bluuebunny/crossref_metadata_2025_split huggingface dataset:
Strategic Roadmap for Digitalized Asset Lifecycle Management
Authors: Kusumawardhani Mayang , Johansen Jan-Viggo , Markeset Tore 
Published: April 2022

Abstract
The oil and gas industry is facing an increasingly complex world, characterized by the diffusion of digital emergence, sustainability awakening, and the seemingly continuous pandemic. To keep their competitive advantage, companies need to map their organizational strategy to prepare for what lies ahead. asset lifecycle management (ALM) is an integral part of oil and gas facilities and could not escape from this diffusion as well.
Digital advancement in ALM has been proliferating for years as companies strive to catch up with current development while anticipating future requirements. The pandemic has massively accelerated the pace of digital advancement of the organization and changed the role of ALM in the organization and the way it's executed. Thus, this paper arises from the motivation to share knowledge in ALM digital efforts with companies of mutual background.
In the paper, we will discuss the current drivers in asset management and how these drivers stir the transformation of asset integrity management (AIM) into ALM. The paper will also discuss how the holistic lifecycle approach and sustainability are retrofitted as part of the organization's transformation that is needed for long-term competitive advantage in the digital age. Finally, a fit-for-purpose roadmap for strategic ALM digitalization will be presented, along with the possibility for further research.
Standardization of Procurement Equipment Specifications: Establishing a Strong Foundation for Oil & Gas Capital Project Development and Delivery
Authors: Postema Adri , Harris David , Berry Dominic 
Published: April 2022

Abstract
Operators need industry-wide standardization to manage the $3 trillion in CAPEX expenditure forecast for 2018-2025 (Global Data, 2018), while maintaining competitiveness and mitigating risks.
With the backing of the World Economic Forum, Joint Industry Program 33 (JIP 33) was initiated to drive industry-level standardization for procuring equipment items, moving the industry structurally – across the value chain - towards common engineering designs and solutions, established by means of cross-company and value-chain collaboration.
By 2022 over 50 standardized, freely available specifications will have been delivered. Their adoption by 12 major operators is being measured and is progressing well. This enables the program to capture and evaluate successes, challenges, key learnings and feedback. The program has also established a process for future maintenance of JIP33 specifications in order to achieve sustained benefits.
The success of JIP33 is measured, within the operating companies and the wider industry, by the extent of adoption and use of the JIP33 specifications. This requires aligning corporate engineering and procurement processes with JIP33 methodology, embedding the JIP33 specifications in company systems, and using JIP33 specifications as default on projects, with a policy of ‘no deviations’.
In 2019-2021 JIP33 specifications have been downloaded over 110,000 times from the IOGP website. Supplier feedback indicates cost savings of up to 50% and a potential reduction of 65% in supplier engineering hours could be achieved if the specifications become industry standard designs. Key information that is filtered through constructive feedback from vendors during the purchase process, has led to a series of recommendations for further improving existing JIP33 specifications. These now become part of a structured maintenance process. JIP33 is closely collaborating with Standards Development Organisations to ensure that valuable learning can be included in updates of the international parent standards.
Industry networks have been established to engage with engineering contractors and suppliers to create awareness of JIP33, and to further efforts in advocating the use of JIP33 specifications across the wider oil and gas industry.
This paper will present the status of the JIP33 program after 5 years. It will showcase some of its early successes, challenges and learnings. Learnings from the adoption and use of the specifications by the JIP33 members will be discussed. Initiatives that further encourage operators, EPC's and suppliers to use the specifications will be shared.
Understanding the Complex Channel Sand Reservoir from High-Definition Oil-Base Mud Microresistivity Image Logs: Case Study from Junggar Basin
Authors: Zhang Zengbao , Xu Wei , Liu Yanhui , Zhou Guangqing , Wang Deshun , Lyu Jainbo , Sun Bo , Feng Jiansheng , Xin Zhong Bin , Liu Bo , Li Shenzhuan , Liang Cai , Wang Wei , Guan Hui , Yu Daiguo , Wei Guo , Sultan Gamal 
Published: April 2022

