The development of low-porosity and low-permeability oil and gas fields has been concerned by scholars all over the world. This study focuses on the sensitivity study of Chang 6 reservoir in CD block of Ordos Basin. Through analysis by such technological means as rock core fluid flow experiment, X diffraction, rock core slices, scanning electron microscopy, it is proven that Chang 6 reservoir mainly gives primary to acid sensitivity, the velocity sensitivity is in the next place and the alkaline sensitivity and water sensitivity are in the end. The sensitivity minerals mainly cover the chlorite, calcite, ferrocalcite, dolomite, siderite and other minerals. Through discussion about the relationship among porosity, permeability and sensitivity indexes, it is deemed that he relationship among porosity, permeability and sensitivity indexes is closely related, and it is found through discussion for four kinds of sensitivity indexes that the trends of velocity sensitivity and acid sensitivity index curves are consistent, and the trends of alkali sensitivity and water sensitivity index curves are consistent. The consistency on relationship possibly enables that relationship between alkali sensitivity and water sensitivity are closely related to the fluid mineralization and the velocity sensitivity and acid sensitivity are closely related to the reaction rate of fluid.
{"title":"Experimental Study on Reservoir Sensitivity for Chang 6 Reservoir in CD Block of Ordos Basin","authors":"Zhibo Zhang, Haomin Liu, Hai-Yong Liu, Bo Wang","doi":"10.3968/10624","DOIUrl":"https://doi.org/10.3968/10624","url":null,"abstract":"The development of low-porosity and low-permeability oil and gas fields has been concerned by scholars all over the world. This study focuses on the sensitivity study of Chang 6 reservoir in CD block of Ordos Basin. Through analysis by such technological means as rock core fluid flow experiment, X diffraction, rock core slices, scanning electron microscopy, it is proven that Chang 6 reservoir mainly gives primary to acid sensitivity, the velocity sensitivity is in the next place and the alkaline sensitivity and water sensitivity are in the end. The sensitivity minerals mainly cover the chlorite, calcite, ferrocalcite, dolomite, siderite and other minerals. Through discussion about the relationship among porosity, permeability and sensitivity indexes, it is deemed that he relationship among porosity, permeability and sensitivity indexes is closely related, and it is found through discussion for four kinds of sensitivity indexes that the trends of velocity sensitivity and acid sensitivity index curves are consistent, and the trends of alkali sensitivity and water sensitivity index curves are consistent. The consistency on relationship possibly enables that relationship between alkali sensitivity and water sensitivity are closely related to the fluid mineralization and the velocity sensitivity and acid sensitivity are closely related to the reaction rate of fluid.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133791298","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}
Complexity of discontinuous reservoir units occurring within the shale-rich N’kapa Formation and the limitation of well-articulated interpretations deduced from 2D seismic data, led to a new approach of interpretation of the 3D seismic data of M-Field located offshore Douala Sub-Basin, Cameroon. The study aimed at determining the subsurface distribution of the delineated reservoir units in terms of geology, structures, stratigraphic architecture as well as the lateral and vertical distribution of each of the reservoir units across the field.Well log signatures were analyzed and interpreted to identify hydrocarbon bearing sands, which were subsequently mapped to the 3D seismic record using the generated 1D synthetic seismogram to tie the well information to the seismic volume. The delineated hydrocarbon bearing sand bodies were mapped as horizons on the 3D seismic record in addition to subsurface structural mapping to generate subsurface depth structure maps. Further still, amplitude variation surface seismic attribute analyses aid the delineation of geometry of depositional channels across the M-Field. Two horizons ( X 1 and Y 1 ) were interpreted and used to generate surfaces attribute maps. The M-Field reservoirs present stratigraphic architecture which suggests levees or confined channel sands deposit as the dominant channel deposit. X 1 and Y 1 are stratigraphic trappedhydrocarbon systems, however, while X 1 is located up-dip, Y 1 is situated on a monoclinic slope in the down dip area of X 1 , such that Y 1 stratigraphically seats on X 1 but eroded around X 1. The high amplitude associated with the delineated erosional surface likely results due to difference in acoustic properties across the interface owing todifference in age and composition of the two units. This suggests that the delineated reservoirs are two different units which are not correlateable as earlier postulate.
