Staged premium screen has been applied to balance the inflow profile of horizontal well under open hole completion in Shengli Oil Field, China. Perforation density of base pipe is the key parameter of staged screen for inflow control, however, it is used to be determined by only considering drawdown due to perforation itself, ignoring two dominant parts caused by formation sand filter cake around screen and sand retention material, therefore the decision plan is not suitable. To solve this problem, a laboratory apparatus was run to test a screen sample, and thoroughly analyzed the effect of perforation density on total inflow control drawdown. A base pipe was also tested, working as a reference to screen sample. The test simulated down hole flowing condition in Well DXY451P21, Block 451, Shengli Oil Field, test results were directly utilized to design staged premium screen for this target well. Finally, the following conclusions can be drawn: pressure drop in screen sample is much sensitive to perforation density, and is obviously larger than that in base pipe sample; flowing pressure is mainly lost in formation sand filter cake and sand retention material, where the flow pattern is seepage flow; perforations on base pipe of premium screen mainly play a part in regulating flowing field, i.e. smaller perforation density will lead produced liquid to flow a longer distance in seepage media and bring a larger additional drawdown; the production performance of Well DXY451P21 is much better than adjacent wells, and promotes economic benefits.
{"title":"Staged Premium Screen Completion Design for Horizontal Well Based on Laboratory Test: A Successful Application in Block 451, Shengli Oil Field","authors":"Chen Yang, Shaoxian Wang, Zongyi Chen, Haibo Yang, Jianguo Zhang","doi":"10.3968/10835","DOIUrl":"https://doi.org/10.3968/10835","url":null,"abstract":"Staged premium screen has been applied to balance the inflow profile of horizontal well under open hole completion in Shengli Oil Field, China. Perforation density of base pipe is the key parameter of staged screen for inflow control, however, it is used to be determined by only considering drawdown due to perforation itself, ignoring two dominant parts caused by formation sand filter cake around screen and sand retention material, therefore the decision plan is not suitable. To solve this problem, a laboratory apparatus was run to test a screen sample, and thoroughly analyzed the effect of perforation density on total inflow control drawdown. A base pipe was also tested, working as a reference to screen sample. The test simulated down hole flowing condition in Well DXY451P21, Block 451, Shengli Oil Field, test results were directly utilized to design staged premium screen for this target well. Finally, the following conclusions can be drawn: pressure drop in screen sample is much sensitive to perforation density, and is obviously larger than that in base pipe sample; flowing pressure is mainly lost in formation sand filter cake and sand retention material, where the flow pattern is seepage flow; perforations on base pipe of premium screen mainly play a part in regulating flowing field, i.e. smaller perforation density will lead produced liquid to flow a longer distance in seepage media and bring a larger additional drawdown; the production performance of Well DXY451P21 is much better than adjacent wells, and promotes economic benefits.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"583 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116308461","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}
Transporting gas in the form of a gas hydrate can prove to be very useful in the supply chain of natural gas to meet future energy demand. There are major challenges that exist in effectively capturing, storing, transporting and utilizing form of energy. The details of the work flow in this paper evaluates the entire hydrate process with particular focus on energy balance using hydrate technology to capture and transport five (5) MMscf/d from Trinidad to Jamaica. The overall energy requirement of the process which involves heating, cooling and expansion is in the range 14-20% of the energy of the gas transported in hydrate form.