Abstract
This study examines an important channel sand reservoir in the Junggar Basin, which has a reservoir quality that varies greatly in the vertical and horizontal directions due to the presence of tight sandstones deposited under different sedimentary conditions. Studies confirmed that the high-energy sandstone deposits have good porosity and permeability based on the core data. The channel sand is 20 m to 30 m thick in the Qigu formation and can be divided into three to four channels. Identifying and characterizing the high-energy sandstone "sweet spots" was the objective of this case study.
In order to find the sweet spot in this reservoir, high-definition oil-base mud microresistivity image logs were acquired in five exploration wells. The image logs made it possible to identify the different kinds of sandstone reservoirs based on sedimentary structure and texture. Parallel bedding, deformed bedding, cross bedding, and massive bedding were all identified. The paleocurrent energy was from high-to-low and from bottom-to-top in a single channel sand body. The core and production data validated the reservoir qualities, which were identified from the sedimentary features.
The channel sand was divided into three to four multistory sand bodies based on image logs. As a result, the typical channel-levee system—composed of massive bedding, cross-bedding and parallel bedding features—was revealed. The massive bedding was mainly at the bottom of the single channel system, surmounted by high-angle cross-bedding, and then finally the parallel bedding intervals. The paleocurrent energy changes from high-to-low vertically within the single channel system. Based on the open-hole and image logs, two types of sweet spots were identified: massive bedding sandstone and high-angle cross-bedding sandstone. These two types were deposited in a high-energy environment which formed the potential sweet spot in the channel complex. The massive bedding intervals, which are mainly in the channel bottom, when cemented by calcite or clay, will become tight sometimes. The high-angle cross-bedding sandstone and uncemented massive-bedding sandstone were the potential target zones for the horizontal well.
This case study will show the interpretation of sedimentary features in the channel sand reservoir based on high-definition image logs, to provide a comprehensive understanding of the geologic features that differentiate reservoir quality. The identification of cross-bedding in the channel sand provided a new way to predict possible tight sandstone sweet spots that can help to design horizontal wells.
Development of a High-Voltage Connector System for Floating Offshore Wind Turbines Using Field Proven Oil and Gas Technology
Authors: Plant Christopher 
Published: April 2022

Abstract
This paper will detail the process of developing a 36/60(72,5) kV high voltage wet mate and dry mate connector system, designed to meet the requirements of floating offshore wind turbines, and utilizing new and proven subsea technology developed to meet the requirements of critical reliability subsea applications.
The paper will consider the state of the art for subsea high voltage wet and dry mate connectors before identifying the requirements of the floating offshore wind industry. A technology readiness assessment will be performed to define a technology qualification program for a new solution to meet the requirements of the floating offshore wind industry. The technology qualification program will then be executed to bring a solution to technology readiness level (TRL) 4, according to API 17Q.
This paper will develop a technology readiness assessment for existing high-voltage connector solutions within the oil and gas industry for applications within floating offshore wind, starting with documenting the current state of the art for subsea high-voltage wet and dry mate connectors. The technology readiness assessment will form the basis of an engineering and test program for a new solution for floating offshore wind applications.
This paper will document the engineering and qualification in accordance with the requirements of the floating offshore wind industry as well as established and emerging international and regional standards, such as IEC and IEEE standards.
It is very likely that as the floating offshore wind industry matures, there will be continual development of the requirements and this paper will discuss likely changes in the requirements for high-voltage connector systems for floating offshore wind in the long term.
Within the floating offshore wind industry, there are many different solutions proposed for the floating substructure. The paper will explore the potential advantages and disadvantages that the use of subsea wet and dry mate connectors might bring to floating offshore wind and will consider the full lifecycle of the floating wind farm, with a high focus on risk and cost during installation, reliability, and maintenance.
In-Situ Stress Models for an Anisotropic Rock Formation Using Well Log Sonic Data - A Comparison of Different Approximations
Authors: Hachem Dany , Wong Sau-Wai 
Published: April 2022

