## SandRidge Energy WRS 71 -5 No. 19a – Frac Service Company

Stage s 1 , 2, 3 & 4 Superior Stages 5, 6 & 7 Halliburton

## SandRidge Energy WRS 71 -5 No. 9 - Pressure Test of Casing

12.9 .09 WellView Field Report says: Tst csg to 4800#; ok.

## TRUE 1 1.1 Float Shoe Casing sho e 7 26 P

‐ 110 6.276 TRUE 2 38.01 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 3 1.25 Float colla r Casing (bla 7 26 P

‐ 110 6.276
TRUE 4 37.02 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 5 36.7 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 6 37.73 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 7 37.19 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 8 37.9 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 9 37.33 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 10 37.13 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 11 36.81 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 12 36.86 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 13 38.29 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 14 38 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 15 37.01 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 16 38.61 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 17 37.16 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 18 37.62 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 19 36.42 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 20 37.5 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 21 36.84 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 22 37.3 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 23 36.94 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 24 38.46 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 25 37.07 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 26 37.18 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 27 37.97 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 28 37.71 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 29 37.08 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 30 37.22 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 31 38.21 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 32 37.21 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 33 35.86 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 34 37.11 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 35 37.66 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 36 37.35 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 37 37.01 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 38 36.35 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 39 36.75 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 40 38.4 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 41 35.34 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 42 36.32 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 43 38.02 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 44 37.05 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 45 36.34 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 46 37.95 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276
TRUE 47 37.65 Casing

‐ Joi n Casing (bla 7 26 P

‐ 110 6.276

## TRUE 48 39.28 Casing

‐ Joi n Casing (bla 7 26 N

‐ 80 6.276
TRUE 49 37.36 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 50 37.25 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 51 36.27 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 52 36.18 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 53 36.28 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 54 38.29 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 55 37.76 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 56 38.2 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 57 38.12 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 58 37.74 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 59 38.02 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 60 37.08 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 61 38.49 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 62 36.66 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276 TRUE 63 38.65 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 64 38.03 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 65 36.76 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 66 36.95 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 67 37.72 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 68 38.02 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 69 37.92 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 70 35.81 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 71 34.23 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 72 36.39 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 73 38 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 74 37.11 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 75 37.02 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 76 37.03 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 77 38.08 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 78 37.55 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 79 36.88 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 80 36.81 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 81 36.6 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 82 38.06 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 83 37.92 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 84 37.65 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 85 37.21 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 86 38.43 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 87 37.68 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 88 37.85 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 89 37.39 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 90 38.36 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 91 36.02 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276 TRUE 92 35.92 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 93 38.14 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 94 38.32 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276

## TRUE 95 37.5 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 96 3.6 D

‐ V tool Casing (bla 7 26 P

‐ 110 6.276
TRUE 97 38.46 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 98 38.32 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 99 37.95 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 100 37.66 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 101 38.61 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 102 38.76 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 103 37.19 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 104 37.98 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 105 38.39 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 106 37.55 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 107 36.56 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 108 38.39 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 109 38.19 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 110 37.78 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 111 36.97 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 112 37.56 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 113 35.52 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 114 37.54 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 115 36.88 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 116 37.39 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 117 36.83 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 118 38.61 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 119 37.21 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 120 36.54 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 121 37.86 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 122 36.63 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 123 37.41 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276 TRUE 124 37.79 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 125 38.47 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 126 38.32 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 127 37.08 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 128 38.39 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 129 37.92 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 130 38.51 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 131 37.67 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 132 37.95 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 133 38.48 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 134 37.21 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 135 37.12 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 136 37.65 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 137 38.42 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 138 38.32 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 139 37.88 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 140 37.12 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 141 38.67 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276

## TRUE 142 37.05 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 143 38.21 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 144 38 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 145 37.42 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 146 35.9 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 147 36.3 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 148 38.19 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 149 37.36 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 150 38.55 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 151 38.71 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 152 35.72 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 153 36.34 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 154 37.19 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 155 38.34 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 156 37.82 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 157 38.35 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 158 36.09 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 159 37.49 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 160 37.72 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 161 37.3 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 162 37.33 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 163 37.52 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 164 36.88 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 165 37.94 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 166 36.91 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 167 37.39 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 168 36.33 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 169 38.36 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 170 37.11 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 171 37.93 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 172 38.17 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 173 37.89 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 174 38.41 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 175 36.67 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 176 38.32 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 177 36.72 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 178 38.12 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 179 37.57 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 180 37.1 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 181 38.32 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 182 37.54 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 183 38.18 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 184 36.43 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 185 37.68 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 186 36.55 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 187 37.24 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 188 38.05 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276

## TRUE 189 37.19 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 190 37.29 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 191 37.53 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 192 36.6 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 193 37.74 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 194 37 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 195 37.42 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 196 36.47 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 197 38.01 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 198 36.53 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 199 38.27 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 200 37.37 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 201 37.17 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 202 37.04 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 203 36.3 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 204 38.68 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 205 37.25 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 206 37.61 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 207 38.48 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 208 38.1 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 209 37.94 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 210 37.05 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 211 37.27 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 212 37.17 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 213 38.01 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 214 38.02 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 215 36.1 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 216 37.2 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 217 36.43 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 218 36.3 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 219 38.64 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 220 38.51 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 221 38.09 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 222 38.38 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 223 37.25 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 224 37.8 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 225 37.61 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 226 38.19 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 227 37.8 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 228 37.84 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
FALSE 33.35 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 229 38.44 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 230 36.49 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 231 37.61 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 232 36.7 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 233 38.31 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 234 37.16 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276

## TRUE 235 36.26 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 236 36.98 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 237 38.18 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 238 38.3 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 239 37.46 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
TRUE 240 38.13 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
FALSE 37.37 Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276
FALSE Casing

‐ join Casing (bla 7 26 P

‐ 110 6.276

## Casing LT&C FALSE 1.1 8,881.90 8,883.00 0 0 Casing LT&C TRUE 39.11 8,843.90 8,881.90 0.4 1 Casing LT&C FALSE 40.36 8,842.60 8,843.90 0.4 1 Casing LT&C FALSE 77.38 8,805.60 8,842.60 0.7 2 Casing LT&C FALSE 114.08 8,768.90 8,805.60 1.1 3 Casing LT&C FALSE 151.81 8,731.20 8,768.90 1.4 3.9 Casing LT&C FALSE 189 8,694.00 8,731.20 1.8 4.9 Casing LT&C FALSE 226.9 8,656.10 8,694.00 2.1 5.9 Casing LT&C FALSE 264.23 8,618.80 8,656.10 2.5 6.9 Casing LT&C FALSE 301.36 8,581.60 8,618.80 2.8 7.8 Casing LT&C FALSE 338.17 8,544.80 8,581.60 3.2 8.8 Casing LT&C TRUE 375.03 8,508.00 8,544.80 3.5 9.8 Casing LT&C FALSE 413.32 8,469.70 8,508.00 3.9 10.7 Casing LT&C FALSE 451.32 8,431.70 8,469.70 4.2 11.7 Casing LT&C FALSE 488.33 8,394.70 8,431.70 4.6 12.7 Casing LT&C FALSE 526.94 8,356.10 8,394.70 4.9 13.7 Casing LT&C FALSE 564.1 8,318.90 8,356.10 5.3 14.7 Casing LT&C FALSE 601.72 8,281.30 8,318.90 5.6 15.7 Casing LT&C FALSE 638.14 8,244.90 8,281.30 6 16.6 Casing LT&C FALSE 675.64 8,207.40 8,244.90 6.3 17.6 Casing LT&C FALSE 712.48 8,170.50 8,207.40 6.7 18.5 Casing LT&C FALSE 749.78 8,133.20 8,170.50 7 19.5 Casing LT&C TRUE 786.72 8,096.30 8,133.20 7.3 20.5 Casing LT&C FALSE 825.18 8,057.80 8,096.30 7.7 21.5 Casing LT&C FALSE 862.25 8,020.80 8,057.80 8.1 22.4 Casing LT&C FALSE 899.43 7,983.60 8,020.80 8.4 23.4 Casing LT&C FALSE 937.4 7,945.60 7,983.60 8.8 24.4 Casing LT&C TRUE 975.11 7,907.90 7,945.60 9.1 25.4 Casing LT&C FALSE 1,012.19 7,870.80 7,907.90 9.5 26.3 Casing LT&C FALSE 1,049.41 7,833.60 7,870.80 9.8 27.3 Casing LT&C FALSE 1,087.62 7,795.40 7,833.60 10.2 28.3 Casing LT&C FALSE 1,124.83 7,758.20 7,795.40 10.5 29.3 Casing LT&C FALSE 1,160.69 7,722.30 7,758.20 10.8 30.2 Casing LT&C TRUE 1,197.80 7,685.20 7,722.30 11.2 31.2 Casing LT&C FALSE 1,235.46 7,647.50 7,685.20 11.5 32.1 Casing LT&C FALSE 1,272.81 7,610.20 7,647.50 11.9 33.1 Casing LT&C FALSE 1,309.82 7,573.20 7,610.20 12.2 34.1 Casing LT&C FALSE 1,346.17 7,536.80 7,573.20 12.6 35 Casing LT&C FALSE 1,382.92 7,500.10 7,536.80 12.9 36 Casing LT&C FALSE 1,421.32 7,461.70 7,500.10 13.3 37 Casing LT&C FALSE 1,456.66 7,426.30 7,461.70 13.6 37.9 Casing LT&C FALSE 1,492.98 7,390.00 7,426.30 13.9 38.8 Casing LT&C FALSE 1,531.00 7,352.00 7,390.00 14.3 39.8 Casing LT&C FALSE 1,568.05 7,315.00 7,352.00 14.6 40.8 Casing LT&C FALSE 1,604.39 7,278.60 7,315.00 15 41.7 Casing LT&C FALSE 1,642.34 7,240.70 7,278.60 15.3 42.7 Casing LT&C FALSE 1,679.99 7,203.00 7,240.70 15.7 43.7

## Casing LT&C FALSE 1,719.27 7,163.70 7,203.00 16.1 44.7 Casing LT&C FALSE 1,756.63 7,126.40 7,163.70 16.4 45.7 Casing LT&C FALSE 1,793.88 7,089.10 7,126.40 16.7 46.7 Casing LT&C FALSE 1,830.15 7,052.90 7,089.10 17.1 47.6 Casing LT&C FALSE 1,866.33 7,016.70 7,052.90 17.4 48.5 Casing LT&C FALSE 1,902.61 6,980.40 7,016.70 17.8 49.5 Casing LT&C FALSE 1,940.90 6,942.10 6,980.40 18.1 50.5 Casing LT&C FALSE 1,978.66 6,904.30 6,942.10 18.5 51.5 Casing LT&C FALSE 2,016.86 6,866.10 6,904.30 18.8 52.5 Casing LT&C FALSE 2,054.98 6,828.00 6,866.10 19.2 53.4 Casing LT&C FALSE 2,092.72 6,790.30 6,828.00 19.5 54.4 Casing LT&C FALSE 2,130.74 6,752.30 6,790.30 19.9 55.4 Casing LT&C FALSE 2,167.82 6,715.20 6,752.30 20.2 56.4 Casing LT&C FALSE 2,206.31 6,676.70 6,715.20 20.6 57.4 Casing LT&C FALSE 2,242.97 6,640.00 6,676.70 20.9 58.3 Casing LT&C FALSE 2,281.62 6,601.40 6,640.00 21.3 59.3 Casing LT&C FALSE 2,319.65 6,563.40 6,601.40 21.7 60.3 Casing LT&C FALSE 2,356.41 6,526.60 6,563.40 22 61.3 Casing LT&C FALSE 2,393.36 6,489.60 6,526.60 22.3 62.2 Casing LT&C FALSE 2,431.08 6,451.90 6,489.60 22.7 63.2 Casing LT&C FALSE 2,469.10 6,413.90 6,451.90 23.1 64.2 Casing LT&C FALSE 2,507.02 6,376.00 6,413.90 23.4 65.2 Casing LT&C FALSE 2,542.83 6,340.20 6,376.00 23.7 66.1 Casing LT&C FALSE 2,577.06 6,305.90 6,340.20 24.1 67 Casing LT&C FALSE 2,613.45 6,269.60 6,305.90 24.4 68 Casing LT&C FALSE 2,651.45 6,231.60 6,269.60 24.8 69 Casing LT&C FALSE 2,688.56 6,194.40 6,231.60 25.1 69.9 Casing LT&C FALSE 2,725.58 6,157.40 6,194.40 25.4 70.9 Casing LT&C FALSE 2,762.61 6,120.40 6,157.40 25.8 71.9 Casing LT&C FALSE 2,800.69 6,082.30 6,120.40 26.2 72.8 Casing LT&C FALSE 2,838.24 6,044.80 6,082.30 26.5 73.8 Casing LT&C FALSE 2,875.12 6,007.90 6,044.80 26.8 74.8 Casing LT&C FALSE 2,911.93 5,971.10 6,007.90 27.2 75.7 Casing LT&C FALSE 2,948.53 5,934.50 5,971.10 27.5 76.7 Casing LT&C FALSE 2,986.59 5,896.40 5,934.50 27.9 77.7 Casing LT&C FALSE 3,024.51 5,858.50 5,896.40 28.2 78.7 Casing LT&C FALSE 3,062.16 5,820.80 5,858.50 28.6 79.6 Casing LT&C FALSE 3,099.37 5,783.60 5,820.80 28.9 80.6 Casing LT&C FALSE 3,137.80 5,745.20 5,783.60 29.3 81.6 Casing LT&C FALSE 3,175.48 5,707.50 5,745.20 29.7 82.6 Casing LT&C FALSE 3,213.33 5,669.70 5,707.50 30 83.6 Casing LT&C FALSE 3,250.72 5,632.30 5,669.70 30.4 84.5 Casing LT&C FALSE 3,289.08 5,593.90 5,632.30 30.7 85.5 Casing LT&C FALSE 3,325.10 5,557.90 5,593.90 31 86.5 Casing LT&C FALSE 3,361.02 5,522.00 5,557.90 31.4 87.4 Casing LT&C FALSE 3,399.16 5,483.80 5,522.00 31.7 88.4 Casing LT&C FALSE 3,437.48 5,445.50 5,483.80 32.1 89.4

## Casing LT&C TRUE 3,474.98 5,408.00 5,445.50 32.4 90.4 Casing LT&C FALSE 3,478.58 5,404.40 5,408.00 32.5 90.5 Casing LT&C TRUE 3,517.04 5,366.00 5,404.40 32.8 91.5 Casing LT&C FALSE 3,555.36 5,327.60 5,366.00 33.2 92.5 Casing LT&C FALSE 3,593.31 5,289.70 5,327.60 33.6 93.5 Casing LT&C FALSE 3,630.97 5,252.00 5,289.70 33.9 94.4 Casing LT&C TRUE 3,669.58 5,213.40 5,252.00 34.3 95.4 Casing LT&C FALSE 3,708.34 5,174.70 5,213.40 34.6 96.4 Casing LT&C FALSE 3,745.53 5,137.50 5,174.70 35 97.4 Casing LT&C FALSE 3,783.51 5,099.50 5,137.50 35.3 98.4 Casing LT&C FALSE 3,821.90 5,061.10 5,099.50 35.7 99.4 Casing LT&C FALSE 3,859.45 5,023.60 5,061.10 36 100.4 Casing LT&C FALSE 3,896.01 4,987.00 5,023.60 36.4 101.3 Casing LT&C FALSE 3,934.40 4,948.60 4,987.00 36.7 102.3 Casing LT&C FALSE 3,972.59 4,910.40 4,948.60 37.1 103.3 Casing LT&C FALSE 4,010.37 4,872.60 4,910.40 37.4 104.3 Casing LT&C FALSE 4,047.34 4,835.70 4,872.60 37.8 105.3 Casing LT&C TRUE 4,084.90 4,798.10 4,835.70 38.1 106.2 Casing LT&C FALSE 4,120.42 4,762.60 4,798.10 38.5 107.2 Casing LT&C FALSE 4,157.96 4,725.00 4,762.60 38.8 108.1 Casing LT&C FALSE 4,194.84 4,688.20 4,725.00 39.2 109.1 Casing LT&C FALSE 4,232.23 4,650.80 4,688.20 39.5 110.1 Casing LT&C FALSE 4,269.06 4,613.90 4,650.80 39.9 111 Casing LT&C FALSE 4,307.67 4,575.30 4,613.90 40.2 112 Casing LT&C FALSE 4,344.88 4,538.10 4,575.30 40.6 113 Casing LT&C FALSE 4,381.42 4,501.60 4,538.10 40.9 114 Casing LT&C FALSE 4,419.28 4,463.70 4,501.60 41.3 114.9 Casing LT&C FALSE 4,455.91 4,427.10 4,463.70 41.6 115.9 Casing LT&C TRUE 4,493.32 4,389.70 4,427.10 42 116.9 Casing LT&C FALSE 4,531.11 4,351.90 4,389.70 42.3 117.8 Casing LT&C FALSE 4,569.58 4,313.40 4,351.90 42.7 118.8 Casing LT&C FALSE 4,607.90 4,275.10 4,313.40 43 119.8 Casing LT&C FALSE 4,644.98 4,238.00 4,275.10 43.4 120.8 Casing LT&C FALSE 4,683.37 4,199.60 4,238.00 43.7 121.8 Casing LT&C FALSE 4,721.29 4,161.70 4,199.60 44.1 122.8 Casing LT&C FALSE 4,759.80 4,123.20 4,161.70 44.4 123.8 Casing LT&C FALSE 4,797.47 4,085.50 4,123.20 44.8 124.8 Casing LT&C FALSE 4,835.42 4,047.60 4,085.50 45.1 125.8 Casing LT&C TRUE 4,873.90 4,009.10 4,047.60 45.5 126.8 Casing LT&C FALSE 4,911.11 3,971.90 4,009.10 45.9 127.7 Casing LT&C FALSE 4,948.23 3,934.80 3,971.90 46.2 128.7 Casing LT&C FALSE 4,985.88 3,897.10 3,934.80 46.6 129.7 Casing LT&C FALSE 5,024.30 3,858.70 3,897.10 46.9 130.7 Casing LT&C FALSE 5,062.62 3,820.40 3,858.70 47.3 131.7 Casing LT&C FALSE 5,100.50 3,782.50 3,820.40 47.6 132.7 Casing LT&C FALSE 5,137.62 3,745.40 3,782.50 48 133.6 Casing LT&C FALSE 5,176.29 3,706.70 3,745.40 48.3 134.6

## Casing LT&C FALSE 5,213.34 3,669.70 3,706.70 48.7 135.6 Casing LT&C FALSE 5,251.55 3,631.50 3,669.70 49 136.6 Casing LT&C TRUE 5,289.55 3,593.50 3,631.50 49.4 137.6 Casing LT&C FALSE 5,326.97 3,556.00 3,593.50 49.7 138.5 Casing LT&C FALSE 5,362.87 3,520.10 3,556.00 50.1 139.5 Casing LT&C FALSE 5,399.17 3,483.80 3,520.10 50.4 140.4 Casing LT&C FALSE 5,437.36 3,445.60 3,483.80 50.8 141.4 Casing LT&C FALSE 5,474.72 3,408.30 3,445.60 51.1 142.4 Casing LT&C FALSE 5,513.27 3,369.70 3,408.30 51.5 143.4 Casing LT&C FALSE 5,551.98 3,331.00 3,369.70 51.8 144.4 Casing LT&C TRUE 5,587.70 3,295.30 3,331.00 52.2 145.3 Casing LT&C FALSE 5,624.04 3,259.00 3,295.30 52.5 146.3 Casing LT&C FALSE 5,661.23 3,221.80 3,259.00 52.9 147.2 Casing LT&C FALSE 5,699.57 3,183.40 3,221.80 53.2 148.2 Casing LT&C FALSE 5,737.39 3,145.60 3,183.40 53.6 149.2 Casing LT&C FALSE 5,775.74 3,107.30 3,145.60 53.9 150.2 Casing LT&C FALSE 5,811.83 3,071.20 3,107.30 54.3 151.2 Casing LT&C FALSE 5,849.32 3,033.70 3,071.20 54.6 152.1 Casing LT&C FALSE 5,887.04 2,996.00 3,033.70 55 153.1 Casing LT&C FALSE 5,924.34 2,958.70 2,996.00 55.3 154.1 Casing LT&C FALSE 5,961.67 2,921.30 2,958.70 55.7 155.1 Casing LT&C FALSE 5,999.19 2,883.80 2,921.30 56 156 Casing LT&C FALSE 6,036.07 2,846.90 2,883.80 56.4 157 Casing LT&C FALSE 6,074.01 2,809.00 2,846.90 56.7 158 Casing LT&C FALSE 6,110.92 2,772.10 2,809.00 57.1 158.9 Casing LT&C FALSE 6,148.31 2,734.70 2,772.10 57.4 159.9 Casing LT&C FALSE 6,184.64 2,698.40 2,734.70 57.7 160.9 Casing LT&C FALSE 6,223.00 2,660.00 2,698.40 58.1 161.9 Casing LT&C FALSE 6,260.11 2,622.90 2,660.00 58.5 162.8 Casing LT&C FALSE 6,298.04 2,585.00 2,622.90 58.8 163.8 Casing LT&C FALSE 6,336.21 2,546.80 2,585.00 59.2 164.8 Casing LT&C FALSE 6,374.10 2,508.90 2,546.80 59.5 165.8 Casing LT&C FALSE 6,412.51 2,470.50 2,508.90 59.9 166.8 Casing LT&C FALSE 6,449.18 2,433.80 2,470.50 60.2 167.7 Casing LT&C FALSE 6,487.50 2,395.50 2,433.80 60.6 168.7 Casing LT&C FALSE 6,524.22 2,358.80 2,395.50 60.9 169.7 Casing LT&C FALSE 6,562.34 2,320.70 2,358.80 61.3 170.7 Casing LT&C FALSE 6,599.91 2,283.10 2,320.70 61.6 171.7 Casing LT&C FALSE 6,637.01 2,246.00 2,283.10 62 172.6 Casing LT&C FALSE 6,675.33 2,207.70 2,246.00 62.3 173.6 Casing LT&C FALSE 6,712.87 2,170.10 2,207.70 62.7 174.6 Casing LT&C FALSE 6,751.05 2,132.00 2,170.10 63 175.6 Casing LT&C FALSE 6,787.48 2,095.50 2,132.00 63.4 176.5 Casing LT&C FALSE 6,825.16 2,057.80 2,095.50 63.7 177.5 Casing LT&C FALSE 6,861.71 2,021.30 2,057.80 64.1 178.5 Casing LT&C FALSE 6,898.95 1,984.10 2,021.30 64.4 179.4 Casing LT&C FALSE 6,937.00 1,946.00 1,984.10 64.8 180.4

## Casing LT&C FALSE 6,974.19 1,908.80 1,946.00 65.1 181.4 Casing LT&C FALSE 7,011.48 1,871.50 1,908.80 65.5 182.4 Casing LT&C FALSE 7,049.01 1,834.00 1,871.50 65.8 183.3 Casing LT&C FALSE 7,085.61 1,797.40 1,834.00 66.2 184.3 Casing LT&C FALSE 7,123.35 1,759.70 1,797.40 66.5 185.3 Casing LT&C FALSE 7,160.35 1,722.70 1,759.70 66.9 186.2 Casing LT&C FALSE 7,197.77 1,685.20 1,722.70 67.2 187.2 Casing LT&C FALSE 7,234.24 1,648.80 1,685.20 67.5 188.2 Casing LT&C FALSE 7,272.25 1,610.80 1,648.80 67.9 189.1 Casing LT&C FALSE 7,308.78 1,574.20 1,610.80 68.2 190.1 Casing LT&C FALSE 7,347.05 1,536.00 1,574.20 68.6 191.1 Casing LT&C FALSE 7,384.42 1,498.60 1,536.00 68.9 192.1 Casing LT&C FALSE 7,421.59 1,461.40 1,498.60 69.3 193 Casing LT&C FALSE 7,458.63 1,424.40 1,461.40 69.6 194 Casing LT&C FALSE 7,494.93 1,388.10 1,424.40 70 194.9 Casing LT&C FALSE 7,533.61 1,349.40 1,388.10 70.3 195.9 Casing LT&C FALSE 7,570.86 1,312.10 1,349.40 70.7 196.9 Casing LT&C FALSE 7,608.47 1,274.50 1,312.10 71 197.9 Casing LT&C FALSE 7,646.95 1,236.10 1,274.50 71.4 198.9 Casing LT&C FALSE 7,685.05 1,198.00 1,236.10 71.8 199.9 Casing LT&C FALSE 7,722.99 1,160.00 1,198.00 72.1 200.9 Casing LT&C FALSE 7,760.04 1,123.00 1,160.00 72.5 201.8 Casing LT&C FALSE 7,797.31 1,085.70 1,123.00 72.8 202.8 Casing LT&C FALSE 7,834.48 1,048.50 1,085.70 73.2 203.8 Casing LT&C FALSE 7,872.49 1,010.50 1,048.50 73.5 204.8 Casing LT&C FALSE 7,910.51 972.5 1,010.50 73.9 205.7 Casing LT&C FALSE 7,946.61 936.4 972.5 74.2 206.7 Casing LT&C FALSE 7,983.81 899.2 936.4 74.5 207.6 Casing LT&C FALSE 8,020.24 862.8 899.2 74.9 208.6 Casing LT&C FALSE 8,056.54 826.5 862.8 75.2 209.5 Casing LT&C FALSE 8,095.18 787.8 826.5 75.6 210.5 Casing LT&C FALSE 8,133.69 749.3 787.8 75.9 211.5 Casing LT&C FALSE 8,171.78 711.2 749.3 76.3 212.5 Casing LT&C FALSE 8,210.16 672.8 711.2 76.7 213.5 Casing LT&C FALSE 8,247.41 635.6 672.8 77 214.5 Casing LT&C FALSE 8,285.21 597.8 635.6 77.4 215.5 Casing LT&C FALSE 8,322.82 560.2 597.8 77.7 216.5 Casing LT&C FALSE 8,361.01 522 560.2 78.1 217.5 Casing LT&C FALSE 8,398.81 484.2 522 78.4 218.4 Casing LT&C FALSE 8,436.65 446.3 484.2 78.8 219.4 Casing LT&C FALSE Casing LT&C FALSE 8,475.09 407.9 446.3 79.1 220.4 Casing LT&C FALSE 8,511.58 371.4 407.9 79.5 221.4 Casing LT&C FALSE 8,549.19 333.8 371.4 79.8 222.4 Casing LT&C FALSE 8,585.89 297.1 333.8 80.2 223.3 Casing LT&C FALSE 8,624.20 258.8 297.1 80.5 224.3 Casing LT&C FALSE 8,661.36 221.6 258.8 80.9 225.3

## Casing LT&C FALSE 8,697.62 185.4 221.6 81.2 226.2 Casing LT&C FALSE 8,734.60 148.4 185.4 81.6 227.2 Casing LT&C FALSE 8,772.78 110.2 148.4 81.9 228.2 Casing LT&C FALSE 8,811.08 71.9 110.2 82.3 229.2 Casing LT&C FALSE 8,848.54 34.5 71.9 82.6 230.1 Casing LT&C FALSE 8,886.67

‐ 3.7 34.5 83 231.1 Casing LT&C FALSE Casing LT&C

## CB60ADE6 8 AAE873E4 0 215E0C201944446CBF91D972606F1D08
CB60ADE6 8 AAE873E4 0 255CD088F9FE413E9ACAF64D56682D2B
CB60ADE6 8 AAE873E4 0 04E4029DF465484080AA310E7B3E2D0F
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A
CB60ADE6 8 AAE873E4 0 E009F78764184798BEB55A325F281E7A

## CB60ADE6 8 AAE873E4 0 8A26DC25E8C74EEE8C123B5E274B1AF1
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE

## CB60ADE6 8 AAE873E4 0 E8B36AD348C04F93BFEA76C3815547EE
CB60ADE6 8 AAE873E4 0 8590F4DDB01A4CB89AD57A42A96CAAC8
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5

## CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5

## CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5

## CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5
CB60ADE6 8 AAE873E4 0 A3618186134F4D8DA006FE1E931CDDA5

## 1
1
1
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44
44

## 1
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47
47

## 47
1
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144

## 144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144

## 144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144
144

## 144
144
144
144
144
144
144
144

## 1.1 9,950 6,230 6.151
38.01 9,950 6,230 6.151

1.25 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151 1,639.63 9,950 6,230 6.151

