bluuebunny/crossref_metadata_2025_split huggingface dataset:
Experimental and Numerical Study of Asphaltene Deposition and Precipitation in the Vapor Extraction Process
Authors: Esmaeili Sajjad , Siadatifar Seyed Emad , Mesbah Mohammad , Maini Brij , Kantzas Apostolos 
Published: March 2023

AbstractVapor Extraction (VAPEX) is one of the most promising solvent-based methods to tackle the issues associated with SAGD. Asphaltene precipitation due to solvent injection and its in-situ upgrading plays an essential role in VAPEX. As the VAPEX chamber expands laterally and vertically, the speed of the front movement and the angle of the chamber boundary varies. This research investigates the rate of asphaltene precipitation and deposition in VAPEX using different solvents.In this research, three VAPEX experiments are carried out in a physical model using bitumen and three solvents (propane, butane, and pentane), where VAPEX chamber movement, expansion rate, and the amount of precipitated asphaltenes are monitored. In addition, an Eulerian-Lagrangian model, including the Eulerian approach for the continuous phase (solvent-rich area of the chamber) and the Lagrangian approach for the extracted asphaltene solid particles by bitumen dilution, is generated for numerical modelling. The movement and the deposition of the asphaltene particles at the front are calculated and then validated with the physical model experiments.A significant amount of precipitated asphaltenes was observed when pentane was used, as it creates a pattern on the wall of the physical model, especially near the wellbore area. However, no specific pattern was observed for other experiments. In terms of chamber expansion and movement, the chamber expanded laterally and then vertically in the pentane and propane systems, while the butane system revealed vertical movement at the beginning, followed by lateral movement. In all cases, the amount of precipitated asphaltenes was always higher near the wellbore compared with areas far from the production well. A numerical model has been implemented to capture the transport phenomena, simulate the asphaltene deposition mechanisms, and reveal the variations in the behavior of different solvents.This study can assist the oil sands industry in optimizing the VAPEX process to have an effective in-situ upgrading and the highest production rate with better oil API gravity, as the literature suffers from a lack of understanding of the mass transfer physics involved in VAPEX. Also, this study sheds light on the physics behind the asphaltene deposition and precipitation process in VAPEX, as it is impossible to be understood without molecular dynamic simulation besides laboratory experiments.
Determination of Optimal Distance Between Wells in SAGD and VAPEX Methods Using Reservoir Simulation
Authors: Bataee Mahmood , Abduljabbar Hebah Mahmood , Shabib-Asl Mohsen , Hamdi Zakaria , Moradi Babak , Ridha Syahrir 
Published: March 2023

AbstractEnergy resource extraction is getting more difficult and using the enhanced and advanced level of technology for oil production is getting more common. Steam-assisted gravity drainage (SAGD) and Vapor extraction (VAPEX) are two favorable methods of EOR in heavy oil reservoirs. However, there are some obscure points about these methods, like optimum distances between wells and the overall cost of each method. The main objectives of this project were to find the best distance of wells in these types of EOR methods and to enhance the production of heavy oil reservoirs by SAGD and VAPEX methods, taking into consideration of the economic aspects of this project. In this project, SAGD and VAPEX methods were modeled to increase the production rate. Each stage of the Enhance Oil Recovery (EOR) was simulated and modified through many scenarios in terms of the injection patterns, production & injection wells’ locations as well as the adjustment of different injection steam injection and solvent injection. This project analyzed the SAGD method in the shallow reservoir (RF of 69.8%), and in the deep reservoir (RF of 38%). In addition, the maximum allowable depth to apply the SAGD method was found in this study (3500ft). Based on the calculation from the software, it was observed that the heat loss for this reservoir was around 350°F. The cumulative oil production of the SAGD method in the shallow reservoir was 3.87×10^6 bbl and the deep reservoir was2.1×10^6 bbl, and it for the VAPEX method at the shallow reservoir was 2.74×10^6 bbl, and at deep reservoir around 2.64×10^6 bbl, based on the results of each method the VAPEX method remain with the same quality at both reservoirs, however, the SAGD has the lower production in the deep reservoir which means this method is not suitable for the deep reservoir. Furthermore, the profit of each method was calculated; the profit of SAGD and VAPEX were (190.97 MM$ & 168.97 MM$) at the shallow reservoir, and (72.97 MM$ 162.32 MM$) at the deep reservoir for each process. Finally, the spacing between injection and production wells was obtained at different distances and the best distance was 30 m.
The Impact of Autonomous Inflow Control Valve on Enhanced Bitumen Recovery in a SAGD Late Life Reservoir: Lab Experiment and Simulation
Authors: Taghavi Soheila , Aakre Haavard , Moldestad Britt M.E. 
Published: March 2023