Abstract
The evaluation and estimation of in-situ stress regimes are vital in many subsurface engineering processes such as borehole stability in deep well drilling, hydraulic fracturing design, water injection for pressure maintenance, geothermal recovery, and geological carbon sequestration.
For complex lithology and highly laminated rock formations such as an organic-rich shale gas reservoir or a clay-rich overburden caprock, the anisotropic mechanical rock properties can be described as transversely isotropic with a vertical symmetry axis - the so-called vertical transverse isotropic (VTI) models.
The use of the poro-elasticity concept is one of the most common approaches in the determination of in-situ stresses. It assumes a porous rock medium and uses elastic parameters, vertical stress, and pore pressure for horizontal stress determination. The application is relatively trivial for isotropic rocks as the elastic parameters can be estimated/obtained from compressional and shear velocity waves available from well logs. However, for anisotropic rocks with transverse isotropy, the approach becomes more complicated. Only three of the five unknown independent stiffness coefficients can be calculated from well logs, requiring advanced sonic logging tools in vertical wells to provide compression, shear and Stoneley waves. The remaining two coefficients involve various assumptions and empirical correlations for their approximations, with no clear consensus or indication as to which is more valid or more accurate than the other.
In this paper, we examine 3 different well-known models and assumptions to derive the VTI minimum in-situ stress for a deep anisotropic rock formation. Specifically, we examine a class of established models and a more recently developed lab-based regression/empirical model. The strengths and weaknesses of each approach are discussed, and a straightforward workflow is proposed. This workflow integrates all possible constraints on the critical stiffness coefficients based on data quality and availability and includes a pragmatic approach to calibrating the log-derived in-situ stress profile with field injection data. Here, we adopt a simplified calibration approach and compare its merit to the traditional scheme.
A Construction Method of Complex Fractures in Marine Carbonate Reservoir
Authors: Wang Wenzhi , Yang Guang , Cui Meng , Wang Haige , Zhou Zhou , Kao Jiawei , Liu Yuqing , Wang Lian 
Published: April 2022

Abstract
Marine fractured-vuggy carbonate reservoirare important oil and gas reservoirs in China, the Middle East, and North America. In the development process, it is necessary to connect hydraulic fractures and as many karst cavities as possible, which are the main geological components of oil and gas storage. However, the systematic theoretical of how to build complex fractures in fractured-vuggy carbonate reservoirs is scarce. Facing this situation, this paper presents a method that can improve the accuracy of fracturing effect prediction and optimize fracturing process design parameters so as toachieve the purpose of increasing production. It studies the factors that could affect that connection. It is found that the density of natural fractures and cavitiesin the reservoir is the main factor affecting the fracture propagation shape. Meanwhile, the liquid containing cavitiesin the reservoir will attract or repel the fractures. Furthermore, natural fractures will cause the migration of fracture propagation path and hydraulic fractures are easy to continue to expand along the direction of large natural fractures. This methodology could be used in future studies for the marine fracture–vuggy carbonate formation. In addition, the research conclusion could be used to design and evaluate hydraulic fracturing operation.
A Data Centric Digital Platform for Rigid Pipeline Engineering
Authors: Truche Sylvain , Le Prin Kevin , Ben Abdallah Mohamed , Minguez Matthieu 
Published: April 2022

