bluuebunny/crossref_metadata_2025_split huggingface dataset:
CO2 Injector Integrity: The Comparison of Semi-Analytical Solution with FE Analysis of Near Wellbore Thermo-Poro-Elasticity Couplings
Authors: Barsukova Antonina 
Published: October 2023

Abstract
Depleted gas reservoirs in the North Sea offer an interesting potential for CO2 storage because the geology is understood and the infrastructure is in place. One of the key issue is to check that the wells which have been producers during the life-time of the reservoirs can now be used safely for cold gas injection. This paper contributes to this question by providing a workflow to analyse the possible failure and debonding between the casing and the cement during the injection phase. A classical analytical solution based on thermo-poroelasticity is proposed, assuming a vertical well, an axisymmetric stress distribution, and either plane strain during gas production, or plane stress during injection. This simplified solution is compared with the predictions of a commercial 3D finite-element (FE) code applied to the near well regions. The application concerns a well in a reservoir, off-shore The Netherlands. The analytical solution, easy to develop, is found to be of great help in shedding light on the FE predictions, which involves detailed but complex process to arrive at the solution. The integrity analysis is performed after completion, at the end of depletion and during CO2 injection. The analytical solution predicts debonding at the casing-cement contact and shear failure hazards in the cement, which are not identified with the numerical tool. This paper provides valuable insights into the application of numerical and analytical solutions, pros and cons for both approaches are discussed considering computation cost and setting up of the model.
Flexible Pipelines Risk Based Integrity Management Planning
Authors: Shahrustami M. Nadzeri M. , Anuar Karim Khairul , Hayati Hussien , Aishah Ali Noor Razak Siti , Anwar A. Samad Khairul , Firmann Nik Zulkefli Nik M. , Zahrin Zain , Salwanie Zakaria Nor 
Published: October 2023

Abstract
This paper shares on recent effort in PETRONAS on standardization of risk model and risk-based integrity management planning for its flexible pipeline assets. A semi quantitative approach is adopted in determining the likelihood of failure by using set of descriptors, coupled with the company standard consequence of failure descriptors to define risk of each threat and damage mechanisms. Screening of credible threats involves understanding on the function and impact of each to flexible pipelines components and compared against failure statistics and experiences in industry. Then, a guideline on the Integrity Management Plan (IMP) was established based on the risk rating i.e. High, Medium and Low, underlining respective inspection, monitoring and maintenance activities required to reduce and control the risk to As Low As Reasonable Practicable (ALARP). The result of this standardization effort on the risk model for flexible pipelines, the company easily can determine its flexible pipeline risk timely.
Meanwhile, with the IMP would enable the company to strategize and prioritize its resources to focus particularly to its high risk, thus high consequences flexible pipeline assets. In previous practice, each pipeline will be assessed based on engineering judgement through an exercise participated by various experts. While sometimes these criteria are not standardized from one pipeline to another, this exercise normally would take several days and sessions to complete due to the fact of lengthy review and challenge session to arrive to consensus on the final risk and its integrity management plan of each of its pipeline. Flexible pipelines integrity management is still considered new to the industry. This type of asset, originally installed on marginal fields with short lived economic life with very less or no maintenance at all. Nevertheless, most of these assets also have been operated beyond its design life as operators are continuously cutting down its production cost. Due to this, a robust integrity management system is required. It is imperative that with understanding on risk as well as exploring ways to maintain this kind of asset is becoming increasingly vital to balance between the risk of failure and cost to operate.
World Longest 7 in Single Trip for Multizones High Rate Water Pack Enhances Completion Strategy in Offshore Indonesia
Authors: Tokoh K. W. , Jatikusuma R. , Manalu D. N. , Yudis P. , Li C. 
Published: October 2023

Abstract
Multizones Single Trip Gravel Pack (MZ-STGP) completion has been mainly utilized in Mahakam field in Indonesia since 2012 to present. The system has been used as a sand control solution for its cost efficiency, the ability to complete multiple pay zones in a single trip and to provide zonal isolation for production selectivity for typical unconsolidated sands, poor sorting, and uniformity coefficient as well as very high fine content. The cost escalates when this requirement happens for multiple zones that may require multi run which needs longer rig time.
As of now, few of completions used to utilize the 9 5/8" system that normally require large bore and pumping more volume of fluid injected to deliver gravel pack slurry into wellbore. Meanwhile as part of drilling and completion cost efficiency, slimmer well architecture and completion system installation has driven by the needs for of a smaller borehole under various scenarios such as cases where 9 5/8" casing cannot reach planned depth and unlock additional reserves deeper below 9 5/8" casing shoe associated with well cost optimization for marginal gas wells at Mahakam.
This paper reviews on successful execution of 7″ Multizones Single String Gravel Pack system deployment, high rate water pack design, lessons learnt and required mitigation on the system itself while ideal deliver gravel pack slurry have to be in place properly at downhole. Further optimization is the Multizones Single String Gravel Pack system developed to unlock more potential sandy reservoir drilled with multi zones gravel placement treatment in order to reduce the rig time and preserve smaller 7in multizones single trip system by extended top bottom assembly to 445 m and service pipe length up to 425 m as world longest 7" MZ-STGP system to achieve optimum well cost economically.
Overview of Multi-Stage Fracturing Using Fiber Enabled Coiled Tubing Plug and Perf Method: First Deployment in Indonesia
Authors: Yudhanto G. , Asrul F. , Ultra D. , Saib E. F. , Aprilianto E. , Hidayat S. N. , Pramadana A. , Akbari A. , Hermawan F. A. , Agatha S. A. , Jenie J. , Gani E. E. 
Published: October 2023

