bluuebunny/crossref_metadata_2025_split huggingface dataset:
Mud-Gas Separator Analysis: A Comprehensive Review of Sizing, Design Criteria, and Industry Standards
Authors: Tetteh D. A. , Salehi S. , Ghalambor A. , Konate N. 
Published: February 2024

Abstract
The Mud-Gas Separator (MGS) is a critical component in well control for handling gas kicks. It is the primary device for separating liquid-gas mixtures in most well control events. Poor separator designs and inefficient separation of gases from liquids in the MGS have resulted in the loss of lives and equipment and adverse environmental effects. Thus, the safe and efficient separation of gases from gas-cut drilling fluids in the MGS is vital. The design and operational efficiency of the MGS depend on certain key elements in its sizing, such as the vent line length and diameter, vessel internal diameter, hydrostatic head of the mud seal, and the vent line back pressure, amongst others. These design considerations and the industrial standards and regulations governing them are hitherto not fully understood. As a result, there is an associated risk in the operation of the MGS.
This paper aims to comprehensively review and analyze key sizing and design considerations for the Mud Gas Separator for both Conventional and Managed Pressure Drilling Operations. Furthermore, industry standards, best practices, guidelines, and regulations on MGS design and operations are also reviewed.
This study uses two primary methodologies: an extensive literature review and a stakeholder engagement consultation to meet the stipulated objectives. The results indicate that the sizing and design of MGS depend on various factors such as well depth, pressure and temperature regimes, formation fluid, and completion fluid systems. The study's outcomes also indicate that existing industry standards and regulations provide sufficient guidelines for various sizing and design considerations. The study also presents an analysis of existing industry recommendations on MGS design and sizing for special wellbore conditions, formation properties, and unconventional drilling applications like managed pressure drilling (MPD).
The study provides further understanding of the MGS sizing and design from industry stakeholders’ perspective to minimize well-control risks associated with MGS.
Raising the Bar: Why an Industrial Standard for Testing Hydraulic Sealability of Well Abandonment Materials in Laboratory is Essential for Well Integrity
Authors: Skorpa R. , Opedal N. , Khalifeh M. , Moreira P. 
Published: February 2024

Abstract
Advances in the properties of OPC and new materials (i.e., mechanical strength, rheological properties, etc.) have shifted the R&D focus towards sealing capability of plugging materials at interfaces between the material and its adjacent medium. The objective of this paper is to outline the importance of new standards for studying hydraulic sealability of barrier materials, with emphasis on interface analysis. This work reviews different procedures used to study hydraulic sealability of barrier materials. Reviewing current standards and procedures for testing and qualifying zonal isolation materials indicates that the focus is mainly on the bulk properties of cement, such as expansion/shrinkage, permeability, and mechanical strength. The benefits of these standards are to provide reproducible results, consistent testing procedures and prevent misunderstandings about behavior of hardened cement in laboratory and field operations. However, interfaces are complex and cannot be tested with current standards, meaning that mechanical properties alone cannot indicate hydraulic sealability. The review process also includes non-setting materials further indicating the need for updated standards.
Per today, there is published work on sealability testing on the barrier material interfaces, either towards the surrounding rock or towards the casing. This is of particular importance due to more emerging well types such as CCS, hydrogen storage, geothermal wells, and purpose based well integrity and plug and abandonment. A thorough review of sealability test setups indicates that different research groups have designed setups with similar features, but with variations on scale dimensions, testing protocol and so on. This, in combination with the availability of modern measurement technologies, offers the possibility of enhanced understanding of barrier sealability. As no standards currently describe a uniform testing procedure, direct comparison of results is thus inaccurate, putting the reproducibility and reliability of analyses at risk. Our observation shows that possible considerations for standardization include understanding the effect of dimensional scales, the sequence in the procedure, the duration of testing, the type of casing steel or rock, and the type of invasion fluid besides the amount of released heat of setting material. Therefore, it is highly beneficial that current standards are updated to include sealability analysis, and updates for new and alternative materials, such as geopolymers, settled barite, and metal alloys.
Computational Design of an Optimal Landing String Profile for Operations in Harsh Environments
Authors: Abnave Vivek , Shenoy Mahesh 
Published: February 2024

