bluuebunny/crossref_metadata_2025_split huggingface dataset:
Proximal Row Carpectomy with and without Capitate Resurfacing
Authors: Hones Keegan M. , Rakauskas Taylor R. , Hao Kevin A. , Densley Sebastian , Kim Jongmin , Wright Thomas W. , Chim Harvey 
Published: April 2024

Background:
In wrist salvage, proximal row carpectomy (PRC) has increasingly shown superior outcomes to four-corner fusion (4CF). Furthermore, PRC with resurfacing capitate pyrocarbon implants (PRC + RCPIs) provides a treatment option that may allow patients to avoid 4CF or wrist arthrodesis and help restore natural joint function and distribute loads evenly across the implant, though RCPI has yet to be evaluated on a large scale. We aimed to compare outcomes between PRC and PRC + RCPI for the treatment of scapholunate advanced collapse (SLAC) and scaphoid nonunion advanced collapse (SNAC) wrists.

Methods:
A systematic review and meta-analysis was performed per Preferred Reporting Items for Systematic Reviews and Meta-Analyses guidelines. PubMed/MEDLINE, Embase, Web of Science, and Cochrane were queried for articles on PRC and PRC + RCPI performed for SLAC and SNAC wrist with minimum 12-month follow-up. Primary outcomes included wrist range of motion (ROM), grip strength, and outcome scores including Disabilities of Arm, Shoulder, and Hand (DASH) and QuickDASH scores, Patient-Rated Wrist and Hand Evaluation (PRWHE), and visual analog scale pain scores.

Results:
Twenty-two studies reporting on 1,804 wrists were included (1,718 PRC alone, 86 PRC + RCPI). PRC + RCPI was associated with greater postoperative radial deviation, but poorer flexion. PRC + RCPI also had significantly lower postoperative QuickDASH (less disability and symptoms) and postoperative PRWHE (lower pain and disability) scores and an improvement in PRWHE compared with PRC. There was no significant difference in grip strength.

Conclusion:
PRC + RCPI demonstrated similar postoperative ROM to PRC alone. While PRC + RCPI was associated with more favorable outcome scores, further research is needed to confirm these findings and assess the incidence and profile of complications related to RCPIs.

Level of Evidence:

Level IV. See Instructions for Authors for a complete description of levels of evidence.
Brownfield Management: Waterflood Surveillance Framework, Streamline Simulation, and Bright Water Polymer Flooding
Authors: Patel Manav Divyeshkumar , Patel Shubham Bhavin , Brajesh Shantnu , S. Hari , Krishna Shanker 
Published: April 2024

Abstract
Mature oil and gas fields typically exhibit declining production rates, necessitating the application of various techniques to alleviate this decline. One such method is waterflooding, a secondary recovery technique involving the injection of water into the reservoir. This process displaces and sweeps oil towards production wells, thereby enhancing recovery rates. However, as these fields mature, challenges become more pronounced. The water cut, representing the ratio of water produced to total fluids, tends to increase over time, posing a significant threat to economic viability. It becomes imperative to implement strategic interventions and advanced technologies for efficient reservoir management, particularly in addressing issues related to aging wells, such as early water breakthrough, and maintaining optimal injection rates.
To tackle these challenges, sophisticated reservoir simulation models are employed to optimize injection patterns, predict reservoir behavior, and enhance overall field performance. Additionally, advanced surveillance technologies are utilized to monitor reservoir dynamics, identify regions with poor sweep efficiency, and adapt water injection strategies accordingly.
This research paper investigates the efficacy of the streamline method in various domains of reservoir management, with a focus on waterflood balancing, rate re-allocation, and improved oil recovery. Through rigorous surveillance analysis using streamline simulation-based workflow, dynamic well pair allocation factors, specific injector efficiency and strategic reallocation of water injection, significant improvements were observed in key producers, validating the adaptability and speed of the streamline method. However, challenges such as thief zones persist, necessitating further exploration. To address this issue of water recycling, bright water polymer was implemented. The bright water solution demonstrated remarkable efficiency in displacing remaining oil and enhancing oil recovery by improving sweep efficiency. This was achieved through a synergistic combination of polymer viscosity and mobility control, resulting in better reservoir sweep and increased oil displacement. Notably it yielded a substantial incremental oil recovery of 1.4 million sm3, accompanied by a significant reduction in water production by 2 million sm3. These findings underscore the effectiveness of the strategies employed, indicating enhanced reservoir performance and optimized oil recovery processes. As efforts continue to refine and expand upon these methodologies, the streamline method emerges as a promising tool for optimizing reservoir management and enhancing oil recovery processes.
Low Molecular Weight Sodium Polyacrylate to Minimize Polymer Retention in Clayey Formations
Authors: Muhammed F. , O’Brien T. , Mohanty K. , Niu F. 
Published: April 2024