Abstract
KS-HZ, onshore producer well, is the first horizontal well of one of operators in Sumatera, Indonesia. The well has been drilled since early 2020 but suspended due to drilling problems. The operator then decided to side-track drill and complete the well with multistage hydraulic fracturing. This project is planned to unlock oil potential from Telisa Formation (less than 3 mD permeability) and boost production performance. Transverse multistage hydraulic fracturing technique is widely used to enhance production from low to medium permeability formation, but it can be quite a challenge when applied to thin T formations (40 feet of thickness) that have soft and shaly sandstone properties. In this well, without adequate completion technology approach and over flushing the proppant in each single stage will have negative impact on production performance.
This paper will describe consideration of multistage fracturing design, a technology approach that used in the completion execution, and efficiency improvement. This includes coiled tubing (CT) and fracturing operations that covers: CT memory logging, CT wellbore clean up, stage optimization, stage spacing, CT abrasive jetting perforation, hydraulic fracturing, CT milling, and CT clean-out. In addition, the utilization of fiber optic enabled CT with pressure, temperature, tension and compression, and gamma ray modules enables operator to monitor real-time downhole parameter for accurate perforation depth placement within the small gap window. It will also help to calibrate frac design on each stage from the advantage of live downhole pressure monitoring during Diagnostic Fracture Injection Test (DFIT) analysis. CT abrasive jetting perforation was also selected to maximize reservoir contact and to reduces near-wellbore friction that minimize the possibility of proppant screen out.
A total of 7 stages of propped hydraulic fracturing method has been successfully placed without any placement failure. Approximately 881,000 lbs of proppant pumped into the Telisa Formation.
As a final point, this first deployment of multistage hydraulic fracturing with fiber optic enabled Coiled Tubing is proven to be unique solution to help the operator to gain additional production from challenging Telisa formation. This success elevates operator's confidence for future project and becomes golden experience for the nation to develop future multistage fracturing in same Telisa Formation across Sumatera Island.
Highly Thixotropic Engineered Cement Solution Helps Overcome Lost Circulation While Drilling Deepwater Exploration Well
Authors: Velasco A. , Segouffin J. , Duarte B. , Simental S. , Rowe M. , Major J. , Toranzo G. E. , Garcia S. 
Published: October 2023

Abstract
Loss of circulation while drilling can significantly increase the cost of drilling a well section. A lost circulation decision tree with robust and proven solutions is a tool that enables operators to address the risks and benefits of the treatments available. This paper describes the use of an engineered cement solution to solve an unexpected total loss of circulation situation without retrieving the drilling bottomhole assembly while allowing well operations to continue, during a deepwater exploration campaign in Mexico.
The highly thixotropic engineered cement (HTEC) systems are lightweight portland cement slurries tailored to exhibit low viscosity when shear stress is applied and develop gel strength rapidly as shear is removed. This enables the systems to penetrate formation fractures where rapid gelation occurs, after which the development of compressive strength delivers a hydraulic seal. A pre-drill risk assessment of lost circulation was built, and a lost-circulation decision tree was developed to have LCM solutions readily available, due to the logistics constraints of work in deepwater. An unexpected loss of circulation event occurred in the 12-1/4" hole section, the decision tree called first for an LCM treatment which was unsuccessful, maintaining losses of 500 bbl/h.
The HTEC system was pumped through the bottom hole assembly (BHA) and placed at the thief zone via a bullhead squeeze. A conventional cement spacer was used to separate the interfaces. The treatment was spotted at the thief zone and allowed to develop compressive strength for 7 hours, then tagged with the drill bit. The rig was able to break circulation with a rate of 2.4 bpm without recording any further losses.
The use of HTEC systems when other LCM systems have had no success, helps reduce drilling fluid cost and rig expenses when correctly engineered. Often a single treatment results in total control of the losses.
A Custom-Fit Approach for Temporary Well Suspension Saves Remedial Stimulation and Well Activation in North Kuwait
Authors: Bastaki Fahad Mahmoud , AlMatar Mohammed Ahmad Mohammed , Al-Bahar Zakaria , Chong Mizan BinOmar , Barki Jassim Hamed , Jamal Mariam , Al-Mehena Mehanna , Slama Mohamed Hedi , Badrawy Kareem , Molero Nestor , Sunagatov Rustem , Sebaih Mohannad Adel 
Published: October 2023