AbstractSteam assisted gravity drainage (SAGD) is an effective thermal recovery method for enhanced bitumen recovery. However, the success of SAGD operation depends on several factors. Reduction in gas and steam production is a crucial factor to achieve a successful SAGD operation. Autonomous inflow control valve (AICV) restricts the inflow of steam and/or gas in the zones where breakthrough occurs and improves recovery from SAGD operations. This can be achieved by restricting the excessive steam and/or gas production in a well that is perfectly isolated by packers. This paper presents the performance analysis of AICVs, and passive inflow control devices (ICDs) based on the results from experiments and simulations.Experiments which illustrate the performance of an orifice type ICD and AICV is presented and compared. The results confirm the significantly better ability of the AICV to restrict the production of gas and/or steam. Simulations are performed with OLGA/ROCX which provides a dynamic wellbore- reservoir model. Simulation results show that utilizing AICV in the SAGD production wells will reduce the gas and steam production by 74% after 365 days of production. The results confirmed the significant benefit of AICV in steam and/or gas reduction and consequently increased oil production. Reduction in steam production will improve the overall SAGD operation performance. This will also result in more cost-effective oil production.In addition, the annular flow in a well completed by inflow controllers was studied by using OLGA and NETool. Almost all the reservoir simulators calculate the multiphase flow properties in annulus with no-slip. This study was an attempt to initiate discussions and provide an insight into a fundamental problem that almost all the reservoir simulators are dealing with.
A Comprehensive Model for Life Cycle Assessment of Blue Hydrogen Production and Optimization Along with CO2 Enhanced Oil Recovery - Reservoirs in Alberta
Authors: Dhingra Simran , Gupta Saahil , Trivedi Japan 
Published: March 2023

AbstractThis study considers the generation of hydrogen by the conventional method of steam methane reforming using natural gas as feed. Natural gas extraction and transportation have been incorporated within the system boundaries of LCA. A base case has been assumed to account for the emissions related to the construction of necessary facilities. Calculations have been performed to determine the CO2 retention percentage based on the HCPV% of CO2 injected into the reservoir. Reservoir field segregation for CO2 sequestration and EOR have been carried out in three levels; initially with respect to location, then based on recovery potential (reserve in place), and finally narrowed down based on petrophysical parameters required for an economic EOR using CO2. The model is designed to perform sensitivity analysis for four major scenarios occurring during the process. This includes the location of the natural gas feed source, point of carbon capture, mode of CO2 transportation, and CO2 sink for sequestration and EOR.
Life Cycle Assessment of Hybrid and Green Hydrogen Generation Models for Western Canada
Authors: Gupta Saahil , Trivedi Japan 
Published: March 2023

