bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Method: Injection Dynamic - Transient Acoustic Pressure Thermal Logging to Increase the Effectiveness of Water Shutoff and Remediation Operation in Depleted Production Wells
Authors: Nayung Galih P. , Rudhy S. , Asep S. , Nur Cahya M. , Humam H. A. 
Published: October 2023

Abstract
The evaluation of flow profile in the wellbore system is an important part of oil & gas field development. Leaks that occur in or behind production casing not only potentially cause safety and environment issues, but also potentially lead to misjudgments of production analysis and the estimation of remaining reserve. The flow profile in the wellbore is mostly affected by the life cycle of well itself during drilling phase, completion phase, production or injection phase and restoration phase. One of many well-known technologies applied in oil & gas industries is the acoustic and pressure thermal log. The selection of surveillance methods to identify leaks and undesired water problems not only provides more effective results but also carries an acceptable risk in the term of project cost. The objective of this paper is to show how a novel approach of acoustic and pressure thermal surveillance can be used to increase the effectiveness of water shutoff job in depleted oil & gas wells.
An innovative approach of dynamic surveillance procedures called injection dynamic – transient method along artificial lift or depleted production wells must be conducted during acoustic, pressure and thermal data acquisition. Certain parameters must be adjusted properly during data acquisition, depending on completion and reservoir characteristics well by well such as area of interest, completion string, completion fluid, perforation type, injectivity test and reservoir properties. Several studies in depleted production wells show that the undesired flow in or behind production casing can be interpreted and identified precisely compared with conventional methods such as cement bond log.
As a result, the acoustic, pressure and thermal data interpretation contribute to both successful water shutoff operation and post-job production performance. Water problems can significantly be reduced from 1300 barrels water per day to 320 barrels water per day and on the other hand oil & gas significantly increased from 34 barrels oil equivalent per day to 532 barrels oil equivalent per day. Moreover, this paper should be beneficial to help all petroleum engineers currently working in mature oil & gas field not only to identify undesired flow problem precisely but also develop more comprehensive and effective remediation plans.
Technology Demonstration of Multi-Species (CO2, SO2, NO2, & PM) Capture
Authors: Wagstaff Christopher , AlGahtani Mohammad , Michaux Sylvain , Sreedharan Sai Shrinivas , Prabhudharwadkar Deoras , Roberts William 
Published: October 2023

Abstract
Post-combustion capture of carbon dioxide usually requires other upstream pollutant capture systems such as selective catalytic reduction for NOx, flue gas desulfurization, electrostatic precipitators, etc (Dziejarski et al. (2023)). Traditional carbon capture technologies cannot be deployed at point emission sources that do not have these systems and use fuels containing sulfur (e.g., heavy fuel oil, sour gas, etc.). A novel pollutant capture system is being developed at KAUST that eliminates this limitation.
A Cryogenic Carbon and Sulfur Capture (CCSC) technology is developed in partnership with Sustainable Energy Solutions (SES, part of Chart Industries). This technology focuses on post-combustion CO2 capture along with SO2, NO2, and other Particulate Matter (PM) pollutants. CCSC is modular in design and mounted on a 15-meter-long trailer. The multi-species co-capture system is mounted in the central section of the trailer and includes a separate control room and gas storage room on either end of the trailer. This trailer-mounted CCSC system has a nominal capacity of capturing 0.25 ton of CO2/day.
This CCSC process cools exhaust flue gases below the desublimating temperatures of CO2 (~−130°C) where CO2 solidifies out of the flue gas. This separation process is done by spraying isopentane as a contact liquid into an upward-moving flue gas. CO2 freezes into the contact liquid and ultimately flows out as a slurry. The contact liquid is regenerated via screwpress, and then the interstitial liquid is recovered via distillation. An additional column is necessary for the separation of a third species SO2.
The main objective of this trailer rig is to serve as a technology and IP development platform to cocapture multiple pollutants all using a single technology. The trailer rig is designed to be flue gas agnostic and finds applications in many facilities. Even though the system is currently optimized for the most probable site which is a heavy fuel oil (HFO) fired steam power plant, it can easily be adapted to shipboard carbon capture and co-capture of other pollutants more prominent from marine applications. A wetted-wire patented technology from KAUST (Wagstaff et al. (2022)) already shows promise for shipboard heat and mass transfer.
Don't Stop Drilling Operations but Use Customized Cross-Linked LCM Solution for Fractured Formations
Authors: Al-Zahrani Walid , Olivares Tulio , Bahamdan Abdulaziz , Burts Donnie 
Published: October 2023

