Forthcoming and Online First Articles

International Journal of Oil, Gas and Coal Technology

International Journal of Oil, Gas and Coal Technology (IJOGCT)

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International Journal of Oil, Gas and Coal Technology (23 papers in press)

Regular Issues

  • A comprehensive comparative study of flow regimes, volumetrics, and hydraulic fractures performance for MIP wells of MSEEL   Order a copy of this article
    by W. David Purvis, Gary D. Holloway, Bryce E. Gagliardi, Zane T. Hall, Taylor B. Shelton, John C. Skelton, William T. Thompson, Mohammad Heshmati 
    Abstract: Reservoir and fluid properties, production rates, wellhead pressures, and hydraulic fracturing data are used to perform rate transient analysis for four MIP wells of Marcellus Shale Energy and Environment Laboratory in West Virginia, USA. Flow regimes, original gas in places, performance of these wells, stimulated reservoir volume areas, and hydraulic fractures performances are analyzed. Several RTA analysis techniques are employed and the pros and cons of each are discussed. It is shown that a log-log plot of pseudo-normalized gas flow rate vs. pMBT is the most promising for flow regime identification. Effect of completion design, e.g., lateral length and cluster spacing, on the performance of these wells is studied, as well. It is also shown that although A ? k could be used to study relative performance of these shale gas wells, A ? k per number of fracture clusters provides a more reliable measure of their relative performance. [Received: 22 October 2021; Accepted: 22 April 2022]
    Keywords: Marcellus Shale; shale gas; rate transient analysis; RTA; fracture performance; stimulated reservoir volume.
    DOI: 10.1504/IJOGCT.2022.10047785
     
  • A new developed thermal model to predict formation failure in vertical wells during steam injection   Order a copy of this article
    by Hawraa Mohammed Al-Ajmi, Adel M. Al-Ajmi, Hamoud K. Al-Hadrami 
    Abstract: As production from mature fields declines, finding technologies to improve hydrocarbon recovery is becoming extremely important in oil and gas industry. In this regard, steam injection through injection wells has proven to be an effective method for increasing oil recovery in heavy oil reservoirs. The implementation of this approach, however, raised the issue of wellbore instability due to the introduction of thermal stresses in the formations around the injection wells. In this work, a new stability model that covers the effect of thermal stresses and considers three-dimensional rock failure mechanism has been established for vertical wells. The developed model has been verified in two field cases. The model results have shown a good match with the actual field observations. The results of the study show that applying steam injection will lead to a significant dropping in the stability of the formations that can be predict by the developed geomechanical model. [Received: November 18, 2021; Accepted: May 18, 2022]
    Keywords: thermal stress; wellbore stability; steam injection; Mogi-Coulomb criterion; formation failure pressure; FFP.
    DOI: 10.1504/IJOGCT.2023.10050716
     
  • Numerical simulation of the reservoir and operational parameters to optimise steam flooding performance   Order a copy of this article
    by Arshad Raza, Farzain Ud Din Kirmani 
    Abstract: A comprehensive sensitivity analysis among various parameters is conducted to understand steam flooding in the oil reservoir. The result obtained for the scenario of crude oil’s quality and reservoir wettability indicated that light crude oils (Oil-D, Oil-F, Oil-H) are a better choice than heavy crude oils (Oil-A and Oil-B) for steam flooding in the oil-wet and water-wet reservoirs due to improved oil mobility. In addition, it was also found that a water-wet reservoir offers more oil recovery than an oil-wet reservoir regardless of the crude oil grade due to effective displacement efficiency. Furthermore, the effect of wettability becomes more pronounced for heavy crude oils. The results for the scenario of steam quality and injection rate in the water-wet system indicated that high-quality steam with an intermediate rate of injection or medium quality steam with a high injection rate is the best option to enhance the recovery from light, medium and heavy oils reservoirs. [Received: February 21, 2022; Accepted: May 15, 2022]
    Keywords: steam flooding; wettability; oil grade; steam quality; injection rate; numerical simulation; operational parameters.
    DOI: 10.1504/IJOGCT.2022.10048425
     
