Journal of oil, gas and petrochemical sciences最新文献

{"title":"\"Wellbore instability prediction and performance analysis using Poroelastic modeling\"","authors":"Ing Mohamed Halafawi, Ing Lazar Avram","doi":"10.30881/JOGPS.00028","DOIUrl":"https://doi.org/10.30881/JOGPS.00028","url":null,"abstract":"","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-07-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74092870","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Comparison of Single, Binary and Temperature-Dependent Adsorption Models Based on Error Function Analysis","authors":"J. Fianu, Jebraeel Gholinezhad, M. Sayed","doi":"10.30881/JOGPS.00027","DOIUrl":"https://doi.org/10.30881/JOGPS.00027","url":null,"abstract":"The choice of adsorption model to use when accounting for gas adsorption in shale gas reservoirs is critical especially for Gas in Place (OGIP) calculations since inaccurate predictions can affect reporting of overall gas reserves. To that end, different adsorption models would have to be compared and evaluated in order to select the model that fits experimental data accurately. In examining the effect of using different error criteria for determining parameters for shale gas adsorption models, a statistically robust error analysis has been performed based on the sum of normalised error (SNE). Most shale gas adsorption modelling are conducted without finding out the most appropriate error function to use which introduces adsorption prediction errors in calculations. Five different error analysis were used including Sum of squared error (SSE), average relative error (ARE), the sum of absolute error (SAE), Marquardt’s Percent standard Deviation (MPSD), and Hybrid fractional error (HYBRID). To account for the influence of temperature in adsorption capacities, the study also compares the use of temperature dependent models, such as Exponential and Bi-Langmuir models for gas adsorption. These models can be conducted at multiple temperatures and ensure adsorption data can be obtained at any temperature beyond laboratory conditions. This is particularly useful when conducting thermal stimulation as an enhanced gas recovery in both coal/shale gas reservoirs. Journal of Oil, Gas and Petrochemical Sciences Submit your Article | www.ologypress.com/submit-article Ology Press Citation: Fianu J, Gholinezhad J, Hassan M. Comparison of Single, Binary and Temperature-Dependent Adsorption Models Based on Error Function Analysis. J Oil Gas Petrochem Sci. (2019);2(2):77-91. DOI: 10.30881/jogps.00027 78 function of pressure, but also of temperature. Section 2 of this study is, therefore, focused on describing the various single component systems, multi-component systems and finally temperature-dependent models used in the modelling of shale gas adsorption. Several works have been conducted on adsorption modelling without taking into consideration the choice of error function used in optimising the adsorption model.6,9,20–22 This often results in only one set of adsorption constants for the adsorption models being used without any serious interrogation to how accurately it fits the adsorption model to experimental data. According to Sreńscek-Nazzal et al.,23 very few detailed studies have been conducted on comparing the accuracy of the error functions used in modelling gas adsorption and also the accuracy of the predicted isotherm parameters. No study has however looked at comparing different error functions on modelling gas adsorption in shale gas reservoirs. In minimising the difference between the experimental data and the predicted results from the adsorption models, several error functions have been proposed and applied to predict optimal isotherms including sum ","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"90 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75850585","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Stochastic simulation of cavitation bubbles formation in the axial valve separator influenced by degree of opening","authors":"A. Kapranova, A. Miadonye","doi":"10.30881/JOGPS.00026","DOIUrl":"https://doi.org/10.30881/JOGPS.00026","url":null,"abstract":"A stochastic modeling of the formation of cavitation bubbles on a specific example is proposed. In this case, the initial stage of hydrodynamic cavitation in the flow part of the axial valve, the separator, was studied. A distinctive feature of this regulating device is the external location of the locking organ. An expression for the differential distribution function of the number of bubbles according to the degree of valve opening is obtained. The model takes into account the design and operating parameters of the axial valve, as well as the physical and mechanical properties of the working environment.