## 39.28 7,240 5,410 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151 1,755.71 9,950 6,230 6.151

## 1,755.71 9,950 6,230 6.151
3.6 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151

## 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151

## 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151

## 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151 5,384.39 9,950 6,230 6.151

## 7.656 8
7.656 7
7.656 6
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5
7.656 5

## 7.656 4
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3
7.656 3

## 7.656 3
7.656 2
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1

## 7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1

## 7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1

## 7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1
7.656 1

## ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill

## ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill

## ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill

## ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill

## ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill

## ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill ######## ######## ######## mgraff ######## ######## rhill

## CB60ADE6 8 215E0C20 1 909D92012A4646A0874F75C3374EF22B 1
CB60ADE6 8 255CD088 F 0D20A786854541FDA2F6E12610D31361 1
CB60ADE6 8 04E4029D F 26923CF7573949AF8C1179441ABCF1C7 1
CB60ADE6 8 E009F787 6 F77E1013E36C4DA292E88839EFDA371B 44
CB60ADE6 8 E009F787 6 2AD440B995394A759FD0C0E6B6A43D47 43
CB60ADE6 8 E009F787 6 55F4F038DE6143B7A81D1347B3A7BAC7 42
CB60ADE6 8 E009F787 6 747BD38EC4BD4257BDF1C7A6F4BBF83F 41
CB60ADE6 8 E009F787 6 F684A7BD0DD045E7A43A37DF7AA5A96C 40
CB60ADE6 8 E009F787 6 1413E8BE44D649A5B5A07D0C8BCB2FFD 39
CB60ADE6 8 E009F787 6 CD18B47E9985440BA1A1A6A024919340 38
CB60ADE6 8 E009F787 6 2710871A42EE4FFD8DA6D972297686C7 37
CB60ADE6 8 E009F787 6 11A14FE71A46444D9D0044F188E2F284 36
CB60ADE6 8 E009F787 6 300C4A488B1E4E13BC547E7985646209 35
CB60ADE6 8 E009F787 6 CE1260DD6AB54F759CB0DBD96BD5214D 34
CB60ADE6 8 E009F787 6 EA7DA2D0E37D456487DCFFF53FF2AB45 33
CB60ADE6 8 E009F787 6 7882BD6E07194204969462FEB1CBD816 32
CB60ADE6 8 E009F787 6 7D6808AB98FB43C5B5A1632199CE4F74 31
CB60ADE6 8 E009F787 6 1A45327F79EC4B9883A5562C8BD11FED 30
CB60ADE6 8 E009F787 6 644934ED43DE43C39EF49710BBF9C1FA 29
CB60ADE6 8 E009F787 6 BE20931F390644399A17D2DBEB0ABEEB 28
CB60ADE6 8 E009F787 6 04055608D8274D26A1B524DD6CF5F7CE 27
CB60ADE6 8 E009F787 6 408E4641527A4990940BA82197F36901 26
CB60ADE6 8 E009F787 6 D195B1B4E0374E53BA64842E4BBD20B2 25
CB60ADE6 8 E009F787 6 E69B5E49CD8743489ED598FC98C5EAE9 24
CB60ADE6 8 E009F787 6 33C8715428044B3082FEB27C77A36874 23
CB60ADE6 8 E009F787 6 34A70A0AA4384236A32DD3F7490C715E 22
CB60ADE6 8 E009F787 6 C4CA7905B690445B9BC09DCEEF06538B 21
CB60ADE6 8 E009F787 6 75FDCF6C55CA4A94922E591229A7C16B 20
CB60ADE6 8 E009F787 6 19EDD4358AC04884A8E1FD6F6FC3712C 19
CB60ADE6 8 E009F787 6 637044A5DD134D13933CD1A5E9881E60 18
CB60ADE6 8 E009F787 6 1AD763C4E2E047BDB350C8BA666ED3A7 17
CB60ADE6 8 E009F787 6 408B026CDB93411EA85B5BDF76C11128 16
CB60ADE6 8 E009F787 6 DC35F709EF434C70BD5D91EDE1F63C6F 15
CB60ADE6 8 E009F787 6 2E04BCF4684A42C6890755AA1279FAA7 14
CB60ADE6 8 E009F787 6 CC7933E60C2E4608A2D466384A5E7C7C 13
CB60ADE6 8 E009F787 6 499D313234F446DDBEF1E87D1C885FB5 12
CB60ADE6 8 E009F787 6 38CFBEB51DAF4963ABF7C243E83ABC55 11
CB60ADE6 8 E009F787 6 CAB0879118994B0C8C8D8017168AF124 10
CB60ADE6 8 E009F787 6 29E60602FB1E4B4FB7799DC30439EA16 9
CB60ADE6 8 E009F787 6 DB09FF071CEC45EFA43026EE5302CB30 8
CB60ADE6 8 E009F787 6 75443B87F7724ED998BDD07605FF3AA8 7
CB60ADE6 8 E009F787 6 DAF2B7DA0129414F9521FF160327B02A 6
CB60ADE6 8 E009F787 6 8E082E8A7D6443CAB972473F1E117343 5
CB60ADE6 8 E009F787 6 C2573A687DAF46CF8C5C132CB2230327 4
CB60ADE6 8 E009F787 6 80D00F26CB1E4562BC24B775AA730208 3
CB60ADE6 8 E009F787 6 8ADDCA45C0D0489D83C2DD7B056E16FD 2
CB60ADE6 8 E009F787 6 0CF82E1538FE4893B4BB08C49F69C5DF 1

## CB60ADE6 8 8A26DC25 E 8C77447D96684551AA76681753883CBC 1
CB60ADE6 8 E8B36AD3 4 84F73A6F39024CA89E11EDCC8285E4C9 47
CB60ADE6 8 E8B36AD3 4 82DCA700BCA54E8DB805ADA3E985536C 46
CB60ADE6 8 E8B36AD3 4 7160D4C729A7482DAB2067D9DC386756 45
CB60ADE6 8 E8B36AD3 4 36F6CB8438EE4A3696156641E40BF67F 44
CB60ADE6 8 E8B36AD3 4 E154789ABAAA4465A71CBF2B4AB97834 43
CB60ADE6 8 E8B36AD3 4 FD6F5E0DB469430DA8ACCE4D2D746EEF 42
CB60ADE6 8 E8B36AD3 4 DDF4999B73BD4595B0D8F5167C82E580 41
CB60ADE6 8 E8B36AD3 4 782101C12F934D00A47C6BB91DFDCD40 40
CB60ADE6 8 E8B36AD3 4 FB3B7637D06642DB8469117D2D83374B 39
CB60ADE6 8 E8B36AD3 4 D15523D0DC1940DE9DFC3701673AAC81 38
CB60ADE6 8 E8B36AD3 4 805B1FAA33FE4FBC8F4EFF18C9F765E2 37
CB60ADE6 8 E8B36AD3 4 78B22FD2B70C419C92361C3E28936BEB 36
CB60ADE6 8 E8B36AD3 4 D750DF96DD4B47B8A8DCF8F27388AA52 35
CB60ADE6 8 E8B36AD3 4 DA2039BEAA7C4E5DBF82B27BD9B0FB36 34
CB60ADE6 8 E8B36AD3 4 21BDB4E4782D482DB0C038CF0EF4FA6F 33
CB60ADE6 8 E8B36AD3 4 DF60F2A3DFB849BFAA47070E073FBAFF 32
CB60ADE6 8 E8B36AD3 4 C59CAD3E77AE4AE4835771943DC81151 31
CB60ADE6 8 E8B36AD3 4 2E025EB1ACCC496FA3869EB736B5EDEC 30
CB60ADE6 8 E8B36AD3 4 10B76A062F9C4815998AE795F172AEBB 29
CB60ADE6 8 E8B36AD3 4 15F8557C84814C95AA4A8814DA9D5EF9 28
CB60ADE6 8 E8B36AD3 4 C822D2E211B44F5597CB2CC142E32017 27
CB60ADE6 8 E8B36AD3 4 2573910206144A0C8EFD2BDC8B1258B5 26
CB60ADE6 8 E8B36AD3 4 3254BB0B82DC485BBDB898E73DA13ADD 25
CB60ADE6 8 E8B36AD3 4 7D65E0A3171A4B229236D20D7DF115CE 24
CB60ADE6 8 E8B36AD3 4 054C798656CD45CABA0CD4BF6C528ED5 23
CB60ADE6 8 E8B36AD3 4 DCADE0979DB84B8EA11F3D9233A933FF 22
CB60ADE6 8 E8B36AD3 4 A5B3838AEFA44501882BDC93B5591A9B 21
CB60ADE6 8 E8B36AD3 4 B1E5AD8954CA4E2488BBC7DBFA5B96D7 20
CB60ADE6 8 E8B36AD3 4 0A7B288583B6467EAA0CB33A5D26C8E6 19
CB60ADE6 8 E8B36AD3 4 8A3817A44BD8481B82E309BE73A9C559 18
CB60ADE6 8 E8B36AD3 4 1F06FE9B02A145C395902A8B67EC2634 17
CB60ADE6 8 E8B36AD3 4 8760BCC7D41C4BEFA326B923D0CA5CB7 16
CB60ADE6 8 E8B36AD3 4 5B2E5A25E6404DFDBF1B2CBD52C0F70F 15
CB60ADE6 8 E8B36AD3 4 4952A85560FC4920BD373962E388C565 14
CB60ADE6 8 E8B36AD3 4 7C1EB05B7CE145909D2E02539A6E5294 13
CB60ADE6 8 E8B36AD3 4 99E6291073C44EA0A5D4C79F1A6FCE87 12
CB60ADE6 8 E8B36AD3 4 4D3DD291EDBA4E7A90106EEF00320416 11
CB60ADE6 8 E8B36AD3 4 20E2CB60AB88413DB5FC8631A1D95EBD 10
CB60ADE6 8 E8B36AD3 4 4297BA13B3D947D2AD47BB1BED99EC01 9
CB60ADE6 8 E8B36AD3 4 0131975040FA443BB2A6619F55F93934 8
CB60ADE6 8 E8B36AD3 4 6DB328717FA14BB794BAC2744C06E589 7
CB60ADE6 8 E8B36AD3 4 142644F9B3174A019D6BB0F1BCE56964 6
CB60ADE6 8 E8B36AD3 4 BE8F812D6297479383144ED91ED2F240 5
CB60ADE6 8 E8B36AD3 4 329919EFBE804ADC87CB1495774C26B5 4
CB60ADE6 8 E8B36AD3 4 98035A7A1BFD4C588E6885396CB18F72 3
CB60ADE6 8 E8B36AD3 4 E05CDFFD6F974C2A8FC5CB3010AAAFAA 2

## CB60ADE6 8 E8B36AD3 4 150B75AB426D46C3A42BAF7BDCDBE49F 1
CB60ADE6 8 8590F4DD B 08B37458320C4F389BCB61FD87E798A8 1
CB60ADE6 8 A3618186 1 10B9B7FA9F0B48E38F2301BC66244FFF 146
CB60ADE6 8 A3618186 1 4752F1CCFC6649ADB36BA1AEA722D446 145
CB60ADE6 8 A3618186 1 0B416808A0CC4D52B2B5AC1A5A98BD1F 144
CB60ADE6 8 A3618186 1 9EA1BDCAA05A46E19E36747614C39F93 143
CB60ADE6 8 A3618186 1 9860B849631F4965B131A0B6ECE989AD 142
CB60ADE6 8 A3618186 1 93FA9255D3314210831AF9DF550A0DA8 141
CB60ADE6 8 A3618186 1 C6206B543E134F629C1EAE86B62698F8 140
CB60ADE6 8 A3618186 1 1DEACFCEDD23490EB975B9933C728FDE 139
CB60ADE6 8 A3618186 1 6E96FE6BEEFC47D791CC359E22C245E8 138
CB60ADE6 8 A3618186 1 EDC382F812894CAB82C4406367CE9E9F 137
CB60ADE6 8 A3618186 1 1FC8002921454CDF9F02F74F1C9470AC 136
CB60ADE6 8 A3618186 1 36564CD82A424EB4BF1625786E80B280 135
CB60ADE6 8 A3618186 1 7BB72830E4D74D3195DA6E2D1373AD38 134
CB60ADE6 8 A3618186 1 E16625FB70A3412193D4640870150C3A 133
CB60ADE6 8 A3618186 1 1DDC8B7CE20A4EB09A9BD3E3F4419814 132
CB60ADE6 8 A3618186 1 A10AC48CEFF94CA994E8DEA5638F17B1 131
CB60ADE6 8 A3618186 1 C24ED3F926CA454B9A2F9879E5DA5DC1 130
CB60ADE6 8 A3618186 1 B95952B60AAA45EBB4ACCA3801D8DCBC 129
CB60ADE6 8 A3618186 1 158B08CF9E5C4CDFB9F737CC07571AF9 128
CB60ADE6 8 A3618186 1 993526308829408A8AB693F40684E8D6 127
CB60ADE6 8 A3618186 1 07372C12E1AE4012BC29D126B27A3593 126
CB60ADE6 8 A3618186 1 A8520F33EF42403CA44A7D86A84949DB 125
CB60ADE6 8 A3618186 1 15BC60AD3CDE4C9BAE410CB828CF4976 124
CB60ADE6 8 A3618186 1 61B34F3C6F3A42F984EBD1B0A4770A0C 123
CB60ADE6 8 A3618186 1 FD10D79F0F4E4352BBBBF44307665757 122
CB60ADE6 8 A3618186 1 A011859B9B8A47228889D6CE2F26401D 121
CB60ADE6 8 A3618186 1 C20455802B914E5E9E8DA48FB2B02FA2 120
CB60ADE6 8 A3618186 1 65C1F0B9369244F3B7D2687448B8CA1E 119
CB60ADE6 8 A3618186 1 496FBBCF59C5409886BEC4B919224803 118
CB60ADE6 8 A3618186 1 29F24598B2094033BF0661602350A171 117
CB60ADE6 8 A3618186 1 B156F85D8BC242C68C8F1852D7E0BA8C 116
CB60ADE6 8 A3618186 1 B550CAF79ACB4F38839255C643B58D3F 115
CB60ADE6 8 A3618186 1 6FF91F7FA202482080BBFE8EA1911D2A 114
CB60ADE6 8 A3618186 1 97B2C04C7ED5417492A35165B6DF1742 113
CB60ADE6 8 A3618186 1 2C7816C8E61946EEA01B54AFB0D6060F 112
CB60ADE6 8 A3618186 1 55E242DD5FD842F288FEDCACF2292D18 111
CB60ADE6 8 A3618186 1 30DDE62624E54AF39EEC14258CCF961B 110
CB60ADE6 8 A3618186 1 447251A8AA354841BE7F0028E9CAEFFB 109
CB60ADE6 8 A3618186 1 6BA360819C9E413FB20FB22A8EB47B2F 108
CB60ADE6 8 A3618186 1 47BD24DF4C6743719F29AA589DDA7124 107
CB60ADE6 8 A3618186 1 C144F072FD35476F8D3C5D4ED77076ED 106
CB60ADE6 8 A3618186 1 3005F4042EE944C6A06AF8C7BE683F46 105
CB60ADE6 8 A3618186 1 6129C3EDDE0546CCA72823A02A72AF45 104
CB60ADE6 8 A3618186 1 5FF9EDEC05DD4C3BBBD000A7D618FD6D 103
CB60ADE6 8 A3618186 1 F818597AF4464CAABD45AE35177C95F8 102

## CB60ADE6 8 A3618186 1 BF31B7EBF12343189AE34B204009A9A2 101
CB60ADE6 8 A3618186 1 545A929B729E4840BC328B80F1843021 100
CB60ADE6 8 A3618186 1 CFBC8D70803A4E8DA459E939F405FD93 99
CB60ADE6 8 A3618186 1 71C7CC909A504312B77806656CCDA53D 98
CB60ADE6 8 A3618186 1 52A34872D52E4C69AD203D9167B05FFB 97
CB60ADE6 8 A3618186 1 9800325581C44B73BA78AC8434930E88 96
CB60ADE6 8 A3618186 1 E1A71DB352A943ACBA0991530934E619 95
CB60ADE6 8 A3618186 1 EB39191D094144AF955EA9628551AEC3 94
CB60ADE6 8 A3618186 1 1C2BD4A83C314025BD726BE0BFA1D0B4 93
CB60ADE6 8 A3618186 1 4A8BE521699F4D389AA68329B046206B 92
CB60ADE6 8 A3618186 1 F7E56CAACBE0431E855EB9BD905FA39B 91
CB60ADE6 8 A3618186 1 D30062B7C0C240858CB403851BDC9239 90
CB60ADE6 8 A3618186 1 86BA1400F6D247B6A2B6245C692C77A2 89
CB60ADE6 8 A3618186 1 F8B534510BD343CC876F1F6B195D15D5 88
CB60ADE6 8 A3618186 1 57C8411396824ADFABCF2B25BA2465EA 87
CB60ADE6 8 A3618186 1 D99121639B4A4F6591578B54D3071903 86
CB60ADE6 8 A3618186 1 E545C49ED144489A832D85DDAC3A4877 85
CB60ADE6 8 A3618186 1 7AE77F46AFDC4A6D9DB5F63BE494EEC5 84
CB60ADE6 8 A3618186 1 E876E476EA1A451B863045C01B8265FC 83
CB60ADE6 8 A3618186 1 4F43BB28F0924A1499DCC5E758C488B9 82
CB60ADE6 8 A3618186 1 5DF8BA0DF41A45D0BA7D15742F5CF9C4 81
CB60ADE6 8 A3618186 1 6F4C637CA82949188028EDD78E6D7B32 80
CB60ADE6 8 A3618186 1 8409FC7A09C4443085E65548A9D9F507 79
CB60ADE6 8 A3618186 1 7110F0CFC83141389F2F6C71ECEE32D1 78
CB60ADE6 8 A3618186 1 07564B4CF77248BAA6159B55E207DB40 77
CB60ADE6 8 A3618186 1 EF13440782304CD1B31C8F376A26ABC2 76
CB60ADE6 8 A3618186 1 868925199B0C4B669D0C48AFAF2DC1CF 75
CB60ADE6 8 A3618186 1 C675F5EF8B2D46F4AEA5BF11BB867206 74
CB60ADE6 8 A3618186 1 2BEF7EC90C8A4950ACC6A53447B920A5 73
CB60ADE6 8 A3618186 1 17CEE118B3F5474BA18AB2825C280A1B 72
CB60ADE6 8 A3618186 1 CD30849AB72A4448A427528A2B8545E1 71
CB60ADE6 8 A3618186 1 421AEA1266B2452BA65CA82160240C6A 70
CB60ADE6 8 A3618186 1 87B9FE8DF30B4B8D9B23EA4A3B690202 69
CB60ADE6 8 A3618186 1 339FE2F46E5343F7959383AC400F215C 68
CB60ADE6 8 A3618186 1 07A05AD8742042F8AE8E862D646615FC 67
CB60ADE6 8 A3618186 1 7DD4CFEA34904AA99C3921F1E055CD03 66
CB60ADE6 8 A3618186 1 02B4DC248A314880AA6FB8495843F2CF 65
CB60ADE6 8 A3618186 1 9AA3D4812D2644C8ACEEB0213F6D4FD8 64
CB60ADE6 8 A3618186 1 04EA6FB939AD4071A210D56321508CF5 63
CB60ADE6 8 A3618186 1 DCC2C6E9A1684FEF99251440E75ED358 62
CB60ADE6 8 A3618186 1 0CC130704A4E4A03BBF06338055C86C3 61
CB60ADE6 8 A3618186 1 3BD4F8467469443A846C463BD27BAB32 60
CB60ADE6 8 A3618186 1 A315220A767D44349FAC16B7D7ABE6B7 59
CB60ADE6 8 A3618186 1 BB9BD7AACBC547EC93F65BC4430AB7C7 58
CB60ADE6 8 A3618186 1 87FC6FFE8F91467EB4D64C3D95804A1D 57
CB60ADE6 8 A3618186 1 872C877F7DDE4C23AC4B68F120B46D03 56
CB60ADE6 8 A3618186 1 3873C8FB6CB14CA4AAE7AE59C64A5F69 55

## CB60ADE6 8 A3618186 1 4BEE48FB447441CEBDA46E8DC0B66849 54
CB60ADE6 8 A3618186 1 F7E064FC0AAC43A494E7AFBEE46AA7B0 53
CB60ADE6 8 A3618186 1 B4C20DF785C044EB940F6B7086FD8863 52
CB60ADE6 8 A3618186 1 1E262D61147741F9858A5172914D99C0 51
CB60ADE6 8 A3618186 1 FB639B3E56BF423F8E4F386296C86B1A 50
CB60ADE6 8 A3618186 1 9E003CA08EA44F0AB5556C5336AA5D1D 49
CB60ADE6 8 A3618186 1 AC5D6F9717C84A9B990F888A457158BC 48
CB60ADE6 8 A3618186 1 026645C6322F497F9959DDEA82071B8A 47
CB60ADE6 8 A3618186 1 FA5610C2C8CB4A399A57685FBAB2C7A5 46
CB60ADE6 8 A3618186 1 14378A1FD94745848FAFC5972753D036 45
CB60ADE6 8 A3618186 1 865247E43467410C93D4548CA310259C 44
CB60ADE6 8 A3618186 1 919C0D9A9B554EC2B4F613C3F77A2A7B 43
CB60ADE6 8 A3618186 1 0C4DB2B63BC24FD6B6C4F482CBACE81E 42
CB60ADE6 8 A3618186 1 E1270F744196424EB144AD4173C04016 41
CB60ADE6 8 A3618186 1 EB71E0942BCC41A4B0B295049CBE61EE 40
CB60ADE6 8 A3618186 1 91F9822486254D659B8D95FD89E56D52 39
CB60ADE6 8 A3618186 1 7BDA04F0C0B2476890CEBD8BEA099D61 38
CB60ADE6 8 A3618186 1 1207DAEEDC6C4D9FA48255FF4C6918B1 37
CB60ADE6 8 A3618186 1 D71942BDEF9848ED829EF1A0257FDC96 36
CB60ADE6 8 A3618186 1 C256925666CE4AC7B02E3DDFD06BD781 35
CB60ADE6 8 A3618186 1 69838F1E58F74D52B5EE884A550E5A22 34
CB60ADE6 8 A3618186 1 E421135B617B43A6AB4BC77803C2924E 33
CB60ADE6 8 A3618186 1 503A06954DD647F4ACEAE52930238E96 32
CB60ADE6 8 A3618186 1 35B82D79789646D081E3F0B14F774588 31
CB60ADE6 8 A3618186 1 FCE1DDAA61194416AB727BD16B8B157C 30
CB60ADE6 8 A3618186 1 FE6DA52CEEF344528EEB44E2F24BB07D 29
CB60ADE6 8 A3618186 1 B8B1BFB8F24144AC9337F430434AA362 28
CB60ADE6 8 A3618186 1 78B31F6EC2344FE284A591FE80773ABB 27
CB60ADE6 8 A3618186 1 20F4DED39F824972A59904293170DB67 26
CB60ADE6 8 A3618186 1 53FA0A6CCF89412C944239D4AC63B99B 25
CB60ADE6 8 A3618186 1 88B541096D59434A9831DEADE34D1B9F 24
CB60ADE6 8 A3618186 1 9AF744B8010845AB9ADC35E9E2D605F4 23
CB60ADE6 8 A3618186 1 443EBC3BA8A6405DA135BC4413351B21 22
CB60ADE6 8 A3618186 1 FEE0F54F311A4634BB12D562044B3C69 21
CB60ADE6 8 A3618186 1 1F7F9E57ACB24276BEB8608B72DE4915 20
CB60ADE6 8 A3618186 1 D0401DAFEFF5465DB749E0ACDDEC0C46 19
CB60ADE6 8 A3618186 1 DF42BFEF80554D8FB797A8221137B8C7 18
CB60ADE6 8 A3618186 1 A03EFAE757104ECFAD1D43BB7ECC19AD 17
CB60ADE6 8 A3618186 1 A376614706A4415BB54BF48960E71A66 16
CB60ADE6 8 A3618186 1 52D37281134C4541905B4AFCD4166533 15
CB60ADE6 8 A3618186 1 3BEC0426474C4879BAE2B98F8C6D481F 14
CB60ADE6 8 A3618186 1 CE0B86AE37A54CBDA759443317B25475 13
CB60ADE6 8 A3618186 1 92B4D5F3A22A48E4B6C19936D94CB07C 12
CB60ADE6 8 A3618186 1 45268570DBE94406AD9B66EE19C051F7 11
CB60ADE6 8 A3618186 1 32D19BEDF3594EADA21EFB0E6F277126 10
CB60ADE6 8 A3618186 1 18E13ADF07F14F70B08AD72D8D0720F8 9
CB60ADE6 8 A3618186 1 8F77821B6EEE411288122F01C6884D53 8

## CB60ADE6 8 A3618186 1 D65116152DE943E199F8F75BCB60DD0A 7
CB60ADE6 8 A3618186 1 C60D7C9D54594208ABDB9B7D49FEF424 6
CB60ADE6 8 A3618186 1 46B87908A1634B1AA15079F4BBE3C4AD 5
CB60ADE6 8 A3618186 1 1DFD5FBB94F347DFA0F85489D7A16D0E 4
CB60ADE6 8 A3618186 1 9A99B8434DD744C2BCAB47C9139A0246 3
CB60ADE6 8 A3618186 1 7354C96FD7974D3CA42DDFD35198FE0E 2
CB60ADE6 8 A3618186 1 CD336180E0C24D79965E4D9A8E014C88 1

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## ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill ######## ######## ######## rhill ######## ######## rhill

### Stage #: 1 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 8,360' Bottom Perf: 8,630' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: 0.76 psi/ft ISDP: 2,790 psi Holes Open: Fluid Eff: (%) 5 min SIP: 2,490 psi Max Rate: Calc. Perm: mD 10 min SIP: 2,460 psi Max Pressure: Pc (psig) psi 15 min SIP: 2,421 psi

Conc. (ppg) Weight (lbs) Type

-- -

-- - 0.50 5,659 100 mesh

-- - 0.75 5,001 100 mesh

-- - 1.00 8,196 40/70 TLC

-- - 1.25 9,472 40/70 TLC

-- - 1.50 10,892 40/70 TLC

-- - 1.50 12,248 40/70 TLC

-- - 1.00 10,768 20/40 TLC 2.00 20,720 20/40 TLC

BBLS Gal LTR: 187362.0 Gals

LBS

30 % tons CO2

n/a

5,044 psig 5744 psig

68.9 bpm 77.1 bpm


## ISIP = 3,641 psig

no -0.8

no n/a n/a

How many ball sealers were pumped: Was there ball action seen? n/a

Avg Treating Press= Maximum =

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced? If so, by how many bbls/gal?

hours before flowing back.

Remarks/Notes Was well flowed back immediately? If not, well was shut-in Total Fluid Pumped: 4,461

Total Proppant: 145,521 Continue on next page if necessary

100 mesh, 40/70 TLC, 20/40 TLC, 20/40 SLC

Foam Quality: Amount of Foam Pumped: 288 DH, 6 CD Type of foam: Type of Proppant:

X-Link Breaker Time: 242.0 25# Linear Gel, 30Q CO2 5,081 75.6 140.0 25# Linear Gel, 30Q CO2 5,071 74.9

180.0 25# Linear Gel, 30Q CO2 4,954 75.3 193.0 25# Linear Gel, 30Q CO2 5,111 74.7 269.0 25# Linear Gel, 30Q CO2 5,167 75.6 154.0 25# Linear Gel, 30Q CO2 5,167 74.7

251.0 25# Linear Gel, 30Q CO2 5,090 75.5 137.0 25# Linear Gel, 30Q CO2 5,166 75.0 252.0 25# Linear Gel, 30Q CO2 5,221 74.9 142.0 25# Linear Gel, 30Q CO2 5,256 74.7

239.0 25# Linear Gel, 30Q CO2 5,190 75.0 155.0 25# Linear Gel, 30Q CO2 5,195 74.7 557.0 25# Linear Gel, 30Q CO2 4,872 47.7 407.0 2% KCl Substitute 3,451 56.0

262.0 25# Linear Gel, 30Q CO2 5,162 72.3 208.0 25# Linear Gel, 30Q CO2 5,013 63.8 Volume (bbls) Pressure (psi) Rate (bbl/min) 250 3,125

FET ANALYSIS 100 Frac Grad:

Fluid Type 57 5,454

FLUIDS PUMPED PROPPANT PUMPED Liner Top Depth

320.2 321.0 MAXIMUM PRESSURE 0.5 - 2 SPF 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 12/22/2009 10:10:00 AM 12:36:00 PM

7.000

### Stage #: 1 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Pipe 1 Size: Pipe 2 Size: Top Perf: 8,360' Bottom Perf: 8,630' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Fluid Type Conc. (ppg) Weight (lbs) Type 3.00 26,627 20/40 TLC 4.00 24,476 20/40 TLC 4.00 11,462 20/40 SLC

-- -

Remarks/Notes 72.9 321.0 2% KCl Substitute 4,379 43.7 Volume (bbls) Pressure (psi) Rate (bbl/min)

91.0 25# Linear Gel, 30Q CO2 4,696 106.0 25# Linear Gel, 30Q CO2 4,726 73.9 155.0 25# Linear Gel, 30Q CO2 4,829 74.4 0.5 - 2 SPF

320.2 321.0 MAXIMUM PRESSURE

PROPPANT PUMPED 250 3,125

FLUIDS PUMPED (CONTINUED FROM PAGE 1) Liner Depth 12/22/2009 10:10:00 AM

7.000 SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 12:36:00 PM 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

### Stage #: 1 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa 2.0 14,795 20/40 Ottawa 2.5 20,083 20/40 Ottawa 3.0 18,988 20/40 Ottawa 4.0 21,642 20/40 Ottawa 4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm


## ISIP = 3,400 psig

Yes 2.0

No 4 250

FET ANALYSIS Frac Grad:

Volume (bbls) Pressure (psi) Rate (bbl/min)

Avg Treating Press= Maximum = X-Link Breaker Time: n/a FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in How many ball sealers were pumped: Was there ball action seen? n/a Foam Quality: Amount of Foam Pumped: 400 Type of foam: Type of Proppant: 20/40 Ottawa, 20/40 SLC Total Fluid Pumped: 441

Total Proppant: 97,100 57.0 3,726 30.0 4% Crystalline KCl 53.0 3,541 38.1 43.0 3,544 38.2 42.0 3,896 38.4 32.0 3,873 37.1 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 16.0 2,560 2.0 40.0 3,882 38.0

56.0 3,292 38.0 22.0 3,485 38.8 35.0 3,507 37.0 20# Linear gel, 80Q CO2 12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7 4% Crystalline KCl 20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2 3,125 Displ Coef: 0.0383 0.5 - 2 SPF Liner Top Depth 7.000

MAXIMUM PRESSURE 198.0 199.2 

# SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s): Treatment Report

Superior Well Services Jason Stewart

### Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report 1 sec (or 2 sec) data in .csv of .txt form Service Company Treatment Report Service Company Field Ticket 

## areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com; mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com; tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com; scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com

### Report Printed 8/19/2011 123 Robert S. Kerr Ave. Oklahoma City, OK 73102 

# Casing & Cement

www.SandRidgeEnergy.com Page 1/1 

## WEST RANCH SOUTH 71-5

For String: Surface Casing Detail: Casing Description Surface Run Date 10/21/2009 00:00 Set Depth (ftKB) 1,118 Wellbore Original Hole Csg Cutoff (ftKB) Casing Cutoff Date Centralizers 5 Scratchers

Casing Components:

Joints

28 Item Description Casing-Joints Icon Casing (black) OD (in) 9 5/8 ID (in) 8.921 Wt (lb/ft) 36.00 Grade J-55 Top Connection Thread LT&C Length (ft) 1,098.00 Top Depth (ftKB) 20.0 Btm (ftKB) 1,118.0

Cementing Job Details: Description Surface Casing Cement Type Casing String Surface, 1,118ftKB Wellbore Original Hole Cementing Start Date 10/21/2009 00:00 Cementing End Date 10/21/2009 01:30 Cementing Company O-TEX
Comment Circulate 20 bbls to pit.

