bluuebunny/crossref_metadata_2025_split huggingface dataset:
Locating CO2 Leakage in Subsurface Traps Using Bayesian Inversion and Deep Learning
Authors: Zhang Zhen , He Xupeng , Li Yiteng , AlSinan Marwa , Kwak Hyung , Hoteit Hussein 
Published: March 2023

Abstract
Geologic CO2 sequestration (GCS) is a promising engineering measure to reduce global greenhouse emissions. However, accurate detection of CO2 leakage locations from underground traps remains a challenging problem. This study proposes a workflow that combines Bayesian inversion and deep learning algorithms to detect the sites of CO2 leakage. There are four main steps in the workflow. Step 1: we identify the key uncertainty parameters. Here we mean the CO2 leakage location. Then we get the training set using Latin Hypercube Sampling (LHS) method and perform the high-fidelity simulation using CMG. Step 2: we train the surrogate model using the data set collected from the last step, in which the Bayesian optimization is used to tune the hyperparameters automatically. Step 3: we perform the Bayesian inversion to invert the CO2 leakage location, in which the surrogate serves as the forward model to reduce the computational expense. Step 4: we feed the inverted CO2 leakage location into the high-fidelity model to produce the pressure response. If the error between the pressure response between the surrogate and the high-fidelity model is small enough, the solution is accepted. Otherwise, the accuracy of the surrogate model and the convergence of the Bayesian inversion process are revisited. We validate this method using a synthetic model of CO2 injection. Results show that the proposed Bayesian inversion assisted by the deep learning algorithm can accurately detect the CO2 leakage location with narrow uncertainties. This approach provides an accurate and efficient way to detect CO2 leakage locations in real-time applications.
Tailored Engineering Cementing Solution to Maintain Well Integrity in Shallowest Liner for Underground Gas Storage Project - Case History from Southwest China
Authors: Li Fangfang , Bhaisora Devesh , Yue Huang 
Published: March 2023

Abstract
Underground gas storage (UGS) wells have emerged as a strategic solution in China. Success of UGS projects largely depends upon maintaining long term well integrity. Cement slurries that are placed across a wellbore should exhibit superior cement bonding as evidenced through a cement bond log (CBL) and long-term integrity to sustain the cyclic stress change by the injection and production process. Such slurries should have improved mechanical properties and the job execution should follow all cementing best practices.
The well architecture included a 9 5/8-in. surface casing and a 7-in. production liner. The 7-in. Liner was run inside an 8.5-in. open hole and extended to surface using a tie-back liner. This well architecture should have a superior quality of cement across the entire liner. Multiple Finite Element Analysis (FEA) runs were performed to determine an optimum Young's modulus and Poisson Ratio for the cement slurry. These rigorous tests can take weeks to complete. As the well was shallow, to cover a wide range of well profiles, three different slurries were tested prior to the job.
The initial mud weight planned for the well was in the range of 1.25 g/cm3 to 1.4 g/cm3. Due to gas influx, the mud density in the section was increased to 1.90 g/cm3. However, losses were also encountered at this mud density. Hydraulic modelling was revised, and slurry rheology and pumping rates were optimized to ensure equivalent circulation density (ECD) control within the pore pressure and fracture gradient window. Displacement rates were optimized to facilitate good displacement efficiency for hole cleaning. The slurry design was tailored with special additives to provide a synergetic effect of improving mechanical properties and minimizing seepage losses. Multiple computational fluid dynamics (CFD) runs were performed to evaluate the cementing job quality and based on the simulations it was decided to increase the cement volume to minimize any impact of contamination. The cementing job was performed with no operational issues and cement returns were observed above the top of the liner. Two different cement evaluation logs - CBL and ultra-sonic log, were conducted and showed good cement quality in the open hole section, meeting the well objectives.
With this successful implementation, the tailored engineered cementing solution was highly recognized. The design and execution methodology were highlighted as the guideline for further successful cementing operations in UGS projects. This study shows a fully comprehensive and scientific way to improve cementing quality for long-term well integrity for UGS projects.
The Impact of Salt Ions on the Rheology of a Crosslinked Polymer Containing a Chelating Agent
Authors: Othman Amro , Murtaza Mobeen , Aljawad Murtada , Kamal Muhammad , Mahmoud Mohamed , Kalgaonkar Rajendra 
Published: March 2023

