Wadi Petro VC November 9 2015 in

DeGolyer and MacNaughtonNovember 9, 2015

Video Conference

Reservoir Simulation Study of Meem and Nubian Reservoir Simulation Study of Meem and Nubian Formations of Wadi FieldFormations of Wadi Field

Petrophysical Evaluation

PetrophysicsPetrophysicsOutlineOutline

Data Inventory Data Quality and Calibration Initial Calculations Shale Volume Porosity Water Saturation Permeability Cutoffs

Reservoir Simulation Study of Meem and Nubian Formations of Wadi FieldPetrophysical Evaluation

November 9, 2015Video Conference

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PetrophysicsPetrophysicsData InventoryData Inventory

Scanning software was used to initially analyze the provided dataset This was used as a quick overview of the dataset only

All files and folders were then manually opened, reviewed, and loaded into TechLog The table below outlines the exact data available in the provided LAS files.

Provided field prints were also reviewed Review of field prints often revealed that some logging runs were not provided

Data scan files and individual well LAS files were checked again to verify (14-Oct-2015)

New digital data in May 2015x = not in datasetData identified in well reports - not found in dataset

Well Zone Core GR Th SP Caliper Rshallow RT DRHO Neutron Density DT Dipole Stonley Image Log NotesD18 Nubian x GR THOR SP CALI LLs LLD x x x DT x FMS?D20 Nubian x GR THOR SP CALI MSFL LLD DRHO NPHI RHOB DT xD22 Nubian x GR HTHO SP HCAL RXO8 AT90 HDRA HNPO RHOZ DTCO MSIP FMI FMI run: 11212 to 12118ft Rm=0.19ohmm at 265F, 8.7ppg.D26 Nubian x GR TH CAL M21R M2RX ZCOR CNC RHOB DT24 x STAR STAR image in top 100ft only - pdf to 12k ft, XMAC run but no dipole in dataset



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Meem Log Data Summary Induction tools used for all available Meem logging intervals Compressional Sonic logged in all Meem intervals, Density logs in 10 wells 7 well with core data in the Meem

WellZoneDateBHTRmRmcRmfMud

TempMudDFDCoreGRThSPCaliperRshallowRTDRHONeutronDensityDTDipoleD1Meem19691700.8670.7740.7267Bentonite1.09xGR editxSPCALISNILDDRHOxRHOBDTxD2Meem19691950.380.530.394Bentonite1.16xGRxSPCALIMLLILDxxxDTxD3Meem19711940.7470.750.1570Bentonite1.15xGRxSPCALIMLLILDDRHOxRHOBDTxD4Meem MeemGRxSPCALIMLLILDDRHOLIPRHOBDTxD5Meem xGRxSPCALIMLLILDDRHOxRHOBDTxD6Meem19882450.080.10.06575CL/CLS Poly1.43MeemGRxSPCALISFLUILDDRHONHPIRHOBDTxD7Meem19882461.2940.6940.25785Low Solid Mud1.35MeemGRxSPCALISFLUILDxxxDTxD8Meem19881900.8480.930.40163Low Soild Poly1.09MeemGRxSPCALISFLUILDxxxDTxD9Meem xGRxSPCALISFLUILDxxxDTxD10Meem MeemGRTHORSPCALISFLUILDDRHONPHIRHOBDTxD11Meem19901830.7221.130.44782Lignosulfonate1.44xGR editxSPCALISFLUILDxxxDTxD12Meem19901610.8011.260.66293Low Solid Dispers1.25xGRxSPCALISFLUILDxxxDTxD13Meem19911780.5050.9770.41192Low Solid Dis Pol1.16xGRxSPCALISFLUILDxxxDTxD14Meem19921900.6560.9760.4881Chromelignite/CHR1.21xGRxSPCALISFLUILDxxxDTxD15Meem1993 MeemGRxSPCALISFLUILDxxxDTxD16Meem MeemGRxSPCALISFLUILDxxxDTxD17Meem xGRxSPCALISFLUILDxxxDTxD18Meem xGRxSPCALISFLUILDxxxDTxD19Meem xGRxSPCALISFLUILDxxxDTxD21Meem xGRxSPCALISFLUILDDRHONPHIRHOBDTxD22Meem20071750.612 xGRHTHOSPHCALRXO8AT90HDRANPHIRHOZDTCOxD23Meem xGRTHSPCALM21RM2RXZCORCNCZDNCDT24xD24Meem 1.26xGRTH CALM21RM2RXZCORCNCZDENDT24xD26Meem 224 OBM low solids poly1.08xGRxxCALM21RM2RXxxxDT24x