Abstract
Clay particles can irreversibly adsorb polymers, limiting the availability of flowing polymers to sweep the reservoir. The adsorption in the near wellbore region can also lead to reduced injectivity. This study investigates the potential of sacrificial agents, specifically sodium polyacrylate, to mitigate polymer retention during polymer flooding. This research aims to determine whether the low molecular weight sodium polyacrylate can minimize polymer retention and enhance the performance of polymer floods in low permeability reservoirs.
Comprehensive experiments were conducted to evaluate the effectiveness of the sacrificial agents. Rheological measurements assessed any potential alteration in the main polymer solution's behavior due to the sacrificial agent's presence. An adsorption study was conducted with clays and crushed rock samples to determine the adsorption of a sacrificial agent and its effect on the adsorption of the polymer. Coreflood experiments were performed to determine the polymer retention and injectivity properties.
The results obtained from the experimental study demonstrated the potential of the low molecular weight polyacrylate polymer as a sacrificial agent in minimizing polymer retention. The sacrificial agent did not alter the polymer rheology. The static adsorption test shows that the pre-adsorption of the sacrificial agent can reduce the polymer adsorption. The adsorption of HPAM polymer in Illite clay was 0.79 mg/gm without the sacrificial agent. It was reduced to 0.44 mg/gm in the presence of the polyacrylate about 56% reduction. The dynamic coreflood tests showed that retention can be reduced significantly by 50% - 70% in the presence of the sacrificial agent. This reduction in retention enabled quicker pressure stabilization, increasing injectivity, and had the added benefit of reducing the residual resistance factor by approximately 47%. The protective layer formed by the sacrificial agent effectively reduced the irreversible adsorption of the main polymer, thereby preserving its integrity and functionality.
This study demonstrated that a small dosage of sodium polyacrylate could reduce the retention of polymers in low-permeability and clay-rich reservoirs. This treatment also increases the injectivity of polymers in clayey sandstone reservoirs. The properties of the liquid Na polyacrylate make it easy to use in the field during waterflood before starting polymer injection. Na polyacrylate can also contribute to scale prevention in and near the wellbore.
Numerical Evaluation of the Carbonate Acid Stimulation Coupling with Co2 Flooding
Authors: Jia Cunqi , Longlong Li , Sepehrnoori Kamy 
Published: April 2024

Summary
CO2 flooding is emerging as a pivotal technique extensively utilized for carbon capture, utilization, and storage (CCUS) strategies. Acid stimulation is one common technique widely employed to improve well-formation connectivity by creating wormholes. This work is motivated to investigate the gas-fingering behavior induced by the acid stimulation during CO2 flooding. We present an integrated simulation framework to couple the acid stimulation and CO2 flooding processes, in which the two-scale continuum model is used to model the development of wormhole dissolution patterns. Then, sensitivity case simulations are conducted through the EoS-based compositional model to further analyze the CO2 fingering behavior in acid stimulation formations separately under immiscible and miscible conditions. Results demonstrate that for acid stimulation, the typical dissolution patterns and the optimum acid injection rate corresponding to the minimum acid breakthrough volume observed in the laboratory are prevalent in field-scale simulations. For CO2 flooding simulation, the dissolution patterns trigger CO2 fingering (bypassing due to the high conductivity of wormholes) in the stimulated region, and a lateral boundary effect eliminating fingers exerts its influence over the system through transverse mixing. The optimum acid injection rate varies when the focus of interest changes from the minimum acid breakthrough volume to CO2 flooding performance. The best CO2 flooding performance is always observed in uniform dissolution. This work provides technical and theoretical support for the practical application of acid stimulation and CO2 flooding.
Flow Reversibility in Hydrogen Storage in Subsurface Aquifers
Authors: Lan Yuzheng , Lake Larry W. 
Published: April 2024

