bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Literature Review on Site Suitability and Structural Hydrodynamic Viability for Artificial Reefs Purposes
Authors: Alsheikh Anas Khaled , Zawawi Noor Amila Wan , Liew Mohd Shahir , Shawn Lim Eu , Toloue Iraj , Danyaro Kamaluddeen Usman , Aszemi Nurshazlyn Mohd 
Published: March 2022

Abstract
In Malaysia, over 400 oil and gas platforms are in operation. In every life cycle of a platform, it undergoes decommissioning. The most used method is by relocating the asset to an onshore fabrication facility. The alternative to onshore decommissioning is by reefing structures in-situ or ex-situ basis. to achieve the environmental assurance of a successful decommissioning by reefing, two domains of parameters were overviewed. the study involved hydrodynamic simulation of platforms. The first domain is in relations to the site to determine its suitability against hosting marine life and thriving coral formulation (Site Suitability). the other domain is in relations to the structure's physical and hydrodynamic properties (structural viability). Site suitability is governed by water depth and current velocity. Structural viability is governed by two sub-domains, one is where dimensions and complexity of the structure are assessed using dimensionality analysis. And the other is its hydrodynamic properties (Vortex Shedding Frequency, Pressure, Wake Region indices).
Optimizing Tubular Running Services Through Digital Solutions – Doing More with Less!
Authors: Thibodeaux Robert L , Smith Logan E , Mahmood Azfar 
Published: March 2022

Abstract
Digital transformation is a term that continues to be popular with the oil and gas industry. The industry's historic opposition to the adoption of innovative technology seems to be fading as operators, contractors, and service providers alike continue to invest in innovative solutions around not only digital technologies, but also in process and system optimization techniques. However, while operators are more willing to adopt newer and automated technologies, the "proof of value" burden still falls on service companies. Perceived value to operators may vary slightly, but overall, the industry has focused on two core tenants of value: Increased safety and efficiencyPersonnel reduction
For widespread adoption of an enhanced digital solution, the technology must not only provide quantifiable value in at least one of the core tenants, but also must repeatably demonstrate the value in the field.
The case study presented demonstrates the value added by introducing a new proprietary Programmable Logic Controller (PLC) based solution into the tubular running process. This system allows for tong operation, elevator and slip function, and single joint elevator (SJE) operation to be performed by a single person, rather than three or four personnel crew, as traditionally employed during tubular running operations. All functions are intelligently executed from a triple certified hazardous zone rated wireless tablet by a single operator's command while located inside the driller's cabin.
Through the deployment of a new consolidated and intelligent control system, the rig was able to reduce the number of personnel typically required for casing run and rack back operations down to two operators per tower, which equates to as much as a 66% reduction in personnel needed for tubular running operations. Additionally, the system allowed the operator to control the equipment from inside the driller's cabin, which improved communications and reduced red zone exposure by 30% while increasing run time efficiency by as much as 11% on some connection strings.
Oilfield Microbiology: Case Study of Molecular Techniques for Determining the Risk of Microbiologically Influenced Corrosion MIC
Authors: Bennet Douglas Grant 
Published: March 2022

Abstract
The objective of this paper is to explain the beneficial information obtained during a microbiological study of an oilfield survey, where molecular microbiology techniques where utilised. The inclusion of these techniques highlighted information that would have otherwise been missed and/or misinterpreted.
The molecular microbiology techniques deployed during this survey included Quantitative Polymerase Chain Reaction (qPCR) and Next Generation Sequencing (NGS).
The aim of PCR technology is to specifically increase a target (gene) from an undetectable amount of starting material. The first step is extraction of DNA from the sample, which will subsequently be subjected to the qPCR technology. During qPCR gene copies are made during thermocycling and a fluorescent marker accumulates, which can be used to quantify the target gene.
Similar to the PCR technology, DNA is extracted from the sample and the DNA is amplified. In NGS, this is then sorted into a library of small DNA segments before they are amplified. During the sequencing step each DNA fragment amplified is sequentially identified from light signals emitted by comparing with a DNA library.
The results obtained indicated crucial additional information that was not detected by traditional methods. In addition to much higher, truer quantification of known populations of Total Prokaryotes and Sulphate Reducing Prokaryotes, identification of other groups of DNA was possible through the NGS technique analysis. The results provided valuable information, which has subsequently been used to apply successful, targeted mitigation strategies to reduce the risk of MIC to assets.
Use of Oxygen Scavenger in Well Safety Valve Balancing Operations
Authors: Lehmann Marc , Lepkova Katerina , Pojtanabuntoeng Thunyaluk , Ghodkay Varun , Greenwood Annamaria , Hirano Susumu , Sunaba Toshiyuki 
Published: March 2022

