Wisam I. Al-Rubaye, Dhiaa S. Ghanem, A. Saleem, Hayder A. Al-Attabi
Errors can occur in the wellbore position according to the fact the survey tools are not completely accurate; therefore, prediction of well path position is imperative for safe and cost-effective drilling operation. The aim of this paper is an analysis of collision avoidance as well as assessment and optimization of wellbore trajectory for minimizing the risk of collision by applying different anti-collision and planning techniques. Thus, anti-collision analysis of pad drilling in the Iraqi oil field has been investigated using Industry Steering Committee for Wellbore Survey Accuracy (ISCWSA) error model to estimate the wellbores position and assess their separation using different techniques available in the industry. Three actual offset wells X1, X2, X3, and one proposed principal X4 well in a drilling pad have been used in the collision avoidance model. Separation factor, ladder, and travel cylinder plots revealed a high possibility of X4 proposed well colliding with X3 actual offset well. The separation factor of 0.75 and 7.5 m center to center prove that the current design of X4 principal design doesn’t meet the anti-collision standards, accordingly, a design revision must be highly considered. The field operator hasn’t revised the well design due to the lack in the assessment of anti-collision risks, thus, the survey service company has advised the operator to modify the predetermined well trajectory due to major risk of collision with X3 offset well and the well has been sidetracked. After reviewing and optimizing the well trajectory by using slant and optimum align (curve hold curve) planning methods, the anti-collision results have been greatly improved. The results showed that, through adopting an adequate anti-collision risk assessment and the modified well design, problems associated with the execution of the improper well design could be totally eliminated.
{"title":"Anti-collision Analysis of Pad Drilling and Optimization of Wellbore Trajectory: A Field Case Study","authors":"Wisam I. Al-Rubaye, Dhiaa S. Ghanem, A. Saleem, Hayder A. Al-Attabi","doi":"10.52716/jprs.v12i2.654","DOIUrl":"https://doi.org/10.52716/jprs.v12i2.654","url":null,"abstract":"Errors can occur in the wellbore position according to the fact the survey tools are not completely accurate; therefore, prediction of well path position is imperative for safe and cost-effective drilling operation. The aim of this paper is an analysis of collision avoidance as well as assessment and optimization of wellbore trajectory for minimizing the risk of collision by applying different anti-collision and planning techniques. Thus, anti-collision analysis of pad drilling in the Iraqi oil field has been investigated using Industry Steering Committee for Wellbore Survey Accuracy (ISCWSA) error model to estimate the wellbores position and assess their separation using different techniques available in the industry. Three actual offset wells X1, X2, X3, and one proposed principal X4 well in a drilling pad have been used in the collision avoidance model. Separation factor, ladder, and travel cylinder plots revealed a high possibility of X4 proposed well colliding with X3 actual offset well. The separation factor of 0.75 and 7.5 m center to center prove that the current design of X4 principal design doesn’t meet the anti-collision standards, accordingly, a design revision must be highly considered. The field operator hasn’t revised the well design due to the lack in the assessment of anti-collision risks, thus, the survey service company has advised the operator to modify the predetermined well trajectory due to major risk of collision with X3 offset well and the well has been sidetracked. After reviewing and optimizing the well trajectory by using slant and optimum align (curve hold curve) planning methods, the anti-collision results have been greatly improved. The results showed that, through adopting an adequate anti-collision risk assessment and the modified well design, problems associated with the execution of the improper well design could be totally eliminated.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-06-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80830165","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}
The paper deals with the analysis of indicators of changes in investment in the oil sector in Iraq to study the traditional patterns and the current patterns developed for oil investment in the extractive, transformational and distributive fields that were employed in Iraq to redraw the map of the economy in general and the oil industry in particular. The paper proceeds from the premise that the licensing rounds that took place in the Iraqi oil sector did not show their tangible results for internal and external reasons that were diagnosed. The study reached the main conclusion that the real performance and progress in the Iraqi oil sector was unbalanced and slow in some areas and that investment in it would create a balance between the urgent needs for expansion of investment projects and their capital requirements.