{"title":"Hydrate Process Analysis Focusing on Energy Requirement","authors":"J. Rajnauth","doi":"10.3968/11010","DOIUrl":"https://doi.org/10.3968/11010","url":null,"abstract":"Transporting gas in the form of a gas hydrate can prove to be very useful in the supply chain of natural gas to meet future energy demand. There are major challenges that exist in effectively capturing, storing, transporting and utilizing form of energy. The details of the work flow in this paper evaluates the entire hydrate process with particular focus on energy balance using hydrate technology to capture and transport five (5) MMscf/d from Trinidad to Jamaica. The overall energy requirement of the process which involves heating, cooling and expansion is in the range 14-20% of the energy of the gas transported in hydrate form.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"123 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121616462","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}
A good protection of coalbed methane reservoir can facilitate its exploitation and usage of, cover the shortage of oil and natural gas supply for China, help cut greenhouse gas emissions, phase down environmental pollution and prevent mine accidents from happening. Firstly, damage mechanisms of coalbed methane reservoir in Qinshui basin of Shanxi province were comprehensively analyzed by X-ray diffraction (XRD), Scanning Electron Microscope (SEM), liner swelling test and hot rolling dispersion experiments, thin-section analysis, mercury penetration analysis, wettability measurement and evaluation of sensitivity. Based on this work, pertinent protection counter- measure study were conducted, the surface wettability modifier SLJ-2 and water sensitivity inhibitor SLYZ-1 were selected out, and then drilling fluid for coalbed methane reservoir in Qinshui basin of Shanxi province composed of 0.4%SLJ-2 + 0.5%SLYZ-1 was developed, which has minimal damage to permeability of ingredient under hygrometric state.
{"title":"A Drilling Liquid to Reduce the Damage Coalbed Methane","authors":"K. Du","doi":"10.3968/11001","DOIUrl":"https://doi.org/10.3968/11001","url":null,"abstract":"A good protection of coalbed methane reservoir can facilitate its exploitation and usage of, cover the shortage of oil and natural gas supply for China, help cut greenhouse gas emissions, phase down environmental pollution and prevent mine accidents from happening. Firstly, damage mechanisms of coalbed methane reservoir in Qinshui basin of Shanxi province were comprehensively analyzed by X-ray diffraction (XRD), Scanning Electron Microscope (SEM), liner swelling test and hot rolling dispersion experiments, thin-section analysis, mercury penetration analysis, wettability measurement and evaluation of sensitivity. Based on this work, pertinent protection counter- measure study were conducted, the surface wettability modifier SLJ-2 and water sensitivity inhibitor SLYZ-1 were selected out, and then drilling fluid for coalbed methane reservoir in Qinshui basin of Shanxi province composed of 0.4%SLJ-2 + 0.5%SLYZ-1 was developed, which has minimal damage to permeability of ingredient under hygrometric state.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"57 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121106294","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}
Oil reserves are found in deep formations where the conditions of temperature and pressure are always high. These conditions have direct effects on the rheological properties of drilling fluid as they vary with increasing temperatures and pressures. Two sets of experiment were carried out on weighted and unweighted mud samples at a temperature of 250oF and 500psi pressure. The presence of locally sourced additives helped the mud to remain pseudoplastic at these conditions and also retained essential properties of the mud need for drilling operations. The plastic viscosities of the weighted and unweighted mud were 36cP and 27cP respectively. The yield stresses were 149lb/1002ft and 110lb/1002ft for the weighted and unweighted samples while the fluid loss volumes were approximately equal. The thickness of the cake for the weighted sample is 3.7mm and 4mm for the unweighted sample. The weighted sample with a reasonably higher PV has a better hole cleaning ability than the unweighted sample. Mucunna Solannie performed excellently to retain the essential properties of these formulations at 250oF and is therefore recommended as a HPHT drilling mud additive.