Abstract
The subsea test tree is a singular subsea safety solution for well test and cleanup operations from any floating rig. The test tree provides wellbore access, dual-barrier well control, and a reliable, fast-acting means to shut in a well and disconnect, in the event of an emergency. Currently, the ability to run and operate the string is severely dependent on the weather conditions due to its influence on the riser flex joint angles. Therefore, the maximum allowable flex joint angle places severe limitations on the weather operating windows. This study outlines the use of computational analysis to formulate the design changes that are needed to extend the current capabilities of the latch mechanism that secures the landing string inside the Blow Out Preventer (BOP). Simulations are conducted using a design of experiments methodology to enhance the asset’s bending ratings. A parametric analysis is conducted and components with geometric features that can potentially impede the sliding motion of the landing string, such as the latch skirt are explicitly modeled.
The finite element analysis (FEA) technique is used to identify the critical components, which can be further optimized to determine the geometric profile, which eventually ensures that the string passes through the riser flex joint without shouldering out at the BOP annular pockets with minimal push or pull force. The study extends the capability of the Subsea Landing String for use with higher flex joint angles and establishes the structural and functional load limits for the different operational scenarios. The solution highlights the importance of using computations in design as a viable alternative to expensive and time consuming experiments, especially when solving complex problems.
The New Era of Deep-Water Drilling Through Integrated Automation Technologies: A Gulf of Mexico Case Study
Authors: Lazzari A. , Iolli F. , Leo G. , Bianchi L. , Sharma N. , Guglielmo C. , Yost T. , Ferrari F. 
Published: February 2024

Abstract
In today's ever-changing and competitive environment, oil and gas industry is quickly moving towards integrated technologies as a founding pillar of any business strategy able to meet the trilemma of the growing energy demand together with the need of an equitable supply and its environmental sustainability.
Deep water drilling technologies are universally recognized among the front runner along this road map, coming from a long journey of trials and errors and capable only in the recent years to move close to the full potential made by the integration, completely machine controlled, of multiple rig equipment.
This paper describes one among the first experience made in the industry of such process control automation set up on the 7th generation drilling ship Saipem Santorini in Gulf of Mexico over the years 2022 and 2023.
Results achieved clearly demonstrate a tangible enhancement of the work safety, as the human/machine interface is lowered by near the 50% along the whole well construction process, as well as the drilling and completion performance went beyond the 10% of global well time reduction, just as a starting point.
This first experience has been documented over a collaborative one-year period through advanced KPI monitoring and systematic approach used for installation, training, remote support and data analytics that illustrates a proven path to success which is going to be reiterated soon up to a level of a new standard for deep water drilling.
Addressing the Energy Trilemma: Offshore Drilling Rig Decarbonization
Authors: Falck F. 
Published: February 2024

Abstract
Offshore drilling rigs play a crucial role in global energy production, particularly in the extraction of oil and gas resources. However, the industry's environmental impact has raised concerns about the need for energy efficiency and decarbonization in offshore operations. This paper aims to explore the challenges and opportunities associated with improving energy efficiency and decarbonizing offshore drilling rigs.
The first part of the paper provides an overview of the Energy Trilemma (Sustainability, Security and Equity) followed by an introduction on the importance of data collection and analysis necessary to monitor energy consumption patterns and carbon emissions associated with offshore drilling rigs. It highlights the significant energy requirements for drilling and mobilization activities along with the corresponding greenhouse gas emissions. These emissions contribute to climate change and environmental degradation, necessitating clear actions for reducing carbon footprints.
The paper highlights the economic and environmental benefits associated with energy efficiency and decarbonization efforts. It emphasizes the potential cost savings resulting from reduced energy consumption and the avoidance of carbon-related taxes or penalties. Furthermore, it reviews a 360-degree approach to Offshore Drilling Rig Decarbonization embedding it into operations, operator-contractor engagements, and technical advances. It also emphasizes the positive impact of such initiatives on reducing greenhouse gas emissions, promoting sustainability, and improving the industry's environmental stewardship.
Next, the paper discusses the potential strategies for enhancing energy efficiency on offshore drilling rigs. It examines advancements in optimized rig design, energy efficiency upgrades, energy storage systems and sustainable behavior enhancements. Additionally, it explores the adoption of low-carbon fuels and electrification of offshore rigs. The proven and expected benefits, challenges, and implementation considerations of these strategies are examined.
In conclusion, achieving energy efficiency and decarbonization on offshore drilling rigs is essential for addressing the Energy Trilemma while it is necessary that the drilling contractor and operator work closely together in operating the business in a way that meets economic, social, and environmental needs of the present without compromising the ability of future generations to meet their own needs. By embracing innovative technologies, optimizing operations, and transitioning towards cleaner energy sources, offshore drilling rigs can significantly reduce their carbon footprints while ensuring a sustainable and responsible future for the industry.
The Effect of Drilling Fluid Contamination on the Properties of Granite-Based Geopolymers at Elevated Temperature
Authors: Khalili P. , Khalifeh M. , Saasen A. 
Published: February 2024