Abstract
Curing drilling fluids losses in fractured and sandstone formations is the most challenging scenario to drilling team. Loss zones are unpredictable, due to large vugular zones, extended and connected fracture structures or in interbedded sandstone formations. However, based on proper evaluation of the offset wells data, loss events can be anticipated. Typically, conventional lost circulation material (LCM) pills containing various particle size distributions are part of the lost circulation armory in fractured sections. However, results show variation. This cross-linked LCM is distinguished for those situations with the most-severe lost circulation, as these cross-linking polymers will produce a rubber gel structure. This chemical blend has extremely effective sealing characteristics that are used as an innovative approach to the initial response to lost circulation. Depending on the bottom hole temperature, a retarder will be used to customize the mentioned LCM solution. This paper discusses a Customized Cross-Linked LCM Solution for Fractured and Sandstone Formations, based on a customized blend of high and low molecular weight anionic polymer, reinforcing material and cross-linking agent that has an extremely effective sealing characteristic. In addition, it can be pumped through the regular bottom hole assembly without losing rig time associated with tripping and mixing conventional LCM treatment.
A Next-Generation, Fully Controllable Alloy Wellbore Sealing Technology
Authors: Lucas Alex , McWilliam Gary , Eden Robert , Rege Gert , Osnes Kay Even , Worthington Sam , Gudmestad Kristian 
Published: October 2023

Abstract
Sealing wellbores via the use of alloy sealing technology presents a number of challenges. The typical approach involves the use of exothermic chemical reactions delivering high temperatures to ensure sufficient heat is generated to ensure the alloys remain molten for long enough to reach their intended radial extent.
One challenge of such an approach are the high temperatures generated and their potential effect on the external well barrier elements (casing, cement, formation). Furthermore, chemical methods are a ‘one shot’ approach that do not permit close control or repeat of the heating the process after initiation.
A next-generation alloy placement system has been developed using an electrical heater, cable and deployment system with sufficient capacity to deploy a fully controllable and verifiable heating solution, capable of operating at lower temperatures for extended durations. This allows close control of heating cycle to prevent damage and optimise the process, resulting in a superior barrier envelope. Furthermore, rigorous design and testing ensures the minimum amount of expensive alloy is used to achieve the desired seal.
This paper details the extensive design and testing programme that was undertaken to devise an optimal alloy plug and mature a complete barrier system that challenges both conventional approaches involving cement, and first-generation alloy plugging technologies. The project culminated in a full-scale pilot in a test well that replicated the challenging wellbore environment of the intended application as closely as possible. The testing demonstrated that the technology is capable of setting a competent alloy barrier to deliver at least a 3,000 psi / 207 bar differential pressure ‘big bore’ seal, even when set in drilling fluid and flowing gas.
Achieving the Impossible – Chasing Oil Column in Extremely Heterogeneous and Highly Flooded Area by Utilizing Extra Deep Azimuthal Resistivity
Authors: Seddik Ibrahim Abdelgaffar , Noordin Firdaus Bin Mohamed , Aziz Khalid Mohamed Abdul , Trisnadi Dicky , Zuraiqi Mohamed Ali , Potshangbam Sanathoi , Saravanakumar Krishnan , Yehia Mohammed , Bouny Ali 
Published: October 2023

