bluuebunny/crossref_metadata_2025_split huggingface dataset:
Correlating Flow Station Parameters with Oil Wells Performance
Authors: AlAklubi Sultan. A. 
Published: March 2024

Abstract
Offshore production system assessment is very important to maintain and optimize wells performance including ESP, gas lift, natural flow wells, flow line network and de-bottlenecking. The oil production gain from optimization will add great value in maintaining production targets and increase the Maximum Sustained Capacity (MSC) which is the maximum production rate can be produced for stable period within a notice of not more than two months. Offshore optimization includes new facilities such as flow stations, gas lift capacity, introducing new ESP wells, laying down new flow lines and additional transmission lines. Production optimization changes warrant an update and reassessment of the production model used for optimization and de-bottleneck studies including the review and evaluation of the existing well & network models to develop a clear strategy and to update the production model with optimization. The optimal lifting rate according to the well level can be determined by varying the gas lifting rate and comparing its rate of change with the minimum economic rate of change which can be obtained during the ability tests for each well considering changing the gas lift injection rate to sense the impact on the production rate with the best increment to get within the given gas injection rate.
In order to assist oil and gas field workers in daily activities and to optimize the time they spent checking and opening closed wells which is a tedious job especially during rough sea conditions and when there is no available means of transportation, a new way of tracking wells production throughout the flow lines pressure feeding the flow station are presented and examined in order to focus on some areas to regain the production loss due to wells shut in suffering from the back pressure exerted by other wells on the stream. Gathering data from several flow lines to build a database which will be much appreciated especially for offshore fields where there is no Supervisory Control and Data Acquisition "SCADA" Units during rough sea conditions and in emergency cases to overcome production loss.
Digitalizing the Management of Electric Submersible Pump Failures Through Failure Prevention and Post-Mortem Analysis Tools
Authors: Ellsworth Michael , Joseph Rejish , Hematillake Dylan , Diaz-Goano Carolina 
Published: March 2024

Summary
The replacement and maintenance of Electric Submersible Pumps (ESP) represents a significant operating expense for any in-situ Oil Sands operation. The goal at Suncor's in-situ operations is to effectively and efficiently manage ESP failures to lower costs, maintain production, reduce carbon emissions, and contribute to safe operations. This goal is in part, accomplished through a collection of software tools that automate and enhance Production Engineering workflows related to the management of over 300 ESPs. An overview of the overall digitalization effort, including information about the development and rationale behind the centralized ESP information and analytics database, various failure prediction tools and anomaly detection methodologies, and the application that delivers these solutions is discussed. The estimated impact of this effort is measured through accuracy. The ideas behind the effort have, both directly and indirectly, contributed to the increase in ESP run life, the decrease in ESP replacement time, the decrease in person-hours per ESP required for management, the increase in safe operations, and the increase to general well availability.
How to Sustainably Improve Production Recovery from Existing Wells
Authors: Moen E. , Antonsen R. , Ejofodomi E. A. 
Published: March 2024

Abstract
In today's oil and gas landscape, production recovery from existing wells remains a pertinent challenge. The ever-increasing demand for hydrocarbons and the emphasis on optimized output have led to the endeavor of maximizing production from established wells. However, despite technological advancements, a significant proportion of these wells underperform, either due to inherent issues, such as formation damage, or a decline in reservoir pressure over time. Traditional methods like bullheading chemicals from the surface have struggled to consistently deliver efficient and sustained solutions. This pressing issue has prompted a shift toward innovative methodologies to restore and sustain productivity in underperforming wells. The oil and gas industry requires robust and sustainable techniques that can efficiently address these challenges, optimizing the productivity of existing wells.
This paper presents a novel, data-driven process that uses a downhole, hydraulically activated system to restore and sustain productivity of sub-par producing oil and gas wells. The paper details the steps required to identify and restore the productivity of underperforming wells. Results are compared with traditional solutions based on bull heading chemical treatments from surface.
Integrated Downhole-Measurement-Enabled Coiled Tubing and Mechanical Wireline Recovery of E-Line Cable in a Live, Sour Gas Well
Authors: Villagrana C. , Abouganem A. , Afsal A. M. , Al-Dahhan M. , Delaune J. , Tapia W. R. , Amri M. 
Published: March 2024

