bluuebunny/crossref_metadata_2025_split huggingface dataset:
Paraffin Production in Eagle Ford: Learning, Applying, and Executing Out of Box Strategies for Living with This Challenging Issue
Authors: Contreras Jesus D. , Vasquez Javier R. , Harton Trey W. , Garikipati Prapul 
Published: September 2024

Abstract
Since the beginning of Eagle Ford development, paraffin production has created significant production losses in wells downhole, well pads and gathering systems. The organization has performed multiple strategies trying to mitigate the problem including chemical injection, hot water/hot oil treatment (downhole) and pigging activities (gathering system).
Nevertheless, a formal solution, if something like that exists, has been elusive. Historically, the approach to paraffin issues in the field has been reactive. In 2020, the team began investigating a more proactive approach with the creation of an integrated hydraulic model to improve pigging operations within the gathering system.
Also, operational data combined with data analytics techniques was used to identify a specific pattern that revealed more about the deposition process at low pressure and low temperature conditions under which paraffin is regularly observed.
This paper will explain that through the discovery of specific pressure trends, at pad level (surface), combined with an unconventional approach for analyzing gas compositional data, it was possible to both detect and predict paraffin deposition at pad level (surface), and in the gathering system, including conditions where paraffin was in suspension (that cannot be observed using conventional tools/methodologies). These workflows completely revolutionized the pigging strategy and ultimately reduced production losses by more than 90%.
Three-Level System to Determine and Correct Real Time Drillstring Vibration
Authors: Carrillo L. A. , Flores R. , Suarez H. , Morales J. P. 
Published: September 2024

Abstract
This paper aims to identify the impact of parameters: Rate of Penetration (ROP), Torque, and Weight on Bit (WOB) on the Specific Mechanical Energy (MSE). This concept has been implemented to evaluate bit performance, determine drilling efficiency, and analyze if the bit adequately utilizes the energy and is not dissipated elsewhere (vibration). However, MSE alone does not differentiate between the causes of inefficiency and additional energy used in drilling. Various studies have analyzed this parameter along with the MSE/DS (MSE/Drilling Strength) ratio to determine if drilling inefficiency is due to rock hardness, vibrations, bit wear, or bit balling (Raul Flores, CMP 2024). Continuing with the study, we have the following:
A three-way protocol to determine and correct drill string vibration is presented with a simplified methodology. When using the original MSE equation, there are two terms: torsional load and axial load. Studies concluded that the axial load can be omitted, yielding the same result. Also, in terms of trend analysis, MSE behaves the same over the drilling time. The MSE/DS ratio led us to a simplified equation called the Ratio Factor (RF), a quick-to-calculate optimized factor. The RF is the ratio between the rotational forces and the normal axial forces on the bit. 3 case studies are shown, where based on the behavior of the MSE and the RF, the problems presented were identified and corrected, Well 1: vibrations, well 2: Bit wear and well-3: Impact of the MSE values.
Insights into the Impacts of Heterogeneity and Capillary Pressure in CO2 Storage in Depleted Gas Reservoirs with a Focus on Water Backflow and Hydrate Formation
Authors: Fernandes B. R. B. , Delshad M. , Indina V. , Farajzadeh R. , Machado M. V. B. , Sepehrnoori K. 
Published: September 2024

Abstract
With the growing demand for geological storage of CO2, depleted gas reservoirs are becoming attractive targets due to proven caprock and existing infrastructures. However, Joule-Thomson cooling can pose a flow assurance risk leading to the formation of hydrates and possible injectivity loss. This study investigates the impacts of capillary pressure and permeability heterogeneity on the formation of hydrates during CO2 storage in depleted gas reservoirs. A compositional thermal reservoir simulator is used to model the fluid and heat flow of CO2 in methane and water-saturated reservoirs. The dissociation and formation of methane and CO2 hydrates are modeled using kinetic reactions to calculate porosity and permeability reduction during hydrate formation. The capillary pressure is scaled using the Leverett J-function to account for variations in porosity and permeability values. The water residual saturation is also correlated with permeability. Variograms are used to generate areal heterogeneity for multilayered reservoir models. Sensitivities to injection rate and wellhead temperature are also performed. The results indicated that the Joule-Thomson cooling is increased with lateral heterogeneity, leading to more formation of hydrates. The heterogeneity created low permeability zones near the injection well, leading to higher pressure drawdown which intensifies the cooling effect. The reduced water saturation during the injection of CO2 altered the capillary pressure and resulted in water backflow and crossflow. The magnitude of capillary-driven backflow and crossflow was observed to be a function of the capillary pressure gradient. For cases with hydrate formation, a complete conversion of water in the pores to hydrate and ice resulted in porosity reduction proportional to its water content and injectivity reduction as high as 30% for multilayered cases. However, water backflow provided a continuous source of water for hydrate and ice formation in low permeability layers which lead to near well plugging. The water backflow due to the capillary pressure gradient can intensify the risk of hydrate formation by more water content in the near wellbore.
Repurposing Depleted Wells for Geomechanical Pumped Storage
Authors: Balushi Faras Al , Taleghani Arash Dahi 
Published: September 2024