{"title":"Seismic Attribute Analysis for Reservoir Description and Characterization of M-Field, Douala Sub-Basin, Cameroon","authors":"O. Osinowo","doi":"10.3968/10220","DOIUrl":"https://doi.org/10.3968/10220","url":null,"abstract":"Complexity of discontinuous reservoir units occurring within the shale-rich N’kapa Formation and the limitation of well-articulated interpretations deduced from 2D seismic data, led to a new approach of interpretation of the 3D seismic data of M-Field located offshore Douala Sub-Basin, Cameroon. The study aimed at determining the subsurface distribution of the delineated reservoir units in terms of geology, structures, stratigraphic architecture as well as the lateral and vertical distribution of each of the reservoir units across the field.Well log signatures were analyzed and interpreted to identify hydrocarbon bearing sands, which were subsequently mapped to the 3D seismic record using the generated 1D synthetic seismogram to tie the well information to the seismic volume. The delineated hydrocarbon bearing sand bodies were mapped as horizons on the 3D seismic record in addition to subsurface structural mapping to generate subsurface depth structure maps. Further still, amplitude variation surface seismic attribute analyses aid the delineation of geometry of depositional channels across the M-Field. Two horizons ( X 1 and Y 1 ) were interpreted and used to generate surfaces attribute maps. The M-Field reservoirs present stratigraphic architecture which suggests levees or confined channel sands deposit as the dominant channel deposit. X 1 and Y 1 are stratigraphic trappedhydrocarbon systems, however, while X 1 is located up-dip, Y 1 is situated on a monoclinic slope in the down dip area of X 1 , such that Y 1 stratigraphically seats on X 1 but eroded around X 1. The high amplitude associated with the delineated erosional surface likely results due to difference in acoustic properties across the interface owing todifference in age and composition of the two units. This suggests that the delineated reservoirs are two different units which are not correlateable as earlier postulate.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"10 3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134288402","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}
Hole cleaning is a key parameter in every drilling program. Efficient bottom hole cleaning is achieved through adequate transportation of cuttings from the wellbore to the surface. Modified natural polymers like Poly anionic cellulose regular (PAC-R), with bentonite clay has been used to achieve good carrying capacity of drilled cuttings in water base mud (WBM). These conventional polymers have adverse effect on the environment, especially the mud-filtrate which pollutes and contaminates the aquifer and the spent mud that requires caution for its disposal. In this work, Local viscosifers were obtained from Mucuna Flagellipe (Ukpo), Brachystegea Eurycoma (Achi), Afzelia Africana (Akpalata) and Detarium microcapum (Ofor) as a substitute for the imported viscosifiers (PAC R) used as a drilling fluid additives. Water-based muds were formulated from the aforementioned locally sourced viscosifiers and that of the conventionally used viscosifier (Pac-R). Laboratory tests were carried out on the different muds formulated and their rheological properties evaluated, such as yield stress, , shear stress plastic viscosity and shear rate. The concentrations of the locally sourced viscosifiers were varied and rheological tests performed show that Mucuna Flagellipe (Ukpo) had a better viscosity compared to Achi, Akplata and Ofor of the same concentration. It was also observed that 5g of Mucuna Flagellipe (Ukpo) and 8g of detarium microcapum (Ofor) gave an equivalent rheological properties of 27lb/100ft2and 26lb/100ft2 as yield stress when compared to2g of Pac-R which gave a yield point of 29lb/100ft2 at a temperature of 180˚F. Also, 8g of Mucuna Flagellipe (Ukpo) gave an equivalent of 5g of PAC-R. Hole cleaning parameters such as slip velocity, annular velocity and cuttings transport efficiency were also considered for evaluating the effectiveness of the proposed muds with local viscosifiers and conventional viscosifiers on hole cleaning. 5g and 8g of Mucuna Flagellipe (Ukpo) compared favourably with PAC-R in terms of hole cleaning. Finally in terms of cost, the locally sourced viscosifiers are cost effective when compared with the conventional vscosifier. Therefore, locally sourced viscosifiers (Mucuna Flagellipe, Ukpo) can be used as a substitute to the conventional Pac-R when drilling top hole at a temperature of 150˚F and below since these holes are drilled within a thermal gradient of 150˚F and below in the Niger delta region of Nigeria.
