bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Concept of Enhanced Oil Recovery (EOR) in Permian Basin. Chlorine Dioxide (CLO2) as Re-Stimulation Agent in Unconventional, Multi-Fractured Horizontal Wells
Authors: Dalamarinis Panagiotis , Fusselman Stephen 
Published: January 2025

Abstract
In conventional reservoirs secondary and tertiary oil recovery have been established methods to increase reserves and extend the production life. In unconventional reservoirs with matrix permeability being as low as nano-Darcy traditional EOR methods have to prove their technical, physical, and economic viability. A new concept for EOR which is used to improve injectivity in SWD wells has been successfully applied in the Permian Basin resulting in production uplift and EUR increase.
The concept/idea was simple. The fracture system that is created during hydraulic fracturing operations is the subsurface pathway for the reservoir fluids to the wellbore. This pathway is subject to scale, paraffins and biofilm depositions as are surface flow lines and facilities. Engineered Chlorine Dioxide (CLO2), a strong oxidizer capable of breaking down and keeping all these proppant pack contaminants in solution, was introduced as an EOR/restimulation agent. Reservoir PVT properties, scale tendencies, and production decline rates were considered to develop "fit for purpose" treatments ranging in volumes between 1,500 – 4,000 bbls of total fluid pumped into the wells.
In our first application of Chlorine Dioxide (CLO2) for restimulation and EOR that was presented by Dalamarinis, et al, 2023, wells at which a similar artificial lift system was installed demonstrating improved production between 70% to 300%. Chlorine Dioxide treatments were pumped in the same wells multiple times over the last three years (with an average frequency of one year) and every time these wells were re-stimulated, production and Downhole Bottom Pressure were restored to the levels observed after the first treatment (as high as 80% when compared to the wells’ IP rates). Furthermore, the application of this Fracture -EOR (F-EOR) method was expanded in Reeves, Culberson, Pecos, and Martin County with more than 60 treatments pumped in approximately 40 wells with oil gravities from as low as 30° to as high as 55° API, with similar success, proving its effectiveness in different environments. The production uplift that was achieved further validated the theory that production decline in unconventional wells is not related exclusively to reservoir depletion but to the skin damage effect developed inside the fracture system, resulting from scale, biofilm, paraffin, and asphaltene deposition, something that Chlorine Dioxide (CLO2) can effectively remove from the near wellbore area, thus restoring the reservoir/wellbore conductivity.
Production results demonstrate that significant production uplift can be achieved, sometimes &gt;500%. With thousands of legacy wells in inventory, operators can mitigate production decline and deferment with Chlorine Dioxide treatments, mitigating the need to constantly drill new wells to achieve production targets.
Maximizing Hydraulic Fracturing Performance and Reducing Emissions Though Acoustic Friction Analysis
Authors: Kroschel J. , Seely B. , Fatheree K. , Khan M. 
Published: January 2025

Abstract
Synergizing new industry synergies requires disruptive, synergizing technologies. This study involves using acoustically measured perforation friction and efficiency to optimize hydraulic fracturing operations for 1876 Resources in the Powder River Basin. Contingent on maintaining optimal fluid distribution, 1876 sought to increase operational efficiency by increasing the stage length to decrease the number of required wireline runs to complete the hydraulic fracturing stimulation. While maintaining fluid distribution across the lateral section of each stage, 1876 was able to increase cluster count, increase stage length, and maintain total proppant for the well. The result was significant reductions in required normalized hydraulic horsepower-hour (HHP/bbl slurry), evidence of improved treatment, and operational efficiency gains. This improvement in treatment also yields reductions in diesel required per stage and decreases emissions per stage.
New Hybrid Workflow for Field Development Planning and Execution: Early Time Fracs vs Long Term Production
Authors: Williams-Kovacs J. D. , Deryushkin D. , Clarkson C. R. 
Published: January 2025