Cement Stage#1 Description: Stage Number 1 Top Depth (ftKB) 20.0 Bottom Depth (ftKB) 1,118.0 Cement Volume Return (bbl) 20.0
Float Failed? No Plug Failed? No Full Return? Yes Pipe Reciprocated? No Pressure Held (psi) 300.0 Top Plug? No Bottom Plug? No Initial Pump Rate (gpm) Final Pump Rate (gpm)

Avg Pump Rate (bbl/min) Final Pump Pressure (p si) Plug Bump Pressure (p si) Pressure Release Date 10/21/2009

Lead Fluid Details for Stage#1 : Fluid Type Lead Fluid Description Amount (sacks) 500 Class C Volume Pumped (bbl)

Estimated Top (ftKB) 20.0 Estimated Bottom Depth (ftKB) 1,118.0 Yield (ft3/sack) 2.08 Mix H20 Ratio (gal/sack) 20.00 Free Water (%)

Density (lb/gal) Plastic Viscosity (cp) Thick ening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

### Report Printed 8/19/2011 123 Robert S. Kerr Ave. Oklahoma City, OK 73102 

# Casing & Cement

www.SandRidgeEnergy.com Page 1/4 

## WEST RANCH SOUTH 71-5

For String: Production Casing Detail: Casing Description Production Run Date 11/30/2009 00:00 Set Depth (ftKB) 8,883 Wellbore Original Hole Csg Cutoff (ftKB) Casing Cutoff Date Centralizers 12 Scratchers

Casing Components:

Joints 144 Item Description Casing-joints Icon Casing (black) OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade P-110 Top Connection Thread LT&C Length (ft) 5,384.39 Top Depth (ftKB) 20.0 Btm (ftKB) 5,404.4
Joints 1 Item Description

D-V tool Icon Casing (black) OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade P-110 Top Connection Thread LT&C Length (ft) 3.60 Top Depth (ftKB) 5,404.4 Btm (ftKB) 5,408.0
Joints

47 Item Description Casing-joints Icon Casing (black) OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade P-110 Top Connection Thread LT&C Length (ft) 1,755.71 Top Depth (ftKB) 5,408.0 Btm (ftKB) 7,163.7
Joints 1 Item Description

Casing-Joints Icon Casing (black) OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade N-80 Top Connection Thread LT&C Length (ft) 39.28 Top Depth (ftKB) 7,163.7 Btm (ftKB) 7,203.0
Joints

44 Item Description Casing-Joints Icon Casing (black) OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade P-110 Top Connection Thread LT&C Length (ft) 1,639.63 Top Depth (ftKB) 7,203.0 Btm (ftKB) 8,842.6
Joints 1 Item Description

Float collar Icon Casing (black) OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade P-110 Top Connection Thread LT&C Length (ft) 1.25 Top Depth (ftKB) 8,842.6 Btm (ftKB) 8,843.9
Joints 1 Item Description

Casing-Joints Icon Casing (black) OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade P-110 Top Connection Thread LT&C Length (ft) 38.01 Top Depth (ftKB) 8,843.9 Btm (ftKB) 8,881.9
Joints 1 Item Description

Float Shoe Icon Casing shoe OD (in) 7 ID (in) 6.276 Wt (lb/ft) 26.00 Grade P-110 Top Connection Thread LT&C Length (ft) 1.10 Top Depth (ftKB) 8,881.9 Btm (ftKB) 8,883.0

Cementing Job Details: Description Cement Plug Type Plug String Production, 8,883ftKB Wellbore Original Hole Cementing Start Date 11/30/2009 00:00 Cementing End Date 11/30/2009 00:00 Cementing Company Halliburton Energy Services
Comment Original production csg cement job

Cement Stage#<Stage Number?> Description: Stage Number Top Depth (ftKB) 8,187.0 Bottom Depth (ftKB) 8,200.0 Cement Volume Return (bbl)

Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pressure Held (psi)

Top Plug? Bottom Plug? Initial Pump Rate (gpm) Final Pump Rate (gpm)

Avg Pump Rate (bbl/min) Final Pump Pressure (p si) Plug Bump Pressure (p si) Pressure Release Date

<Fluid Type?> Fluid Details for Stage#<Stage Number?>: Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl)

Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) Plastic Viscosity (cp) Thick ening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

Description Production Casing Cement Type Casing String Production, 8,883ftKB Wellbore Original Hole Cementing Start Date 11/30/2009 05:00 Cementing End Date Cementing Company Halliburton Energy Services
Comment 2 stage

Cement Stage#1 Description: Stage Number 1 Top Depth (ftKB) 6,750.0 Bottom Depth (ftKB) 8,883.0 Cement Volume Return (bbl) 0.0
Float Failed? No Plug Failed? No Full Return? Yes Pipe Reciprocated? No Pressure Held (psi)

Top Plug? No Bottom Plug? Yes Initial Pump Rate (gpm) 6 Final Pump Rate (gpm) 4 Avg Pump Rate (bbl/min) 5 Final Pump Pr essure (psi) 906.0 Plug Bump Pressure (psi) 1,888.0 Pressure Release Date

### Report Printed 8/19/2011 123 Robert S. Kerr Ave. Oklahoma City, OK 73102 

# Casing & Cement

www.SandRidgeEnergy.com Page 2/4 

## WEST RANCH SOUTH 71-5

For String: Production Spacer Fluid Details for Stage#1 : Fluid Type Spacer Fluid Description H20 Amount (sacks) Class Volume Pumped (bbl) 20.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) 0.00 Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) 8.30 Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

Lead Fluid Details for Stage#1 : Fluid Type Lead Fluid Description Amount (sacks) 280 Class H Volume Pumped (bbl) 65.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) 1.32 Mix H20 Ratio (gal/sack) 6.06 Free Water (%)

Density (lb/gal) 14.20 Plastic Viscosity (cp) Thickening Time (hr) 3.50 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

2nd lead Fluid Details for Stage#1 : Fluid Type 2nd lead Fluid Description Amount (sacks) 710 Class H Volume Pumped (bbl) 165.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) 5,404.0 Yield (ft3/sack) 1.32 Mix H20 Ratio (gal/sack) 6.06 Free Water (%)

Density (lb/gal) 14.20 Plastic Viscosity (cp) Thickening Time (hr) 3.50 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

2nd Spacer Fluid Details for Stage#1 : Fluid Type 2nd Spacer Fluid Description H20 Amount (sacks) Class Volume Pumped (bbl) 10.0 Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) 8.30 Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

Cement Stage#2 Description: Stage Number 2 Top Depth (ftKB) 2,704.0 Bottom Depth (ftKB) 5,408.0 Cement Volume Return (bbl)

Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pressure Held (psi)

Top Plug? Bottom Plug? Initial Pump Rate (gpm) Final Pump Rate (gpm)

Avg Pump Rate (bbl/min) Final Pump Pressure (p si) Plug Bump Pressure (p si) Pressure Release Date

### Report Printed 8/19/2011 123 Robert S. Kerr Ave. Oklahoma City, OK 73102 

# Casing & Cement

www.SandRidgeEnergy.com Page 3/4 

## WEST RANCH SOUTH 71-5

For String: Production <Fluid Type?> Fluid Details for Stage#<Stage Number?>: Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl)

Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) Plastic Viscosity (cp) Thick ening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

Description Cement Plug Type Plug String Production, 8,883ftKB Wellbore Original Hole Cementing Start Date 1/5/2010 00:00 Cementing End Date 1/5/2010 00:00 Cementing Company Halliburton Energy Services
Comment 2 sks cement above CIBP

Cement Stage#<Stage Number?> Description: Stage Number Top Depth (ftKB) 8,322.0 Bottom Depth (ftKB) 8,335.0 Cement Volume Return (bbl)

Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pressure Held (psi)

Top Plug? Bottom Plug? Initial Pump Rate (gpm) Final Pump Rate (gpm)

Avg Pump Rate (bbl/min) Final Pump Pressure (p si) Plug Bump Pressure (p si) Pressure Release Date

<Fluid Type?> Fluid Details for Stage#<Stage Number?>: Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl)

Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) Plastic Viscosity (cp) Thick ening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

Description Cement Plug Type Plug String Production, 8,883ftKB Wellbore Original Hole Cementing Start Date 1/7/2010 00:00 Cementing End Date 1/7/2010 00:00 Cementing Company Halliburton Energy Services
Comment 2 sks cement above CIBP

Cement Stage#<Stage Number?> Description: Stage Number Top Depth (ftKB) 8,827.0 Bottom Depth (ftKB) 8,883.0 Cement Volume Return (bbl)

Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pressure Held (psi)

Top Plug? Bottom Plug? Initial Pump Rate (gpm) Final Pump Rate (gpm)

Avg Pump Rate (bbl/min) Final Pump Pressure (p si) Plug Bump Pressure (p si) Pressure Release Date

<Fluid Type?> Fluid Details for Stage#<Stage Number?>: Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl)

Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) Plastic Viscosity (cp) Thick ening Time (hr) 1st Compressive Strength (psi)

Comment

### Report Printed 8/19/2011 123 Robert S. Kerr Ave. Oklahoma City, OK 73102 

# Casing & Cement

www.SandRidgeEnergy.com Page 4/4 

## WEST RANCH SOUTH 71-5

For String: Production
Additive Details

Add Conc Conc Unit

Description Cement Plug Type Plug String Production, 8,883ftKB Wellbore Original Hole Cementing Start Date 1/21/2010 00:00 Cementing End Date 1/2/2010 00:00 Cementing Company Halliburton Energy Services
Comment 3 sks cement above CBP

Cement Stage#<Stage Number?> Description: Stage Number Top Depth (ftKB) Bottom Depth (ftKB) Cement Volume Return (bbl)

Float Failed? Plug Failed? Full Return? Pipe Reciprocated? Pressure Held (psi)

Top Plug? Bottom Plug? Initial Pump Rate (gpm) Final Pump Rate (gpm)

Avg Pump Rate (bbl/min) Final Pump Pressure (p si) Plug Bump Pressure (p si) Pressure Release Date

<Fluid Type?> Fluid Details for Stage#<Stage Number?>: Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl)

Estimated Top (ftKB) Estimated Bottom Depth (ftKB) Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) Plastic Viscosity (cp) Thick ening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

# Lariat

Report Date: 12/2/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,900 Footage (ftKB) 0 Drill Hrs (hrs) Avg ROP (ft/hr) DFS 44

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Rigging down Planned Operations Finish rigging down and move Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 12:00 7.00 7.00 NU & Test 8,900 8,900 Nipple up production head/clean pits/rig realesed @ 12:00 PM, 12/1/09. 12:00 14:00 2.00 9.00 Rig Up & Down 8,900 8,900 Rig down.



### Air/Mud Data MW (lb/gal) Vis (s/qt) PV (cp) YP (lbf/100ft2) Gel 10 sec Gel 10 min Gel 30 min Filtrate (mL/30min)

Cake (/32") pH Solids (%) LGS (%) MBT (lb/bbl) Oil (%) H20 (%)

Chlor (mg/L) Ca (mg/L) ES (V) HTHP Filt (mL/30min) Pf (mL/mL) Mf (mL/mL) ECD (lb/gal) LCM

Hole Volume (bbl) Pit Volume (bbl) Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment



### Bit Run # 20 Size (in)

8 3/4 Model GX-35 Make Hughes SN 5163492 Jets (/32") 16/16/16 In (ftKB) 8,661 Out (ftKB) 8,900 Drld (ftKB) 239 Drl Hrs (hrs) 24.50 ROP (ft/hr) 9.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 WT A 4 0 NO LOG 

### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 8,531 3.70 101.60 8,621 2.90 84.90 8,650 2.60 79.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 Production 7 26.00 P-110 8,883 

### BHA #20, 8 3/4 Slick BHA No. 20 Drill String Name 8 3/4 Slick Length (ft)

BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft)

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB)



### Diesel Fuel Received Used Cum On Location

Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 Costs Daily Cost Total 48,543 Field Est To Date 2,391,239 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 12/1/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,900 Footage (ftKB) 0 Drill Hrs (hrs) Avg ROP (ft/hr) DFS 43

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Nipple down/clean pits Planned Operations Move rig Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 10:30 5.50 5.50 Prod Csg/Cmt 8,900 8,900 Run 237 jts of 7", P-110, 26#, LT&C casing.

10:30 12:00 1.50 7.00 C&C Hole/Mud 8,900 8,900 Circulate.

12:00 14:00 2.00 9.00 Prod Csg/Cmt 8,900 8,900 Cement 1st stage/lead 20bbls H20, cement 280 sxs class H 50/50 poz, displace w/108.8 bbls H20 and 229.8bbls mud/plug down 2:00 PM, 11/30/08/circulate 0sxs to surface.

14:00 20:00 6.00 15.00 C&C Hole/Mud 8,900 8,900 Circulate between stages.

20:00 21:30 1.50 16.50 Prod Csg/Cmt 8,900 8,900 Second stage, lead 20bbls H20, cement 710sxs class H 50/50 poz, displace w/205.8 H20, plug down @ 9:30 PM 11/30/09/circulate 0sxs to surface. 21:30 05:00 7.50 24.00 NU & Test 8,900 8,900 Nipple down/set slips/65000 on slips./clean pits.



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 47 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 7 Gel 10 min 10 Gel 30 min 13 Filtrate (mL/30min) 5.2 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 4 H20 (%) 80 Chlor (mg/L)

166,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 12.16 LCM

Hole Volume (bbl) 704.5 Pit Volume (bbl) 300.0 Storage Volume (bbl) 0.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment



### Bit Run # 20 Size (in)

8 3/4 Model GX-35 Make Hughes SN 5163492 Jets (/32") 16/16/16 In (ftKB) 8,661 Out (ftKB) 8,900 Drld (ftKB) 239 Drl Hrs (hrs) 24.50 ROP (ft/hr) 9.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 WT A 4 0 NO LOG 

### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 8,531 3.70 101.60 8,621 2.90 84.90 8,650 2.60 79.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 Production 7 26.00 P-110 8,883 

### BHA #20, 8 3/4 Slick BHA No. 20 Drill String Name 8 3/4 Slick Length (ft)

BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft)

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB)



### Diesel Fuel Received Used 435 Cum On Location 3263 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 Costs Daily Cost Total 97,430 Field Est To Date 2,342,696 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/30/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,900 Footage (ftKB) 0 Drill Hrs (hrs) Avg ROP (ft/hr) DFS 42

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Running 7" casing. Planned Operations Finish running 7" casing and cement. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Rtn. Maint. 8,900 8,900 Service rig. 05:30 09:00 3.50 4.00 Trip - Other 8,900 8,900 TIH. 09:00 10:00 1.00 5.00 Excess Ream 8,900 8,900 Ream to bottom 8819'-8900',(81').

10:00 11:30 1.50 6.50 C&C Hole/Mud 8,900 8,900 Circulate bottoms up/mix slug.

11:30 12:00 0.50 7.00 Trip - LDDP 8,900 8,900 Pump out 5 joints of D.P. 12:00 13:00 1.00 8.00 Trip - LDDP 8,900 8,900 Rig up lay down machine/spot slug 13:00 21:30 8.50 16.50 Trip - LDDP 8,900 8,900 Lay down D.P./break kelly 21:30 22:00 0.50 17.00 Rtn. Maint. 8,900 8,900 Service rig 22:00 05:00 7.00 24.00 Prod Csg/Cmt 8,900 8,900 Rig up casing crew/Ran 120jts of 7", P-110, 26#, LT&C casing.



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 48 PV (cp) 20.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 11 Gel 30 min 14 Filtrate (mL/30min) 5.2 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 4 H20 (%) 80 Chlor (mg/L)

166,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.50 LCM

Hole Volume (bbl) 717.0 Pit Volume (bbl) 417.0 Storage Volume (bbl) 0.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8900 70 30 22 27 66 24 hr max 31 units @ 8852'.



### Bit Run # 20 Size (in)

8 3/4 Model GX-35 Make Hughes SN 5163492 Jets (/32") 16/16/16 In (ftKB) 8,661 Out (ftKB) 8,900 Drld (ftKB) 239 Drl Hrs (hrs) 24.50 ROP (ft/hr) 9.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 WT A 4 0 NO LOG 

### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 8,531 3.70 101.60 8,621 2.90 84.90 8,650 2.60 79.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 Production 7 26.00 P-110 8,883 

### BHA #20, 8 3/4 Slick BHA No. 20 Drill String Name 8 3/4 Slick Length (ft)

BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft)

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB)



### Diesel Fuel Received Used 548 Cum On Location 3698 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 100 Q (gpm) 314 Pres (psi) 1,050 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 414,973 Field Est To Date 2,245,267 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/29/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,900 Footage (ftKB) 0 Drill Hrs (hrs) Avg ROP (ft/hr) DFS 41

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Logging Planned Operations Finish logging and TIH Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:00 1.00 1.00 C&C Hole/Mud 8,900 8,900 Circulate bottoms up/mix slug.

06:00 11:00 5.00 6.00 Trip - Logs 8,900 8,900 Pump out 5 joints/spot slug/TOH for logs. 11:00 12:00 1.00 7.00 Rtn. Maint. 8,900 8,900 Service rig 12:00 13:30 1.50 8.50 Logging 8,900 8,900 Rig up loggers 13:30 05:00 15.50 24.00 Logging 8,900 8,900 Log/Start logging @ 8870'/1st log Quad combo, 2nd Image



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 7 Gel 10 min 10 Gel 30 min 14 Filtrate (mL/30min) 5.2 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 4 H20 (%) 80 Chlor (mg/L)

166,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.49 LCM

Hole Volume (bbl) 717.0 Pit Volume (bbl) 417.0 Storage Volume (bbl) 50.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8860 90 10 23 8870 90 10 24 8880 90 10 22 8890 90 10 23 8900 70 30 22 27 66 24 hr max 31 units @ 8852'



### Bit Run # 20 Size (in)

8 3/4 Model GX-35 Make Hughes SN 5163492 Jets (/32") 16/16/16 In (ftKB) 8,661 Out (ftKB) 8,900 Drld (ftKB) 239 Drl Hrs (hrs) 24.50 ROP (ft/hr) 9.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 WT A 4 0 NO LOG 

### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 8,531 3.70 101.60 8,621 2.90 84.90 8,650 2.60 79.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #20, 8 3/4 Slick BHA No. 20 Drill String Name 8 3/4 Slick Length (ft)

BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft)

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB)



### Diesel Fuel Received Used 547 Cum On Location 4246 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 100 Q (gpm) 314 Pres (psi) 1,160 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 28,089 Field Est To Date 1,830,293 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/28/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,900 Footage (ftKB) 228 Drill Hrs (hrs) 22.50 Avg ROP (ft/hr) 10.1 DFS 40

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Drilled to 8900' Planned Operations Circulate for logs/Trip for logs/Log Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 10:30 5.50 5.50 Drilling 8,672 8,725 Rotate 53', 50 wob, 50/50 rpms, 314 gpm, 130 diff. 9.6

10:30 11:00 0.50 6.00 Rtn. Maint. 8,725 8,725 Service rig. 11:00 23:30 12.50 18.50 Drilling 8,725 8,851 Rotate 126', 50 wob, 50/50 rpms, 314 gpm, 130 diff. 10.1

23:30 00:00 0.50 19.00 Rtn. Maint. 8,851 8,851 Service rig. 00:00 04:30 4.50 23.50 Drilling 8,851 8,900 Rotate 49', 50 wob, 50/50 rpms, 314 gpm, 130 diff. 10.9

04:30 05:00 0.50 24.00 C&C Hole/Mud 8,900 8,900 Circulate bottoms up.



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 44 PV (cp) 17.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 8 Gel 30 min 10 Filtrate (mL/30min) 5.1 Cake (/32") 1 pH 8.6 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 4 H20 (%) 80 Chlor (mg/L)

165,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.49 LCM

Hole Volume (bbl) 698.2 Pit Volume (bbl) 382.0 Storage Volume (bbl) 50.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8730 100 17 19 66 24 hr max 39 units @ 8692' 8850 90 10 27 8860 90 10 23 8870 90 10 24 8880 90 10 27 27 66 24 hr max 31 units @ 8852'



### Bit Run # 20 Size (in)

8 3/4 Model GX-35 Make Hughes SN 5163492 Jets (/32") 16/16/16 In (ftKB) 8,661 Out (ftKB) 8,900 Drld (ftKB) 239 Drl Hrs (hrs) 24.50 ROP (ft/hr) 9.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 WT A 4 0 NO LOG WOB (min) (1000lbf) 44 WOB (max) (1000lbf) 50 BHA ROP (ft/hr) 10 SPP (psi) 120.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 310 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 205 Drag (1000lbf) 105 Start (ftKB) 8,672 End (ftKB) 8,900 

### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 8,531 3.70 101.60 8,621 2.90 84.90 8,650 2.60 79.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #20, 8 3/4 Slick BHA No. 20 Drill String Name 8 3/4 Slick Length (ft)

BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft)

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 229 4.50 16.60 X-95 XH 7,251 

### Diesel Fuel Received Used 962 Cum On Location 4793 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 100 Q (gpm) 314 Pres (psi) 1,160 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 23,361 Field Est To Date 1,802,204 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/27/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,672 Footage (ftKB) 61 Drill Hrs (hrs) 7.00 Avg ROP (ft/hr) 8.7 DFS 39

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drilled to 8661'/TFB # 19/Drilling @ 8672' Planned Operations drlg to TD Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Dir Sliding 8,611 8,612 Slide 1', 60 wob, 55 rpms, 345 gpm, 100 diff. 2

05:30 08:00 2.50 3.00 Dir Rotate 8,612 8,634 Rotate 22', 55 wob, 51/50 rpms, 316 gpm, 135 diff. 8.9

08:00 08:30 0.50 3.50 Srvys 8,634 8,634 Check shot @ 8594', 3.6 degrees, 87.2 AZI. 08:30 10:30 2.00 5.50 Dir Rotate 8,634 8,661 Rotate 27', 55 wob, 51/50 rpms, 316 gpm, 135 diff. 13.5

10:30 11:00 0.50 6.00 Rtn. Maint. 8,661 8,661 Service rig 11:00 12:00 1.00 7.00 C&C Hole/Mud 8,661 8,661 Circulate bottoms up/70 SH, 30 LS/ mix slug 12:00 18:00 6.00 13.00 Trip for Bit 8,661 8,661 Pump out 5 joints/spot slug/TFB # 19/lay down directional tools 18:00 00:00 6.00 19.00 Trip for Bit 8,661 8,661 Pick up new motorand dial to 0/TIH 00:00 02:30 2.50 21.50 Excess Ream 8,661 8,661 Ream 8556'-8661', 105'.

02:30 04:00 1.50 23.00 Drilling 8,661 8,666 Break in bit/Rotate 5', 7-30 wob, 52/52 rpms, 320 gpm, 100 diff. 3.3

04:00 04:30 0.50 23.50 Rtn. Maint. 8,666 8,666 Service rig 04:30 05:00 0.50 24.00 Drilling 8,666 8,672 Rotate 6', 44 wob, 52/52 rpms, 320 gpm, 100 diff. 12



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 44 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 8 Gel 30 min 10 Filtrate (mL/30min) 5.1 Cake (/32") 1 pH 8.5 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 4 H20 (%) 80 Chlor (mg/L)

165,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.49 LCM

Hole Volume (bbl) 679.3 Pit Volume (bbl) 375.0 Storage Volume (bbl) 165.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8640 10 10 80 41 8640 10 10 80 50 8650 20 10 70 53 8650 20 10 70 59 50 72 63 24 hr max 63 units @ 8602'
8660 20 80 15 50 66 24 hr max gas 63 units @ 8602'



### Bit Run # 20 Size (in)

8 3/4 Model GX-35 Make Hughes SN 5163492 Jets (/32") 16/16/16 In (ftKB) 8,661 Out (ftKB) 8,900 Drld (ftKB) 239 Drl Hrs (hrs) 24.50 ROP (ft/hr) 9.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 WT A 4 0 NO LOG WOB (min) (1000lbf) 44 WOB (max) (1000lbf) 50 BHA ROP (ft/hr) 10 SPP (psi) 100.0 Motor RPM (rpm) 52 RPM (rpm) 52 PU (max) (1000lbf) 310 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 195 Drag (1000lbf) 105 Start (ftKB) 8,661 End (ftKB) 8,672 

### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 60 BHA ROP (ft/hr) 9 SPP (psi) 135.0 Motor RPM (rpm) 51 RPM (rpm) 50 PU (max) (1000lbf) 300 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 195 Drag (1000lbf) 105 Start (ftKB) 8,611 End (ftKB) 8,661 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 8,531 3.70 101.60 8,621 2.90 84.90 8,650 2.60 79.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #20, 8 3/4 Slick BHA No. 20 Drill String Name 8 3/4 Slick Length (ft)

BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft)

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,031 

### Diesel Fuel Received Used 708 Cum On Location 5755 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 SPM (spm) 110 Q (gpm) 306 Pres (psi) 1,150 Stroke (in) 10.00 Slow ... No
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,150 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 33,930 Field Est To Date 1,778,843 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/26/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,611 Footage (ftKB) 166 Drill Hrs (hrs) 19.00 Avg ROP (ft/hr) 8.7 DFS 38

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir Slide drlg @ 8611' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:30 2.50 2.50 Excess Ream 8,445 8,445 Ream 8287'-8445', 158'.

07:30 12:30 5.00 7.50 Dir Rotate 8,445 8,476 Rotate 31', 58 wob, 51/50 rpms, 316 gpm, 137 diff. 6.2

12:30 13:00 0.50 8.00 Srvys 8,476 8,476 Survey @ 8436', 3.3 degrees, 113.0 AZI. 13:00 16:30 3.50 11.50 Dir Rotate 8,476 8,508 Rotate 32', 58 wob, 51/50 rpms, 316 gpm, 137 diff. 9

16:30 17:00 0.50 12.00 Rtn. Maint. 8,508 8,508 Service rig. 17:00 20:00 3.00 15.00 Dir Rotate 8,508 8,539 Rotate 31', 58 wob, 51/50 rpms, 316 gpm, 137 diff. 10.3

20:00 20:30 0.50 15.50 Srvys 8,539 8,539 Check shot @ 8499', 3.7 degrees, 105.9 AZI. 20:30 23:30 3.00 18.50 Dir Rotate 8,539 8,571 Rotate 32', 58 wob, 51/50 rpms, 316 gpm, 137 diff. 10.7

23:30 00:00 0.50 19.00 Srvys 8,571 8,571 Survey @ 8531', 3.7 degrees, 101.6 AZI. 00:00 03:00 3.00 22.00 Dir Rotate 8,571 8,602 Rotate 31', 58 wob, 51/50 rpms, 316 gpm, 137 diff. 10.3

03:00 03:30 0.50 22.50 Srvys 8,602 8,602 Check shot @ 8562', 3.9 degrees, 90.9 AZI. 03:30 05:00 1.50 24.00 Dir Sliding 8,602 8,611 Slide 9', 60 wob, 55 rpms, 345 gpm, 100 diff. 6



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 45 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 6 Gel 10 min 8 Gel 30 min 11 Filtrate (mL/30min) 5.1 Cake (/32") 1 pH 8.6 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 5 H20 (%) 79 Chlor (mg/L)

165,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.50 LCM

Hole Volume (bbl) 679.3 Pit Volume (bbl) 358.0 Storage Volume (bbl) 265.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8470 50 50 38 35 72 72 24 hr max 72 units @ 8445' 8550 20 20 60 52 8570 20 20 60 37 8590 30 10 60 60 8610 20 10 70 40 65 72 72 24 hr max 72 units @ 8445'



### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 60 BHA ROP (ft/hr) 9 SPP (psi) 100.0 Motor RPM (rpm) 55 RPM (rpm) 0 PU (max) (1000lbf) 300 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 195 Drag (1000lbf) 105 Start (ftKB) 8,445 End (ftKB) 8,611 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR 

### Bit Run # 17 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,166 Out (ftKB) 8,355 Drld (ftKB) 189 Drl Hrs (hrs) 27.50 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 FC G 0 1 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 8,531 3.70 101.60 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #19, 8 3/4 Steerable BHA No. 19 Drill String Name 8 3/4 Steerable Length (ft) 1,652.71 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 42 HWDP 4 1/2 24.00 1,29...