  • A comprehensive review on the high-density clear completion fluids for applications in HPHT Well completion   Order a copy of this article
    by Ramanand Singh, Rajiv Sharma, G. Ranga Rao 
    Abstract: This paper will provide a broad high-level comprehensive review of various high-density completion fluids (HDCF) for the high pressure and high temperature (HPHT) reservoir. The goal is to explain the advantages and disadvantages of various high-density completion fluids over conventional completion fluids. Existing completion fluids solutions are low to mid-density range, expansive, limited availability, corrosion issues, and not suitable for all types of reservoir formations. Solids-free high-density completion fluids differ from conventional completion fluids in several key aspects such as high density, solids-free, low viscosity, alkaline pH, less corrosive, minimum formation damage, and thermal stability. The desired requirements from a high-density completion fluid system include insignificant solids, providing rheological stability, fulfilling environmental conditions, and reducing reservoir damage. A suitable completion fluid system can provide sufficient density for well control while eliminating solid weighting materials which are potentially formation damaging. [Received: 13 January 2022; Accepted: 25 May 2022]
    Keywords: high-density completion fluids; HDCF; high pressure and high temperature; HPHT; solid-free; brine; formation damage; true crystallisation temperature; TCT.
    DOI: 10.1504/IJOGCT.2022.10048479
     
  • Advanced exergy analysis of the modified process of natural gas cryogenic helium extraction   Order a copy of this article
    by Peng Gao, Hong Jiang 
    Abstract: Conventional exergy analysis can only quantitatively analyse the exergy destruction of devices, while advanced exergy analysis can obtain the detailed distribution of the exergy destruction. For analysing the energy consumption of equipment in the process of cryogenic helium extraction, advanced exergy analysis was performed on a modified process for natural gas helium extraction. The analysis results show that the largest part of most equipment exergy destruction is endogenous exergy destruction; the equipment that has the largest exergy destruction in the process is the cold box, followed by the compressor. The exergy destruction of compression equipment is similar, but the exergy destruction of different heat exchange equipment is different. Sensitivity analysis shows that in order to minimise the unavoidable exergy destruction of the column, the recommended feed pressure of the primary concentration column is 3,200, and the recommended feed temperature of the cryogenic separator before the secondary concentration column is -150. [Received: January 18, 2022; Accepted: June 14, 2022]
    Keywords: natural gas; helium extraction; modified process; energy saving; energy consumption analysis; advanced exergy analysis.
    DOI: 10.1504/IJOGCT.2022.10049170
     
  • Development and evaluation of fracture gradient curve model: a case study of south-central Kazakhstan   Order a copy of this article
    by Branimir Stanisavljevic, Vesna Karovic Maricic, Irena Isakov 
    Abstract: An accurate fracture gradient value is one of the most important issues in oil and gas well design and drilling. The value of a fracture gradient is a critical parameter for determining the drilling mud weight and selecting the proper depths for setting the casing in the planning process of drilling operations. This paper proposed the new curve model of fracture gradient for the south-central Kazakhstan (central Asia) region based on the analysis of leak-off test and format integrity test results. Data from more than 400 tested wells were analysed and compared with the results of existing methods for predicting the fracture gradient and with the results from previous drilling projects in that region. By using the new curve model, the more precise values of fracture gradient are determined. Besides an improved fracture gradient model development and validation, the models analytical expressions are presented. The article's most important results are determining the model's values of fracture gradient and providing a more accurate calculation of mud weight, less mud losses, more precise evaluations of cementing operations, better selection of the casing setting depth and improved drilling safety. [Received: February 13, 2022; Accepted: June 2, 2022]
    Keywords: fracture gradient; new curve model; oil well design; drilling; Kazakhstan.
    DOI: 10.1504/IJOGCT.2022.10049370
     