Abstract
Rigid pipeline engineering, alike most of the engineering activities, has to manage a deep transformation in the way it is performed. This trend is seen throughout the industry. This transformation is driven by the massive introduction and development of digital products and services, which as of today drive what is called a Digital Transformation. The paper briefly provides some insights on how such a transformation is reshaping the current established order in term of organization, schedule, product, processes, human resources, and business strategy. While this transformation is still moving on, a specific focus on Data is getting a massive momentum, as Data is becoming, within a general consensus, a major sought-after assest, a business field on its own.
Based on that new paradigm, the notion of single digital thread is introduced to highlight the need to manage the flow of data which is produced through the different digital products, platforms, or services. In the Company, this notion of a single digital thread is symbolized by Subsea Studio™ (here after called SS) to which the different digital products, platforms and services are connected.
Once such a context is properly defined, the focus is done on the digital platform called Smart Pipeline Design ARENA (hereafter named ARENA) which is to be seen as a product configurator dedicated to rigid pipeline engineering. The authors firstly present what ARENA is about, what ARENA intends to offer and how ARENA is embedded in the digital ecosystem and strategy of the company. To conclude, the authors introduce how the platform and the massive use of Artificial Intelligence algorithms can impact rigid pipeline engineering and more generally improve the business performance. This is achieved providing (i) some insights on the way automation and optimization are implemented in standard engineering process flow and (ii) most importantly the savings which have to be expected in terms of direct engineering cost (i.e. man hours) and technology & procurement cost.
Casing Exit System with No Red Zone Assembly
Authors: Gregurek Philip Matthew , Eidem Morten , Nguyen Tuan Anh , Grindhaug Gaute , Ferdin Valerie , Ali Mohsen , Hern Greg Lee , Munir Waqas 
Published: April 2022

Abstract
This system delivers on improved safety, robustness, and efficiency of a casing exit operation by providing a positive impact in the reduction of carbon emissions. This is possible due to the system's ability to reduce the required time to pick up, deploy, run in hole, install, and to perform the milling operation. The reduction in time in these operations translates to an increase in personnel safety and reduces carbon emissions to the environment. The system furthers the efforts of safety with its ability to combine the traditional required separate clean-out run with the installation run. This substantial time savings and deletion of a separate clean-out operation removes the opportunity of exposing personnel to the risk of potential falling objects, cluttering of the rig floor with additional tools, and the handling of the tools. Traditional whipstock systems utilize a shear bolt as it's mill to whipstock interface, whereas this system uses a self-aligning cylinder that can be assembled on the rig floor or can be pre-assembled in the shop prior to being loaded out. The benefits of being pre-assembled allows for the system to be picked up and directly installed into the well, thus preventing personnel exposure to dangerous pinch points. Traditional whipstock systems are limited to a run-in hole rate of two minutes per stand. The limitation of the slow run-in rate promotes delays in the progression of subsequent tasks. The long durations while running the traditional system in hole can lead to distractions and complacency resulting in injuries due to lack of focus. The system can prevent failed runs and reduced trips with its combination of redundant activated anchor and mill to whipstock interface, the anchor being configurable in either hydraulic or annular activation, can also be activated by setting down on a bridge plug, fish, or cement plug. With the use of the connector style whipstock, the anchor can be dragged up hole and reoriented if needed to the original kickoff point (KOP). This eliminates the necessity to pull out of hole and to re-run due to a failure in setting the whipstock. Thus, preventing unnecessary changes to the casing exit operation and decreasing handling of tools by personnel.
Assessment of the Potential for Hydrogen Production from Bottom Fixed Offshore Wind in Uruguay
Authors: Tomasini Juan , Gristo Pablo , Ferro Santiago , Novo Rodrigo 
Published: April 2022