Abstract
Granite-based geopolymers have shown great potential as viable and sustainable alternatives to fully replace OPC. This article shows the impact of drilling fluid contamination (both water-based and oil-based) on the rheological and mechanical properties of such a geopolymer. The mechanisms involved in contamination are also explored. The maximum contamination intake before geopolymers lose most of their strength is investigated. Optimized granite-based geopolymer is mixed with varying volumes of a typical water-based drilling fluid (5% and 10%). The resulting mixture is cured under bottom hole static temperatures (BHST) of 70℃ and 13.79 MPa pressure to simulate production casing conditions. Compressive and tensile strengths of the cured contaminated geopolymer are measured after 1, 3, and 7 days. The early strength is evaluated using the Ultrasonic Cement Analyzer (UCA). The impact of the drilling fluid on the geopolymer's microstructure is analyzed using Scanning Electron Microscopy (SEM). The results show that the geopolymer is more sensitive to the Water-Based Mud (WBM), and slurry does not develop strength after 1 day if contaminated with higher than 10% WBM. This behavior is due to geopolymerization reaction in which water remains in the system, unlike the consumption of water in OPC due to hydration. Particle sedimentation is also increased as more contamination is introduced into the geopolymer. SEM images show that after contamination with OBM, geopolymer slurry becomes an oil in water emulsion which leaves dispersed oil in pores throughout the sample after the setting phase.
Quantifying the Effect Temperature, Foam Quality and Fluid Loss Agent have on the Fluid Loss Performance of Foam Cement
Authors: Pearl W. , Padilla L. , Patterson T. 
Published: February 2024

Abstract
Foaming a cement slurry is known to reduce the fluid loss compared to that of the unfoamed base slurry (McElfresh, P. M. and Boncan, G, 1982). This study looks to quantify the effect other parameters such as fluid loss additive concentration, fluid loss additive type (ie: film former, particle bridging or water viscosifier), foam quality and temperature have on the foamed fluid loss performance.
Base foam cement slurries were designed with in the density range of 16.6-16.8 ppg. Static fluid loss testing was conducted on all slurry designs without foaming. The slurries were conditioned in an HPHT consistometer at either 50, 66 or 90 °F and 6250 psi prior to conducting static fluid loss testing. Two fluid loss values for the base slurry designs were targeted (approx. 100 and 200 mL API) to quantify the effect fluid loss additive concentration has on foamed fluid loss performance. The designs were then foamed to foam qualities of 10% and 40% in a Multiple Analysis Cement System (MACS) analyzer and conditioned for 30 minutes before being transferred to a foamed fluid loss cell and tested.
The control slurry with no fluid loss additive was tested at 66 °F and foamed to a 10% and 40% foam quality. There was a significant decrease in fluid loss after foaming with an almost 86% reduction in fluid loss versus the uncontrolled blowout value obtained by the base design. In the absence of fluid loss additive in the slurry, the fluid loss values showed improvement with increasing foam quality. The slurries containing a fluid loss additive showed the same reduction in fluid loss once foamed but didn’t show a significant change in fluid loss between the 10% foam quality to the 40% foam quality. The trend was the same for the slurries that started with an approximately 200 mL and 100 mL fluid loss. Both saw reductions when foaming but no significant change between foam quality values. An increase in slurry temperature generally produced lower fluid loss values once foamed.
Foamed fluid loss was performed and compared between slurries with and without a fluid loss additive present. Some of the slurries with fluid loss additives didn’t have fluid loss performance that correlated to foam quality. Two of the tested fluid loss additives showed a strong synergy with foaming to reduce the fluid loss. In comparison, the slurry without any fluid loss additives had fluid loss performance directly correlated to foam quality presenting some operational complexity.
Enhancing Well Integrity: Spectral Acoustic Diagnosis and Biomineralization Remediation in the United States
Authors: Volkov Maxim , Griffin John , Avilez Samuel , Binde Hayden 
Published: February 2024

Effective management of asset retirement obligations is a paramount objective for operators in the oil and gas industry. As the industry undergoes significant shifts in focus towards environmental sustainability and regulatory compliance, ensuring the efficient and thorough decommissioning of wells and the permanent sealing of potential reservoirs during plug and abandonment (P&A) procedures has become imperative. Operators seek additional assurances both before and during the P&A process to confirm the integrity of cement barriers and plugs, as well as the overall effectiveness of containment measures. (G. Ishmukhametova,2017)
In the pursuit of achieving long-term integrity in well abandonment while optimizing the utilization of limited rig resources, operators must grasp the intricacies of potential flow paths. This knowledge is critical for the strategic placement of the most effective barriers to prevent any future environmental or safety risks associated with well abandonment.
One of the primary challenges in well abandonment is the possibility of annulus pressure or fluid flow at the surface resulting from barrier failures. While surface diagnostic techniques such as flow checks and gas or fluid sampling can provide valuable insights into the origins of leaks, they often fall short in precisely identifying the source and leak path with complete certainty. In most cases, this ambiguity hampers traditional methods for re-establishing cement barriers, such as cement squeezing, section milling, or casing expansion.
Use of Operational Standard Practices to Generate Standardized Digital Well Programs and Work Instructions in Program Builder and Rig Site Execution Delivers More Competitive Wells
Authors: Jallorina J. , Ogbunamiri E. , Zimpfer D. , Sorensen C. , Myre J. 
Published: February 2024