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Nubian Log Data Summary Laterolog tools used for majority of Nubian logging intervals (Newer wells have

induction logs) Neutron, Density, and Sonic data available in most Nubian intervals FMI DLIS data available in the D22 well only

7 wells with core data in Nubian

WellZoneDateBHTRmRmcRmfMud

TempMudDFDCoreGRThSPCaliperRshallowRTDRHONeutronDensityDTDipoleD1Nubian19692970.7561.10.53178Lignosulfate1.22NubianGR editTHORSPCALIMSFLLLDDRHONPHIRHOBDT D2Nubian19703200.820.510.5169Bentonite1.14NubianGRxSPCALIMLLp ILDDRHOp LIPRHOBDTxD3Nubian19712950.090.1360.08662Salty Bent1.17xGRxSPCALIMLLxxLIPxxxD4Nubian1971 Bentonite1.29xGRxSPCALISNILDxxxxxD5Nubian19752800.0621.20.05182Salt Saturated1.28xGRxSPCALIMLLxxxxxxD6Nubian19882920.5060.790.30884Lignosulfate1.19xGRTHORxCALILLSLLDDRHONPHIRHOBDTxD7Nubian19883420.5020.8590.3782Lignosulfonate1.16NubianGRTHOR CALILLSLLDDRHONPHIRHOBDTxD8Nubian19892700.630.590.2876Lignite/Ligosulf1.53xGRTHORxCALIMSFLLLDDRHONPHIRHOBDTxD9Nubian 322 NubianGRxSPCALIMSFLLLDDRHONPHIRHOBDT D10Nubian xGRTHORSPCALIMSFLLLDDRHONPHIRHOBDT D11Nubian19902400.1750.3850.10198Cromellignosulh1.41NubianGR editTHORSPCALILLSLLDxxxDTxD12Nubian1991312 JOF-VERT1.21NubianGRp THORSPCALISFLUILDp DRHOp NPHIp RHOBDTxD13Nubian19912780.530.5650.38378Lignosulphonate1.2xGRTHORSPCALILLSLLDDRHONPHIRHOBDTxD14Nubian19933010.9490.7150.67272Lignosulphonate1.04NubianGRTHORSPCALIMSFLLLDDRHONPHIRHOBDTxD15Nubian1993303 xGRTHORxCALIILMILDDRHONPHIRHOBDTxD16Nubian xxTHORxCALIxxDRHONPHIRHOBDT D17Nubian xGRxSPCALILLSLLDDRHONPHIRHOBDTxD18Nubian xGRTHORSPCALILLsLLDxxxDTxD19Nubian xGRTHORSPCALILLSLLDDRHONPHIRHOBxxD21Nubian xGRTHORxCALILLSLLDDRHONPHIRHOBDTxD22Nubian 2650.6220.7510.50173Low Solid Poly 8547ppmxGRHTHOSPHCALRXO8AT90HDRAHNPORHOZDTCOMSIPD23Nubian 2590.4640.5710.55380L.S.P 12,000mg/l1.02xGRxxCALM21RM2RXZCORCNCZDNCDT24xD24Nubian20092690.5180.7210.368430,000ppm1.26xGRTH CALM21RM2RXZCORCNCZDENDT24x

D26Nubian 2930.3060.4140.32388Air Beads, 79% Water 3000 mg/l0.93xGRTH CALM21RM2RXZCORCNCRHOBDT24x



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Table below outlines additional data provided for Nubian wells

New digital data in May 2015x = not in datasetData identified in well reports - not found in dataset

