Tamarind Field. -Case Study- IIT-Kharagpur Prithvi-2016
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1 Tamarind Field -Case Study- IIT-Kharagpur Prithvi-2016 Disclaimer: The materials used in this exercise are only for educational purpose specific to the IIT-Kharagpur Prithvi event-2016 and thereby can not be used or reproduced for any purpose without prior consent from Cairn India Ltd.
2 Introduction: The Tamarind Field is an onshore field which consists of fluvial clastic reservoirs and lacustrine shale. Delft Formation is the oil bearing sandy interval (reservoir), where basal units have better sand development. The overlying thick Macay Shale interval is working as the regional seal across the field. The field lies in the region which has suffered extensive structural deformation and adjustment, which gave rise to fault dip closure structural trap. The oil company has used 3D seismic data for mapping key reservoir units mainly top of reservoir and determined the over all field structure. Oil company has also acquired all basic logs in all wells and estimated the petrophysical properties like porosity, water saturation etc. Objective: The company is planning to develop the Tamarind field. For detailed planning they need to evaluate the EUR and profit/loss condition owing to operation for 5 years with available geological and geophysical data and other relevant data. Problem Statement: Prepare depth map using given depth values and well logs and estimate the hydrocarbon in place volume(stoiip) for Tamarind field. Estimate the EUR of the Tamarind field based on provided recovery factor. Calculate the Total Profit after tax for 5 year( year wise break ups ). The required information is provided below: Ultimate Recovery Factor of the reservoir : 30% The field is to be produced for 5 years. Reserve Exhaustion: For the first year 10 % of EUR For the second year 25% of EUR For the third year 35% of EUR For the fourth year 20% of EUR For the fifth year 10% of EUR Crude Price : Refer adjacent table Capital Expenditure : Rs Cr. ( one time before commencement of production) Average Crude Year Price(Rs./bbl) Operating Expenditure : Rs. 350 / barrel ( 1 st year), Rs.350/ barrel ( 2 nd year ), Rs.450/barrel ( 3 rd Year ), Rs. 500/barrel ( 4 th Year ) & Rs.500/barrel ( 5 th year ) Taxes to Government : 30% ( 1 st year ), 40%( 2 nd Year ), 50% ( 3 rd year ), 30% ( 4 th year ) & 20% ( 5 th Year ) Field abandonment cost : 15% of Capex Corporate Income tax : 10% of every years revenue Capextobedistributedas40%1 st year,30%2 nd year,and10%insubsequentyearswithnointerestandnodepreciationasincentive.
3 Blue Bird Basin Data Provided: 1. Basemap (Fig-1), TVDSS depth (True Vertical depth Sub-Sea) values (-ve no. is sign convention depicting measurements below MSL) and well locations for seismic-interpreted Top Delft Formation(Reservoir) are provided with major faults. 2. Well panels of field for well-correlation(fig-2: field Tamarind). 3. Well-log templates of Tamarind Field(Fig-2) consist TVDSS depth (SSTVD), Gamma-Ray (GR), Deep Resistivity (LLD), Density (RHOB) and Neutron(TNPH). 4. SeismicSectionsinthestudyarea(ReferFig-3toFig-5) 5. Annexure with key formulae, some reservoir parameters and some general tips. 6. Graph and tracing papers for area and volume calculation purpose. Exercise: 1. All exercises should be done in the A3 size maps/sections/well-templates. 2. Basemap for field (Fig-1) showing seismic interpreted Top Delft Reservoir depth values and well locations has been provided. Prepare the depth contour map at 50m contour interval for field. Well logs from the field have been provided with corresponding TVDSS depth. 3. a) Mark the reservoir top, base and Oil-Water Contact(OWC) on the respective well templates of the fields. b) Identify smaller units(if any) within Delft formation. Make well correlation using log motifs for each field. 4. Mark the major Faults on the seismic section passing through the area of interest as highlighted in Fig-1 with dotted lines. 5. Estimatethenetandgrossreservoirthicknessesfortheindividualwellsaswellasforthefield. 6. IdentifyAverageNettoGrossRatio(NTG)forthefieldfromwelllogs. 7. Calculate the area for possible hydrocarbon accumulations using the graph sheets and tracing papers. 8. Estimate the STOIIP of the Tamarind Field(Refer the tips/ formulae provided). 9. Calculate the Reserves based on given Recovery Factor. 10.CalculatetheTotalProfitaftertaxfor5year(yearwisebreakups).
4 Annexure: Glossary: MM Million (10^6) MMm 3 Million Cubic Metres MMbbls Million Barrels TVDSS True Vertical Depth with respect to Mean Sea level (MSL) ms millisecond GR Gamma Ray Log LLD Deep Resistivity Log RHOB Density Log TNPH Neutron Log Bo Formation Volume Factor for Oil EUR Estimated Ultimate Recovery FVF Formation Volume Factor Key Formulae: Conversion Factors: Barrel (bbl) to Cubic Metre Cubic Metre to Barrel (bbl) General Tips: Calculate area in sq. m. unit and use given average reservoir thickness for each field. Calculate average NTG from logs. Porosity, Saturation, Bo values for each field are given below. Formulae for time-depth conversion and STOIIP calculation are given. Consider all the depth values in logs to be negative. Negative values represent depth below Mean Sea Level (MSL). (MSL=0 TVDSS=0 TWTSS) Tamarind Field Avg. Thickness (m) 90 Avg. Water Saturation 5% Avg. porosity 26% Bo/FVF 1.05 Gross Rock Volume (GRV) in MMm 3 for any field = Area of hydrocarbon accumulation in m 2 X Average Reservoir Thickness Hydrocarbon In-Place or STOIIP (MMbbls) = (GRV X Avg. NTG X Avg. Porosity X Avg. HC Saturation X Geometric Factor)/FVF HC Saturation = 1 (Average Water Saturation) Millions of Cubic Metres (MMm 3 ) = 10^6 m 3 Geometric Factor= Conversation factor from m 3 to bbl
5 A A B B Fig1: Base map of Tamarind Field for the Top Delft Formation with TVDSS depth points, well locations, major faults and key Seismic lines C
6 Fig. 2: Well logs for Tamarind Field
7 A A Denotes Reservoir Zone Fig. 3
8 B B Denotes Reservoir Zone Fig. 4
9 C C Denotes Reservoir Zone Fig. 5
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