bluuebunny/crossref_metadata_2025_split huggingface dataset:
CO2 Pipeline Integrity Management: A Digital Twin Approach
Authors: Sun Ta Ju , Bhowmik Subrata 
Published: April 2023

Abstract
Carbon capture, utilization and storage (CCUS) has been recognized as one of the decarbonization pathways to reduce greenhouse (GHG) emissions and to achieve net zero. CO2 transportation is the key element from carbon capture to utilization such as enhanced oil recovery (EOR) or storage in existing wells. Using new or repurposed natural gas pipelines either offshore or onshore with real-time monitoring can prevent risks during transportation caused by impurities of carbon dioxide (CO2).
It is unrealistic to manufacture new CO2 pipelines due to increasing overall project cost and carbon footprint. Retrofitting existing onshore or offshore natural gas pipelines with multiple sensors for flow measurement, pressure and temperature measurement and fatigue stress measurement can not only cost-effectively reduce carbon footprint but also minimize maintenance costs through real-time risk-based inspection.
The proposed solution will conclude with a holistic assessment of structural integrity in transporting CO2 and the integration of a data-driven model of repurposed natural gas pipelines to improve pipelines integrity further.
Different impurities in the CO2 can change the flow properties during CO2 transportation. Although CO2 transportation has been deployed for several decades, the impacts of impurities in CO2 has to be better understood. Building a model with different impurities of CO2 in a digital twin has a potential influence to tackle this issue. A computational model of pipeline fatigue damage, which is affected by temperature and pressure mainly, in the pipelines is developed to predict the fatigue damage under specific circumstances. Integration of multiple sensors in the pipeline can avoid early failure and maintain it proactively. CO2 could be in liquid and gas phases in the unsaturated zone during transportation.
The proposed concept of digital twin will offer a prediction at the early stage to mitigate potential risks specific to existing natural gas pipelines for CO2 transportation from carbon capture to utilization or storage.
Isolation of North Sea Pipeline Successfully Carried Out By Resident ROV and Remote Operations from Shore
Authors: Johnsen Georg , Solbjør Kenneth , Iversen Arve , Rouge Nick , Alsvik Hallgeir Foss , Anderson Gary , Craig Stephanie 
Published: April 2023

Abstract
Pipeline isolation tools have long been used in decommissioning activities where continued production in connected pipeline sections is required. To reliably execute an isolation program, robust communication systems are required to load the isolation tool, track, activate and deactivate it, and monitor the tool during the isolation process. Historically, that has meant hard wiring or acoustically linking to the offshore platform or vessel.
Typical subsea pipeline isolation projects are performed and supported by an ROV or diving vessel; however, advances in communication technology have changed that paradigm. Robust LTE and VSAT connectivity enable robust, dependable communications that support remote operations. Today, it is possible to execute the same types of pipeline isolation programs from globally located, onshore remote operations centers. Combining advanced pipeline isolation technologies with remotely operated resident ROV systems can transform operations by eliminating the need for costly vessel support and reduce the number of people required offshore.
A recent pipeline isolation program used for the first time on Equinor's Veslefrikk Field in the Norwegian North Sea employed leading isolation technology and a resident, battery-powered, electric work-class ROV system remotely operated from shore, demonstrating that there is now a viable option to using an ROV or diving vessel for these types of subsea operations.
This approach allowed key personnel to work as an interconnected team from an onshore base where they collaborated, controlled, and watched live operations rather than mobilizing offshore, enabling cost savings, reducing HSE risk, and increasing collaboration. By using the onshore remote operations center, the project team was able to ensure a successful campaign.
The project was completed as planned, demonstrating not only the feasibility but the value and repeatability of this approach to pipeline isolation.
Recovery from Extended Unplanned Shutdown – A Flow Assurance Perspective
Authors: Hernandez Oris Cristina , Mohikar Akshay , Hudson Ian 
Published: April 2023