Abstract
This study details a complex wire recovery operation in a live well that involved transitioning from coiled tubing (CT) to mechanical wireline (MWL), in both slickline [MA1]or braided line, to retrieve the wire in good condition and later hand it over to an electrical wireline (e-line) unit to spool it onto a drum. The operation was carried out on a live, sour gas well, demanding a unique setup and emphasizing safety. Two successful recovery operations removed a significant amount of e-line left in the well plus the upper section of the e-line bottomhole assembly (BHA) while safely pushing the lower section of the e-line BHA to the bottom of the well. An integrated, multipurpose pressure control equipment (PCE) stack provided safety and redundancy, facilitating retrieval with both CT and MWL. The PCE stack design proved robust, enabling recovery without killing the well. Notably, the operation seamlessly integrated CT, MWL, e-line, and a stimulation vessel, all utilizing the same PCE. A significant challenge involved the handover of the recovered e-line from CT to MWL, requiring careful coordination and movement to prevent stripping the retrieved e-line inside the wire-line valve rams and the risk of gas leaks. Innovatively, this operation marked the first use of downhole measurements for wire recovery alongside the application of jars and impact hammers while pumping on the backside of the coiled tubing, a pioneering approach in this context of live-well e-line recovery. Downhole measurements, particularly tension and compression readouts, aided decision-making, reducing the need for reruns. Furthermore, a downhole camera captured changes in the e-line and BHA. Overall, this operation represents an innovative achievement in wire recovery from live, sour gas wells.
Flowback Three-Phase Flowmeter Implementation for Post-Fracturing Cleanouts: A Case Study from Argentina
Authors: Mirande J. M. , Vassallo J. , Mambriani P. , Gonzalez C. , Fajardo E. , Vecchietti M. , Krasuk R. , Misonischnik A. 
Published: March 2024

Abstract
Unconventional horizontal wells completed with plug-and-perf fracturing techniques require coiled tubing (CT) to clean out the well before it is put into production. To remove proppant and plug debris, water is pumped into the wellbore and flowed back to the surface through the annular section between the CT and the production casing. This study describes implementation and impact of a three-phase flowmeter to measure the return rate and detect proppant and gas in real time.
During CT post-fracturing cleanouts, fluid return rate is critical to monitor because the annular fluid velocity that carries solids out of the well is proportional to it. In addition, wells in Argentina must be kept in a near-balanced condition to avoid producing gas from the well. Fluid return rates used to be measured with an ultrasonic flowmeter, which experienced signal loss when there was more than 5% sand or gas in the fluid, making it unreliable for this workscope. A three-phase flowmeter was therefore implemented to achieve high-frequency and real-time measurements of water, proppant, and gas at the surface.
Implementation of the three-phase flowmeter allowed cleanout optimizations without sacrificing operational safety. Having a precise and continuous measurement permitted the variation of the flowback choke strategy, increasing the return rate to a value closer to the pumping rate by 0.1 bbl/min without affecting the well balance condition. During the execution of the first four-well pad after this new flowmeter was implemented, analysis of the sand flow rate measurement showed that the wells were already clean when the CT had to be pulled out of hole (POOH) after reaching total depth, as only traces of sand were detected during this part of the operation. With this information, the job procedure was optimized by increasing the horizontal section POOH speed from 6 m/min to 12 m/min, if sand was not detected at surface. It also prevented pumping gel pills. This represented a 10% reduction in the total operating time per well and a 25% reduction in xanthan gel consumption in the next completed pad.
This is the first time that a three-phase flowmeter has been implemented for post-fracturing cleanouts in Argentina Vaca Muerta operations. The increase in the precision of surface measurements means a more controlled cleanout strategy, during which flowback is evaluated in real time and the operational program can be optimized. Poor flowback control is a known contributing factor to stuck pipe incidents. This technology plays a critical role in addressing one of the major risks during CT operations.
Challenges and Solutions of Concentric Coiled Tubing Fishing
Authors: Rahimov K. , Nicol S. 
Published: March 2024

Abstract
Concentric coiled tubing technology has many applications for well intervention activities ranging from wellbore cleanout to well unloading and delivering multiple chemicals downhole via separate conduits. Technology historically developed for ultra low bottom hole pressure applications but currently utilization of it was expanded to wellbores with positive wellhead pressure. Concentric Coiled tubing string present similar risk and challenges as Conventional CT. Stuck in hole situation is one of the most notorious situations that requires very close attention and detailed contingency recovery planning. Unlike single pipe recovery where industry has very well-established guidelines and expertise, concentric pipe technology historically lacked both detailed planning and recovery experience. This paper details out the engineering design to address recovery of the CCT. Paper highlights stages requiring for the successful project delivery, step by step guideline and lists out purpose build equipment. Although proposed engineering solutions was not implemented due to the contingency nature, nevertheless careful approach and detailed engineering, risk assessment methods used in developing precise guidelines provides very good resource into existing industry challenge.
Successful Selective Fractures in a Horizontal Well Demonstrate the Effectiveness of an Abrasive Jetting and Stimulation Process in Mexico
Authors: Fontana Cristian , Menconi Federico , Medina Eber , Lugo Ramiro , Perez Raul 
Published: March 2024