{"title":"Evaluation of Local Viscosifiers as an Alternative to Conventional Pac-R","authors":"A. Kerunwa, Binaebi Austin Gbaranbiri","doi":"10.3968/10412","DOIUrl":"https://doi.org/10.3968/10412","url":null,"abstract":"Hole cleaning is a key parameter in every drilling program. Efficient bottom hole cleaning is achieved through adequate transportation of cuttings from the wellbore to the surface. Modified natural polymers like Poly anionic cellulose regular (PAC-R), with bentonite clay has been used to achieve good carrying capacity of drilled cuttings in water base mud (WBM). These conventional polymers have adverse effect on the environment, especially the mud-filtrate which pollutes and contaminates the aquifer and the spent mud that requires caution for its disposal. In this work, Local viscosifers were obtained from Mucuna Flagellipe (Ukpo), Brachystegea Eurycoma (Achi), Afzelia Africana (Akpalata) and Detarium microcapum (Ofor) as a substitute for the imported viscosifiers (PAC R) used as a drilling fluid additives. Water-based muds were formulated from the aforementioned locally sourced viscosifiers and that of the conventionally used viscosifier (Pac-R). Laboratory tests were carried out on the different muds formulated and their rheological properties evaluated, such as yield stress, , shear stress plastic viscosity and shear rate. The concentrations of the locally sourced viscosifiers were varied and rheological tests performed show that Mucuna Flagellipe (Ukpo) had a better viscosity compared to Achi, Akplata and Ofor of the same concentration. It was also observed that 5g of Mucuna Flagellipe (Ukpo) and 8g of detarium microcapum (Ofor) gave an equivalent rheological properties of 27lb/100ft2and 26lb/100ft2 as yield stress when compared to2g of Pac-R which gave a yield point of 29lb/100ft2 at a temperature of 180˚F. Also, 8g of Mucuna Flagellipe (Ukpo) gave an equivalent of 5g of PAC-R. Hole cleaning parameters such as slip velocity, annular velocity and cuttings transport efficiency were also considered for evaluating the effectiveness of the proposed muds with local viscosifiers and conventional viscosifiers on hole cleaning. 5g and 8g of Mucuna Flagellipe (Ukpo) compared favourably with PAC-R in terms of hole cleaning. Finally in terms of cost, the locally sourced viscosifiers are cost effective when compared with the conventional vscosifier. Therefore, locally sourced viscosifiers (Mucuna Flagellipe, Ukpo) can be used as a substitute to the conventional Pac-R when drilling top hole at a temperature of 150˚F and below since these holes are drilled within a thermal gradient of 150˚F and below in the Niger delta region of Nigeria.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114665414","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}
Y. Ouyang, Yun-kai Gao, Xianwen Wang, Zhifeng Duan
For unconventional oil and gas reservoirs, the main body at home and abroad adopts segmented fracturing technology for cemented well completion bridge plugs, and the application ratio accounts for more than 85%. In order to improve the development effect of the tight oil and gas reservoirs in the Ordos Basin and increase the output of single wells, the horizontal wells in the Sulige tight gas reservoir adopt casing cementing well completion + bridge plug fracturing. The integrity between the casing-cement ring and the formation consolidation body is the precondition for ensuring the effectiveness of the segmented fracturing closure and the transformation effect. In this paper, the wellbore is subjected to alternating pressure when the volume of horizontal wells is compressed. By analyzing the force of the casing-cement-soil consolidated body and the temperature and casing internal pressure, the calculated relationship between the force of the consolidated body and the displacement of the first and second cemented surfaces was obtained. It provides an important reference for guiding the on-site construction design and follow-up research.