Abstract
Monoethylene glycol (MEG) is often used to reduce the differential pressure across well valves so that they can be opened without damage. This MEG ultimately commingles with production fluids and if not deoxygenated contributes to the overall content of dissolved oxygen that may be seen by a receiving production facility. Normally, the dissolved oxygen levels would be removed to insignificant levels during fluid transport. Since the corrosion reactions sequester the oxygen as the fluids are exposed to less noble materials of construction, such as carbon steel. However, in facilities that utilise corrosion resistant alloys (CRA) the residual dissolved oxygen level can be so significant that it warrants reduction using oxygen scavengers. This paper reports on corrosion studies that illustrate the consequence of dissolved oxygen levels being carried through to a MEG reclamation unit constructed of CRA, and laboratory and field validation studies on the use of a bisulfite-based scavenger for removal of oxygen in 90wt% MEG used for equalising pressure of Subsurface Safety Valves.
Cyclic Behaviour of a Malaysian Deepwater Clay
Authors: Colreavy Cathal , Boylan Noel , Andersen Knut H , Huang Noorizal Nasri , Girsang Christian Hariady 
Published: March 2022

Abstract
Offshore structures are subjected to cyclic loading from a range of sources and an appreciation for how the underlying soil responds to that loading is essential for design. The behaviour of soil under cyclic loading differs to that from monotonic loading and advanced laboratory testing is required to assess this behaviour. This paper describes the behaviour of a deepwater soft clay under cyclic loading. The site is located offshore Sabah, Malaysia in water depths up to 1,200 m. As part of the geotechnical investigation for the site, a suite of cyclic simple shear tests was carried out on samples retrieved from boreholes on the site. Results from this suite of tests were used to establish a set of cyclic contour diagrams for the site. These contour diagrams will be used in the design of foundations for offshore structures at the site. This is the first comprehensive study of the cyclic behaviour of deepwater Malaysian clay. As such, they provide a useful starting point for the development of contour diagrams in similar soils.
Improving Aging Field Value Through Production Data Revitalization
Authors: Jamaludin Izzuddin , Tan Zhao Zheng , Surin Nicholas Aloysius , Hew Zhong Ying 
Published: March 2022

Abstract
Field-D consists of multi-stacked oil reservoirs with commingle production and dual strings. Well integrity issues are main challenges causing crossflow between zones and unintentional production/injection. With massive effort of rebuilding static model and rework on history matching (HM), many inconsistencies of production data allocation were discovered, such as oil recovery factor (RF) &gt;60%. This paper discusses the exercise of cleaning up production data as per latest subsurface understanding and memory production logging tool (MPLT) campaigns.
Reinterpretation of stratigraphic correlation, depositional environment, and petrophysical parameters are among major workflows during the static model rebuilding process. As current reservoir allocations are based on legacy permeability-thickness (KH) ratio, the requirement to revise allocation split based on latest understanding is considered compulsory. This is further justified by dynamic modeling HM exercise where inconsistencies are observed between legacy data and model response, resulting in poor HM quality and unrealistic RF, suggesting different production/injection distribution than in current database. Additionally, MPLT campaign is executed every year to obtain latest split percentage. A pilot exercise is embarked on to redefine contribution for each zone in every well in fault block VIII and rerun allocation starting day 1.
Successful production data allocation rerun is expected to demonstrate representative RF for individual reservoir. Higher RF are expected for zones with secondary drive mechanism i.e., water and gas injection, as opposed to natural depletion reservoirs (NDR). This exercise also will enable accurate reporting during the Annual Reporting of Petroleum Resources (ARPR) to the host government. Additionally, more accurate forecast using decline curve analysis (DCA) can be realized, and robust analysis can be performed to improve respective reservoir RF. Better well management also is anticipated as zonal isolation such as water or gas shut off or adding perforation jobs can be properly planned and executed. Looking from injection well point of view, proper distribution will be possible so that only targeted zones will receive the pressure support. A full field implementation is currently ongoing for the rest of fault block in Field-D.
Disruptive Dumpflooding Completion, Case Study Ecuador
Authors: Pleshkov Dmitry , Corella Moya Carlos Andres , Corella Moya Byron Ricardo , Ortiz Angel Vicente Silva , Paredes Luis , Huaca Augusto , Chicaiza Freddy , Marin Gustavo Ariel , Garcia Jose Norberto , Tapia Raul Armando Valencia , Rajain Anur Kumar 
Published: March 2022

