bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pinocchio Tool as an Innovative Approach of Reactivating Idle Wells With Partially-Open SCSSV Flapper
Authors: Abdillah Mohammad Izzatul Akmal , Ho Yap Yin , Dasan Larissa Manyie , Leong Chua Hing , Mokhtar Mohd Khaidir Bin Mohd , Xiong Choi Yee 
Published: August 2024

Abstract
The Pinocchio Tool is an innovative quick fix in reactivation of idle wells with partially open TR-SCSSV flapper, specifically for cases where the flapper is unable to be opened due to unidentified hindrance accumulating behind the flapper. The Pinocchio Tool methodology has been proven to be a success from a recently completed idle well reactivation campaign.
The Pinocchio Tool was an idea that stemmed out from a problematic well with TR-SCSSV issue whereby the flapper was unable to be operated due to two-way leak in its control line, and further diagnosis indicated that the flapper was only partially opened due to mechanical hindrance behind the flapper. Cycling tests and lock open had been attempted to no success. Prior to resorting to large-scale solutions such as CTU/Eline milling, the team came up with the Pinocchio Tool - a steel device that mechanically pushes down and holds open the flapper, allowing hydrocarbon from the well to flow through. The design of the tool consists of a thin prong extending from a larger-OD body made up of four hollow sections. The prong pushes and holds open the flapper down, while the upper body connects to an installation extension (of matching design as the existing upper completion) and set with a standard lock mandrel. Well barrier, at the absence of a SCSSV, is then established with a nipple-less storm choke.
Upon installation of the Pinocchio Tool, the well was able to flow as per desired parameter. This has proven the tool to be a reliable temporary fix for wells with similar problems while detailed plannings can be done for the more resource-heavy solutions such as CTU, e-line or workover, preventing prolonged close-in of the affected wells - safeguarding both process safety and business needs.
The Pinocchio Tool is the first in the world of its kind - an effective simple solution which only requires minimal fabrication and deployment via slickline.
Contractor Ownership of MPD Systems to Increase Availability and Use of MPD Methods
Authors: Johnson A. , Fraczek J. 
Published: August 2024

Abstract

Objectives/Scope
The goal of this paper is to provide a detailed analysis of factors affecting the permanent integration of managed pressure drilling (MPD) on jackup rigs. This paper highlights approaches that have eliminated or reduced barriers to adoption and improved the availability and use of MPD methods in deepwater and jackup drilling operations.

Methods, Procedures, Process
This paper assesses a variety of factors affecting the permanent adoption of MPD on jackup rigs. The paper begins with an overview of MPD adoption offshore in shallow and deepwater environments. Factors impacting the decision to permanently install MPD on deepwater versus jackup rigs are discussed. The focus of the paper then shifts to the factors affecting utilization of MPD including user mindsets regarding when and how to apply MPD. Finally, solutions to remove the barriers to MPD use are discussed, particularly relating to crew competencies, equipment readiness, and retention of best practices.

Results, Observations, Conclusions
Early on, the availability of MPD services allowed operators to reach through extremely narrow drilling windows to targets that would not otherwise be technically or economically feasible. Today, MPD has grown beyond the initial foothold and is increasingly used to improve drilling performance even in less challenging well sections. In deepwater, several wells have been drilled using MPD to avoid contingencies in applications where the drilling window does not necessarily require MPD. In other deepwater wells, ready availability has enabled operators to reach difficult targets by turning on the MPD system even on a very short-term basis. A shift toward contractor ownership of MPD systems has made many of these cases possible, but this trend has been slower to develop in the jackup segment. There, key constraints must be addressed such as aligning competencies between MPD and rig crews, retaining best practices, ensuring a favorable balance of tradeoffs, and enabling a greater degree of equipment utilization for non-MPD applications. Early results with contractor-owned MPD systems show permanently integrated MPD is possible in the jackup segment and that contractors enhance the overall MPD service when given the right tools and know-how.