AbstractThe aim of this paper is to conduct a techno-economic feasibility analysis of adopting a hybrid approach to hydrogen generation. This includes grey hydrogen sourced from natural gas using Steam Methane Reforming (SMR) and green hydrogen from renewable energy. The key focus is on assessing the environmental impacts of such a transition over the next decade in Western Canada while ensuring a clean and stable supply of hydrogen for various industrial processes. A life cycle assessment (LCA) is performed to ascertain greenhouse gas emissions per kg of hydrogen produced. The system boundaries extend from the set up and generation of renewable electricity at standalone and integrated renewable power plants (solar and wind) to the production of hydrogen using water electrolysis. The viability of a site for hydrogen generation from renewables is based on a study of the photovoltaic (PV) and wind potential of various locations in Western Canada. Additionally, an analysis considering the expected improvements in efficiency and scale of upcoming electrolyser technologies is incorporated into the model. Most of the life cycle CO2 emissions of solar and wind sourced hydrogen are from the initial setting up of the power plants. In comparison with SMR sourced hydrogen, total life cycle emissions show a reduction of approximately 90%. As electrolyser technology is improved, hydrogen produced using dedicated renewable sources will achieve price parity over the longer term with the model proposed. It also helps predict the rate at which a hybrid supply of hydrogen can be converted to a primarily green hydrogen supply. These results will serve as a reliable way to transition from grey hydrogen that is currently being produced to green hydrogen, without increasing costs exponentially and with no change in availability. The analysis provides a roadmap for a phased decarbonization of various industries, including the oil and gas industry, where hydrogen is used as a feedstock. Further, it acts as a technical guide to effectuating various hydrogen strategies and achieving emission reduction targets that have been envisaged by provinces in Western Canada.
Unsupervised PSD Clustering to Assess Reservoir Quality Along the Horizontal Wells: An Efficient Inflow Control Devices Design
Authors: Izadi Hossein , Roostaei Morteza , Mahmoudi Mahdi , Rosi Giuseppe , Stevenson Jesse , Tuttle Aubrey , Sutton Colby , Mirzavand Rashid , Leung Juliana Y. , Fattahpour Vahidoddin 
Published: March 2023

AbstractIn steam-assisted gravity drainage (SAGD) operations, inflow control devices (ICDs) might provide an extra pressure drop (ΔP) on top of the liquid pool's ΔP. To avoid hot-spot zones, this ΔP design heavily relies on reservoir quality. Flow-loop experiments can provide flow قate measurements versus ΔP for various nozzle designs. Therefore, an efficient ICD design should be investigated in a numerical flow simulation that represents reservoir quality and heterogeneity by employing flow-loop data.In this study, core analysis and 40 PSD data drilled in the same location are collected, and permeability for each PSD is estimated using a correlation developed in our previous study. Given PSD offers a measure of hydraulic properties and heterogeneity, it can provide an indirect indicator of potential hot-spot zones. Moreover, representative PSDs are determined by using a clustering algorithm to tie the best-designed ICD to the relevant geology. The reservoir model for the database's location is generated using real data, three tabular data from flow-loop experiments are assigned to the reservoir simulation, and the ICDs' performances are compared.The clustering algorithm generated five groups with a weighted average permeability of 4,013 mD. The first and second largest clusters with 6.55% and 35.05% fines content cover 55% and 23% of the database, respectively. By employing a relatively conservative production with subcooling between 10°C and 15°C, the cases with liner deployed (LD) ICDs offered a greater oil production rate, better steam conformance, and lower cumulative steam oil ratio (cSOR) than the cases without ICDs. However, in a rather risky production scenario with subcool between 1°C and 5°C, the case without ICDs could not be simulated in the desired the subcool temperature. Because of its enhanced steam conformance and slightly higher oil production rate, LDICD#1 was picked as the best case for the two scenarios. Compared to the case without ICDs, the oil production rate and cSOR for the case with LDICD#1 at higher subcool temperature rose by 17% and reduced by 8%, respectively. Compared to the case without ICDs, the oil production rate and cSOR for the case at lower subcool temperature with LDICD#1 raised by 21% and reduced by 12%, respectively.The findings demonstrate the effectiveness of ICDs at various subcool levels. The results could be applied in SAGD projects to reduce greenhouse gas emissions by reducing the water and natural gas usage to generate steam. Completion and production engineers would benefit from a better understanding of production relative performance to develop more effective operations design.
Carbon Sequestration: The Ignored Promise of the Non-Utilization of Carbon Route
Authors: Gupta Subodh 
Published: March 2023