1 Jars -

Hydraulic 6 1/2 73.50 31.77

9 DC 6 1/2 247.00 273.60 1 DC 6 1/2 98.50 31.10 1 UBHO 6 1/2 226.00 2.63 1 Great White 1.83 0.16 6 3/4 42.00 22.29 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 219 4.50 16.60 X-95 XH 6,936 

### Diesel Fuel Received Used 813 Cum On Location 6463 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... Yes SPM (spm) 110 Q (gpm) 345 Pres (psi) 1,525 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 30,131 Field Est To Date 1,744,914 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/25/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,445 Footage (ftKB) 39 Drill Hrs (hrs) 6.00 Avg ROP (ft/hr) 6.5 DFS 37

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Ream to bottom @ 8445' Planned Operations Dir drlg w/ surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 11:00 6.00 6.00 Dir Rotate 8,406 8,445 Rotate 39', 48 wob, 50/50 rpms, 290 gpm, 80 diff. 6.5

11:00 12:30 1.50 7.50 C&C Hole/Mud 8,445 8,445 Circulate bottom ups (10% shale, 90% chert) mix slug. 12:30 13:00 0.50 8.00 Trip - Other 8,445 8,445 Lay down 5 jts with kelly, pump slug, and set kelly back. 13:00 19:30 6.50 14.50 Trip for Bit 8,445 8,445 TFB-lay down 33 jts X-95 drill pipe and 14 drill collars. 19:30 20:00 0.50 15.00 Rtn. Maint. 8,445 8,445 Service rig. 20:00 22:00 2.00 17.00 Trip - Other 8,445 8,445 Make up new bit, test motor and MWD (GOOD TEST). 22:00 04:00 6.00 23.00 Trip for Bit 8,445 8,445 TIH w/bit #19, pick up 42 jts of HYWT drill pipe,
04:00 05:00 1.00 24.00 Excess Ream 8,445 8,445 Ream 158' to bottom, 5k on bit.



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 10 Gel 30 min 13 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 5 H20 (%) 79 Chlor (mg/L)

166,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.47 LCM

Hole Volume (bbl) 673.0 Pit Volume (bbl) 388.0 Storage Volume (bbl) 265.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8410 100 15 bottoms up 10 sh,90 chert
8420 100 17 96 units @ 8355' 8430 100 16 8440 100 15


### Bit Run # 19 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,445 Out (ftKB) 8,661 Drld (ftKB) 216 Drl Hrs (hrs) 24.00 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 4 4 WT A E 2 NO PR WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 60 BHA ROP (ft/hr) 9 SPP (psi) 137.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 300 SO (1000lbf) 162 Off-Btm Str Wt (1000lbf) 185 Drag (1000lbf) 98 Start (ftKB) 8,445 End (ftKB) 8,445 

### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 8 SPP (psi) 1,250.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 310 SO (1000lbf) 158 Off-Btm Str Wt (1000lbf) 200 Drag (1000lbf) 110 Start (ftKB) 8,406 End (ftKB) 8,445 

### Bit Run # 17 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,166 Out (ftKB) 8,355 Drld (ftKB) 189 Drl Hrs (hrs) 27.50 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 FC G 0 1 NO PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 8,436 3.30 113.00 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #19, 8 3/4 Steerable BHA No. 19 Drill String Name 8 3/4 Steerable Length (ft) 1,652.71 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 42 HWDP 4 1/2 24.00 1,29...

1 Jars -

Hydraulic 6 1/2 73.50 31.77

9 DC 6 1/2 247.00 273.60 1 DC 6 1/2 98.50 31.10 1 UBHO 6 1/2 226.00 2.63 1 Great White 1.83 0.16 6 3/4 42.00 22.29 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 0 4.50 16.60 X-95 XH 

### Diesel Fuel Received 5,995.0 Used 812 Cum On Location 7276 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 52,325 Field Est To Date 1,714,783 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/24/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,406 Footage (ftKB) 60 Drill Hrs (hrs) 8.50 Avg ROP (ft/hr) 7.1 DFS 36

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 8406' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Rtn. Maint. 8,346 8,346 Service rig. 05:30 08:00 2.50 3.00 Dir Rotate 8,346 8,355 Rotate 9', 55 wob, 50/50 rpms, 290 gpm, 80 diff. 3.6

08:00 09:30 1.50 4.50 C&C Hole/Mud 8,355 8,355 Circulate bottoms up, mix slug.

09:30 10:30 1.00 5.50 Trip for Bit 8,355 8,355 Lay down 5 jts w/kelly, pump slug, set kelly back. 10:30 13:30 3.00 8.50 Trip for Bit 8,355 8,355 Trip out of hole for bit #17. 13:30 14:00 0.50 9.00 Trip for Bit 8,355 8,355 L/D motor and P/U new 1.83 bend, .16 rpg, MWD and Test. 14:00 19:30 5.50 14.50 Trip for Bit 8,355 8,355 Trip in hole with bit # 18 (stage in). 19:30 20:00 0.50 15.00 Rtn. Maint. 8,355 8,355 Service rig. 20:00 22:30 2.50 17.50 Excess Ream 8,355 8,355 Ream 158' to bottom, 36' fill.

22:30 02:00 3.50 21.00 Dir Rotate 8,355 8,372 Rotate 17', 48 wob, 50/50 rpms, 290 gpm, 60 diff. 4.8

02:00 02:30 0.50 21.50 Srvys 8,372 8,372 Survey @ 8332'. 02:30 05:00 2.50 24.00 Dir Rotate 8,372 8,406 Rotate 34', 48 wob, 50/50 rpms, 290 gpm, 60 diff. 13.6



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 44 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 6 Gel 10 min 9 Gel 30 min 11 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 5 H20 (%) 79 Chlor (mg/L)

167,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.48 LCM

Hole Volume (bbl) 666.7 Pit Volume (bbl) 398.0 Storage Volume (bbl) 265.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8350 20 20 60 26 8360 80 20 26 24 hr max 17 @8374 8370 10 90 14 8380 10 90 16 8390 100 13


### Bit Run # 18 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,355 Out (ftKB) 8,445 Drld (ftKB) 90 Drl Hrs (hrs) 12.00 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 8 8 FC A E 2 NO PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 8 SPP (psi) 1,250.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 310 SO (1000lbf) 158 Off-Btm Str Wt (1000lbf) 200 Drag (1000lbf) 110 Start (ftKB) 8,355 End (ftKB) 8,406 

### Bit Run # 17 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,166 Out (ftKB) 8,355 Drld (ftKB) 189 Drl Hrs (hrs) 27.50 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 FC G 0 1 NO PR WOB (min) (1000lbf) 50 WOB (max) (1000lbf) 50 BHA ROP (ft/hr) 7 SPP (psi) 1,275.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 315 SO (1000lbf) 168 Off-Btm Str Wt (1000lbf) 215 Drag (1000lbf) 100 Start (ftKB) 8,346 End (ftKB) 8,355 

### Bit Run # 16 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,042 Out (ftKB) 8,166 Drld (ftKB) 124 Drl Hrs (hrs) 12.50 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 3 CT N E 2 FC PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #18, 8 3/4 Steerable BHA No. 18 Drill String Name 8 3/4 Steerable Length (ft) 792.05 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 223.00 123.23 1 Jars -

Hydraulic 6 1/2 49.50 31.77

19 DC 6 1/2 223.00 580.03

1 DC 6 1/2 86.50 31.10 1 UBHO 6 1/2 214.00 2.63 1 Great White 1.83 0.16 6 3/4 12.00 22.29 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received Used 988 Cum On Location 2093 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 36,080 Field Est To Date 1,662,458 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/23/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,346 Footage (ftKB) 170 Drill Hrs (hrs) 22.50 Avg ROP (ft/hr) 7.6 DFS 35

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 8346' Planned Operations Dir drlg w/ surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:00 2.00 2.00 Dir Rotate 8,176 8,184 Rotate 8' 8 wob, 50/50 rpms, 290 gpm, diff 56. 4

07:00 07:30 0.50 2.50 Srvys 8,184 8,184 Survey @ 8144'. 07:30 10:00 2.50 5.00 Dir Sliding 8,184 8,194 Slide 10', 65 wob, 50 rpm, 310 gpm, diff 80, mtf 300. 4

10:00 18:00 8.00 13.00 Dir Rotate 8,194 8,246 Rotate 52' 8 wob, 50/50 rpms, 290 gpm, diff 56. 6.5

18:00 18:30 0.50 13.50 Rtn. Maint. 8,246 8,246 Service rig. 18:30 21:30 3.00 16.50 Dir Rotate 8,246 8,278 Rotate 32' 8 wob, 50/50 rpms, 290 gpm, diff 56. 10.6

21:30 22:00 0.50 17.00 Srvys 8,278 8,278 survey @ 8238'. 22:00 05:00 7.00 24.00 Dir Rotate 8,278 8,346 Rotate 68', 8wob, 50/50 rpms, 290 gpm diff 56. Last check shot 8301' 3.6 inc, 111.3

azm. 9.7



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 28 Gel 10 sec 6 Gel 10 min 9 Gel 30 min 13 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.5 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 5 H20 (%) 79 Chlor (mg/L)

165,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.40 LCM 0 Hole Volume (bbl) 654.1 Pit Volume (bbl) 403.0 Storage Volume (bbl) 265.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8213 40 60 10 8280 100 25 24 hr max gas 34 units @ 8316'
8300 100 26 8320 100 26 8340 100 26 8340 trace of shale


### Bit Run # 17 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,166 Out (ftKB) 8,355 Drld (ftKB) 189 Drl Hrs (hrs) 27.50 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 FC G 0 1 NO PR WOB (min) (1000lbf) 50 WOB (max) (1000lbf) 50 BHA ROP (ft/hr) 7 SPP (psi) 1,275.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 315 SO (1000lbf) 168 Off-Btm Str Wt (1000lbf) 215 Drag (1000lbf) 100 Start (ftKB) 8,176 End (ftKB) 8,346 

### Bit Run # 16 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,042 Out (ftKB) 8,166 Drld (ftKB) 124 Drl Hrs (hrs) 12.50 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 3 CT N E 2 FC PR 

### Bit Run # 15 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5160890 Jets (/32") 16/16/16 In (ftKB) 8,024 Out (ftKB) 8,054 Drld (ftKB) 30 Drl Hrs (hrs) 3.00 ROP (ft/hr) 10.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 NO A E 0 NO BHA WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 5 BHA ROP (ft/hr) 10 SPP (psi) 800.0 Motor RPM (rpm) RPM (rpm) 55 PU (max) (1000lbf) 290 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 200 Drag (1000lbf) 90 Start (ftKB) End (ftKB)

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 8,238 3.60 105.10 8,332 3.40 111.70 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #17, 8 3/4 Steerable BHA No. 17 Drill String Name 8 3/4 Steerable Length (ft) 792.01 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 213.50 123.23 1 Jars -

Hydraulic 6 1/2 40.00 31.77

19 DC 6 1/2 213.50 580.03

1 DC 6 1/2 77.00 31.10 1 UBHO 6 1/2 204.50 2.63 1 Great White 1.83 0.16 6 3/4 27.50 22.25 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received Used 1012 Cum On Location 3081 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 29,416 Field Est To Date 1,626,378 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/22/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,176 Footage (ftKB) 55 Drill Hrs (hrs) 2.50 Avg ROP (ft/hr) 22.0 DFS 34

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 8176' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:00 1.00 1.00 Dir Sliding 8,121 8,128 Slide 7' 50 wob, 50 rpms,300 gpm,1450 psi,diff 50, mtf 318. 7

06:00 10:00 4.00 5.00 Dir Rotate 8,128 8,166 Rotate 38' 48 wob,50/50 rpms,300 gpm,1450 psi,diff 50 9.5

10:00 11:00 1.00 6.00 C&C Hole/Mud 8,166 8,166 Circulate bottoms up/pump 5 jts out,pump slug and set kelly. 11:00 16:00 5.00 11.00 Trip for Bit 8,166 8,166 Trip out of the hole for bit # 16 (SLM =8163.74) 16:00 18:00 2.00 13.00 Trip for Bit 8,166 8,166 Lay down bit ,mtr and mwd, pick up new 1.83/.16 mtr and test (good test). 18:00 19:00 1.00 14.00 Trip for Bit 8,166 8,166 Run in hole to shoe and cut 100' of drilling line. 19:00 00:30 5.50 19.50 Trip for Bit 8,166 8,166 Finish trip in hole-(stage in) 8009' 00:30 02:00 1.50 21.00 Excess Ream 8,166 8,166 Ream 157' to bottom--28' fill

02:00 02:30 0.50 21.50 Rtn. Maint. 8,166 8,166 Service rig 02:30 05:00 2.50 24.00 Dir Rotate 8,166 8,176 Rotate 10' 50 wob,50/50 gpm,diff 57. 4



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 45 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 8 Gel 30 min 11 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.6 Solids (%) 16 LGS (%) 4 MBT (lb/bbl) Oil (%) 4 H20 (%) 80 Chlor (mg/L) 165 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.48 LCM

Hole Volume (bbl) 666.7 Pit Volume (bbl) 345.0 Storage Volume (bbl) 265.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8160 30 70 17 8160 30 70 17 32 units @ 8166' 8166 10 90 8 8166 10 90 8 8170 30 70 6


### Bit Run # 17 Size (in)

8 3/4 Model HR-55H Make Hughes SN 5159956 Jets (/32") 16/16/16 In (ftKB) 8,166 Out (ftKB) 8,355 Drld (ftKB) 189 Drl Hrs (hrs) 27.50 ROP (ft/hr) 7.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 FC G 0 1 NO PR WOB (min) (1000lbf) 50 WOB (max) (1000lbf) 50 BHA ROP (ft/hr) 7 SPP (psi) 1,275.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 315 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 210 Drag (1000lbf) 95 Start (ftKB) 8,166 End (ftKB) 8,176 

### Bit Run # 16 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,042 Out (ftKB) 8,166 Drld (ftKB) 124 Drl Hrs (hrs) 12.50 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 3 CT N E 2 FC PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 10 SPP (psi) 1,400.0 Motor RPM (rpm) RPM (rpm) 50 PU (max) (1000lbf) 300 SO (1000lbf) 145 Off-Btm Str Wt (1000lbf) 180 Drag (1000lbf) 120 Start (ftKB) 8,121 End (ftKB) 8,166 

### Bit Run # 15 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5160890 Jets (/32") 16/16/16 In (ftKB) 8,024 Out (ftKB) 8,054 Drld (ftKB) 30 Drl Hrs (hrs) 3.00 ROP (ft/hr) 10.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 NO A E 0 NO BHA WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 5 BHA ROP (ft/hr) 10 SPP (psi) 800.0 Motor RPM (rpm) RPM (rpm) 55 PU (max) (1000lbf) 290 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 200 Drag (1000lbf) 90 Start (ftKB) End (ftKB)

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 8,040 3.70 142.70 8,144 5.00 122.60 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #17, 8 3/4 Steerable BHA No. 17 Drill String Name 8 3/4 Steerable Length (ft) 792.01 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 213.50 123.23 1 Jars -

Hydraulic 6 1/2 40.00 31.77

19 DC 6 1/2 213.50 580.03

1 DC 6 1/2 77.00 31.10 1 UBHO 6 1/2 204.50 2.63 1 Great White 1.83 0.16 6 3/4 27.50 22.25 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received Used 1012 Cum On Location 3081 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... Yes Costs Daily Cost Total 36,662 Field Est To Date 1,596,962 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/21/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,121 Footage (ftKB) 79 Drill Hrs (hrs) 12.50 Avg ROP (ft/hr) 6.3 DFS 33

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 8121' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:00 2.00 2.00 Trip - Other 8,054 8,042 TOH lay down NB 3 point reamer and bit. 07:00 07:30 0.50 2.50 Rtn. Maint. 8,054 8,042 Service rig 07:30 09:30 2.00 4.50 Trip - Other 8,054 8,042 Pick up .16 1.83 mtr, mwd and test (good test). 09:30 16:00 6.50 11.00 Trip - Other 8,054 8,042 Make up bit and stage in the hole. (tagged @ 5123' p/up kelly a washed 36') finish TIH to 7868'
16:00 20:30 4.50 15.50 Excess Ream 8,042 8,042 Ream 74' to bottom, 8 wob, 60 rpms, 280 gpm, (depth corr to 8042') 20:30 01:30 5.00 20.50 Dir Rotate 8,042 8,089 Rotate 47', 48 wob, 50 rpms, 280 gpm, diff 57. 9.4

01:30 02:00 0.50 21.00 Srvys 8,089 8,089 Survey @ 8040'. 02:00 02:30 0.50 21.50 Rtn. Maint. 8,089 8,089 Service rig. 02:30 05:00 2.50 24.00 Dir Rotate 8,089 8,121 Rotate 32', 48 wob, 50 rpms, 280 gpm, diff 57. (check shot @ 8081' inc 4.2--azm 138.2) 12.8



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 48 PV (cp) 19.0 YP (lbf/100ft2) 27 Gel 10 sec 7 Gel 10 min 11 Gel 30 min 14 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

167,000 Ca (mg/L) ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.40 LCM

Hole Volume (bbl) 641.6 Pit Volume (bbl) 350.0 Storage Volume (bbl) 265.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8042 100 11 Trip gas @ 8054' 35 units
8070 40 60 8090 100 11 8100 100 13 78 units @ 8036' 8110 100 14


### Bit Run # 16 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,042 Out (ftKB) 8,166 Drld (ftKB) 124 Drl Hrs (hrs) 12.50 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 3 CT N E 2 FC PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 10 SPP (psi) 1,400.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 300 SO (1000lbf) 145 Off-Btm Str Wt (1000lbf) 180 Drag (1000lbf) 120 Start (ftKB) 8,042 End (ftKB) 8,121 

### Bit Run # 15 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5160890 Jets (/32") 16/16/16 In (ftKB) 8,024 Out (ftKB) 8,054 Drld (ftKB) 30 Drl Hrs (hrs) 3.00 ROP (ft/hr) 10.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 NO A E 0 NO BHA WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 5 BHA ROP (ft/hr) 10 SPP (psi) 800.0 Motor RPM (rpm) RPM (rpm) 55 PU (max) (1000lbf) 290 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 200 Drag (1000lbf) 90 Start (ftKB) 8,054 End (ftKB)



### Bit Run # 14 Size (in)

8 3/4 Model GX-44C Make Hughes SN 5163087 Jets (/32") 16/16/16 In (ftKB) 7,945 Out (ftKB) 8,024 Drld (ftKB) 79 Drl Hrs (hrs) 8.00 ROP (ft/hr) 9.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC A E 6 WT TQ Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 8,040 3.70 142.70 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #16, 8 3/4 Steerable BHA No. 16 Drill String Name 8 3/4 Steerable Length (ft) 792.11 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 186.00 123.23 1 Jars -

Hydraulic 6 1/2 12.50 31.77

19 DC 6 1/2 186.00 580.03

1 DC 6 1/2 49.50 31.10 1 UBHO 6 1/2 177.00 2.63 1 Great White 1.83 0.16 6 3/4 12.50 22.35 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received Used 1048 Cum On Location 4093 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 Costs Daily Cost Total 35,928 Field Est To Date 1,560,300 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/20/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,054 Footage (ftKB) 30 Drill Hrs (hrs) 1.50 Avg ROP (ft/hr) 20.0 DFS 32

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Trip out of the hole @ 8054' Planned Operations TOH and pick up tools Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Rtn. Maint. 8,024 8,024 Service rig 05:30 08:00 2.50 3.00 Excess Ream 8,024 8,024 Ream 412' ,f/ 5438-5850'.

08:00 08:30 0.50 3.50 Trip - Other 8,024 8,024 Trip 1070', f/5850'-6920' 08:30 21:30 13.00 16.50 Excess Ream 8,024 8,024 Ream 1104' f/6920'-8054'. 32' of fill.

21:30 23:00 1.50 18.00 Drilling 8,024 8,054 Drlg 30' 55 rpms,48 wob,280 gpm,800 psi. 20 23:00 00:00 1.00 19.00 C&C Hole/Mud 8,054 8,054 Circulate bottoms up,(bottoms up sample 100% chert) 00:00 01:00 1.00 20.00 Trip - Other 8,054 8,054 Lay dow 6 jts with kelly.pump slug set kelly back and TOH. 01:00 05:00 4.00 24.00 Trip - Other 8,054 8,054 Lay down 44 singles,and TOH to lay down NB 3 point.



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 46 PV (cp) 18.0 YP (lbf/100ft2) 27 Gel 10 sec 5 Gel 10 min 7 Gel 30 min 11 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 83 Chlor (mg/L)

167,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.47 LCM

Hole Volume (bbl) 641.6 Pit Volume (bbl) 347.0 Storage Volume (bbl) 265.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8042 100 33 bottoms up sample @ 8054' 100 % chert



### Bit Run # 16 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5163880 Jets (/32") 16/16/16 In (ftKB) 8,042 Out (ftKB) 8,166 Drld (ftKB) 124 Drl Hrs (hrs) 12.50 ROP (ft/hr) 8.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 3 CT N E 2 FC PR 

### Bit Run # 15 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5160890 Jets (/32") 16/16/16 In (ftKB) 8,024 Out (ftKB) 8,054 Drld (ftKB) 30 Drl Hrs (hrs) 3.00 ROP (ft/hr) 10.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 NO A E 0 NO BHA WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 5 BHA ROP (ft/hr) 10 SPP (psi) 800.0 Motor RPM (rpm) RPM (rpm) 55 PU (max) (1000lbf) 290 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 200 Drag (1000lbf) 90 Start (ftKB) 8,024 End (ftKB) 8,054 

### Bit Run # 14 Size (in)

8 3/4 Model GX-44C Make Hughes SN 5163087 Jets (/32") 16/16/16 In (ftKB) 7,945 Out (ftKB) 8,024 Drld (ftKB) 79 Drl Hrs (hrs) 8.00 ROP (ft/hr) 9.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC A E 6 WT TQ Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 8,040 3.70 142.70 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #16, 8 3/4 Steerable BHA No. 16 Drill String Name 8 3/4 Steerable Length (ft) 792.11 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 186.00 123.23 1 Jars -

Hydraulic 6 1/2 12.50 31.77

19 DC 6 1/2 186.00 580.03

1 DC 6 1/2 49.50 31.10 1 UBHO 6 1/2 177.00 2.63 1 Great White 1.83 0.16 6 3/4 12.50 22.35 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB)



### Diesel Fuel Received Used 1048 Cum On Location 4093 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 27,119 Field Est To Date 1,524,372 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/19/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,024 Footage (ftKB) 0 Drill Hrs (hrs) 1.50 Avg ROP (ft/hr) 0.0 DFS 31

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Reaming Doglegs @ 5438' = 16 hrs reaming Planned Operations Reaming Doglegs Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:00 2.00 2.00 Trip - Other 8,024 8,024 TIH --Tagged @ 3950',p/up kelly 07:00 07:30 0.50 2.50 Excess Ream 8,024 8,024 Ream 65' f/3950'-4015'

07:30 08:00 0.50 3.00 Trip - Other 8,024 8,024 TIH--Tagged @ 4646' 08:00 14:00 6.00 9.00 Excess Ream 8,024 8,024 Ream 372' f/4646'-5018

14:00 14:30 0.50 9.50 Rtn. Maint. 8,024 8,024 Service rig 14:30 21:30 7.00 16.50 Excess Ream 8,024 8,024 Ream 198' f/ 5018'-5216'

21:30 22:00 0.50 17.00 Trip - Other 8,024 8,024 TIH--Tag @ 5258' 22:00 01:00 3.00 20.00 Unplanned 8,024 8,024 Work stuck pipe,jar out to 5216' ,packed off. 01:00 01:30 0.50 20.50 C&C Hole/Mud 8,024 8,024 circulate to free pipe .

01:30 03:30 2.00 22.50 Excess Ream 8,024 8,024 Ream 254',5216'-5470'.

03:30 04:00 0.50 23.00 Trip - Other 8,024 8,024 Lay down 6 jts with kelly. 04:00 04:30 0.50 23.50 Trip - Other 8,024 8,024 TIH with one stand tagged up 04:30 05:00 0.50 24.00 Excess Ream 8,024 8,024 Ream 63' f/5375-5438'



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 45 PV (cp) 18.0 YP (lbf/100ft2) 25 Gel 10 sec 5 Gel 10 min 8 Gel 30 min 10 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.5 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

167,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.48 LCM

Hole Volume (bbl) 641.6 Pit Volume (bbl) 341.0 Storage Volume (bbl) 225.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 8024 100 37


### Bit Run # 15 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5160890 Jets (/32") 16/16/16 In (ftKB) 8,024 Out (ftKB) 8,054 Drld (ftKB) 30 Drl Hrs (hrs) 3.00 ROP (ft/hr) 10.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 NO A E 0 NO BHA WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 5 BHA ROP (ft/hr) 10 SPP (psi) 800.0 Motor RPM (rpm) RPM (rpm) 55 PU (max) (1000lbf) 290 SO (1000lbf) 175 Off-Btm Str Wt (1000lbf) 200 Drag (1000lbf) 90 Start (ftKB) 8,024 End (ftKB) 8,024 

### Bit Run # 14 Size (in)

8 3/4 Model GX-44C Make Hughes SN 5163087 Jets (/32") 16/16/16 In (ftKB) 7,945 Out (ftKB) 8,024 Drld (ftKB) 79 Drl Hrs (hrs) 8.00 ROP (ft/hr) 9.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC A E 6 WT TQ 

### Bit Run # 13 Size (in)

8 3/4 Model
GX-E38CH Make Hughes SN 5163095 Jets (/32") 16/16/16 In (ftKB) 7,732 Out (ftKB) 7,945 Drld (ftKB) 213 Drl Hrs (hrs) 29.00 ROP (ft/hr) 7.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 6 8 OC A 3 8 LN PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #15, 8 3/4 Packed Hole BHA No. 15 Drill String Name 8 3/4 Packed Hole Length (ft) 742.00 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 175.00 123.23 1 Jars -

Hydraulic 6 1/2 175.00 31.72

19 DC 6 1/2 175.00 580.03

1 Reamer 7 3.00 6.02 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received Used 1012 Cum On Location 5141 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 Costs Daily Cost Total 27,590 Field Est To Date 1,497,253 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/18/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 8,024 Footage (ftKB) 79 Drill Hrs (hrs) 8.00 Avg ROP (ft/hr) 9.9 DFS 30

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time TIH w/reamer @ 8024' Planned Operations Ream hole Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 10:30 5.50 5.50 Dir Rotate 7,945 7,989 Rotate 44' 50/50, 314 gpm, 80 diff. 8 10:30 11:00 0.50 6.00 Srvys 7,989 7,989 Survey @ 7949. 11:00 13:30 2.50 8.50 Dir Rotate 7,989 8,024 Rotate 35' 50/50, 314 gpm, 80 diff. 14 13:30 15:00 1.50 10.00 C&C Hole/Mud 8,024 8,024 Circulate bottoms up,mix slug.

15:00 16:00 1.00 11.00 Trip for Bit 8,024 8,024 Lay down 5 jts with kelly,pump slug,set kelly back. 16:00 19:00 3.00 14.00 Trip for Bit 8,024 8,024 TFB # 14. 19:00 20:00 1.00 15.00 Trip for Bit 8,024 8,024 Lay down motor and mwd. 20:00 21:00 1.00 16.00 Rtn. Maint. 8,024 8,024 Service rig. 21:00 03:00 6.00 22.00 Trip - Other 8,024 8,024 Wait on near bit reamer. 03:00 05:00 2.00 24.00 Trip - Other 8,024 8,024 TIH to ream doglegs.