{"title":"Investment Trends in the Iraqi Oil Sector (Upstream – Oil Refining – Gas Treatment - Transportation - Distribution) (2003 – 2020)","authors":"Aysar Y. Fahad, Hisham Yas Shaalan","doi":"10.52716/jprs.v12i2.662","DOIUrl":"https://doi.org/10.52716/jprs.v12i2.662","url":null,"abstract":"The paper deals with the analysis of indicators of changes in investment in the oil sector in Iraq to study the traditional patterns and the current patterns developed for oil investment in the extractive, transformational and distributive fields that were employed in Iraq to redraw the map of the economy in general and the oil industry in particular. The paper proceeds from the premise that the licensing rounds that took place in the Iraqi oil sector did not show their tangible results for internal and external reasons that were diagnosed. The study reached the main conclusion that the real performance and progress in the Iraqi oil sector was unbalanced and slow in some areas and that investment in it would create a balance between the urgent needs for expansion of investment projects and their capital requirements.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"1079 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-06-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84707398","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}
Pub Date : 2022-04-21DOI: 10.52716/jprs.v12i1(suppl.).622
Fahad M. Al-Najm, Amer Jassim Al-Khafaji, F. Sadooni
The X Formation, which dates from the Late Cenomanian to the early Turonian, is the largest carbonate reservoir in Iraq's South Mesopotamian Basin. There are two shallowing-up depositional periods in it, which begin with deep water mudstone associated with wackestone, which gradually shallows into rudist and is dominated by big foraminifera shoals and barriers, which are followed by lagoonal and intertidal facies. The identification of five distinct reservoir rock types, including mB2, mB1, CRII, mA, and CRI, was based on a combination of sediment types and diagenetic processes that influenced porosity types. The formation oil geochemical studies point to a Lower Cretaceous marine carbonate source depositional environment that is early mature and anoxic.
{"title":"The Late Cretaceous X Reservoir petrophysics properties and its Oil Geochemistry in the Nameless Oilfield, Mesopotamian Basin, South Iraq","authors":"Fahad M. Al-Najm, Amer Jassim Al-Khafaji, F. Sadooni","doi":"10.52716/jprs.v12i1(suppl.).622","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).622","url":null,"abstract":"The X Formation, which dates from the Late Cenomanian to the early Turonian, is the largest carbonate reservoir in Iraq's South Mesopotamian Basin. There are two shallowing-up depositional periods in it, which begin with deep water mudstone associated with wackestone, which gradually shallows into rudist and is dominated by big foraminifera shoals and barriers, which are followed by lagoonal and intertidal facies. The identification of five distinct reservoir rock types, including mB2, mB1, CRII, mA, and CRI, was based on a combination of sediment types and diagenetic processes that influenced porosity types. The formation oil geochemical studies point to a Lower Cretaceous marine carbonate source depositional environment that is early mature and anoxic.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"74 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79998622","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}
Pub Date : 2022-04-21DOI: 10.52716/jprs.v12i1(suppl.).626
H. Almalikee, H. K. Almayyahi, Methaq Khazal Al-Jafar
Water injection is the main strategy to increase oil production and support reservoirs pressure in the X oilfield and almost any other oilfield. The available source for the water injection in X field is the Qarmat Ali river which is located 20km to the north. However, the amount of water from that river is insufficient. Therefore, alternative water sources were investigated and among them, it was identified the Nahr Umr aquifer as the most promising. Nahr Umr is a regional giant aquifer; it is composed of high porous high permeable sandstone at an average depth of 2900m. The analysis of Nahr Umr aquifer water showed that it has a very high salinity (240000 ppm) almost composed of sodium and calcium chlorides, free of Oxygen, no solid particles were observed, no quantities of dissolved H2S, and very low occurrence of bacteria owing to the high water salinity and high temperature of the aquifer. On other hand, aquifer water contains a significant amount of dissolved CO2 (5.5%) which can cause corrosion. Therefore, there is a need to treat that water to decrease CO2 or use high corrosion-resistant materials in the pipelines and water source wells.
