Drill Cuttings Analysis: How to Determine the Geology of a Formation and Reservoir

Drill Cuttings Analysis: How to Determine the Geology of a Formation and Reservoir Chuck Stringer ASA Manager Southern Region 2015 TECH MKT_2014-BD-REG-1673 1

The one item that has lacked serious consideration in the characterization of a vertical and lateral boreholes, are the drill cuttings. All wireline responses are dictated by the mineralogy/lithology and the fluids contained within them. At ASA we log and define the borehole and reservoir through analyzing the drill cuttings and core by three separate analytical methods. 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 2

Our three analytical methods: X-Ray Fluorescence (XRF- Chemostratigraphy) ChemoGR for drill cuttings location along a lateral well bore Trace elements for geologic correlation Total Organic Carbon (TOC) proxies Drilling hazards Fault Analysis Scanning Electron Microscope/QEMSCAN Digital imaging and analysis of: Mineralogy Rock Structure Lithology Porosity Density Pyrolysis S1 producible hydrocarbon S2 Kerogen - non producible hydrocarbon TOC - total organic hydrocarbon Tmax - Maximum temperature indicates oil maturity Carbonate Carbon 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 3

ChemoGR - Know where the cuttings came from ] ChemoGR is calculated from Potassium (K), Thorium (Th) and Uranium (U) and is measured in ppm (parts per million) It is converted into API equivalent units Application: Can be directly comparable to M/LWD Gamma Ray Lag control: by overlaying the ChemoGR and the Gamma the sample lag can be corrected. 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 4

ChemoGR Lag correction ChemoGR Gamma Lag-Gamma offset Pump Efficiency used in lag was incorrect by 0.002847 feet per foot - a difference of 40 feet by T.D. 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 5

SEM/EDX Core or Cuttings Automated Mineralogy Analysis at Well Site or nearby In-Field Lab Mineralogy Element and mineral, 3000 minerals characterized. Comparable to XRD but greater resolution, (2 million sample). Lithologic Structure Primary and secondary Grain/Cement analysis Porosity Macro-Porosity in unconventional rock Porosity in conventional rock Density Bulk Density Automated Analysis 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 6

High Resolution Mineral Mapping and Porosity: Spatial Relevance Colo rs Mineral Vol% FI 10 Quartz 0.33 K-Feldspar 0.24 Plagioclase 0.06 Calcite 0.02 Dolomite 58.39 Siderite 0.00 Illite 0.40 Smectite 0.00 Kaolinite 0.00 Chlorite 0.00 Muscovite 0.00 Biotite 0.00 Pyrite 0.40 Rutile-Anatase 0.01 Apatite 0.01 Gypsum/Anhyd rite 39.82 Barite 0.00 Celestine 0.00 Infiltration 0.04 Other 0.17 Unclassified 0.08 5um LithoSCAN mineral map of the cuttings particles with individual mineral grains identified by color. In this case Porosity Any feature or mineral can be identified by color and computer washed to show only that subject. 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 8 5um

Pyrolysis S1 oil yield - the amount of thermally freed hydrocarbons (mg/g). S2 kerogen yield - the amount of hydrocarbons generated through pyrolysis of kerogen (mg/g). S3 - the amount of CO2 produced during pyrolysis (300 to 400 C) of kerogen (mg/g). S4 - the amount of residual carbon produced by oxidation after the completion of pyrolysis (mg/g): S4 is a measure of the non-generative organic carbon content of the rock. S5 - CO2 generated during oxidation (550 to 850 C) Tmax - the temperature at which the maximum generation of hydrocarbons from pyrolysis cracking of the kerogen occurs ( C). Absolute Tmax - kinetics analysis Carbonate Carbon (wt. %) - This is a measure of the inorganic carbon content of the rock and is derived from the mineral carbonate component of the rock. TOC - measurement of the Total Organic Carbon content of the rock in weight percent (wt. %). 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 9