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 44 PV (cp) 18.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 9 Gel 30 min 12 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

168,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 11.40 LCM

Hole Volume (bbl) 616.4 Pit Volume (bbl) 410.0 Storage Volume (bbl) 325.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7990 100 32 trip gas 77 units @7945'
8000 100 34 8010 100 34 8020 100 33


### Bit Run # 15 Size (in)

8 3/4 Model GX-E44C Make Hughes SN 5160890 Jets (/32") 16/16/16 In (ftKB) 8,024 Out (ftKB) 8,054 Drld (ftKB) 30 Drl Hrs (hrs) 3.00 ROP (ft/hr) 10.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 NO A E 0 NO BHA WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 5 BHA ROP (ft/hr) 10 SPP (psi) Motor RPM (rpm) RPM (rpm)

PU (max) (1000lbf) 290 SO (1000lbf) 152 Off-Btm Str Wt (1000lbf) 192 Drag (1000lbf) 95 Start (ftKB) 8,024 End (ftKB) 8,024 

### Bit Run # 14 Size (in)

8 3/4 Model GX-44C Make Hughes SN 5163087 Jets (/32") 16/16/16 In (ftKB) 7,945 Out (ftKB) 8,024 Drld (ftKB) 79 Drl Hrs (hrs) 8.00 ROP (ft/hr) 9.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC A E 6 WT TQ WOB (min) (1000lbf) 45 WOB (max) (1000lbf) 45 BHA ROP (ft/hr) 10 SPP (psi) 1,425.0 Motor RPM (rpm) 50 RPM (rpm) 50 PU (max) (1000lbf) 282 SO (1000lbf) 135 Off-Btm Str Wt (1000lbf) 185 Drag (1000lbf) 94 Start (ftKB) 7,945 End (ftKB) 8,024 

### Bit Run # 13 Size (in)

8 3/4 Model
GX-E38CH Make Hughes SN 5163095 Jets (/32") 16/16/16 In (ftKB) 7,732 Out (ftKB) 7,945 Drld (ftKB) 213 Drl Hrs (hrs) 29.00 ROP (ft/hr) 7.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 6 8 OC A 3 8 LN PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 7,949 2.80 157.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #15, 8 3/4 Packed Hole BHA No. 15 Drill String Name 8 3/4 Packed Hole Length (ft) 742.00 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 175.00 123.23 1 Jars -

Hydraulic 6 1/2 175.00 31.72

19 DC 6 1/2 175.00 580.03

1 Reamer 7 3.00 6.02 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received 4,997.0 Used 1088 Cum On Location 6153 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 36,961 Field Est To Date 1,469,663 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/17/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,945 Footage (ftKB) 0 Drill Hrs (hrs) Avg ROP (ft/hr) DFS 29

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Ream @ 7926' Planned Operations Dir drlg w/ surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 10:00 5.00 5.00 Trip for Bit 7,945 7,945 TFB #13. 10:00 12:00 2.00 7.00 Trip for Bit 7,945 7,945 Pick up 1.83/.16,make up bit and test motor & mwd ( test good ). 12:00 14:00 2.00 9.00 Trip for Bit 7,945 7,945 TIH w/bit # 13 to shoe and cut drlg line. 14:00 18:30 4.50 13.50 Trip for Bit 7,945 7,945 Finish TIH w/bit to 7706',p/up kelly. 18:30 05:00 10.50 24.00 Excess Ream 7,945 7,945 Ream 220' to 7926,( tagged @ 7723') 20.9



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 47 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 10 Gel 30 min 14 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

170,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.40 LCM

Hole Volume (bbl) 635.3 Pit Volume (bbl) 341.0 Storage Volume (bbl) 225.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7910 100 11 7920 100 15 7930 10 90 14 7940 30 70 21


### Bit Run # 14 Size (in)

8 3/4 Model GX-44C Make Hughes SN 5163087 Jets (/32") 16/16/16 In (ftKB) 7,945 Out (ftKB) 8,024 Drld (ftKB) 79 Drl Hrs (hrs) 8.00 ROP (ft/hr) 9.9

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC A E 6 WT TQ WOB (min) (1000lbf) 45 WOB (max) (1000lbf) 45 BHA ROP (ft/hr) 10 SPP (psi) Motor RPM (rpm) RPM (rpm)

PU (max) (1000lbf) 282 SO (1000lbf) 135 Off-Btm Str Wt (1000lbf) 183 Drag (1000lbf) 99 Start (ftKB) 7,945 End (ftKB) 7,945 

### Bit Run # 13 Size (in)

8 3/4 Model
GX-E38CH Make Hughes SN 5163095 Jets (/32") 16/16/16 In (ftKB) 7,732 Out (ftKB) 7,945 Drld (ftKB) 213 Drl Hrs (hrs) 29.00 ROP (ft/hr) 7.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 6 8 OC A 3 8 LN PR 

### Bit Run # 12 Size (in)

8 3/4 Model GX-28S Make Hughes SN 6077543 Jets (/32") 16/16/16 In (ftKB) 7,494 Out (ftKB) 7,732 Drld (ftKB) 238 Drl Hrs (hrs) 28.50 ROP (ft/hr) 8.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC O 1 8 BT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,102 4.90 233.60 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #14, 8 3/4 Steerable BHA No. 14 Drill String Name 8 3/4 Steerable Length (ft) 791.79 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 172.00 123.23 1 Jars -

Hydraulic 6 1/2 172.00 31.72

19 DC 6 1/2 172.00 580.03

1 DC 6 1/2 37.00 31.10 1 UBHO 6 1/2 172.00 2.63 1 Great White 1.83 0.16 6 3/4 8.00 22.08 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received Used 1023 Cum On Location 2244 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 35,435 Field Est To Date 1,432,702 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/16/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,945 Footage (ftKB) 161 Drill Hrs (hrs) 20.00 Avg ROP (ft/hr) 8.0 DFS 28

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time TFB @ 7945' Planned Operations TFB. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:30 1.50 1.50 Dir Rotate 7,784 7,800 Rotate 16' 50 rpm,314 gpm,80 diff 10.6 06:30 07:00 0.50 2.00 Srvys 7,800 7,800 Survey @ 7760' 07:00 11:00 4.00 6.00 Dir Rotate 7,800 7,842 Rotate 42' 50 rpm,314 gpm,80 diff 8.4 11:00 11:30 0.50 6.50 Rtn. Maint. 7,842 7,842 Service rig 11:30 12:30 1.00 7.50 Dir Sliding 7,842 7,847 Slide 5' 50 rpms,351 gpm,100 diff,mtf 80 5 12:30 14:00 1.50 9.00 Dir Rotate 7,847 7,863 Rotate 16' 50 rpm,314 gpm,80 diff 10.6 14:00 14:30 0.50 9.50 Unplanned 7,863 7,863 calibrate wt. indicator. 14:30 18:00 3.50 13.00 Dir Rotate 7,863 7,895 Rotate 32' 50 rpm,314 gpm,80 diff 9.1 18:00 18:30 0.50 13.50 Srvys 7,895 7,895 Survey @ 7855' 18:30 22:00 3.50 17.00 Dir Rotate 7,895 7,926 Rotate 31' 50 rpm,314 gpm,80 diff 8.8 22:00 22:30 0.50 17.50 Rtn. Maint. 7,926 7,926 Service rig 22:30 02:00 3.50 21.00 Dir Sliding 7,926 7,936 Slide 10' 50 rpms,351 gpm,100 diff,mtf 65 2.8 02:00 03:30 1.50 22.50 Dir Rotate 7,936 7,945 Rotate 9' 50 rpm,314 gpm,80 diff 6 03:30 05:00 1.50 24.00 C&C Hole/Mud 7,945 7,945 Circulate bottoms up ,lay down 5 jts with kelly ,pump slug and set kelly back.TFB



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 43 PV (cp) 18.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 9 Gel 30 min 13 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.3 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 83 Chlor (mg/L)

169,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.50 LCM 0 Hole Volume (bbl) 622.7 Pit Volume (bbl) 450.0 Storage Volume (bbl) 125.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7840 100 20 7910 100 7920 100 24 hr max 31 units @ 7826'
7930 10 90 7940 30 70


### Bit Run # 13 Size (in)

8 3/4 Model
GX-E38CH Make Hughes SN 5163095 Jets (/32") 16/16/16 In (ftKB) 7,732 Out (ftKB) 7,945 Drld (ftKB) 213 Drl Hrs (hrs) 29.00 ROP (ft/hr) 7.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 6 8 OC A 3 8 LN PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 7 SPP (psi) 1,445.0 Motor RPM (rpm) 54 RPM (rpm) 50 PU (max) (1000lbf) 282 SO (1000lbf) 135 Off-Btm Str Wt (1000lbf) 183 Drag (1000lbf) 99 Start (ftKB) 7,784 End (ftKB) 7,945 

### Bit Run # 12 Size (in)

8 3/4 Model GX-28S Make Hughes SN 6077543 Jets (/32") 16/16/16 In (ftKB) 7,494 Out (ftKB) 7,732 Drld (ftKB) 238 Drl Hrs (hrs) 28.50 ROP (ft/hr) 8.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC O 1 8 BT PR 

### Bit Run # 11 Size (in)

8 3/4 Model GX-22 Make Hughes SN 6049619 Jets (/32") 16/16/16 In (ftKB) 7,148 Out (ftKB) 7,494 Drld (ftKB) 346 Drl Hrs (hrs) 32.50 ROP (ft/hr) 10.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 4 RG G E 1 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,102 4.90 233.60 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 7,855 1.90 205.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #13, 8 3/4 Steerable BHA No. 13 Drill String Name 8 3/4 Steerable Length (ft) 791.88 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 164.00 123.23 1 Jars -

Hydraulic 6 1/2 164.00 31.72

19 DC 6 1/2 164.00 580.03

1 DC 6 1/2 29.00 31.10 1 UBHO 6 1/2 164.00 2.63 1 Great White 2.12 0.16 6 3/4 29.00 22.17 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 222 4.50 16.60 X-95 XH 7,061 

### Diesel Fuel Received Used 1011 Cum On Location 3267 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... Yes Costs Daily Cost Total 28,244 Field Est To Date 1,397,267 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/15/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,784 Footage (ftKB) 76 Drill Hrs (hrs) 11.00 Avg ROP (ft/hr) 6.9 DFS 27

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 7784' Planned Operations Dir drlg w/ surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Dir Rotate 7,708 7,712 Rotate 4' 50/106 rpms,351 gpm, 335 diff. 8 05:30 06:00 0.50 1.00 Srvys 7,712 7,712 Survey @ 7672' 06:00 07:30 1.50 2.50 Dir Rotate 7,712 7,732 Rotate 20' 50/106 rpms,351 gpm, 335 diff. 13.3 07:30 08:30 1.00 3.50 C&C Hole/Mud 7,732 7,732 Circulate bottoms up (40 cht, 10 ls, 50 sh,) mix slug 08:30 12:30 4.00 7.50 Trip for Bit 7,732 7,732 Pump out 5 jts, pump slug, set kelly back,TFB. 12:30 14:30 2.00 9.50 Trip for Bit 7,732 7,732 Change out motor and dial to 2.12 w/.16 rpg,change out Monel,surface test motor and mwd. 14:30 19:00 4.50 14.00 Trip for Bit 7,732 7,732 TIH w/bit #13 to 7575, p/up kelly to ream. 19:00 21:30 2.50 16.50 Excess Ream 7,732 7,732 Ream 157',50/50 rpms,314 gpm. 22' hard reaming. 21:30 02:00 4.50 21.00 Dir Rotate 7,732 7,769 Rotate 37' 50/106 rpms,314 gpm, 335 diff. 8.2 02:00 02:30 0.50 21.50 Rtn. Maint. 7,769 7,769 Service rig 02:30 05:00 2.50 24.00 Dir Sliding 7,769 7,784 Slide 15' 54 rpms,339 gpm,218 diff,mtf 120-CS @ 7729' ,1.2 inc, azm 287.8 6



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 43 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 6 Gel 10 min 11 Gel 30 min 15 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.3 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

170,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.47 LCM

Hole Volume (bbl) 616.4 Pit Volume (bbl) 319.0 Storage Volume (bbl) 225.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7732 50 10 40 7740 100 22 623 trip gas 623 units @ 7732'
7750 10 90 22 7760 10 90 8 7770 10 90 13


### Bit Run # 13 Size (in)

8 3/4 Model
GX-E38CH Make Hughes SN 5163095 Jets (/32") 16/16/16 In (ftKB) 7,732 Out (ftKB) 7,945 Drld (ftKB) 213 Drl Hrs (hrs) 29.00 ROP (ft/hr) 7.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 6 8 OC A 3 8 LN PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 7 SPP (psi) 1,445.0 Motor RPM (rpm) 54 RPM (rpm) 50 PU (max) (1000lbf) 282 SO (1000lbf) 150 Off-Btm Str Wt (1000lbf) 192 Drag (1000lbf) 88 Start (ftKB) 7,732 End (ftKB) 7,784 

### Bit Run # 12 Size (in)

8 3/4 Model GX-28S Make Hughes SN 6077543 Jets (/32") 16/16/16 In (ftKB) 7,494 Out (ftKB) 7,732 Drld (ftKB) 238 Drl Hrs (hrs) 28.50 ROP (ft/hr) 8.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC O 1 8 BT PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 8 SPP (psi) 1,850.0 Motor RPM (rpm) RPM (rpm) 50 PU (max) (1000lbf) 280 SO (1000lbf) 155 Off-Btm Str Wt (1000lbf) 193 Drag (1000lbf) 87 Start (ftKB) 7,708 End (ftKB) 7,732 

### Bit Run # 11 Size (in)

8 3/4 Model GX-22 Make Hughes SN 6049619 Jets (/32") 16/16/16 In (ftKB) 7,148 Out (ftKB) 7,494 Drld (ftKB) 346 Drl Hrs (hrs) 32.50 ROP (ft/hr) 10.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 4 RG G E 1 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 7,007 3.30 261.80 7,102 4.90 233.60 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 7,760 1.50 277.90 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #13, 8 3/4 Steerable BHA No. 13 Drill String Name 8 3/4 Steerable Length (ft) 791.88 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 164.00 123.23 1 Jars -

Hydraulic 6 1/2 164.00 31.72

19 DC 6 1/2 164.00 580.03

1 DC 6 1/2 29.00 31.10 1 UBHO 6 1/2 164.00 2.63 1 Great White 2.12 0.16 6 3/4 29.00 22.17 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 219 4.50 16.60 X-95 XH 6,937 

### Diesel Fuel Received Used 1011 Cum On Location 3267 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... Yes SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 37,232 Field Est To Date 1,369,023 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/14/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,708 Footage (ftKB) 173 Drill Hrs (hrs) 22.50 Avg ROP (ft/hr) 7.7 DFS 26

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 7,708' Planned Operations Dir drlg w/ surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Rtn. Maint. 7,535 7,535 Service rig 05:30 06:00 0.50 1.00 Srvys 7,535 7,535 Survey @ 7482' 06:00 09:00 3.00 4.00 Dir Sliding 7,535 7,555 Slide 20' 106 rpms,351 gpm,335 diff,mtf 150. 6.6

09:00 13:00 4.00 8.00 Dir Rotate 7,555 7,597 Rotate 42' 50/106 rpms,351 gpm,335 diff 10.5 13:00 16:00 3.00 11.00 Dir Sliding 7,597 7,617 Slide 20' 106 rpms,351 gpm,335 diff,mtf 120. 6.6

16:00 16:30 0.50 11.50 Srvys 7,617 7,617 Survey @ 7577' 9.2 16:30 17:30 1.00 12.50 Dir Rotate 7,617 7,627 Rotate 10' 50/106 rpms,351 gpm,335 diff 10 17:30 19:30 2.00 14.50 Dir Sliding 7,627 7,642 Slide 15' 106 rpms,351 gpm,335 diff,mtf 50. 7.5 19:30 21:30 2.00 16.50 Dir Rotate 7,642 7,658 Rotate 16' 50/106 rpms,351 gpm,335 diff 8 21:30 01:00 3.50 20.00 Dir Sliding 7,658 7,675 Slide 17' 106 rpms,351 gpm,335 diff,mtf 50. 4.8 01:00 05:00 4.00 24.00 Dir Rotate 7,675 7,708 Rotate 33' 50/106 rpms,351 gpm,335 diff 8.25



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 43 PV (cp) 18.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 9 Gel 30 min 14 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.3 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 83 Chlor (mg/L)

172,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.40 LCM

Hole Volume (bbl) 603.8 Pit Volume (bbl) 468.0 Storage Volume (bbl) 200.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment sent 200 bbls to mud plant Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7600 30 70 14 7630 100 10 7650 10 90 13 24 hr max 36 units @ 7675'
7670 70 10 20 15 7700 90 10 23


### Bit Run # 12 Size (in)

8 3/4 Model GX-28S Make Hughes SN 6077543 Jets (/32") 16/16/16 In (ftKB) 7,494 Out (ftKB) 7,732 Drld (ftKB) 238 Drl Hrs (hrs) 28.50 ROP (ft/hr) 8.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC O 1 8 BT PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 8 SPP (psi) 1,850.0 Motor RPM (rpm) 106 RPM (rpm) 50 PU (max) (1000lbf) 280 SO (1000lbf) 155 Off-Btm Str Wt (1000lbf) 193 Drag (1000lbf) 87 Start (ftKB) 7,535 End (ftKB) 7,708 

### Bit Run # 11 Size (in)

8 3/4 Model GX-22 Make Hughes SN 6049619 Jets (/32") 16/16/16 In (ftKB) 7,148 Out (ftKB) 7,494 Drld (ftKB) 346 Drl Hrs (hrs) 32.50 ROP (ft/hr) 10.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 4 RG G E 1 WT PR 

### Bit Run # 10 Size (in)

8 3/4 Model FHi23VPS Make Smith SN PN0921 Jets (/32") 16/16/16 In (ftKB) 6,909 Out (ftKB) 7,148 Drld (ftKB) 239 Drl Hrs (hrs) 30.50 ROP (ft/hr) 7.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 6,912 5.10 322.90 7,007 3.30 261.80 7,102 4.90 233.60 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 7,577 4.00 227.80 7,672 1.70 195.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #12, 8 3/4 Steerable BHA No. 12 Drill String Name 8 3/4 Steerable Length (ft) 793.03 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 135.50 123.23 1 Jars -

Hydraulic 6 1/2 135.50 31.72

19 DC 6 1/2 135.50 580.03

1 DC 6 1/2 135.50 31.12 1 UBHO 6 1/2 135.50 2.63 1 Great White 2.12 0.30 6 3/4 61.00 23.30 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 217 4.50 16.60 X-95 XH 6,874 

### Diesel Fuel Received Used 943 Cum On Location 4278 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,830 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 28,289 Field Est To Date 1,331,791 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/13/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,535 Footage (ftKB) 108 Drill Hrs (hrs) 9.00 Avg ROP (ft/hr) 12.0 DFS 25

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 7,535' Planned Operations Dir drlg w/ surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Srvys 7,427 7,427 Survey @ 7387. 05:30 06:00 0.50 1.00 Rtn. Maint. 7,427 7,427 Service rig. 06:00 10:00 4.00 5.00 Dir Rotate 7,427 7,490 Rotate 63' 50/106 rpms,351 gpm,335 diff. 15.7 10:00 11:00 1.00 6.00 Dir Sliding 7,490 7,494 Slide 4',106 rpms,351 gpm,335 diff, mtf 170. 4 11:00 12:30 1.50 7.50 C&C Hole/Mud 7,494 7,494 Circulate bottoms up,lay dn 5 jts with kelly,pump slug,set kelly back. 12:30 16:30 4.00 11.50 Trip for Bit 7,494 7,494 TFB # 11. 16:30 18:00 1.50 13.00 Trip for Bit 7,494 7,494 Change out bit,test motor & mwd, (good test). 18:00 23:30 5.50 18.50 Trip for Bit 7,494 7,494 TIH to 7363, ( stage in),pick up kelly. 23:30 00:30 1.00 19.50 Excess Ream 7,494 7,494 Ream 131' to bottom

00:30 01:00 0.50 20.00 Rtn. Maint. 7,494 7,494 Service rig and get check shot 01:00 01:30 0.50 20.50 Dir Rotate 7,494 7,499 Rotate 5' 50/106 rpms,351 gpm,335 diff. ( brake bit in ) 10

01:30 04:30 3.00 23.50 Dir Sliding 7,499 7,522 Slide 23',106 rpms,351 gpm,335 diff, mtf 150. 7.6

04:30 05:00 0.50 24.00 Dir Rotate 7,522 7,535 Rotate13' 50/106 rpms,351 gpm,335 diff. 26



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 45 PV (cp) 18.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 11 Gel 30 min 15 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.3 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

172,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.62 LCM

Hole Volume (bbl) 591.2 Pit Volume (bbl) 415.0 Storage Volume (bbl) 200.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7490 100 14 7494 100 12 7500 100 13 7510 100 5 trip gas @ 75 units @ 7494' 7520 100 4


### Bit Run # 12 Size (in)

8 3/4 Model GX-28S Make Hughes SN 6077543 Jets (/32") 16/16/16 In (ftKB) 7,494 Out (ftKB) 7,732 Drld (ftKB) 238 Drl Hrs (hrs) 28.50 ROP (ft/hr) 8.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 8 FC O 1 8 BT PR WOB (min) (1000lbf) 48 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 8 SPP (psi) 1,850.0 Motor RPM (rpm) 106 RPM (rpm) 50 PU (max) (1000lbf) 280 SO (1000lbf) 125 Off-Btm Str Wt (1000lbf) 135 Drag (1000lbf) 65 Start (ftKB) 7,494 End (ftKB) 7,535 

### Bit Run # 11 Size (in)

8 3/4 Model GX-22 Make Hughes SN 6049619 Jets (/32") 16/16/16 In (ftKB) 7,148 Out (ftKB) 7,494 Drld (ftKB) 346 Drl Hrs (hrs) 32.50 ROP (ft/hr) 10.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 4 RG G E 1 WT PR WOB (min) (1000lbf) 44 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 11 SPP (psi) 1,850.0 Motor RPM (rpm) 106 RPM (rpm) 50 PU (max) (1000lbf) 200 SO (1000lbf) 110 Off-Btm Str Wt (1000lbf) 141 Drag (1000lbf) 59 Start (ftKB) 7,427 End (ftKB) 7,494 

### Bit Run # 10 Size (in)

8 3/4 Model FHi23VPS Make Smith SN PN0921 Jets (/32") 16/16/16 In (ftKB) 6,909 Out (ftKB) 7,148 Drld (ftKB) 239 Drl Hrs (hrs) 30.50 ROP (ft/hr) 7.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 6,725 3.30 315.00 6,820 5.10 274.40 6,912 5.10 322.90 7,007 3.30 261.80 7,102 4.90 233.60 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 7,482 3.00 274.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #12, 8 3/4 Steerable BHA No. 12 Drill String Name 8 3/4 Steerable Length (ft) 793.03 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 135.50 123.23 1 Jars -

Hydraulic 6 1/2 135.50 31.72

19 DC 6 1/2 135.50 580.03

1 DC 6 1/2 135.50 31.12 1 UBHO 6 1/2 135.50 2.63 1 Great White 2.12 0.30 6 3/4 61.00 23.30 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 210 4.50 16.60 X-95 XH 6,652 

### Diesel Fuel Received Used 900 Cum On Location 5221 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,830 Stroke (in) 9.00 Slow ... No SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... Yes Costs Daily Cost Total 35,973 Field Est To Date 1,303,502 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/12/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,427 Footage (ftKB) 242 Drill Hrs (hrs) 22.00 Avg ROP (ft/hr) 11.0 DFS 24

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 7427' Planned Operations Dir drlg w/surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Rtn. Maint. 7,185 7,185 Service rig 05:30 10:00 4.50 5.00 Dir Rotate 7,185 7,237 Rotate 52', 50/100 rpms, 332 gpm, 215 diff. 11.5 10:00 10:30 0.50 5.50 Srvys 7,237 7,237 Survey @ 7197' 10:30 13:30 3.00 8.50 Dir Sliding 7,237 7,262 Slide 25', 106 rpms, 351 gpm, diff 188, MTF 10. 8.3

13:30 16:30 3.00 11.50 Dir Rotate 7,262 7,300 Rotate 38', 50/100 rpms, 332 gpm, 215 diff. 12.6 16:30 17:00 0.50 12.00 Rtn. Maint. 7,300 7,300 Service rig 17:00 19:30 2.50 14.50 Dir Sliding 7,300 7,322 Slide 22', 106 rpms, 351 gpm, diff 188, MTF 60. 8.8

19:30 20:00 0.50 15.00 Dir Rotate 7,322 7,332 Rotate 10', 50/100 rpms, 332 gpm, 215 diff. 20 20:00 20:30 0.50 15.50 Srvys 7,332 7,332 Survey @ 7292' 20:30 22:00 1.50 17.00 Dir Sliding 7,332 7,352 Slide 20', 106 rpms, 351 gpm, diff 188, MTF 80. 13.3

22:00 23:30 1.50 18.50 Dir Rotate 7,352 7,363 Rotate 11', 50/100 rpms, 332 gpm, 215 diff. 7.3 23:30 02:00 2.50 21.00 Dir Sliding 7,363 7,383 Slide 20', 106 rpms, 351 gpm, diff 188, MTF 80. 8

02:00 05:00 3.00 24.00 Dir Rotate 7,383 7,427 Rotate 44', 50/100 rpms, 332 gpm, 215 diff. 14.6



### Air/Mud Data MW (lb/gal) 11.30 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 8 Gel 10 min 13 Gel 30 min 18 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 0 H20 (%) 84 Chlor (mg/L)

170,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 11.50 LCM 0 Hole Volume (bbl) 905.7 Pit Volume (bbl) 333.0 Storage Volume (bbl) 200.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7250 100 10 7360 90 10 22 24 hr max 24 units @ 7360
7370 70 30 13 7380 50 50 14 7390 40 60 22


### Bit Run # 11 Size (in)

8 3/4 Model GX-22 Make Hughes SN 6049619 Jets (/32") 16/16/16 In (ftKB) 7,148 Out (ftKB) 7,494 Drld (ftKB) 346 Drl Hrs (hrs) 32.50 ROP (ft/hr) 10.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 4 RG G E 1 WT PR WOB (min) (1000lbf) 44 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 11 SPP (psi) 1,850.0 Motor RPM (rpm) 106 RPM (rpm) 50 PU (max) (1000lbf) 200 SO (1000lbf) 110 Off-Btm Str Wt (1000lbf) 141 Drag (1000lbf) 59 Start (ftKB) 7,185 End (ftKB) 7,427 

### Bit Run # 10 Size (in)

8 3/4 Model FHi23VPS Make Smith SN PN0921 Jets (/32") 16/16/16 In (ftKB) 6,909 Out (ftKB) 7,148 Drld (ftKB) 239 Drl Hrs (hrs) 30.50 ROP (ft/hr) 7.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 WT PR 

### Bit Run # 9 Size (in)

8 3/4 Model FHI23VPS Make Smith SN PN0922 Jets (/32") 16/16/16 In (ftKB) 6,623 Out (ftKB) 6,909 Drld (ftKB) 286 Drl Hrs (hrs) 20.00 ROP (ft/hr) 14.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 ER BHA Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 6,630 0.60 332.30 6,725 3.30 315.00 6,820 5.10 274.40 6,912 5.10 322.90 7,007 3.30 261.80 7,102 4.90 233.60 7,197 4.00 174.90 7,292 4.30 218.00 7,387 2.20 193.20 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #11, 8 3/4 Steerable BHA No. 11 Drill String Name 8 3/4 Steerable Length (ft) 793.03 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 107.00 123.23 1 Jars -

Hydraulic 6 1/2 107.00 31.72

19 DC 6 1/2 107.00 580.03

1 DC 6 1/2 107.00 31.12 1 UBHO 6 1/2 107.00 2.63 1 Great White 2.12 0.30 6 3/4 32.50 23.30 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 208 4.50 16.60 X-95 XH 6,588 

### Diesel Fuel Received Used 988 Cum On Location 1019 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... Yes SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 44,371 Field Est To Date 1,267,529 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/11/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,185 Footage (ftKB) 55 Drill Hrs (hrs) 10.00 Avg ROP (ft/hr) 5.5 DFS 23

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg to 7185'. Planned Operations Dir drlg w/surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Dir Sliding 7,130 7,132 Slide 2', 56 rpms, 350 gpm, 210 diff. 4 05:30 06:00 0.50 1.00 Rtn. Maint. 7,132 7,132 Service rig 06:00 07:00 1.00 2.00 Dir Rotate 7,132 7,142 Rotate 10', 60/51 rpms, 320 gpm, 200 diff. 10 07:00 10:00 3.00 5.00 Dir Sliding 7,142 7,148 Slide 6', 56 rpms, 350 gpm, 350 diff. 2 10:00 11:00 1.00 6.00 C&C Hole/Mud 7,148 7,148 Circulate bottoms up.

11:00 16:00 5.00 11.00 Trip for Bit 7,148 7,148 Pump out 5 joints/TFB # 10. 16:00 18:00 2.00 13.00 Trip for Bit 7,148 7,148 Change out bit and motor and test. 18:00 21:30 3.50 16.50 Trip for Bit 7,148 7,148 TIH with bit # 11. 21:30 23:00 1.50 18.00 Excess Ream 7,148 7,148 Wash to bottom, 7015'-7148', (133')

23:00 00:00 1.00 19.00 Dir Rotate 7,148 7,154 Rotate 5', 55/96 rpms, 320 gpm, 120 diff, breaking bit in. 6

00:00 02:30 2.50 21.50 Dir Sliding 7,154 7,166 Slide 12', 106 rpms, 350 gpm, 200 diff. 4.8 02:30 03:00 0.50 22.00 Dir Rotate 7,166 7,173 Rotate 7', 55/96 rpms, 320 gpm, 140 diff. 14 03:00 03:30 0.50 22.50 Srvys 7,173 7,173 Check shot @ 7133', 4.0 inc, 219.0 AZI. 03:30 05:00 1.50 24.00 Dir Sliding 7,173 7,185 Slide 12', 106 rpms, 350 gpm, 185 diff. 8



### Air/Mud Data MW (lb/gal) 11.30 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 28 Gel 10 sec 8 Gel 10 min 15 Gel 30 min 18 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.3 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

170,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.63 LCM

Hole Volume (bbl) 566.1 Pit Volume (bbl) 328.0 Storage Volume (bbl) 290.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7140 90 10 10 7148 80 10 10 13 7148 80 10 10 13 16 45 24 hr max 19 units @ 7111'
7160 90 10 14 7180 100 13 13 47 24 hr max 47 units @ 7148'.



