bluuebunny/crossref_metadata_2025_split huggingface dataset:
Performance of Bonded Bead Sand Screen as Remedial Sand Control in Highly Erosive Environment
Authors: Chandrakant Ashvin Avalani , Muhammad Yusof Aqil , M Zin Zulkifli , Rosland Eadie Azahar , Balgobin Amrit Stefan , Li Ren Chung , McClean Charlie Alexander 
Published: October 2023

Abstract
Sand production remains one of the major challenges in managing mature fields in Malaysia. Wells that experience severe sand production due to primary sand control failure and are uneconomical for workovers require a remedial solution to continue producing without compromising asset integrity. In these cases, operators rely heavily on Through-Tubing Sand Screen (TTSS), however the applications remain limited due to short TTSS lifespan especially in highly erosive environment. Frequent changeout is economically and operationally not feasible with increased intervention risk. Therefore, most high Gas-Oil Ratio (GOR) wells remain closed-in today, in need of a durable sand screen that can withstand high erosional velocity. Various types of Erosion Resistant Through-Tubing Sand Screens (ER-TTSS) have been implemented to test their durability and longevity in these wells.
This paper will discuss the performance of Malaysia's first installation of bonded bead sand screen in Well A. In contrast to conventional wire wrap or mesh filtration media, bonded bead sand screen incorporates tightly fused beads in cartridge form that act as depth filter to exclude sand, installed on a flushed perforated base pipe. The design is expected to provide superior erosion resistance performance as compared to conventional metallic sand screen. Prior to installation, Computational Fluid Dynamic (CFD) simulation and Sand Retention Test (SRT) were conducted to determine potential erosion rate at the targeted flow rate and optimum bead size, respectively.
During the 3 months pilot installation period, vigilant surface sand monitoring was in place, aided by real-time Acoustic Sand Monitoring (ASM) and Ultrasonic Flowline Thickness measurement (RT-UT). Well flowing parameters were also monitored closely to ensure that well is flown within the target parameters. Bonded bead sand screen was then retrieved post 3 months effective flowing period for detailed inspection, teardown and evaluation. Second screen were then installed for a period of &gt; 6 months as part of the replication. Several criteria were identified as key performance indicators to evaluate the effectiveness of this technology.
The outcome of pilot installation, teardown findings and subsequent replacement of bonded bead sand screen in Well A will be discussed. Recommendations for future optimization will also be included to ensure that bonded bead sand screen remains as one of the competent through-tubing sand solutions, especially for high GOR wells.
Project Financing of W Asset with Reserve Based Lending (RBL) Method
Authors: Warsiyanto Faizal Ardi , Arisetiawan Ronald , Kurniawan Akbar , Setyawan Aries Agung 
Published: October 2023

Abstract
The global pandemic of the coronavirus outbreak in 2020 caused the world economy to shake and world energy demand to weaken, impacting oil prices to fall dramatically. In this situation, oil and gas companies need to adapt by streamlining costs.
PT Mega Energi Tbk (PTME) is an upstream holding public company with several subsidiaries that manage oil and gas block assets in Indonesia. In 2018, PTME acquired oil-producing assets "W" and established the ME-W company. At that time, the oil price was 80 $ a barrel for purchase, but the oil price crisis in 2020 changed the plan.
It was about PTME’s strategy for keeping W’s assets and sharing that pledge with the bank. In 2018, PTME secured financing from a bank to purchase W assets and launch ME-W. At that time, the cash flow of ME-W could service this debt, but as the oil price fell, simply maintaining business operations became impossible for the company. ME-W was forced to reduce operational expenses and delay the expansion plan, but as a result, the company's cash flow performance wasn't as strong when the loan arrangement was signed. If ME-W can't pay the installment of the principal and interest on the loan, PTME will lose its rights to ME-W. For this reason, the company must refinance to pay off the prior loan.
PTME has another subsidiary, ME-B manages asset B, which sells gas and is not affected by the decline in the oil price. ME-B will submit for ME-W loan refinancing. Due to the high business risk in the oil and gas industry and ME-B doesn’t have assets whose more value than the previous loan, the company submitted a new loan scheme, Reserve-Based Lending (RBL). The RBL method can make the bank feel more secure because the determining loan amount uses the company's cash flow performance. The bank will do a redetermination every six months to review the company's performance.
ME-B has an advantage in processing loan requests. ME-B only needs to provide forecast entitlement that reflects the gas sales agreement until the loan end date based on reserve tail calculation. The RBL system can help PTME to settle previous loans and preserve ME-W assets.
This paper can provide information that the RBL method is commonly utilized by oil and gas companies and financial institutions overseas and about the possibility of financing oil and gas projects in Indonesia using the same method by local banks.
Kuwait's First Successful Implementation of Managed Pressure Cementing in Deep Jurassic Reservoirs of Kra Al-Maru Field
Authors: Ekpe Joseph , Al-Shehab Ahmad Yousif , Al-Othman Ahmad Hussain Eissa , Baijal Sanjeev , Marin German , Benyounces Hakim , Aliyeva Aida , Alqabandi Raghad , Al-Fakeh Bushrah 
Published: October 2023