Abstract
Rising interest in hydrogen as an alternative energy source calls for investigation into how to produce, store and extract hydrogen efficiently from subsurface aquifers. This work studies the storage and extraction of hydrogen underground in aquifers using fractional flow theory. The similarity between injection (to store) and production (to extract) of hydrogen into and from the subsurface is how we define flow reversibility in this work.
First, we identify possible sources of irreversibility from the general fractional flow equations because these express how much of the injected hydrogen can be recovered. Full reversibility means that all the injectant will be recovered. Then, we examine, case by case, how shock formation, trapping hysteresis and gravity impact flow reversibility. Finally, we study how the shape of fractional flow curve and residual saturation hysteresis curve quantitatively affect flow reversibility.
We establish two types of reversibility. Reversibility of the first kind belongs to processes where the forward and reverse displacements are time symmetrical; such processes do not form shocks. Reversibility of the second kind refers to scenarios where key observables measured by an observer are not hysteretic. Hence, this study establishes several points of interest in quantifying hysteresis caused by flow reversal.
For hydrogen storage and extraction, we identify that both gravity and trapping hysteresis contribute to irreversibility of the first kind; gravity does not directly cause irreversibility of the second kind while trapping hysteresis necessarily does. Both kinds of irreversibility are associated with time asymmetry, with the second kind of irreversibility being incapsulated by the first kind of irreversibility.
South Oman Polymer Project: A Decade of Operational Excellence and Comprehensive Reservoir Monitoring and Surveillance
Authors: Al Sawafi M. M. , Aljabri A. 
Published: April 2024

Abstract
The largest polymer flood field in the Middle East has been in operation since 2010, with over 45 polymer patterns and approximately 300 wells. Over the past 13 years, the project has faced various challenges, including ensuring sustained injection uptime, maintaining polymer viscosity stability, and optimizing the polymer pumps uptime, all of which directly impacting the field's polymer oil recovery.
Managing such a complex project necessitates a comprehensive understanding of fluid dynamics. To comprehend the reservoir's behavior, an exhaustive surveillance plan is conducted annually, enabling the team to assess performance and take appropriate actions as needed. A substantial amount of data has been gathered to monitor polymer performance, encompassing surface and subsurface aspects such as wells' production data, polymer and water injection rates, polymer daily consumption, polymer viscosities, back-produced polymer concentration, pressure data and others.
The large amount of data requires periodic analysis. To facilitate this, the team has developed automated tools to visualize polymer flood performance in real-time. These tools incorporate pre-defined sets of algorithms to retrieve surveillance data and present it in easily interpretable charts and tables, allowing the team to concentrate on areas of concern.
Furthermore, well and pattern monitoring is conducted through an approach known as exceptional based surveillance (EBS), which triggers alarms when data deviates from preset operational parameters.
These efforts have resulted in increased recovery from the polymer flood. Surveillance activities have demonstrated the effectiveness of data-driven and focused efforts in improving performance. In conjunction with operational excellence, an increase of around 50% in oil recovery has been achieved over the past few years.
The paper will provide examples of acquired data, analyses performed, and actions taken to enhance oil recovery.
The Investigation into Carbonated Water as Pre-Fracturing Fluid to Improve Shale Oil Recovery by CT Online Scanning and Imbibition Experiments
Authors: Han Xiaobing , Yu Haiyang , Tang Huiting , Shi Jianchao , Huang Tao 
Published: April 2024

