PETROPHYSICAL ANALYSIS AND SEISMIC STRATIGRAPHY INTERPRETATION TO DETERMINE HYDROCARBON RESERVOIR IN TARAKAN BASIN, BUNYU ISLAND WATERS

Tarakan Basin area of Bunyu Island Waters is known to have hydrocarbon potential with complex geological structures. This study aims to determine reservoir characterization and to obtain prospect of hydrocarbon reservoir zones based on petrophysical and seismic stratigraphy analysis with reference to Well DDS-1 and 2D seismic Line S88. Petrophysical analysis results 3 zones that have potential as hydrocarbon reservoirs. Based on petrophysical quantitative analysis, Zone 1 has values of 52.25% for shale volume, 18.48% for effective porosity, 39.84% for water saturation and 13.03 mD for permeability. Zone 2 has values of 54.66% for shale volume, 10.27% for effective porosity, 40.9% for water saturation and 1.14 mD for permeability. Zone 3 has values of 49.22% for shale volume, 9.33% for effective porosity, 56.33% for water saturation and 0.22 mD for permeability. Out of these three reservoir zones in Well DDS- 1, Zone 1 has the prospect of hydrocarbons which is supported by the net pay value. Based on seismic stratigraphy interpretation, the reservoir zone is correlated to the Tabul Formation, which comprises calcareous clay and limestone.

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Petrophysical Analysis to Determine Reservoir and Source Rocks in Berau Basin, West Papua Waters

BULLETIN OF THE MARINE GEOLOGY ◽

10.32693/bomg.35.1.2020.659 ◽

2020 ◽

Vol 35 (1) ◽

Author(s):

Popy Dwi Indriyani ◽

Asep Harja ◽

Tumpal Bernhard Nainggolan

Keyword(s):

Source Rock ◽

Water Saturation ◽

Effective Porosity ◽

Source Rocks ◽

Reservoir Rock ◽

Petrophysical Analysis ◽

Shale Volume ◽

Clastic Sediments ◽

Volume Porosity ◽

West Papua

Berau Basin is assessed to have same potential in clastic sediments with Mesozoic and Paleozoic ages, where reservoirs and source rocks are similar to productive areas of hydrocarbons in Northwest Shield Australia. This study aims to identify the hydrocarbon prospect zones and potential rocks zones using petrophysical parameters, such as shale volume, porosity, water saturation and permeability. Petrophysical analysis of reservoir and source rock are carried out on three wells located in the Berau Basin, namely DI-1, DI-2 and DI-3 in Kembelangan and Tipuma Formation. Qualitative analysis shows that there are 4 reservoir rock zones and 4 source rock zones from thorough analysis of these three wells. Based on quantitative analysis of DI-1 well, it has an average shale volume (Vsh) 9.253%, effective porosity (PHIE) 20.68%, water saturation (Sw) 93.3% and permeability (k) 55.69 mD. DI-2 well’s average shale volume, effective porosity, water saturation and permeability values are 29.16%, 2.97%, 67.9% and 0.05 mD, respectively. In DI-3 well, average shale volume, effective porosity, water saturation and permeability values are 6.205%, 19.36%, 80.2% and 242.05 mD, respectively. From the reservoir zone of these three wells in Kembelangan Formation, there are no show any hydrocarbon prospect.

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Hydrocarbon Reservoir Characterization of ‘Khume’ Field, Offshore Niger Delta, Nigeria

Journal of Geography Environment and Earth Science International ◽

10.9734/jgeesi/2021/v25i1030314 ◽

2021 ◽

pp. 47-60

Author(s):

K. A. Obakhume ◽

O. M. Ekeng ◽

C. Atuanya

Keyword(s):