Abstract
The development of Najmah-Sargelu (NJ-SR) limestone fractured reservoir, has a significant role in Kuwait Oil Company (KOC) 2040 strategy. To achieve this objective, hydrocarbon potential across the NJ-SR reservoir will have to be evaluated in the West Kuwait of Kra Al-Maru (Figure 1). First and foremost, this section will have to be drilled to planned section TD, cased off and successfully cemented. This paper discusses KOC experiences and best practices implemented to ensure utilizing managed pressure drilling equipment to achieve a successful 7-5/8-in liner cement job at well depth of 16,945ft. MD (15,756ft. TVD), and reservoir pressure and temperature ranges of 12,000 - 15,000psi and 230 - 280 deg F respectively.
This new approach to cementing is based on Managed Pressure Drilling technology. It addresses running the 7-5/8- in liner and cementing it in MPD mode. A step-bystep procedure is provided that ensures a constant bottom pressure is maintained throughout the process. Risk assessment showing what can go wrong and mitigations are provided, and the method is described in detail to allow readers comprehend the unique case presented in this paper.
Managed Pressure Cementing (MPC) technique in case study well is compared to offset wells in West Kuwait Field where cementing was conducted conventionally. In most cases, the cement bond logs show cement dispersed throughout the annulus with no continuous bond - channels in the cement behind the casing. The most significant new findings from this paper are that, in a couple of wells where there were no losses while pumping cement conventionally- the cement bond logs showed moderate to poor cement behind casing and channels within the cement. Figure 1Kra Al-Maru Field, West Kuwait
This technology offers opportunity to achieve good cement bonding with liner in fractured limestone which can be problematic due to the risk of losses and the presence of hydrocarbons with high pore pressure in West Kuwait NJ-SR intervals. This novelty approach using Managed Pressure Cementing technique to case and cement liners in West Kuwait fields and tight margin reservoir will ensure good cement bond logs behind casing and improve well testing and completions strategies.
The Contingent Resources Class: Non-Differentiation of Contingent Resources and Its Implications
Authors: Van Der Haar Katarina 
Published: October 2023

Abstract
Contingent Resources do not form part of Reserves reporting requirement for companies listed on most stock exchanges, but they are often provided in the information companies share with investors and the public in the form of media releases.
Contingent Resources are, according to the Petroleum Resources Management System (PRMS) "quantities of petroleum estimated to be potentially recoverable from known accumulations but are not yet considered mature enough for commercial development due to one or more contingencies" (PRMS, 2018). The sub-classes in the Contingent Resources classification are: Development PendingDevelopment on HoldDevelopment UnclarifiedDevelopment Not Viable
These sub-classes are not equal in their chance of development and portray a vast range in the "maturity" of a project. From projects that are about to be classified as Reserves, to projects that are unlikely to be developed.
The choice of sub-class can have an impact on a company's resource base and it is important to be realistic about the sub-class in which a Contingent Resource belongs.
When companies decide to report their Contingent Resources, all of the above sub-classes of the Contingent Resources class are labelled with the letter "C". A requirement to mention the specific sub-class of a Contingent Resource is not always present. This means that without further background information, they all look alike and can appear to have equal maturity and equal chance of development.
The PRMS is a system with definitions and guidelines. It is not a set of rules. Thus, terms in the PRMS require interpretation.
What do reserves evaluators do to ensure that Contingent Resources are classified and reported consistently? Are investors sufficiently informed when they deal with Contingent Resources, or would it be useful to have a requirement for reporting the respective sub-class?
This paper attempts to highlight some of the intricacies of the Contingent Resources class.
Malaysia's Multinational Oil and Gas Company Critical Decision in Production and Operations Management and the Company Competitive Strategy
Authors: Ahmad Shatiry M Sahir , Abu Akbal , Basri M Amir Fikri 
Published: October 2023

Abstract
In this paper, Petronas, to understand the critical decision in production and operations management for Group Project & Delivery (GPD). GPD is one of Petronas's business units that manage Petronas projects. The project's scope covers downstream and upstream projects that consist of LNG, new energy, offshore, and many more. The business unit (BU) will manage the project from the initiation until the project's closing as the PMBOK process group. The importance is to understand area seems that need to focus more on the correct decision in the production and operations management company operations in more than 10 countries worldwide either as the operators, joint venture or service providers.
Thus, the company's critical decision is to understand the findings from the design of goods and services, managing quality, process, and capacity design, location strategy, layout strategy, human resources and job design, supply chain management, inventory, scheduling, and maintenance. From the available data, the three critical decisions in rank in the production and operations management for the GPD are managing quality, human resources, and job design and scheduling.
Fluid Identification with Multiple Nonelectrical Methods in Ultradeep Tight Gas Reservoir, A Case Study from Tarim Basin
Authors: Hu Jianfeng , Zhao Yuanliang , Shuai Shichen , Ge Shengquan , Cai Liang , Wang Wei , Wu Jinlong , Zhao Xianran 
Published: October 2023

