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Item Open Access Well productivity enhancement using matrix acidizing-a Niger Delta case(2015) Ohia, Nnaemeka; Igwilo, K; Duru, UAs a result of the rapid reduction in productivity of well B14, south west of the Niger Delta region, the need to investigate the cause of the damage was initiated. When it was identified fine migration as the major cause of the production decline, acid stimulation was recommended as the mitigation strategy. Acid (matrix) stimulation practice involves the pumping of acid into the formation through the wellbore at the rates and pressures below the fracture gradient of the formation. Conventionally, hydrochloric acid (HCL) is used for carbonate formations while hydrofluoric acid (HF)/ mud acid (HCL +HF) is best suited for sandstone formations. Also, in a very high damaged formation and very high temperature environment that requires prolong contact of the HCL acid with the steel pipe, due to the severe corrosion that will occur, organic acids are more suitable. In stimulating this well, mud acid was used and the well was stimulated using organic mud acid or organic clay acid. Stimulating this well led to a total incremental production gain of over 485 BOPD (150% gain) however a corresponding reduction in skin was not observed This paper reviews and highlights the operational best practices as utilized in this project as well as the potential cause for an increase in skin even after a stimulation job.Item Open Access In-situ combustion: Reservoir candidacy/project selection criteria(s) for Niger Delta heavy oil reservoirs(2018-09) Ossai, Patrick Godwin Oyindobra; Duru, Ugochukwu Ilozurike; Obah, Boniface; Ohia, Princewill NnaemekaThere is a drastic need for the oil companies operating within the onshore(s) and offshore(s) of Nigeria to critically start looking at the various possibilities of heavy oil production from the nation’s various fields located in the Niger Delta region using already available Enhanced Oil Recovery techniques/methods such as In-situ combustion (ISC), CHOPS and SAGD. This study focused on In-situ combustion as a means of enhancing likely heavy oil production in the Niger Delta using the Nelson & McNeil 1961 ISC model. The study developed applicable screening criteria(s) for both reservoir candidacy and ISC project selection in the Niger Delta. Corresponding programs and flow-charts that would allow petroleum engineers in the Niger Delta to theoretically evaluate production erformances using his/her computer(s) was also developed. It was discovered also during our course of work that all six reservoirs considered in both Case 1 (Venezuela reservoir) and Case 2 (Niger Delta reservoirs) met this study’s reservoir candidacy selection criteria(s) for possible applicability of an ISC project performance evaluation(s) with respect to enhancing oil production. These reservoirs were further graded / ranked based on their theoretical ISC project performances as calculated and evaluated using a well known ISC model as documented in the ISC handbook.Item Open Access Geomechanical principles of hydraulic fracturing method in unconventional gas reservoirs(Kambohwell Publisher Enterprises, 2018-05) Unwana, Solomon Anwana; Ossai, Patrick Godwin Oyindobra; Duru, Ugochukwu Ilozurike; Ohia, Princewill Nnaemeka ,; Selegha AbrakasaUnconventional gas production from shale formation is not new to oil and gas experts worldwide. But our research work was built around hydraulic fracturing technique with focus on the Perkins Kern-Nordgren (PKN) 1972 hydraulic fracturing model(s). It is a very robust and flexible model that can be used on two major shale reservoirs (with the assumption of a fixed height and fracture fluid pressure). The essence was to compare detailed geo-mechanical parameters extracted from wire-line logs with Perkin-C model to select the right well as candidate for simulation. It aided in the prediction production of shale gas from tight shale formations. These also helped in reviewing safe and economical ways of obtaining clean energy sources. Based on similarities in well and formation properties our research team subjected IDJE-2 well (located in the Agbada shale Formation of Niger Delta, Nigeria) to various conditions, equations and assumptions proposed by the study model while also validating our results with the PENOBSCOT L-30 well, located in Canada (with existing profound results from stimulations). The PENOBSCOT L-30 well (Case 1) and IDJE-2 well (Case 2) were both