{"title":"Performance Evaluation of a Biomaterial in an Aqueous-Based Drilling Mud at High Pressure High Temperature","authors":"U. Duru, I. Onyejekwe, N. Uwaezuoke, D. Isu","doi":"10.3968/11130","DOIUrl":"https://doi.org/10.3968/11130","url":null,"abstract":"Oil reserves are found in deep formations where the conditions of temperature and pressure are always high. These conditions have direct effects on the rheological properties of drilling fluid as they vary with increasing temperatures and pressures. Two sets of experiment were carried out on weighted and unweighted mud samples at a temperature of 250oF and 500psi pressure. The presence of locally sourced additives helped the mud to remain pseudoplastic at these conditions and also retained essential properties of the mud need for drilling operations. The plastic viscosities of the weighted and unweighted mud were 36cP and 27cP respectively. The yield stresses were 149lb/1002ft and 110lb/1002ft for the weighted and unweighted samples while the fluid loss volumes were approximately equal. The thickness of the cake for the weighted sample is 3.7mm and 4mm for the unweighted sample. The weighted sample with a reasonably higher PV has a better hole cleaning ability than the unweighted sample. Mucunna Solannie performed excellently to retain the essential properties of these formulations at 250oF and is therefore recommended as a HPHT drilling mud additive.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124554075","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}
Tinghui Hu, Dong Liu, Qin Zhu, Manyi Wang, Zhen-song Lian
Researches on the water breakthrough patterns and laws of horizontal well are weak. Based on this, a typical model was established by using the geology and reservoir parameters of the heavy oil reservoir with large bottom water in the Bohai Sea. Generally, there are 4 water-out patterns for horizontal well in bottom-water heavy oil reservoir, including punctiform breakthrough waterflooding in a local horizontal section, punctiform breakthrough waterflooding in several local horizontal sections, linear breakthrough waterflooding in the whole horizontal section, and water channeling along high permeability zone. Then, the typical diagnosis curves of these water breakthrough patterns were drawn by studying WOR (water-oil ratio) and its first-order time derivative. However, there are usually value errors in the actual production data, so the interference of noise signals in production data would reduce the accuracy and reliability of water output diagnosis. Using wavelet transform method to denoise dynamic data can simultaneously guarantee both the smoothness and approximation of derivative curves. Finally, the effective measures of different water flooding modes were put forward by the case study of 22 horizontal wells in LD bottom-water reservoir. It has reference significance for efficient development of bottom-water reservoir with horizontal wells in high water cut stage.
{"title":"Study and Application of Diagnosis Curves of Water Channeling Patterns for Horizontal Well in Bottom-water Heavy Oil Reservoir","authors":"Tinghui Hu, Dong Liu, Qin Zhu, Manyi Wang, Zhen-song Lian","doi":"10.3968/11132","DOIUrl":"https://doi.org/10.3968/11132","url":null,"abstract":"Researches on the water breakthrough patterns and laws of horizontal well are weak. Based on this, a typical model was established by using the geology and reservoir parameters of the heavy oil reservoir with large bottom water in the Bohai Sea. Generally, there are 4 water-out patterns for horizontal well in bottom-water heavy oil reservoir, including punctiform breakthrough waterflooding in a local horizontal section, punctiform breakthrough waterflooding in several local horizontal sections, linear breakthrough waterflooding in the whole horizontal section, and water channeling along high permeability zone. Then, the typical diagnosis curves of these water breakthrough patterns were drawn by studying WOR (water-oil ratio) and its first-order time derivative. However, there are usually value errors in the actual production data, so the interference of noise signals in production data would reduce the accuracy and reliability of water output diagnosis. Using wavelet transform method to denoise dynamic data can simultaneously guarantee both the smoothness and approximation of derivative curves. Finally, the effective measures of different water flooding modes were put forward by the case study of 22 horizontal wells in LD bottom-water reservoir. It has reference significance for efficient development of bottom-water reservoir with horizontal wells in high water cut stage.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133527363","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}
Peibin Gong, Long He, Shujiang Wang, Xilian Fan, Chen Yang, Baojiang Sun
In the case of drilling mud completely erupted out of wellbore in high pressure gas wells, a series of fluid flowing governing equations are established in the consideration of coupling relationship between gas in well bore and formation. The change in casing pressure and bottom hole pressure with time was numerically simulated during shut in and well killing process. The results show that casing pressure and bottom hole pressure can achieve stable value quickly after shut in. The casing pressure increases rapidly first and then decreases to zero in well killing process. The earlier a well killing is performed, the smaller the peak value of casing pressure will occur under the same kill rate. A high kill rate can generate a small peak value of casing pressure after the well killing starts.