Abstract
The formation of a hydrate blockage in a flowline is one of the highest flow assurance risks to oil and gas production, particularly in deepwater systems. The financial consequence of having to remediate a hydrate blockage in a subsea flowline can amount to tens of millions of dollars in intervention costs and deferred production. To manage this risk, subsea fields in deepwater are usually designed and operated with multiple barriers in place to prevent hydrate blockage formation. These barriers include a combination of insulation, dead oil circulation to displace hydrate forming components out of the subsea system, depressurization, active heating and/or the deployment of hydrate inhibitors. For systems that operate outside of the hydrate conditions during steady state, these barriers are ideally required to perform before the system enters the hydrate region (cooldown time) and hydrate formation starts to occur.
During unplanned shutdowns, operators have a limited amount of time to deploy these barriers or restart the field. A large percentage of unplanned shutdowns are relatively short, and it is typical to be able to restart the field before the cooldown time expires. This paper will focus on the learnings from bp's experience in recovering from extended unplanned shutdowns where hydrate prevention activities could not be performed, i.e., the system cools down to ambient conditions and the hydrate prevention barriers were not applied. The overall philosophy and key considerations for a successful recovery from such a situation are discussed.
Integration of Petroleum Technologies for the Economic Monetization of Small Offshore Fields
Authors: Yan Lai Wai , Gupta Mukesh , Tajuddin Nazim Musani , M Diah M Amri B , Shah Jamari M , Masoudi Rahim , Mokhtar Syahrini Bt 
Published: April 2023

Abstract
This paper entails the profitable development of an offshore small oil reservoir. Offshore technologies are expensive and require higher capital expenditures (CAPEX) and operating expenses (OPEX) due to the need for advanced technologies for drilling, production, and environmental protection. Generally, reservoirs with large reserves are considered for large capital investments. However, this paper demonstrates how accurate reservoir description in conjunction with advanced offshore technologies can help to develop small offshore fields economically. These technologies are deployed in an integrated manner (surface and subsurface) to develop such fields. Offshore logistics for production facility maintenance increases the OPEX due to the transportation of personnel and equipment to and from the site. Offshore production systems have higher CAPEX due to specialised offshore equipment, including sub-sea equipment. Other than higher costs, the oil price volatility makes it difficult to plan for long-term production to recover the cost. Therefore, offshore fields have several challenges, e.g., logistical, technical, environmental, economic, and safety. However, collaborations and partnerships between industry and government help to share the project's economic risk. Cost can be further reduced through new development, production, and reservoir characterisation technologies to manage offshore development and operations costs. Production is enhanced through advancement in well construction and production systems to support high OPEX of floating production, storage, and offloading system.
Managing the High Temperature Risk in a Horizontal HPHT Deepwater Well
Authors: Liu Yu , Griffith Steve , Ain Fitz Mathew , Palacio Julio , Tchagop Alfred , Lasher Dana , Champion Brett 
Published: April 2023

Abstract

Objectives/Scope
The bottom hole circulating temperature of horizontal wells can be higher than those of vertical wells. That risk is compounded in HPHT slim-hole applications where static geothermal temp can reach 320°-350° F. The combination of horizontal wellbore geometry, HPHT conditions, and slim-hole design results in significant challenges to achieving the primary objectives of drilling and data acquisition. This paper describes a technical workflow established through collaboration between the operator and service providers to manage high temperature risks to ALARP (As Low As Reasonably Possible) with effective design optimizations.

Methods, Procedures, Process
The workflow consists of risk assessment, offset data analysis, HT (high temperature) model calibration, model-based sensitivity analysis, and design optimization on BHA, hole size, and parameters. Multiple modelling software are used to support this physics-based design approach.

Results, Observations, Conclusions
The established workflow identified a set of effective risk mitigations through bottom hole assembly (BHA) redesign, hole size change, drilling parameter adjustment, and a decision-based TD criterion. The previously identified HT risks are reduced to ALARP and can be managed during execution.