  • Experimental investigation of divalent ions and screening in smart water on calcite rock surface   Order a copy of this article
    by Mohammad Hossein Zareian, Seyed Reza Shadizadeh, Abolghasem Emamzadeh 
    Abstract: Massive demand for fossil fuel against limited available oil conventional reservoirs worldwide highlights that innovative enhanced oil recovery method. Nowadays, due to the accessibility of seawater and rivers, smart water and low salinity water injection have gained more attention. This paper addresses the mechanisms behind smart water injection and studies a real case from a carbonate oil reservoir. For this purpose, contact angle measurement was employed to screen and find the best smart water composition among different types of water. A core flooding experiment was used to evaluate the performance of the smart water injection in calcite rock. Two different scenarios were implemented in the core displacement experiment to examine the effect of divalent ions. Based on the experimental results, the main mechanism behind the smart water injection is the wettability alteration of the calcite rock surface. Also, as the most central divalent ions, an increase in calcium ions has been effective in increasing the water wetness of the rock surface, resulting in river water with double calcium ion content as the best smart water. [Received: November 8, 2021; Accepted: June 2, 2022]
    Keywords: smart water; carbonated reservoir; wettability alteration; contact angle; coreflooding; calcite.
    DOI: 10.1504/IJOGCT.2022.10049474
     
  • A review of all aspects of dry coal cleaning methods and evaluation of widely used applications   Order a copy of this article
    by Murat Kademli 
    Abstract: Although all developments in the energy industry, coal holds still its vital place and seems to will have a major role in future. That is why the direct utilisation of coal becomes impracticable even impossible in those days. Thus, the aim of this review is that all aspects of dry coal cleaning methods are overviewed, analysed and evaluated, including the applicability to the industry in the face of wet methods. The density-based methods have potential than other dry coal cleaning methods and had made great development within the coal preparation industry. The Ep values of air jigs or air tables are between 0.13 and 0.26 g/cm3, but fluidised bed separation method has between 0.03 and 0.07 g/cm3 and it provides to rivalry with wet methods and is a serious alternative for coal preparation. [Received: January 17, 2022; Accepted: July 20, 2022]
    Keywords: dry coal preparation; separation efficiency; density-based methods; non-density-based methods; comparison of dry methods; particle size effect.
    DOI: 10.1504/IJOGCT.2022.10049836
     
  • Smart plugging and low-damage foam drilling fluid technology for CBM drilling   Order a copy of this article
    by Zhiyong Li, Yu Zhou, Long Qu, Xufei Zhang 
    Abstract: Once the drilling fluid filtrate invades along microfractures of coal reservoirs during the drilling process, it can cause notable wall instability. Foam spheres would infiltrate and move through the pores and into the fractures under drilling differential pressure between the wellbore and formation. As a result, microfoams deformed and the volume became larger to achieve plugging. In order to improve the foam foaming performance and stability during drilling, thereby enhancing the plugging effect, a new type of anionic Gemini surfactant, ZY-1, was designed and synthesised. Not only did ZY-1 reduce surface tension but also the half-life of foams produced was more than three times that of conventional foaming agents. Furthermore, contact angle recovery rate of cores and the desorption rate of drilling fluid reached 86% and 88.24%, respectively. And the plugging rate and gas permeability recovery value after pollution were both above 90% for the developed low-damage drilling fluid. [Received: October 24, 2021; Accepted: April 26, 2022]
    Keywords: coalbed methane; CBM; plugging; reservoir protection; surfactant; foam drilling fluid.
    DOI: 10.1504/IJOGCT.2022.10050257
     
  • Experimental and numerical simulation of the deposition characteristics of NH4Cl particles in 90 elbow   Order a copy of this article
    by Xinyu Liu, Jianxun Quan, Xiaofei Liu, Haozhe Jin, Guofu Ou 
    Abstract: The deposition of NH4Cl particles in the equipment can cause potential safety hazards in petrochemical enterprises. In this study, a gas-solid-flow experimental equipment has been built to explore the characteristics of NH4Cl deposition with different humidity and fluid velocity. The results show that: the gas flow rate, relative humidity (RH), and duration have little influence on the deposition position of NH4Cl particles, but they affect the deposition amount of NH4Cl particles greatly; due to the formation of liquid droplets and the influence of secondary flow in the elbow, the deposition increases rapidly in the range of 45-75 and reaches 0.57 g at 67.5. After evaluating the experiment, a computational fluid dynamics (CFDs) coupled with DEM method is employed to analyse the flow parameters of particles. Numerical results of particle deposition show a good agreement with the corresponding experimental data. [Received: February 25, 2022; Accepted: July 6, 2022]
    Keywords: gas-solid flow; particles deposit; NH4Cl; CFD-DEM coupling.
    DOI: 10.1504/IJOGCT.2022.10050385
     