Abstract
After having decarbonized almost the entire electricity matrix, the next step in the Uruguayan energy transition includes the development of a hydrogen economy, for which both local and export markets are being considered, based on vast untapped unconventional renewable resources potential onshore and offshore. For ANCAP (NOC), hydrogen is key in the transition to a low-carbon and sustainable energy company, hence initiating several actions including the assessment of the potential for hydrogen production from offshore wind. Leveraging on data and information from offshore oil and gas exploration projects, distinct regions were delineated as the most suitable for the development of offshore green hydrogen production projects both from bottom fixed and floating wind technologies. In this work we present the results of the potential assessment of two regions suitable for bottom fixed offshore wind technologies.
Region 1 is located at the interior waters of the Uruguayan territorial sea at distances longer than 10km from the coast and water-depth ranging from 10 to 30 m. Region 2 is located on the Uruguayan Exclusive Economic Zone at distances longer than 60 km from the coast on water-depth ranging from 20 to 60 m. The assessment of the potential of these regions includes both the power generation and hydrogen production according to stochastic model based on capacity density data from North and Baltic Sea projects, energy requirements for PEM electrolysis technology and capacity factor data specific for offshore Uruguay. Additionally, both regions were evaluated and compared based on other inferred aspects derived from different development concepts, such as social acceptance, OPEX, CAPEX and logistics among others.
Results indicate that Region 1 and Region 2 have potential for power generation of 14GW and 110GW respectively, that corresponds to hydrogen production potential of 1.2Mton/year and 10Mton/year respectively (indicated figures corresponds to mean values). From contrasting both regions on other different aspects, results that Region 1 has advantages regarding CAPEX and OPEX while Region 2 has advantages regarding potential social acceptance and logistic requirements. Calculated hydrogen production potential for both regions represent more than eighty times the equivalent diesel currently consumed in Uruguay for heavy duty transport, demonstrating the relative size of the local market compared with the offshore potential. On the other hand, already announced green hydrogen future requirements for Europe and Asia suggest attractive markets for this kind of developments.
For the first time the potential for hydrogen production from bottom-fixed offshore wind in Uruguay was assessed indicating very attractive results, both technically and economically, for the export market. Results are encouraging as lead to new possibilities to support the next energy transition in the country towards the development of a hydrogen economy.
A New Approach to future FLNG for Offshore Gas Monetization
Authors: Liu Xiaogang , Fu Liping , Ji Xiuyun , Zeng Xiaogang , Chen Guang , Zhang Yuezheng 
Published: April 2022

Abstract
A new approach to future FLNG is presented which will significantly reduce the overall CAPEX, EPCIC schedule, and OPEX compared to past conventional bespoke FLNG designs and project execution methods.
Using a standardized design approach on both FLNG topside and Hull, this new FLNG concept will provide standardized design of liquefaction and process modules with flexible and standardized hull forms and cargo containment systems. This FLNG concept can be deployed around world near shore or offshore with Jetty or Single Point Mooring, such as SSY or an External Turret. The standardization approach enables reduction in the EPCIC cost and schedule so that it becomes a more attractive solution for Gas Monetization.
The paper will describe:
➢ Topside Modularization is based on functionality and Standardized design for easy integration and assembly for various sizes of production capacity and pre-process requirements. ➢ Environmentally friendly approach using highly efficient SMR technology employing aero-derivative gas turbine utilizing waste heat recovery to lower the carbon dioxide footprint. ➢ Patented turbo-expander based NGL recovery process and feed gas booster can provide flexibility in a range of deployment scenarios with standardized design of refrigeration and liquefaction modules. ➢ Embedded Advanced Control (WACTM) with ICSS can significantly reduce the number of operators on board and ultimately achieve unmanned operation. ➢ Proven robust SPB cargo containment system with standardized tank design provides storage for both LNG and LPG that fits standardized hull dimensions. ➢ EPCIC project execution by a single contractor on topside, hull, construction, integration, pre-commissioning, and gas trials to reduce interface, save cost and shorten schedule ➢ Completion of gas trials at LNG terminal before transportation to reduce the cost and risk of onsite commissioning issues.
This new FLNG concept can be applied to a capacity range from 1 MTPA to 4 MTPA with different combination of standardized functional plug-in modules. It can be optimized to accommodate feed gas range from associated to non-associated gas streams, and can be deployed either offshore or near-shore with a standardized hull design adapted for different mooring systems. This new FLNG concept can greatly reduce the risks with project execution and overall schedule, thus providing an ideal solution for Offshore Gas Monetization.