subjected to same conditions, equations and assumptions as applicable to the study model to enable us compare and evaluate stimulation performances. But both cases tend to react differently. However the fluid behavior at constant injection time increases at about 99.64%. Whereas, the maximum width at wellbore shows that a constant increase of fracture width will yield an increase in propant permeability, tensile strength and Poisson’s ratio for Case 1 & 2. Our research results show how rock properties can affect fracture geometry and expected production rates from stimulated shaleItem Open Access Hydraulic evaluation of drilling fluid performance on hole cleaning for different rheological models(Society of Petroleum Engineers, 2005-08-03) Duru, Ugochukwu; Chukwu, Godwin A.; Obah, BonifaceBottom hole cleaning is an important function of drilling fluid that needs special attention during a drilling operation. Good hole cleaning results in an increase in penetration rate and, at the same time, reduces the operating drilling cost. One of the effective steps towards reducing operating cost is to have a well designed drilling hydraulics program that will optimize the energy used at the mud pumps. A variety of hydraulic optimization designs are available depending on the cutting structure and the formation to be drilled but a common objective is to maximize the available hydraulics to provide optimum hole cleaning. Many authors have discussed various ways of effecting proper hole cleaning using different approaches and methods. Fluid velocity, pump rate, fluid rheology, drill pipe eccentricity, pipe rotation and particle settling velocity, among others were used at various times to evaluate effective hole cleaning. The economic appraisal of hole cleaning using hydraulic horsepower and jet impact force by Wright et al (2003) have proved that both can be used for the design of optimum hydraulic programs on the basis of minimum drilling cost. In this study, basic hydraulic models for vertical oil wells were used to determine the pressure drop in a drill string circulating system and hence, the equivalent circulating density (ECD) using both the Bingham plastic and Power law fluids’ rheological models. From the slip velocity relationships, the transport efficiency of the cuttings for both models was determined. An economic evaluation of the hydraulics from the energy and horsepower requirements for both models showed that the power law fluid model provided a better transport efficiency, and hence more economical in terms of minimum drilling cost.Item Open Access Reliability evaluation of onitsha power distribution network via analytical technique and the impact of PV system(U. P., 2014-06) Izuegbunam, F. I.; Uba, I. S.; Akwukwaegbu, I. O.; Dike, D. O.This paper evaluates the Reliability of Onitsha power distribution network using analytical technique and the level of improvement achievable through application of photovoltaic (PV) system at injection substations. ETAP simulation software was used to run the power flow and reliability assessment of the Network. The investigation revealed that before the PV installations the total revenue lost due to outages in 2009, 2010 and 2011 amounted to N17,439,247,940; N28,718,370,004 and N61,131,521,807 respectively. Whereas after the PV installation the total revenue lost reduced to N6,769,656,987, N12,718,370,004 and N21,359,660,013 respectively representing 61.2%, 55.7% and 65.1% reduction in revenue loss for the period under review.Item Open Access Dynamic security assessment of 330KV Nigeria power system(U. P., 2012-07) Izuegbunam, F. I.; Ubah, C. B.; Akwukwaegbu, I. O.The security of power system operation is a measure of its reliability; hence the planning and real-time operation of power system requires regular security assessment. This paper presents a dynamic security assessment of the Nigeria 330 kV power network. It considered the installed capacity of the power system alongside the available capacity as well as network structure in terms redundancy for flexibility. Some weak areas of the system were identified and the security status of the network assessed under large disturbance condition. Results match expectations as the system’s response to impressed contingencies were discussed. Feasible corrective measures proffered for improved system’s security.Item Open Access Load flow control and analytical assessment of voltage stability index using thyristor controlled series capacitor (TCSC)(U. P., 2014-04) Akwukwaegbu, I. O.; Okwe, Gerald