Abstract
This study delves into the implementation of an integrated completion strategy for a horizontal infill well within a gas reservoir, with a primary focus on enhancing hydrocarbon recovery. The first lateral well in the field served as a testing ground for the combined utilization of Coiled Tubing (CT) and hydraulic fracturing services aimed at optimizing completion strategies and increasing adaptability in the presence of potentially drained zones along the horizontal section.
The 1.75-inch CT facilitated a rigless operation, with a calibration run ensuring tool passage through potential restrictions, leading to subsequent Abrasive Jetting (AJ) and hydraulic fracturing operations. Grounded in the well's established petrophysical and structural model, a thoughtful selection of depth facilitated the placement of a bridge plug, with Abrasive Jetting (AJ) establishing effective wellbore-reservoir communication. Diagnostic Fracture Injection Tests (DFIT) were then conducted iteratively to assess the interaction of the infill well with undrained areas.
The application of pinpoint stimulation technology demonstrated its capacity to induce fractures through a minimal number of holes, allowing for increased control over initiation sites and improved fracture height coverage. This approach enhances well productivity by increasing the fracture area in contact with the formation. Practicality and cost-effectiveness were validated using CT for various well-intervention procedures, complemented by Abrasive Jetting (AJ) assisted fracturing to minimize fracture entry friction.
The multi-stage operation revealed successful drainage of two zones during the intervention. The acquisition of reservoir data for simulation purposes was pivotal in shaping future field development plans and strategically placing additional lateral wells to optimize recovery factors.
To maximize hydrocarbon recovery and minimize costs, the AJ process and hydraulic fracturing techniques must be carefully optimized for economic feasibility. Reservoir simulations are employed to refine treatments for future projects, leveraging insights from pressure profiles and interactions with offset wells. The lessons learned from this well provide valuable insights for upcoming lateral infill wells, contributing to the continual improvement of execution methodologies.
This first infill well not only validated the hypothesis that reserves persist beyond the drainage radius of previous wells but also demonstrated a doubling of expected production levels. The success of this endeavor underscores the potential advancements in hydrocarbon recovery techniques, with implications extending beyond commercial interests to contribute to the broader understanding of reservoir dynamics and optimal well completion strategies.
Restoring Production Via Non-Rig Deployed Wireline Technology
Authors: Diwaku W. J. , Sambo H. , Sonhi J. M. , Saadi A. Ahmed , Wallach M. 
Published: March 2024

Abstract
Objectives/Scope: This paper details the challenges faced and the solutions deployed to restore production following failure of a formation isolation valve (FIV).
Methods, Procedures, Process: The FIV was installed to isolate the reservoir during the deployment of the Upper Completion. Once the wellhead, tree, and flowlines were hooked up, several attempts were made to open the valve to initiate production. Despite the planned pressure cycles being applied, the FIV did not open. It was suspected that there was fill/debris on top of the valve preventing its hydraulic activation. The failure of the FIV, and associated lost production, drove the team to develop a remedial intervention plan. The Operator and Business Partner team evaluated multiple alternatives before selecting a combined slickline and electric line tractor-deployed solution. The plan included a drift run to determine the wellbore condition above the FIV, followed by a cleanout run and the milling of the FIV Inconel ball-valve. Due to the high hole angle, a tractor was required to apply weight on the mill bit.
Results, Observations, Conclusions: After the removal of the wellbore debris using a slickline bailer and a suction tool deployed with electric line (EL), a tractor milling assembly was deployed that successfully milled through the FIV ball-valve. The successful milling operation saved approximately $30MM in Major Rig Work Over cost by bringing the well back to production levels in accordance with the pre-drill estimates.
Novel/Additive Information: This paper describes the process followed to design an optimal intervention plan, and the detailed planning and operational steps. The optimal engineered solution coupled with operational discipline during execution successfully brought the well back to production, minimizing the lost production cost while avoiding a costly rig-based intervention.
This paper also highlights the novel technologies utilized, the milling BHA configuration, specific lessons learned, and best practices recorded during the execution.
Conveying Extended Reach Solutions: First Coiled Tubing Perforation in Horizontal Live Gas Wells with Downhole Tractors
Authors: Tapia William R. , Delaune Julien , Villagrana Luis C. , Afsal A. M. , Stephens A. Abouganem , Borkin A. , French A. 
Published: March 2024