{"title":"Using Nahr Umr Aquifer as an Additional Source of Injection Water for the X Oilfield","authors":"H. Almalikee, H. K. Almayyahi, Methaq Khazal Al-Jafar","doi":"10.52716/jprs.v12i1(suppl.).626","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).626","url":null,"abstract":"Water injection is the main strategy to increase oil production and support reservoirs pressure in the X oilfield and almost any other oilfield. The available source for the water injection in X field is the Qarmat Ali river which is located 20km to the north. However, the amount of water from that river is insufficient. Therefore, alternative water sources were investigated and among them, it was identified the Nahr Umr aquifer as the most promising. Nahr Umr is a regional giant aquifer; it is composed of high porous high permeable sandstone at an average depth of 2900m. The analysis of Nahr Umr aquifer water showed that it has a very high salinity (240000 ppm) almost composed of sodium and calcium chlorides, free of Oxygen, no solid particles were observed, no quantities of dissolved H2S, and very low occurrence of bacteria owing to the high water salinity and high temperature of the aquifer. On other hand, aquifer water contains a significant amount of dissolved CO2 (5.5%) which can cause corrosion. Therefore, there is a need to treat that water to decrease CO2 or use high corrosion-resistant materials in the pipelines and water source wells.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"72 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86269981","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}
Pub Date : 2022-04-21DOI: 10.52716/jprs.v12i1(suppl.).636
M. A. Ali
Thirty-one samples of sludge were taken, stored at the natural radioactive waste collection site, NORM, in Khidir Al-Maa, south of Basra city, resulting from the operations of extracting and filtering crude oil in oil fields in Basra Oil Company, to determine gas concentrations Radon 222Rn and other radioisotopes in Sludge models. The rapid electronic technology was adopted through the RAD7 device, the active method, and the gamma analysis technique using HPGe High Purity Germanium Detectors to determine the specific activity of radioactive elements. The measurements for this study showed 98463±7031 Bq.m-3 in sample no. S10 a barrel of sludge was brought from the third Degassing Station plant in the northern Rumaila oil field and least concentrated is 8317±594 Bq.m-3 in sample no. S14 sludge belonging to the sixth Degassing Station / West Qurna-1, the study also revealed the presence of high concentrations of the specific effectiveness of radioactive isotopes (214Pb, 212Bi, 226Ra) and (212Pb, 212Bi, 228Ac) of the uranium-238 series and Thorium-232 series in a sludge form selected from a barrel returning to the third gas isolation plant - North Rumaila Oilfield and stockpile at the collection site, where the specific activity value of radium was 226 Ra 133851 Bq.k-1 of the uranium-238 series and for lead 212Pb 56432 Bq.k-1 of For uranium-238 series compared to their concentrations, 32 Bq.k-1 45 Bq.k-1 in a natural soil model. The effective dose to which on-site workers would be exposed in contact was calculated and found to be 196.92 Svh-1, a dose that exceeded the proposed 50 Sv. h-1 dose limits by the US EPA. The probability of developing cancer due to exposure to radon per million people was found and it was found to be a high value compared to the suggested value (170-230) per million people previously by ICRP.