  • Evaluating the effect of petroleum price volatility on government revenue in Ghana   Order a copy of this article
    by Riverson Oppong, Clarence Nii Aryee Aryeequaye, Frank Gyimah Sackey 
    Abstract: The Ghanaian economy is highly exposed to petroleum price fluctuations (volatility) since petroleum revenues is a major contributor to total government revenue. The resulting volatility in government revenue also has a bullwhip effect on other sectors such as the private sector, making planning difficult and complex. This study examines the effect of petroleum price volatility (PPV) on government revenue and economic growth using quarterly time series data for the period 2010 to 2020. The study adopts the autoregressive distributed lag (ARDL) for estimating the models. Three regressions are estimated to address the set objectives of the study. A pairwise correlation matrix was adopted to determine the relationship between the variables. The findings indicate petroleum price volatility has a negative effect on government revenue both in the short run and the long run. Furthermore, the findings also demonstrate petroleum revenue makes a significant positive contribution to the growth of Ghanaian economy. [Received: January 5, 2022; Accepted: June 18, 2022]
    Keywords: price volatility; autoregressive distributed lags; ARDL; petroleum revenue; cointegration; Ghana.
    DOI: 10.1504/IJOGCT.2022.10050521
     
  • Preparation and mechanism of viscosification of recyclable associating polymer with low damage for fracturing   Order a copy of this article
    by Chengyu Zhou, Min Zhou, Linghao Zeng, Yuan Sun, Mingyao Lei, Yifan Li, Benhui Li, Wei Wan, Peng Zhang 
    Abstract: Due to the complicated and variable formation conditions, P(AM-AA-APPEA) was developed. The viscosification mechanism was analysed via relative molecular weight, infrared spectroscopy (IR), nuclear magnetic resonance spectrum (1H-NMR), rheological properties, and scanning electron microscopy (SEM). It shows that M = 1.25*106 (M represents molecular weight). The polymer is composed of amides, hydroxyl groups and benzene rings. When the shear rate is 170 s-1 with continuous shear for 120 min at 90 C, the viscosity is maintained at about 50 mPa.s. Gel breaking performance, formation damage, dynamic filtration, matrix permeability and fracture conductivity experiments show that it has easy glue breaking, low surface tension, low residue content, good compatibility and good rheological property. At 0.3% thickener concentration, the conductivity damage rate is 41.56%, the dynamic filtration coefficient is 4.24 * 10-5 m.s-1/2, and the permeability loss rate is 16.4%. The recovery performance experimental results show that it has good recyclability. [Received: October 22, 2021; Accepted: July 28, 2022]
    Keywords: associating polymer; viscosification mechanism; low damage; fracturing; scanning electron microscopy; SEM.
    DOI: 10.1504/IJOGCT.2022.10050563
     
  • A productivity model for vertical wells with horizontal multi-fractures   Order a copy of this article
    by Tianyu Luo, Songxia Liu, Shuai Liu 
    Abstract: Hydraulic fracturing is an important technique for reservoir stimulation. However, the productivity of vertical wells with horizontal fractures in shallow formations for quick reservoir evaluation has been under-researched. In this study, we approximate the actual flow by four regimes: 1) radial flow in far field; 2) vertical linear flow in near fracture area; 3) radial flow in near fracture area; 4) radial flow inside the fracture. Then we established an analytical productivity model for vertical wells with multiple horizontal fractures in shallow formations. For one fracture, the result deviation of our model is less than 5.3% from the classical method. For four fractures, our result is within 9% of deviation compared with CMG numerical simulation software. This model can be used to optimise parameters of horizontal fractures. [Received: November 11, 2020; Accepted: January 2, 2022]
    Keywords: vertical well; horizontal fracture; productivity; analytical model; fracture optimisation.
    DOI: 10.1504/IJOGCT.2022.10044928
     