Novel/Additive Information
Mindsets around MPD are a key factor affecting permanent integration. Attitudes on utilization represent one facet of a mindset. Some MPD users may use it often, while others use it only in certain cases. These may be described on a spectrum as high-utilization and low-utilization mindsets. Both are MPD promoters in different ways. Mindsets may shift with new technology, moving a user from one mindset to another.
Non-Explosive Tubing Puncher for Well Plug and Abandonment Operation
Authors: Panoot S. , Marut D. 
Published: August 2024

Abstract
This paper details the inaugural implementation of a novel non-explosive tubing puncher in well plug and abandonment (P&A) operations in Thailand, marking a significant evolution in operational safety by circumventing the use of explosives. The industry's historical reliance on non-explosive punchers, while reducing explosive risks, faced limitations in efficiency, flow area capabilities, and need the electric line units. Addressing these constraints, the new technology puncher integrates a hydraulic press system with electronic control powered by an alkaline battery, enabling slickline operations and negating the need for electric lines.
The tool's multi-punch head design introduces unparalleled flexibility, allowing for the adjustment of the flow area and punch hole phasing. This precision is achieved through an activated battery triggered by slickline motion, initiating the puncher's function and ensuring completion within a predefined timeline. Operational risk and the necessity for stringent personal zone management are drastically reduced, streamlining the P&A process. The non-explosive puncher requires approximately 40 minutes at punch depth, with reduced surface preparation time, offering a competitive overall operation duration compared to traditional methods.
Notably, the cement pumping operations through six of 0.5-inch punch holes align with the flow area specifications of explosive punchers, maintaining standard pumping rates and pressures across variable well depths. The barrier integrity, rigorously tested, met industry standards throughout the trials.
The introduction of this advanced non-explosive puncher signifies a breakthrough in safety and operational efficiency. It enhances personnel safety by facilitating offline tubing punch activities, thereby simplifying the P&A process. This innovative approach not only reduces operational risks but also represents a paradigm shift in well abandonment methodology, contributing significantly to the body of knowledge in P&A operations.
Novel Downhole Annular Barrier Solution for Water Shut Off – Kuwait Case Study
Authors: Koch Jonathan , Al-Gharib Majed , Al-Ajmi Ali , Olsen Jonathan Eugen , Leiknes Tom-Morten , Al-Harbi Majed 
Published: August 2024

Abstract
Globally, significant numbers of wells are impaired by poor cement quality in well annuli leading to inadequate sealing of zones and reduced well integrity. Subsequent undesired flow in well annuli such as from connected water sources can result in both significant "locked in" production potential and environmental risk. Downhole Annular Barrier (DAB) (or Downhole Annular Repair (DAR)) systems can be employed via well intervention to correct integrity and conformance control issues and extend the productive life of wells in a safe and cost-effective manner. New and emergent DAB technologies can provide novel solutions to difficult well annuli problems, where traditional remediation solutions such as annular remedial cementing would not be appropriate, efficient, or otherwise have a low chance of success.
This paper will review the planning and successful execution of one such novel DAB intervention by Kuwait Oil Company (KOC) for Water Shut Off (WSO) in an onshore conventional oil well. The intervention objective was isolation of the poorly cemented casing / wellbore annulus to prevent, or significantly reduce, water flow due to OWC (Oil Water Contact) rising across the open production perforations. WSO was successfully achieved utilizing the pinpoint injected resin technology. This technology entailed injecting epoxy resin into the annular space at desired isolation depth, forming a 360-degree pressure barrier. This was world's first application of the service company product technology (CS) for WSO in a sandstone oil well.
Novel Cementing Technology for Deep Water Development Wells in South China Sea
Authors: Zhang H. , Cui C. , Feng Y. T. , Qi Y. , Li Y. , Wang Y. W. , Wen D. Y. , Zhang F. M. , Tian J. , Huang F. , Feng Q. H. , Chen Z. M. , Tang Y. T. , Zhao J. , Zhao H. , Xiao W. , Yu B. , Fang E. L. , Dai D. 
Published: August 2024