### Bit Run # 11 Size (in)

8 3/4 Model GX-22 Make Hughes SN 6049619 Jets (/32") 16/16/16 In (ftKB) 7,148 Out (ftKB) 7,494 Drld (ftKB) 346 Drl Hrs (hrs) 32.50 ROP (ft/hr) 10.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 4 RG G E 1 WT PR WOB (min) (1000lbf) 44 WOB (max) (1000lbf) 48 BHA ROP (ft/hr) 11 SPP (psi) 185.0 Motor RPM (rpm) 96 RPM (rpm)

PU (max) (1000lbf) 200 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 130 Drag (1000lbf) 45 Start (ftKB) 7,148 End (ftKB) 7,185 

### Bit Run # 10 Size (in)

8 3/4 Model FHi23VPS Make Smith SN PN0921 Jets (/32") 16/16/16 In (ftKB) 6,909 Out (ftKB) 7,148 Drld (ftKB) 239 Drl Hrs (hrs) 30.50 ROP (ft/hr) 7.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 WT PR WOB (min) (1000lbf) 31 WOB (max) (1000lbf) 37 BHA ROP (ft/hr) 8 SPP (psi) 250.0 Motor RPM (rpm) 56 RPM (rpm) 0 PU (max) (1000lbf) 175 SO (1000lbf) 110 Off-Btm Str Wt (1000lbf) 130 Drag (1000lbf) 45 Start (ftKB) 7,130 End (ftKB) 7,148 

### Bit Run # 9 Size (in)

8 3/4 Model FHI23VPS Make Smith SN PN0922 Jets (/32") 16/16/16 In (ftKB) 6,623 Out (ftKB) 6,909 Drld (ftKB) 286 Drl Hrs (hrs) 20.00 ROP (ft/hr) 14.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 ER BHA Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 6,344 0.05 278.00 6,459 1.00 294.80 6,534 2.50 245.30 6,630 0.60 332.30 6,725 3.30 315.00 6,820 5.10 274.40 6,912 5.10 322.90 7,007 3.30 261.80 7,102 4.90 233.60 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #11, 8 3/4 Steerable BHA No. 11 Drill String Name 8 3/4 Steerable Length (ft) 793.03 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 107.00 123.23 1 Jars -

Hydraulic 6 1/2 107.00 31.72

19 DC 6 1/2 107.00 580.03

1 DC 6 1/2 107.00 31.12 1 UBHO 6 1/2 107.00 2.63 1 Great White 2.12 0.30 6 3/4 32.50 23.30 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 201 4.50 16.60 X-95 XH 7,160 

### Diesel Fuel Received Used 933 Cum On Location 2007 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,830 Stroke (in) 9.00 Slow ... Yes SPM (spm) 62 Q (gpm) 195 Pres (psi) 630 Stroke (in) 9.00 Slow ... Yes Costs Daily Cost Total 27,734 Field Est To Date 1,223,158 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/10/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 7,130 Footage (ftKB) 178 Drill Hrs (hrs) 20.00 Avg ROP (ft/hr) 8.9 DFS 22

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 7130 Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Rtn. Maint. 6,952 6,952 Service rig 05:30 06:00 0.50 1.00 Srvys 6,952 6,952 Survey @ 6912', 5.1 inc, 322.9 AZI. 06:00 08:00 2.00 3.00 Dir Rotate 6,952 6,983 Rotate 31', 60/51 rpms, 320 gpm, 195 diff. 15.5 08:00 08:30 0.50 3.50 Srvys 6,983 6,983 Check shot @ 6943', 3.6 inc, 331.4 AZI. 08:30 11:00 2.50 6.00 Dir Rotate 6,983 7,015 Rotate 32', 60/51 rpms, 320 gpm, 200 diff. 12.8 11:00 11:30 0.50 6.50 Rtn. Maint. 7,015 7,015 Service rig 11:30 12:00 0.50 7.00 Srvys 7,015 7,015 Check shot @ 6975', 2.9 inc, 304.0 AZI. 12:00 14:00 2.00 9.00 Dir Sliding 7,015 7,030 Slide 15', 56 rpms, 350 gpm, 250 diff. 7.5 14:00 15:30 1.50 10.50 Dir Rotate 7,030 7,047 Rotate 17', 60/51 rpms, 320 gpm, 200 diff. 11.3 15:30 16:00 0.50 11.00 Srvys 7,047 7,047 Survey @ 7007', 3.3 inc, 261.8 AZI. 16:00 16:30 0.50 11.50 Dir Sliding 7,047 7,049 Slide 2', 56 rpms, 350 gpm, 250 diff. 4 16:30 18:30 2.00 13.50 Dir Rotate 7,049 7,078 Rotate 29', 60/51 rpms, 320 gpm, 200 diff. 14.5 18:30 19:00 0.50 14.00 Srvys 7,078 7,078 Check shot @ 7038', 4.6 inc, 242.6 AZI. 19:00 23:30 4.50 18.50 Dir Sliding 7,078 7,098 Slide 20', 56 rpms, 350 gpm, 150 diff. 4.4 23:30 01:30 2.00 20.50 Dir Rotate 7,098 7,110 Rotate 12', 60/51 rpms, 320 gpm, 200 diff. 10 01:30 02:00 0.50 21.00 Srvys 7,110 7,110 Check shot @ 7070', 5.4 inc, 240.6 AZI. 02:00 05:00 3.00 24.00 Dir Sliding 7,110 7,130 Slide 20', 56 rpms, 350 gpm, 210 diff. 6.7



### Air/Mud Data MW (lb/gal) 11.30 Vis (s/qt) 44 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 8 Gel 10 min 13 Gel 30 min 18 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.4 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

170,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.55 LCM

Hole Volume (bbl) 559.8 Pit Volume (bbl) 364.0 Storage Volume (bbl) 240.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 7010 100 8 8 24 hr max 45 units @ 6852'
7060 60 10 5 7080 90 10 4 7100 80 20 7 7120 80 20 13 16 24 hr max 19 units @ 7111'



### Bit Run # 10 Size (in)

8 3/4 Model FHi23VPS Make Smith SN PN0921 Jets (/32") 16/16/16 In (ftKB) 6,909 Out (ftKB) 7,148 Drld (ftKB) 239 Drl Hrs (hrs) 30.50 ROP (ft/hr) 7.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 WT PR WOB (min) (1000lbf) 31 WOB (max) (1000lbf) 37 BHA ROP (ft/hr) 8 SPP (psi) 250.0 Motor RPM (rpm) 56 RPM (rpm) 0 PU (max) (1000lbf) 175 SO (1000lbf) 110 Off-Btm Str Wt (1000lbf) 130 Drag (1000lbf) 45 Start (ftKB) 6,952 End (ftKB) 7,130 

### Bit Run # 9 Size (in)

8 3/4 Model FHI23VPS Make Smith SN PN0922 Jets (/32") 16/16/16 In (ftKB) 6,623 Out (ftKB) 6,909 Drld (ftKB) 286 Drl Hrs (hrs) 20.00 ROP (ft/hr) 14.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 ER BHA 

### Bit Run # 8 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124580 Jets (/32")

12/12/12/12/12/12/12 In (ftKB) 6,253 Out (ftKB) 6,623 Drld (ftKB) 370 Drl Hrs (hrs) 24.00 ROP (ft/hr) 15.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 BT A X 0 CT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 6,344 0.05 278.00 6,459 1.00 294.80 6,534 2.50 245.30 6,630 0.60 332.30 6,725 3.30 315.00 6,820 5.10 274.40 6,912 5.10 322.90 7,007 3.30 261.80 7,102 4.90 233.60 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #10, 8 3/4 Steerable BHA No. 10 Drill String Name 8 3/4 Steerable Length (ft) 793.06 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 74.50 123.23 1 Jars -

Hydraulic 6 1/2 74.50 31.72

19 DC 6 1/2 74.50 580.03

1 DC 6 1/2 74.50 31.12 1 UBHO 6 1/2 74.50 2.63 1 Great White 2.12 0.16 6 3/4 30.50 23.33 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 199 4.50 16.60 X-95 XH 6,304 

### Diesel Fuel Received Used 977 Cum On Location 2940 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 67 Q (gpm) 210 Pres (psi) 600 Stroke (in) 9.00 Slow ... Yes SPM (spm) 112 Q (gpm) 352 Pres (psi) 1,850 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 37,962 Field Est To Date 1,195,424 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/9/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 6,952 Footage (ftKB) 99 Drill Hrs (hrs) 10.00 Avg ROP (ft/hr) 9.9 DFS 21

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 6952'. Planned Operations Dir drlg w/surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Dir Rotate 6,853 6,865 Dir rotate 12', 35 wob, 50/77 rpms, 320 gpm, @ 1800 psi, 300 diff. 24

05:30 06:00 0.50 1.00 Srvys 6,865 6,865 Survey @ 6820', 5.1 inc, 274.4 AZI. 06:00 08:00 2.00 3.00 Dir Sliding 6,865 6,890 Slide 25', 37 wob, 84 rpms, 350 gpm, @ 1940 psi, 340 diff. 12.5

08:00 08:30 0.50 3.50 Dir Rotate 6,890 6,897 Dir rotate 7', 35 wob, 50/77 rpms, 320 gpm, @ 1800 psi, 300 diff. 14

08:30 09:30 1.00 4.50 Dir Sliding 6,897 6,909 Slide 12', 37 wob, 84 rpms, 350 gpm, @ 1940 psi, 340 diff. 12

09:30 10:30 1.00 5.50 C&C Hole/Mud 6,909 6,909 Circulate bottoms up.

10:30 14:30 4.00 9.50 Trip - Other 6,909 6,909 Pump out 4 joints/TOH 14:30 17:00 2.50 12.00 Trip - Other 6,909 6,909 Lay down motor and bit/pick up new motor 2.12, and test same. 17:00 17:30 0.50 12.50 Rtn. Maint. 6,909 6,909 Service rig. 17:30 21:00 3.50 16.00 Trip - Other 6,909 6,909 TIH with bit # 10. 21:00 22:30 1.50 17.50 Excess Ream 6,909 6,909 Wash to bottom, 6793'-6909', (116').

22:30 23:00 0.50 18.00 Dir Rotate 6,909 6,914 Dir rotate 5', 35 wob, 55/51 rpms, 320 gpm, @ 1500 psi, 190 diff. 10

23:00 01:00 2.00 20.00 Dir Sliding 6,914 6,930 Slide 16', 37 wob, 56 rpms, 350 gpm, @ 1700 psi, 210 diff. 8

01:00 01:30 0.50 20.50 Srvys 6,930 6,930 Check shot @ 6890', 6.0 inc,303.9 AZI. 01:30 04:00 2.50 23.00 Dir Sliding 6,930 6,940 Slide 10', 37 wob, 56 rpms, 350 gpm, @ 1700 psi, 210 diff. 4

04:00 05:00 1.00 24.00 Dir Rotate 6,940 6,952 Dir rotate 12', 35 wob, 60/51 rpms, 320 gpm, @ 1500 psi, 190 diff. 12



### Air/Mud Data MW (lb/gal) 11.20 Vis (s/qt) 46 PV (cp) 20.0 YP (lbf/100ft2) 27 Gel 10 sec 8 Gel 10 min 13 Gel 30 min 17 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.5 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

172,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.66 LCM

Hole Volume (bbl) 547.2 Pit Volume (bbl) 333.0 Storage Volume (bbl) 100.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 6909 100 8 21 7 24 hr max 8 units @ 6852'
6910 100 6 6920 100 8 6930 100 10 6940 100 8 8 45 24 hr max 45 units @ 6852'



### Bit Run # 10 Size (in)

8 3/4 Model FHi23VPS Make Smith SN PN0921 Jets (/32") 16/16/16 In (ftKB) 6,909 Out (ftKB) 7,148 Drld (ftKB) 239 Drl Hrs (hrs) 30.50 ROP (ft/hr) 7.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 WT PR WOB (min) (1000lbf) 31 WOB (max) (1000lbf) 37 BHA ROP (ft/hr) 8 SPP (psi) 190.0 Motor RPM (rpm) 51 RPM (rpm) 60 PU (max) (1000lbf) 175 SO (1000lbf) 110 Off-Btm Str Wt (1000lbf) 125 Drag (1000lbf) 35 Start (ftKB) 6,909 End (ftKB) 6,952 

### Bit Run # 9 Size (in)

8 3/4 Model FHI23VPS Make Smith SN PN0922 Jets (/32") 16/16/16 In (ftKB) 6,623 Out (ftKB) 6,909 Drld (ftKB) 286 Drl Hrs (hrs) 20.00 ROP (ft/hr) 14.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 ER BHA WOB (min) (1000lbf) 32 WOB (max) (1000lbf) 37 BHA ROP (ft/hr) 14 SPP (psi) 300.0 Motor RPM (rpm) 84 RPM (rpm)

PU (max) (1000lbf) 155 SO (1000lbf) 110 Off-Btm Str Wt (1000lbf) 125 Drag (1000lbf) 30 Start (ftKB) 6,853 End (ftKB) 6,909 

### Bit Run # 8 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124580 Jets (/32")

12/12/12/12/12/12/12 In (ftKB) 6,253 Out (ftKB) 6,623 Drld (ftKB) 370 Drl Hrs (hrs) 24.00 ROP (ft/hr) 15.4 Survey Data MD (ftKB) Incl (°) Azm (°) 6,149 2.90 329.20 6,249 3.90 319.00 6,344 0.05 278.00 6,459 1.00 294.80 6,534 2.50 245.30 6,630 0.60 332.30 6,725 3.30 315.00 6,820 5.10 274.40 6,912 5.10 322.90 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #10, 8 3/4 Steerable BHA No. 10 Drill String Name 8 3/4 Steerable Length (ft) 793.06 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 74.50 123.23 1 Jars -

Hydraulic 6 1/2 74.50 31.72

19 DC 6 1/2 74.50 580.03

1 DC 6 1/2 74.50 31.12 1 UBHO 6 1/2 74.50 2.63 1 Great White 2.12 0.16 6 3/4 30.50 23.33 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 193 4.50 16.60 X-95 XH 6,113 

### Diesel Fuel Received Used 767 Cum On Location 3917 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,500 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 30,216 Field Est To Date 1,157,462 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/9/2009 Spud Date: 10/19/2009

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 BT A X 0 CT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/8/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 6,853 Footage (ftKB) 230 Drill Hrs (hrs) 16.00 Avg ROP (ft/hr) 14.4 DFS 20

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 6853'. Planned Operations Dir drlg w/surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:30 2.50 2.50 Excess Ream 6,623 6,623 Ream tight spots @ 4870'/4810'/5110'.

07:30 08:30 1.00 3.50 Trip for Bit 6,623 6,623 TIH. 08:30 10:30 2.00 5.50 Excess Ream 6,623 6,623 Wash to bottom, 6580'-6623',(43')

10:30 11:00 0.50 6.00 Dir Rotate 6,623 6,628 Dir rotate 5', 25 wob, 55/77 rpms, 320 gpm, @ 1800 psi, 200 diff. 10

11:00 13:00 2.00 8.00 Dir Sliding 6,628 6,643 Slide 15', 33-35 wob, 84 rpms, 350 gpm, @ 1900 psi, 300 diff. 7.5

13:00 13:30 0.50 8.50 Srvys 6,643 6,643 Check shot @ 6598', 2.1 inc, 228.7 AZI. 13:30 15:00 1.50 10.00 Dir Rotate 6,643 6,675 Dir rotate 32', 35 wob, 50/77 rpms, 320 gpm, @ 1850 psi, 300 diff. 21.3

15:00 15:30 0.50 10.50 Srvys 6,675 6,675 Check shot @ 6628', .6 inc, 332.3 15:30 17:30 2.00 12.50 Dir Rotate 6,675 6,707 Dir rotate 32', 35 wob, 50/77 rpms, 320 gpm, @ 1850 psi, 300 diff. 16

17:30 18:00 0.50 13.00 Rtn. Maint. 6,707 6,707 Service rig 18:00 19:30 1.50 14.50 Dir Rotate 6,707 6,738 Dir rotate 31', 35 wob, 50/77 rpms, 320 gpm, @ 1850 psi, 300 diff. 20.7

19:30 21:00 1.50 16.00 Dir Sliding 6,738 6,751 Slide 13', 33-35 wob, 84 rpms, 350 gpm, @ 2100 psi, 300 diff. 8.7

21:00 21:30 0.50 16.50 Dir Rotate 6,751 6,770 Dir rotate 19', 35 wob, 50/77 rpms, 320 gpm, @ 1950 psi, 300 diff. 38

21:30 22:00 0.50 17.00 Srvys 6,770 6,770 Survey @ 6725', 3.3 inc, 315.0 AZI. 22:00 22:30 0.50 17.50 Rtn. Maint. 6,770 6,770 Service rig 22:30 00:00 1.50 19.00 Dir Rotate 6,770 6,802 Dir rotate 32', 35 wob, 50/77 rpms, 320 gpm, @ 1950 psi, 300 diff. 21.3

00:00 02:00 2.00 21.00 Dir Sliding 6,802 6,822 Slide 20', 33 wob, 84 rpms, 350 gpm, @ 2200 psi, 300 diff. 10

02:00 03:00 1.00 22.00 Dir Rotate 6,822 6,833 Dir rotate 11', 35 wob, 50/77 rpms, 320 gpm, @ 1700 psi, 300 diff. 11

03:00 05:00 2.00 24.00 Dir Sliding 6,833 6,853 Slide 20', 33 wob, 84 rpms, 350 gpm, @ 2200 psi, 300 diff. 10



### Air/Mud Data MW (lb/gal) 11.30 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 8 Gel 10 min 13 Gel 30 min 17 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.5 Solids (%) 17 LGS (%) 4 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

172,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 11.69 LCM

Hole Volume (bbl) 528.3 Pit Volume (bbl) 331.0 Storage Volume (bbl) 100.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 6630 60 40 25 21 22 24 hr max 67 units @ 6618'
6800 80 20 30 6810 50 50 9 6820 60 40 5 6830 30 70 8 21 24 hr max 31 units @ 6688'



### Bit Run # 9 Size (in)

8 3/4 Model FHI23VPS Make Smith SN PN0922 Jets (/32") 16/16/16 In (ftKB) 6,623 Out (ftKB) 6,909 Drld (ftKB) 286 Drl Hrs (hrs) 20.00 ROP (ft/hr) 14.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 2 BT A E 0 ER BHA WOB (min) (1000lbf) 32 WOB (max) (1000lbf) 37 BHA ROP (ft/hr) 14 SPP (psi) 300.0 Motor RPM (rpm) 84 RPM (rpm)

PU (max) (1000lbf) 155 SO (1000lbf) 110 Off-Btm Str Wt (1000lbf) 125 Drag (1000lbf) 30 Start (ftKB) 6,623 End (ftKB) 6,853 

### Bit Run # 8 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124580 Jets (/32")

12/12/12/12/12/12/12 In (ftKB) 6,253 Out (ftKB) 6,623 Drld (ftKB) 370 Drl Hrs (hrs) 24.00 ROP (ft/hr) 15.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 BT A X 0 CT PR 

### Bit Run # 7 Size (in)

8 3/4 Model QD505 Make Hughes SN 7124887 Jets (/32")

13/13/13/13/13/13/13 In (ftKB) 5,750 Out (ftKB) 6,253 Drld (ftKB) 503 Drl Hrs (hrs) 29.00 ROP (ft/hr) 17.3 Survey Data MD (ftKB) Incl (°) Azm (°) 6,054 1.60 324.90 6,149 2.90 329.20 6,249 3.90 319.00 6,344 0.05 278.00 6,459 1.00 294.80 6,534 2.50 245.30 6,630 0.60 332.30 6,725 3.30 315.00 6,820 5.10 274.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #9, 8 3/4 Steerable BHA No. 9 Drill String Name 8 3/4 Steerable Length (ft) 801.68 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 44.00 123.23 1 Jars -

Hydraulic 6 1/2 44.00 31.72

19 DC 6 1/2 44.00 580.03

1 DC 6 1/2 44.00 31.12 1 UBHO 6 1/2 44.00 2.63 1 Great White 1.83 0.24 6 3/4 44.00 31.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 190 4.50 16.60 X-95 XH 6,019 

### Diesel Fuel Received Used 966 Cum On Location 4684 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 66 Q (gpm) 207 Pres (psi) 600 Stroke (in) 9.00 Slow ... Yes SPM (spm) 114 Q (gpm) 358 Pres (psi) 2,200 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 36,729 Field Est To Date 1,127,245 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/8/2009 Spud Date: 10/19/2009

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 3 CT G X 0 WT DMF Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/7/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 6,623 Footage (ftKB) 108 Drill Hrs (hrs) 11.50 Avg ROP (ft/hr) 9.4 DFS 19

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg to 6623'/Trip for bit # 8 Planned Operations Finish trip and Dir drlg w/survey Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:30 1.50 1.50 Dir Rotate 6,515 6,547 Dir rotate 32', 10 wob, 55/77 rpms, 320 gpm, @ 1450 psi, 145 diff. 21.3

06:30 10:30 4.00 5.50 Dir Sliding 6,547 6,558 Slide 11', 23 wob, 84 rpms, 348 gpm, @ 1450 psi, 250 diff. 2.8

10:30 11:30 1.00 6.50 Dir Rotate 6,558 6,579 Dir rotate 21', 10 wob, 55/77 rpms, 320 gpm, @ 1475 psi, 200 diff. 21

11:30 12:00 0.50 7.00 Rtn. Maint. 6,579 6,579 Service rig 12:00 13:00 1.00 8.00 Dir Rotate 6,579 6,599 Dir rotate 20', 10 wob, 55/77 rpms, 320 gpm, @ 1465 psi, 260 diff. 20

13:00 13:30 0.50 8.50 Srvys 6,599 6,599 Check shot @ 6551', 2.9 inc, 234.4 AZI. 13:30 17:00 3.50 12.00 Dir Sliding 6,599 6,611 Slide 12', 23 wob, 84 rpms, 348 gpm, @ 1550 psi, 250 diff. 3.4

17:00 17:30 0.50 12.50 Srvys 6,611 6,611 Check shot @ 6563',2.9 inc, 232.8 AZI. 17:30 18:00 0.50 13.00 Dir Rotate 6,611 6,623 Dir rotate 12', 10 wob, 55/77 rpms, 320 gpm, @ 1560 psi, 260 diff. 24

18:00 18:30 0.50 13.50 Srvys 6,623 6,623 Check shot @ 6578', 3.0 inc, 228.8 AZI. 18:30 19:30 1.00 14.50 C&C Hole/Mud 6,623 6,623 Circulate bottoms up.

19:30 22:30 3.00 17.50 Trip for Bit 6,623 6,623 Pump out 4 jts/TOH for bit # 8 22:30 01:00 2.50 20.00 Trip for Bit 6,623 6,623 Change bits/test motor and tool. 01:00 05:00 4.00 24.00 Trip for Bit 6,623 6,623 TIH with bit # 9/tight @ 4870' and 4810'/pick up kelly.



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 44 PV (cp) 18.0 YP (lbf/100ft2) 26 Gel 10 sec 8 Gel 10 min 11 Gel 30 min 15 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.4 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 0 H20 (%) 84 Chlor (mg/L)

171,000 Ca (mg/L) 420 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.48 LCM

Hole Volume (bbl) 522.1 Pit Volume (bbl) 406.0 Storage Volume (bbl) 25.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 6590 40 50 10 19 25 24 hr max 50 units @ 6446' 6590 40 50 10 27 6600 40 50 10 23 6610 50 50 21 6623 60 40 19 21 22 24 hr max 50 units @ 6460'



### Bit Run # 8 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124580 Jets (/32")

12/12/12/12/12/12/12 In (ftKB) 6,253 Out (ftKB) 6,623 Drld (ftKB) 370 Drl Hrs (hrs) 24.00 ROP (ft/hr) 15.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 BT A X 0 CT PR WOB (min) (1000lbf) 1 WOB (max) (1000lbf) 1 BHA ROP (ft/hr) 15 SPP (psi) 145.0 Motor RPM (rpm) 77 RPM (rpm) 55 PU (max) (1000lbf) 140 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 120 Drag (1000lbf) 20 Start (ftKB) 6,515 End (ftKB) 6,623 

### Bit Run # 7 Size (in)

8 3/4 Model QD505 Make Hughes SN 7124887 Jets (/32")

13/13/13/13/13/13/13 In (ftKB) 5,750 Out (ftKB) 6,253 Drld (ftKB) 503 Drl Hrs (hrs) 29.00 ROP (ft/hr) 17.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 3 CT G X 0 WT DMF 

### Bit Run # 6 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7125020 Jets (/32")

14/14/14/14/14/14/14 In (ftKB) 4,930 Out (ftKB) 5,750 Drld (ftKB) 820 Drl Hrs (hrs) 47.00 ROP (ft/hr) 17.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 WT S X 0 CT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 5,769 2.50 336.10 5,864 1.60 305.10 5,959 2.10 324.70 6,054 1.60 324.90 6,149 2.90 329.20 6,249 3.90 319.00 6,344 0.05 278.00 6,459 1.00 294.80 6,534 2.50 245.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #8, 8 3/4 Steerable BHA No. 8 Drill String Name 8 3/4 Steerable Length (ft) 801.68 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 24.00 123.23 1 Jars -

Hydraulic 6 1/2 24.00 31.72

19 DC 6 1/2 24.00 580.03

1 DC 6 1/2 24.00 31.12 1 UBHO 6 1/2 24.00 2.63 1 Great White 1.83 0.24 6 3/4 24.00 31.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 183 4.50 16.60 X-95 XH 5,797 

### Diesel Fuel Received Used 715 Cum On Location 5650 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,560 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 28,178 Field Est To Date 1,090,517 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/6/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 6,515 Footage (ftKB) 262 Drill Hrs (hrs) 12.50 Avg ROP (ft/hr) 21.0 DFS 18

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 6515'. Planned Operations Dir drlg w/surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 09:30 4.50 4.50 Rtn. Maint. 6,253 6,253 Cut drilling line. 09:30 10:00 0.50 5.00 Rtn. Maint. 6,253 6,253 Service rig. 10:00 10:30 0.50 5.50 C&C Hole/Mud 6,253 6,253 Break circulation.

10:30 13:00 2.50 8.00 Trip - Other 6,253 6,253 TIH with bit # 8. 13:00 14:30 1.50 9.50 Excess Ream 6,253 6,253 Wash to bottom/ 6167'-6253', (86').

14:30 15:00 0.50 10.00 Dir Rotate 6,253 6,262 Dir rotate 9', 8-9 wob, 55/77, 320 gpm, @ 1500 psi, 110 diff. 18

15:00 15:30 0.50 10.50 Srvys 6,262 6,262 Check shot @ 6217', 3.6 inc, 316.8 AZI. 15:30 17:30 2.00 12.50 Dir Sliding 6,262 6,277 Slide 15', 23 wob, 84 rpms, 348 gpm, @ 1480 psi, 280 diff. 7.5

17:30 18:30 1.00 13.50 Dir Rotate 6,277 6,294 Dir rotate 17', 10 wob, 55/77, 320 gpm, @ 1500 psi, 160 diff. 17

18:30 19:00 0.50 14.00 Srvys 6,294 6,294 Survey @ 6249', 3.9 inc, 319.0 AZI. 19:00 20:30 1.50 15.50 Dir Sliding 6,294 6,306 Slide 12', 23 wob, 84 rpms, 348 gpm, @ 1480 psi, 280 diff. 8

20:30 23:30 3.00 18.50 Dir Rotate 6,306 6,389 Dir rotate 83', 10 wob, 55/77, 320 gpm, @ 1500 psi, 160 diff. 27.7

23:30 00:00 0.50 19.00 Rtn. Maint. 6,389 6,389 Service rig 00:00 03:30 3.50 22.50 Dir Rotate 6,389 6,484 Dir rotate 95', 10 wob, 55/77, 320 gpm, @ 1465 psi, 145 diff. 27.1

03:30 04:00 0.50 23.00 Srvys 6,484 6,484 Survey @ 6459', 1 inc, 298.4 AZI. 04:00 05:00 1.00 24.00 Dir Rotate 6,484 6,515 Dir rotate 31', 10 wob, 55/77, 320 gpm, @ 1465 psi, 145 diff. 31



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 48 PV (cp) 20.0 YP (lbf/100ft2) 27 Gel 10 sec 9 Gel 10 min 14 Gel 30 min 17 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.6 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 0 H20 (%) 84 Chlor (mg/L)

170,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 11.46 LCM

Hole Volume (bbl) 496.9 Pit Volume (bbl) 242.0 Storage Volume (bbl) 200.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 6250 90 10 21 12 22 24 hr max 112 units @ 6236'
6400 80 20 19 6430 70 30 17 6460 40 50 10 25 6490 40 40 20 18 25 24 hr max 50 units @ 6446'



### Bit Run # 8 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124580 Jets (/32")

12/12/12/12/12/12/12 In (ftKB) 6,253 Out (ftKB) 6,623 Drld (ftKB) 370 Drl Hrs (hrs) 24.00 ROP (ft/hr) 15.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 BT A X 0 CT PR WOB (min) (1000lbf) 1 WOB (max) (1000lbf) 1 BHA ROP (ft/hr) 15 SPP (psi) 145.0 Motor RPM (rpm) 77 RPM (rpm) 55 PU (max) (1000lbf) 140 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 120 Drag (1000lbf) 20 Start (ftKB) 6,253 End (ftKB) 6,515 

### Bit Run # 7 Size (in)

8 3/4 Model QD505 Make Hughes SN 7124887 Jets (/32")

13/13/13/13/13/13/13 In (ftKB) 5,750 Out (ftKB) 6,253 Drld (ftKB) 503 Drl Hrs (hrs) 29.00 ROP (ft/hr) 17.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 3 CT G X 0 WT DMF 

### Bit Run # 6 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7125020 Jets (/32")

14/14/14/14/14/14/14 In (ftKB) 4,930 Out (ftKB) 5,750 Drld (ftKB) 820 Drl Hrs (hrs) 47.00 ROP (ft/hr) 17.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 WT S X 0 CT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 5,678 2.50 343.20 5,769 2.50 336.10 5,864 1.60 305.10 5,959 2.10 324.70 6,054 1.60 324.90 6,149 2.90 329.20 6,249 3.90 319.00 6,344 0.05 278.00 6,459 1.00 294.80 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #8, 8 3/4 Steerable BHA No. 8 Drill String Name 8 3/4 Steerable Length (ft) 801.68 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 24.00 123.23 1 Jars -

Hydraulic 6 1/2 24.00 31.72

19 DC 6 1/2 24.00 580.03

1 DC 6 1/2 24.00 31.12 1 UBHO 6 1/2 24.00 2.63 1 Great White 1.83 0.24 6 3/4 24.00 31.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 179 4.50 16.60 X-95 XH 5,670 

### Diesel Fuel Received Used 834 Cum On Location 6365 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,400 Stroke (in) 9.00 Slow ... No SPM (spm) 68 Q (gpm) 214 Pres (psi) 600 Stroke (in) 9.00 Slow ... Yes Costs Daily Cost Total 42,494 Field Est To Date 1,062,339 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/5/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 6,253 Footage (ftKB) 217 Drill Hrs (hrs) 10.50 Avg ROP (ft/hr) 20.7 DFS 17

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg to 6253'/Trip. Planned Operations Finish trip and Dir drlg w/surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:00 1.00 1.00 Dir Sliding 6,036 6,046 Slide 10', 8 wob, 106 rpms, 351 gpm, @ 1300 psi, 200 diff. 10

06:00 07:00 1.00 2.00 Dir Rotate 6,046 6,095 Dir rotate 49', wob 8k, 55/95 rpms, 320 gpm, @ 1225 psi, 190 diff. 49

07:00 07:30 0.50 2.50 Srvys 6,095 6,095 Survey @ 6054', 1.6 inc, 347.6 AZI. 07:30 11:00 3.50 6.00 Dir Rotate 6,095 6,163 Dir rotate 68', wob 8k, 55/95 rpms, 320 gpm, @ 1225 psi, 190 diff. 19.4

11:00 12:00 1.00 7.00 Dir Sliding 6,163 6,165 Slide 2', 8 wob, 106 rpms, 351 gpm, @ 1300 psi, 200 diff. 2

12:00 16:00 4.00 11.00 Dir Rotate 6,165 6,253 Dir rotate 88', wob 8k, 55/95 rpms, 320 gpm, @ 1360 psi, 170 diff. 22

16:00 17:00 1.00 12.00 C&C Hole/Mud 6,253 6,253 Circulate bottoms up.