  • Laboratory measurement of oil viscosity reduction due to CO2 injection at high-pressure, high-temperature conditions   Order a copy of this article
    by Yaser Alghawi, Hamid Rahnema, Edgard Parra 
    Abstract: This work presents the use of rolling-ball viscometer to measure viscosity reduction of two dead oil samples injected with CO2 at a temperature of 168°F and a pressure range of 1,114.7 psi-3,514.7 psi. First, a new digital control unit was designed to replace the analogue unit. Afterwards, viscometer was calibrated with Cannon S-6 and S-60 viscosity standards. Next, validation was conducted by measuring the viscosity of n-decane at a temperature range of 77°F-266°F and a pressure range of 514.7 psi-2,014.7 psi. Next step was the investigation of CO2 effect in reducing n-decane viscosity at 130°F-266°F temperature range and 1,014.7 psi-2,014.7 psi pressure range. Results showed significantly reduced viscosities of the CO2 mixture compared to n-decane viscosities, especially at lower temperatures. Afterwards, viscosity of two distinct crude samples was measured at 168°F and 14.7 psi-3,514.7 psi pressure interval. Next, CO2 was injected to respective oil samples and system viscosity was measured at the same temperature and at pressures between 1,114.7 psi and 3,514.7 psi. [Received: September 20, 2021; Accepted: January 30, 2022]
    Keywords: viscosity; viscometer; rolling-ball; carbon dioxide; CO2; crude oil; enhanced oil recovery; EOR.
    DOI: 10.1504/IJOGCT.2022.10046894
     
  • Influence of relative permeability, capillary pressure, and well orientation in the geological carbon sequestration in a saline aquifer   Order a copy of this article
    by Abhishek Gupta, Akshoy Ranjan Paul 
    Abstract: In carbon capture and sequestration (CCS), geological sequestration of carbon dioxide (CO2) in deep saline aquifers with porous and permeable rocks is one of the most feasible among various solutions to sequester CO2. Here, the TOUGH2 numerical simulator was validated with the analytical model developed predicting the CO2 behaviour in confined saline aquifers. The sensitivity of the numerical model was examined by changing the model of fluid relative permeability (RP) and capillary pressure (CP) functions. Corey's RP functions and Van Genuchten's CP function is most effective to capture the gas saturation (SG) well. The effect of CO2 injection, well orientation, and its length in a simplified saline aquifer model are also demonstrated. This study reveals that the horizontal well configuration is most acceptable. For the same injection well length (at 100 m), 22% drop in the pressure rise is computed in horizontal well as compared to its vertical counterpart. [Received: October 9, 2021; Accepted: February 7, 2022]
    Keywords: carbon capture and sequestration; CCS; CO2 geological sequestration; saline aquifers; relative permeability; capillary pressure; well orientation.
    DOI: 10.1504/IJOGCT.2022.10045886
     
  • Experimental evaluation of imbibition effect in Mahu conglomerate reservoirs   Order a copy of this article
    by Jing Zhang, Jianhua Qin, Xibin Fan 
    Abstract: Since hydraulic fracturing fluid plays a significant role in the soaking process, it is interesting to present a study of the imbibition effect by slickwater, brine and guar gum. In this paper, we conducted an experimental study of the imbibition effect on recovering the tight Mahu field, which are the largest discovered conglomerate reservoirs. The recovery performance by different imbibition fluids was compared. Nuclear magnetic resonance (NMR) technique was used to understand what type of pore scale contributes mostly to the imbibition recovery process. Laboratory results indicated that the lowest interfacial tension in some sense is adverse to spontaneous imbibition. The imbibition rate with the largest interfacial tension is the highest. When the bond number falls in a value where both capillary forces and gravity drainage play a role in the recovering process, the oil recovery factor is significant in this case. The oil recovery factor by slickwater imbibition is 40.76%, which is much higher than brine and guar gum. It is observed that the slickwater displacement still recovered additional oil after the imbibition process. [Received: August 17, 2021; Accepted: January 2, 2022]
    Keywords: imbibition; conglomerates; bond number; recovery mechanism.
    DOI: 10.1504/IJOGCT.2022.10046893
     
