bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Life Cycle Carbon Footprint Calculator for Early Quantification of the Environmental Impact of Oil and Gas Services and Products
Authors: Montiel Edgar , Nachef Kinda , Marquina-Guinois Elodie , Spenley Karen , Van Kuijk Robert 
Published: October 2022

Abstract
Schlumberger has taken the lead in the oil and gas service industry by creating a footprint emissions quantification tool that balances the time investment with the accuracy required to assess the carbon footprint of technologies along their lifecycle, in order to draw comparisons and shed the light on less impactful services. As an initiative, this is intended to help with the pressing issue of greenhouse gas (GHG) emissions and how we may contribute to limit the impact of our industry on global warming.
Schlumberger's Technology Sustainability Team, with a representation from all divisions, has built a versatile lifecycle carbon emission calculator, integrating different oil and gas use-phase models. This calculator's development has entailed an in-depth understanding of the lifecycle assessment (LCA) framework as per ISO 14040, a detailed bibliography for the selection of the emission factors to be used, as well as a thorough technical understanding of the processes, equipment, and operations to develop the computation modules, and in particular the use phases models.
It is intended to be user-friendly and efficient, thus allowing even those who are not sustainability experts, to perform a carbon footprint lifecycle initial assessment of their product line or new services in their development phase.
We will present the methodology used, the learnings and the use-phase emissions computed in the context of Schlumberger services’ technology portfolio. A comparison of the carbon emissions on the full lifecycle of a product, computed with this tool versus a third party performed full LCA may also be presented to exemplify the investment return in both cases, and how such a calculator is used to assess a wide portfolio of products and services.
The presented tool allows to efficiently assess the "hot spots" on the lifecycle of a product. As the embedded carbon footprint estimate is one of the outcomes of the LCA, it can be put in perspective of the full lifecycle for further action taking. With the overall picture, the output of this tool can be the basis for discussion of opportunities with customers in their way to reduce their footprint.
Using a Digital Platform as a PMO in a Mega Project
Authors: Daniel K. Varghese 
Published: October 2022

How project owners used a digital platform to ensure that their project reviews focussed on proactive actions towards the mitigation of potential issues rather than just discussions of project history.
A US$ 3,200 mega project to build a natural gas fertiliser complex at three different locations in 48 months was planned to be executed through multiple contracts by a SPV (Special Purpose Vehicle). The SPV was formed by 5 different public sector companies. This paper explores how they were able to utilise a digital platform to take over the PMO function successfully and with minimum human resources.
Since the project was of national importance and being monitored very closely by the Union Government, the project's management wanted the assurance of standardized reports to analyse schedule, cost, safety & quality, and to report accordingly to the appropriate levels. They engaged a cloud-based digital platform to ensure that, even with minimal resources (almost 1/10th of conventional manpower requirements) and even though it was a mega project with multiple stakeholders, the platform they chose ensured that all the typical PMO functions would be managed smoothly.
Unlock Hydrocarbon Potential of Najmah Kerogen Unconventional Reservoir (West Kuwait)
Authors: Nguyen Kim Long , Al-Morakhi Rasha , Verma Naveen Kumar , Quttainah Riyad , Sheikh Bilal Sajid , Youssef Ahmed 
Published: October 2022

AbstractHydrocarbon exploration and production in unconventional reservoir is under-developed in Middle East. Therefore, the understanding about this subject is still scanty which leads to conspicuous uncertainties in comprehensive reservoir evaluation and development. It plays a critical role to minimize the cost of exploration, drilling and operations. Detail plan for core acquisition and study is crucial to provide accurate and sufficient information to unlock the potential of Jurassic unconventional reservoirs in West Kuwait (WK). Hydraulic fracturing has proven to be a successful technique for increasing the productivity of unconventional reservoirs. However, before reaching that step, many factors should be intensively evaluated to minimize the risks. A potential area to place a MSF well should satisfy several criteria: high TOC, hydrocarbon maturity (oil, wet gas, or gas), less bitumen, proper containment to hold the vertical extension of fractures beyond the upper/lower boundary, etc…This paper aims to describe the integrated process of reservoir characterization to identify Najmah Kerogen sweet spots in order to facilitate the first Multistage Hydraulic Fracturing (MSF) well in West Kuwait (WK) unconventional reservoir.The study showed that Najmah Kerogen reservoir in WK fields has world-class quality of hydrocarbon potential: average TOC is 10-13%, Kerogen type II/III, mostly in the oil window except some fields have high potential of wet gas/condensate. Thermal maturity increases basin-wards from South-East to North-West. The reservoir is organic-rich mudstone that comprises mainly calcite, dolomite, quartz, kaolinite, and pyrite. In general, the middle unit has lower organic content and higher brittleness compared to the upper and lower one. The reservoir characteristic of the middle unit is favorable for landing the MSF well. The upper unit contains high bitumen amount, so it should be voided in the plan of MSF. Fracture analysis shows the majority of natural fractures are following NNE-SSW direction that in line with regional tectonic understanding and results the favorable drilling direction in NW-SE to ensure the wellbore stability and maximize the efficiency of hydraulic fracturing job. As a result, Field-H was identified as the best candidate to drill the first MSF well in Najmah Kerogen (middle and lower unit) from the outcome of the study. The comprehensive understanding of Najmah Kerogen was crucial to develop unconventional reservoirs in WK fields, especially when the development of unconventional reservoirs is still in the early phase.
Successful Perforating Deployment in Deep Gas Wells Completed with Permanent Fiber Optic Behind-Casing for Hydraulic Fracturing. A State of the Art in Well Delivery.
Authors: Nunez Alvaro Javier , Al Husaini Nasser Khalfan , Al Kendi Al Muntaser Nasser , AL-Yahyaai Hamood Said , Al Hinai Adnan Saif , Abdelazim Mohamed Fathy 
Published: October 2022