Ibe- Voltage stability problem has become one of the major concerns in the operation of power system in recent years. The reason is that power systems all over the globe are being operated with reduced margins because of the exponentially growing demands and the associated stress on the power transmission resources aggravated by a general reluctance to invest in improvement of the electric grid infrastructure. Moreover, voltage instability has been responsible for severe network collapses world-wide and subsequently, the possible threat of voltage instability is becoming more pronounced in power utilities. In order to avoid the voltage collapse, this paper presents maximum loadability identification of a load bus in a power transmission network which is achieved by performing voltage stability study by utilizing Fast Voltage Stability Index (FVSI) as an indicator of the maximum loadability termed as Qmax. In this technique, reactive power loading will be increased gradually at particular load bus until the FVSI reaches close to unity. Therefore, a critical value of FVSI was set as the maximum loadability point. This value ensures the system from entering voltage-collapse region. The main purpose in the maximum loadability assessment is to plan for the maximum allowable load value to avoid voltagecollapse; which is important in power system planning risk assessment index. In order to improve the system stability, Thyristor Controlled Series Capacitor (TCSC) is installed in the most severe line, which is identified from the line stability index values of all lines in a system. TCSC is a series compensated device used for voltage stability enhancement, which is to be connected in series with transmission line. It can control the transmission line impedance to improve the line transfer capability and to regulate the receiving end bus voltage. This proposed technique was applied to solve real problems in a 14 bus power grid using Power flow analysis. Power flow is very necessary for planning, operation, economic scheduling and exchange of power between utilities. Newton Raphson iterative algorithm is used for solving the power flow problems due to its ability to converge very fast with small number of iteration. Simulation of power flow solutions with and without TCSC was done using MATLAB 7.5 program. The result shows that the application of TCSC improved the voltage profile of the system and furtherly enhanced the power flow.Item Open Access Water flooding process of oil recovery in the Niger Delta region of Nigeria(U. P., 2020) Chikwe, A. O.; Duru, U. I.; Obasi, E. C.Water flooding is a process of hydrocarbon recovery where water is injected through injection wells into the reservoir to recover oil from the production well. It is usually injected in a reservoir rock that has fluid communication with the producing reservoir. Waterflooding is secondary recovery mechanism whose purpose is to maintain and support reservoir pressure thus displacing hydrocarbon towards the producing wellbore. In this study a reservoir in the Niger Delta, Reservoir OZ-70 is used for evaluation and economic analysis of the water flooding project using five spot pattern. Reservoir OZ-70 had oil at the start of the flood to be 2.38MMSTB. The reservoir was left depleted with the unrecovered oil in it. But based on the analysis carried out on secondary oil recovery by water flooding, 0.98 MMSTB was recovered from 2.38 MMSTB about 41.1% at a breakthrough period of 428 days. When water viscosity was increased from 0.60 to 0.65, 0.99MMSTB about 41.7% was recovered. Economic evaluation of the reservoir oz-70 water flooding project was also performed. Net present value (NPV) was calculated to be $8.74million while internal rate of return (IRR) at a discount rate of 10% was 126.3%. Therefore, since the NPV is greater than zero and IRR greater than hurdle rate (10%) the project is economically viable.Item Open Access Enhanced recovery of heavy oil in the Niger Delta: Nelson and Mcneil model a key option for In-Situ combustion application(Canadian Research & Development Center of Sciences and Cultures, 2025) Ossai, Patrick G. O.; Ohia, Princewill N.; Obah, Boniface; Duru, Ugochukwu I.; David O. OnaiwuIn-situ heavy oil recovery involves several field tested enhanced oil recovery methods/techniques with applicable models. Such field tested techniques include non-thermal oil recovery, hybrid oil recovery and solvent-base oil recovery. The viabilities and field successes recorded by these