{"title":"Determination of the Radon Concentration of Gas 222Rn Emitted From Sludge Samples Located in the Radioactive Waste Collection Warehouse in Khader Al-Maa South of Basra City – Iraq","authors":"M. A. Ali","doi":"10.52716/jprs.v12i1(suppl.).636","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).636","url":null,"abstract":"Thirty-one samples of sludge were taken, stored at the natural radioactive waste collection site, NORM, in Khidir Al-Maa, south of Basra city, resulting from the operations of extracting and filtering crude oil in oil fields in Basra Oil Company, to determine gas concentrations Radon 222Rn and other radioisotopes in Sludge models. The rapid electronic technology was adopted through the RAD7 device, the active method, and the gamma analysis technique using HPGe High Purity Germanium Detectors to determine the specific activity of radioactive elements. The measurements for this study showed 98463±7031 Bq.m-3 in sample no. S10 a barrel of sludge was brought from the third Degassing Station plant in the northern Rumaila oil field and least concentrated is 8317±594 Bq.m-3 in sample no. S14 sludge belonging to the sixth Degassing Station / West Qurna-1, the study also revealed the presence of high concentrations of the specific effectiveness of radioactive isotopes (214Pb, 212Bi, 226Ra) and (212Pb, 212Bi, 228Ac) of the uranium-238 series and Thorium-232 series in a sludge form selected from a barrel returning to the third gas isolation plant - North Rumaila Oilfield and stockpile at the collection site, where the specific activity value of radium was 226 Ra 133851 Bq.k-1 of the uranium-238 series and for lead 212Pb 56432 Bq.k-1 of For uranium-238 series compared to their concentrations, 32 Bq.k-1 45 Bq.k-1 in a natural soil model. The effective dose to which on-site workers would be exposed in contact was calculated and found to be 196.92 Svh-1, a dose that exceeded the proposed 50 Sv. h-1 dose limits by the US EPA. The probability of developing cancer due to exposure to radon per million people was found and it was found to be a high value compared to the suggested value (170-230) per million people previously by ICRP.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"53 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87441124","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}
Pub Date : 2022-04-21DOI: 10.52716/jprs.v12i1(suppl.).617
Luay Hameed Shaheed
The development of High-Pressure and High-Temperature (HP/HT) wells is accompanied by high risk, and still represents one of the greatest technological challenges for the oil and gas industry related to the equipments used and their ability to sustain these conditions. The results analysis of data is key to investigating reasons for bad performances and failures of well completion design and detecting at an early stage potential downhole events.This paper applies machine learning to the results of real data analysis of deep and deviated well in the HP/HT environment. It presents techniques used to analyze design limits for the tubing string of the well with different rates of production and water injection, and predict pressure and temperature when multiple operations are applied to the tubular string during the well's lifetime. It also analyzes the most important parameters that impact the tubular string, such as temperature effect, safety factors, and tubing length change. A simulation model for a well has been developed to accomplish the objective of this work by using WellcatTM software modules (Prod & Tube) based on real data from the Elgin/Franklin fields in the North Sea. Two designs of tubular string were used to analyze design limits; the first included a tubing size of 4 ½ in and a latched permanent packer, and the second was identical to the first one but included an expansion joint tool to allow free movement of the tubing, and it was used to mitigate the first well completion design failure. Based on the results of this paper, three load cases (produce-6 months, tubing leak, and water injection) failed in the first design when the rates of oil production and water injection were increased to 12000 bbl/d and 5000 bbl/d respectively, whilst all load cases fell into the triaxial envelope and met the axial criteria in the second design. Furthermore, the predicted results of pressure and temperature for the tubing and surroundings indicate the tubular string could be exposed to buckling problems and serious thermal expansion in the annulus. As well, tubing length can be changed (elongated or shortage) owing to thermal effects during multiple load cases.
{"title":"Analysis and Mitigation of High-Pressure and High-Temperature Well Completion Design of Elkin/Franklin Fields in the North Sea","authors":"Luay Hameed Shaheed","doi":"10.52716/jprs.v12i1(suppl.).617","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).617","url":null,"abstract":"The development of High-Pressure and High-Temperature (HP/HT) wells is accompanied by high risk, and still represents one of the greatest technological challenges for the oil and gas industry related to the equipments used and their ability to sustain these conditions. The results analysis of data is key to investigating reasons for bad performances and failures of well completion design and detecting at an early stage potential downhole events.This paper applies machine learning to the results of real data analysis of deep and deviated well in the HP/HT environment. It presents techniques used to analyze design limits for the tubing string of the well with different rates of production and water injection, and predict pressure and temperature when multiple operations are applied to the tubular string during the well's lifetime. It also analyzes the most important parameters that impact the tubular string, such as temperature effect, safety factors, and tubing length change. A simulation model for a well has been developed to accomplish the objective of this work by using WellcatTM software modules (Prod & Tube) based on real data from the Elgin/Franklin fields in the North Sea. Two designs of tubular string were used to analyze design limits; the first included a tubing size of 4 ½ in and a latched permanent packer, and the second was identical to the first one but included an expansion joint tool to allow free movement of the tubing, and it was used to mitigate the first well completion design failure. Based on the results of this paper, three load cases (produce-6 months, tubing leak, and water injection) failed in the first design when the rates of oil production and water injection were increased to 12000 bbl/d and 5000 bbl/d respectively, whilst all load cases fell into the triaxial envelope and met the axial criteria in the second design. Furthermore, the predicted results of pressure and temperature for the tubing and surroundings indicate the tubular string could be exposed to buckling problems and serious thermal expansion in the annulus. As well, tubing length can be changed (elongated or shortage) owing to thermal effects during multiple load cases.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73148196","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}
