bluuebunny/crossref_metadata_2025_split huggingface dataset:
API Pipeline Safety Management Systems: Assessments Updates and Contractor Safety Programs
Authors: Frazier C. M. , Knape L. A. 
Published: October 2023

Abstract
The API Pipeline Safety Management System (Pipeline SMS) Assessment Program continues to provide a not-for-profit industry-accredited option for pipeline operators to assess their safety management system. In addition to assessments and gauging Pipeline SMS maturity, the Pipeline SMS Industry Team has also worked to produce guidance to help operators and contractors/service providers understand and align their safety programs. Here, API will review key assessment findings to date as well as highlight the tools we have created for contractors/service providers to implement Pipeline SMS.
The API Pipeline SMS Assessment Program has conducted assessments at 17 pipeline operators in North America, representing small and large operators in both the liquid and gas product businesses. In March 2023, API updated its benchmarking database and analyzed it to verify if previous trends continued and if we have seen improvements in lower scoring areas. Trends and themes will be discussed, as well as API's work to assist industry in these areas.
Positively, pipeline operators around North America have acknowledged the need to leadership to embody safety values and make those values evident to their employees and contractors. In addition, and in alignment with leadership presence, safety culture of front-line staff continues to be one of the highest scoring areas. Another area of positive feedback from benchmarking is with emergency preparedness and response, with most sites receiving very high marks for this management system element.
However, some areas require more focus. In North America, operators are required to make external stakeholders (e.g., the government, the public, those with land that abuts the pipeline right-of-way, police, emergency services, etc.) aware of their operations and safety efforts, and provide them a mechanism to give operators feedback; this is an area where API has seen lower scoring. However, in the past year, API has seen improvements to the maturity performance in this area.
One theme is that many operators voice concern over management of contractor/service provider safety programs. This led API to create a Pipeline SMS Contractor Guide, as well as contractor implementation tools to help implement and gauge maturity of safety programs. Both the Guide and the Tools are available free of charge on www.pipelinesms.org and will be demonstrated here.
Pipeline SMS and API RP 1173 support the API Energy Excellence® Program, a program that helps operators implement overarching management systems through thirteen (13) elements in support of operational excellence across all segments of operations. There are few, if any, published guidance documents on a management system framework that can be applied to all segments. In addition, the contractor materials add to the suite of materials aiding industry in operational excellence.
Phase Behaviour and Physical Properties of Dimethyl Ether (DME)/CO2/N2/Water/Heavy Oil Systems Under Reservoir Conditions
Authors: Li Yunlong , Huang Desheng , Dong Xiaomeng , Yang Daoyong 
Published: October 2023

Abstract
The application of a mixture of dimethyl ether (DME) and flue gas is a promising method to recover heavy oil as DME is first-contact miscible with hydrocarbons and partially miscible with water, CO2 can accelerate mass transfer, and N2 can boost the energy in a depleted heavy oil reservoir; however, phase behaviour and physical properties of DME/CO2/N2/water/heavy oil systems are still not well quantified. In this study, theoretical and experimental techniques are developed to determine phase behaviour and physical properties of the aforementioned systems at pressures ranging from 2 MPa to 20 MPa and temperatures spanning from 352.15 K to 433.15 K. In addition to collecting experimental data from the public domain, eight constant composition expansion (CCE) tests are carried out. A thermodynamic model that incorporated the Peng-Robinson equation of state (PR EOS), a modified alpha function, the Péneloux volume-translation strategy, and the Huron-Vidal (HV) mixing rule is used to reproduce the measured phase equilibria data. The tuned binary interaction parameters (BIPs) are utilized in conjunction with the thermodynamic model to accurately predict saturation pressure (Psat) and swelling factor (SFs) with a root-mean-squared relative error (RMSRE) of 3.32% and 0.57%, respectively. Furthermore, the recently proposed model demonstrates its high accuracy in forecasting the oleic/vapor (LV) two-phase boundaries for N2/heavy oil systems and DME/CO2/heavy oil systems with an RMSRE of 1.93% and 2.77%, respectively. Similarly, the accuracies of the predicted aqueous/oleic/vapor (ALV) three-phase boundaries for N2/water/heavy oil systems and DME/CO2/water/heavy oil systems are 2.85% and 3.47%, respectively. Besides, water is found to increase the phase boundaries for DME/CO2/heavy oil systems but decrease those of N2/heavy oil systems and DME/CO2/N2/heavy oil systems. Additionally, as the concentration of N2 and CO2 in the feed mixture is increased, its Psat is increased. In this work, new PVT experiments are conducted to evaluate the impact of adding DME/CO2/N2 into the heavy oil bulk phase in the absence and presence of water. The developed model accurately characterizes the phase boundaries and physical characteristics of the reservoir fluids containing polar components, which are essential for design, evaluation, and optimization of hybrid steam-solvent injection processes in heavy oil reservoirs.
HSURF: A New Modular Platform for Underwater Remote Semi-Autonomous Facilities Inspection
Authors: Iacoponi S. , Alhosani H. , Mankovskii N. , Infanti A. , Zhilin I. , Renda F. , Stefanini C. , De Masi G. 
Published: October 2023