in-situ heavy oil recovery techniques/methods cannot be overemphasized. But, the main focus of this study is on heavy oil recovery using in-situ combustion with attention on the application of Nelson and McNeil model as documented in the in-situ combustion handbook (Partha, 1999). We subjected data(s) obtained from five (5) heavy oil reservoirs located within the same field in the Niger Delta to the correlations, equations, assumptions and calculations proposed by our study model. This enabled the research team to carry out performance evaluations while considering in-situ combustion implementation using our proposed model. Our result outcomes were further validated with a foreign heavy oil reservoir having similar reservoir properties. Our study results show how viable and profitable (with possible commercial production) heavy oil production from unconventional reservoirs in the Niger Delta would be. Currently, most of the internally generated oil revenue by the Nigeria government is from cheap/light oil obtained from conventional reservoirs (which is fast declining globally).Item Open Access Optimum tubing size prediction model for vertical multiphase flow during flow production period of oil wells(Springer, 2020-10-04) Nwanwe, C. C.; Nwanwe, U. I.; Nwanwe, O. I.; Chikwe, A. O.; Ojiabo, K. T.; Umeojiako, C. T.Optimum tubing size (OTS) selection was traditionally done by using nodal analysis to perform sensitivity analysis on the different tubing sizes. This approach was found to be both cumbersome and time-consuming. This study developed a user-friendly and time-efficient OTS prediction computer model that could allow Petroleum Production Engineers to select the best tubing size for any vertical oil well. The tubing size selection was based on the present operating low rate, economic considerations and future operating low rate as defined by the OTS selection criteria of this study. The robustness of the model was tested using tubing sizes ranging from 0.824 to 6.0 inch in a vertical well producing from both saturated and undersaturated oil reservoirs. The 2.750-inch tubing was found the OTS for both scenarios. In the validation, the results obtained from the novel OTS prediction model and Guo et al. (Petroleum production engineering: a computer-assisted approach, Gulf Professional Publishing, Cambridge) spreadsheet program using the Pettman–Carpenter method were in excellent agreement for operating low rate but not for operating pressure. Furthermore, the novel OTS prediction model was in excellent agreement with the same spreadsheet program based on modified Hagedorn–Brown correlation for both operating fowl rate and pressure. The results showed that the model developed in this study is reliable and can be used in the field for vertical oil wells. The new model could as well inform the Production Engineer when the well would need artificial lifts for economic production of the well. It was recommended that Newton–Raphson and modified Hagedorn–Brown methods be used in future study.Item Open Access A Novel approach to estimation of leak location in an oil pipeline(U. P., 2015-08) Obibuike, U. J., Obah, B., Aboniyi, C., Anyadiegwu, C. I. C. & Ogwo, O. U. JThis paper presents various approaches to the location of leak in an oil pipeline. However these approaches are based on the available input data for the leak location study. The first approach is the hydraulic gradient intersection approach using Pipes and Excel worksheet. This method relies on the expectation that a leak disturbance settles out eventually to a new Steady-state position. The second approach utilizes a new concept of flow through an orifice and liquid relief through a valve to evolve a criterion for elapsed leak time in an event of a leak as well actual leak time to determine leak location. Orifice area was determined through a liquid relieving scenario and back-pressure at the point of leak assumed to be at atmospheric pressure. A set of mathematical equations were developed and integral solution of the form function of a function was used to solve the resulting differential equation describing the depressurizing process. The model was however validated using a pipeline profile data of a pipeline X which has suffered spill in time past at Niger Delta region where it performed well. The two approaches vary in their input data requirements as mentioned before. Key inputs to the former are the input and output flow conditions of temperature, pressure and flow rate while the latter requires the