Well Zone Core GR Th SP Caliper Rshallow RT DRHO Neutron N Matrix Density DT Dipole StonleyImage LogNotesA1 Nubian x GR THOR SP HCAL RXOZ LLD x NPHI LIME RHOZ DT D1 Nubian Nubian GR edit THOR SP CALI MSFL LLD DRHO NPHI LIME RHOB DT x FIL? Core Fracture StudyD2 Nubian Nubian GR x SP CALI MLL p ILD DRHO p LIP LIME/SNP RHOB DT x Dipmeter tif Mention of core poro of up to 14% and perm 56mD D3 Nubian x GR x SP CALI MLL x x LIP LIME/SNP x x x Dipmeter tifD3A Nubian x GR x x x x x x x x DT xD4 Nubian x GR x SP CALI SN ILD x x LIME/SNP x DT x Dipmeter tifD-N from 9400 to 10200D5 Nubian x GR x SP CALI MLL x x x x DT x Dipmeter tifD6 Nubian x GR THOR x CALI LLS LLD DRHO NPHI SAND RHOB DT x Dipmeter tifImage tifsD7 Nubian Nubian GR THOR CALI LLS LLD DRHO NPHI RHOB DT x Dipmeter tifD8 Nubian x GR THOR x CALI MSFL LLD DRHO NPHI RHOB DT xD9 Nubian Nubian GR x SP CALI MSFL LLD DRHO NPHI RHOB DT x FMS?D10 Nubian x GR THOR SP CALI MSFL LLD DRHO NPHI SAND RHOB DT x CNL no bowspringD11 Nubian Nubian GR edit THOR SP CALI LLS LLD x x x DT x FMS?D12 Nubian Nubian GR p THOR SP CALI SFLU ILD p DRHO p NPHI p RHOB DT xD13 Nubian x GR THOR SP CALI LLS LLD DRHO NPHI RHOB DT x Thorium curve reading too high. Top of Nubian missed by D-N?D14 Nubian Nubian GR THOR SP CALi MSFL LLD DRHO NPHI RHOB DT x FMS?D15 Nubian x GR THOR x CALI ILM ILD DRHO NPHI RHOB DT xD16 Nubian x x THOR x CALI x x DRHO NPHI RHOB DT xD17 Nubian x GR x SP CALI LLS LLD DRHO NPHI RHOB DT x FMS?D18 Nubian x GR THOR SP CALI LLs LLD x x x DT x FMS?D19 Nubian x GR THOR SP CALI LLS LLD DRHO NPHI SAND RHOB x x FMS?D20 Nubian x GR THOR SP CALI MSFL LLD DRHO NPHI RHOB DT xD21 Nubian x GR THOR x CALI LLS LLD DRHO NPHI LIME RHOB DT x xD22 Nubian x GR HTHO SP HCAL RXO8 AT90 HDRA HNPO LIME RHOZ DTCO MSIP FMI FMI run: 11212 to 12118ft Rm=0.19ohmm at 265F, 8.7ppg.D23 Nubian x GR x x CAL M21R M2RX ZCOR CNC ZDNC DT24 x x XMAC run but no dipole in datasetD24 Nubian x GR TH CAL M21R M2RX ZCOR CNC ZDEN DT24 x x XMAC run but no dipole in datasetD26 Nubian x GR TH CAL M21R M2RX ZCOR CNC RHOB DT24 x STAR STAR image in top 100ft only - pdf to 12k ft, XMAC run but no dipole in datasetK1 Nubian Nubian DRHO NPHI RHOB x



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PetrophysicsPetrophysicsData Quality and NormalizationData Quality and Normalization

Calibration and log data quality were analyzed Calibration information was checked when available



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Data acquisition parameters were verified and noted Corrections to neutron matrix made when necessary

All Neutron porosity curves used in evaluation were set to Limestone matrix Most of the provided data already in Limestone matrix Neutron porosity provided Sandstone matrix were recalculated to Limestone

D6 D9 D19

This was evaluated by reading the data acquisition parameters in the log headers and by confirming the actual matrix by the logging tool responses.



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Curves were analyzed for anomalous response indication possible need to normalize Density curves in the Nubian are shown here as logged

Several wells were identified as benefiting from normalization

D24

D9



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Density curves normalized



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Neutron tools corrected for lithology

D10

D13

D14D9

D8



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Neutron tools normalized



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Spectral gamma ray data was seen to have good distribution



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Thorium distribution



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PetrophysicsPetrophysicsInitial CalculationsInitial Calculations

Formation Temperature Calculation

Bottom hole temperatures from logging tool measurements

Adjusted for circulation times taken from log headers

Formation temperature gradient of 0.04 C/m



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Washouts flagged when caliper measures 1 inch over bit size



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Density Correction flagged when less than -0.1 g/cc and greater than 0.1 g/cc



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PetrophysicsPetrophysicsShale VolumeShale Volume

Shale Volume Calculation Shale volume was calculated using the minimum of the linear

index of three shale indicators when available: Gamma ray Apparent matrix density from neutron-density crossplot Thorium from the spectral gamma ray

Only gamma ray measurements were used when poor density pad contact indicated

Shale volumes compared to image log data, core description and mud logs when available

More accurate clay typing could be achieved with the use of geochemical logging



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PetrophysicsPetrophysicsPorosityPorosity

Porosity Calculation - Meem Porosity was calculated using both compressional sonic and

neutron-density data Compressional sonic data available in all Meem penetrations Neutron-density data available in 7 wells (Density data in 10

wells) Sonic porosity calculated using Wyllie time average (47.6 us/ft

in Meem) Neutron-density crossplot porosity was calculated using

neutron curves in a limestone matrix and bulk density (fluid density of 1.0 g/cc) and corrected for hydrocarbon effects.