Abstract
In this paper we present the H-SURF modular system, consisting of three different platforms (floater, sinker and fish), that can be used for underwater wireless telecontrolled inspection. Differently from the most common commercial approaches where tethered big ROVs are used for subsea inspection, here many small untethered semiautonomous robots are used, oriented to a robotic swarm concept. The full system allows teleoperation from a remote base station and inspection of complex subsea structures consisting of several tubes and valves, taking benefit of the collaboration among different platforms and many small and flexible robots. We show the testing results of telecontroled navigation in a very complex trajectory and a semiautonomous detailed inspection of a submersed vertical structure.
Light Weight Tomographic Monitoring of Pipe Wall Thickness
Authors: Instanes Geir , Pedersen Audun O. , Simonetti Francesco , Nagy Peter B. 
Published: October 2023

Abstract
Tomographic methods are used with ultrasonic guided wave wall thickness monitors to provide two-dimensional maps of the wall thickness throughout a monitored area. Tomographic monitoring systems are typically configured with 16 to 32 non-intrusive ultrasound transducers positioned in predetermined patterns for optimal coverage and resolution. Other monitoring systems have much fewer transducers, positioned according to the pipe geometry and wall area of main concern. Although these systems are not optimized for wall thickness mapping, the same or similar tomographic methods can improve analysis and interpretation of the datasets they produce. Algorithms are sought for implementation in responsive, interactive software for browsing and analysis of recorded wall thickness monitoring data. Simple tomographic algorithms are also desirable for use in embedded software. A "light weight" tomographic algorithm is outlined, and a prototype implementation is tested against a proven full-scale tomography software package. The two approaches produce similar results on small datasets corresponding to wall thickness monitoring systems with few transducers installed. For the larger datasets generated for high resolution wall thickness mapping, the reference software is superior in terms of both computational load and accuracy.
Successful Velocity String Deployment Pilot to Improve Productivity and Sustainable Gas Recovery for Three Sub-Optimal Completion Wells in Oman Block-61
Authors: Al Darai A. , Al Fadhli K. , Al Harrasi S. , Najwani M. A. , Raji A. , Qamar O. , Villarroel P. , Daoud S. , van der Ven B. 
Published: October 2023

Abstract
Block 61 is a gas field, located in Oman, characterized by tight reservoirs. Majority of the vertical wells in the field are completed with 4½″ to 5½″ production tubing. As wells continued to produce over time, a decline in the production was observed due to liquid loading. A Sustainable option to enhance production recovery was introduced. This involved reducing the current production tubing internal diameter (ID) and area. To accomplish this without compromising the reservoir, a velocity string (VS), using a snubbing unit, was installed for three wells in effort to determine if it's fit for purpose for full field development.
(VS) wells were chosen based on specific selection criteria, mainly focusing on wells with reservoir pressure around 4,500 psi and different performance levels, to evaluate VS completion design and capabilities under various well conditions.
Three pilot candidate wells were completed with smaller sized velocity string completion tubing in Block 61. The installation was executed through a Snubbing unit with wellhead pressure control configuration in snubbing mode, resulting in the deployment of the VS under pressure. The benefits of this well intervention method is that it eliminates the potential for hydrate formation and reservoir damage since no kill fluid is pumped in the wellbore.
The VS completion design consists of jointed chrome pipes, completion components (Sliding Sleeve Door (SSD) & Wireline Entry Guide (WEG)) and a hang-off packer.
From an operational perspective, the wells were delivered safely with minimal non-productive time (NPT) and 31% ahead of schedule. This resulted from the continuous and proactive implementation of lessons learned, which were captured during the VS installation operations.
This paper will cover the valuable lesson learned to help drive efficiency and optimization of future planned campaigns.
Moreover, post VS installation, the 3 pilot candidate wells were brought back to production. The production rates from the candidate wells showed initial positive results flowing through the VS completion as predicted during the project design and planning.
The application of the snubbing unit for bp Oman was the first successful VS installation in Block 61. This effective deployment presents an opportunity to extend the production life for over two hundred wells in Block 61 with high efficiency when intervening on these wells. The objective of this paper is to summarize the journey of installation of velocity strings in Block 61, aiming to cover aspects such as planning, design, wellbore preparation, operational execution and well performance results post installationBody text 1 paragraph.
Systematic Talent Management & Succession Planning
Authors: Taechasapasith T. , Silakorn N. 
Published: October 2023