Abstract
Recently, a hybrid workflow for cost-effective and efficient field development planning and execution was introduced to accelerate learnings from post-frac data and to inform development decisions, without waiting for long-term production. This workflow combines typically gathered field data (i.e. geomechanics, flowback and short-term production) with existing integrated workflows to significantly reduce uncertainty and execution time associated with today’s asset development workflows. Although powerful, this workflow lacks ties with long-term production data and does not account for variability in fluid properties across the asset, which limits wide-spread applicability.
In this paper, the hybrid workflow will be extended to incorporate long-term production data. The extended workflow incorporates a series of correlations and asset maps which can be used to benchmark and improve completion design selection and performance, with the ultimate goal of streamlining asset development. The workflow includes the development and application of the following: 1) asset map of effective stress; 2) asset map of permeability 3) fracture area correlation (effective stress vs. fracture area); 4) normalized rate correlation (90-day production rate vs. linear flow parameter, LFP); and 5) long-term production correlation (extended production vs LFP). Component 5 is the key new addition to the workflow, which adds significant value and improves the widespread applicability in complex assets. A mass-flow rate approach will also be utilized to enhance the ability to compare productivity from wells producing from varying fluid types.
By integrating flowback analysis (FBA) with other multi-disciplinary analysis methods into this enhanced hybrid workflow, operators can effectively improve development efficiency and performance of their assets over both short and long-term production. The enhanced hybrid workflow will be demonstrated using a case study from a high-profile asset in a prolific North American unconventional reservoir. The studied asset shows significant variability in fluid properties, geomechanics and productivity.
Using this workflow, operators can connect initial reservoir and fluid properties to long term asset performance and by integrating FBA, link geomechanical properties to stimulated area with a given design to achieve target frac and production performance. Incorporating this workflow also assists with minimizing both G&A and development capital costs.
By incorporating long-term production into the hybrid workflow, the widespread applicability is significantly improved, while also providing a key link between early-time frac performance and long-term productivity. Using this enhanced hybrid workflow, operators can unlock the full potential of their assets, while dramatically improving the efficiency and cost-effectiveness of asset development.
A Unique Process Using a Modified Slickwater Treatment that Enables Optimized Depletion of Shales and Tight Reservoirs with and without Laterals and Less than Half the Sand Used for Typical Lateral Completions
Authors: Ely John , Harper Jon , Wolters Brad , Jacoby Mark 
Published: January 2025

Abstract

Objectives/Scope
A frac design procedure which varies widely from the typical present-day design has been shown to achieve economic success utilizing larger volumes and much less proppant than presently used. The Authors will document at least 5 years of production of both horizontal and verticals. This data indicates tremendous potential for vertical stimulation of shales and tight reservoirs across the country.

Methods Procedures, Process
The type of design was an offshoot of work done in the Bossier Shale 20 + years ago. The Fracpro model is used for optimization of the volumes. The previous success seen in the Bossier using alternating sweeps (no proppant) allows for successful propping with higher effective volume than continuous sand addition. Very selective perforating is used allowing for pseudo limited entry. Although a very high success rate was achieved with high volume verticals, the industry was not receptive to anything other than horizontal completions.

Results, Observations, Conclusions
As we have often been reminded, we need to study the past lest we make the same mistake again. In this case we studied the past and discovered that there is a viable slick water technique to stimulate verticals in ultra tight reservoirs and to optimize our present-day horizontal designs. We will present multiple well production from 7 different reservoirs and compare production and economics with the "Waterfrac Sweep" process and offset horizontal production. Because of having a huge data base on one reservoir we will go into depth with a particular play in New Mexico where specific completion design was used to optimize production over time. The results of utilizing this technique are intriguing due to the lack of intuitive historical frac understanding. The process does not bow to the "pump more sand" adage and destroys the long-held worry of over flushing destroying near well permeability.

