Papers by Hisham Ben Mahmud
In the petroleum industry, multiphase flow dynamics within the tubing string have gained signific... more In the petroleum industry, multiphase flow dynamics within the tubing string have gained significant attention due to associated challenges. Accurately predicting pressure drops and wellbore pressures is crucial for the effective modeling of vertical lift performance (VLP). This study focuses on predicting the multiphase flow behavior in four wells located in the Faihaa oil field in southern Iraq, utilizing PIPESIM software. The process of selecting the most appropriate multiphase correlation was performed by utilizing production test data to construct a comprehensive survey data catalog. Subsequently, the results were compared with the correlations available within the PIPESIM software. The outcomes reveal that the Hagedorn and Brown (HB) correlation provides the most accurate correlation for calculating pressure in FH-1 and FH-3 while the Beggs and Brill original (BBO) correlation proves to be the optimal fit for wells FH-2 and Gomez mechanistic model for FH-4. These correlations show the lowest root mean square (RMS) values of 11.5, 7.56, 8.889, and 6.622 for the four wells, respectively, accompanied by the lowest error ratios of 0.00692%, 0.00033%, 0.00787%, and 0.0011%, respectively. Conversely, Beggs and Brill original (BBO) correlation yields less accurate results in predicting pressure drop for FH-1 compared with other correlations. Similarly, correlations, such as Orkiszewski for FH-2, Duns and Ros for FH-3, and ANSARI for FH-4, also display less accuracy level. Notably, the study also identifies that single-phase flow dominates within the tubing string until a depth of 6000 feet in most wells, beyond which slug flow emerges, introducing significant production challenges. As a result, the study recommends carefully selecting optimal operational conditions encompassing variables such as wellhead pressure, tubing dimensions, and other pertinent parameters. This approach is crucial to prevent the onset of slug flow regime and thus mitigate associated production challenges.
A mini-investigation on enhanced oil recovery evolution (2007 – 2020)
MATEC web of conferences, 2023
Modeling interaction between CO2, brine and chalk reservoir rock including temperature effect on petrophysical properties
Energy geoscience, Oct 1, 2021
Abstract Carbon dioxide (CO2) capture and sequestration through CO2 enhanced oil recovery (EOR) i... more Abstract Carbon dioxide (CO2) capture and sequestration through CO2 enhanced oil recovery (EOR) in oil reservoirs is one of the approaches considered to reduce CO2 emission into the atmosphere. The injection of CO2 into a subsurface geological formation may lead to chemical reactions that may affect the formation pore structure and characteristics. In this study, the effect of CO2–brine–rock interaction on the rock petrophysical properties and mineral volume fraction was numerically investigated during CO2 injection into a chalk reservoir rock. A 3D numerical modelling and simulation were conducted using COMSOL® Multiphysics commercial software of computational fluid dynamics (CFD) to simulate CO2–brine core flooding process in a chalk core. The model was validated against a core–scale experimental data from the literature. Simulation differential pressure data matched the literature experimental data closely and consistently indicating good agreement between them. Temperature effect on the performance of CO2–brine–chalk sequestration was also evaluated in the present study. Results indicated that porosity was only slightly affected by temperature increase during CO2 injection in contrast to permeability that was substantially affected by temperature. Moreover, chemical reactions enhanced as temperature increased leading to significant increase in permeability. Thus, carbonated brine sequestration excelled at elevated temperature due to increased acidity which governs the sequestration process. The developed model maybe considered as a reliable tool to optimize various operating parameters of CO2–brine sequestration.
Energy geoscience, Oct 1, 2021
This is a PDF file of an article that has undergone enhancements after acceptance, such as the ad... more This is a PDF file of an article that has undergone enhancements after acceptance, such as the addition of a cover page and metadata, and formatting for readability, but it is not yet the definitive version of record. This version will undergo additional copyediting, typesetting and review before it is published in its final form, but we are providing this version to give early visibility of the article. Please note that, during the production process, errors may be discovered which could affect the content, and all legal disclaimers that apply to the journal pertain.