AbstractDespite the mature nature of carbon capture and storage (CCS) technology and its combination with various ways of carbon utilization (CCUS), the extent of its global application has been less than 0.1% in addressing the emissions challenge. The reason is the high cost of CCS compared to the prevailing price on carbon in most jurisdictions. The objective of this paper is to present potentially low-cost alternatives to CCS/CCUS.Petroleum is the most suitable fuel for the transport needs of the society due to its unparalleled energy density and affordability. The goal of limiting atmospheric CO2 can be met equivalently either by addressing emissions from petroleum (e.g., with CCS) at a cost, or with use of low carbon fuels such as renewables. So far, alternatives to petroleum, despite some advances, have faced an even higher cost hurdle. Therefore petroleum-based fuels with carbon mitigation, deserve a fresh look. CCS has a cost range of $70 - 150/t CO2. While at this cost, oil may still have an advantage over some alternatives, it is an edge that can be further enhanced with new developing technologies such as Lower-oxidation (L-ox) among others (SPE-196109). In L-Ox, energy is derived from carbonaceous fuels in a manner that does not produce a gaseous waste product - CO2.The current work first starts with highlighting the limitations of various now-familiar options such as hydrogen, direct air capture, or renewables etc., then it discusses the technical feasibility of electro-thermo-chemical (ETC) routes that show promise and require relatively limited further development of technology, utilizing insights and support from recent advances in unrelated fields. ETC-based approaches can be used both for deriving energy without CO2 production (as in L-Ox), as well as for chemical reduction of the CO2 (produced in the combustion process of energy generation) into ‘useless’ liquids or solids. This latter approach – ‘non-utilization and sequestration’, quite opposite to CCUS, along with L-Ox presents a more economically sustainable option for carbon abatement. This paper lends substance to support the expected feasibility of each.Aside from providing a critique of various alternatives, this work offers new insights into developing novel electro-thermo-chemical methods for a low-cost carbon abatement. The significance of this is in helping sustain and preserve global living standards, through affordable, energy-dense, and carbon-neutralized petroleum.
Geomechanical Investigation of Caprock Integrity of Potential CO2 Storage Reservoirs in Lloydminster Area
Authors: Shen Chen , Wang Bo , Azadbakht Saman , Hawkes Christopher , Zhang Zhi , Zeng Fanhua 
Published: March 2023

AbstractCarbon Capture Utilization and Storage (CCUS) has been widely accepted to be an effective technology to control anthropogenic greenhouse gas emissions globally. For CO2 geo-sequestration, the key is to understand the caprock integrity to assure the safety of the long term sealing effect. However, many caprock integrity studies do not consider the effects of geochemical reactions among CO2, formation brine and caprock.In this work, we used the Lloydminster heavy oil region as the target area and studied the effects of geochemical reactions on the caprock integrity. We collected caprock core samples from both Waseca heavy oil layer and the Deadwood saline aquifer in this area. Then, static tests (Caprock submerged into formation brine over-saturated with CO2 for 40 days) were conducted in the autoclave system under the reservoir pressure (Waseca: 5.4MPa, Deadwood: 11.5MPa) and temperature (Waseca: 25⁰C Deadwood: 35⁰C) to mimic the process of CO2 storage in two candidate formations. Finally, triaxial tests were conducted to compare the change in rock strength between core samples before and after CO2 treatment. Meanwhile, XRD analysis has also been conducted to provide the information of mineral composition change on caprock samples before and after CO2 treatment.Triaxial test results showed that caprock strength has increased (higher axial stress and lateral stress) and fracture pressure increased by 15.84% and 5.45% on average in Waseca and Deadwood formation respectively. Mineralogy analysis indicated that a large amount of carbonate minerals reacted with CO2-saturated brine and stable minerals were generated which help tighten the caprock structure, triggering the self-sealing effect thus caprock strength was enhanced. The research outcomes indicate that in the future site selection for CCS projects, reservoirs with caprocks containing carbonated minerals can be competitive candidates.
CCUS and Comparison of Oil Recovery by Huff n Puff Gas Injection Using Methane, Carbon Dioxide, Hydrogen and Rich Gas in Shale Oil Reservoirs
Authors: Bao Xiaolin , Fragoso Alfonso , Aguilera Roberto 
Published: March 2023