Abstract
Carbonated water (CW) imbibition is an effective method for enhanced oil recovery, by combining the advantages of CO2 and water. Nevertheless, there are few reports in existing studies on its performance in shale oil reservoirs. This research is specifically focused on these shale oil reservoirs, investigating the variation in countercurrent imbibition distance (CID) and the imbibition effects of using CW as a pre-fracturing fluid. In this study, CT online scanning experiments were conducted with shale cores to investigate the CID of formation water, CW, and fracturing fluids. Simultaneously, we determined and comparatively analyzed the countercurrent imbibition recovery (CIR) of these fluids. Furthermore, imbibition experiments were conducted using a high-temperature and high-pressure visual apparatus to assess the imbibition recovery of formation water, CW, and fracturing fluids. The findings suggest that CW significantly enhances shale oil recovery, with CID and CIR values reaching 1.75 cm and 6.95%, respectively. Compared to formation water and fracturing fluid, the CID of CW increased by 0.75 cm and 0.25 cm, while the CIR rose by 4.77% and 1.90%, respectively. CW achieved the highest imbibition recovery at 29.22%, exceeding that of fracturing fluids (25.18%) and formation water (10.25%). In this research, the application of CW as a pre-fracturing fluid to enhance shale oil recovery is introduced for the first time. Moreover, it quantifies the CID of CW and fracturing fluids in shale matrices, offering a pioneering strategy for the enhanced coordination of fracturing, shut-in, and production processes in shale oil exploitation.
Adsorption Kinetics of Copolymers and Sulfonated Polymers for Enhanced Oil Recovery
Authors: Silva C. , Beteta A. , McIver K. , Sorbie K. , Johnson G. , Hesampour M. 
Published: April 2024

Abstract
Polymer flooding is one of the most mature enhanced oil recovery (EOR) techniques, where the injection water viscosity is increased through addition of a high molecular weight polymer. In field operations, one of the most critical parameters for successful polymer flooding is the polymer adsorption. During transport, the polymer will irreversibly adsorb onto the reservoir rock, with the exact extent of adsorption depending on reservoir/polymer properties, such as the polymer composition and molecular weight, mineralogy of the reservoir, brine composition, reservoir temperature etc. For each reservoir, there will be an upper limit of adsorption above which sufficient polymer will be removed from solution to make the process uneconomic.
Copolymers of acrylamide (AM) and acrylic acid (AA) have been the most prominent chemicals to be applied, whereas sulfonated polymers containing acrylamide tertiary butyl sulfonic acid (ATBS) have been used for higher temperature and/or salinity conditions. In this work, it is demonstrated that there is a large kinetic component to the adsorption for a range of six polymer species on silica sand. The work was carried out in a field composition brine at a temperature of 31°C. The polymers consisted of AA-AM co-polymers (20-33 % AA) and AM-AA-ATBS ter-polymers (up to 15 mol% ATBS). While an adsorption of ~20 µg/g was measured after 24 hours, this increased continuously over 20-30 days for the AA-AM co-polymers. The same trend was observed for the AM-AA-ATBS terpolymers – with an adsorption at 24 hours of ~15 µg/g increasing over time to 36 ug/g. Two polymer species (33 % AA & 15 % ATBS) were then taken forward to dynamic core flood experiments where a novel shut-in procedure was used to highlight the kinetic behavior. The breakthrough profiles were matched via numerical simulation using a simple isotherm and kinetic constant. These results were then extrapolated to other conditions to highlight the potential for misinterpretation of traditional core flooding approaches. To the authors knowledge, the kinetic adsorption and its impact has not been very extensively discussed in the literature.
The ability to accurately plan polymer flooding projects is essential to fully optimise recovery performance as efficiently as possible, minimise the environmental footprint and reliably predict polymer breakthrough for production chemistry requirements. Thus, a complete understanding of the polymer adsorption and adsorption kinetics is critical for the continued development of polymer EOR.
Review of Ongoing CO2 Enhanced Oil Recovery Operations in Wyoming, USA
Authors: Robertson E. P. 
Published: April 2024