Abstract
This paper demonstrates how systematic Succession Planning is important to PTTEP business especially when we operate over 50 petroleum exploration, development, and production projects in more than 10 countries across several regions with the primary focus on Southeast Asia and the Middle East as well as other petroleum-prolific areas displaying investment opportunities, both E&P and beyond E&P businesses. It ensures that all critical positions are occupied continuously and gains more engagement from the PTTEP talent pool.
In 2020, Succession Planning became one of the KPIs among Top Management resulting in "1st time solid Succession Planning". Career Review Committee comprises CEO and Top executives responsible for identifying, developing, and retaining talent and succession planning so we can sustain our strategy of "strengthen leadership to a sustainable organization." We partnered with a global consulting company for a talent assessment tool based on talent models and benchmarks using a nine-box grid matrix of potential together with performance and other consideration factors for talent identification. Once successors are identified, the Company designs an Individual Development Plan (IDP) which consists of a career rotation plan and development framework.
With strong support from all management, in 2021 we achieved a set of solid succession planning to support business growth with a successor ratio of more than three successors in all executive posts. Since then, PTTEP management movement and appointment have been considered systematically and even more efficiently through a practical end-to-end talent management process, starting from talent assessment to identify talent and successor, and development to ensure readiness. We completed 100% of the Individual Development Plan (IDP) focusing on both career plans and competency gap closing for talents. By developing various development programs including accelerated programs partnering with world-class institutions and leading consulting companies, leadership training courses, mentoring programs, executive talks, and networking programs both online and offline, we got a high satisfaction score of over 80%. Impactful succession planning also saves costs from internal development and placement without high external executive hiring costs. This upcoming year, the focus is how to prepare workforces to expand to our new territories in the Beyond E&P. With the new business requirement, therefore, we plan to encourage and provide talents with more career advancement opportunities to rotate across their discipline to achieve new career goals and more challenging job opportunities to expand the successor pool in the future.
This paper shows that systematic Succession Planning benefits the company as it keeps our workforce and talent pipeline stable. Its benefits, however, are not only for PTTEP itself but could be for the PTT Group as well, as it provides a valuable resource pool among them.
Prospect Focused Imaging Through Advance Seismic Driven High-Resolution Fluid Modeling Approach
Authors: Mukherjee Jagannath , Das Debjyoti , Chakraborty Dibakar 
Published: October 2023

Abstract
Petroleum Systems Modeling is a well-known workflow to evaluate the basin potential. However, in the prospect maturation stage, we mainly focus on reservoir and trap characterization. The lack of an established workflow to quantify the risks associated with seal integrity and preferred migration, is one of the main reasons for dry wells.
This establishes an innovative workflow and explores the value of coupling the regional scale insights into a prospect specific study in a field with existing discovery for exploration risk mitigation. An integrated fluid migration approach has been adopted to de-risk the prospect and predict the likely migration pathway in the petroleum system. This integrated workflow consists of detailed reservoir scale characterization using advanced seismic attributes, followed by static and dynamic migration simulation to envisage the local migration process within a high-resolution reservoir model to assess the sealing capacity of the cap rock.
A modified invasion percolation method has been used to evaluate the effect of buoyancy and capillary pressure driven hydrocarbon fluid migration in the high-resolution reservoir model and in turn, inspect the seal integrity to withhold the hydrocarbon column height. The fluid migration model was simulated with a multi-phase PVT model to estimate the hydrocarbon phase at the reservoir condition. A fluid mixing model was also built at the prospect scale to evaluate the fluid phase and composition understanding. This helped in estimating fluid distribution in the field scale in terms of phase and components of hydrocarbon. The seal integrity model involves detailed assessment of the PVT model along with wettability and interfacial tension of the rock properties for accurate prediction of the column height holding capacity. The model has been calibrated with the existing well data and production data in terms of hydrocarbon saturation and the tested fluid phase at the production well.
This novel approach can be positioned as an advanced quantification tool in prospect focused imaging where the risk parameters relating to migration and cap rock are also being evaluated without losing any information from the regional context. This new way of de-risking process can help to mitigate the potential risks associated with the petroleum systems elements to increase exploration success.
Innovative Geological Interpretation Framework for Real-Time Drilling Operations
Authors: Alohali Ruaa , Alhabib Murtadha , Alkhardawi Ibrahim , Alghamdi Yasser 
Published: October 2023