{"title":"Stress Analysis of the Integrity of Casing-Cement Ring-Structural Consolidation Body by Volume Fracturing","authors":"Y. Ouyang, Yun-kai Gao, Xianwen Wang, Zhifeng Duan","doi":"10.3968/10411","DOIUrl":"https://doi.org/10.3968/10411","url":null,"abstract":"For unconventional oil and gas reservoirs, the main body at home and abroad adopts segmented fracturing technology for cemented well completion bridge plugs, and the application ratio accounts for more than 85%. In order to improve the development effect of the tight oil and gas reservoirs in the Ordos Basin and increase the output of single wells, the horizontal wells in the Sulige tight gas reservoir adopt casing cementing well completion + bridge plug fracturing. The integrity between the casing-cement ring and the formation consolidation body is the precondition for ensuring the effectiveness of the segmented fracturing closure and the transformation effect. In this paper, the wellbore is subjected to alternating pressure when the volume of horizontal wells is compressed. By analyzing the force of the casing-cement-soil consolidated body and the temperature and casing internal pressure, the calculated relationship between the force of the consolidated body and the displacement of the first and second cemented surfaces was obtained. It provides an important reference for guiding the on-site construction design and follow-up research.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132816069","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 cementing interface of oil and gas wells is often the weak link between oil and gas turbulence. Due to the low cementation strength at the fracturing interface, the two interfaces have been crushed to form turbulence channels before the target layer is opened during fracturing. If the closure is not good, there will be inter-layer channeling. Therefore, the pressure bearing capacity of the fracturing interface is an important indicator for designing the fracturing construction parameters. The pressure capacity of the two interfaces during the fracturing process is the key to evaluating the success of the fracturing construction. This paper establishes the calculation model for the stress distribution of horizontal wells in horizontal wells under the effect of non-uniform stress. At the same time, the influence of the pressure change in the wellbore during the fracturing process on the stress distribution in the borehole wall was analyzed. The calculation model of the interfacial stress distribution in the horizontal well during the fracturing process was established, and the debonding pressure and debonding length of the two interfaces under different cementing strengths were calculated. After the establishment of the horizontal well fracturing two interface crack propagation mechanics model, calculate the pressure required for cracks along the two interfaces to expand at different failure lengths.
{"title":"Study on Failure Length of Cementing Interface in Horizontal Wells During Fracturing","authors":"Hongjun Lu, Xuesheng Wu, H. Meng, W. Xie","doi":"10.3968/10410","DOIUrl":"https://doi.org/10.3968/10410","url":null,"abstract":"The cementing interface of oil and gas wells is often the weak link between oil and gas turbulence. Due to the low cementation strength at the fracturing interface, the two interfaces have been crushed to form turbulence channels before the target layer is opened during fracturing. If the closure is not good, there will be inter-layer channeling. Therefore, the pressure bearing capacity of the fracturing interface is an important indicator for designing the fracturing construction parameters. The pressure capacity of the two interfaces during the fracturing process is the key to evaluating the success of the fracturing construction. This paper establishes the calculation model for the stress distribution of horizontal wells in horizontal wells under the effect of non-uniform stress. At the same time, the influence of the pressure change in the wellbore during the fracturing process on the stress distribution in the borehole wall was analyzed. The calculation model of the interfacial stress distribution in the horizontal well during the fracturing process was established, and the debonding pressure and debonding length of the two interfaces under different cementing strengths were calculated. After the establishment of the horizontal well fracturing two interface crack propagation mechanics model, calculate the pressure required for cracks along the two interfaces to expand at different failure lengths.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"49 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128410136","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}
Surfactant-polymer flooding technology which used in J oilfield is still the first time in Bohai bay, the reference materials are very seldom for its response characteristic and project optimization. Since there’s no blank water flooding stage between polymer flooding and surfactant-polymer flooding in J oilfield, it’s difficult to accurately judge the response characteristic of production wells and injection wells by the conventional method; on the other side, as surfactant-polymer flooding gradually entered the end stage, the effect of decrease water and increase oil became worse, there’s urgently need to improve the effect of chemical flooding. Thus, the research of response characteristic and mobility optimization are conducted in this article. The water cut funnel method is used for the first time to recognize the response of the production wells in J oilfield, and to use the Hall curve method to recognize the response of the injection wells. Meanwhile, based on the idea of mobility control, the minimum polymer concentration which is needed to control the mobility of surfactant-polymer flooding is studied, and establish the mobility control template, the effect of the surfactant-polymer flooding is improved effectively by use of the template to guide the optimization of the polymer concentration, and daily production increase about 15% of J oilfield. The research can be used to guide and refer to other similar offshore oilfield development.