Novel/Additive Information
The target well will be the first horizontal HPHT deepwater well to be drilled in GOM deepwater. The workflow described in this paper can help reinforce the physics-based design optimizations, and avoid HT related damages to critical downhole tools with limited supply and long replacement lead times due to current market constraints.
Pushing the Limits in Deep Water Data Acquisition for Accelerated Field Development: Industry Record Batch Well Testing
Authors: Karacali Ozgur , Ramcharan Narindra , Sahadeo Lorenzo , Holub Chase , Julien Jenilee , Sunarto Hadantha , Tong Songyang 
Published: April 2023

Abstract
This paper presents a dynamic deepwater well testing solution that was developed to execute consecutive well tests on multiple reservoirs of various parameters and complexities and describes the design, planning, application, and benefits of the batch well testing package. Batch well testing has the potential to optimize well testing operations, improve equipment utilization, reduce operator costs, and obtain significant amounts of dynamic reservoir data quickly for field development and facility design.
Esso Exploration and Production Guyana Limited (EEPGL), ExxonMobil's Guyana affiliate, and its co-venturers had a challenging objective to complete several deepwater development projects at an accelerated pace in the Stabroek block of Guyana, which required the acquisition of an extensive amount of dynamic reservoir data and representative fluid samples. The data and reservoir samples were required to inform creation of field development plans and to drive a fit-for-purpose floating, production, storage, and offloading vessel (FPSO) and topside designs. This led to an extensive well test program utilizing existing predrilled appraisal wells that were conditioned and prepared for well testing. This was enhanced by a dedicated drillship equipped with a surface well test package to test all commercial discoveries consecutively.
Extensive laboratory tests were performed on reservoir samples collected during wireline sampling to help determine operating parameters for each well test and identify mitigation measures to be employed, alleviating potential flow assurance risks such as wax deposition, asphaltene breakout, and hydrates. The reservoir fluid studies conducted on the wireline samples also helped to create specific fluid identifications for the multiphase meter to increase accuracy of flow rates and fluid composition during well testing. The surface well testing package installed on the rig was optimized to efficiently process a range of fluid types form high gas-oil ratio oil to black oil wells with high flow rates. Testing multiple deepwater wells successively involved precise planning and a robust maintenance plan between wells. A dedicated rig for batch well testing resulted in significant cost synergies for the operator, enabled precise planning, streamlined onshore and offshore maintenance, and assisted supply chain management to ensure equipment availability and performance reliability for the continuous program.
This paper highlights the industry record implementation of a batch well testing program, an industry first in this operating environment, that was designed to be executed for seven wells and that enabled the delivery of high-quality reservoir data from multiple differentiated deepwater reservoirs quickly in support of the operator's potential growth plans. The program was completed with zero spills to the environment.
Magnetic Mud Shielding Effects on Measurement-While-Drilling Azimuth Survey Acceptance Tolerance at Low Latitudes: A Case Study, Malaysia
Authors: Kok Keng Hung , Jen Andrew , Tipdontree Poppoom 
Published: April 2023

Abstract
Synthetic oil base drilling muds are re-cycled for cost efficiency and to minimize environmental effects. Invariably, very fine micro-sized magnetic or paramagnetic material from drill-string and casing wear accumulates in the drilling mud over time and cause significant shielding effect on the downhole cross-axial magnetometer sensors. This case study explores various mitigating methods to acquire Measurement-While-Drilling (MWD) surveys within acceptance tolerances and where possible, to define minimum wellbore uncertainties levels depending on the wellbore trajectory relative to earth's magnetics especially at lower latitudes.
Learnings from the Standardization of Quality Procurement Specifications
Authors: Reed Michele , Harris David Antony 
Published: April 2023