Abstract
In South China Sea Block X, a deep water promising gas reservoir more than 100 billion m3 was discovered. Unlike onshore or shallow water wells, cementing operations in deep water development wells face tougher challenges. Low temperature and shallow hazards limit conventional cement slurries, especially when these issues coexist. Besides, temperature prediction and oil-based mud (OBM) removal also add to the complexity of the cementing operations. A novel cementing technology for deep water development wells has been developed in order to ensure long-term isolation. This paper will describe in detail how to design the cement slurry parameters, how to apply the hydrate decomposition simulation, how to predict the temperature and how to remove the OBM. With the novel technology, cementing operations in Block X have been successfully carried out for 11 wells, achieving the desired objective of well bore integrity. Cement bond logging (CBL) evaluation has shown excellent bonding result. This successful cement operation helped to establish record for the biggest deep water gas field in South China Sea.
Innovative Placement for Epoxy Sealant to Cure Casing Sustained Annulus Pressure – Implementation in Gulf Area.
Authors: Zhukin A. , Al Dahmani S. , Yugay A. , Tawfik F. G. , Alkarbi M. , Olsen J. E. 
Published: August 2024

Abstract
More than 30% of the wells worldwide are reported to have unplanned Sustained Casing Pressure (SCP) / Sustained Annulus Pressure (SAP) based on recent data1. The issue greatly impacts production methods of field development with subsequently large impact on well expenditure. Several techniques are available to repair SCP/SAP however, they are mostly limited by rate of circulation and injectivity during squeezing and placing cementitious material behind casing. The objective of this paper is to demonstrate and share experience gained in the Gulf region to apply innovative placement methods of an alternative material (epoxy) for well repair of SAP in cases of no injectivity to cure fluid migration behind casing.
The most common and widely used practice to cure SAP/SCP behind casing is conventional casing milling and / or perforation with subsequent cement lock-up squeeze with subsequent pumping cementitious material from surface to the annulus. Unfortunately, this practice has a low success rate. Circulation cementing squeeze is not practical in many cases since we conduct primary cement job with cement to the surface and in many cases conduct subsequent "top up" job. There is an advanced solution using PWC-Perforate, Wash and Cement with special tool, that delivers reliable results, however it requires to have interval with poor cement isolation. The proposed advanced Downhole Annular Repair method has been utilized in the Gulf region country to cure sustained annulus pressure behind production casing. The method allows a single wireline run to accomplish successful SAP curing with following major steps: Positioning/anchoring tool at desired depth; gain access behind casing via a set of radial perforations and placement of epoxy resin using internal pump in the hesitation injection over the extended period of time.
The 4 wells have been treated using the innovative placement and alternative material to cure SAP behind production casing. Sealant has been injected using hesitation mode for a period of 10-20 hrs until initial setting time is reached. Well commissioning results demonstrated successful SAP treatment on 4 wells.
Revolutionary Pre-Set Well Design: Removing an Entire Section, Speeding Up Well Delivery by Six Days
Authors: Agarwal Rohit , Essmat Nooruldeen Zeyad , Paz Daniel , Alismail Ahmed , Lopez Gustavo , Diaz Leonardo , Levario Jesus Alvidrez , Corona Mauricio 
Published: August 2024