Abstract
The growth in hydraulic fracturing activities increased the demand for freshwater, a scarce commodity in water-deprived regions. The alternative is to utilize seawater (SW) or produced water (PW) from oil and gas operations to formulate high total dissolved solids (TDS) fracturing fluids. If achieved, it will result in more sustainable hydraulic fracturing operations that are cost and logistics efficient. Furthermore, aside from the hydrocarbons in PW, both SW and PW have similar ions, so the same remedy should be suitable for both. Therefore, this study investigates the influence of individual ions on a crosslinked polymer solution that contains a chelating agent.
The study investigated the effect of individual ions on the rheology of fracturing fluid formulated using carboxy methyl hydroxy propyl guar (CMHPG) polymer. The studied salts included calcium chloride (CaCl2.2H2O), magnesium chloride (MgCl2.6H2O), sodium chloride (NaCl), and sodium sulfate (Na2SO4). First, the effect of delayed zirconium (Zr) crosslinker on individual ions was investigated by varying the Zr concentrations (0.3, 0.6, and 1 wt. %). Then, the selected crosslinker concentration was used to inspect the impact of N, N-Dicarboxymethyl glutamic acid (GLDA) chelating agent on the crosslinked system at different concentrations (4, 10, and 20 wt. %). Finally, the rheology of polymer in SW and deionized water (DW) was tested as a reference. The testing parameters on the two sets of the experiments were constant, which included 70 °C temperature, 500 psi pressure, 100 1/s shear rate, and 45 minutes for polymer hydration in a fluid.
The rheology of the crosslinked CMHPG polymer was mostly impacted by sulfate and then calcium ions. The viscosity of the solution containing only sodium sulfate was reduced to that of SW. Unlike the DW, the increase in the crosslinker concentration increased the viscosity of SW and individual ion solutions. The ions’ salinity affected the long-term viscosities as they dropped to less than 10 cP in all concentrations in less than one hour. Sodium and magnesium ions did not significantly impact the solution viscosity and behaved like that of DW. The low-concentration chelating agent raised the stability of MgCl and DI solutions. In the SW, NaCl, and CaCl2, the viscosity dropped at the first 20 minutes then the curve rose to reach higher values than the DI after 3 hours.
This work demonstrated how the crosslinker and chelating agent affect different salt systems’ behavior and viscosity. The results can be used to understand the rheology of fracturing fluids based on seawater or produced water.
Unique Solution to a Challenging Multilateral Well Intervention Using an Electric Multilateral Tool and Distributed Temperature Diagnostics on Coiled Tubing in a West Kuwait Field
Authors: Sebea Salem Hamad Al , Abu-Eidah Abdullah Ibrahim , Patra Milan , ALKhayouti Malak Yousef , Bumijdad Mohammed Mousa , Al-Hamdan Abdulaziz , Khandelwal Nakul , Chawla Sapna , AlWazzan Abdulatif , Alkreebani Mohammad , Travesso Joshua 
Published: March 2023