This research describes the using of a new well completion technology system that enhance the homogeneous and heterogeneous reservoir deliverability and the production performance gained through a completion technique using Autonomous Inflow Control Valve (AICD) by self-decreasing/delaying water and gas progress and promoting increasing in oil production, therefore, equalizing the drawdown (∆P=Pi-Pwf) along the well and provide a dynamic water shut-off operation and significantly increasing the economic life of a well and therefore, reducing capital and operational expenditures for the field development. The research presents a production performance simulation results for a conventional and smart well completion technology in a horizontal well in a southern Iraqi oilfield for two stages during well life; early stage (till 2018) and late stage (till 2033). For early stage of well life, there was no significant difference in results when comparing between the conventional completion design and the smart completion design. In the contrast, the simulation results for the late life of the well showed that the well can produce for approximately 1056.7 barrel per day crude oil with a water-cut of 82 % at the year of 2033. The also revealed that the results showed that the cumulative oil production from the year of 2018 till 2050 will be 23 million barrel of crude oil and 44 million barrel of water when the well is completed with conventional completion design. When the completion design has been changed and equipped with autonomous inflow control devices (AICDs) technology and simulated the production performance by NETool Software. The simulation results showed that the oil production has been increased by 891 barrel per day (1947.3 barrel per day) and the water cut has reduced significantly in comparison with the conventional production completion by 17 % (65.4 %) at the year of 2033. The results revealed that the cumulative oil production from the year of 2018 till 2050 will be 31 million barrel of crude oil and 33 million barrel of water. It has been concluded, from the reservoir and production simulation, that the application of the technology is successful and showed a clear advantage of using Autonomous Inflow Control Device (AICD) that provides better water influx control profile.
{"title":"Using Smart Completion Technology to Control Water Coning Problems and Increase Oil Recovery in a Southern Iraqi Oilfield","authors":"Maitham Mezher Razaq, Ansaf Fadhi Hassan, Alameer Abdulkareem Radhi","doi":"10.52716/jprs.v12i1(suppl.).624","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).624","url":null,"abstract":"This research describes the using of a new well completion technology system that enhance the homogeneous and heterogeneous reservoir deliverability and the production performance gained through a completion technique using Autonomous Inflow Control Valve (AICD) by self-decreasing/delaying water and gas progress and promoting increasing in oil production, therefore, equalizing the drawdown (∆P=Pi-Pwf) along the well and provide a dynamic water shut-off operation and significantly increasing the economic life of a well and therefore, reducing capital and operational expenditures for the field development. \u0000 The research presents a production performance simulation results for a conventional and smart well completion technology in a horizontal well in a southern Iraqi oilfield for two stages during well life; early stage (till 2018) and late stage (till 2033). For early stage of well life, there was no significant difference in results when comparing between the conventional completion design and the smart completion design. In the contrast, the simulation results for the late life of the well showed that the well can produce for approximately 1056.7 barrel per day crude oil with a water-cut of 82 % at the year of 2033. The also revealed that the results showed that the cumulative oil production from the year of 2018 till 2050 will be 23 million barrel of crude oil and 44 million barrel of water when the well is completed with conventional completion design. When the completion design has been changed and equipped with autonomous inflow control devices (AICDs) technology and simulated the production performance by NETool Software. The simulation results showed that the oil production has been increased by 891 barrel per day (1947.3 barrel per day) and the water cut has reduced significantly in comparison with the conventional production completion by 17 % (65.4 %) at the year of 2033. The results revealed that the cumulative oil production from the year of 2018 till 2050 will be 31 million barrel of crude oil and 33 million barrel of water. \u0000 It has been concluded, from the reservoir and production simulation, that the application of the technology is successful and showed a clear advantage of using Autonomous Inflow Control Device (AICD) that provides better water influx control profile. \u0000 ","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82418653","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}
Pub Date : 2022-04-21DOI: 10.52716/jprs.v12i1(suppl.).635
Safaa Abdul Ghany Alfaez
In this study; membrane distillation technology using to associated oil water production desalination by air gap membrane distillation unit to removed salt from the water after separating oil product, via PTEF commercial hydrophobic membrane distillation with 0.22 µm porous and 0.011 m contact surface area, evaluated the desalination system and operation parameter for feed water effected on process production by employment the distillation under boiling point temperature that getting commercial increments and study the energy gain by calculating the GOR of the desalination process. The study focusing on the air gap membrane distillation desalination process by a range of temperature after primary simple sedimentation and filtration it's obtained salt rejection up to 98.9% that proves process separation efficiency. Evaluated the mean operation parameters of feed water affected on permeate water production when selected the feed temperature and flow rate with fixed coolant temperature, coolant flow rate, and air gap width to get an optimum range for feed water operation parameter to obtain optimum value to permeate water production and saving energy.