  • Optimisation research on a thin coal seam isolated island coal face mining back channel layout and its support parameters   Order a copy of this article
    by Bo Xue, Yong Zhang, Chen Wang, Yong Liu, Yufei Tian, Yuyang Wang 
    Abstract: The large deformation and serious failure of the anchor bolt (cable) of a thin coal seam island coal face retrieval mining roadway is a very difficult technical problem to solve. This article is based on the background of the Jizhong Energy Company Handan Mining Group Guo Erzhuang mine 22204 face mining. Through research, theoretical analysis, numerical simulation and experimental methods that revealed the characteristics of the perimeter rock of the roadway and the destruction mechanism, the composite support scheme of 'anchor + anchor cable + lining' was designed to calculate the reliability of the ultimate bearing capacity of the scheme. The simulation analysis of the design with numerical simulation software was used to verify the rationality of the support scheme. Finally, the composite support was successfully applied in the Guo Erzhuang mine. The onsite monitoring results showed a 64% reduction in the roof subsidence and a 70% reduction in the deformation of two gangway. The support scheme effectively controlled the convergent deformation of the retrieval roadway and achieved good industrial testing expectations. The results of the research could provide a reference for the control technology of a thin coal seam island coal face retrieval roadway under similar geological conditions. [Received: October 30, 2020; Accepted: February 03, 2022]
    Keywords: thin coal seam; island coal; surrounding rock control; support optimisation.
    DOI: 10.1504/IJOGCT.2022.10046891
     
  • Production and characterisation of biodiesel extracted from Indian bamboos   Order a copy of this article
    by Renjith Krishnan, Lalhmingsanga Hauchhum, Rajat Gupta, Gokul Gopan 
    Abstract: Here, bamboo types found in India such as Dendrocalamus asper, Pseudosasa japonica, Dendrocalamus giganteus, Sinarundinaria falcata, and Bambusa vulgaris are considered for the thermochemical conversion process. Primarily, these bamboos are converted to bio-oil by the pyrolysis process and found that Bambusa vulgaris yields more bio-oil than all other bamboos. Later, the bio-oils generated from bamboos are converted to biodiesels through the transesterification process. The properties such as relative density, acid number, kinematic viscosity, cetane number, flash point, cloud point, pour point, ash content, carbon residues, and higher heating value of all biodiesels are done. It is found that biodiesel generated from Bambusa vulgaris has the property values neared to standard biodiesel, so the properties of different blends of Bambusa vulgaris biodiesel with petro-diesel are also found. Here, the result shows that the blend BV15 is suitable for CI engines as it keeps all the property values of good biodiesel. [Received: November 21, 2021; Accepted: January 13, 2022]
    Keywords: bamboo; bio-oil; biodiesel; pyrolysis; transesterification.
    DOI: 10.1504/IJOGCT.2022.10045588
     
  • Polymeric flocculants: agglomerate investigation of fines and sand particles at multiphase flow   Order a copy of this article
    by Noor 'Aliaa Amira M. Fauzi, Tarek Ganat, Khaled Abdalla Elraies, Suzalina Zainal, Najeebullah Lashari, Wasan Saphanuchart, Tushar Sharma 
    Abstract: For oil engineers, sand production control is one of the most important issues due to the present global oil price situation. Solids are prevented from being transported by capturing fines and sand within the separator. Particle size was determined by evaluating polymers in terms of performance, rheology, and compatibility. In this work, the main objective is to reduce fines and sand transfers that cause significant surface equipment issues and to evaluate the agglomeration effectiveness of two types of sand, sand samples A and B. Adsorption effectiveness determines the newest chemical formulation. The experiments made were on sand, fluid, polymer, and agglomeration performance (bottle tests and dynamic flow tests). A combo-polymeric system (high aggregation at 1% KCl and 100 mg/L combo-polymer mixture) shows rapid agglomeration. [Received: August 10, 2021; Accepted: February 05, 2022]
    Keywords: agglomeration; chemical; hydrocarbon; polymer; sand; viscosity.
    DOI: 10.1504/IJOGCT.2022.10046892
     