Abstract
The conventional pre-set well design involves landing the well at high inclination (50 – 60 degree) on top of the reservoir using six (6) casing policy followed by drilling of multi-laterals across the reservoir using under-balance coiled tubing drilling (UBCTD). A novel well design is presented in this paper which eliminates one complete casing string without compromising the well's objectives. The 8-3/8-in. hole section is drilled across a highly charged formation and secured with a 7-in. liner. Consequently, a 5-7/8-in. section is then drilled and landed on top of reservoir. The well is later completed using 4-1/2-in. cemented liner, which is mandatory as per well requirement. In this paper, the critical design criteria are explored while combining these two (2) sections, considering well control requirements, and cementing methodologies to ensure proper separation of highly charged layers from the reservoir.
This optimization has resulted in a time saving of six (6) days which enabled the well under study to set a record as the fastest well delivered in this category. This concept has been adopted in consecutive wells and is emerging as a new standard for the specific type of well.
By combining the last two (2) sections in a single hole size, the time for running the 7-in. liner, 5-7/8-in. cleanout trip and drilling the short 5-7/8-in. hole is saved which results in a direct time savings for the operation. The paper details how the last section was drilled as an 8-3/8-in. hole and cased off with 7-in. × 4-1/2-in. liner tapered string using fit for purpose centralizers. Furthermore, to ensure the integrity of this solution, a clean-out bottom hole assembly (BHA) combined with inflow test assembly was run in hole and the shoe track was drilled till 20ft above shoe simultaneously. The integrity of cement job and liner top packer was validated by performing inflow test. The well is then completed with upper completions, production tree installed and well is temporary abandoned where the Coil Tubing Drilling (CTD) rig will come later in future to drill the remaining cement in shoe track and reservoir.
The optimized well design explores the design criteria for combining of two (2) sections and presents a novel solution to explore such possibilities in other well designs.
Unprecedented Design and Deployment of Advanced Lower Completions in an Extremely Challenging Environment in the Middle East
Authors: AlHosni F. , AlRomaihi A. , Arias M. , AbdulRahim S. , Uslu M. , Yasari A. , Rojas L. , Handoko L. , Centeno M. 
Published: August 2024

Abstract
Deploying advanced lower completion in long lateral big bore carbonates sections in one of the Middle East giant fields has presented a considerable challenge due to various factors such as well designs, extreme hole conditions, high friction factors, risk of getting stuck, severe loss circulation, to a premature setting of packers. This manuscript outlines the innovative initiatives and solutions that resulted in a pathbreaking deployment of a complex lower completions assembly in the subject field.
On offset wells, several complications were encountered in running big bore Limited Entry Liner (LEL) with inner string to the setting depth due to high friction factors, hanger capacity limitations, lost circulation, and packers’ restrictions, which increased the complexity and led to long non-productive times (NPT). During the drilling phase, initiatives were taken to optimize the connection practices, conditioning the wellbore, and devise an effective fluids displacement strategy. Pioneering solutions were developed and implemented with the LEL hanger system and liner centralization and deployed with engineered reservoir-friendly completion fluids having remarkably reduced friction factors.
To deploy the advanced lower completions safely without encountering issues, as seen in the offset wells, several new engineered solutions were introduced on the subject well through a multi-level risk assessment to identify all the risks and hazards involved during the execution and eliminate or mitigate them in the backdrop of a thorough analysis of the offset wells. The change in connection practices and wellbore conditioning while drilling ensured a smooth lateral section to run in the hole lower completions. Innovative modifications were made to the liner hanger system allowed the removal of a dedicated inner displacement string. Further, the friction factors were still high. With the risk of getting stuck and lost circulation, the low friction factor, displacement, and loss control strategies of the reservoir-friendly completions fluid with improved centralization of the lower completions assembly not only eliminated the sticking tendency but also eliminated the need for friction reduction tools, leading to a safe deployment of the advanced lower completions with swellable packers, successfully meeting the early production objectives in a record time compared to previous similar jobs performed.
This paper covers the existing gap in knowledge related to the deployment of advanced lower completions assembly in challenging downhole conditions and complex well design that led to making the pavement for all upcoming similar applications in the subject field. The solutions and lessons learned presented in this study have the potential for global replication, offering valuable guidance for similar projects worldwide.
Chronic gut inflammation differentially modulates mitochondrial and antioxidant transcriptional programs in limbic brain structures
Authors: MATISZ Chelsea E , LAPOINTE Valerie , BEEKMAN Kaylen , HAIGHT Travis , SUTHERLAND Robert J , ZOVOILIS Athanasios , GRUBER Aaron J 
Published: August 2024