{"title":"Simulated Calculation of Bullheading Method When the Well is Empty","authors":"Peibin Gong, Long He, Shujiang Wang, Xilian Fan, Chen Yang, Baojiang Sun","doi":"10.3968/10995","DOIUrl":"https://doi.org/10.3968/10995","url":null,"abstract":"In the case of drilling mud completely erupted out of wellbore in high pressure gas wells, a series of fluid flowing governing equations are established in the consideration of coupling relationship between gas in well bore and formation. The change in casing pressure and bottom hole pressure with time was numerically simulated during shut in and well killing process. The results show that casing pressure and bottom hole pressure can achieve stable value quickly after shut in. The casing pressure increases rapidly first and then decreases to zero in well killing process. The earlier a well killing is performed, the smaller the peak value of casing pressure will occur under the same kill rate. A high kill rate can generate a small peak value of casing pressure after the well killing starts.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"22 6-7","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132090728","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}
Block 2 is located at the northeastern end of the Sanzhao sag in the Liao Basin.The main oil layer is Fuyang oil layer.There is a problem that the sand body develops rapidly and the reservoir distribution is not clear. In order to solve the problem of modification, this paper uses the seismic attribute technique to analyze the lateral distribution characteristics of the reservoir in the Shang 2 block of the Sanzhao Sag in the study area. On the basis of establishing the forward modeling by ray tracing method, the influence analysis of mudstone interlayer thickness and sand-ground ratio forward analysis are carried out. The analysis results show that the sedimentary environment of the Fuyang oil layer is mainly the sub-facies of the delta diversion plain, which develops the diversion channel, the diversion bay and the mat-like sand microfacies, and the channel is mainly distributed in the eastward direction.
{"title":"Research on Sesmic Attribute Reservoir Prediction Method: Taking the Shang Block 2 of Sanzhao Sag as an Example","authors":"Q. Xu","doi":"10.3968/11068","DOIUrl":"https://doi.org/10.3968/11068","url":null,"abstract":"Block 2 is located at the northeastern end of the Sanzhao sag in the Liao Basin.The main oil layer is Fuyang oil layer.There is a problem that the sand body develops rapidly and the reservoir distribution is not clear. In order to solve the problem of modification, this paper uses the seismic attribute technique to analyze the lateral distribution characteristics of the reservoir in the Shang 2 block of the Sanzhao Sag in the study area. On the basis of establishing the forward modeling by ray tracing method, the influence analysis of mudstone interlayer thickness and sand-ground ratio forward analysis are carried out. The analysis results show that the sedimentary environment of the Fuyang oil layer is mainly the sub-facies of the delta diversion plain, which develops the diversion channel, the diversion bay and the mat-like sand microfacies, and the channel is mainly distributed in the eastward direction.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122420203","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}
N. Uwaezuoke, Nkemakolam Chinedu Izuwa, S. Onwukwe
Gas with negligible or zero composition of hydrogen sulphide is sweet natural gas. During production, transportation and processing, the presence of traces of water can cause problems such as ice formation and/0r the problem of gas hydrates, increase in corrosion potential of the gas and two-phase flow problems if condensation occurs. Calculation of the water content at specified temperature and pressure conditions is the first step. A formula based approach of the calculation is proposed, and comparison with existing formulas presented. Application of the proposed formula in the specified ranges of temperature and pressure conditions of 15oC (59oF) to 48.8oC (119.84oF) and 1.07MPa (155.19 psia) to 10MPa (1450.38 psia) is recommended for sweet natural gases. A calculated Mean Absolute Percentage Deviation (MAPD) of 16.4077% from the experimental data is the statistical indicator used for validity check. It predicted better than some existing models which are adaptable under certain conditions. Only a hand-held device is required as the proposed model is highly simplified.