Abstract
Most of the fields in Ecuador are considered "mature." Water injection is a well-known solution for mature fields. Water injection projects require a source of clean water. Traditionally, minimum specifications are achieved by surface treatment facilities. However, in the Ecuadorian Oriente Basin, the Hollin reservoir is an active aquifer with water meeting the requirements for use in waterflooding. But in other cases, water from production wells and from traditional surface facilities requires high investment costs because of associated facilities, chemical treatments, water production lines, and other requirements. A novel completion design has been developed. This proposed completion is called "modified dumpflooding" and represents a cost-effective solution for Ecuadorian mature fields. Dumpflooding is a modified version of dual concentric completion using most of its configuration pieces. It also takes advantage of extensive local experience in dual concentric completion design. Modified dumpflooding completion enables companies to use just one well for water production, injecting it into the depleted reservoir as a closed loop. Additionally, it helps to save costs in surface facilities by reducing human exposure to high pressure lines over large distances and eliminating operational expenditures for chemicals and equipment maintenance. Nodal analysis is foundational to helping companies understand how current design of waterflooding projects is behaving. It also provides a basis for mechanical configuration optimization to reduce bottlenecking points and improve completion performance.
A Novel Artificial Intelligence Framework for the Optimal Control of Wireless Temperature Sensors for Optimizing Oxygen Injection in Subsurface Reservoirs
Authors: Katterbauer Klemens , Al Qasim Abdulaziz , Al Shehri Abdallah , Yousif Ali 
Published: March 2022

Abstract
Hydrogen has become a very promising green energy source and it has the potential to be utilized in a variety of applications. Hydrogen, as a power source, has the benefits of being transportable and stored over long periods of times, and does not lead to any carbon emissions related to the utilization of the power source. Thermal EOR methods are among the most used recovery methods. They involve the introduction of thermal energy or heat into the reservoir to raise the temperature of the oil and reduce its viscosity. The heat makes the oil mobile and assists in moving it towards the producer wells. The heat can be added externally by injecting a hot fluid such as steam or hot water into the formations, or it can be generated internally through in-situ combustion by burning the oil in depleted gas or waterflooded reservoirs using air or oxygen. This method is an attractive alternative to produce cost-efficiently significant amounts of hydrogen from these depleted or waterflooded reservoirs. A major challenge is to optimize injection of air/oxygen to maximize hydrogen production via ensuring that the in-situ combustion sufficiently supports the breakdown of water into hydrogen molecules.
which can then be separated from other gases via a palladium copper alloy membrane, leaving clean blue hydrogen. A crucial challenge in this process is achieving sufficient temperature in the reservoir in order to achieve this combustion process. The temperatures typically must reach around 500 degree Celsius to break the molecules apart. Hence, accurately monitoring the temperature within the reservoir plays a crucial role in order to optimize the oxygen injection and maximize recovery from the reservoir.
Artificial intelligence (AI) practices have allowed to significantly improve optimization of reservoir production, based on observations in the near wellbore reservoir layers. This work utilizes a data-driven physics-inspired AI model for the optimal control of the high temperature wireless sensors for the optimal control of the oxygen injection in real-time.
The framework was examined on a synthetic reservoir model with various producers and injectors. Each producer and injector contain various wireless high temperature sensors that are connected to each other. The framework then utilizes the temperature sensor data, in addition to the produced hydrogen, to optimize oxygen injection.
This work represents a first and innovative approach to optimize subsurface wireless high temperature wireless sensing for maximizing hydrogen recovery from waterflooded reservoirs. The data-driven approach allows to optimize the hydrogen recovery representing a crucial element towards the drive for economical extraction of blue hydrogen.
Impact of Various Tubing Material Performance Under High CO2 Environment on Future Marginal Field Development Strategy
Authors: Syed Abd Rahim Syarifah Puteh Mariah , Azman Mohd Fairuz , Awang@Mohamed Zaidi , Ahmad Fuad Mior Yusni 
Published: March 2022