Abstract
Geomechanical Pumped Storage (GPS) is an innovative renewable energy storage method that utilizes the elastic deformation of subsurface formations to store and retrieve water for electricity generation during peak energy demand periods. By leveraging the elastic properties of underground formations and the lifting of overburden, GPS stores water within hydraulic fractures. This study aims to identify the most efficient GPS design to maximize energy storage in subsurface formations focusing on the hydraulic connection between the wellbore and the fractures. We developed a Mechanical Earth Model (MEM) to simulate different fracture closure modes including uniform and mouth closure modes. We modeled the interactions between fluid flow and rock deformation during water injection, storage, and recovery phases using poroelasticity principles. Results indicate that uniform fracture closure mode reduces fluid loss, thereby improving energy storage and recovery efficiency. Converting abandoned oil and gas wells into GPS sites could also reduce costs, which offers an adaptable and cost-effective energy storage solution.
Fracture Conductivity with Application of 3D Printing Technology
Authors: White V. A. , Arias J. Colina , Zhu Ding , Hill A. D. 
Published: September 2024

Abstract
Fracture conductivity is a measure of the success of completion designs and subsurface fracturing treatments from fractured well performance. Conductivity can be evaluated from experimental investigation. Traditionally, samples for conductivity experiments involve fracturing downhole or outcrop rocks to create realistic fracture surfaces capturing diverse morphologies. Previous studies show that fracture topography strongly influences the conductivity created, and therefore fractured well performance. However, the distinctive nature of these surfaces hinders repeatability and complicates the identification of rock characteristics impact on conductivity. In this research we use 3D printing technology to generate repeatable conductivity test samples with statistically controlled parameters to characterize fracture surface roughness and rock geomechanical properties. The test procedure provides a more isolated evaluation of the factors that control the resultant conductivity.
A digital fracture surface model was generated using Geostatistical Software Library with application of mean deviation, standard deviation, and correlation lengths as changing parameters that influence surface roughness. Two mirror sides of fracture sample were made digitally as replica of original fracture samples. Molds of samples were printed with a Liquid Crystal Display (LCD) Ultra-Violet 3D printer using a selected 3D printing resin. Then the testing samples are made with cement that has appropriate mechanical properties from the molds. Several physical samples of fracture conductivity test were created with cement and the printed molds. All samples have the standard API conductivity dimension, and the conductivity tests follow the modified API conductivity test procedures. The proppant used in the tests include local 100-mesh sand and 200-mesh sand.
The experimental results show a good repeatability of the 3D printed samples, which confirms the consistency of the experimental procedure. From that point, the comparisons of different proppant type, size and concentration on conductivity are made, and conclusions on proppant selection for optimal conductivity are generated.
The procedure developed in this research eliminates the uncertainty of randomness of individual fractured rocks, and better evaluates the effect of the type and size of proppant on fracture conductivity for different fracture surface topographies. The finding of this research help to understand fracture conductivity as a function of geostatistical features of the fracture surface, and the effect of proppant type, size and loading on fracture conductivity and fractured well performance. This can be used in fracture designs for more efficient treatments.
Project X Complex Transportation & Installation Campaign; Strategies & Scheduling for Greater Cost Effectiveness
Authors: Kassim K. , Ngadiman H. B. , Rahman K. A. , Shahudin F. , Marimuthu M. 
Published: September 2024