Niger Delta ◽

Reservoir Characterization ◽

Gamma Ray ◽

Water Saturation ◽

Seismic Interpretation ◽

Effective Porosity ◽

Well Logs ◽

Integrative Approach ◽

Neutron Density ◽

Hydrocarbon Reservoir

The integrative approach of well log correlation and seismic interpretation was adopted in this study to adequately characterize and evaluate the hydrocarbon potentials of Khume field, offshore Niger Delta, Nigeria. 3-D seismic data and well logs data from ten (10) wells were utilized to delineate the geometry of the reservoirs in Khume field, and as well as to estimate the hydrocarbon reserves. Three hydrocarbon-bearing reservoirs of interest (D-04, D-06, and E-09A) were delineated using an array of gamma-ray logs, resistivity log, and neutron/density log suites. Stratigraphic interpretation of the lithologies in Khume field showed considerable uniform gross thickness across all three sand bodies. Results of petrophysical evaluations conducted on the three reservoirs correlated across the field showed that; shale volume ranged from 7-14%, total and effective porosity ranged from 19-26% and 17-23% respectively, NTG from 42 to 100%, water saturation from 40%-100% and permeability from 1265-2102 mD. Seismic interpretation established the presence of both synthetic and antithetic faults. A total of six synthetic and four antithetic faults were interpreted from the study area. Horizons interpretation was done both in the strike and dip directions. Time and depth structure maps revealed reservoir closures to be anticlinal and fault supported in the field. Hydrocarbon volumes were calculated using the deterministic (map-based) approach. Stock tank oil initially in place (STOIIP) for the proven oil column estimated for the D-04 reservoir was 11.13 MMSTB, 0.54 MMSTB for D-06, and 2.16 MMSTB for E-09A reservoir. For the possible oil reserves, a STOIIP value of 7.28 MMSTB was estimated for D-06 and 6.30 MMSTB for E-09A reservoir, while a hydrocarbon initially in place (HIIP) of 4.13 MMSTB of oil equivalents was derived for the undefined fluid (oil/gas) in D-06 reservoir. A proven gas reserve of 1.07 MMSCF was derived for the D-06 reservoir. This study demonstrated the effectiveness of 3-D seismic and well logs data in delineating reservoir structural architecture and in estimating hydrocarbon volumes

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An Integrated Microfacies and Well Logs-Based Reservoir Characterization of Yamama Formation, Southern Iraq

Iraqi Journal of Science ◽

10.24996/ijs.2021.62.10.16 ◽

2021 ◽

pp. 3570-3586

Author(s):

Mohanad M. Al-Ghuribawi ◽

Rasha F. Faisal

Keyword(s):

Reservoir Characterization ◽

Water Saturation ◽

Effective Porosity ◽

Well Logs ◽

Petrophysical Properties ◽

Reservoir Properties ◽

Thin Sections ◽

Porosity And Permeability ◽

South Of Iraq ◽

Southern Iraq

The Yamama Formation includes important carbonates reservoir that belongs to the Lower Cretaceous sequence in Southern Iraq. This study covers two oil fields (Sindbad and Siba) that are distributed Southeastern Basrah Governorate, South of Iraq. Yamama reservoir units were determined based on the study of cores, well logs, and petrographic examination of thin sections that required a detailed integration of geological data and petrophysical properties. These parameters were integrated in order to divide the Yamama Formation into six reservoir units (YA0, YA1, YA2, YB1, YB2 and YC), located between five cap rock units. The best facies association and petrophysical properties were found in the shoal environment, where the most common porosity types were the primary (interparticle) and secondary (moldic and vugs) . The main diagenetic process that occurred in YA0, YA2, and YB1 is cementation, which led to the filling of pore spaces by cement and subsequently decreased the reservoir quality (porosity and permeability). Based on the results of the final digital computer interpretation and processing (CPI) performed by using the Techlog software, the units YA1 and YB2 have the best reservoir properties. The unit YB2 is characterized by a good effective porosity average, low water saturation, good permeability, and large thickness that distinguish it from other reservoir units.

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Hydrocarbon reservoir characterization of “Otan-Ile” field, Niger Delta

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-020-01069-y ◽

2021 ◽

Vol 11 (2) ◽

pp. 601-615

Author(s):

Tokunbo Sanmi Fagbemigun ◽

Michael Ayu Ayuk ◽

Olufemi Enitan Oyanameh ◽

Opeyemi Joshua Akinrinade ◽

Joel Olayide Amosun ◽

...