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81310142","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Horizontal versus vertical wells interference in hydraulically fractured shale reservoirs","authors":"Samuel Igba, Lateef T. Akanji, Toochukwu Onwuliri","doi":"10.30881/JOGPS.00025","DOIUrl":"https://doi.org/10.30881/JOGPS.00025","url":null,"abstract":"The authors acknowledgethe Petroleum Technology Development Fund (PTDF) Nigeria for sponsoring this project. Special thanks to Christie Judith, and members of Computer Modelling Group (CMG) for technical support on the use of CMG-GEM software for this study.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"162 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75428388","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Wellbore trajectory optimization for horizontal wells: the plan versus the reality","authors":"Mohamed Halafawi, L. Avram","doi":"10.30881/JOGPS.00024","DOIUrl":"https://doi.org/10.30881/JOGPS.00024","url":null,"abstract":"Horizontal wellbore profile and trajectory optimization without hole problems are considered the most essential part in well planning and design. In this paper, a long radius horizontal well was trajectory optimized by selecting horizontal profile, kick off point (KOP), horizontal turn trajectory, vertical turn determination, and mud weights. After that, in order to design 3D profile, the Minimum Curvature Method (MCM)was used for survey determination. Moreover, the best well orientation was selected based on rock mechanics and wellbore stability so that the optimum trajectory could be drilled without instability problems. Real horizontal well passed through 5 targets: NRQ 255 6H-1, NRQ 255 6H-2, NRQ 255 6H-3, NRQ 255 6H-4, and NRQ 255 6H-5 are studied. The planned trajectory has found the same as real trajectory until 9 5/8” casing is landed to true vertical depth (TVD) =7230 ft. and measured depth (MD) =7343.6 ft. However, during drilling 8.5’’ hole, it was impossible to continue drilling due to the drillstring being stuck because of caved shale and hole pack off. Wellbore trajectory was redesigned and selected after building new wellbore stability and geomechanical stress models using logging while drilling (LWD) data. A 6’’ sidetrack hole was successfully drilled and hit the five targets horizontally.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-02-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84171634","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Dynamic analysis approach to evaluate in-situ combustion performance for heavy oil production","authors":"Jia Yao, Yiming Song","doi":"10.30881/JOGPS.00023","DOIUrl":"https://doi.org/10.30881/JOGPS.00023","url":null,"abstract":"In China, in-situ combustion has been widely used in heavy oil reservoirs due to its advantages, such as less thermal loss along the well bore, wider applicability range, higher displacement efficiency and so on. In order to operate the in-situ combustion successfully, it is necessary to fully require adequate production performance information. According to the principle and characteristics of in-situ combustion, dynamic analysis of in-situ combustion has been used to analyze the changes of some parameters, and corresponding rules on changes of these parameters have been achieved. Combining these drawn rules from previous results, such as reservoir pressure, produced gas compositions and combustion front position, with the developing requirements of the oil field, it is feasible to make necessary adjustments to enhance heavy oil recovery and increase profitability. Dynamic analysis on Gao 3-6-18 oil block, the main part of in-situ combustion pilot test reservoir in Liaohe Oilfield, was utilized to illustrate the feasibility of this dynamic analysis approach on evaluation of in-situ combustion performance for heavy oil production.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"171 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-01-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77496742","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Microfacies analysis and depositional environment of limestone deposits: Arochukwu – Obotme – Odorikpe axis southeastern Nigeria","authors":"Ideozu, Ikoro, Akpofure","doi":"10.30881/JOGPS.00022","DOIUrl":"https://doi.org/10.30881/JOGPS.00022","url":null,"abstract":"Microfacies analysis of limestone deposits from Arochukwu – Obotme – Odoro Ikpe Axis has been carried out complimented with biostratigraphic and sedimentological analysis. Fieldwork and Laboratory techniques employed are standard methods as used in limestone petrography (preparation of the limestone thin sections), sedimentological and biostratigraphic studies. Petrographic analysis results indicate that the limestone is made up of between 80% and 60% allochems while cements make up between 19% and 38% respectively. The allochems consists of shell fragments, whole pelecypod shells, algal grains, diatoms, foraminiferids, whole gastropods shells, bryozoans, ostracods, crinoids and coral fragments in addition to ooids/peloids, quartz grains, intraclasts and phosphate grains that make up the