Abstract
It is widely known that for highly corrosive environment, corrosion-resistance alloy (CRA) is recommended as the production tubing material. This is because its alternative, carbon steel (CS) is prone to corrosion that leads to integrity issues such as tubing leak and tubing parted. However, CRA usage would increase well cost resulting in unattractive commercial implication especially for a marginal field development which tends to be very sensitive economically. This paper gathers the actual performance of various tubing materials that have been installed in a high CO2 oil field in Peninsular Malaysia, in which the findings would be used to determine a proper tubing material selection strategy for future development.
Actual data from 30 years of production was collected and to be analyzed statistically. Each well's water cut trend was evaluated to establish relationship between producing water to the corrosion rate and metal loss in the presence of CO2.
It is noted that some wells completed with CS both in single and dual completion are still producing with no leaks after 30 years. This case applies to either single string or dual string, with both strings are completed as producer. However, majority of active CS-completed wells require tubing pack off to overcome multiple leaks, especially in dual utility wells. Notably, wells that are completed with CRA e.g., 13 Cr are active with no possible leaks at all. Some wells which are completed with glass-reinforced epoxy (GRE) and higher grade of CRA; 22 & 25 Cr, also do not show any potential leaks or tubing integrity issue.
It is proven and highly recommended to complete high CO2 fields with CRA material. Nevertheless, by understanding the well and reservoir performance, particularly on the effect of water cut in relation to general corrosion due to CO2, the use of more expensive materials can be optimized. This paper is to discuss, in the context of marginal field development where production life is relatively shorter and production rate is low, the consideration of deploying a cheaper material and/or less corrosion-resistant substances as the tubing material to make the development more commercially attractive or remain status quo with CRA.
Successful Drilling of the Deepest and Hottest HPHT Carbonate Well in Central Luconia, Off the Coast of Sarawak, Offshore Malaysia
Authors: Ong Swee Hong Gary , Dejdamrongpreecha Warapong , Sookparkkit Pawan , Ungku Hamzah Ungku Syafena , Chia Boon Shin , Udin Rurizalakmal , Zulkarnain Marzuki , Manson James Hunter , Phasook Chevit , Umar Lawrence , Kongpat Nitipong 
Published: March 2022

Abstract
HPHT wells are typically associated with high complexity, technically challenging, long duration, high risk and high NPT as many things could go wrong especially when any of the critical nitty- gritty details are overlooked. The complexity is amplified with high risk of losses in carbonate reservoir with high level of contaminants compounded by the requirement of high mud weight above 17 ppg during monsoon season in an offshore environment.
The above sums up the challenges an operator had to manage in a groundbreaking HPHT carbonate appraisal well which had successfully pushed the historical envelope of such well category in Central Luconia area, off the coast of Sarawak where one of the new records of the deepest and hottest carbonate HPHT well had been created.
This well took almost 4 months to drill with production testing carried out in a safe and efficient manner whereby more than 4000m of vertical interval was covered by 6 hole sections.
With the seamless support from host authority, JV partners and all contractors, the well was successfully delivered within the planned duration and cost, despite the extreme challenges brought about by the COVID-19 pandemic.
This paper will share the experience of the entire cycle from pre job engineering/planning, execution and key lesson learnt for future exploitations.
Defining the Zonal Contribution in a Horizontal Well with Cased Hole ICD's Completion Using Innovative Integration of Multi Arrays Production Logging, Spectral Noise and High Resolution Temperature Log
Authors: Al-Sabea Salem , Patra Milan Kumar , Abu-Eida Abdullah , Dhafiri Jamayel Mubarak , Gobran Mahmoud Hamdy , Al Rasheed Fatemah Amir , Prosvirkin Sergey 
Published: March 2022