Abstract
Digitalization is rapidly transforming oil and gas industry, particularly in real-time drilling operations. Many years back, manually-drawn wellsite striplogs were mostly used to assist drilling operations. The legacy technique encountered major challenges such as data accessibility, paper-based interpretation preservation and decision-making process delays. The technologies introduced offer significant improvements where processes with digitalization help build reliable systems for wellsite operations to overcome the challenges by providing an innovative solution to monitor drilling on 24/7 basis.
The implemented solution is customized based on an in-depth analysis of exploration workflows. It empowers geologists with interactive interpretation features for casing points identification, lithology interpretation and well correlation utilizing visually-rich log templates. Furthermore, a full integration with corporate repositories and map services is established to facilitate access to drilling, geological and petrophysical data. Due to the criticality of exploration drilling operations, computing services are configured using distributed redundant systems architecture to ensure high availability.
The implementation significantly minimizes manual data entry of active wells, which enhances data quality in an efficient manner. The integration with corporate databases and key vendor applications provides a centralized hub for all wellsite geological operations and achieves improved correlation results. The utilization of the interactive GIS maps improves well location identification, spatial measurements with offset wells and reports on relevant log data availability to create geologically meaningful correlation charts. The solution enhances the overall performance by providing an efficient and streamlined access to a cutting-edge set of geological interpretation tools from rig-site utilizing satellite communication. This technology enabled the digitization of more than 5000 wells with standardized business rules to build a consolidated database for wellsite daily operations.
The introduced single hub that enables access to geological interpretation data allows geologist to generate customized reports to summarize drilling operations to executive management. Advanced data analytics features and dashboards are implemented to reveal unseen patterns of current and historical data. The comprehensive framework offers digital transformation opportunities such as formation tops prediction and drilling cutting images classification. Furthermore, mobility features will be introduced to provide reliable access anytime, anywhere to facilitate faster decision-making process.
ML Driven Integrated Approach for Perforation Interval Selection Based on Advanced Borehole Images AI Assisted Interpretation
Authors: Petrov A. , Belouahchia M. , Noufal D. 
Published: October 2023

Abstract
Carbonate reservoirs are typically naturally fractured, resulting in a complex network of fluid movement that plays a crucial role in determining their production and recovery performance. However, due to the inherent complexity and heterogeneity of these reservoirs, evaluating their recovery potential is a highly challenging task. In this study, we propose an Al-assisted workflow that utilizes machine learning techniques to identify sweet spots in carbonate reservoirs.
A supervised Deep Learning model is utilized to segment relevant features, specifically fractures, in borehole images using pixel-wise identification. Subsequently, sinusoidal fitting algorithms are employed to determine the dip and strike of each feature. The obtained dip magnitude and azimuth direction of fracture planes are analyzed using supervised machine learning techniques to identify the orientation of the three principal stress axes that caused the fracturing. Based on borehole image interpretation, a feature map is generated and employed for porosity estimation and partitioning. The reservoir connectedness index is estimated based on porosity analysis and the feature map, which is utilized as input for image-based permeability estimation. Finally, an integrated approach combining advanced borehole image interpretation and stress analysis is used to identify sweet spots based on the reservoir's rock quality and geomechanical properties for perforation.
Quantitative information extracted from BHI was utilized to identify heterogeneous zones that showed higher secondary porosity and pore connectedness. This information proved to be valuable in identifying the most productive zones and in understanding the correlations between different carbonate porosity components and well productivity data. We observed an excellent correlation between production log profile and the connectedness log derived from the borehole image, indicating that the variation in production profile is likely triggered by the textural variation in the reservoir. The pore connectedness index serves as a significant and relevant qualitative measure to predict the producibility of the reservoir and can be used to optimize the completion of future wells.
To overcome limitations in characterizing carbonate reservoirs, machine learning techniques have been used. This involves annotating geologic features using a well database, with supervision from subject matter experts. The resulting machine learning model is tested on new wells and can identify pay zones, perforation intervals, and stress analysis, including minimum and maximum horizontal stresses. The models successfully detect fractures, breakouts, bedding planes, vugs, and slippage passages with pixel-level precision, reducing BHI analysis time. Machine learning is a promising development in reservoir characterization, improving the accuracy and efficiency of analyzing carbonate reservoirs.