Keyword(s):

Niger Delta ◽

Reservoir Characterization ◽

Water Saturation ◽

Structural Deformation ◽

Well Log ◽

Reservoir Properties ◽

Good Tool ◽

Log Data ◽

Hydrocarbon Reservoir ◽

Hydrocarbon Saturation

AbstractOtan-Ile field, located in the transition zone Niger Delta, is characterized by complex structural deformation and faulting which lead to high uncertainties of reservoir properties. These high uncertainties greatly affect the exploration and development of the Otan-Ile field, and thus require proper characterization. Reservoir characterization requires integration of different data such as seismic and well log data, which are used to develop proper reservoir model. Therefore, the objective of this study is to characterize the reservoir sand bodies across the Otan-Ile field and to evaluate the petrophysical parameters using 3-dimension seismic and well log data from four wells. Reservoir sands were delineated using combination of resistivity and gamma ray logs. The estimation of reservoir properties, such as gross thickness, net thickness, volume of shale, porosity, water saturation and hydrocarbon saturation, were done using standard equations. Two horizons (T and U) as well as major and minor faults were mapped across the ‘Otan-Ile’ field. The results show that the average net thickness, volume of shale, porosity, hydrocarbon saturation and permeability across the field are 28.19 m, 15%, 37%, 71% and 26,740.24 md respectively. Two major faults (F1 and F5) dipping in northeastern and northwestern direction were identified. The horizons were characterized by structural closures which can accommodate hydrocarbon were identified. Amplitude maps superimposed on depth-structure map also validate the hydrocarbon potential of the closures on it. This study shows that the integration of 3D seismic and well log data with seismic attribute is a good tool for proper hydrocarbon reservoir characterization.

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Characterization of Mishrif Formation Reservoir in Amara Oil Field, Southeast Iraq, Using Geophysical Well-logging

Iraqi Journal of Science ◽

10.24996/ijs.2021.62.12.11 ◽

2021 ◽

pp. 4702-4711

Author(s):

Asmaa Talal Fadel ◽

Madhat E. Nasser

Keyword(s):

Reservoir Characterization ◽

Gamma Ray ◽

Water Saturation ◽

Total Porosity ◽

Effective Porosity ◽

Oil Field ◽

Neutron Density ◽

Reservoir Water ◽

Resistivity Logs ◽

Reliable Knowledge

Reservoir characterization requires reliable knowledge of certain fundamental properties of the reservoir. These properties can be defined or at least inferred by log measurements, including porosity, resistivity, volume of shale, lithology, water saturation, and permeability of oil or gas. The current research is an estimate of the reservoir characteristics of Mishrif Formation in Amara Oil Field, particularly well AM-1, in south eastern Iraq. Mishrif Formation (Cenomanin-Early Touronin) is considered as the prime reservoir in Amara Oil Field. The Formation is divided into three reservoir units (MA, MB, MC). The unit MB is divided into two secondary units (MB1, MB2) while the unit MC is also divided into two secondary units (MC1, MC2). Using Geoframe software, the available well log images (sonic, density, neutron, gamma ray, spontaneous potential, and resistivity logs) were digitized and updated. Petrophysical properties, such as porosity, saturation of water, saturation of hydrocarbon, etc. were calculated and explained. The total porosity was measured using the density and neutron log, and then corrected to measure the effective porosity by the volume content of clay. Neutron -density cross-plot showed that Mishrif Formation lithology consists predominantly of limestone. The reservoir water resistivity (Rw) values of the Formation were calculated using Pickett-Plot method.