Abstract
Operators and Engineering, Procurement and Construction contractors (EPCs) have traditionally had their own quality requirements for the same products offered by the same manufacturers causing increased complexity, delivery and costs to each purchaser. Through IOGP JIP33 (International Oil and Gas Producers, Joint Industry Programme), industry-level standardized product requirements are being implemented to improve capital efficiency through industry-wide standardization. This paper discusses the learnings and challenges of deploying the standardization of specifically the Quality Requirements Specification (QRS) through the various operators who participate in IOGP and how this impacts digitization of quality requirements.
JIP33 standardized procurement specifications are developed by product Subject Matter Experts and contain standardized Technical Requirement Specifications (TRS), Quality Requirements, Information Requirements and Procurement Data Sheet. The Quality Requirements Specification (QRS) provides standardized quality interventions and defines the purchaser's involvement based on the purchaser's criticality rating. All JIP33 specifications are free to use by any organization. With over 50 product and support specifications published and with 5 years of implementation, the JIP33 Quality Network now provides implementation guides and training materials to share learnings and help companies implement the QRS.
In March 2022, the JIP33 Sponsoring companies conducted a survey which found that 43% of published quality specifications were implemented even though the technical specifications were over 60% implemented. This led to further review to determine the challenges of implementing standardized quality requirements for products. The results indicated a few common challenges including: Differences in procurement processes and responsible parties (procurement vs engineering) across the industry.Lack of understanding on how the QRS impacts the Inspection and Test PlanInterface with pre-established Global Frame Agreements.Lack of familiarity with JIP33 and QRS documents
Each of these challenges requires a planned management of change as well as a cultural and behavioral transformation from previous procurement practices to implement with the various functions supporting the procurement and quality processes. A QRS implementation guide was developed to address such challenges and offers solutions and ways of working to facilitate implementation.
Standardizing technical requirements on a product is not necessarily a ground breaking or novel concept but including both standardized quality and information requirements that are aligned together is new to the industry. Since standardized quality and information requirements would be integrated into existing business systems, and especially in a digital context, implementing standardized aligned quality and information requirements requires change management across multiple functions.
Mackenzie Delta LNG Transport and Ice Management Study
Authors: Salminen Jukka , Hindley Rob , Saarinen Sami 
Published: April 2023

Abstract
This paper will study the LNG Transport opportunities from the Canadian Arctic to the Asian markets.
Mackenzie Delta LNG (MDLNG) project is in the Canada's Northwest Territories (NWT) which contains publicly owned conventional natural gas reserves which could be developed for export that would provide immediate economic benefit to the Inuvialuit Settlement Region, NWT and Canada.
This paper presents the results of a feasibility study undertaken to evaluate the shipping routes and ice conditions along the route from the Arctic to the Asian LNG markets. Arctic LNG carriers have been in use in the Russian Arctic for years already and we have been deeply involved in the design, development, and testing of those current LNG carriers. Russian rules are somewhat different and thus the operations would commence in Canada and US waters that would give some opportunities in the LNG Carrier design as well. In this paper we will go through the general differences in the LNG carriers design for MDLNG. Currently the plan is to build gravity-based structure (GBS) to the offshore MacKenzie Delta. The GBS would need additional ice management support and vessels. In this paper we would talk about ice management vessels needed to support the operations for loading the LNG carriers as well as talk about the recommended ice management operations.
With modern technology, good design and planning, it can be shown that the LNG transportation by ships is a feasible solution compared to building pipelines across the Arctic.
Machine Learning Based FPSO Topsides Weight Estimation for a Project on an Early Stage
Authors: Yao Changqing , Ren Xiang , Valiveti Dakshina , Ryu Sam , Chaney Carmela , Zeng Yifei 
Published: April 2023