Abstract

Chronic inflammatory diseases are frequently comorbid with depression and anxiety, often persisting during periods of inflammatory remission. This suggests functional changes to neural circuits involved in the contextual regulation of motivation and threat processing. Here, we test how chronic gut inflammation evoked by dextran sodium sulfate (DSS) affects gene expression in several limbic brain structures associated with these functions. We assessed post-mortem expression of mRNA transcripts in the anterior cingulate cortex (ACC), CA1 hippocampus, nucleus accumbens (NAc), and primary motor cortex (M1) as a non-limbic control. The levels of mRNA associated with mitochondrial function, inflammation, and synaptic connectivity were altered in DSS-treated animals, but the specific pattern of changes was heterogeneous among brain structures. Chronic gut inflammation affected transcript expression in the CA1 and NAc more so than in the ACC and M1. These differences involved genes related to antioxidant systems and mitochondrial function. For example, expression of the cytochrome oxidase 1 gene mt-co1, which is necessary for oxidative phosphorylation, was reduced in ACC and NAc of DSS animals, suggesting reduced capacity for ATP production in these regions. Markers of gut inflammation correlated with expression of several transcripts in the ACC, including markers of synapses and GABA synthesis. The NAc showed strong correlations of mitochondrial function and measures of mitochondrial fission, inflammation, synaptic connectivity, and GABA synthesis. In sum, these data indicate neuroinflammatory processes in the brain evoked by chronic relapsing gut inflammation are heterogeneous among brain structures, and possess complex relationships between mitochondrial function, antioxidants, neurotransmission and gut inflammation.
Event-based mapping and spatial pattern analysis of landslides in parts of central Vietnam
Authors: Das Raja , Wegmann Karl William , Tien Pham Van 
Published: August 2024

Abstract

Systematic inventorying after large triggering events is essential for understanding the spatio-temporal dynamics of landslides and enabling advanced predictive analysis. The landslide inventories triggered by typhoon Ketsana, tropical storm Podul, and typhoonMolave in the highlands of central Vietnam are presented to better understand the spatial interaction (i.e., clustering, dispersion, or independence) among these landslide events using a global clustering indicator Ripley’s K. A total of 8,744, 915, and 10,257 landslides were mapped and attributed to typhoons Ketsana, Podul, and Molave, respectively, utilizing high-resolution RapidEye (5m/px) and PlanetScope (3m/px) satellite imagery. The inhomogeneous Ripley’s K and cross K-functions were employed for intra-inventory and inter-inventory landslide distribution analyses to assess the clustering, dispersion, or randomness of landslide occurrences at various distances. The findings reveal pronounced clustering among landslides triggered by typhoons Ketsana and Molave. In contrast, tropical storm Podul caused landslide clustering up to 22.5 km, after which a strong aversion was observed. Interactions between landslides from the Ketsana and Molave inventories exhibited clustering within the 0–8.1 km range and repulsion beyond 8.6 km. Conversely, landslides from the Ketsana and Podul events displayed repulsion at all distances, indicating the absence of clustering. Subsequently, a Spatial Kolmogorov-Smirnov test was conducted on seven continuous covariates—elevation, topographic slope, topographic aspect, Topographic Position Index, drainage density, annual average rainfall, and distance from mapped geologic faults. A Chi-square test was applied to lithology as a categorical covariate. These analyses aimed to evaluate the spatial independence of landslide distribution concerning these covariates. A statistically significant p-value in these tests indicated a non-random spatial association between landslide occurrences and the covariates, signifying spatial dependency among them.
Multi-target quantum compilation algorithm
Authors: Binho Le , Hai Vu Tuan , Viet Nguyen Tan , Urbaneja Jesus , Linh Nguyen Vu , Lan Tran Nguyen 
Published: August 2024

Abstract

In quantum computing, quantum compilation transforms a target unitary into a trainable unitary represented by a quantum circuit. Traditional quantum compilation optimizes circuits for a single target. However, many quantum systems require simultaneous optimization of multiple targets. To address this, we developed a multi-target quantum compilation algorithm to enhance the performance and flexibility of simulating multiple quantum systems. Our benchmarks and case studies demonstrate the algorithm’s effectiveness, highlighting the significance of multi-target optimization in advancing quantum computing. This work establishes the foundation for further development and evaluation of multi-target quantum compilation algorithms.