{"title":"Membrane Distillation Technology Using for Desalination of Associated Oil Water Production and Study Efficiency of Feed Water Operation Parameter on Air Gap Membrane Distillation Process Production","authors":"Safaa Abdul Ghany Alfaez","doi":"10.52716/jprs.v12i1(suppl.).635","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).635","url":null,"abstract":"In this study; membrane distillation technology using to associated oil water production desalination by air gap membrane distillation unit to removed salt from the water after separating oil product, via PTEF commercial hydrophobic membrane distillation with 0.22 µm porous and 0.011 m contact surface area, evaluated the desalination system and operation parameter for feed water effected on process production by employment the distillation under boiling point temperature that getting commercial increments and study the energy gain by calculating the GOR of the desalination process. \u0000The study focusing on the air gap membrane distillation desalination process by a range of temperature after primary simple sedimentation and filtration it's obtained salt rejection up to 98.9% that proves process separation efficiency. Evaluated the mean operation parameters of feed water affected on permeate water production when selected the feed temperature and flow rate with fixed coolant temperature, coolant flow rate, and air gap width to get an optimum range for feed water operation parameter to obtain optimum value to permeate water production and saving energy.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88272998","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}
Pub Date : 2022-04-21DOI: 10.52716/jprs.v12i1(suppl.).639
F. Al-Maliky, D. A. Kadhim
The current work involved optimizing the spars of wind turbine blades while taking into account the wind speed quantities that affected the blade structure. The objective was to determine the optimal dimensions of turbine blade spar configurations using the finite element method under the influence of the maximum pressure associated with the first mode shape while maintaining the Von Misses stresses within the assumed safety factor (1.5). (200-230 MPa). The blade was stiffened with a main box spar and two auxillary spars on each side. Appropriate spar locations were specified for poisons with a high natural frequency first mode. The blade parts' dimensions were discretized to allow for greater flexibility and precision in dimension assignment. By utilizing the ANSYS program, the optimization process required a certain number of iterations to modify the blade structure's dimensions. Optimized iteration was considered in order to increase the thickness in areas of high stress and decrease the thickness in areas of low stress. Additionally, a comparison between a blade structure with optimal dimensions and one with non-optimal dimensions was included.