Abstract
The objective of this study is to develop a data-driven machine learning based tool to estimate the FPSO topsides weight. The data were collected from public sources including IHS, news and magazines, covering world-wide active FPSO geographic locations, topsides weights, and their production throughput. One of the challenges is that the size of the dataset is less than 200 data points, largely due to the limited total number of FPSOs worldwide. Another challenge is that there are missing values for gas production, as such, imputation of missing values becomes necessary. In this study, data imputation was conducted by incorporating geographic information and physics guided feature engineering, through which the imputation is more accurate compared to simple imputers. For machine learning algorithms, polynomial regression was first evaluated as the baseline model and various machine learning models were built and compared with the baseline, such as Gaussian process regressor, random forest, neural network, and natural gradient boosting, with the purpose of identifying the most accurate one. To solve the overfitting issue caused by the small size of the dataset, several strategies have been investigated and compared, such as k-fold cross validation, regularization and extensive hyper-parameter tuning via Bayesian optimization algorithm based on the Hyperopt library.
Among all the machine learning models, it is found that the natural gradient boosting method is the best performer with a mean absolute percentage error (MAPE) of 24% on the blind testing data, which is 35% lower than the baseline model. Shapley Additive exPlanations (SHAP) analysis was also implemented for model interpretation and gas production was found to be the most influential feature. The trained gradient boosting model was deployed to an internal web application in which users could get a quick estimation of FPSO topsides weight by providing three features: gas production, oil production and water depth. The 2D and 3D cross plots with historic data and predicted value are also provided in the web-app for better results visualizations.
The novelty of this paper is to develop a data-driven machine learning tool for FPSO topsides weight estimation on an early stage of a project, which can serve as an independent alternative to the traditional empirical based approaches to help pre-design the facilities and estimate the cost. In the back-end, the best machine learning model was identified, along with the best imputation strategy based on a physics guided feature engineering approach. In the front-end, a web application was developed for an interactive estimation of FPSO topsides weight. With continuous enrichment and validation of the collected data, the machine learning approach can serve as a trustworthy fast and early estimation for FPSO topsides weight.
Overcoming the Challenges and Complexities of Maintaining the Integrity of Subsea Infrastructure in Cook Inlet, Alaska
Authors: Kidwell Rachel B. , Bacher Tasha M. 
Published: April 2023

Abstract
Legal Notice: Any use of trade, product, methods, terminology (lingo, etc.) or firm names are for descriptive purposes only and do not imply endorsement by that company, Hilcorp Alaska, LLC, or any of its affiliates or parent company.

Objectives/Scope
The objectives of this paper are to highlight the following:
The complexities of managing and maintaining a fleet of aging offshore infrastructure in Cook Inlet, Alaska, using conventional and unconventional methods. The continued search for innovative solutions and refining current processes to extend the life of these facilities. Once the facilities have reached the end of their producing life, retrofit for other potential useful opportunities such as capitalizing on the renewable resource possibilities Cook Inlet possesses.

Methods, Procedures, Process

Results, Observations, Conclusions
Cook Inlet, Alaska is the state's main industrial water way and home to 15 offshore production platforms owned and operated by Hilcorp Alaska. Operating in the Cook Inlet is extremely complex and difficult because of its unique environment.
Many of those 15 platforms were installed in the 1960's and originally thought to have short life expectancy. Over 60 years later, due to regular inspections and repairs guided by API 2 SIM, most of the facilities are still producing.
Many typical forms of inspections and repairs cannot be conducted in Cook Inlet. Operators, inspectors, contractors, and divers must get creative to overcome many hurdles to achieve the tasks necessary for operation and structural integrity.
When platforms go through the P&A process, the threat of environmental hydrocarbon pollution is removed. Hilcorp is currently looking into renewable resource opportunities for these structures to further achieve its goal of extending the useful opportunities of these facilities, given their robust infrastructure.

Additive Industry Information
This paper details the continuing challenges and constant search for new technologies. The hope is to educate the industry on the specific resources and technology that is needed in Cook Inlet and sharing the unconventional methods that have been developed over the years.
This paper does not discuss downhole operations.