Abstract

Objectives/Scope
The Horizontal wells enhance reservoir performance by placing a long wellbore section within the reservoir. As they help in reducing water and/or gas production, increasing oil rates, reducing sand production and finally in achieving efficient drainage of the reservoir. The inflow control devices (ICDs) are used to address the issues of premature water and/or gas breakthrough, uniform flow distribution and reservoir depletion in the oilfield. They reduce the flow of unwanted fluids and balance the production distribution across the entire lateral section. The production contribution across the ICDs monitoring to take necessary remedial action is one of the challenges in this type of completion.
In this case study, the main objective was to determine the contribution profile and source of water in horizontal well with passive ICD completion installed back in 2011. The various challenges were the low production rate, heavy oil with water, erratic and inconsistent nature of the well flow, ESP design test with lack of recent flow results, and lack of some data about the ICDs. In addition, unlike most of the cases where the ICDs are installed in open hole, this case the ICDs are installed in 7in liner with nine perforation intervals.

Methods, Procedures, Process
This paper presents the use of multi arrays production logging combined with spectral noise and high precise temperature tools, to determine the contribution profile and source of water in this challenging ICD completion.

Results, Observations, Conclusions
The contribution profile across the ICDs was determined using the multi arrays production logging data and temperature simulation models assisted by noise data. The results were in contrary to the previous production logging results and helped significantly in the design of proper ICD cleaning operations. The work-over resulted in successfully restoring and attaining high oil gain.

Novel/Additive Information
The innovative combination of multi arrays production logging combined with spectral noise and high precise temperature tools to determine the contribution profile and source of water in horizontal well with ICD completion.
Microporosity Quantification and Flow Unit Prediction Using Neural Networks: A Case Study from Malaysia
Authors: Manhique Samía Janny Celeste de Ducílio , Salim Ahmed Mohamed Ahmed , Latiff Abdul Halim Abdul 
Published: March 2022

AbstractThis paper aims to quantify microporosity and access its impact on reservoir quality properties, to identify Hydraulic Flow Units (HFU) using core porosity and permeability data, to predict HFU and accurately estimate permeability in un-cored intervals/wells. Mercury Injection Capillary Pressure (MICP), Nuclear Magnetic Resonance (NMR) at high pressure (T2 distribution), and Water-Oil relative permeability curve data were used to quantify microporosity. The median pore-throat size was estimated through Windland's R35 equation and modified Kozeny-Carmen equations led to an accurate determination of Flow Zone Indicators (FZI) in each cored interval. Subsequently, Neural Networks were used to predict HFU in un-cored intervals using log data, this model was then extrapolated to estimate permeability in un-cored intervals. Microporosity estimations from MICP are relatively higher compared to NMR and Water-Oil Relative Permeability estimations. Estimations from MICP range from 25-69% while 11-32% is the range of estimations from the other methods. In conjunction to MICP data and clay volume assessment, two distinct zones were identified. The top intervals are characterized by high microporosity levels and steep-convex capillary pressure curves while the bottom intervals have lower microporosity levels and steep-concave capillary pressure curves. Analysis indicated that there are six (6) flow units and that the correlation coefficient (R2) between FZIcore and FZIlog is 99.89% and 91.89% for Kcore and KLog thus validating the model to be used for predictions in un-cored intervals. Through Windland's R35 equation it was concluded that there are two dominant pore throat sizes, meso and macro with ranges between 0.72 – 2.53 μm.