AbstractThe objective of this paper is to compare oil recoveries by huff ‘n’ puff gas injection using methane (CH4), carbon dioxide (CO2), hydrogen (H2) and rich gas (70% CH4, 20% C3H8, plus 10% C6H14), and to advance some ideas regarding carbon capture, utilization and storage (CCUS) of CO2, and storage of hydrogen when these gases are used in huff ‘n’ puff operations.The procedure considers a real huff ‘n’ puff pilot well in the Eagle Ford shale of Texas with methane injection. Following history match of the pilot well, the injected gas is switched in the reservoir simulator to CO2, H2 and rich gas. Key to success in this process, is geologic containment, which occurs when large volumes of hydrocarbons remain over geologic time in the windows where they were generated. This is the case of the Eagle Ford shale, where hydrocarbons display an upside-down distribution, with oil on the top, condensate in the middle and dry gas at the bottom. Geologic containment permits the implementation of simultaneous huff ‘n’ puff, utilization and storage of CO2 with nil probabilities of leakage.Results show that huff ‘n’ puff gas injection can significantly increase oil recoveries to be 25-35% of the OOIP (depending on the specific injected gas), compared to about 10% by primary means during the simulation time. The benefits of huff ‘n’ puff gas injection are also applicable in other shale reservoirs where oil, condensate and dry gas present an upside down distribution. One example in Canada is the Duvernay shale. Geologic containment allows adequate and safe storage of CO2 and hydrogen without leaks at the end of the huff ‘n’ puff project. This paper also assesses and corroborates the conclusion that "significant improvements in oil recovery can be obtained by injecting gas at larger rates during shorter periods of time (as opposed to injecting gas at smaller rates during longer periods of time)." The same conclusion holds true for methane, CO2, hydrogen and rich gas injection.The novelty of this work is demonstrating the efficiency of CCUS and huff ‘n’ puff gas injection when geologic containment exists in the shale reservoir. It is a solution where everyone benefits and allows to significantly increase oil recoveries, while providing safe storage of CO2 and H2 without any leaks.
Perforating for Stimulation: Techniques, Challenges, Considerations, and Efficient Workflows
Authors: Khan Abdul Muqtadir , Binziad Abdullah , Alsubaii Abdullah , Ahmed Danish , Alotaibi Abdulmajeed 
Published: March 2023

Abstract
Connecting the wellbore and reservoir rock systems through perforating is the primary mechanism to provide a flow path for hydrocarbons. In stimulation, this pathway becomes two dimensional (in functionality) because it is required to facilitate injection of fracturing fluids and production of reservoir fluids. Ineffective perforation can add of near-wellbore complexities. In this study, we looked at different perforation techniques from classical to recent contemporary. We investigated both stimulation and intervention aspects to provide pros and cons for these techniques and evaluate their effectiveness. Six challenging scenarios in stimulation were detailed with lessons learnt, best practices, and guidelines. These included deviated wells, soft rock formations, double pipe completions, fracture diversion requirement, horizontal wells with plug-and-perforate completions, and a mature asset. The workflows included perspectives such as perforating, fracture pressure analysis, and diagnostic injections. Efficient workflows for the well engineering cycle were also developed for the case when the injection rate cannot be established due to the inefficient wellbore−rock connection. Contingency interventions and bottomhole assembly (BHA) configurations were investigated with the goal of enabling a flexible strategy in a single intervention run to enhance injectivity.
Currently, operational efficiency and business needs are paramount. This work presents integrated understanding, established practices, and resulting workflows to manage tradeoff and optimize the net present value of integrated projects.
An Improved Parameterization Procedure for NDDO-Descendant Semiempirical Methods
Authors: Ong Adrian Wee Wen , Cao Steve Yueran , Kwek Leong Chuan 
Published: March 2023

Abstract
Concept
MNDO-based semiempirical methods in quantum chemistry have found widespread application in the modelling of large and complex systems. A method for the analytic evaluation of first and second derivatives of molecular properties against semiempirical parameters in MNDO-based NDDO-descendant models is presented, and the resultant parameter Hessian is compared against the approximant currently used in parameterization for the PMx models.

Methods
As a proof of concept, the exact parameter Hessian is employed in a limited reparameterization of MNDO for the elements C, H, N, O and F using 1206 molecules for reference data (heats of formation, ionization energies, dipole moments and reference geometries). The correctness of our MNDO implementation was verified by comparing the calculated molecular properties with the MOPAC program.