Abstract
The scope of this paper is to discuss the methodology to perforate deep High pressure, High Temperature (HPHT) gas wells that are completed with permanent fiber optic behind-casing for hydraulic fracturing operations in Petroleum Development Oman (PDO), the main objective is to show the planning and successful execution of perforating and hydraulic fracturing operations in this new type of completions. The paper will show the enhancement of Well Delivery and the outstanding results in these challenging operations.
The paper will start by elaborating on this new type of completions with permanent fiber optic, the benefits, and the challenges associated to perforate the casing while maintaining the integrity and functionality of the fiber optic throughout all the hydraulic fracturing operations. Different orienting tools, gun sizes, shaped charges, explosive types, and gun phasing were evaluated and assessed to achieve the optimum system. Yard tests were done with an actual casing joint and fiber optic. Further, it will discuss the design, planning and successful job execution in one of the new gas wells with 4 fracturing stages completed.
Field operations were successfully executed in a deep gas well with 4 frac stages using plug and perf technique, the optimum and novel perforating system allowed to complete a total of 24 perforating runs without any damage to the permanent fiber optic behind-casing, it also allowed to successfully initiate and propagate the fracture in all stages. A final multi finger Caliper log also indicated that there was no tubing damage or deformation across the perforated clusters after milling all the frac isolation plugs. The well was successful delivered to production operations. The concept of perforating and fracturing deep gas wells completed with permanent fiber optic has been proved with substantial benefits, not only for the hydraulic fracturing operations but also for future Well Reservoir Management (WRM) and surveillance activities through the life cycle of the well.
Perforating and hydraulic fracturing in wells completed with permanent fiber optic is a novel approach to enhance hydraulic fracturing and well delivery, this is in alignment with the continuous improvement (CI) ideas and the lean thinking across the oil and gas industry. It's easy to replicate in other gas and oil fields, as well as horizontal wells to be hydraulically fractured, it will reduce cost, Health, Safety & Environment (HSE) exposure and will help increase the recovery of hydrocarbon reserves.
Case Study on the Application of In-Situ Combustion for Ultra-Low Permeability Oil Shale from Natih B Formation (Oman): Synthetic Oil Generation and Micro-Scale Pore Structure Changes
Authors: Varfolomeev Mikhail Alekseevich , Yuan Chengdong , Bolotov Alexander Vladimirovich , Saifullin Emil Rinatovich , Minkhanov Ilgiz Failevich , Mehrabi-Kalajahi Seyedsaeed , Derevyanko Vadim Konstantinovich , Al-Muntaser Ameen Ahmed , Suwaid Muneer Abdo , Sadikov Kamil , Taura Usman , Al-Wahaibi Yahya , Al-Bahry Saif , Joshi Sanket , Naabi Ahmed , Hasani Majid , Al Busaidi Rashid Said 
Published: October 2022