Abstract
Standardizing well plans by utilizing Standard Practices (SPs) in the digital tools Program Builder (PrB) and Rig Site Execution (RSE) increases the competitiveness of wells operations. The process improves collaboration both within operators and with vendors, enables digitalization of data and workflows, and accelerates experiential learnings to produce more predictable outcomes. SPs are phase- or task-level operational procedures written by Franchise (Standardization) Engineers that are rig, well, and vendor agnostic which are made up of activities with operations codes, checks, and steps. SPs are categorized by Preliminary Well Designs (PWDs), and the Well Planning Report allows for definition of the sequence of SPs required for the operational plan given the PWD assigned to the well.
Once the program is initiated in PrB, the Engineer can add well, vendor, and rig specific details to the operational plan which was auto generated from SPs. The Engineer invites other collaborators, whether within the same company or a third-party, into the tool to contribute. When the draft program is ready, a review process is facilitated within PrB, and the program is assured. Next, the operational plan becomes the foundation of the work instructions, which the Supervisor owns. They enrich the program to transform it into a worksite-ready document for the wellsite staff. All edits made to the SPs are captured and become the basis of a feedback loop to continuously improve SPs. These performance improvements will naturally cascade through wells globally.
Use of Program Builder has already been demonstrated in Operations. The program was created by the Design Engineer within three weeks and was deployed to the worksite. Initial feedback from the field was strong, resulting in the decision to continue the process through work instructions. The tool was found to improve operational efficiency and drive full transparency between the office and the worksite.
Standardizing and simplifying programs reduces the administrative burden on the Engineer, allowing them to focus on higher-value aspects of the planning, and presents a single source of truth for the entire well execution process. Deriving the work instructions from the program ensures that the procedural guidance defined by Franchise through SPs is followed all the way to the worksite, leading to predictable outcomes and competitive well delivery.
Drilling Evolution in the Top Section Offshore Arabian Gulf
Authors: Kuravskiy D. , Alabi A. 
Published: February 2024

Abstract
This paper examines the progression of drilling performance in the top sections of offshore wells within the Arab Gulf region. Emphasis is placed on the evolution of well trajectory design, drill bit selection, directional bottomhole assembly (BHA) configurations, mud systems, and the application of advanced drilling optimization techniques. In the offshore fields under study, the top section typically involves drilling through formations at a range of depths with moderate inclinations. Despite the relatively straightforward technological requirements, such as using motor BHA in combination with rock bits and sea water as the base fluid, this section presents significant operational challenges.
Drilling Evolution in the Top Section Offshore Arabian Gulf
The initial drilling approach in these wells, characterized by frequent total losses and execution complications, led to considerable inefficiencies. Key challenges included dealing with anti-collision risks, managing complex geophysical dynamics, and addressing issues arising from soft formation drilling, such as lack of directional control and frequent stuck pipe incidents. The use of sea water as a mud system added to these complications, particularly in deeper sections where its inability to effectively transport cuttings increased the risk of pack-offs.
Applying Artificial Intelligence to Optimize Engine Power Demand
Authors: Trueheart L. , Koritala C. , Stopkoski C. 
Published: February 2024

Abstract
The oil and gas industry faces pressure to reduce emissions and minimize fuel consumption to decrease the carbon footprint of drilling operations. Like other players in the sector, drilling contractors have made a commitment to achieving measurable improvements that reduce greenhouse gas (GHG) emissions through the application of new technologies. The challenge is in identifying areas of operation with the greatest potential to deliver efficiency gains and finding ways to realize the reductions.
In evaluating rig operations, it became clear that optimizing engine usage has the potential to deliver considerable cost savings and at the same time improve drilling performance. Ideally, this would mean automating the process, but automating drilling processes is not straightforward. It requires in-depth knowledge of rig operations and an understanding of the interplay between the driller, who controls the drilling process, and the generators that power the rig.
One solution is to use artificial intelligence (AI) to analyze operational data to capture drilling insights that reliably predict power usage, ensuring operations can be executed as planned and that power demand never exceeds power availability. With the introduction of AI on AC drilling rigs, data monitored by the electronic drilling recorder (EDR) can be analyzed to correlate rig activities with power usage, enabling improvements in drilling efficiency and power management. Using AI changes the paradigm, making it possible to proactively forecast and deliver the correct amount of power to the rig as demand changes throughout the drilling process.
This paper delves into the application of AI and automation of the power generation system to demonstrate its impact in revolutionizing drilling operations by forecasting and delivering power needs to deliver efficient drilling programs that use less fuel, produce lower emissions, extend equipment service life, and make fewer demands on the driller and rig crew.