AbstractThis paper presents a summary of oil recovery from each of the nine commercial scale CO2 enhanced oil recovery projects in Wyoming along with a brief discussion of the geology of the fields. The current CO2 supply and pipeline system for the State is discussed along with an estimate of potential future production from CO2 enhanced oil recovery (EOR), if widely employed in Wyoming. CO2 injection, production, and pipeline sales data were obtained from the Wyoming Oil and Gas Conservation Commission and supplemented where possible by production data elsewhere in the public domain; all data used is public. Wyoming has world-class fields that have proven to be excellent targets for CO2 EOR. The process has been used in Wyoming since 1986 and there are nine commercial-scale floods that are currently active in the State. The average incremental oil recovery for Wyoming's ongoing CO2 EOR floods is over 10% of original oil in place and the average total incremental oil recovered for all ongoing CO2 floods is over 15 million barrels per reservoir and over 135 million barrels for the State. Since 2010, over 10% of the state's oil production has been incremental oil from CO2 floods. The State has excess CO2 supply that can be used for EOR, the current pipeline system has excess capacity, and the State has many fields within its four main oil producing basins that appear to be amenable to CO2 EOR.
Hydraulic Fracturing and Flowback in the Heterogeneous Unconventional Formation: Do Water Blocks Still Play a Role?
Authors: He Zexuan , DiCarlo David 
Published: April 2024

Abstract
Understanding the dynamics of water blocks in reservoir formations is crucial for optimizing hydrocarbon production in unconventional reservoirs. This study investigates the impact of heterogeneity on water block behavior through experimental analysis using a composite heterogeneous two-layer core sample. The experimental results reveal that the presence of high permeability layers mitigates the severity of water blocks compared to homogeneous low permeability layers. During hydraulic fracturing, fracturing water primarily invades the high permeability layer, resulting in uneven water saturation distribution across the core sample. Pressure drop analysis during flowback and hydrocarbon production indicates rapid normalization of pressure drop in heterogeneous unconventional formations, contrasting with prolonged normalization in homogeneous formations. These findings underscore the importance of reservoir heterogeneity in minimizing water block impact and optimizing hydrocarbon production. By elucidating the mitigating effect of high permeability layers on water block behavior, this study provides valuable insights for reservoir management strategies in unconventional reservoirs.
Full Field Polymer Flooding Development Concept in Nimr Oil Fields with Horizontal Injectors and Strong Bottom Aquifer
Authors: Karpan V. M. , Bimani A. , Bellman L. , Ketkar S. , Amri I. , Al Sulaimani H. , van Batenburg D. W. , Zaynetdinov T. , Bouwmeester R. , de Almeida P. 
Published: April 2024

Abstract
The Nimr fields comprise a group of medium size mature oil fields in the Southern part of Oman. This study focuses on Nimr-A and Nimr-E fields. The fields have similar reservoir properties and have been in commercial production since 1980 through the depletion. The strong regional bottom aquifer provides pressure support in these fields. The combination of a strong aquifer and relatively high viscosity of Nimr crude (~250-700 cP at reservoir conditions) resulted in the rapid development of water conning, limiting the oil recovery efficiency. Therefore, polymer flooding was selected as the technology to improve recovery. During 2013-2019, a polymer injection trial was executed in the Nimr-E field, whereby three horizontal injectors were used to evaluate the performance of polymer flooding under the reservoir conditions. As a result, the incremental recovery factor due to polymer has reached ~7% of STOIIP. Furthermore, due to the strong bottom aquifer, incremental oil production was observed even during the extended periods of injection shut-in through the "water cone recharging" mechanism. This has led to the proposal of a new polymer flooding concept for oil reservoirs with strong bottom aquifers called Nothing-Alternating-Polymer (NAP). In 2020, a new field trial was started in the Nimr-E field to investigate the performance of the concept under controlled field conditions and identify the optimal NAP design.
This publication presents the conceptual design of an integrated polymer flooding project in two mature Nimr oil fields. Both surface and subsurface considerations were taken into account and discussed here. Despite moving at different project development paces at the earlier stages, the projects were synchronized, and their value drivers were reviewed in line with modern-day requirements. Considerable attention was paid to reducing carbon intensity and water source sustainability. Polymer flooding was selected due to incremental and accelerated oil recovery at reduced carbon intensity. The selection of a sustainable water source was also important, given the high value of water resources in Oman.
Commercial-scale polymer flooding in Nimr A and Nimr E is PDO's most recent polymer flooding project, with value drivers focused on reduced CO2 intensity, water sustainability, and commercial robustness. The proposed multi-field, phased polymer development concept uses ~80 horizontal injectors above the oil-water contact to benefit from the aquifer support. Nimr is a flagship project for polymer flooding, with its results defining the development of polymer flooding in Oman for years to come.