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Reservoir Characterization of Sand Intervals of Lower Goru Formation Using Petrophysical Studies; A Case Study of Zaur-03 Well, Badin Block, Pakistan

International Journal of Economic and Environmental Geology ◽

10.46660/ojs.v10i3.320 ◽

2019 ◽

Vol 10 (3) ◽

pp. 118-124

Author(s):

Mustafa Yar ◽

Syed Waqas Haider ◽

Ghulam Nabi ◽

Muhammad Tufail ◽

Sajid Rahman

Keyword(s):

Reservoir Characterization ◽

Water Saturation ◽

Effective Porosity ◽

Indus Basin ◽

Reservoir Properties ◽

Drilling Parameters ◽

Resistivity Logs ◽

Prime Objective ◽

Lower Goru Formation

Present study deals with petrophysical interpretation of Zaur-03 well for reservoir characterization of sandintervals of Lower Goru Formation in Badin Block, Southern Indus Basin, Pakistan. Early Cretaceous Lower GoruFormation is the distinct reservoir that is producing hydrocarbons for two decades. Complete suite of wireline logsincluding GR log, Caliper log, SP log, Resistivity logs (MSFL, LLS, LLD), Neutron log and Density log along withwell tops and complete drilling parameters were analyzed in this study. The prime objective of this study was to markzones of interest that could act as reservoir and to evaluate reservoir properties including shale volume (Vsh), porosity(ϕ), water saturation (Sw), hydrocarbon saturation (Sh) and net pay thickness. Based on Petrophysical evaluation threezones have been marked in Lower Goru Formation, A Sand (1890m to 1930m), B-sand (1935m to 2010) and C-sand(2015m to 2100m). The average calculated parameters for evaluation of reservoir properties of Zaur-03 well depicts anaverage porosity of 8.92% and effective porosity of 4.81%. Water Saturation is calculated as 28.54% and HydrocarbonsSaturation is 71.46%. Analysis shows that Sh in Zaur-03 well is high so the production of hydrocarbons iseconomically feasible.

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Seismic Data Interpretation and Petrophysical Analysis of Kabirwala Area Tola (01) Well, Central Indus Basin, Pakistan

Applied Sciences ◽

10.3390/app11072911 ◽

2021 ◽

Vol 11 (7) ◽

pp. 2911

Author(s):

Naveed Ahmad ◽

Sikandar Khan ◽

Abdullatif Al-Shuhail

Keyword(s):

Gamma Ray ◽

Water Saturation ◽

Research Work ◽

Total Porosity ◽

Effective Porosity ◽

Indus Basin ◽

Drilling Process ◽

Reservoir Properties ◽

Log Data ◽

Petrophysical Analysis

Well logging is a significant procedure that assists geophysicists and geologists with making predictions regarding boreholes and efficiently utilizing and optimizing the drilling process. The current study area is positioned in the Punjab Territory of Pakistan, and the geographic coordinates are 30020′10 N and 70043′30 E. The objective of the current research work was to interpret the subsurface structure and reservoir characteristics of the Kabirwala area Tola (01) well, which is located in the Punjab platform, Central Indus Basin, utilizing 2D seismic and well log data. Formation evaluation for hydrocarbon potential using the reservoir properties is performed in this study. For the marked zone of interest, the study also focuses on evaluating the average water saturation, average total porosity, average effective porosity, and net pay thickness. The results of the study show a spotted horizon stone with respect to time and depth as follows: Dunghan formation, 0.9 s and 1080.46 m; Cretaceous Samana Suk formation, 0.96 s and 1174.05 m; Datta formation, 1.08 s and 1400 m; and Warcha formation, 1.24 s and 1810 m. Based on the interpretation of well logs, the purpose of petrophysical analysis was to identify hydrocarbon-bearing zones in the study area. Gamma ray, spontaneous potential, resistivity, neutron, and density log data were utilized. The high zone present in the east–west part of the contour maps may be a possible location of hydrocarbon entrapment, which is further confirmed by the presence of the Tola-01 well.

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Reservoir Characterization of Sand Intervals of Lower Goru Formation Using Petrophysical Studies; A Case Study of Zaur-03 Well, Badin Block, Pakistan

International Journal of Economic and Environmental Geology ◽

10.46660/ijeeg.vol10.iss3.2019.320 ◽

2019 ◽

Vol 10 (3) ◽

pp. 118-124

Author(s):

Mustafa Yar ◽

Syed Waqas Haider ◽

Ghulam Nabi ◽

Muhammad Tufail ◽

Sajid Rahman

Keyword(s):