Explanation of benefit to practicing Engineer
The results from the large volume high-rate treatments with less sand will allow for a different approach to slick water stimulation. The approach shown in this paper will allow for strong consideration of a different technique to allow for economic completion of tight reservoirs.
Practical Methods for Completing the SCOOP Woodford and Sycamore
Authors: Calvin James , Pinkerton Hap , Shepherd Cameron 
Published: January 2025

Abstract
The Anadarko Basin is one of the deepest basins in North America. It extends over 50,000 square miles from Central Oklahoma into both the Oklahoma and Texas panhandles as well as parts of Colorado and Kansas. The predominant hydrocarbon types are light oil, condensate, and natural gas. Approximately 14,000 horizontal wells have been completed since 2010, but the basin has been favorable for both vertical and horizontal completions. The basin can be divided into several sub areas which include the STACK and the SCOOP. Given the depths as well as the complex geology, major plays such as the Woodford Shale and the Mississippian (Sycamore Formation and Meramec Formation) present many challenges to completions which include but are not limited to as follows:
High treating pressures Faulting and seismicity Skin damage related to polyacrylamide friction reducer Near wellbore complexity and leak-off encountered during completions Sub optimal well spacing and well communication
On top of the geological challenges, Operators continue to be challenged with improving well economics by improving well production and simultaneously controlling or reducing costs. This translates into the following general objectives for completions:
Higher desired treatment rates Larger proppant amounts Larger water volumes Reduced completion times Deploying economic chemical packages Mitigating adverse well communication Reducing seismicity where applicable
Practical methodologies that help mitigate the subsurface challenges as well as help Operators meet their economic challenges will be discussed. These methods and their effectiveness are examined through a combination of conceptualization, field testing, lab testing, data analytics, statistics, and geomechanical modeling. A case history regarding a series of wells drilled in both the Sycamore and the Woodford in the southern part of the SCOOP that required well intervention techniques will also be presented. Several of the above-mentioned methodologies were deployed to optimize the well completions and meet operator objectives. Case histories for the above-mentioned methodologies will also be presented separately where applicable.
Improved operational efficiencies and production can be observed when utilizing targeted methods. As examples, stimulations can be sized based on proper data analysis and modeling by area and formation which can improve well economics by avoiding the oversizing or under sizing of stimulations. Next, production can be enhanced by the utilization of less polyacrylamide in fluid systems or utilizing a non-polyacrylamide polymer. Also, operational inefficiencies related to near wellbore complexity and fluid leak-off can be mitigated using tailored and adjustable fluid system packages as well as operational breakdown techniques. The fluid leak-off mitigation alone has implications on stimulation cluster efficiency, well communication, fracture geometry growth, and seismicity mitigation.
Design, Test, Evaluate, Repeat: Continuous Improvement of Field Development Through Field Testing and Modelling, a Marcellus Case Study
Authors: Pichon Stephane , Buchanan Christopher , Khazov Nikolay , Segstro Ryan , Rios Carmen Gomez , Slikas Miguel , Depaz Mirko Hernandez 
Published: January 2025

Abstract
Optimization of the development of unconventional resources is a continuous process, with each iteration providing incremental progress. The objective of this work is to describe the journey from field test design, data acquisition, execution, evaluation, and modeling to provide guidance for decision-making and to show how improving the understanding of an asset translates into practical enhancements for its field development.
The case study involves two "high data density" pads in the Marcellus, utilizing chemical tracers, perforation imaging, and production logging, in addition to legacy data acquired from the asset. After thoroughly evaluating the acquired data, a complete pad is history-matched using an integrated hydraulic fracturing and reservoir simulation workflow. The calibrated model is then used for a sensitivity study, which is further enhanced through machine learning with a customized script developed in Python. This creates a large library of cases linking field development to production, well cost, and economics.
Success is defined by achieving conclusions with reasonable certainty that can be implemented, along with a quantifiable production and cost impact. To achieve this, the design of the field experiment is critical. Initiated by preliminary observations from legacy datasets, both test pads aimed to test the effectiveness of the field development assumptions. Tailored data acquisition programs revealed that stage architecture did not deliver on its promise and that well spacing can be a strong lever for well performance. Learnings from the first pad helped refine the test design for the second pad, highlighting that stage architecture offers a better return on investment than increasing sand and fluid volumes.
Building on field observations, numerical modeling, later enhanced by machine learning, provides a holistic view of development scenarios. This, combined with integration with well cost and economics, delivers directional guidance on where the field development could be taken next, depending on the business strategy.
The case study is the result of multiple years of effort, providing practical examples to illustrate how a better understanding translates into modifications of the field development of an asset to maximize return on investment.
A New Method to Quantify the Connections Between Wells Based on Pressure and Strain Responses Measured in a Monitoring Well
Authors: Liu Jingyu , Wu Kan , Jin Ge , Blasingame Thomas A. 
Published: January 2025