Pyrolysis Data Sample ID San Marcos 1H_9510 San Marcos 1H_9600 San Marcos 1H_9690 San Marcos 1H_9770 San Marcos 1H_9860 San Marcos 1H_9950 San Marcos 1H_10040 San Marcos 1H_10130 San Marcos 1H_10220 San Marcos 1H_10310 San Marcos 1H_10400 San Marcos 1H_10490 San Marcos 1H_10580 San Marcos 1H_10610 San Marcos 1H_10640 San Marcos 1H_10670 San Marcos 1H_10760 San Marcos 1H_10790 San Marcos 1H_10820 San Marcos 1H_10850 San Marcos 1H_10940 San Marcos 1H_11030 San Marcos 1H_11120 San Marcos 1H_11210 San Marcos 1H_11300 San Marcos 1H_11390 San Marcos 1H_11720 San Marcos 1H_11840 San Marcos 1H_11930 Well Name S-2 >20.0 10.0-20.0 5.0-10.0 2.5-5.0 <2.0 Depth (ft) 9510 9600 9690 9770 9860 9950 10040 10130 10220 10310 10400 10490 10580 10610 10640 10670 10760 10790 10820 10850 10940 11030 11120 11210 11300 11390 11720 11840 11930 Basin TOC - S1 HI OI Oxygen S2(Total Hydrogen Index S1-Free Oil Kerogen S3 TmaxOrganic PI Production Weight Index (S3/TOC x (mghc/g Yield (mgco2/g Maturity Carbon Index (mg) (S2/TOC x 100) mg rock) (mghc/g rock) ( C) less S1 (S1/(S1+S2)) 100) mg rock) (Free Oil)) CO2/g TOC HC/g TOC (wt. %) 69.6 11.24 10.1 0.77 439 4.16 0.53 197 15 70.8 13.09 15.9 0.81 438 5.65 0.45 235 12 69.2 34.18 21.4 0.47 442 5.33 0.62 259 5 70.2 13.99 16.3 0.83 438 5.22 0.46 253 12 69.7 18.26 15.4 0.55 439 4.23 0.54 266 9 70.8 4.18 7.5 1.58 438 4.84 0.36 144 30 70.4 27.32 16.3 0.59 440 4.28 0.63 246 8 69.1 6.88 9.8 0.97 438 4.35 0.41 197 19 69.7 4.59 5.9 1.48 439 3.96 0.44 134 33 69.8 25.83 11.2 0.53 440 2.75 0.70 226 10 70.3 52.12 16.0 0.54 442 3.57 0.77 200 6 70.8 32.1 22.2 0.66 441 6.05 0.59 252 7 70.3 6.13 11.2 0.78 438 4.48 0.35 224 15 69.4 1.82 3.7 1.23 436 3.93 0.33 89 30 70.1 6.1 10.2 0.97 438 4.31 0.38 210 20 70.7 1.73 2.6 1.23 439 4.01 0.4 61 29 70 29.84 23.9 0.8 440 5.79 0.55 287 9 70.5 10.4 17.5 0.78 438 6.04 0.37 252 11 70.4 3.07 6.2 0.72 438 2.77 0.33 203 23 69.9 11.39 10.0 0.49 440 2.97 0.53 254 12 70.6 1.52 3.7 1.22 436 3.14 0.29 112 37 70.4 3 4.9 1.03 438 3.34 0.38 135 28 70.4 12.32 11.5 0.85 439 3.7 0.52 241 17 70.4 16.38 15.3 0.6 440 3.9 0.52 289 11 69.6 42.34 15.8 0.62 443 3.58 0.73 219 8 69.4 5.19 4.4 1.04 437 2.91 0.54 130 30 70.1 22.83 11.1 0.46 443 3.22 0.67 215 8 70.5 33.15 21.1 0.48 442 5.24 0.61 261 5 69.8 2.08 2.0 1.56 439 3.17 0.51 60 46 Excellent Generative Potential Very Good generative potential Good generative potential Fair Good generative potential Poor generative potential 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 T MAX <430 430-455 <456-475 >475 2015 TECH MKT_201-BDREG-1673 TOC Immature <0.5 oil window 0.5-1.0 condensate 1.0-2.0 dry gas >2.0 10 HI vs OI Poor Organic Carbon Content Fair hydrocarbon source potental Good hydrocarbon source potental Very Good hydrocarbon source potental Modified Van Krevelen Type II Oil Type II Oil and Gas Type II Gas Type III Gas Prone Type IV Low Potential

ASA Putting it together Identify Mineralogy, porosity and hydrocarbon sweet spots Identify potential drilling and production impediments such a ductile beds 2015 TECH MKT_2014-BD-REG-1673 11

Integration of the three analytical systems ChemoGR (chemically derived gamma) and data corrected to the wireline Gamma Ray SEM Mineralogy Silica Silica clay Clay Calcite Kerogen Producible hydrocarbon TOC Wireline Porosity SEM +5um Porosity Calcite Silica K/Rb Spectral Gamma Wireline Gamma ChemoGR 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 13

Log the lateral Development Log, spectral gamma(xrf), Pyrolysis proxies(xrf), Pyrolysis(Hawk), Mineralogy(SEM), RBI SEM, Poisson Ratio, Young s Modulus, Mud Gases, ROP Develop fines logs that locate those beds that will produce fines when fracked Determine those minerals that will be susceptible to acids and the amount of fines that will be developed from that action Frac Fluid reactivity to mineralogy Major and minor elements for stratigraphic correlation Data into FracInsight 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 14

Slide 15 Eagle Ford Example SPE 158846 Clay rich rock, low RBI, Low EFV, = higher WHTP (Well Head Treatment Pressure), Small Fractures and Lower Production A near-wellbore choke is caused by narrow width and tortuous fractures in clay-rich rock SPE 132990 Frac Stage # => S17 S16 S15 S14 S13 S12 S11 S10 S9 S8 S7 S6 S5 S4 S3 S2 S1 WHTP Green = Ductile RBI:Relative Brittleness Index Red = Brittle EFV % Clay In the beginning there was Gamma and it was good SPE 158846 GR GR SPE 158846 Variation of Average WHTP 4000 3500 SPE 158846 16 2500 2000 1500 1000 500 Average WHTP Differential - PSI More micro seismic = better Low Gamma = Brittle = Good Production Frac Stage And now the rest of the story 3000 14 12 10 8 6 4 2 0 17 16 15 14 13 12 11 10 9 8 7 Frac Stage EAR 99 2015 HALLIBURTON. ALL RIGHTS RESERVED. 6 5 4 3 2 0 1 2015 TECH MKT_201-BDREG-1673 18 15 17 16 15 14 13 12 11 10 9 8 Stage # 7 6 5 4 3 2 1 Relative % of Production Flow (%) Higher Average WHTP s SPE 158846 due to lateral outside of intended target interval 20 Well #1H

Data Developed by ASA is downloaded in the FracInsight 2015 TECH MKT_2014-BD-REG-1673 16

SM What is the FracInsight Service? An unbiased repeatable tool to select perforations and frac stage locations from the best available formation evaluation data along a horizontal well. 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 17

SM Marcellus ASA Horizontal FracInsight SPE 170908 Service SEM-EDX Mineralogy & Porosity NO XRF Modeled Mineralogy Vertical Well Projected Data 2015 HALLIBURTON. ALL RIGHTS RESERVED. EAR 99 2015 TECH MKT_201-BDREG-1673 18 Rig Time Required