limestone. The cement type is interpreted as sparite and porosity type is interparticle and fracture. Important fossils identified in the limestone samples include Anomalinoides sp, Textularia sp, ostracods, pelecypods, gastropods and corals which occur either as whole skeletal forms or as fragments. Based on the microfacies characteristics, the limestone in the study area are sandy bioclastic packstone, bioclastic packstone and bioclastic wackstone bioclastic wackstone / bioclastic packstone at Locations 5 (Amuvi), (Obotme) – 2, (Asaga) 3 and 4 (Okobo) and sandstone with about 10% shell fragments at Location 2 (Odoro Ikpe), – sandy bioclastic packstone. Two microfacies identified in the study area which correspond to SMF 5 and SMF 9. The environment of deposition is interpreted as normal marine, subtidal to shallow shelf which is consistent with shallow inner neritic to middle neritic interpreted from biostratigraphy (foraminifera and palynomorphs) identified in the limestone and associated shale samples.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"557 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-01-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85764527","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Loss prevention in hydrocarbon facilities","authors":"N. Menon","doi":"10.30881/JOGPS.00021","DOIUrl":"https://doi.org/10.30881/JOGPS.00021","url":null,"abstract":"Loss Prevention techniques in hydrocarbon facilities are to prevent personal injury or loss of life, to protect the installation from fire, explosion, and operational safety hazards inherent to the facilities and Protection of the environment by early detection of hazardous conditions and the subsequent shutdown, vapor depressurizing, and ventilation of hydrocarbons. The loss prevention philosophy is normally formulated based on a maximum of one major incident occurring at any one time, and the premise that hazards can arise in any section of the facility, in varying degrees of magnitude, and from a variety of sources. On normally-manned[1] facilities, personnel are trained to manage operational activities with the highest regard for safe procedures and to react appropriately in the event of emergencies. The safety of the facility requires that the plant is inspected and maintained, safe procedures are used and improved based on experience, to minimize the probability of occurrence of hazardous conditions. On un-manned facilities[2], fire protection systems are provided based on a formal risk assessment which shows them to be necessary. This article focuses on the loss prevention philosophy implemented in a hydro carbon facility for safe operation of the facility either during manned operations or unmanned operations by focusing on parameters such as the design strategy adopted while designing the facility (such as facility layout, fire protection, flaring design, drains design), areas classifications inside the facility that is designed, escape and evacuation route, climate control etc.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"78 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-01-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89147737","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Determination of Fracture Scale Limit in Numerical Simulations of Fractured Vuggy Reservoir","authors":"Donglia Zhang, Shuyue Cui, and Zhang Yun","doi":"10.30881/JOGPS.00019","DOIUrl":"https://doi.org/10.30881/JOGPS.00019","url":null,"abstract":"In fractured vuggy reservoirs, the fracture scales differ and the fracture distribution is uneven, so fractures with varying scales may require different simulation methods. It is highly important to determine the fracture aperture limits, which are used to determine the fracture scale. In this paper, a uniform coarse grid and local refined grid are used separately in numerical simulations. The results of the two simulation approaches are compared and analyzed, based on which the fracture scale limit is determined. It is considered that the limit is reached when the two simulation results become significantly different. Based on the simulation result, it is concluded that the aperture limit of a large fracture in the numerical simulation of a fractured vuggy reservoir varies with the permeability of pores.","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"52 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80682405","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Derivation of the nonlinear dynamics of the interface between a kick gas fluid and mud system in a gas wellbore based on momentum conservation principle","authors":"M. Amadu, A. Miadonye","doi":"10.30881/JOGPS.00018","DOIUrl":"https://doi.org/10.30881/JOGPS.00018","url":null,"abstract":"","PeriodicalId":93120,"journal":{"name":"Journal of oil, gas and petrochemical sciences","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79628193","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}