertinent to water depths, debris size, shape will be discussed, with the problems associated with removal of debris caused by human activates, aged structure, inadequate waste disposal, etc. The authors will outline techniques and procedures for removal of this debris and discuss a tool system that is a workable solution for these problems. This paper will focus on the use of a Multipurpose debris lifter to remove debris from areas within platform vicinity that have normally proven very difficult. The system has been shown to be effective in removing debris from problem areas.
Validation of Patient Health Questionnaire- 9 and Pilot Study of its Diagnostic Properties in a Heterogeneous Lithuanian Speaking Population
Authors: Mineikytė-Bieliūnienė Kamilė , Kiziela Antanas , Viliūnienė Rima 
Published: March 2023

Abstract

Background
there is a high prevalence of depressive and anxiety disorders in the world, though the diagnosis is mostly insufficient. The Lithuanian-speaking population does not have a validated and open-access screening tool for depression. Due to appealing diagnostic superiority, universality within different populations, and open access the validation of Patient Health Questionnaire 9 (PHQ-9) is a must.
Methods
PHQ-9 was translated. Face, content, criterion-related, and construct validity checked by a group of psychiatrists. Two groups, clinical (N43) and non-clinical (N416), filled out the questionnaire. Reliability, internal consistency, parallel form variability, factor analysis, and diagnostic cut-off points were measured.
Results
PHQ-9 translation has confirmed psychometric validity as high reliability of the questionnaire was estimated with a Cronbach α of 0.858–0.877. Exploratory factor analysis indicated a one-factor structure. Questionnaire performed with great accuracy to distinguish the presence of illness in the clinical sample. Preliminary cut-off points were determined to be 8 with a sensitivity of 86.5%, specificity of 100.0% and accuracy of 89.1% across the psychiatric patient population.
Conclusions
The translated version of PHQ-9 is a reliable and suitable tool to screen for depressive symptoms.