Abstract
Well placement in flank and highly flooded areas is almost impossible with conventional logging while drilling (LWD) technology. Extremely heterogeneous reservoir properties coupled with an uneven flood front presented high project risk, with the potential to compromise the landing and not optimally place the well, which could impact the well objective. Extra deep azimuthal resistivity (EDAR) look ahead capability with a greater depth of detection is the only feasible technology to mitigate these challenges due to high uncertainty of waterfront.
The initial wellbore has been on production since 2010 and reached more than 90% water cut by 2021. To extend its life, the well must be sidetracked as a new drain hole. Since the well was located in a complex geological structure, which was highly flooded with a complicated flood front pattern, the reservoir target was very challenging. Conventional logging technology, which has minimal depth of investigation, does not have sufficient capability to provide data sufficiently far from wellbore to take proactive decisions on landing and placing the well within the oil zone. Look ahead capability of EDAR technology, which can detect much deeper resistivity contrast ahead of the bit, was selected to identify the optimum landing point. This EDAR technology was also adopted in the horizontal section to geosteeer within the main oil column and assisted in optimizing lower completion design.
EDAR inversion has shown tremendous value in mapping the resistivity changes while approaching to land the well in the target zone. It mapped a flooded zone 80 ft ahead of bit. This information helped in optimizing the trajectory to delay the landing while searching for an oil column in the target reservoir. EDAR inversion mapped the oil column 20 ft ahead of bit from the flooded zone and the trajectory was accordingly adjusted to land successfully in the oil pool bounded by water zones above and below.
Real-time inversion along the horizontal section was utilized successfully in navigating and mapping the gradual change in oil column towards toe of the well, mapping a thin column (~20ft) at heel to more than 100 ft thick towards well toe.
One Step Closer to Replacing Portland Cement with Geopolymers for Oil Well Applications
Authors: Kamali M. , Khalifeh M. , Kverneland J. , Benmesbah M. , Delabroy L. , Middleton R. 
Published: October 2023

Abstract
Inorganic geopolymers are typically composed of aluminosilicate-rich powders and alkali silicate solutions as hardeners. Once mixed, these geopolymers exhibit cement-like behavior. However, highly alkaline solutions raise HSE (Health, Safety, and Environment) concerns in field operations. This paper provides a comprehensive characterization of a "one-part" granite-based geopolymer for oilfield applications that eliminates the need for alkaline solutions. Exactly like to cement, only fresh water is required to mix the geopolymer. As the reference material, API neat Class G cement was used for comparison. The fluid properties in the liquid state, including viscosity, gel strength, static fluid-loss, and mechanical properties after solidification such as sonic strength development, uniaxial compressive strength, and tensile strength, were tested following API standards. The initial analysis indicated that the rock-based geopolymer may not require any dispersant if the ingredients are engineered properly. However, a limitation of the geopolymer is its short thickening time at elevated temperatures. The use of two candidate organic and inorganic retarders extended the pumping time, followed by solidification and strength development. The short-term mechanical properties of the one-part geopolymer were evaluated by curing samples under downhole condition up to 60 days, where the bottom-hole circulation temperature and the static temperatures were 50°C and 70°C, respectively. The mix design exhibits a rapid transition from gelation to hardening. The compressive strength of the solidified samples was 50% less than that of the neat Class G cement, but the material demonstrated 4 times more flexibility.
Improving Wastewater Treatment Through Application of Industry 4.0
Authors: Fonia Devendra Singh 
Published: October 2023

Abstract
Wastewater Treatment faces the challenges of constantly changing parameters of the influence. These fluctuations can be in terms of COD, TOC, Ammonia, Sulphides, Phenols, cyanides, oil& grease etc.
This paper focuses on two (2) refinery Waste-Water Treatment Plants (WWTP's) where providing stable and consistent treatment was difficult due to constantly fluctuating: COD with fluctuations from a low of 100 mg/ltr, to a high of 2000 mg/ltr.TOC with fluctuations from a low of 50 mg/ltr, to a high of 450 mg/ltr.Ammonia with fluctuations from a low of 5 mg/ltr, to a high of 70 mg/ltr.Sulphides with fluctuations from a low of 3 mg/ltr, to a high of 170 mg/ltr.
Use of Double Machine Learning for Microseismic Data Analysis: What Factors Influence Microseismic Events?
Authors: Conde Oliver Rojas , Misra Siddharth , Liu Rui 
Published: October 2023