{"title":"Optimizing of Turbine blade spar using Ansys program","authors":"F. Al-Maliky, D. A. Kadhim","doi":"10.52716/jprs.v12i1(suppl.).639","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).639","url":null,"abstract":"The current work involved optimizing the spars of wind turbine blades while taking into account the wind speed quantities that affected the blade structure. The objective was to determine the optimal dimensions of turbine blade spar configurations using the finite element method under the influence of the maximum pressure associated with the first mode shape while maintaining the Von Misses stresses within the assumed safety factor (1.5). (200-230 MPa). The blade was stiffened with a main box spar and two auxillary spars on each side. Appropriate spar locations were specified for poisons with a high natural frequency first mode. The blade parts' dimensions were discretized to allow for greater flexibility and precision in dimension assignment. By utilizing the ANSYS program, the optimization process required a certain number of iterations to modify the blade structure's dimensions. Optimized iteration was considered in order to increase the thickness in areas of high stress and decrease the thickness in areas of low stress. Additionally, a comparison between a blade structure with optimal dimensions and one with non-optimal dimensions was included.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85482833","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}
Pub Date : 2022-04-21DOI: 10.52716/jprs.v12i1(suppl.).623
Mohammed Q. Abd Talib, M. Al-Jawad
Pressure volume temperature (PVT) analysis is the process of determining the fluid behaviors and properties of oil and gas samples from an existing well. Normally, PVT properties are experimentally measured in the laboratory. However, the absence of PVT measurement negatively impacts the application of many petroleum engineering calculations such as reserves estimation, material balance, reservoir simulation, production equipment design, and optimization of well performance. In this work, we developed a program using VBA and MS EXCEL to compare between the collected measurements of PVT properties that were collected from 41 Iraqi oil cruds and the values obtained from the correlations. After the comparison process, we chose the correlation that have the close values to the PVT measurements that were collected previously. This type of study, in which we compare the results of existing literature correlations to the measured value in a laboratory for a specific country or location, has been conducted in a number of countries, including Kuwait, the United Arab Emirates, and Egypt, but not in Iraq, which is where the value of this study lies. A total of 92 correlations were involved in this study including, (19) Bubble point pressure, (10) gas-oil ratio, (20) oil FVF, (10) saturated Viscosity, (3) density at bubble point, (7) undersaturated oil compressibility, (12) dead viscosity, (3) undersaturated oil FVF, (8) undersaturated viscosity. Over all, the best performance was obtained using the “Elsharkawy and Alikhan [1] “correlation for ( Pb, Rs, Bo) , “Standing [2]” correlation for Density at bubble point , “Almehaideb [3]” for below bubble point viscosity , “Labedi [4]” for Dead viscosity, “Al-Marhoun [5]” for above bubble point oil FVF, “Standing [2]” for above bubble point oil compressibility, “Petrosky and Farshad [6]” for above bubble point viscosity, based on consistently low values of (AAPE) and (RMS) and cross plot.
{"title":"Assessment of the Common PVT Correlations in Iraqi Oil Fields","authors":"Mohammed Q. Abd Talib, M. Al-Jawad","doi":"10.52716/jprs.v12i1(suppl.).623","DOIUrl":"https://doi.org/10.52716/jprs.v12i1(suppl.).623","url":null,"abstract":"Pressure volume temperature (PVT) analysis is the process of determining the fluid behaviors and properties of oil and gas samples from an existing well. Normally, PVT properties are experimentally measured in the laboratory. However, the absence of PVT measurement negatively impacts the application of many petroleum engineering calculations such as reserves estimation, material balance, reservoir simulation, production equipment design, and optimization of well performance. \u0000In this work, we developed a program using VBA and MS EXCEL to compare between the collected measurements of PVT properties that were collected from 41 Iraqi oil cruds and the values obtained from the correlations. After the comparison process, we chose the correlation that have the close values to the PVT measurements that were collected previously. \u0000This type of study, in which we compare the results of existing literature correlations to the measured value in a laboratory for a specific country or location, has been conducted in a number of countries, including Kuwait, the United Arab Emirates, and Egypt, but not in Iraq, which is where the value of this study lies. \u0000A total of 92 correlations were involved in this study including, (19) Bubble point pressure, (10) gas-oil ratio, (20) oil FVF, (10) saturated Viscosity, (3) density at bubble point, (7) undersaturated oil compressibility, (12) dead viscosity, (3) undersaturated oil FVF, (8) undersaturated viscosity. \u0000Over all, the best performance was obtained using the “Elsharkawy and Alikhan [1] “correlation for ( Pb, Rs, Bo) , “Standing [2]” correlation for Density at bubble point , “Almehaideb [3]” for below bubble point viscosity , “Labedi [4]” for Dead viscosity, “Al-Marhoun [5]” for above bubble point oil FVF, “Standing [2]” for above bubble point oil compressibility, “Petrosky and Farshad [6]” for above bubble point viscosity, based on consistently low values of (AAPE) and (RMS) and cross plot.","PeriodicalId":16710,"journal":{"name":"Journal of Petroleum Research and Studies","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82058439","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}
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