Abstract
The complex geology of fold-and-thrust belt led to significant difficulties with the engineering aspects of drilling, logging, completion, and testing. The Bashijiqike Formation and Baxigai Formation feature a tight sandstone reservoir that exists below a salt layer with high pressure and high downhole temperature. Reservoir characterization is indispensable in the development of this Cretaceous structural fractured tight sandstone reservoir formation. Fluid identification is a key tool used to locate the sweet spot with high producibility for further development. Resistivity is the most common and straight-forward method. However, because of the mixed effect from pore structure, formation sedimentary dips, far-end fractures, and the influence of the surrounding rocks etc., gas and water cannot easily be identified based on the resistivity difference. Compressional coefficient and Poisson's ratio is without obvious cross-over effect because of the compaction effect on rock sonic waves. Under these circumstances, new methods based on other nonelectrical technologies are used.
Nonelectrical means for fluid identification including T1–T2 based on 2D NMR measurement, and the spectroscopy related sigma and chlorine element method were successfully applied in this region. The 2D NMR measurements provide porosity and permeability information for T2 based analysis. When used in conjunction with T1 based measurement, the fluid identification through different T1–T2 response provides an advantage for distinguishing hydrocarbon and water, especially for gas. Since relaxation due to diffusion only applies to T2 and never to T1, given the typical magnetic field gradients of the logging tool, the oil and gas signal can easily be distinguished from the T1/T2 ratio. The continuous measurement enables the separation and quantitation of different fluids that exist in the pore system for the entire interval of the targeted reservoir. Formation water salinity is contributed by the NACL present in the fluid in this area. Advanced spectroscopy data provides chlorine measurements minus this effect in a mud system. The chlorine from the formation is calculated in this way. Formation water can be derived to further identify the main contributor of the fluid inside the pore system.
Case studies are presented from this ultradeep tight gas reservoir that solved the fluid identification issue when resistivity cannot directly distinguish fluid type. The result matched the well with the test, which provided a novel solution to finalize the sweet spot interval for the targeted reservoir.
Pattern Fracturing: Design and Execution Case Study with Fracturing Completion for Reservoir Management in Ordos Shale Oil
Authors: Mu Lijun , Zhang Tongwu , Xu Yingxin , Chen Qiang , Luo Yin , Liu Yuan , Niu Li , Ma Fujian , Huang Zheyuan 
Published: October 2023

Abstract
The use of volume-oriented completion and fracturing practice in Ordos Basin shale oil wells began in the mid-2010s, and it was effective in boosting productivity. However, recently, well performance has stopped improving and the engineering effort has increased, indicating that the oversized stimulation volume trigged certain mechanisms that negatively influenced production. To address this, we developed the pattern fracturing method, a new concept for platform-based completion and fracturing optimization, and it proved to be effective in a five-well field campaign.
Most completion and fracturing optimization is based on a single strategy; although the job design may vary between stages or wells due to the change of lateral quality, the overall intensity remained the same. Pattern fracturing applies two strategies for the candidate wells in the same platform: one for energy charger (EC) wells and the other for reinforced producer (RP) wells. Different design objectives are applied in each EC and RP group of wells. As validated by numerical simulation, pattern fracturing can significantly reduce the chance of the interference between the wells and can recover the entire reserve more efficiently.
During the field test, two of the five wells were assigned as EC wells and three were RP wells. Each EC well was completed with average 35000 m3 slickwater at maximum 14 m3/min pumping rate for each stage, while each RP well was completed with an average 16000 m3 gel-fluid at 6 m3/min pumping through a coiled-tubing-conveyed completion. Microseismic monitoring technology was used in 39 fracturing stages during the execution to visualize the reservoir section coverage by hydraulic fracturing, and high-frequency pressure monitoring technology was deployed in all stages to detect the offset well interference with precision.
The benefits of pattern fracturing were clear: lower horsepower consumption, higher efficiency of job execution, and fewer perceived frac hits from offset wells observed during the job execution phases. During the production phase, the performance from the platform also showed a very positive result. This indicates that the pattern fracturing strategy does work well for Ordos Basin shale oil as a new production enhancement approach.
Key Learning Experience in Managing Prolific High Temperature Wells in Offshore Malaysia
Authors: Khairul Anuar Khairina , Barat Junnyaruin , Idris Faisal Rizal , Xiong Choi Yee 
Published: October 2023