{"title":"Research of Surfactant-polymer Flooding Response Characteristic and Mobility Optimization of J Oilfield in Bohai Bay","authors":"Xinran Wang, Zongbin Liu, Fengjun Zhou, Haofei Xu","doi":"10.3968/10414","DOIUrl":"https://doi.org/10.3968/10414","url":null,"abstract":"Surfactant-polymer flooding technology which used in J oilfield is still the first time in Bohai bay, the reference materials are very seldom for its response characteristic and project optimization. Since there’s no blank water flooding stage between polymer flooding and surfactant-polymer flooding in J oilfield, it’s difficult to accurately judge the response characteristic of production wells and injection wells by the conventional method; on the other side, as surfactant-polymer flooding gradually entered the end stage, the effect of decrease water and increase oil became worse, there’s urgently need to improve the effect of chemical flooding. Thus, the research of response characteristic and mobility optimization are conducted in this article. The water cut funnel method is used for the first time to recognize the response of the production wells in J oilfield, and to use the Hall curve method to recognize the response of the injection wells. Meanwhile, based on the idea of mobility control, the minimum polymer concentration which is needed to control the mobility of surfactant-polymer flooding is studied, and establish the mobility control template, the effect of the surfactant-polymer flooding is improved effectively by use of the template to guide the optimization of the polymer concentration, and daily production increase about 15% of J oilfield. The research can be used to guide and refer to other similar offshore oilfield development.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116227327","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}
Haige Wang, Guodong Ji, L. Cui, Siqi Li, T. Yan, Zihe Chen
Hamiltonian function is proposed and the modeling of system energy of rock under harmonic vibro-impact is undertaken in this study. The modeling includes two aspects, namely, energy equation of rock system with no damping and the one with damping. Also, the results of numerical simulation are presented. Four main control parameters are considered, including natural frequency of rock, impact frequency, impact force, damping coefficient. It is confirmed that the system energy of rock will increase with the increase of natural frequency impact frequency and impact force. While impact force, damping coefficient and stiffness of rock will mainly decide the vibration amplitude of system energy.
{"title":"Modeling of System Energy of Rock Under Harmonic Vibro-Impact","authors":"Haige Wang, Guodong Ji, L. Cui, Siqi Li, T. Yan, Zihe Chen","doi":"10.3968/10263","DOIUrl":"https://doi.org/10.3968/10263","url":null,"abstract":"Hamiltonian function is proposed and the modeling of system energy of rock under harmonic vibro-impact is undertaken in this study. The modeling includes two aspects, namely, energy equation of rock system with no damping and the one with damping. Also, the results of numerical simulation are presented. Four main control parameters are considered, including natural frequency of rock, impact frequency, impact force, damping coefficient. It is confirmed that the system energy of rock will increase with the increase of natural frequency impact frequency and impact force. While impact force, damping coefficient and stiffness of rock will mainly decide the vibration amplitude of system energy.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"603 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113996441","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 and gas discovery in the Liaodong Bay Depression is mainly distributed in the steep slope, the uplift and the sag zone at current situation. The reservoir developed on southeastern gentle slope zone is the first discovery in this area, which has great significance to the study of the gentle slope zone hydrocarbon accumulation regularity. Based on the analysis of the hydrocarbon accumulation condition of the gentle slope zone, the major controlling factors and hydrocarbon accumulation pattern of the gentle slope zone are summarized. It shows that the gentle slope belt has the superior accumulation conditions, where develops Lithological-tectonics traps and lithological traps Controlled by fracture and provenance. The source rock circumstance is advantageous too, because the gentle slope zone is close to the hydrocarbon-rich Liaozhong sag. The mudstone in Dongying formation(Ed) and the first section of Shahejie formation (Es1) and the sandstone in the second member of Shahejie formation (Es2) are form into a good reservoir cap association. Hydrocarbon accumulation in the gentle slope belt is mainly controlled by 3 factors: the development of the reservoirs in the Es2 is controlled by the valley-slope break coupling; the migration of oil and gas is controlled by “Fault-unconformity-sandbody”(FUS) long-range efficient migration system; reservoir physical properties and oil and gas test capacity are controlled by sedimentary facies differences. There are two reservoir models: lithology - tectonics and lithology.