Abstract
This paper discusses on the methods of the installation of platforms, pipelines and subsea fiber optic cable including its challenges the subsequent mitigations. The knowledge is based on the successful installations of Project X Gas Development Project consist of a CPP, flare tower & riser platform, 28" × 81km pipeline from CPP to riser platform and 8km CPP to nearby platform of subsea fiber optic cable.
The methodology applied in the installation of the CPP jacket is via reverse launch and self upending method. The CPP topside is installed via longitudinal floatover method. The rest of the jackets, topside and other structures was lifted and installed by main work barge. The pipeline was installed via typical S-lay pipeline installation utilizing automatic welding system for the pipelaying and stalk-on of risers at both sides of the platform. The inspection is using Automatic Ultrasonic Testing (AUT) complete with the Engineering Criticality Assessment (ECA) and precomm activities were performed as well. The subsea fiber optic cable has been laid and post trenching was performed to bury the cable.
There are multiple approaches that a company can take to reduce the schedule and ultimately reduce the cost of offshore installation. For platform installation for example for this project is on the self upending method for jacket installation whereby less main work barge cranage capacity can be used to upend the structure underwater. The flare tower and riser platform jacket were installed using a double block upending method as the HLV crane is equipped with split block configuration on the main hoist. This reduces the duration as it eliminates the flooding and buoyancy requirement including reduction in lifting points. Furthermore, floatover installation with integrated topside design significantly reduces the duration of offshore installation including the need to have high cranage capacity to lift the topside. For pipeline installation, stalk-on of risers reduces the need to flood to pipeline prior to riser installation and eliminates a weak point of subsea flange connection for this gas pipeline. Furthermore, an overall study of the pipeline in flooded and operational condition can reduce the numbers of concrete mattress installation required to meet the design requirement. For subsea fiber optic cable, a post trenching machine that is less sensitive to weather ie. that can perform the work during monsoon, can further improve the schedule of the offshore installation. The overall schedule was improved by 20% and subsequently the cost implicated is reduced as well.
The diverless platforms installation including reverse launch self upending method for jacket installation and longitudinal floatover topside installation are the few novel approaches in the project.
Thermo-Catalytic Decomposition of Methane to Produce Low-Carbon Hydrogen and Solid Carbon
Authors: Ishak M. A. , Chai I. C. H. , Chan Y. H. , Nikulainen K. E. , Laukka J. , Hazri H. S. 
Published: September 2024

Abstract
The study explores the use of thermo-catalytic decomposition (TCD) of methane to produce hydrogen (H2) and solid carbon. The research focuses on the performance of a proprietary molten metal catalyst in a TCD reactor, evaluating methane conversion efficiency and carbon quality under various operating conditions, including flow rates, pressure, and temperature. The results demonstrate that increasing the temperature from 920°C to 1030°C enhances methane conversion efficiency from 61% to 94%. Catalyst loss was minimal at 0.03%/day, primarily due to manual solid carbon removal. The study also found that higher pressure (from 1 to 12bar) increases H2 yield, from 69% to 85%. The solid carbon produced includes valuable forms such as cryptocrystalline graphite (CG). The TCD process shows an 80% reduction in CO2 intensity compared to traditional steam methane reforming (SMR). This novel approach, termed Turquoise hydrogen production, is economical, modular, and does not require clean water or precious metals, offering potential economic benefits through the sale of high-value carbon materials.
Advancements in Production Optimization through an Innovative Hybrid Data-Physics Architecture
Authors: Matoorian Raya , Malaieri Mohammadreza , Shor Roman , Aguilera Roberto 
Published: September 2024

AbstractThis research addresses the challenges in using machine learning (ML) to assess and optimize production in unconventional wells, where computational costs (dependence on the accuracy of physical models) and complexity of wellbore design create significant challenges for decision-making and field development. A novel Hybrid Data-Physics (HDP) architecture is proposed that integrates data-driven models with physics equations embedded in a deep neural network (DNN). This approach optimizes both network and physical parameters simultaneously to predict short and long-term production rates, thereby generating more realistic operational scenarios.Using a comprehensive dataset from nearly 1300 Duvernay wells within the Western Canadian Sedimentary Basin (WCSB), the proposed HDP model significantly improves production performance estimations by refining physical parameters through iterative neural network processes. The model performs exceptionally well even with limited data, particularly in unconventional wells where geological complexities pose challenges for traditional simulation methods. By incorporating simpler equations such as decline curves, the HDP model bypasses the need for complex physics, capturing hidden complexities and operational trends.This study highlights the HDP model's transformative potential in production optimization, merging data analytics with physics-based modeling to enhance operational insights and decision-making. This pioneering approach reduces uncertainty and adapts to dynamic conditions, offering a robust, efficient tool for unconventional reservoir management. Additionally, the HDP model's ability to integrate various data types and adapt to evolving conditions underscores its versatility and practical applicability in real-world scenarios. Through this integration, the model not only enhances predictive accuracy but also provides a scalable solution that can be tailored to diverse reservoir conditions and operational needs.
Development and Evaluation of an Alternative Fluid for Offshore Fracturing of Moderate to High Permeability Formations
Authors: Vitthal S. , Van Zanten R. , Malbrough J. , Tallin A. , Reynolds M. A. , Dawson J. , Hoeman K. 
Published: September 2024