Abstract
A comprehensive study was conducted on the strategic utilization of coiled tubing (CT) to convey over 1,200 ft of perforating guns in single runs in extended reach wells, effectively overcoming the lockup effect in 7-in. monobore completion using downhole tractor and real-time monitoring tools. This solution serves as the key enabler for the project, reducing risks and maximizing operational efficiency.
CT reach simulations exposed the limitations in conveying long 2 7/8-in. perforating guns using 2 3/8-in. outside diameter (OD) CT strings to the lowermost intervals. The assessment highlighted the need for additional forces, achievable through hydraulic hammers or downhole tractors, or the options to convey the perforating guns with CT in multiple runs to perforate the lowermost intervals or to rely on conventional tubing-conveyed perforations (TCP) for the most challenging combination of interval length and well trajectory. After a comprehensive risk analysis, downhole tractors emerged as the preferred choice, being less intrusive and more reliable.
The main challenge was to design the bottomhole assembly to allow appropriate circulating parameters for the tractor activation without disrupting the hydraulic firing head activation. Fiber-optics-enabled CT strings facilitated real-time downhole data collection to meet all parameters. Collaborative efforts, meticulous planning, yard tests, and strategic arrangements demonstrated the operational feasibility, inspiring confidence in this technique.
The successful implementation of the CT downhole tractor proved transformative for the project by achieving the ability to perforate deeper and longer intervals without relying on conventional TCP. This resulted in significant cost savings by reducing rig time by at least 3 days per run and minimizing operational complexities. It also eliminated the need for an electromechanical plug setting between the TCP perforation and the completion stages and the removal of the plug prior to the CT stimulation of the perforated intervals.
Compared to TCP, the CT approach exhibited superior efficacy. The strategic implementation of downhole tractors serves as a prime example of innovation, enhancing operational efficiency while staying aligned with the project's vision.
Impact of foliar spray of zinc in nano form on lentil grown under residual fertility of preceding rice
Authors: NANDY POULOMI , Das Sanjib Kumar , Tarafdar Jagadish Chandra 
Published: March 2024

Abstract

Field trials were carried out during the rabi season of 2018-19 and 2019-20 to observe the combined impact of recommended fertilizer dose with or without nano zinc on lentils under residual soil status of preceding rice. The experiment was designed in split-plot with three replications holding sixteen treatment combinations viz. residual effect of eight treatments applied in rice as main plot factors and recommended dose of nutrients with and without nano zinc spray in lentil in two treatments as subplots factors. Experimental results revealed that better growth, yield associating traits and yield of lentil was found in the residual effect of integrated nutrient management treated plots with foliar application of nano zinc. Among the main plot factors residual effect of 50% RDN via synthetic fertilizer + 50% via FYM applied in preceding rice achieved the maximum seed yield and between the subplot factors significantly higher seed yield was obtained from recommended dose of nutrients with nano zinc spray in lentil which was increased by 11.11% than without nano zinc sprayed treatments.
Development and optimization of LSPR-based aptasensor for detection of Vibrio cholerae
Authors: Abolghasemi Zahra , Robatjazi Seyed Morteza , Zeinoddini Mehdi 
Published: March 2024

Abstract
Vibrio cholera was one of the major water-borne pathogens that can enter into the biofilm phase in a period of life; hence, it was challenging to recognize these bacteria. For this, we reported the development of a colorimetric aptasensor based on aptamer and gold nanoparticles (GNPs) for effective management and treatment of this disease. The aptamer sequence was selected according to previous work and amplified-based PCR and specific primers. Aptamer with high binding affinity to V.cholerae was firstly immobilized on the surface of GNPs, and detection was accomplished through aggregation of GNPs induced by target bacteria, which was associated with color changes of the reaction after addition of NaCl. To find an optimum condition, a specific approach based on a Taguchi orthogonal array was therefore used to evaluate critical parameters and to optimize them such as conjugation time, temperature, pH, and aptamer concentration. Analysis of signal-to-noise ratios revealed the great influence of temperature and pH on the conjugation of GNPs-aptamers. The optimum conditions for immobilization of aptamer were determined to be 9 for pH, 3 h for incubation time, 10˚C for incubation temperature, and 550nM for aptamer concentration. Under the optimum conditions, a linear calibration relationship was obtained between the ratio of A630/A524 and concentrations of V.cholerae over the range from 102 to 107CFU/mL. The detection limit and time were 6 CFU/mL and 80min, respectively. The developed colorimetric aptasensor is simple, convenient, and suitable for on-site detection of V.cholerae.