{"title":"The Major Controlling Factors Analysis of Hydrocarbon Accumulation on the Gentle Slope Belt of the Southeastern Liaodong Bay Depression","authors":"Yongjun Liu, Xiang-yang Tu, Wensen Zhu, Geng Qian, De-bing Zhang","doi":"10.3968/10437","DOIUrl":"https://doi.org/10.3968/10437","url":null,"abstract":"Oil and gas discovery in the Liaodong Bay Depression is mainly distributed in the steep slope, the uplift and the sag zone at current situation. The reservoir developed on southeastern gentle slope zone is the first discovery in this area, which has great significance to the study of the gentle slope zone hydrocarbon accumulation regularity. Based on the analysis of the hydrocarbon accumulation condition of the gentle slope zone, the major controlling factors and hydrocarbon accumulation pattern of the gentle slope zone are summarized. It shows that the gentle slope belt has the superior accumulation conditions, where develops Lithological-tectonics traps and lithological traps Controlled by fracture and provenance. The source rock circumstance is advantageous too, because the gentle slope zone is close to the hydrocarbon-rich Liaozhong sag. The mudstone in Dongying formation(Ed) and the first section of Shahejie formation (Es1) and the sandstone in the second member of Shahejie formation (Es2) are form into a good reservoir cap association. Hydrocarbon accumulation in the gentle slope belt is mainly controlled by 3 factors: the development of the reservoirs in the Es2 is controlled by the valley-slope break coupling; the migration of oil and gas is controlled by “Fault-unconformity-sandbody”(FUS) long-range efficient migration system; reservoir physical properties and oil and gas test capacity are controlled by sedimentary facies differences. There are two reservoir models: lithology - tectonics and lithology.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130254802","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}
In this study, well log derived petrophysical parameters of four (4) delineated clastic reservoirs in AK field, located onshore eastern Niger Delta have been effectively employed to characterize and assess hydrocarbon prospect potential of the field. Wireline well log data, such as gamma ray, resistivity log suite, Compensated Neutron Log (CNL) and Formation Density Compensated (FDC) were studied and analyzed for qualitative and quantitative evaluation of the formation units in the field. Lithologic discrimination aided the identification of sandy units, while fluid identification and discrimination defined the hydrocarbon saturated reservoir units in the field. Other derived parameters such as porosity, permeability, water saturation, hydrocarbon saturation, Net To Gross (NTG), net hydrocarbon pay, Bulk Volume Water (BVW) among others were employed to quantitatively characterize the delineated reservoir units, especially to establish their hydrocarbon potential. Four (4) sandy reservoir units, A1, A2, A3 and A4 which ranged in thickness from about 60-350 ft were identified from four exploratory wells AK-01, AK-02, AK-03 and AK 04 to be hydrocarbon bearing. The clastic reservoirs presented medium to relatively high formation porosity (0.27-0.38), low to average permeability value (61.6-685.5 mD) and significant to high hydrocarbon saturation (0.42-0.97). A plot of true formation resistivity values (Rt) against water saturation (Sw) indicate that all reservoir units encountered in well AK-01 are oil saturated. However, only reservoir sands A1 and A2 are predominantly oil reservoirs in well AK02 while sands A3 and A4 plot in oil and water field. In well AK-03, reservoir A1 contains only oil while the remaining reservoirs contain oil and water. The reservoir units as encountered in well AK-04 show slightly different fluid saturation pattern as reservoir A1 contains only oil, A4 is gas saturated while the remaining two reservoir units (A3 and A4) plot in the field of both water and oil.