Abstract
Well interference test methods in Multi-Fracture Horizontal Wells (MFHWs) focus on the connectivity and conductivity between the "entire" wells. Practically it is challenging to identify the contribution of each fracture from each cluster in a MFHW. However, understanding fracture connections at the cluster level can provide detailed guidance for optimizing completion designs and well spacing. This work proposes a new method to interpret far-field strain change and pressure data to quantify fracture connectivity and properties at the cluster level. The case study uses field data acquired from the DOE Hydraulic Fracturing Test Site-1 (Phase III) performed in the Eagle Ford shale. A dedicated well with permanent fiber and external pressure gauges installed was used to monitor strain and pressure changes (respectively) during put-on production (so-called "POP") of adjacent wells. A 1D linear flow model was proposed to simulate transient flow within fractures, allowing for the calculation of pressure responses at the monitoring well. By assuming a linear relationship between pressure and strain changes, we were able to match the observed pressure and strain changes to determine fracture connectivity and conductivity between the production and monitoring wells.
Using field data from permanent fiber and external pressure gauges, we validated the analytical solution for modeling changes in strain during initial production performance. We note that the pressure and strain changes indicate the same fracture properties. During hydraulic fracturing treatment, 59 fracture hits were identified in the monitoring well, which is 250 ft horizontally from the producing well. During initial production, DSS strain data revealed only 20 fracture connections among 230 clusters between the producing well and the monitoring well. The calculations show fracture conductivities ranging from 0.1 to 15 mD·ft, with 10 connections exceeding 1 mD·ft. This analysis provides an important observation: out of the 230 perforation clusters and considering a well spacing of 250 ft, approximately 26% of the fractures connected from the treatment well to the monitoring well during fracturing, while only about 9% of the fractures remained connected during initial production. This study introduces an innovative interpretation method that can be used to quantify fracture connectivity and conductivity at the cluster level by leveraging advanced monitoring technology in unconventional reservoirs. This approach provides practicing engineers with unique data to optimize the well completion designs and well spacing, thereby enhancing the development and productivity of unconventional reservoirs.
A Study of Water Injection in Structural High Relief Gas and Condensate Reservoirs
Authors: Leon-G. Alfredo , Samaniego-V. Fernando , Perez-H. Jose Luis , Lopez-C. Fabian , Urquieta Edgar , Rivas-G. Santiago 
Published: January 2025