Abstract
For decades, borate crosslinked guars have been the workhorse for fracturing conventional and higher permeability formations particularly in offshore operations. The development of shales/unconventional reservoirs has led to many new learnings and innovations including new fracturing fluids. In shales, uncrosslinked polyacrylamides (PAs) at low gel concentrations (0.5-2.0 gpt) have become the dominant fluid because of their lower cost, greater friction reduction, and higher retained conductivity. The use of these fluids is commonly regarded to be limited to unconventional formations where permeabilities are in the nano-micro darcy range.
Recently, some conventional low permeability (0.1-1 mD) reservoirs have been fractured using higher concentrations (4-12 gpt) of PA in place of crosslinked gels with encouraging results. The potential of these fluids for fracturing of even higher permeability formations (10-1000 md), as commonly found offshore, has not been investigated.
This paper describes the identification and evaluation of a linear polyacrylamide (PA) fluid designed to meet the technical specifications for fracturing deepwater/offshore wells in higher permeability formations. Early evaluation identified that a very high polymer loading of 40 gallons per thousand(gpt) would be needed to meet the challenging requirements for offshore application. The evaluation of a 40 gpt polyacrylamides for use as a fracturing fluid has not been looked at by the industry. The qualification and testing program evaluated fluid compatibility, rheology, proppant conductivity, regain permeability, fluid loss, and fluid friction in comparison to a typical 35 pounds per 1000 gallons (lbm/Mgal) borate crosslinked (XL) gel. The practicality of pumping the PA system was also evaluated by an SIT test from an offshore stimulation vessel.
The results show that the 40 gpt PA fluid appears to be an attractive alternative to borate crosslinked fluids for offshore fracturing. Its benefits include higher fracture conductivity for improved productivity, reduced formation damage, lower friction pressures, and simpler QC with fewer additives. In some cases, these fluids could replace high density XL-based fracturing fluids needed for fracturing over pressured reservoirs. The SIT test confirmed its feasibility for use in offshore fracture operations.
Saudi Arabia Southern Area Oil Operations Achieving 1 Million Metric tonCO2e Emissions Avoidance
Authors: Elayoubi E. M. , Gercek S. 
Published: September 2024

Abstract
Reducing carbon emissions is a strategic action for the oil and gas industry to improve its sustainability and resilience in the face of evolving global energy demand and environmental regulations and the need to mitigate the impact of climate change. Despite the seemingly existing paradox of producing energy while reducing emissions that result from it; this paper aims to show that it is feasible and can be accomplished. Further, this paper presents a case study of Saudi Aramco, Southern Area Oil Operations (SAOO) that successfully reduced more than 1 million metric tons of carbon dioxide equivalent (tCO2e) emissions through various initiatives over the course of 3 years. SAOO set in motion a plan that has a combination of measures including energy efficiency projects, replacing equipment with lower carbon footprint, reducing flared gas volumes, and implementing a rigorous fugitive emissions detection and repair program. Moreover, this paper highlights the environmental benefits of the multitude of implemented initiatives, which ultimately led to avoiding emissions of more than 1 million metric tCO2e over a 3-year period. Along the way, SAOO availed non-renewable natural resources of oil, gas and water, as well as electricity. Additionally, SAOO improved efficiency of its operations and energy consumption; all leading to saving money while meeting customer demands safely and in an environmentally sound manner. Furthermore, insights into the challenges faced and lessons learned during the implementation process will be shared. Finally, this paper shows that reducing carbon emissions can serve the oil and gas industry meet energy demands, while addressing increasingly more stringent environmental regulations, all while staying profitable, and improving sustainability.
Development and Qualification of a High Angle Multi-Frac (HAMF) Completion System for Deepwater Subsea Wells
Authors: Vitthal Sanjay , Goncu Aykut , Spencer Virginia , Jackson Ian , Xiao Xiaohui , Song Christy Y. , Vanee Mike , Cheeseman Brenton 
Published: September 2024

Abstract
Deepwater developments in the Gulf of Mexico have historically focused on high kH (∼10,000 – 100,000 md-ft) Miocene reservoirs. Production from a single sand in these prolific reservoirs has been sufficient to justify the high costs of a deepwater well. In the last decade, there have been significant volumes discovered in Upper/Lower Wilcox age reservoirs in the Gulf of Mexico. These new discoveries typically comprise of stacked sets of lower permeability (1 – 20 md) sandstones. Several of these Wilcox discoveries have been successfully developed using cased hole vertical wells and single trip multi-zone frac-pack completion systems. Despite some of the successes, the project economics of vertical fractured wells in the lower Wilcox remains challenging due to low recovery factors (8 – 20%) and low EUR/layer.
This paper describes an alternative lower completion concept for developing these lower Wilcox reservoirs referred to as a High Angle Multi Fractured (HAMF) well design concept. The value of the HAMF concept was assessed via reservoir modeling to understand it's value for low mobility reservoirs. Supporting evidence on the EUR uplift from analogue field studies and analytical modeling is also shown.
Functional specifications for the completion system and the frac sleeve were developed based on the reservoir and operational requirements for subsea installations. Following design reviews, a completion system was selected that met the requirements, albeit with some modifications. The selected sleeve system was designed, manufactured, and went through comprehensive qualification and testing. A horizontal cemented 10 sleeve system was installed and hydraulically fractured in a land trial to evaluate the system functionality. Diagnostic evaluation including downhole gauges, radio-active tracers and 3D acoustic imaging are presented.