Generally, both porosity calculations produced similar results and compared favorably to core measurements



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Porosity Calculation - Meem Generally, both porosity calculations produced similar results D6



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Porosity Calculation - Meem Generally, both porosity calculations produced similar results D10



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Porosity Calculation - Meem Generally, both porosity calculations produced similar results

and compared favorably to core measurements.



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Porosity Calculation

Nubian Porosity was calculated using compressional sonic and

neutron-density data Sonic porosity calculated using Wyllie time average (52 us/ft in

Nubian) Neutron-density crossplot porosity was calculated using

neutron curves in a limestone matrix and bulk density (fluid density of 1.0 g/cc).

Neutron-Density porosity was used expect in cases of identified bad hole



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Nubian Porosity Calculation D2



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Nubian Porosity Calculation



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Core Porosity Where core points were judged to be acceptable they served to

validate the porosity calculations from the logging tool data. Overburden corrections were not made due to the absence of

laboratory pressure testing information. Individual core points that were judged to be acceptable were

compared against log calculated porosity on each log plot.



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Core Porosity vs Log Calculated Porosity – NubianBest fit regression when very high and low core points are not considered



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Core Porosity vs Log Calculated Porosity – MeemBest fit regression when very high and low core points are not considered



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PetrophysicsPetrophysicsWater SaturationWater Saturation

Water Saturation Calculation

Water saturation was calculated using the Indonesian equation Formation water resistivity of 0.03 ohm.m Cementation exponent of 2 Saturation exponent of 2 Tortuosity of 1



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Several different approaches used in the estimation of connate water resistivity Salinity estimated from water from test information:

100kppm Cl concentration in D6 well Separate Rw estimates considered from service company work:

Special core analysis study on analogous Nubian Rw calculated range of 0.034 to 0.041 ohm.m

Pickett plot analysis



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Pickett Plot in Meem Color represents individual wells



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Pickett Plot in Nubian Color represents individual wells



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Pickett Plot in Lower Nubian Color represents shale volume



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Pickett Plot in Nubian Shale Marker Color represents shale volume



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Meem - Water Saturation vs Porosity

IndonesianModified Simandoux



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Nubian - Water Saturation vs Porosity


Indonesian Modified Simandoux



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Shale conductivity correction was identified to be necessary in both Meem and Nubian reservoirs. Dual Water and Waxman Smits methods were not considered primarily due to the absence of reliably measured CEC and electrical property information.

Indonesian and Modified Simandoux methods were both considered. In the Meem reservoir, although clay correction was identified as needed, neither the

Indonesian nor the Modified Simandoux methods produced significantly different results.

However, in the Nubian reservoir the Modified Simandoux method was observed to under estimate water saturation in low porosity. The Indonesian equation was able to calculate more consistent and reasonable water saturations throughout the porosity ranges seen in the Nubian reservoir.

Special core analysis could improve the water saturation equation results.




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PetrophysicsPetrophysicsPermeabilityPermeability

The significant scatter of the core permeability data did not allow for a meaningful regression analysis to be made

Core permeability data was used to bound the log calculated perm only Permeability was calculated with a Coates-Timur equation, using calculated reservoir

parameters Meem reservoir: Perm = 600 * PHIE^4 * ((1-0.15)/0.15)^2 Nubian reservoir: Perm = 2000 * PHIE^4 * ((PHIT-PHIE*0.1)/(PHIE*0.1))^2

Irreducible water values were chosen based on lowest calculated water saturations in each reservoir in the upper portions of the oil columns.

Klinkenburg effects were not estimated due to the sparse core data available.

In general, the core data was used to verify the porosity calculations made using the log data and to give permeability ranges for permeability calculation.



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Entire dataset of Core Porosity and Core Permeability Colors represent different reservoir intervals



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Meem Core Porosity and Core Permeability

Colors represent wells with core data



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Nubian Core Porosity and Core Permeability

Colors represent wells with core data



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PetrophysicsPetrophysicsCutoffsCutoffs

Production and test data in conjunction with porosity-permeability relationships were considered in the determination of cutoffs. In this case, the porosity-perm data from the core had significant scatter and were not straightforward in determining cutoff relationships.

Vsh 40%Phie 5%Swe 65%

Ney pay from cutoffs identify reservoir matrix contributing to production Contribution of fractured reservoir in lower range of porosity was not included in the

matrix portion of the petrophysical evaluation.



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Summary and ConclusionSummary and ConclusionA preliminary petrophysical analysis was performed.A preliminary petrophysical analysis was performed.

Completed a preliminary analysis of matrix properties (volume of shale, porosity, permeability, and water saturation)

Review FMI logs received last week



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