Abstract
Multilateral wells offer multiple benefits to oil and gas operators, including lowering the field development cost by minimizing wellsite construction work and increasing reservoir contact leading to enhanced reservoir production. They also present challenges, with each leg requiring separate intervention and uniform stimulation to gain full advantage of these complex wells.
An operator in Kuwait drilled a 2-leg level 1 multilateral well to enhance production from the Mishref formation. Mishref is a fast-depleting reservoir requiring an extended contact area to drain the reservoir uniformly and efficiently. The main challenges with multilateral intervention include identifying the junction depths, gaining lateral entry, and confirming the correct lateral entry. To overcome these challenges, the operator identified the unique technology of utilizing Real-Time Hybrid Coiled Tubing (RTHCT) with an Electric Multilateral Tool (EMLT). Diagnostics using Distributed Temperature Sensing (DTS) were also used to compare pre and post-stimulation effectiveness.
Intervention into a level 1 multilateral well presented several challenges, and RTHCT with the EMLT were successfully used to overcome these. The solution includes a hybrid fiber optic and electrical cable installed in the CT string and a Modular Bottom Hole Assembly (MBHA) equipped with various sensors. An electrically controlled indexing tool, inclination sensor, tool-face sensor, downhole camera, hydraulic knuckle joint, and pulsating stimulation tool were used as part of the BHA to enable real-time diagnostics and dynamic controls from the surface to successfully enter and stimulate both the lateral legs. This customized solution helped identify each different lateral without the need to tag the bottom of each lateral. This paper focuses on applications, strategies, and benefits of specific tool configurations developed for multilateral well intervention, which enabled the stimulation of both the Mishref laterals. Also discussed are the DTS diagnostics used to identify any thief and impermeable zones. Pre and post-stimulation diagnostics were performed to identify the effectiveness of the stimulation treatment.
This paper includes strategies that address proper tool selection, confirmation of lateral entry, hydrostatic pressure balance, borehole stability, and acid design. It also explores the potential of new, synergistic strategies and work processes planned for stimulation of the Mishref reservoir.
Bahrain LNG Import Terminal (BLNGIT) Project:1st LNG Commissioning Cargo and Integration of Imported Regasified LNG (RLNG) with Domestic Khuff Gas in the Existing Distribution Network
Authors: AlKhunaizi Fawaz A. Aziz , Prudhvi Muni Shankar , Mohamed Anwar 
Published: March 2023

Abstract
In order to meet the country's future energy requirements, and in particular the increased demand for electricity and water in addition to major industrial growth, Bahrain's Ministry of Oil & Environment (MoOE) – formerly known as the National Oil and Gas Authority (NOGA) - has taken the strategic decision to import Liquefied Natural Gas (LNG) to supplement existing local gas supplies as a long-term energy policy.
NOGA and the Oil and Gas Holding Company B.S.C (c) (nogaholding) signed project agreements in 2015 for the development of an LNG Receiving and Regasification Terminal in the Kingdom of Bahrain with an international consortium.
The purpose of this paper is to shed light on this ‘first-of-its-kind’ project development in the Kingdom of Bahrain in order to highlight (i) the challenges and management of such challenges, (ii) the ultimate project/operational objectives and successful results, and (iii) lessons learnt.
Modeling Two-Phase Intermittent/Annular Flow Pattern Transition in High Liquid Viscosity Upward Vertical Wells
Authors: Al-Safran Eissa , Ghasemi Mohammad 
Published: March 2023

Abstract
Two-phase flow pattern prediction is required for accurate prediction of liquid holdup and pressure gradient in upward vertical wells. Recent studies of flow pattern models evaluation in high liquid viscosity two-phase in vertical pipe upward flow revealed (Al-Safran et al., 2020) discrepancies in all transition boundaries, including the intermittent (IN)/annular (AN) transition. This study aims to investigate the effect of liquid viscosity to improve Taitel et al. (1980) and Barnea (1987) IN/AN flow pattern transition models predictions. Taitel et al. liquid droplet fallback model is modified by incorporating liquid viscosity effect in the critical Weber number to predict droplet terminal velocity. In addition, this work eliminates the assumption of negligible annular film thickness (due to high viscosity liquid) in predicting the critical gas velocity to transport liquid drop upward, i.e. transition to intermittent flow. Sensitivity analysis revealed that the interfacial friction factor (fi) and liquid entrainment (fE) closure relationships are crucial in Barnea (1987) film bridging and film instability IN/AN transition models. Therefore, a comprehensive evaluation of fi and fE correlations and their combinations revealed that the combination of Pan and Hanratty (2002) fE correlation and Ishii and Grolmes (1975) fi correlation is the best, i.e. produces least prediction error, for wide range of liquid viscosity. A validation study against large experimental database of high liquid viscosity (4 mPa.s to 1600 mPa.s) flow pattern showed high prediction efficiency for the improved Taitel et al. and Barnea IN/AN transition models.
Asphaltene Testing for Inhibitor Evaluation
Authors: Jennings David , Golchha Abhishek , Breitigam Justin , Yen Andrew , Xu Kui 
Published: March 2023