{"title":"Petrophysical Properties’ Evaluation for Reservoir Characterization of AK Field, Onshore Eastern Niger Delta, Southern Nigeria","authors":"O. Osinowo, F. S. Ajayi, Nurudeen Abiodun Akeye","doi":"10.3968/10350","DOIUrl":"https://doi.org/10.3968/10350","url":null,"abstract":"In this study, well log derived petrophysical parameters of four (4) delineated clastic reservoirs in AK field, located onshore eastern Niger Delta have been effectively employed to characterize and assess hydrocarbon prospect potential of the field. Wireline well log data, such as gamma ray, resistivity log suite, Compensated Neutron Log (CNL) and Formation Density Compensated (FDC) were studied and analyzed for qualitative and quantitative evaluation of the formation units in the field. Lithologic discrimination aided the identification of sandy units, while fluid identification and discrimination defined the hydrocarbon saturated reservoir units in the field. Other derived parameters such as porosity, permeability, water saturation, hydrocarbon saturation, Net To Gross (NTG), net hydrocarbon pay, Bulk Volume Water (BVW) among others were employed to quantitatively characterize the delineated reservoir units, especially to establish their hydrocarbon potential. Four (4) sandy reservoir units, A1, A2, A3 and A4 which ranged in thickness from about 60-350 ft were identified from four exploratory wells AK-01, AK-02, AK-03 and AK 04 to be hydrocarbon bearing. The clastic reservoirs presented medium to relatively high formation porosity (0.27-0.38), low to average permeability value (61.6-685.5 mD) and significant to high hydrocarbon saturation (0.42-0.97). A plot of true formation resistivity values (Rt) against water saturation (Sw) indicate that all reservoir units encountered in well AK-01 are oil saturated. However, only reservoir sands A1 and A2 are predominantly oil reservoirs in well AK02 while sands A3 and A4 plot in oil and water field. In well AK-03, reservoir A1 contains only oil while the remaining reservoirs contain oil and water. The reservoir units as encountered in well AK-04 show slightly different fluid saturation pattern as reservoir A1 contains only oil, A4 is gas saturated while the remaining two reservoir units (A3 and A4) plot in the field of both water and oil.","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"97 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133615592","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}
BHA lateral vibration has been identified as one limiter that may hinder the rate of penetration (ROP). Based on Newton’s equations of motion and Euler-Bernoulli beam bending equation, a steady-state forced-frequency response dynamic model was developed to analyze vibration performance for a single point mass in the BHA surrogate. Wherein, the connection between points relied on massless springs or dampers. The frequency-domain model more accurately represented actual mechanical states for a particular BHA configuration. On this basis, the state vector for a mass point was calculated by the semi-analytical transfer function matrix method at any given position in the BHA surrogate, which greatly reduced the number of discrete elements and the associated computing time. It caused rapid screening of a large number of design alternatives on a PC. The state vector included the lateral and angular deflections, as well as the beam bending moment and shear load, which were integrated as a dynamic vibration performance index called Lateral Vibration Strength Estimate (LSE) utilized to quantitatively evaluate the lateral vibration state. The field application demonstrates that the methods for modeling bottom hole assembly (BHA) vibration performance during drilling to enable improved design in pre-drill and operation for enhanced drilling rate of penetration, to reduce downhole equipment failure in drilling. Field validation for the surveillance tool was performed by comparing high-frequency downhole memory sensor data (100samples/second data rate).
{"title":"Development and Application of a BHA Vibrations Analysis Model","authors":"Meng Cui","doi":"10.3968/10409","DOIUrl":"https://doi.org/10.3968/10409","url":null,"abstract":"BHA lateral vibration has been identified as one limiter that may hinder the rate of penetration (ROP). Based on Newton’s equations of motion and Euler-Bernoulli beam bending equation, a steady-state forced-frequency response dynamic model was developed to analyze vibration performance for a single point mass in the BHA surrogate. Wherein, the connection between points relied on massless springs or dampers. The frequency-domain model more accurately represented actual mechanical states for a particular BHA configuration. On this basis, the state vector for a mass point was calculated by the semi-analytical transfer function matrix method at any given position in the BHA surrogate, which greatly reduced the number of discrete elements and the associated computing time. It caused rapid screening of a large number of design alternatives on a PC. The state vector included the lateral and angular deflections, as well as the beam bending moment and shear load, which were integrated as a dynamic vibration performance index called Lateral Vibration Strength Estimate (LSE) utilized to quantitatively evaluate the lateral vibration state. The field application demonstrates that the methods for modeling bottom hole assembly (BHA) vibration performance during drilling to enable improved design in pre-drill and operation for enhanced drilling rate of penetration, to reduce downhole equipment failure in drilling. Field validation for the surveillance tool was performed by comparing high-frequency downhole memory sensor data (100samples/second data rate).","PeriodicalId":313367,"journal":{"name":"Advances in Petroleum Exploration and Development","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132547470","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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