Abstract
Following the rig-based well testing stage, completion programs of high-pressure wells in North Kuwait call for well killing with heavy oil-based mud (OBM). The workover rig is then demobilized, and production flowlines are installed. Well activation plans are carried out riglessly, and coiled tubing (CT) is instrumental to bringing the wells back to sustainable production. One of the major drawbacks from this practice is the formation damage generated by the OBM, which often requires additional interventions for remediation.
To address this limitation, a new approach leveraging instrumented CT for temporary well suspension was recently implemented. Real-time downhole telemetry is enabled by an optical line installed in the CT pipe and used to accurately set a through-tubing inflatable packer (TTIP). Once the latter is anchored at the planned depth, above the interval open to the formation, CT is disconnected from the packer assembly, and the fishing neck is protected with a sand plug. CT is then retrieved to surface, and a slickline dump bailer is run to spot cement on top of the sand plug. Once the cement has set, CT is run to displace the wellbore to kill fluid.
Two pilot wells were selected to implement this new approach for temporary well suspension. Both wells had a maximum potential wellhead pressure in the order of 7,400 psi, and 15.0-ppg OBM was originally planned for well suspension purposes. Upon completion of the zonal testing program - which included initial stimulation, well activation, and flowback - instrumented CT was run with high-pressure rotary jetting to condition the TTIP setting depth and displace the wellbore with brine, after which, a shut-in wellhead pressure near 2,000 psi was observed. In the next CT run, TTIP was set close to the end of the production tubing, and critical stages, such as depth correlation, packer inflation, and packer anchoring testing were closely controlled via real-time downhole measurements. Additional verification of the TTIP effective seal was carried out before the CT was disconnected from the packer assembly through an inflow test relying on live downhole pressure monitoring. Once the TTIP released, the temporary suspension was completed following the methodology described above. Finally, the wells were observed at surface with zero pressure for more than 24 hours, receiving acceptance from the operator.
This alternative approach for temporary well suspension represents an innovative solution to bring wells back into production without additional restimulation or well activation. This methodology greatly relies on CT real-time downhole telemetry, and operators from the Middle East can benefit from the experience gained in this project.
Machine Learning Assisted Cement Integrity Evaluation During Plugging and Abandonment Operations
Authors: Camerini I. G. , Ferreira G. R. B. , de Souza L. P. B. , Hidalgo J. A. S. , Correia Tiago M. , Rodrigues A. S. , Batista J. H. G. 
Published: October 2023

Summary
Due to the growth of Plugging and Abandonment operations, the challenges of assessing the integrity of the cement layer and the quality of its bond to the casing and formation increase consequentially. Hence, it is paramount to ensure that the wellbore is hydraulically isolated from the surrounding environment before permanently sealing the well. However, nowadays, this process depends on the skills of a specialist interpreting a vast amount of complex data acquired through logging operations, which turns the task human-dependent, error-prone, and time-consuming. Motivated by that cement evaluation task, ouronova, in partnership with Repsol Sinopec Brazil, is developing a computational tool to interactively assist the specialist in interpreting cement integrity logging data and the operator in optimizing the planning and management of Plugging and Abandonment campaigns. The so-called P&A Assistant software uses machine learning techniques that, through the work done so far, have shown to be a promising alternative to improve the accuracy and reliability and reduce the time of the cement sheath integrity analysis. The software is also prepared to work with logging data acquired in a through-tubing configuration, which represents a reduction in operational cost and time. The paper presents the software's initial module, presenting three different unsupervised methods (K-means, Bisecting K-means, and Gaussian Mixture Model) and input feature combinations, with the aim of optimizing the model. The main results of the work indicate that the methods implemented using the Cement Bond Long channel and Bond Index channel have better results when compared to the models combined with Variable Density Log and AIBK, with values above 0.7 for Rand Index and 0.5 for Silhouette Coefficient. For the unsupervised methods, the K-mean model had the best performance.
Improvement of Thru Tubing Gravel Pack Placement Techniques Enhancing Gas Potential for Offshore Fields
Authors: Choodesh A. , Chantarataneewat W. , Peerakham C. , Piyakunkiat N. 
Published: October 2023