Abstract
Oil shale is considered as the world's second largest solid fossil fuel resource. Oil shale is an extremely ash-rich sedimentary rock loaded with organic matter. Most of the organic matter is rich in kerogen and a small amount of bitumen, which can be converted into synthetic oil using different thermal treatment methods. In-situ combustion (ISC) is a promising thermal enhanced oil recovery (EOR) method for the conversion of kerogen contained in oil shale to synthetic oil by oxidation. However, its field application is still limited due to difficulty in ignition, low combustion efficiency, and low rock permeability, etc. The main goal of this work was to determine the optimal conditions for synthetic oil generation and changes in the properties of oil shale.
In this work, a self-designed combustion tube was developed to evaluate the effect of catalyst and water, including improving combustion front propagation and shale oil recovery. Copper (II) stearate (0.1 wt% by metal) was used as an oil-soluble catalyst to improve the process of ISC. The performance of ISC was evaluated in terms of material balance, recovery factor, composition of evolved gases, and produced synthetic oil quality. In addition, the changes in the properties of oil shale rock were also investigated using 3D computed tomography.
According to the results of the combustion tube experiments, the presence of both water and catalysts is favorable for reactions that produce synthetic oil, sufficient heat generation (according to CO2 release) and hydrocarbon gases. The temperature profile and pressure profile indicate a successful ignition and successful establishment of combustion front for Natih B oil shale. The catalysts and water together improved the stability of combustion front and increase the efficiency of ISC process. The permeability was increased about 4 times higher after combustion.
Generally, these promising results technically prove the potential for the development of shale oil from Natih B Formation (Oman) by ISC process. The use of ISC can allow the conversion of oil shale into light synthetic oil with hydrocarbon gas production. Moreover, based on the obtained results the in-situ combustion can occur in ultra-low permeability reservoirs.
New Method of Offshore Platform Strengthening by Prefabricated X-Frames and Retractable Joints
Authors: Chatterjee Prabir Kumar , Shah Jinesh 
Published: October 2022

Abstract
This paper presents a new approach of offshore jacket strengthening with rigidly connected members and minimizing the number of clamps and bolts. Horizontal and diagonal braces between two successive elevations of a jacket in a plane may be combined to form a prefabricated X-brace which will be able to replace a set of existing damaged members. To facilitate easy installation, X-frame will be assembled along with its connecting half-clamps and one side of the X-frame will be provided with retractable ends. The annulus portion of the movable ends of the X-frame will be grouted to make rigidly joined new braces. The case study involves an aging offshore platform that undergoes a large amount of horizontal movement due to environmental loads. In spite of earlier upgrade with new piles and clamped braces, the substructure is found to be considerably flexible as a result of loose clamps and construction tolerance provided at the ends of each member. A detailed analytical study has been performed with the proposed strengthening scheme that shows significant improvement of the platform movement.
Remote Automated Well Test Operation on Un-Manned Well-Head Tower to Achieve Operational Safety and Efficiency
Authors: Joshi Mehul , Ramabhaskaran Padmanabhan , Shah Ankit , Soni Sandeep , Gupte Rohan , Mitra Jitendra 
Published: October 2022

Abstract
The unmanned operation in an offshore operating asset with large number of wells inherits a variety of operational and safety challenges, which demands innovation and emerging technology adoption. This paper demonstrates one of such operational activities related to well testing, where the value realized from mitigation of challenges brings significant process improvement in terms of safety and efficiency. Moreover, this paper also highlights the importance of planning and implementing such an initiative to overcome the process optimization challenges and associated change management risks.
The current process of well test operation requires the process engineer to divert the well strings by operating the valves manually to perform the test. The associated challenges related to the execution of such an operation were captured while devising the automated well test approach for remote WHT. This solution was formulated on a fallback strategy to retain the existing process in case of remote access failure. Using the SCADA system at the control location, the operator can execute the remote operation using a simplified process just by selecting a well and initiating the associated test operation.
This automated process enabled users to plan, execute, and control the well test operation seamlessly, realizing operational KPIs safely and efficiently. The manual interventions and related mistakes were minimized by using this automated approach. The interlock feature of the approach brought automation and operational efficiency to the process due to the system performing conditional checks on different associated equipment in this process. This significantly improved the manhour efforts and interlinked human errors, which could otherwise cause a significant loss of operational time and cost. The seamless integration with corporate data sources assured information flow from field to head offices fast and accurately, which adds to the process efficiency by avoiding human errors related to manual data handling. The integration aspect of this solution was unique as it was based on constant feedback and rigorous testing with end-users, along with robust architecture to incorporate various IT components and OT cybersecurity concerns.
The novelty of this solution was based on an approach that caters to the complexity, safety and process efficiency concerns of the current process when observed from the operational challenges associated with a giant producing field in a remote location. This brings the field in control and enables the asset operation team to plan the operations in a proactive manner, delivering quality outputs while achieving the critical operational KPIs.
Application of 4D Geomechanical Modelling for Fault Critical Re-Active Stress Evaluation in Underground Gas Storage
Authors: Chen Dong , Zhou Wei , Luo Ji , Huang Zhaoting , Xu Hanbing , Fu Ying , Cheng Ronghong , Lian Liming , Jin Quan , Qiao Xia , Wu Mimi , Yang Xiao , Huang Xingning 
Published: October 2022