{"title":"Water Content of Sweet Natural Gas: A Simplified Formula-Based Approach","authors":"N. Uwaezuoke, Nkemakolam Chinedu Izuwa, S. Onwukwe","doi":"10.3968/11133","DOIUrl":"https://doi.org/10.3968/11133","url":null,"abstract":"Gas with negligible or zero composition of hydrogen sulphide is sweet natural gas. During production, transportation and processing, the presence of traces of water can cause problems such as ice formation and/0r the problem of gas hydrates, increase in corrosion potential of the gas and two-phase flow problems if condensation occurs. Calculation of the water content at specified temperature and pressure conditions is the first step. A formula based approach of the calculation is proposed, and comparison with existing formulas presented. Application of the proposed formula in the specified ranges of temperature and pressure conditions of 15oC (59oF) to 48.8oC (119.84oF) and 1.07MPa (155.19 psia) to 10MPa (1450.38 psia) is recommended for sweet natural gases. A calculated Mean Absolute Percentage Deviation (MAPD) of 16.4077% from the experimental data is the statistical indicator used for validity check. It predicted better than some existing models which are adaptable under certain conditions. Only a hand-held device is required as the proposed model is highly simplified.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"03 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124383241","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}
with the increasing time of water drive development in the Sazhong development zone, the oilfield has gradually entered the stage of high water cut stage or ultra-high water cut stage, and now it has entered the development stage of the high water cut period of the coexistence of the two drive. In order to extend the production life of the oilfield and plan the scale of production, based on the application of reservoir engineering method to calculate the natural decline rate and by grouping the Sa Pu oil layer and the Gaotaizi oil reservoir in the Sazhong oilfield, reducing the yield base of each year and re prediction of water drive production decline rule in Sazhong development area, which is concluded that the average decline rate is 7.46%. At the same time, the characteristics of tertiary oil recovery are analyzed, and the production replacement equation is established through the production demand under different production decline conditions. Based on the law of decreasing water drive and the change rule of chemical flooding production, the average chemical drive reserves in 12th Five-Year and the annual largest chemical drive reserves as tertiary oil recovery reserves, and the output forecast index of the sash development zone can be obtained.
{"title":"Study on Development Law and Yield Replacement Method in Sazhong Development Area","authors":"Shang Gao","doi":"10.3968/11002","DOIUrl":"https://doi.org/10.3968/11002","url":null,"abstract":"with the increasing time of water drive development in the Sazhong development zone, the oilfield has gradually entered the stage of high water cut stage or ultra-high water cut stage, and now it has entered the development stage of the high water cut period of the coexistence of the two drive. In order to extend the production life of the oilfield and plan the scale of production, based on the application of reservoir engineering method to calculate the natural decline rate and by grouping the Sa Pu oil layer and the Gaotaizi oil reservoir in the Sazhong oilfield, reducing the yield base of each year and re prediction of water drive production decline rule in Sazhong development area, which is concluded that the average decline rate is 7.46%. At the same time, the characteristics of tertiary oil recovery are analyzed, and the production replacement equation is established through the production demand under different production decline conditions. Based on the law of decreasing water drive and the change rule of chemical flooding production, the average chemical drive reserves in 12th Five-Year and the annual largest chemical drive reserves as tertiary oil recovery reserves, and the output forecast index of the sash development zone can be obtained.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126111731","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}
Reservoir studies of naturally repressured reservoirs are highly problematic. Thus, their reserve estimation is notoriously in error. This is aggravated by the presence of communicating areas. The repressurization is due to the enhancement of the reservoir energy sourced by additional undeveloped productive zone(s). The aim of this study was to determine the source of constant recharging (repressurization) of a reservoir in the Niger Delta Oil Field. Several techniques were adopted to investigate the source of repressurization of the reservoir. An unknown productive zone was identified to be communicating with the reservoir which increased the STOIIP by over 100%.
{"title":"Producibility Scenario of Unidentified Productive Zone","authors":"A. Kerunwa","doi":"10.3968/10998","DOIUrl":"https://doi.org/10.3968/10998","url":null,"abstract":"Reservoir studies of naturally repressured reservoirs are highly problematic. Thus, their reserve estimation is notoriously in error. This is aggravated by the presence of communicating areas. The repressurization is due to the enhancement of the reservoir energy sourced by additional undeveloped productive zone(s). The aim of this study was to determine the source of constant recharging (repressurization) of a reservoir in the Niger Delta Oil Field. Several techniques were adopted to investigate the source of repressurization of the reservoir. An unknown productive zone was identified to be communicating with the reservoir which increased the STOIIP by over 100%.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128068040","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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