time (shut-in time and time of leak). Key outputs are the rate variation of flow rates against leak location.Item Open Access Advances in well design(SAVAP International, 2013) Kerunwa, Anthony, Fekete, P. O. & Anyadiegwu, C. I. CModern drilling technologies are emerging progressively to meet current challenges in well operations. Operators are going into much more complex environments, and drilling conditions become much tighter. Conventional well designs are no longer able to handle these new environments. The result is increased drilling costs, Non Productive Time, hole collapse, etc. While well engineers are worried by these developments, the busy schedule of most companies does not give room for delegating staff to proper study and research as to implement recent improvements into pre-drill plans. In some cases, economics may not favour adoption of new drilling methods as well. This work is a review of selected advances in well design available to oilindustries today. Particularly emphasis was laid on the well design aspects of Drilling with Casing (DWC), Managed Pressure Drilling (MPD), Solid Expandable Systems, Air drilling and Geo mechanical Modelling for wellbore stability. To show the benefits of these advanced well design applications, case studies from different well operations have been presented. The yardstick for measuring these benefits is conventional drilling and well designs methods. While these results might not have covered all areas of improvements in well design, it is expected that this review will provide oil companies with an idea of trends in well design and areas for improving drilling performance at various operational levels. Hole problems will be minimised by such large margins that cost savings in drilling budget becomes significant. Reoccurrence of well problems may be minimised.Item Open Access Performance evaluation of a biomaterial in an aqueous based drilling mud at high pressure high temperature(Canadian Research & Development Center of Sciences and Cultures, 2019) Duru, U. I.; Onyejekwe, I. M.; Uwaezuoke, N.; Isu, D. O.Oil reserves are found in deep formations where the conditions of temperature and pressure are always high. These conditions have direct effects on the rheological properties of drilling fluid as they vary with increasing temperatures and pressures. Two sets of experiment were carried out on weighted and unweighted mud samples at a temperature of 250o F and 500psi pressure. The presence of locally sourced additives helped the mud to remain pseudoplastic at these conditions and also retained essential properties of the mud need for drilling operations. The plastic viscosities of the weighted and unweighted mud were 36cP and 27cP respectively. The yield stresses were 149lb/1002 ft and 110lb/1002 ft for the weighted and unweighted samples while the fluid loss volumes were approximately equal. The thickness of the cake for the weighted sample is 3.7mm and 4mm for the unweighted sample. The weighted sample with a reasonably higher PV has a better hole cleaning ability than the unweighted sample. Mucunna Solannie performed excellently to retain the essential properties of these formulations at 250o F and is therefore recommended as a HPHT drilling mud additive.Item Open Access Reduction in annular pressure loss by mud rheology control-a means of mud pump pressure optimization: A case study of a Niger Delta Well(International Knowledge Press, 2016-02-18) Onugha, Ifeyinwa N.; Igwilo, Kevin C.; Duru, Ugochukwu I.This paper proposes two linear mathematical models for the reduction of annular pressure loss in a Niger Delta well- X, so that mud pump pressure is optimized. Data related to mud rheology, mud pump pressure, drill cuttings and the well geometry is available for well X which has already been drilled. The first linear model involves the reduction in pressure drop in the drill collar-casing annulus and the second linear model involves the reduction in pressure drop in the drill pipe-casing annulus. These models express reduced or critical annular pressure drops in terms of two mud rheological parameters- the yield point and plastic viscosity. For combined annular drill collar and drill pipe pressure loss, this paper proposes that the two linear mathematical models can be solved simultaneously to obtain optimum yield point and plastic viscosity of the drilling mud system to be employed for hole cleaning in the combined drill collar-casing and drill pipe-casing annulus. The HerschelBulkley model is employed as the