Abstract
Sand production is naturally occurred in Miocene-Pliocene clastic reservoirs. To develop the well throughout the years of field experiences, sand production management during the very early and late stages of well life, as a result of depletion of reservoir pressure has brought up many challenges, especially in terms of field potential sustaining, well productivity and investment justification.
Thru-tubing gravel pack (TTGP) is one of the options considered for sand control remedy. Placing gravel into the annulus of tubing-screen and tubing- blank section which similar principle as circulation gravel pack and can be deployed in various methods using wireline, coiled tubing, or bull heading without the need for workover or rig operations. Based on field experience, the coiled tubing considers more efficient method for thru tubing gravel pack compared to wireline conveyance, i.e., using a dump bailer. But the drawback of conventional thru tubing gravel pack (TTGP) is the high skin value because the gravel only fill up in the annular section as above mentioning. Perforation damage still generate additional skin, smaller ID of the screen, finally end up with shorter well life expected.
The most effective placement techniques are by squeezing the gravel to pack in the perforation and possible void space in the reservoir with the coiled tubing. It has been proven method for minimizing the production of sand-fines, reducing perforation damage, and prolonging well life. But the successful squeezing the gravel to pack in the perforation and possible void space in the reservoir via coiled tubing the challenge operation, especially on 3-1/2" Monobore completion with 1.5" OD of coiled tubing. The improvement of the through-tubing gravel pack pumping technique, which focuses on improving gravel placement, addresses a problem that needs a solution with utilizing the existing equipment and services. To overcome this limitation, a concept of combining the gravel placement in both coiled tubing and annulus has been innovated, studied and evaluated to eliminate the problem of limited gravel placement.
This improvement of thru tubing gravel pack placement technique has been applied field where sand production is expected from both virgin formations and existing depleted zones. The gas potential gain from all implemented wells (11 wells) has observed at 62 MMSCFD at Maximum Allowable Sand Rate (MASR).
Machine Learning Assisted Fracture Network Characterization of A Naturally Fractured Reservoir Using Seismic Attributes
Authors: Ray A. K. , Dandapani R. , Devulapalli S. , Biswal S. 
Published: October 2023

Summary
Characterizing the naturally fractured unconventional reservoirs is challenging because of the reservoir complexity and heterogeneity. Delineating Fault-fracture networks through seismically derived discontinuity attributes is an effective way to characterize these fractured reservoirs. As there are multiple discontinuity attributes containing meaningful information about the fault-fracture networks, it is important to integrate these attributes using a sophisticated machine learning technique for enhanced delineation of these fault-fracture networks. Self-Organizing Map (SOM), the latest and robust unsupervised classification technique, can extract the integrated information of these anomalous features from multiple seismic attributes.
Automated clustering algorithms fall into two categories – supervised and unsupervised algorithms. Unsupervised machine learning algorithms are purely data-driven and help in recognizing and classifying the patterns from a dataset without any prior information. Posteriori information such as well data, is integrated into the results for recognizing the facies classification and calibrating the interpretation. Unsupervised learning methods also help to highlight subtle stratigraphic features that might otherwise be unnoticed using conventional analytical methods.
In this study, we adopted a recent unsupervised classification technique called SOM. The technique has been applied successfully to a naturally fractured reservoir in an Onland field, in India. The objective of the study was to extract the subtle faults and fracture network information from the seismic-based attributes in order to characterize the naturally fractured reservoir. By use of the relevant seismic discontinuity attributes and application of the advanced SOM technique using optimum parameters set, subtle faults/fracture corridors could be mapped effectively using the SOM results. SOM Principal Axis derived from this technique, was a valuable attribute in characterizing the naturally fractured reservoir. This attribute was also a useful input during the Discrete Fracture Network (DFN) modeling stage, in guiding the natural fracture network propagation.
Smart-Drive Navigation & Emergency Response Solution
Authors: Almasri H. J. , Al-Hosany A. J. , Al Habshi M. H. , Khalil B. M. 
Published: October 2023

Abstract
The Smart-Drive Navigation & Emergency Response Solution represents a cutting-edge, customized solution developed internally by our COMPANY's IT and GIS teams. Leveraging the Esri GIS technology suite, including ArcMap Pro, Navigator, Tracker, and Field worker, this solution harnesses the power of advanced sophisticated algorithms to optimize multi-destination routing and conduct advanced routing analysis.
These algorithms consider many parameters, including average speed limits, hazard zones, road conditions, closure times, fenced roads, private roads, vehicle types, user classifications, obstacles, and access locations.
This remarkable solution has emerged as a pivotal tool for optimizing field operations, maximizing resource distribution, enhancing field teams’ mobility, mitigating driving risks, reducing commuting time, and improving emergency response times. In addition to minimizing costs and saving valuable time, it significantly enhances overall Health, Safety, and Environment (HSE) performance and operational efficiency.
Within this manuscript, we delve into the challenges that were overcome, the innovative solutions implemented, the notable features of the system, and the extensive benefits it provides. Furthermore, we explore the promising prospects that lie ahead for this remarkable system.