Abstract
Well integrity management for High Temperature (HT) wells can be challenging due to stresses and cyclic behaviour during thermal expansion or corrosive stress cracking that may impact the fatigue life of wellhead, tubing and casing. The impact can be catastrophic and detrimental to production sustainability and surrounding asset. This paper discussed operator’s experience and case studies in managing well integrity issues while operating HT wells in two fields, Field X and Field Y, located in offshore Malaysia. Field X and Field Y in offshore Malaysia, consists of five prolific High Temperature (HT) gas producers respectively, with temperature exceeding 300⁰F.
For Field X, since its first gas delivery in 2017, well integrity issues include the incident of wellhead seals failure, wellhead tilting, abnormal conductor growth, tubing leaks and Drive Pipe Housing Head (DPHH) sliplock issues, resulted in production deferment and loss of primary containment.
Meanwhile, for Field Y, the wellhead growth issue was observed only recently, end of 2021, after wells were on production for almost 2 years since 2020. The sudden movement has impacted the flowline to bend and expose the surface system to disastrous situation. Subsequently, the platform was on total shut down for a few days and led to unplanned production deferment and penalty due to production commitment. Analysis for WELLCAT and wellhead design has shown minimal concern on the wellhead growth but restriction on the surface line has caused production curtailment. To-date, the only identified issue is on the relative pattern of Flowing Tubing Head Pressure (FTHP) vs the wellhead growth.
Proactive and reactive measures are implemented including in-depth Root Cause Failure Analysis (RCFA) to understand gaps and mitigation required, which provide imperative insight and benchmark on strategies to manage HT wells.
The key issues and observations based on operator’s experience in managing HT wells include: Impact of cement integrity and cyclic load on wellhead growth and axial load exerted on wellhead.Oxygen corrosion of tubing causing intergranular corrosion weakening the tubing wall due to wellhead failure.Possible stress corrosion cracking resulted from wellhead tilting and growth.Wellhead design and acceptance requires validation on cyclic load and analysis on the capacity of sliplock to cater axial load at 30" conductor.Surface system modification requirement including flowline to cater for the bending effect caused by the growth.
This paper also highlighted preventive, monitoring practices and technology application to rectify well integrity issues in HT wells at Field X. Discussion on wellhead maintenance scope, nitrogen injection in annulus, tubing corrosion management and bracing support to address abnormal wellhead growth.
A Pore-to-Process Digital Design Methodology to Evaluate Efficiency of Geothermal Power Plants
Authors: Behrang Arash , Abbas Hicham , Istchenko Chris , Solano Angela 
Published: October 2023

Summary
The development and operation of geothermal plants play a crucial role in the transition to sustainable and low-carbon energy systems. In this paper, we have presented a seamless and flexible pore-to-process digital solution for the design and assessment of geothermal systems, encompassing the geothermal reservoir, gathering network, and geothermal power plant. Our primary focus in this study centers on the geothermal power plant with a detailed analysis of the functionality and performance of two commonly used configurations—a single-flash power plant and a double-flash geothermal power plant. Our work highlights that overall exergy efficiency of the studied geothermal power plants declines over time, primarily due to a decrease in the quality of the geothermal reservoir. Additionally, our analysis demonstrated that variations in the inlet separator pressure have a notable impact on the overall behavior of the power plant. Parametric studies also reveal that increasing the inlet separator pressure leads to decreased overall exergy efficiency and turbine power, resulting from less efficient conversion of available exergy into useful work.
Our studies showed that a substantial portion of the available exergy in the geothermal fluid is being dissipated in the condenser. Consequently, optimizing the design and operation of the condenser emerges as a crucial factor in enhancing the overall efficiency of geothermal power plants.
Automation of legal precedents retrieval: findings from a literature review
Authors: Mentzingen Hugo , Bacao Fernando , António Nuno 
Published: October 2023

Abstract
Judges frequently rely their reasoning on precedents. Courts must preserve uniformity in decisions while, depending on the legal system, previous cases compel rulings. The search for methods to accurately identify similar previous cases is not new and has been a vital input, for example, to case-based reasoning (CBR) methodologies. This literature review offers a comprehensive analysis of the advancements in automating the identification of legal precedents, primarily focusing on the paradigm shift from Manual Knowledge Engineering to the incorporation of Artificial Intelligence (AI) technologies such as Natural Language Processing (NLP) and Machine Learning (ML). While multiple approaches harnessing NLP and ML show promise, none has emerged as definitively superior, and further validation through statistically significant samples and expert-provided ground truth is imperative. Additionally, this review employs text-mining techniques to streamline the survey process, providing an accurate and holistic view of the current research landscape. By delineating extant research gaps and suggesting avenues for future exploration, this review serves as both a summation and a call for more targeted, empirical investigations.