17:00 21:00 4.00 16.00 Trip - Other 6,253 6,253 Trip for motor. 21:00 01:30 4.50 20.50 Trip - Other 6,253 6,253 Trip check collars/Change motor, Jars, 1 DC, and bit. 01:30 03:30 2.00 22.50 Trip - Other 6,253 6,253 Pick up motor and MWD/test/TIH with DCs. 03:30 04:00 0.50 23.00 Rtn. Maint. 6,253 6,253 Service rig 04:00 05:00 1.00 24.00 Rtn. Maint. 6,253 6,253 Cut drilling line



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 44 PV (cp) 17.0 YP (lbf/100ft2) 25 Gel 10 sec 7 Gel 10 min 11 Gel 30 min 14 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.6 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 0 H20 (%) 84 Chlor (mg/L)

174,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 11.56 LCM

Hole Volume (bbl) 415.1 Pit Volume (bbl) 311.0 Storage Volume (bbl) 188.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 6160 100 10 12 24 hr max 82 units @ 5994'
6220 100 21 6230 90 10 82 6240 90 10 23 6250 90 10 21 12 12 24 hr max 112 units @ 6236'



### Bit Run # 7 Size (in)

8 3/4 Model QD505 Make Hughes SN 7124887 Jets (/32")

13/13/13/13/13/13/13 In (ftKB) 5,750 Out (ftKB) 6,253 Drld (ftKB) 503 Drl Hrs (hrs) 29.00 ROP (ft/hr) 17.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 3 CT G X 0 WT DMF WOB (min) (1000lbf) 8 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 17 SPP (psi) 190.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 135 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 115 Drag (1000lbf) 20 Start (ftKB) 6,036 End (ftKB) 6,253 

### Bit Run # 6 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7125020 Jets (/32")

14/14/14/14/14/14/14 In (ftKB) 4,930 Out (ftKB) 5,750 Drld (ftKB) 820 Drl Hrs (hrs) 47.00 ROP (ft/hr) 17.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 WT S X 0 CT PR 

### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 5,487 2.50 5.30 5,582 2.60 12.60 5,678 2.50 343.20 5,769 2.50 336.10 5,864 1.60 305.10 5,959 2.10 324.70 6,054 1.60 324.90 6,149 2.90 329.20 6,249 3.90 319.00 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #7, 8 3/4 Steerable BHA No. 7 Drill String Name 8 3/4 Steerable Length (ft) 791.70 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 198.50 123.23 1 Jars -

Hydraulic 6 1/2 215.00 32.23

19 DC 6 1/2 198.00 579.03

1 DC 6 1/2 123.00 31.12 1 UBHO 6 1/2 123.00 2.63 1 Great White 1.83 0.30 6 1/2 29.00 22.46 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 171 4.50 16.60 X-95 XH 5,416 

### Diesel Fuel Received 6,000.0 Used 578 Cum On Location 7199 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,400 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 49,185 Field Est To Date 1,019,845 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/4/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 6,036 Footage (ftKB) 286 Drill Hrs (hrs) 18.50 Avg ROP (ft/hr) 15.5 DFS 16

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 6036' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:30 2.50 2.50 Trip for Bit 5,750 5,750 TIH with bit # 7 07:30 08:30 1.00 3.50 Excess Ream 5,750 5,750 Wash to bottom, 5655'-5750', (95')

08:30 09:30 1.00 4.50 Dir Rotate 5,750 5,760 Dir rotate 10', 8 wob, 55/95 rpms, 320 gpm, @ 1350 psi, 170 diff. 10

09:30 12:00 2.50 7.00 Dir Sliding 5,760 5,775 Slide 15', 12 wob, 104 rpms, 346 gpm, @ 1350 psi, 180 diff. 6

12:00 12:30 0.50 7.50 Srvys 5,775 5,775 Check shot @ 5737', 3.8 inc, 339.0 AZI. 12:30 13:30 1.00 8.50 Dir Rotate 5,775 5,797 Dir rotate 18', 8 wob, 55/95 rpms, 320 gpm, @ 1350 psi, 190 diff. 18

13:30 15:30 2.00 10.50 Dir Sliding 5,797 5,810 Slide 13', 10 wob, 104 rpms, 346 gpm, @ 1350 psi, 180 diff. 6.5

15:30 16:00 0.50 11.00 Rtn. Maint. 5,810 5,810 Service rig 16:00 17:30 1.50 12.50 Dir Rotate 5,810 5,857 Dir rotate 37', 8 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 290 diff. 24.7

17:30 18:00 0.50 13.00 Srvys 5,857 5,857 Check shot, 1.5 inc, 323.5 AZI. 18:00 18:30 0.50 13.50 Dir Sliding 5,857 5,859 Slide 2', 10 wob, 104 rpms, 346 gpm, @ 1300 psi, 125 diff. 4

18:30 19:30 1.00 14.50 Dir Rotate 5,859 5,873 Dir rotate 14', 8 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 14

19:30 21:30 2.00 16.50 Dir Sliding 5,873 5,876 Slide 3', 10 wob, 104 rpms, 346 gpm, 1175 psi, 125 diff. 1.5

21:30 22:00 0.50 17.00 Dir Rotate 5,876 5,881 Dir rotate 5', 8 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 10

22:00 23:00 1.00 18.00 Dir Sliding 5,881 5,884 Slide 3', 10 wob, 104 rpms, 346 gpm, 1175 psi, 125 diff. 3

23:00 23:30 0.50 18.50 Dir Rotate 5,884 5,905 Dir rotate 21', 8 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 42

23:30 02:30 3.00 21.50 Dir Rotate 5,905 6,000 Dir rotate 95', 8 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 31.7

02:30 03:00 0.50 22.00 Srvys 6,000 6,000 Check shot @ 5959', 2.1 inc, 324.9 AZI. 03:00 03:30 0.50 22.50 Dir Rotate 6,000 6,031 Dir rotate 31', 8 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff 62

03:30 05:00 1.50 24.00 Dir Sliding 6,031 6,036 Slide 5', 10 wob, 104 rpms, 346 gpm, 1150 psi, 115 diff. 3.3



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 45 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 11 Gel 30 min 15 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.9 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

174,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.58 LCM

Hole Volume (bbl) 383.7 Pit Volume (bbl) 346.0 Storage Volume (bbl) 100.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 5880 100 58 60 24 hr max 79 units @ 5764'
6000 100 75 6020 100 16 6030 100 30 6040 100 39 24 hr max 269 units @ 5906'



### Bit Run # 7 Size (in)

8 3/4 Model QD505 Make Hughes SN 7124887 Jets (/32")

13/13/13/13/13/13/13 In (ftKB) 5,750 Out (ftKB) 6,253 Drld (ftKB) 503 Drl Hrs (hrs) 29.00 ROP (ft/hr) 17.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 3 CT G X 0 WT DMF WOB (min) (1000lbf) 8 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 17 SPP (psi) 110.0 Motor RPM (rpm) 95 RPM (rpm)

PU (max) (1000lbf) 135 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 106 Drag (1000lbf) 20 Start (ftKB) 5,750 End (ftKB) 6,036 

### Bit Run # 6 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7125020 Jets (/32")

14/14/14/14/14/14/14 In (ftKB) 4,930 Out (ftKB) 5,750 Drld (ftKB) 820 Drl Hrs (hrs) 47.00 ROP (ft/hr) 17.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 WT S X 0 CT PR Survey Data MD (ftKB) Incl (°) Azm (°) 5,202 1.80 21.70 5,297 1.10 320.60 5,392 2.70 307.20 5,487 2.50 5.30 5,582 2.60 12.60 5,678 2.50 343.20 5,769 2.50 336.10 5,864 1.60 305.10 5,959 2.10 324.70 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #7, 8 3/4 Steerable BHA No. 7 Drill String Name 8 3/4 Steerable Length (ft) 791.70 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 198.50 123.23 1 Jars -

Hydraulic 6 1/2 215.00 32.23

19 DC 6 1/2 198.00 579.03

1 DC 6 1/2 123.00 31.12 1 UBHO 6 1/2 123.00 2.63 1 Great White 1.83 0.30 6 1/2 29.00 22.46 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 165 4.50 16.60 X-95 XH 5,181 

### Diesel Fuel Received Used 741 Cum On Location 1777 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,400 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 28,117 Field Est To Date 970,660 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/4/2009 Spud Date: 10/19/2009 

### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/3/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 5,750 Footage (ftKB) 271 Drill Hrs (hrs) 12.00 Avg ROP (ft/hr) 22.6 DFS 15

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 5750'/TIH with bit # 7 bit Planned Operations Finish trip and Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Rtn. Maint. 5,479 5,479 Service rig 05:30 06:30 1.00 1.50 Dir Sliding 5,479 5,485 Slide 6', 10 wob, 104 rpms, @ 1450 psi, 190 diff. 6

06:30 08:30 2.00 3.50 Dir Rotate 5,485 5,530 Dir rotate 45', 10 wob, 55/95 rpms, 320 gpm, @ 1375 psi, 180 diff. 08:30 09:00 0.50 4.00 Srvys 5,530 5,530 Survey @ 5487', 2.5 inc, 5.3 AZI. 09:00 10:30 1.50 5.50 Dir Sliding 5,530 5,537 Slide 7', 10 wob, 104 rpms, @ 1450 psi, 192 diff. 4.7

10:30 11:30 1.00 6.50 Dir Rotate 5,537 5,560 Dir rotate 23', 10 wob, 55/95 rpms, 320 gpm, @ 1400, 195 diff. 23

11:30 12:00 0.50 7.00 Srvys 5,560 5,560 Check shot @ 5519', 2.5 inc, 14.1 AZI. 12:00 13:30 1.50 8.50 Dir Rotate 5,560 5,623 Dir rotate 63', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 195 diff. 42

13:30 14:00 0.50 9.00 Rtn. Maint. 5,623 5,623 Service rig 14:00 16:30 2.50 11.50 Dir Rotate 5,623 5,687 Dir rotate 64', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 25.6

16:30 17:00 0.50 12.00 Srvys 5,687 5,687 Check shot @ 5646', 2.6 inc, 336.80 AZI. 17:00 19:30 2.50 14.50 Dir Rotate 5,687 5,750 Dir rotate 63', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 25.2

19:30 20:30 1.00 15.50 C&C Hole/Mud 5,750 5,750 Circulate bottoms up

20:30 01:00 4.50 20.00 Trip for Bit 5,750 5,750 Pump out 4 joints/TOH for bit # 6/strap out/SLM no corrections 01:00 03:30 2.50 22.50 Trip for Bit 5,750 5,750 Lay down motor and bit/pick up new and test 03:30 05:00 1.50 24.00 Trip for Bit 5,750 5,750 TIH with bit # 7



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 45 PV (cp) 17.0 YP (lbf/100ft2) 25 Gel 10 sec 8 Gel 10 min 10 Gel 30 min 12 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.3 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

174,000 Ca (mg/L) 520 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.56 LCM

Hole Volume (bbl) 377.4 Pit Volume (bbl) 320.0 Storage Volume (bbl) 220.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 5600 100 57 65 24 hr max 134 units @ 5510' 5690 100 35 5710 90 10 105 5730 100 95 5750 90 10 80 148 24 hr max 200 units @ 5724'



### Bit Run # 7 Size (in)

8 3/4 Model QD505 Make Hughes SN 7124887 Jets (/32")

13/13/13/13/13/13/13 In (ftKB) 5,750 Out (ftKB) 6,253 Drld (ftKB) 503 Drl Hrs (hrs) 29.00 ROP (ft/hr) 17.3

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 3 CT G X 0 WT DMF WOB (min) (1000lbf) 8 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 17 SPP (psi) Motor RPM (rpm) RPM (rpm)

PU (max) (1000lbf) 135 SO (1000lbf) 105 Off-Btm Str Wt (1000lbf) 110 Drag (1000lbf) 15 Start (ftKB) 5,750 End (ftKB) 5,750 

### Bit Run # 6 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7125020 Jets (/32")

14/14/14/14/14/14/14 In (ftKB) 4,930 Out (ftKB) 5,750 Drld (ftKB) 820 Drl Hrs (hrs) 47.00 ROP (ft/hr) 17.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 WT S X 0 CT PR WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 17 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 115 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 105 Drag (1000lbf) 10 Start (ftKB) 5,479 End (ftKB) 5,750 

### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG Survey Data MD (ftKB) Incl (°) Azm (°) 4,917 3.80 293.00 5,012 1.60 313.50 5,107 1.10 22.80 5,202 1.80 21.70 5,297 1.10 320.60 5,392 2.70 307.20 5,487 2.50 5.30 5,582 2.60 12.60 5,678 2.50 343.20 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #7, 8 3/4 Steerable BHA No. 7 Drill String Name 8 3/4 Steerable Length (ft) 791.70 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 198.50 123.23 1 Jars -

Hydraulic 6 1/2 215.00 32.23

19 DC 6 1/2 198.00 579.03

1 DC 6 1/2 123.00 31.12 1 UBHO 6 1/2 123.00 2.63 1 Great White 1.83 0.30 6 1/2 29.00 22.46 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 156 4.50 16.60 X-95 XH 4,942 

### Diesel Fuel Received Used 962 Cum On Location 2518 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,400 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 44,552 Field Est To Date 942,543 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/3/2009 Spud Date: 10/19/2009 Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/2/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 5,479 Footage (ftKB) 259 Drill Hrs (hrs) 20.50 Avg ROP (ft/hr) 12.6 DFS 14

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg Slide @ 5479' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:00 1.00 1.00 Dir Sliding 5,220 5,223 Slide 3', 12 wob, 95 rpms, 320 gpm, @ 1400 psi, 150 diff. 3

06:00 06:30 0.50 1.50 Dir Rotate 5,223 5,228 Rotate 5', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 10

06:30 09:30 3.00 4.50 Dir Sliding 5,228 5,240 Slide 12', 12 wob, 95 rpms, 350 gpm, @ 1450 psi, 150 diff. 4

09:30 10:00 0.50 5.00 Dir Rotate 5,240 5,243 Rotate 3', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 6

10:00 10:30 0.50 5.50 Rig Repair 5,243 5,243 Replace 4" union on vibrating hose. 10:30 11:00 0.50 6.00 Rtn. Maint. 5,243 5,243 Service rig. 11:00 12:30 1.50 7.50 Dir Rotate 5,243 5,274 Dir rotate 31', 10 wob, 55/95 rpms, 320 gpm, @ 1375 psi, 212 diff. 20.7

12:30 13:00 0.50 8.00 Srvys 5,274 5,274 Check shot @ 5234', 1.2 inc, 12.3 AZI. 13:00 15:30 2.50 10.50 Dir Rotate 5,274 5,339 Dir rotate 65', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 26

15:30 16:00 0.50 11.00 Srvys 5,339 5,339 Survey @ 5297', 1.1 inc, 320.6 AZI. 16:00 17:00 1.00 12.00 Dir Rotate 5,339 5,370 Dir rotate 31', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 170 diff. 31

17:00 17:30 0.50 12.50 Srvys 5,370 5,370 Check shot @ 5329', 1.8 inc, 306.7 AZI. 17:30 20:00 2.50 15.00 Dir Sliding 5,370 5,383 Slide 13', 10 wob, 104 rpms, 350 gpm, @ 1400 psi, 227 diff. 5.2

20:00 21:30 1.50 16.50 Dir Rotate 5,383 5,417 Dir rotate 34', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 175 diff. 22.7

21:30 22:00 0.50 17.00 Srvys 5,417 5,417 Check shot @ 5376', 2.4 inc, 303.1 AZI. 22:00 00:30 2.50 19.50 Dir Sliding 5,417 5,432 Slide 15', 10 wob, 104 rpms, 350 gpm, @ 1425 psi, 150 diff. 6

00:30 02:30 2.00 21.50 Dir Rotate 5,432 5,465 Dir rotate 32', 10 wob, 55/95 rpms, 320 gpm, @ 1375 psi, 175 diff. 16

02:30 03:00 0.50 22.00 Srvys 5,465 5,465 Check shot @ 5424', 2.6 inc, 326.4 AZI. 03:00 05:00 2.00 24.00 Dir Sliding 5,465 5,479 Slide 14', 11 wob, 104 rpms, 350 gpm, @ 1450 psi, 175 diff. 7



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 45 PV (cp) 18.0 YP (lbf/100ft2) 25 Gel 10 sec 7 Gel 10 min 9 Gel 30 min 11 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.3 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

174,000 Ca (mg/L) 520 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.57 LCM

Hole Volume (bbl) 352.2 Pit Volume (bbl) 340.0 Storage Volume (bbl) 270.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 5410 50 10 40 28 5430 40 10 50 30 5450 70 10 20 36 5470 80 20 60 5480 90 10 35 86 24 hr max 110 units @ 5335'



### Bit Run # 6 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7125020 Jets (/32")

14/14/14/14/14/14/14 In (ftKB) 4,930 Out (ftKB) 5,750 Drld (ftKB) 820 Drl Hrs (hrs) 47.00 ROP (ft/hr) 17.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 WT S X 0 CT PR WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 17 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 115 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 105 Drag (1000lbf) 10 Start (ftKB) 5,220 End (ftKB) 5,479 

### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG 

### Bit Run # 4 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,685 Out (ftKB) 3,885 Drld (ftKB) 200 Drl Hrs (hrs) 10.50 ROP (ft/hr) 19.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA Survey Data MD (ftKB) Incl (°) Azm (°) 4,632 2.50 327.30 4,727 2.10 300.80 4,823 1.30 299.20 4,917 3.80 293.00 5,012 1.60 313.50 5,107 1.10 22.80 5,202 1.80 21.70 5,297 1.10 320.60 5,392 2.70 307.20 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #6, 8 3/4 Steerable BHA No. 6 Drill String Name 8 3/4 Steerable Length (ft) 795.19 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 169.50 123.23 1 Jars -

Hydraulic 6 1/2 186.00 32.23

19 DC 6 1/2 169.00 579.03

1 DC 6 1/2 94.00 31.12 1 UBHO 6 1/2 94.00 2.63 1 Great White 1.83 0.30 6 1/2 94.00 25.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 141 4.50 16.60 X-95 XH 4,466 

### Diesel Fuel Received Used 1095 Cum On Location 3480 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,400 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 43,680 Field Est To Date 897,991 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/2/2009 Spud Date: 10/19/2009 Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/1/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 5,220 Footage (ftKB) 290 Drill Hrs (hrs) 14.50 Avg ROP (ft/hr) 20.0 DFS 13

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 5220' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:00 1.00 1.00 Logging 4,930 4,930 Rig down loggers. 06:00 10:00 4.00 5.00 Trip - Logs 4,930 4,930 TIH w/bit # 6. 10:00 11:00 1.00 6.00 Excess Ream 4,930 4,930 Wash to bottom/4895'-4930',(35').

11:00 11:30 0.50 6.50 Rtn. Maint. 4,930 4,930 Service rig. 11:30 12:00 0.50 7.00 Rig Repair 4,930 4,930 Work on pumps. 12:00 12:30 0.50 7.50 Dir Rotate 4,930 4,936 Dir rotate 6', 10 wob, 55/95 rpms, 320 gpm, @ 1200 psi, 200 diff. 12

12:30 14:30 2.00 9.50 Dir Sliding 4,935 4,953 Slide 18', 10 wob, 95 rpms, 320 gpm, 200 diff. 9

14:30 15:00 0.50 10.00 Srvys 4,953 4,953 Survey @ 4917', 3.8 inc, 293.0 AZI. 15:00 16:00 1.00 11.00 Dir Rotate 4,953 4,970 Dir rotate 17', 10 wob, 55/95 rpms, 320 gpm, @ 1300 psi, 150 diff. 17

16:00 19:00 3.00 14.00 Dir Sliding 4,970 4,990 Slide 20,, 10 wob, 102 rpms, 330 gpm, @ 1425 psi, 150 diff. 6.7

19:00 19:30 0.50 14.50 Rig Repair 4,990 4,990 Repair kelly hose 19:30 22:00 2.50 17.00 Dir Rotate 4,990 5,053 Dir rotate 63', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 200 diff. 25.2

22:00 22:30 0.50 17.50 Srvys 5,053 5,053 Check shot @ 5107', 1.1 inc, 22.8 AZI. 22:30 23:30 1.00 18.50 Dir Sliding 5,053 5,073 Slide 20', 10 wob, 95 rpm, 320 gpm, @ 1400 psi, 150 diff. 20

23:30 00:30 1.00 19.50 Dir Rotate 5,073 5,085 Dir rotate 12', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 225 diff. 12

00:30 01:00 0.50 20.00 Rtn. Maint. 5,085 5,085 Service rig 01:00 03:30 2.50 22.50 Dir Rotate 5,085 5,180 Dir rotate 95', 10 wob, 55/95 rpm, 320 gpm, @ 1400 psi, 225 diff. 38

03:30 04:00 0.50 23.00 Srvys 5,180 5,180 Check shot @ 5139', 1.4 inc, 21.7 AZI. 04:00 05:00 1.00 24.00 Dir Rotate 5,180 5,220 Dir rotate 40', 10 wob, 55/95 rpms, 320 gpm, @ 1400 psi, 240 diff. 40



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 48 PV (cp) 18.0 YP (lbf/100ft2) 27 Gel 10 sec 7 Gel 10 min 11 Gel 30 min 13 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.5 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) H20 (%) 84 Chlor (mg/L)

174,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.63 LCM

Hole Volume (bbl) 327.1 Pit Volume (bbl) 320.0 Storage Volume (bbl) 184.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 5150 10 90 333 5160 10 90 256 24 max 471 units @ 5146'
5190 50 40 10 32 5200 50 40 10 35 5210 50 40 10 33 471 24 max 514 units @ 5164'



### Bit Run # 6 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7125020 Jets (/32")

14/14/14/14/14/14/14 In (ftKB) 4,930 Out (ftKB) 5,750 Drld (ftKB) 820 Drl Hrs (hrs) 47.00 ROP (ft/hr) 17.4

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 WT S X 0 CT PR WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 17 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 115 SO (1000lbf) 105 Off-Btm Str Wt (1000lbf) 105 Drag (1000lbf) 5 Start (ftKB) 4,930 End (ftKB) 5,220 

### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG 

### Bit Run # 4 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,685 Out (ftKB) 3,885 Drld (ftKB) 200 Drl Hrs (hrs) 10.50 ROP (ft/hr) 19.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA Survey Data MD (ftKB) Incl (°) Azm (°) 4,442 0.90 162.90 4,537 0.80 289.00 4,632 2.50 327.30 4,727 2.10 300.80 4,823 1.30 299.20 4,917 3.80 293.00 5,012 1.60 313.50 5,107 1.10 22.80 5,202 1.80 21.70 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #6, 8 3/4 Steerable BHA No. 6 Drill String Name 8 3/4 Steerable Length (ft) 795.19 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 169.50 123.23 1 Jars -

Hydraulic 6 1/2 186.00 32.23

19 DC 6 1/2 169.00 579.03

1 DC 6 1/2 94.00 31.12 1 UBHO 6 1/2 94.00 2.63 1 Great White 1.83 0.30 6 1/2 94.00 25.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 147 4.50 16.60 X-95 XH 4,656 

### Diesel Fuel Received Used 864 Cum On Location 4575 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,400 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 68,758 Field Est To Date 854,311 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 11/1/2009 Spud Date: 10/19/2009 Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/31/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 4,930 Footage (ftKB) 52 Drill Hrs (hrs) 7.50 Avg ROP (ft/hr) 6.9 DFS 12

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg to 4930'/log/rig down loggers Planned Operations TIH and resume Dir drlg w/surveys. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 08:00 3.00 3.00 Dir Rotate 4,878 4,910 Dir rotate 32', 12 wob, 55/95 rpms, 320 gpm, @ 1365 psi, 205 diff. 10.7

08:00 09:30 1.50 4.50 Dir Sliding 4,910 4,911 Slide 1', 12-15 wob, 95 rpm, 330 gpm, @ 1400 psi, 250 diff. .7

09:30 10:00 0.50 5.00 Rtn. Maint. 4,911 4,911 Service rig. 10:00 10:30 0.50 5.50 Rig Repair 4,911 4,928 Clean screen on # 2 pump/ swap pumps. 10:30 13:00 2.50 8.00 Dir Rotate 4,911 4,928 Dir rotate 17', 12 wob, 55/95 rpms, 330 gpm, @ 1420 psi, 140 diff. 17

13:00 13:30 0.50 8.50 Srvys 4,928 4,928 Check shot @ 4886', 2.8 inc, 286.5 AZI. 13:30 14:00 0.50 9.00 Dir Rotate 4,928 4,930 Dir drlg 2', 12 wob, 55/95 rpms, 330 gpm, @ 1420 psi, 140 diff. 4

14:00 14:30 0.50 9.50 C&C Hole/Mud 4,930 4,930 Circulate bottoms up.

14:30 17:30 3.00 12.50 Trip - Logs 4,930 4,930 Short trip for logs/pull up to 3280'/Tight @ 4660'-4680'. 17:30 18:30 1.00 13.50 C&C Hole/Mud 4,930 4,930 Circulate bottoms up.