Reservoir Characterization ◽

Water Saturation ◽

Effective Porosity ◽

Indus Basin ◽

Reservoir Properties ◽

Drilling Parameters ◽

Resistivity Logs ◽

Prime Objective ◽

Lower Goru Formation

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Geophysical appraisal for the sandy levels within Abu Roash C and E members in Abu Gharadig Field, Western Desert, Egypt

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-021-01107-3 ◽

2021 ◽

Vol 11 (3) ◽

pp. 1101-1122

Author(s):

Mohammad Abdelfattah Sarhan

Keyword(s):

Relative Permeability ◽

Water Saturation ◽

Effective Porosity ◽

Western Desert ◽

Absolute Permeability ◽

Normal Faults ◽

Shale Volume ◽

Bulk Volume ◽

Zone Ii ◽

Water Cut

AbstractThe present work concerns with the geophysical assessment for the sandstones of Abu Roash C and E members for being potential hydrocarbon reservoirs at Abu Gharadig Field, Western Desert, Egypt. The analysis of seismic data covers Abu Gharadig Field showing ENE–WSW anticline fragmented by NW–SE normal faults. The presence of these structures is due to the dextral wrench corridor that extensively deformed the north area of the Western Desert within Late Cretaceous episode. The examination of well-log data of Abu Gharadig-6 Well revealed that the favourable zone locates between depths 9665–9700 ft (zone I) within Abu Roash “C” Member. The second promising zone in Abu Gharadig-15 Well occurs between depths 9962–9973 ft (zone II) in Abu Roash “E” Member. The quantitative evaluation indicated that zone I has better reservoir quality than zone II since it is characterised by low shale volume (0.01), high effective porosity (0.22), low water saturation (0.14), low bulk volume of water (0.03), higher values of absolute permeability (113 mD), high relative permeability to oil and low water cut, whereas zone II has 0.13 shale volume, 0.16 effective porosity, 0.39 water saturation, 0.06 bulk volume of water, lower values of absolute permeability (27 mD), low relative permeability to oil and relatively high water cut. The obtained results recommended that the drilling efforts should be focused on the sandy levels within Abu Roash C Member (1st priority) and the sand levels within Abu Roash E Member (2nd priority) in Abu Gharadig Basin and its surroundings.

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Determination of Petrophysical Parameters of Reservoir Rock with a Special Look to Shale Effect (Case Study: One of the Gas Fields in Southern Iran)

Petroleum & Petrochemical Engineering Journal ◽

10.23880/ppej-16000262 ◽

2021 ◽

Vol 5 (2) ◽

pp. 1-10

Author(s):

Taheri K

Keyword(s):

Water Saturation ◽

Accurate Determination ◽

Reservoir Rock ◽

Petrophysical Properties ◽

Gas Reservoir ◽

Reservoir Water ◽

Petrophysical Parameters ◽

Hydrocarbon Reservoir ◽

Shale Volume

Determination of petrophysical parameters is necessary for modeling hydrocarbon reservoir rock. The petrophysical properties of rocks influenced mainly by the presence of clay in sedimentary environments. Accurate determination of reservoir quality and other petrophysical parameters such as porosity, type, and distribution of reservoir fluid, and lithology are based on evaluation and determination of shale volume. If the effect of shale volume in the formation not calculated and considered, it will have an apparent impact on the results of calculating the porosity and saturation of the reservoir water. This study performed due to the importance of shale in petrophysical calculations of this gas reservoir. The shale volume and its effect on determining the petrophysical properties and ignoring it studied in gas well P19. This evaluation was performed in Formations A and B at depths of 3363.77 to 3738.98 m with a thickness of 375 m using a probabilistic calculation method. The results of evaluations of this well without considering shale showed that the total porosity was 0.1 percent, the complete water saturation was 31 percent, and the active water saturation was 29 percent, which led to a 1 percent increase in effective porosity. The difference between water saturation values in Archie and Indonesia methods and 3.3 percent shale volume in the zones show that despite the low shale volume in Formations A and B, its effect on petrophysical parameters has been significant. The results showed that if the shale effect not seen in the evaluation of this gas reservoir, it can lead to significant errors in calculations and correct determination of petrophysical parameters.

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