Abstract
Fault stability is the risk of reactivation under dynamic stress conditions. The reactivation of faults in the oilfield is mainly caused by the increase of fluid pressure in the reservoir zone, with the quantitative evaluation index of the critical reservoir pressure required for fault reactivation under the current pore pressure condition. When the formation pore pressure reaches the critical stress, the corresponding fault part will be in a critical stress state. The slippage of the critical stress fault tends to cause fluids leakage. Therefore, the study of fault stability is of great significance to oilfield production; In order to guarantee national natural gas peak regulation and supply, the YH underground gas storage (UGS) has been proposed and is carried out with the project of expanding storage capacity and increasing production. The operator hopes to effectively guide the optimization of the limit operation pressure and ensure its long-term safe operation. It is urgently required to carry out fault stability evaluation for the YH underground gas storage. The operator plans to find out the conditions for the activation of the faults, with studies about the stability of the fault under the impact of mining and the impact of the system parameters on the stability of the fault. The results suggest that: whether the fault is in a stable or active state depends on the magnitude relationship between the apparent friction factor (k1) and the fault friction factor (k). When k1 &lt; k, the fault will be in a self-locking state. However, when k1 ≥ k, the fault is in a reactive state. The apparent friction factor reflects the stress risk level of the fault under the collective impact of the in situ stress (including σ1 and σ3), the cohesion of the fault plane (c) and fluid pressure of fault (pi). Higher k1 indicates higher tendency of fault re-activation. k is a quantity factor determined by the friction angle (φ) within the fault. The larger friction angle of fault indicates higher friction factor and the more stable state. The system parameters (includingφ, c, pi, σ1 and σ3) will affect the stability of the fault after the change of initial stress conditions: the smaller cohesion of the fault plane and greater fracture fluid pressure indicate the fault will be easier to reactivate. This paper established the 4D dynamic geomechanical model of the YH underground gas storage and took the fault stability as the judgement basis to analyze the in-situ stress characteristics of different faults. The research results could be used to evaluate the UGS operation safety quantitatively under the impact of the dynamic stress conditions, which will provide technical guidance for optimizing the operation plan of the UGS.
Study, Analysis and Methodology Involved in Frac String Rotation to Minimize the Axial Efforts to Enhance Monobore Completion Integrity and Accessibility to Streamline Frac Operations in Unconventional Wells of Abu Dhabi, UAE
Authors: Ruiz Fernando , Al Hadidy Khaled , El Yossef Bassem , Amorocho Alexander , Nunez Ygnacio , Kumar Rakesh , Al Karra Mohamed , Lari Aliya , Fahmy Moataz , Ramadan Taha , Ibeziako Chuma , Hebish Ayman , Negoi Adrian , Cardozo Luis , Al Hendy Mohamed , Al-Rahma Rahma , Hamdy Ibrahim , Al Shamisi Eisa , Bin Sumaida Ali , Al Mutawa Ahmed , Coscia Marco 
Published: October 2022

Abstract
The purpose of this paper is to share the results and knowledge learned in implementing new procedure and techniques to rotate the 5-1/2", 26 PPF, T-95/P-110 Frac String (FS) during running into Unconventional wells. Developed by ADNOC Onshore ASR - UC Drilling Department at Abu Dhabi (U.A.E.) the novelty involves six (06) different technologies necessary to minimize axial buckling in the monobore completion while maximizing well accessibility and integrity during the Rigless frac operations.
The 6 key enablers technologies employed to rotate the Frac String up to 30,000 pound-ft: Connection: strength to withstand rotation required to release the axial buckling.High Speed Reamer Shoe: open hole debris cleaning / obstruction removal.Bonded Ceramic Centralizers: providing 80% standoff, reducing the friction factor and removing the mud cake with the rotation.Casing Running Tool: designed to wash down and rotate FS during running.Rotating Tubing Hanger: enabling FS rotation using different techniques and design a new mechanism for it after landed and locked into the Tubing Head Spool.Rotating Cement Head: ability to rotate the FS while pumping cement and plugs simultaneously.
Because of friction, sliding during running will result in helicoidal buckling of the FS that has a negative knock down effect on later completion operations / interventions and even in some cases not possible to reach the TD.
The results of previous UC wells where FS was run in sliding mode revealed issues due to the helicoidal buckling of the FS impairing annulus / cement bond quality, creating tortuosity and altering the Internal Diameter (ID) leading to issues in accessing the well bore with the Plug and Perf tool for the fracking operations.
The total depth for standard UC wells ranges from 16,000’ to 23,000’ MD with ± 12,500’ TVD and ± 8000’ MD 8"1/2 horizontal section dipping up to ±92° inclination for production reasons. Such profiles generate Friction Factor (FF) ± 0.5 in Open Hole. Based on performed simulations and depending on the well profile, surface torque required to rotate the string was between 25,000 to 30,000 pound-ft.
This paper will describe and provide details on how the FS helicoidal buckling was minimized and its limitations overcome thanks to the six key enablers technologies devised by Onshore ASR - UC Drilling Department. It will also highlight other important added benefits such as mud cake removal, improved annulus geometry and cement bond.