Mineral analysis of sandstone formation using chelating agents during sandstone matrix acidizing
Petroleum Research
CO2 EOR and injection process: Role of nanomaterials
Elsevier eBooks, 2022
Journal of Petroleum Exploration and Production Technology
In the original publication of the article, the corresponding author name was incorrectly publish... more In the original publication of the article, the corresponding author name was incorrectly published as Ali Al-Rubaie; it should read Ali Al-Rubaye.
Study on the synergism of cellulose nanocrystals and janus graphene oxide for enhanced oil recovery
Geoenergy Science and Engineering
Experimental investigation of the influence of carbonated water on sandstone and carbonate rock properties
Petroleum Research
Analytically evaluate relative permeability at unsteady-state core flooding
Journal of Petroleum & Environmental Biotechnology, Jul 27, 2017
International Journal of Petroleum and Petrochemical Engineering, 2017
Oil recovery options are generally divided into three main stages: primary, secondary and tertiar... more Oil recovery options are generally divided into three main stages: primary, secondary and tertiary recovery. In the initial oil production stage, primary oil recovery is a result of displacement energy that naturally occurs in reservoirs. These natural driving mechanisms include depletion, gas cap, water and combination drives. Secondary oil recovery takes place as oil production rate significantly decreases. The main purpose of secondary oil recovery is to control pressure in the reservoir to maintain or increase oil production rate by introducing external fluid to the reservoir. It is usually done with processes like water flooding or gas injection. Recovery factor from primary and secondary oil recovery is usually around 20-40% and is affected by reservoir rock properties, fluid properties and geological heterogeneities (Romero-Zerón, 2012). Tertiary oil recovery is considered if cost to production ratio of secondary oil recovery process becomes no longer economical. The ultimate target of tertiary oil recovery, also known as enhanced oil recovery (EOR) is to improve the overall oil sweep efficiency. In EOR processes, the recovery factor increases to about 30-60% (Sino Australia Oil and Gas Ltd, 2013). An EOR process increases hydrocarbon production by altering formation properties for conducive extraction (Needham and Doe, 1987). The true meaning of EOR is the ultimate oil recovery that can be recovered from a reservoir in a cost-effective manner on top of oil economically recovered after primary and secondary oil recoveries. Research and pilot testing are conducted to further develop different methods of EOR. These methods includethermal recovery and non-thermal methods such as chemical flooding, miscible flooding, immiscible gas drive and microbial treatment. As wetting and non-wetting phases flow together in porous medium, each phase follows separate and distinct paths. The distribution of the two phases is according to their wetting characteristics. Because wetting phase occupies smaller pore openings at small saturations, and these pore openings only slightly contribute to flow, the presence of small wetting phase saturation would only affect nonwetting phase permeability to limited extent. And because non-wetting phase occupies central or Abstract: The advances in coring and core analysis techniques provide the premise to measure required petrophysical properties and to acquire simultaneously other reservoir rock dependent parameters. The objective of coring and core analysis is to reduce uncertainty in reservoir evaluation by providing data representative of the reservoir conditions. Relative permeability data are essential to understanding multiphase flow in porous media and reservoir simulation that are usually obtained by steady-state flow or unsteady-state flow methods. In this study experiments were performed using unsteady-state method that considers the effect of fluid viscosity and average saturation at breakthrough. Three core plugs of different petrophysical properties were used to conduct core flooding tests where the variations in oil residual saturation and oil-water relative permeability were measured and compared with Johnson, BossIer and Naumanncorrelation, Pirson's correlation and Corey's model. Relative permeabilities and residual oil saturations obtained by Pirson's correlation were lower than those of Johnson, Bossler and Naumann correlation and Corey's model. It was observed that as core plug permeability increases, water breakthrough slightly increases.