Abstract
Asphaltenes are a global flow assurance problem responsible for reduced production and increased operating costs in many oilfields. Asphaltene inhibitor programs are needed to manage problems and increase operational profitability. Improvements are needed in both developing new inhibitors with better performance and in the understanding and application of testing methods used for evaluating inhibitors.
This paper discusses ongoing efforts to improve our understanding of asphaltene deposition and inhibitor testing with a goal to be able to correlate testing results to satisfactorily predict asphaltene inhibitor field performance before application. Three different asphaltene test methods used in our laboratory are presented. The methods include both live and dead crude oil testing. Results from testing with each method and their relevance to field conditions are discussed. More focus is given on the dead-oil testing methods though as live-fluid testing, being more difficult and costly, is not an option for many field studies. Fundamental deposition studies are shown from one of these methods, highlighting the effect of varying different test conditions on deposition. Finally, a case history of a successful asphaltene inhibitor field application is included at the end of the paper. It is included to provide an example of the benefits of an effective asphaltene inhibitor application and show some comparisons between laboratory testing and field experience.
Extended Well Testing Campaign in Extreme H2S Environment in SIMOP
Authors: Katamesh Hesham , Hamdy Emad 
Published: March 2023

Abstract
In a modern era of unprecedented events, such as the COVID-19 pandemic, energy matters now more than ever. What was previously impossible is now a challenge that should be met with measured risk and a mitigation plan.
In early 2020, a service company pursued a solution to provide a compact surface well test (SWT) package for an extended well test (EWT) on an offshore production platform in the Zafaraana field with extremely high concentrations of H2S. The solution involved proper treatment and safe delivery of well effluent within acceptable H2S limits to a floating production storage and offloading (FPSO) facility.
The EWT was to be installed for a long period to allow production from the reservoir, treatment of the effluent using H2S scavenger, and delivery to the FPSO facility by means of electric transfer pumps. This was the only way to produce because the FPSO facility could not accommodate the high H2S concentrations from the reservoir.
A further challenge was that it was a simultaneous operation (SIMOPs) wherein the rig was engaged in drilling and completion activities of other wells on the same offshore platform; operational conflicts were identified during the HAZOP/HAZID meeting to help mitigate potential issues.
Extending the Range of Cement Evaluation
Authors: AlArfaj Sarah , Fituri M. Aiman , Shastri Mukesh , Rane Nitin , Al-Kanderi Jassim , AlMohailain Muhanad , Baijal Sanjeev , Al-Qadhi Fahad , Ekpe Joseph , Al Farai Saleh 
Published: March 2023

Abstract
Well integrity assurance and zonal isolation, are the main pillars for any oil and gas well, it was a practice in the past to evaluate cement behind casings for casings smaller than 13 3/8 inch, however with the increase in drilling deeper and more challenging wells, the need for evaluating cement behind larger and thicker casings became a necessity.
Different logging companies have invested in their existing cement evaluation services and upgraded their tool designs, specifications, and increased tool operating range to address the larger and thicker casing requirements. By mid-2016, the upgraded tool measurements range was extended to evaluate up to 22-inch.
KOC in South-East asset started developing their Marrat deep reservoir back in 2018, these wells are designed with large surface casings ranging between (18 5/8-inch and 24-inch) across their main reservoirs (Burgan) and the shallow water and gas bearing formations (Dammam, Radhuma, Tayarat, and Mishrif). Dammam, Radhuma, Tayarat, and Mishrif formations, feature a highly fractured carbonate reservoir and comprise corrosive water and trapped gas pockets. The corrosive water and the trapped gas pockets pose future potential well integrity risks in the field, which implies the need for proper zonal isolation throughout the well and the field lifespan. These formations also comprise a low formation frac gradient, that raises the requirement for low-density cement ranging from 8.5 to 10.5 PPG to overcome the shallow loss zone.
The newly developed extended range for the ultrasonic cement evaluation tools can cover up to 18 5/8 inch surface casings for KOC, however, some additional tests, work, and modifications were required to accommodate the 24-inch casing, which will be discussed later in this paper.
Thermal Investigation of ESP Motor Temperature Rise with Focus on Heavy Oil Applications
Authors: Najmi Kamyar , Teves Ricardo , Zarate Guzman Nahun , Zhu David , Thompson Howard , Gunter Shawn 
Published: March 2023