rheological model that represents the properties of the drilling mud system analyzed and is generated for eight rheological cases each of the drill collar and drill pipe annular hole cleaning as well as two cases of the combined drill collar and drill pipe annular hole cleaning.Item Open Access Influence of metakaolin and nano-clay on compressive strength and thickening time of class G oil well cement(Scholarone manuscript, 2019) Arinkoola, Akeem Olatunde; Salam, Kazeem Kolapo; Alagbe, Solomon Oluyemi; Afolayan, Ayodele Sunday; Salawudeen, Taofeek Olalekan; Jimoh, Monsurat Omolola; Duru, Ilozurike Ugochukwu; Hammed, Jimoh Olugbenga; Adeosun, Tunde AdamsonIn this research, the Compressive Strength (CS) and Thickening Time (TT) of oil well cement with different Metakaolin (MK) dosage was evaluated in the presence of Nanoclay (NC). The variables were randomized in a Box-Behnken Design (BBD) experiment using 5 - 15 wt. % MK by weight of cement and 5-15 wt. % NC by weight of MK. The CS and thickening time were assessed and optimized using Response Surface Methodology (RSM). The result shows that, CS increases linearly with NC and hyperbolically with MK. Cement slurries with 5–15 wt.% NC shorten TT by about 35 minutes in the presence of 5 wt.% MK. TT reduction of 103 minutes was recorded when MK was increased to 15 wt.% in the slurry with 5wt.% NC. At optimum condition, 10.78 wt. % MK and 13.73 wt. % NC resulted in CS and TT of 3029±2.65 psi and 410±1.25 minutes, respectively.Item Open Access Performance characteristics of Parkia biglobosa as fluid loss control agent in aqueous mud system(2020) Uwaezuoke, Nnaemeka; Onwukwe, Ibuchukwu S.; Igwilo, Chinwuba K.; Duru, Ugochukwu I.; Obah, B.Recent trend in the use of biomaterials in oilfield applications involves minimum refining and purification. The effectiveness of Parkia biglobosa as fluid loss control additive in aqueous based mud was tested according to API standard. The effect of temperature on the formulation was determined to identify any deviation due to presence of the material in the formulation. At 8ppb concentration used, 3.6mL fluid loss and 1.1mm filter cake thickness were recorded; compared with 8mL and 0.8mm, and 5.4mL and 0.8mm of Pleurotus and PAC respectively. Both fluid loss and filter cake thickness increased with increase in temperature. A low-flat discontinuous gel was observed at elevated temperatures which is desirable. Other drilling fluid rheological parameters were not adversely altered by the presence of the material, even at elevated temperature conditions. The biodegradable material was found to be suitable as fluid loss agent, both in effectiveness and environmental consideration since it is biodegradable, and might reduce cost of formulation since minimum processing is required.Item Open Access Performance evaluation of Mucuna solannie as a drilling fluid additive in water-base mud at cold temperature(Academic journals, 2020) Duru, U. I.; Onyejekwe, I. M.; Isu, D. O.; Uwaezuoke, N.; Arinkoola, A. O.Weighted and unweighted aqueous mud formulations from a biomaterial, at cold temperature of 5°C, were tested for their rheological characteristics. Based on API guidelines and recommended equipment for drilling fluid tests, the rheological properties of the formulations were determined. The muds exhibited pseudoplastic behaviour. The fluid loss volumes of the weighted and unweighted muds are 14 and 21 ml, respectively, while the filter cake thicknesses are 2.5 and 3 mm, respectively. The yield stresses of the weighted and unweighted muds are 209 and 159 lb/100 ft2 , respectively. Plastic viscosity of 42 cP for the weighted mud against 23 cP for the unweighted mud showed that the weighted mud has a better cutting lifting capacity if PV is used as an indicator. Mucuna solannie additive can also perform in cold temperature, and has the potential to be used in cold temperature drilling.Item Open Access Performance of water injection in oil rim reservoir recovery factor(STM Journals, 2014) Onwukwe, Stanley; Duru, Ugochukwu; Obah, BonifaceThis study examines the potential improvements in recovery factors in optimizing oil production from oil rim reservoirs through water injection and without water injection (i.e. primary production) scenarios in the development strategies of the oil rim reservoirs.A generic simulation model developed from ECLIPSE dynamic simulator was used as core representative of oil rim reservoirs to experiment production optimization with and without water injection. Reservoir