Abstract
This study proposes a new workflow for analyzing microseismic data using causal inference techniques. This approach allows us to identify the causal relationships between a new microseismic event and its spatiotemporally proximal, prior microseismic events, while taking into account confounding variables that influence both the cause-and-effect variables. We applied this workflow to microseismic data acquired from hydraulic fracturing operations on 2 horizontal wells in the Marcellus Shale. Our results revealed several new insights into the microseismic source mechanisms, including: 1) The magnitude of a new microseismic event does not depend on the number or spatial and temporal concentrations of the spatiotemporally proximal, prior events; 2) When the maximum magnitude of prior event in a region increases, a new event occurs much earlier in that region; 3) A region with a large number of microseismic events will produce a new microseismic event much earlier in time than a region with fewer events. These causal relationships suggest that accurately selecting confounders is crucial for obtaining accurate causal estimates. Failure to properly select confounders can result in significant overestimation or underestimation of the causal estimates, as high as +/- 100%. Our results also confirm that causation and correlation are two distinct concepts. A causal analysis with true confounders reveals the true causal relationship that cannot be quantified using correlation/association methods. This is demonstrated using Double Machine Learning (DML) to compute the average treatment effect for both a true confounder variable and a random confounder variable.
Applications & Challenges of the Non-Metallic Material for Hydrocarbon Piping
Authors: Saeed W. S. , Al Mehairi A. S. , Alnaqbi A. M. , Al Blooshi S. O. 
Published: October 2023

Abstract
This paper will explore the various applications and challenges of non-metallic piping for hydrocarbon service and how it helps reduce corrosion costs. According to the NACE study, the total annual cost of corrosion in the oil and gas industry is estimated to be $1.372 billion. It is remarkable how much money can be saved by implementing non-metallic piping solutions. Not only does it reduce corrosion costs, but it also helps improve safety and efficiency in the oil and gas industry. By reducing the need for frequent maintenance, non-metallic piping provides a cost-effective and reliable solution for hydrocarbon service.
This paper highlights two successful case studies for High-Density Poly Ethylene (HDPE) in the oil and gas industry and further elaborates on the challenges. Additionally, the lesson learned from another case for the fire water network is highlighted along with a rout case analysis of the failures.
Flawless Startup – A Holistic Approach to Fasttrack Starting Up a Multimillion Project
Authors: Ioan Tiberiu , Malagon Cecilia , Ruzhnikov Alexey , Elmokashfi Haytham 
Published: October 2023

Abstract
Project management defines five phases, where the project initiation (or start-up) is the most critical. That is specifically applicable to the drilling industry in the case of multi-well, multi-rig projects. This paper covers the implementation of the start-up sub-process within the integration operating model during the planning phase, the optimization of resources, and the stakeholder strategy that allowed to spud the wells in a compressed schedule and exceeded the expectations.
Once the project manager was appointed, the handover process between sales and the project execution teams started. This activity marked the Project Initiation phase within the Project Management process. The Project Manager followed the Start-up sub-process to ensure all the tasks required to start a complex project were followed to spud on time and avoid HSE incidents and liquidated damages.
The Start-up sub-process follows the Project Management Institute (PMI) framework and includes all the project management areas but is applied to the specificities of the customer, commercial model, and project complexity.
Advancing Energy Performance Monitoring of Large Compression Units Using a Thermodynamic Digital Twin
Authors: Alzaabi Y. S. , Sajjad S. S. 
Published: October 2023