The generated heat inside a motor is one of the main factors limiting a motor operation. Electrical submersible pump (ESP) motor is not an exception from this limiting factor. Running an ESP motor above the rated temperature can cause serious mechanical and electrical damages to the motor and finally result in motor failure. Therefore, an accurate prediction of motor internal temperature can help not only with expansion of ESP operating envelope, enhancement of motor reliability and run life, but also reduces operating costs and power consumption (carbon reduction).
In addition to industry wide challenges to cool down motors, ESP motors have certain characteristics that make motor thermal management more challenging. ESP motors generally generate a lot of heat and heat dissipation is subject to environmental conditions (such as dynamic well multiphase fluid conditions, well bore geometry and chemistry etc.) that are not easily manageable.
Mechanical Shock Response Analysis of Rilling Microchips for Optimal Performance Evaluation
Authors: Tella Sherif Adekunle , Li Bondong , Li Sanguo , Zhan Guodong David 
Published: March 2023

Abstract
To precisely predict the fluctuation of wellbore properties, local overheating and guide the drilling trajectory in the wellbore during drilling operations, it is preferable to use cost-effective drilling microchips to collect real-time downhole data measurements while drilling. The drilling microchips usually consist of SoC, add-on memory, sensors and on-chip battery. However, the microchips can be subjected to mechanical shocks during the release and drilling operations which can induce interconnects and components failure and eventually leads to damage, loss of stored data and a low recovery rate. As the efficient performance of the drilling microchips can be constrained due to the shock loads, hence, it is essential to understand the peak response of the device when subjected to such suddenly applied stresses or designed response spectrum. The development and validation of simulation modeling approaches is the initial step in this direction. This paper will present the effects of varied shock loads and duration on the drilling microchips using two methods: response spectrum analysis and direct time stepping through mode superposition. It can be deduced that the sum of the effective modal masses for all computed eigenmodes is around 0.8947, 0.8912 and 0.9076 in z, y and x directions. Thus, these modes account for 89.47%, 89.12% and 90.76% of the dynamic forces in the z-direction, y-direction and x-direction respectively.
Development of a New Inhibitive Fluid to Mitigate Shale Drilling Problems
Authors: AlArfaj Mohammad , Alqahtani Hassan , Alsubaie Turki , alotaibi Mohammad 
Published: March 2023

Abstract
In oil and gas industry, drilling shale formations requires careful design of drilling fluids to control shale-fluid interactions and mitigate wellbore instability. As the aqueous phase of the fluid invades shale formations and contacts clay particles, that may cause shale swelling and disintegration. As a result, solids loading increase in the borehole and that might lead to tight holes and, eventually, stuck pipes. Also, the rate of penetration might be reduced due to low hole cleaning efficiency and bit balling. Therefore, differet types of inhibitive drilling fluids have been developed to counter act the interactions between the aquwous phase and clay particles.
In order to develop an inhibitive water-based mud capable of mitigating the adverse effects of shale-mud interactions, it is important to characterize the shale sample in terms of mineralogical composition. Also, the shale-mud interactions should be studied through a series of experimental dispersion.
This paper presents the results of characterization and testing one shale sample and its interactions with an inhibitive drilling fluid and a comparison to non-inhibitive drilling fluid.