Geochemical and physical alteration of clay-rich shales under supercritical CO2 conditions
Applied Geochemistry
Inconsiderable fraction of the hydrocarbon can be produced by the natural drive of the reservoir.... more Inconsiderable fraction of the hydrocarbon can be produced by the natural drive of the reservoir. Practical knowledge has proven that when the reservoir pressure is depleted, the recovery factor nearly reaches 20%. Some of heavy fluid reservoirs cannot be produced by all natural energy drivers. As a result, improved oil recovery is introduced as a strategy to increase oil recovery. Prior implementing an improved oil recovery process in a field, it is essential to investigate its potential for achievement. However, the objective of this project is to evaluate the improved oil recovery in a sandstone reservoir is considered in this study. GEM compositional reservoir simulator has been utilized, having injection and production wells. A model is developed to perform history matching with a field production data to verify the model results and to examine an improved oil recovery method on cumulative production and recovery factor. The results showed that the water flooding has insignificant impact on the cumulative oil production, while implementing horizontal production wells had improved and doubled the reservoir performance by a factor of 2 and reducing oil saturation from 80% to 30%.
Geochemical modelling of CO2 interactions with shale: Kinetics of mineral dissolution and precipitation on geological time scales
Chemical Geology, 2022
The impact of supercritical CO2 on the pore structure and storage capacity of shales
Journal of Natural Gas Science and Engineering, 2022
PT Matahari Putra Prima Tbk (MPPA) is an Indonesian retail company which is the owner of the Mata... more PT Matahari Putra Prima Tbk (MPPA) is an Indonesian retail company which is the owner of the Matahari Department Store and Hypermart Supermarkets and Foodmart networks. For more than 50 years, the company group PT Matahari Putra Prima Tbk (MPPA) has successfully developed Matahari Department Store, Matahari Supermarket and finally Matahari Market Place, which is a supermarket for the premium segment in Kelapa Gading, Bogor, Serpong, Metropolis and GTC in Makassar. Since November 2002, MPPA has also operated 46 Boston Drugs & Pharmacy stores in its supermarkets to support the concept of one stop shopping. However, behind all this, PT Matahari Putra Prima Tbk (MPPA) still has problems in the field of occupational health and safety (K3). This writing aims to identify, assess and provide recommendations for controlling the OSH risks that exist in PT Matahari Putra Prima Tbk (MPPA). The method used in this paper is Job Safety Analysis (JSA) based on mobile android. Data collection was ca...
Facile asymmetric modification of graphene nanosheets using κ-carrageenan as a green template
Journal of Colloid and Interface Science, 2021
The synthesis of Janus nanosheets using κ-carrageenan (κ-Ca) as a green template endows a greener... more The synthesis of Janus nanosheets using κ-carrageenan (κ-Ca) as a green template endows a greener and more straightforward method compared to traditional approaches of using wax template. We hypothesize that the hydrogen bonding interaction between κ-Ca and graphene oxide (GO) allows partial masking of GO's single facet, paving the way for the asymmetric modification of the exposed surface. GO is first encapsulated within the porous hydrogel matrix formed by κ-Ca to isolate one of the facets. The exposed surface was then selectively hydrophobized to produce an amphiphilic asymmetrically modified graphene oxide (AMGO). The properties of AMGO synthesized under different κ-Ca/GO ratios were studied. The κ-Ca/GO interactions and the properties of GO and AMGO were investigated and characterized. AMGO was successfully produced with a yield of 90.37 % under optimized synthesis conditions. The separation of κ-Ca and AMGO was conducted without organic solvents, and the κ-Ca could be subsequently recovered. Furthermore, the porous hydrogel matrix formed by κ-Ca and GO exhibited excellent shape-retaining properties with high thermal tolerance of up to 50 °C. Given these benefits, this newly developed method endows sustainability and open the possibility of formulating more flexible material synthesis protocols.
Comparative elemental, mineral and microscopic investigation of sandstone matrix acidizing at HPHT conditions
Petroleum Research, 2022
Application of Nanotechnology in Enhanced Oil Recovery
Nanotechnology for Electronic Applications
Multiphase Transient Flow in Pipes
The development of oil and gas fields in offshore deep waters (more than 1000 m) will become more... more The development of oil and gas fields in offshore deep waters (more than 1000 m) will become more common in the future. Inevitably, production systems will operate under multiphase flow conditions. The two–phase flow of gas–liquid in pipes with different inclinations has been studied intensively for many years. The reliable prediction of flow pattern, pressure drop, and liquid holdup in a two–phase flow is thereby important.
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Papers by Hisham Ben Mahmud