  • Laboratory simulation of the influence of chromatographic effect and microbial oxidation on hydrocarbon microseepage   Order a copy of this article
    by Guo-Jian Wang, Yu Zou, Ronald W. Klusman, Jun-Hong Tang, Li Lu 
    Abstract: An experimental apparatus has been constructed with various experimental conditions to simulate the influence factors of the hydrocarbon gases microseeping from the deep reservoir to the surface. Both the chromatographic effect and the microbial oxidation effect are considered in the experiment. The results show that: the vertical hydrocarbon microseepage has the characteristics of a 'jump-over migration effect'; the coupling of a chromatographic process and microbial oxidation has less effect on the composition ratios of microseepage hydrocarbons, whereas the microbial oxidation has a large effect on the isotope values of methane; and the normal alkane and iso-alkane content of vertical microseepage show obvious differences due to the influence of chromatographic process and microbial oxidation. These experimental results may help to identify the genetic origins of the vertically migrating hydrocarbons, and thus promote the successful application of the surface hydrocarbon geochemical exploration technology. [Received: July 1, 2021; Accepted: February 23, 2022]
    Keywords: microseepage hydrocarbon; chromatographic effect; microbial oxidation; simulation experiment; geochemical anomaly identification.
    DOI: 10.1504/IJOGCT.2022.10047168
     
  • Improvement of roller cone drill bit design by using finite element method and experimental study   Order a copy of this article
    by Hassan Mohammadi Majd, Behrooz Hassani 
    Abstract: An approach for increasing the rate of penetration (ROP) of roller cone bits is presented. The proposed approach is based on 3D finite element method (FEM) simulation as well as field test results that were carried out on the Aghajari formation located in the southwest of Iran. In order to reduce the operation time by improving roller cone bit design, the FEM simulation of the complex nature of the contact between the roller cone bit and the formation was performed and the obtained results were compared with the field test data. Results were employed to improve the geometry of the bit profile. Based on the improved design, a roller cone bit was manufactured and employed in the field experiment to assess the performance and to verify the numerical simulation. The results show a positive effect of the improvements on the ROP which leads to a considerable reduction in drilling costs. [Received: September 15, 2021; Accepted: February 26, 2022]
    Keywords: roller cone bit; finite element method; FEM; profile design; Drucker-Prager; rate of penetration; ROP.
    DOI: 10.1504/IJOGCT.2022.10046751
     
  • Study on gas migration law and influencing factors of gas drainage   Order a copy of this article
    by Yi Wang, Chenguang Zhao, Bing Wu 
    Abstract: Gas drainage is the main measure of coal mine gas prevent and control. The analysis of gas drainage influencing factors and the optimal design of drill holes are very important to the drainage effect. In this study, a fluid structure coupling model of coal seam gas based on stress equation and transfusion equation is established. The influencing factors of gas drainage are extraction time, occurrence depth, extraction pressure and dill hole diameter. COMSOL software is used to simulate the influence of different factors on gas drainage effect, and the distribution law of the gas pressure is obtained. Finally, the field monitoring of gas extraction in Yuwu mine was carried out, which comparing with the simulation, the results show that the trend of model simulation data is consistent with that of field data, which prove the accuracy of the model. The model can be used to further study the law of gas migration in the process of drainage. And provides a basis for the optimal design of gas drainage. [Received: August 25, 2021; Accepted: March 14, 2022]
    Keywords: gas extraction; gas migration law; numerical simulation; fluid structure coupling model; porosity; permeability; drilling optimisation design.
    DOI: 10.1504/IJOGCT.2022.10047065
     
  • Rheological studies on a novel brine-based high density completion fluid for applications in oil and gas reservoirs   Order a copy of this article
    by Ramanand Singh, Rajiv Sharma, G. Ranga Rao 
    Abstract: Although, brine-based completion fluids are commonly used in the oil and gas reservoirs, options for high density completion fluids are rare. Existing solutions are either highly toxic or prohibitively expensive. We explore a novel 'high density completion fluid (HDCF)' and investigate its formulation magnesium bromide in aqueous medium. The experimental results are from different ranges of temperature (95°F to 175°F) and specific gravity of 1.47. The rheological properties (i.e., apparent viscosity, plastic viscosity and yield point) have been analysed and it demonstrates a non-Newtonian completion fluid, which follows the Bingham plastic model having low apparent viscosity, plastic viscosity and yield point; and these are favoured for industrial application. Furthermore, we analyse the HDCF for stability, solid free nature, low viscosity and low precipitation to ensure desired field application. Our results are expected to be beneficiary for early and timely oil and gas production using the completion program. [Received: September 30, 2021; Accepted: April 20, 2022]
    Keywords: rheology; apparent viscosity; magnesium bromide; solid free; completion fluid; brine.
    DOI: 10.1504/IJOGCT.2022.10047640