Abstract
Compositional single porosity and naturally fractured 3D simulation studies are presented for the Fenix and Giraldas gas and condensate fields, aimed at investigating the effect of the recovery of the high condensate content of these reservoirs of a very active aquifer and of water injection in the aquifer, for the former and the latter respectively. The Fenix field producing formation is made of fractured dolomite and limestone, with matrix porosity ranging between 4 and 8 percent, well test estimations of permeability around 4 md and a structural relief of 984 ft. The initial condensate content was 297 STB/MMSCF and a dew point pressure of 6009 psi. The highly active aquifer associated to this reservoir has caused that during its exploitation, the pressure behavior has been at conditions above the dew point pressure. The simulation study for this field analyzed the effects on the condensate recovery of the reservoir production rate, of the formation properties and aquifer activity. Currently, the estimated condensate recovery factor is 60 percent, and the estimated figure would not be an aquifer is 30 percent. Based upon the analysis of the strongly water influx case history of the Fenix field, a simulation study was performed for the giant Giraldas field, presently at an advanced stage of exploitation. This reservoir has an associated small aquifer, showing a high structural relief of 2624 ft., porosity of 7 percent and permeability of 1.5 md. Three cases were studied: natural depletion and water injection at high pressure conditions above the dew point and at current low pressure field conditions. Water injection was controlled injecting about 30 percent of the hydrocarbon pore volume, completing the injection wells at the bottom of the reservoir to make the best use of the gravitational effect. After waterflooding, final blowdown operations were also simulated. For the low pressure waterflood case, 51 percent of the hydrocarbon pore volume was injected and a production forecast was carried out for the next 15 years. The estimated condensate recovery factor for the natural depletion, for the high pressure and for the low pressure cases, were 34.9, 45.2 and 44.2 percent, respectively. From the results of this study, it can be concluded that properly conducted water injection on high structural relief gas and condensate reservoirs, results in an important increase of the condensate recovery.
Occurrence Of Multiple Myeloma In A First Degree Relative Of A Previously Diagnosed Patient
Authors: Obodo Onochie I. , Anigbo Chukwudi S. , Ocheni Sunday , Obodo Odichimma C. , Duru Augustine N. , Okoye Helen C. , Obiefuna Adaobi G. 
Published: January 2025

Abstract

Background
Multiple myeloma (MM) is a haematological malignancy characterized by neoplastic proliferation of terminally differentiated plasma cells. First degree relatives of patients who previously suffered from MM are believed to be at an increased risk of developing the disease. Though this is a very rare occurrence, it suggests that there are genetic factors that play key roles in the pathogenesis of the disease.
Objectives
To report a case of familial multiple myeloma and highlight the need for family screening.
Methods
This is the case report of a 65-year-old woman who presented to our clinic requesting to be screened for MM, as she was being worked up for a knee replacement surgery due to severe osteoarthritis of the right knee. She gave a history of MM occurring in her mother, who later passed following complications from the disease. She had no significant associating complaint, other than incidental findings of anaemia on complete blood count (CBC) during routine clinical visits.
Results
Results showed an ESR of 76mm/1hr, IgG was elevated at 3079 mg/dL (700–1600), elevated kappa FLC of 86.1mg/L (6.7–22.4), kappa/lambda FLC ratio of 7.688 (0.31–1.56), and bone marrow plasmacytosis of > 30%, with numerous abnormal forms (flaming cells, multinucleated cells) seen.
Conclusion
Cases of familial MM have been reported in the literature, with the majority occurring amongst siblings, and a few in the off-springs of previous MM patients. This case report highlights the need for routine screening and genetic counselling to be offered to first-degree of persons with multiple myeloma.
A comprehensive landscape of human organ N-glycoproteome
Authors: Tian Zhixin , bi ming , Wang Tao , Qin Chao , Yuan Yanggang , Qin Suideng , Liang Hongwei 
Published: January 2025

Abstract

N-glycosylation, as a common post-translational modification with enormous structures, plays key roles in protein folding, cellular recognition and signaling pathways. State-of-the-art mass spectrometry-based N-glycoproteomics has enabled deep N-glycoproteome characterization of various human organs. However, a comprehensive N-glycoproteome landscape of human organs remains lacking. Here we present a systematic human N-glycoproteome atlas spanning 18 organs/tissues with identification of 31,003 N-glycan structure-level and 14,043 monosaccharide composition-level intact N-glycopeptides on 5,539 N-glycosites of 3,681 N-glycoproteins. Tissue-specific N-glycosylation patterns, novel glycoforms and crosstalk between sialylation and fucosylation are observed. This atlas, complemented by a unified multi-software analysis framework, provides insights into organ-specific glycobiology and establishes a fundamental reference for understanding physiological N-glycosylation characteristics of human tissues.