data of permeability, oil rim thickness, fluid properties, m-factor, aquifer strength and process parameters sampled from the Niger Delta oil field were used and a lacket-Burman Design of experiment (DOE) was used to give a central sensitivity results from the simulation runs. Recovery factors were obtained for the two different production scenarios: primary production and production under water injection. Regression analyses were carried out on the experimental results to generate proxyequations for recovery factor for the two production scenarios. It was observed that the use of water injection is irrelevant for oil rims with active water aquifer. However, waterinjection will increase the ultimate recovery of oil rim reservoirs under weak aquifer.Item Open Access Optimizing liquid recovery from a gas condensate reservoir operating below dew poin(U. P., 2019) Ariche, Princewill O; Onwukwe, S. I.; Duru, Ugochukwu; Chikwe, AnthonyFluid flow in gas condensate reservoir is very complex and involves phase changes, multiphase flow of the fluid, phase redistribution in and around the wellbore and retrograde condensation. This study seeks to evaluate the effect of hydraulic fracturing on gas and liquid production of gas condensate reservoir with pressure below dewpoint. This research utilised a compositional simulator (Eclipse 300) with a single vertical well model, relative permeability model,fluid and PVT parameters to model a gas condensate reservoir operating below dewpoint. Two cases were investigated. Case 1 is a control scenario where the reservoir was unfractured and allowed pressure to deplete using the reservoir energy. Case 2 represents a hydraulic fractured reservoir to ascertain the effect of fracturing on liquid and gas production. The hydraulic fracturing job was done using dual porosity dual permeability condensation model in Eclipse 300 with a conductive fracture attached closer to the wellbore with various fracture parameters. After ten years of production, the cumulative liquid production was 957803STB for the unfractured case. Fracturing the reservoir at fracture half length of 1000ft, fracture width of 0.03ft, fracture permeability of 1000md gave a cumulative liquid production of 1055936STB after ten years of production. Increasing the fracture half length to 2000ft, fracture width to 0.06ft, fracture permeability to 2000md gave a total liquid production of 1056137STB. Further increase of fracture half length to 3000ft, fracture width to 0.1ft and fracture permeability to 3000md gave a total liquid production of 1057139STB. The result obtained showed that continuous increase in fracture parameters may not result to an economic liquid recovery. Based on cumulative liquid production and economic feasibility of the project, a fracture half length of 1000ft, fracture width of 0.03ft and fractured permeability of 1000md proved optimal for the reservoir considered.Item Open Access A comprehensive review on the feasibility and challenges of millimeter wave in emerging 5G mobile communication(U. P., 2019) Agubor, Cosmas Kemdirim; Akwukwuegbu, Isdore; Olubiwe, Mathew; Nosiri, Chikezie Onyebuchi; Ehinomen, Atimati; Olukunle, Akande Akinyinka; Okozi, Samuel Okechukwu; Ezema, Longinus; Okeke, Benjamin ChukwujekwuThis article presents a comprehensive review on the feasibility and challenges of millimeter wave in emerging fifth generation (5G) mobile communication. 5G, a multigigabit wireless network is the next generation wireless communication network. The mmWave cellular system which operates in the 30-300 GHz band has been proposed for use as the propagation channel. Its large bandwidth potential makes it a candidate for the next-generation wireless communication system which is believed to support data rates of multiple Gb/s. High frequency bands such as mmWave have channel impairments. These impairments are challenges that are necessary to be properly understood. Employing mmWave as a propagation channel requires dealing with these challenges which this paper is aimed at reviewing. One aim of the work is to discuss these challenges in a more elaborate manner using simple mathematical equations and graphics to ensure clarity. To achieve this, current related works were studied. Challenges and solutions are identified and discussed. Suggested research directions for future work are also presented. One is developing suitable electronic such as fast analog-to-digital (ADC) and digital-to-analog (DAC) systems necessary for the transmitter/receiver (TX/RX) system.