Abstract
The compression units installed on the sales gas network encounter a diverse range of operating modes due to the fluctuating supply and demand conditions and the corresponding dynamics of the network. Determining the actual performance in such applications creates a significant challenge due to the variability of specific energy consumption. This paper introduces a new and reliable monitoring system that allows for real-time assessment of energy performance in dynamic compression. The system also identifies potential applications for energy conservation.
The methodology involved a comprehensive examination of the design and original equipment manufacturer (OEM) data associated to the compression units. This was subsequently followed by an in-depth review of the operating envelope. Afterwards, a comprehensive thermodynamic model was developed for compression units that incorporates all operational modes. The model was then confirmed using real operational data by integrating the OEM's actual performance curves into the thermodynamic digital twin. In order to facilitate the monitoring of compressor performance when the thermodynamic digital twin is not available, an additional mathematical model has been developed alongside the existing thermodynamic model. This supplementary model allows operators to conduct off-line monitoring of the compressors.
Conducting a comprehensive performance analysis of centrifugal compressors is imperative in order to accurately assess their operational status and efficiency. A decline in performance can serve as an indicator of internal wear or fouling, which, if left unaddressed, may lead to diminished throughput, increased energy consumption, or unexpected interruptions in operation. Hence, the performance metric encompasses not only energy consumption and operational expenses, but also encompasses critical factors such as reliability.
The development of an integrated thermodynamic digital twin for large sales gas compression units, which possess a total throughput capacity exceeding 500 MMSCFD, has facilitated and exhibited efficient energy performance monitoring, even in the presence of varying operating scenarios. The tool enabled the immediate comparison between the actual performance, specifically the energy consumption, and the anticipated performance based on the model. Additionally, it facilitated immediate tracking of polytropic efficiency trends and provided a real-time visualization of potential opportunities for energy savings.
The digital twin has demonstrated its efficacy as a cost-effective and dependable tool for real-time prediction of compressor performance across different operational modes. The information obtained from the compression digital twin can be integrated with process simulation models to enhance the optimization of the overall process. The model has the potential to enhance supervisory capabilities, diagnostics, control capabilities, and even aid in the prediction of failures in advance.
Application of a Digital Twin for Asset-Wide Production Planning and Optimization – A Case Study
Authors: Atibodhi N. , Toprasert P. , Thienthanukit W. , Supha-Kitti D. , Pongsripian W. , Wang F. , Luengo E. , Nazir F. , Mijares G. 
Published: October 2023

Abstract
This paper presents the results and insights gained from implementing a Digital Twin within the context of a Production Planning and Optimization (PPO) solution. The paper shares the framework and principles of Production Planning and Optimization and the way they drive the requirements and use of the Digital Twin to allow for the effective solution of the planning and optimization problem. In particular, it highlights the requirement of a model of record and an "evergreen" Digital Twin that should include the automated processes to assess the quality of the data consumed, to update the model when changes to the design or operation occur, and to calibrate the model using the latest data available.
A Case Study of an implementation of a Short-Term Production Planning and Optimization (STPPO) solution for over a thousand wells and hundred platforms in three offshore gas fields in Thailand is presented. The solution helps the end user to carry the short-term production planning and optimization for the fields within the presented context, allowing for the definition of daily production and operational targets for all the wells in the asset to meet a desired production target while observing operating and product quality constraints.
The Case Study is implemented within the PPO framework introduced in the paper thus allowing for the future functionality expansion, such as the integration to a Long-Term Production Planning and Optimization (LTPPO), through the incorporation of constraints focused on longer term value drivers of the asset, such as recovery and other reservoir management indicators. Because of this, the solution is well posed to help closing the gap between the Reservoir and Production/Operations personnel and to support multidisciplinary collaboration.
The Case Study not only presents the technical details of the solution, but more importantly it highlights the challenges encountered in its implementation and adoption by the user. Specially, it underlines the importance to plan and implement continuous enhancement processes to align the solution and governance system, work processes, and operating culture to maximize user adoption and return on investment.