18:30 22:00 3.50 17.00 Trip - Logs 4,930 4,930 Pump out 2 joints/TOH for logs. 22:00 23:00 1.00 18.00 Logging 4,930 4,930 Rig up loggers. 23:00 04:00 5.00 23.00 Logging 4,930 4,930 Log/loggers TD 4903'/run GR,DL,ND,Sonic. 04:00 05:00 1.00 24.00 Logging 4,930 4,930 Rig down loggers



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 50 PV (cp) 20.0 YP (lbf/100ft2) 27 Gel 10 sec 10 Gel 10 min 14 Gel 30 min 17 Filtrate (mL/30min) 4.9 Cake (/32") 1 pH 8.6 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

173,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.67 LCM

Hole Volume (bbl) 320.8 Pit Volume (bbl) 308.0 Storage Volume (bbl) 150.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 4890 90 10 37 4900 90 10 32 4910 90 10 32 4920 90 10 8 36 24 hr max 41 units @ 4872'
4930 90 10 5 37 37 

### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 22 SPP (psi) 125.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 102 SO (1000lbf) 95 Off-Btm Str Wt (1000lbf) 100 Drag (1000lbf) 2 Start (ftKB) 4,878 End (ftKB) 4,930 

### Bit Run # 4 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,685 Out (ftKB) 3,885 Drld (ftKB) 200 Drl Hrs (hrs) 10.50 ROP (ft/hr) 19.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA 

### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 4,157 1.00 210.10 4,251 1.80 207.00 4,347 2.20 152.50 4,442 0.90 162.90 4,537 0.80 289.00 4,632 2.50 327.30 4,727 2.10 300.80 4,823 1.30 299.20 4,917 3.80 293.00 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #5, 8 3/4 Steerable BHA No. 5 Drill String Name 8 3/4 Steerable Length (ft) 795.19 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 122.50 123.23 1 Jars -

Hydraulic 6 1/2 139.00 32.23

19 DC 6 1/2 122.00 579.03

1 DC 6 1/2 47.00 31.12 1 UBHO 6 1/2 47.00 2.63 1 Great White 1.83 0.30 6 1/2 47.00 25.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 130 4.50 16.60 X-95 4.5 4,119 

### Diesel Fuel Received 3,300.0 Used 694 Cum On Location 5439 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,350 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 25,619 Field Est To Date 785,554 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/30/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 4,878 Footage (ftKB) 278 Drill Hrs (hrs) 20.50 Avg ROP (ft/hr) 13.6 DFS 11

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 4718 Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:00 1.00 1.00 Dir Rotate 4,600 4,642 Dir rotate 42', 10 wob, 55/95 rpms, 320 gpm @ 1350 psi, 192 diff. 42

06:00 08:30 2.50 3.50 Dir Sliding 4,642 4,650 Slide 8', 12 wob, 95 rpms, 320 gpm @ 1350 psi, 200 diff. 3.2

08:30 09:00 0.50 4.00 Dir Rotate 4,650 4,673 Dir rotate 23', 10 wob, 55/95 rpms, 320 gpm, @1290 psi, 190 diff. 46

09:00 09:30 0.50 4.50 Srvys 4,673 4,673 Survey @ 4632', 2.5 inc, 327.3 AZI. 09:30 12:00 2.50 7.00 Dir Sliding 4,673 4,693 Slide 20', 12 wob, 95 rpms, 320 gpm @ 1250 psi, 175 diff. 8

12:00 12:30 0.50 7.50 Dir Rotate 4,693 4,705 Dir rotate 12', 10 wob, 55/95 rpms, 320 gpm @ 1250 psi, 190 diff. 24

12:30 13:00 0.50 8.00 Srvys 4,705 4,705 Service rig. 13:00 14:00 1.00 9.00 Dir Rotate 4,705 4,720 Dir rotate 15', 12 wob, 55/95 rpms, 320 gpm, @ 1380 psi, 125 diff. 15

14:00 15:00 1.00 10.00 Dir Sliding 4,720 4,722 Slide 2', 14 wob, 95 rpms, 320 gpm, @ 1350 psi, 250 diff. 2

15:00 16:30 1.50 11.50 Dir Rotate 4,722 4,738 Dir rotate 16', 12 wob, 55/95 rpms, 320 gpm, @ 1350 psi, 255 diff. 16

16:30 17:00 0.50 12.00 Srvys 4,738 4,738 Check shot @ 4696', 2.2 inc, 306.3 AZI. 17:00 18:00 1.00 13.00 Dir Rotate 4,738 4,752 Dir rotate 14', 12 wob, 55/95 rpms, 320 gpm, @ 1365 psi, 300 diff. 9.3

18:00 18:30 0.50 13.50 Srvys 4,752 4,752 Check shot @ 4711', 2.2 inc, 300.8 AZI. 18:30 20:30 2.00 15.50 Dir Sliding 4,752 4,766 Slide 14', 14 wob, 95 rpms, 320 gpm, @ 1375 psi, 300 diff. 7

20:30 21:00 0.50 16.00 Srvys 4,766 4,766 Check shot @ 4727', 2.1 inc, 300.8 AZI. 21:00 23:00 2.00 18.00 Dir Rotate 4,766 4,800 Dir rotate 34', 12 wob, 55/95 rpms, 320 gpm, @ 1350 psi, 245 diff. 17

23:00 23:30 0.50 18.50 Srvys 4,800 4,800 Check shot @ 4759', 1.7 inc, 310.6 AZI. 23:30 04:00 4.50 23.00 Dir Rotate 4,800 4,864 Dir rotate 64', 12 wob, 55/95 rpms, 320 gpm, @ 1365 psi, 190 diff. 14.2

04:00 04:30 0.50 23.50 Srvys 4,864 4,864 Survey @ 4823', 1.3 inc, 299.2 AZI. 04:30 05:00 0.50 24.00 Dir Rotate 4,864 4,878 Dir rotate 14', 10 wob, 55/95 rpms, 320 gpm , @ 1365, 190 diff. 28



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 49 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 12 Gel 30 min 16 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.5 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

174,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.84 LCM

Hole Volume (bbl) 301.9 Pit Volume (bbl) 351.0 Storage Volume (bbl) 190.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 4680 80 20 17 16 27 hr max 80 units @ 4578' 4800 50 50 20 4820 40 60 21 4840 80 20 38 4860 70 20 10 32 36 24 hr max 78 units @ 4795'


### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 22 SPP (psi) 125.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 102 SO (1000lbf) 95 Off-Btm Str Wt (1000lbf) 100 Drag (1000lbf) 2 Start (ftKB) 4,600 End (ftKB) 4,878 

### Bit Run # 4 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,685 Out (ftKB) 3,885 Drld (ftKB) 200 Drl Hrs (hrs) 10.50 ROP (ft/hr) 19.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA 

### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2 Survey Data MD (ftKB) Incl (°) Azm (°) 4,062 2.20 157.60 4,157 1.00 210.10 4,251 1.80 207.00 4,347 2.20 152.50 4,442 0.90 162.90 4,537 0.80 289.00 4,632 2.50 327.30 4,727 2.10 300.80 4,823 1.30 299.20 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #5, 8 3/4 Steerable BHA No. 5 Drill String Name 8 3/4 Steerable Length (ft) 795.19 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 122.50 123.23 1 Jars -

Hydraulic 6 1/2 139.00 32.23

19 DC 6 1/2 122.00 579.03

1 DC 6 1/2 47.00 31.12 1 UBHO 6 1/2 47.00 2.63 1 Great White 1.83 0.30 6 1/2 47.00 25.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 128 4.50 16.60 X-95 4.5 4,055 

### Diesel Fuel Received Used 282 Cum On Location 2833 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,350 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 18,685 Field Est To Date 759,935 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/30/2009 Spud Date: 10/19/2009

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/29/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 4,600 Footage (ftKB) 648 Drill Hrs (hrs) 18.00 Avg ROP (ft/hr) 36.0 DFS 10

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 4600' Planned Operations Dir drlg w/surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Danny Lewis

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:30 1.50 1.50 Dir Rotate 3,952 4,008 Dir rotate 56', 10 wob, 55/95 rpms, 320 gpm, @ 1225 psi, 190 diff 37.3

06:30 07:00 0.50 2.00 Srvys 4,008 4,008 Survey @ 3967', 0.5 inc, 155.9 AZI. 07:00 07:30 0.50 2.50 Dir Rotate 4,008 4,040 Dir rotate 32', 10 wob, 55/95 rpms, 320 gpm, @1225 psi, 190 diff. 64

07:30 08:00 0.50 3.00 Dir Sliding 4,040 4,055 Slide 15', 12 wob, 95 rpms, 320 gpm, @ 1225 psi, 300 diff. 30

08:00 08:30 0.50 3.50 Dir Rotate 4,055 4,103 Dir rotate 48', 10 wob, 55/95 rpms, 320 gpm, @ 1225 psi, 190 diff. 96

08:30 09:00 0.50 4.00 Srvys 4,103 4,103 Survey @ 4062', 2.2 inc, 157.0 AZI. 09:00 10:30 1.50 5.50 Dir Sliding 4,103 4,121 Slide 18', 12 wob, 95 rpms, 320 gpm, @ 1225 psi, 300 diff. 12

10:30 11:30 1.00 6.50 Dir Rotate 4,121 4,182 Dir rotate 61', 10 wob, 55/95 rpms, 320 gpm, @ 1225 psi, 190 diff. 61

11:30 12:00 0.50 7.00 Srvys 4,182 4,182 Check shot @ 4125', 1.3 inc, 176.2 AZI. 12:00 13:00 1.00 8.00 Dir Sliding 4,182 4,194 Slide 12', 12 wob, 95 rpms, 320 gpm, 300 diff. 12

13:00 13:30 0.50 8.50 Srvys 4,194 4,194 Survey @ 4157', 1.0 inc, 210.1 AZI. 13:30 14:30 1.00 9.50 Dir Rotate 4,194 4,230 Dir rotate 36', 10 wob, 55/95 rpms, 320 gpm, @ 1300 psi, 300 diff. 36

14:30 15:00 0.50 10.00 Srvys 4,230 4,230 Check shot @ 4189',1.1 inc, 235 AZI. 15:00 16:00 1.00 11.00 Dir Rotate 4,230 4,293 Dir rotate 63', 10 wob, 55/95 rpms, 320 gpm, @ 1300psi, 300 diff. 63

16:00 16:30 0.50 11.50 Rtn. Maint. 4,293 4,293 Service rig 16:30 17:00 0.50 12.00 Dir Sliding 4,293 4,311 Slide 18', 12 wob, 95 rpms, 320 gpm, @ 1300 psi, 325 diff 36

17:00 17:30 0.50 12.50 Dir Rotate 4,311 4,325 Dir rotate 14', 10 wob, 55/95 rpms, 320 gpm, @ 1300psi, 300 diff. 28

17:30 18:00 0.50 13.00 Srvys 4,325 4,325 Check shot @ 4284', 2.1 inc, 190.7 AZi. 18:00 18:30 0.50 13.50 Dir Sliding 4,325 4,338 Slide 13', 12 wob, 95 rpms, 320 gpm, @1300 psi, 325 diff. 26

18:30 19:00 0.50 14.00 Srvys 4,338 4,338 Check shot @ 4297', 2.2 inc, 152.5 AZI. 19:00 19:30 0.50 14.50 Dir Rotate 4,338 4,388 Dir rotate 50', 10 wob, 55/95 rpms, 320 gpm, @ 1325 psi, 326 diff. 100

19:30 21:30 2.00 16.50 Dir Sliding 4,388 4,406 Slide ', 18 wob, 95 rpms, 320 gpm, @ 1330 psi, 328 diff. 9

21:30 22:00 0.50 17.00 Dir Rotate 4,406 4,420 Dir rotate 14', 10 wob, 55/95 rpms, 320 gpm, @ 1350 psi, 330 diff. 28

22:00 22:30 0.50 17.50 Srvys 4,420 4,420 Check shot @ 4379', 2.3 inc, 150.1 AZI. 22:30 23:30 1.00 18.50 Dir Sliding 4,420 4,440 Slide 20', 12 wob, 95 rpms, 320 gpm, @ 1350 psi, 225 diff. 40

23:30 00:30 1.00 19.50 Dir Rotate 4,440 4,483 Dir Rotate 43', 10 wob, 55/95 rpms, 320 gpm, @ 1335 psi, 200 diff. 86

00:30 01:00 0.50 20.00 Srvys 4,483 4,483 Check shot @ 4442', .9 inc, 162.9 AZI. 01:00 02:00 1.00 21.00 Dir Rotate 4,483 4,513 Dir rotate 30', 10 wob, 55/95 rpms, 320 gpm, @ 1360 psi, 190 diff. 60

02:00 02:30 0.50 21.50 Srvys 4,513 4,513 Check shot @ 4472', .6 inc, 214.5 AZI 02:30 03:30 1.00 22.50 Dir Rotate 4,513 4,547 Dir rotate 34', 10 wob, 55/95 rpms, 320 gpm, @ 1360 psi, 190 diff. 64

03:30 04:00 0.50 23.00 Srvys 4,547 4,547 Check shot @ 4506', .6 inc, 273.0 AZI 04:00 05:00 1.00 24.00 Dir Rotate 4,547 4,600 Dir rotate 53', 10 wob, 55/95 rpms, 320 gpm, @ 1350 psi, 190 diff. 53



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 49 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 8 Gel 10 min 13 Gel 30 min 16 Filtrate (mL/30min) 4.7 Cake (/32") 1 pH 8.7 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

174,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.1 ECD (lb/gal) 11.64 LCM

Hole Volume (bbl) 283.0 Pit Volume (bbl) 352.0 Storage Volume (bbl) 245.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 4190 90 10 10 20 24 hr max 470 units @ 4074' 4520 100 40 4540 80 20 14 4560 80 20 21 Survey Data MD (ftKB) Incl (°) Azm (°) 3,735 0.16 3,873 0.20 202.90 3,904 0.50 155.90 4,062 2.20 157.60 4,157 1.00 210.10 4,251 1.80 207.00 4,347 2.20 152.50 4,442 0.90 162.90 4,537 0.80 289.00 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #5, 8 3/4 Steerable BHA No. 5 Drill String Name 8 3/4 Steerable Length (ft) 795.19 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 122.50 123.23 1 Jars -

Hydraulic 6 1/2 139.00 32.23

19 DC 6 1/2 122.00 579.03

1 DC 6 1/2 47.00 31.12 1 UBHO 6 1/2 47.00 2.63 1 Great White 1.83 0.30 6 1/2 47.00 25.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 118 4.50 16.60 X-95 4.5 3,738 

### Diesel Fuel Received Used 1303 Cum On Location 3115 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 SPM (spm) 102 Q (gpm) 320 Pres (psi) 1,350 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 20,316 Field Est To Date 741,249 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/29/2009 Spud Date: 10/19/2009 Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 4580 70 30 31 26 24 hr max 470 units @ 4074'


### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 22 SPP (psi) 1,250.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 102 SO (1000lbf) 95 Off-Btm Str Wt (1000lbf) 92 Drag (1000lbf) 6 Start (ftKB) 3,952 End (ftKB) 4,600 

### Bit Run # 4 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,685 Out (ftKB) 3,885 Drld (ftKB) 200 Drl Hrs (hrs) 10.50 ROP (ft/hr) 19.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA 

### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/28/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 3,952 Footage (ftKB) 248 Drill Hrs (hrs) 11.00 Avg ROP (ft/hr) 22.5 DFS 9

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir drlg @ 3952' Planned Operations Dir drlg w/ surveys Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:00 2.00 2.00 Dir Sliding 3,704 3,735 Slide 31', 12 wob, 121 rpm's, 356 gpm's @ 1218 psi, 366 diff. 15.5

07:00 07:30 0.50 2.50 Srvys 3,735 3,735 Survey @ 3735'. 07:30 15:30 8.00 10.50 Dir Sliding 3,735 3,885 Slide 150', 12 wob, 121 rpm's, 356 gpm's @ 1218 psi, 366 diff. 18.75

15:30 16:00 0.50 11.00 Rtn. Maint. 3,885 3,885 Service rig. 16:00 17:00 1.00 12.00 C&C Hole/Mud 3,885 3,885 Circulate bottoms up, L/D 4 jts with kelly, pump slug and TOH. 17:00 21:30 4.50 16.50 Trip - Other 3,885 3,885 Trip out of hole lay down baker v-trak. 21:30 23:30 2.00 18.50 Trip - Other 3,885 3,885 Pick up motor, mwd, scribe and test (good test). 23:30 03:30 4.00 22.50 Trip - Other 3,885 3,885 TIH w/ motor and rr-bit # 4 to 3913'. 03:30 04:00 0.50 23.00 Excess Ream 3,885 3,885 Wash 127' to bottom (no- fill ).

04:00 05:00 1.00 24.00 Dir Rotate 3,885 3,952 Dir rotate 67', 10 wob, 45/103, 342 gpm @ 1250 psi, 180 diff, check shot @ 3904' inc 0.2, azm 202.9. 67



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 50 PV (cp) 20.0 YP (lbf/100ft2) 26 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 16 Filtrate (mL/30min) 4.6 Cake (/32") 1 pH 8.5 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) 0.0 Oil (%) 1 H20 (%) 83 Chlor (mg/L)

172,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.66 LCM

Hole Volume (bbl) 245.3 Pit Volume (bbl) 347.0 Storage Volume (bbl) 185.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 3790 40 60 37 3860 100 0 30 3870 90 10 38 24 hr max 305 units @ 3710'
3880 50 50 58 trip gas 48 units 3890 50 50 30 

### Bit Run # 5, Rerun Size (in)

8 3/4 Model

QD-505 Rerun Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,885 Out (ftKB) 4,930 Drld (ftKB) 1,045 Drl Hrs (hrs) 47.00 ROP (ft/hr) 22.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 5 7 WT A X 0 CT LOG WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 22 SPP (psi) 1,250.0 Motor RPM (rpm) 103 RPM (rpm) 45 PU (max) (1000lbf) 102 SO (1000lbf) 95 Off-Btm Str Wt (1000lbf) 92 Drag (1000lbf) 6 Start (ftKB) 3,885 End (ftKB) 3,952 

### Bit Run # 4 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,685 Out (ftKB) 3,885 Drld (ftKB) 200 Drl Hrs (hrs) 10.50 ROP (ft/hr) 19.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA WOB (min) (1000lbf) 14 WOB (max) (1000lbf) 14 BHA ROP (ft/hr) 19 SPP (psi) 1,250.0 Motor RPM (rpm) 121 RPM (rpm)

PU (max) (1000lbf) 96 SO (1000lbf) 93 Off-Btm Str Wt (1000lbf) 91 Drag (1000lbf) 5 Start (ftKB) 3,704 End (ftKB) 3,885 

### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 2,151 0.15 2,436 0.02 2,690 0.84 2,943 1.11 3,197 0.67 3,450 0.21 3,735 0.16 3,873 0.20 202.90 3,904 0.50 155.90 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #5, 8 3/4 Steerable BHA No. 5 Drill String Name 8 3/4 Steerable Length (ft) 795.19 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 122.50 123.23 1 Jars -

Hydraulic 6 1/2 139.00 32.23

19 DC 6 1/2 122.00 579.03

1 DC 6 1/2 47.00 31.12 1 UBHO 6 1/2 47.00 2.63 1 Great White 1.83 0.30 6 1/2 47.00 25.95 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 97 4.50 16.60 X-95 4.5 3,073 

### Diesel Fuel Received Used 840 Cum On Location 4418 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 SPM (spm) 100 Q (gpm) 279 Pres (psi) 1,230 Stroke (in) 10.00 Slow ... No
No. 2 Make Ideco Model T-800 SPM (spm) 40 Q (gpm) 126 Pres (psi) 750 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 34,851 Field Est To Date 720,934 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/27/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 3,704 Footage (ftKB) 52 Drill Hrs (hrs) 3.00 Avg ROP (ft/hr) 17.3 DFS 8

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir Slide drlg @ 3704'. Planned Operations Dir Slide Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:30 2.50 2.50 Dir Sliding 3,652 3,685 Slide 33', 15 wob, 121 rpms, 356 gpm @ 1500 psi, 460 diff. 13.2

07:30 09:30 2.00 4.50 C&C Hole/Mud 3,685 3,685 Circulate, L/D 5 jts with kelly and pump slug. 09:30 12:00 2.50 7.00 Trip for Bit 3,685 3,685 Set kelly back and TOH for bit. 12:00 12:30 0.50 7.50 Rtn. Maint. 3,685 3,685 Service rig. 12:30 16:00 3.50 11.00 Trip for Bit 3,685 3,685 Change out v-track, make up bit and TIH. 16:00 01:30 9.50 20.50 Unplanned 3,685 3,685 Pull 26 stands, wait on oilworks and repair eton brake. 01:30 02:30 1.00 21.50 Trip for Bit 3,685 3,685 Trip in hole to 3560'. 02:30 04:30 2.00 23.50 Excess Ream 3,685 3,685 wash 125' to bottom 15' fill

04:30 05:00 0.50 24.00 Dir Sliding 3,685 3,704 Slide 19', 15 wob, 112 rpms, 320 gpm @1250 psi, 250 diff. 38



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 50 PV (cp) 20.0 YP (lbf/100ft2) 27 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 16 Filtrate (mL/30min) 4.5 Cake (/32") 1 pH 8.6 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

169,000 Ca (mg/L) 560 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) LCM 0 Hole Volume (bbl) 232.7 Pit Volume (bbl) 347.0 Storage Volume (bbl) 115.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 3650 10 90 210 3670 20 70 10 320 3680 20 70 10 130 Max gas 498 units @3574
3685 20 70 10 34


### Bit Run # 4 Size (in)

8 3/4 Model QD-505 Make Hughes SN 7124305 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 3,685 Out (ftKB) 3,885 Drld (ftKB) 200 Drl Hrs (hrs) 10.50 ROP (ft/hr) 19.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA WOB (min) (1000lbf) 14 WOB (max) (1000lbf) 14 BHA ROP (ft/hr) 19 SPP (psi) 1,250.0 Motor RPM (rpm) 121 RPM (rpm)

PU (max) (1000lbf) 96 SO (1000lbf) 93 Off-Btm Str Wt (1000lbf) 91 Drag (1000lbf) 5 Start (ftKB) 3,685 End (ftKB) 3,704 

### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR WOB (min) (1000lbf) 6 WOB (max) (1000lbf) 15 BHA ROP (ft/hr) 39 SPP (psi) 1,500.0 Motor RPM (rpm) 121 RPM (rpm)

PU (max) (1000lbf) 96 SO (1000lbf) 93 Off-Btm Str Wt (1000lbf) 91 Drag (1000lbf) 5 Start (ftKB) 3,652 End (ftKB) 3,685 

### Bit Run # 2 Size (in)

8 3/4 Model

HA-1-Mill tooth Make JZ SN F31786 Jets (/32") 15/15/15 In (ftKB) 1,158 Out (ftKB) 1,179 Drld (ftKB) 21 Drl Hrs (hrs) 1.00 ROP (ft/hr) 21.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A 0 0 NO BHA Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 1,405 0.07 1,676 0.11 1,930 0.18 2,151 0.15 2,436 0.02 2,690 0.84 2,943 1.11 3,197 0.67 3,450 0.21 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #4, 8 3/4 Steerable BHA No. 4 Drill String Name 8 3/4 Steerable Length (ft) 774.76 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 75.50 123.23 1 Jars -

Hydraulic 6 1/2 92.00 32.23

19 DC 6 1/2 75.50 579.03

1 XO Sub 6 1/2 74.50 3.06 1 Float Sub 6 1/2 74.50 5.68 1 Baker 0.34 6 3/4 10.50 30.53 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 89 4.50 16.60 X-95 4.5 2,819 

### Diesel Fuel Received Used 823 Cum On Location 5258 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 SPM (spm) 97 Q (gpm) 270 Pres (psi) 1,230 Stroke (in) 10.00 Slow ... No
No. 2 Make Ideco Model T-800 SPM (spm) 97 Q (gpm) 305 Pres (psi) 1,236 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 42,067 Field Est To Date 686,083 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/26/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 3,652 Footage (ftKB) 572 Drill Hrs (hrs) 22.00 Avg ROP (ft/hr) 26.0 DFS 7

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir Slide drlg at 3652'. Planned Operations Dir Slide. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 10:00 5.00 5.00 Dir Sliding 3,080 3,197 Slide 117', 15 wob, 121 rpms, 356 gpm at 1500 psi, 460 diff. 23.4

10:00 10:30 0.50 5.50 Srvys 3,197 3,197 Survey at 3197'. 10:30 13:30 3.00 8.50 Dir Sliding 3,197 3,280 Slide 83', 15 wob, 121 rpms, 356 gpm at 1500 psi, 460 diff. 27.6

13:30 14:00 0.50 9.00 Rtn. Maint. 3,280 3,280 Service rig. 14:00 21:00 7.00 16.00 Dir Sliding 3,280 3,450 Slide 170', 15 wob, 121 rpms, 356 gpm at 1500 psi, 460 diff. 24.2

21:00 21:30 0.50 16.50 Srvys 3,450 3,450 Survey at 3450'. 21:30 03:00 5.50 22.00 Dir Sliding 3,450 3,609 Slide 159', 15 wob, 121 rpms, 356 gpm at 1500 psi, 460 diff. 28.9

03:00 03:30 0.50 22.50 Rtn. Maint. 3,609 3,609 Service rig. 03:30 05:00 1.50 24.00 Dir Sliding 3,609 3,652 Slide 43', 15 wob, 121 rpms, 356 gpm at 1500 psi, 460 diff. Last check shot @ 3640' = 0.14*. 28.6



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 45 PV (cp) 17.0 YP (lbf/100ft2) 22 Gel 10 sec 6 Gel 10 min 9 Gel 30 min 12 Filtrate (mL/30min) 4.6 Cake (/32") 1 pH 8.1 Solids (%) 8 LGS (%) 5 MBT (lb/bbl) Oil (%) 1 H20 (%) 83 Chlor (mg/L)

169,000 Ca (mg/L) 600 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.2 ECD (lb/gal) 11.63 LCM

Hole Volume (bbl) 195.0 Pit Volume (bbl) 3.1 Storage Volume (bbl) 80.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 3220 10 90 12 3550 10 90 210 3580 20 80 320 400 3600 20 80 130 24 hr max 756 units @ 3508
3620 100 34


### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR WOB (min) (1000lbf) 6 WOB (max) (1000lbf) 15 BHA ROP (ft/hr) 39 SPP (psi) 1,500.0 Motor RPM (rpm) 121 RPM (rpm)

PU (max) (1000lbf) 96 SO (1000lbf) 93 Off-Btm Str Wt (1000lbf) 91 Drag (1000lbf) 5 Start (ftKB) 3,080 End (ftKB) 3,652 

### Bit Run # 2 Size (in)

8 3/4 Model

HA-1-Mill tooth Make JZ SN F31786 Jets (/32") 15/15/15 In (ftKB) 1,158 Out (ftKB) 1,179 Drld (ftKB) 21 Drl Hrs (hrs) 1.00 ROP (ft/hr) 21.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A 0 0 NO BHA 

### Bit Run # 1 Size (in)

12 1/4 Model

Mach 132 Halco Make SN 7132 Jets (/32") 0 In (ftKB) 40 Out (ftKB) 1,158 Drld (ftKB) 1,118 Drl Hrs (hrs) 16.50 ROP (ft/hr) 67.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 1,405 0.07 1,676 0.11 1,930 0.18 2,151 0.15 2,436 0.02 2,690 0.84 2,943 1.11 3,197 0.67 3,450 0.21 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 774.98 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 65.00 123.23 1 Jars -

Hydraulic 6 1/2 81.50 32.23

19 DC 6 1/2 65.00 579.03

1 XO Sub 6 1/2 64.00 3.06 1 Float Sub 6 1/2 64.00 5.68 1 Baker 0.34 6 3/4 64.00 30.75 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 89 4.50 16.60 X-95 4.5 2,819 

### Diesel Fuel Received Used 802 Cum On Location 6081 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 SPM (spm) 42 Q (gpm) 117 Pres (psi) 750 Stroke (in) 10.00 Slow ... No
No. 2 Make Ideco Model T-800 Costs Daily Cost Total 28,271 Field Est To Date 644,016 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/25/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 3,080 Footage (ftKB) 840 Drill Hrs (hrs) 20.00 Avg ROP (ft/hr) 42.0 DFS 6

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir Slide drlg @ 3080'. Planned Operations Dir Slide. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 08:00 3.00 3.00 Dir Sliding 2,240 2,373 Slide 133', 14 wob, 121 rpms, 356 gpm @ 1500 psi, 460 diff. 44.3

08:00 08:30 0.50 3.50 Rtn. Maint. 2,373 2,373 Service rig. 08:30 10:00 1.50 5.00 Dir Sliding 2,373 2,436 Slide 63', 14 wob, 121 rpms, 356 gpm @ 1500 psi, 460 diff. 42

10:00 10:30 0.50 5.50 Srvys 2,436 2,436 Survey @ 2436'. 10:30 14:30 4.00 9.50 Dir Sliding 2,436 2,690 Slide 254', 14 wob, 121 rpms, 356 gpm @ 1500 psi, 460 diff. 63.5

14:30 15:00 0.50 10.00 Srvys 2,690 2,690 Survey @ 2690'. 15:00 22:00 7.00 17.00 Dir Sliding 2,690 2,943 Slide 253', 14 wob, 121 rpms, 356 gpm @ 1500 psi, 460 diff. 36.1

22:00 22:30 0.50 17.50 Srvys 2,943 2,943 Survey @ 2943'. 22:30 02:00 3.50 21.00 Dir Sliding 2,943 3,038 Slide 95', 14 wob, 121 rpms, 356 gpm @ 1500 psi, 460 diff. 27.1

02:00 03:00 1.00 22.00 Unplanned 3,038 3,038 Work v-trak, turn to clean rib and reset mwd box. 03:00 04:00 1.00 23.00 Rtn. Maint. 3,038 3,038 Service rig work on auto-driller. 04:00 05:00 1.00 24.00 Dir Sliding 3,038 3,080 Slide 42', 14 wob, 121 rpms, 356 gpm @ 1500 psi, 460 diff.
05:00 05:00 24.00 3,080



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 49 PV (cp) 20.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 12 Gel 30 min 15 Filtrate (mL/30min) 4.6 Cake (/32") 1 pH 8.2 Solids (%) 8 LGS (%) 5 MBT (lb/bbl) Oil (%) 2 H20 (%) 82 Chlor (mg/L)

168,000 Ca (mg/L) 600 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) LCM 0 Hole Volume (bbl) 132.1 Pit Volume (bbl) 315.0 Storage Volume (bbl) 210.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 2660 100 45 3050 70 30 24 3060 50 50 33 3070 10 90 20 3080 10 90 11 24 hr max 66 units @ 2754'



### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR WOB (min) (1000lbf) 6 WOB (max) (1000lbf) 15 BHA ROP (ft/hr) 39 SPP (psi) 1,500.0 Motor RPM (rpm) 121 RPM (rpm)

PU (max) (1000lbf) 96 SO (1000lbf) 85 Off-Btm Str Wt (1000lbf) 84 Drag (1000lbf) 6 Start (ftKB) 2,240 End (ftKB) 3,080 

### Bit Run # 2 Size (in)

8 3/4 Model

HA-1-Mill tooth Make JZ SN F31786 Jets (/32") 15/15/15 In (ftKB) 1,158 Out (ftKB) 1,179 Drld (ftKB) 21 Drl Hrs (hrs) 1.00 ROP (ft/hr) 21.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A 0 0 NO BHA 

### Bit Run # 1 Size (in)

12 1/4 Model

Mach 132 Halco Make SN 7132 Jets (/32") 0 In (ftKB) 40 Out (ftKB) 1,158 Drld (ftKB) 1,118 Drl Hrs (hrs) 16.50 ROP (ft/hr) 67.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 705 0.75 1,113 1.25 1,405 0.07 1,676 0.11 1,930 0.18 2,151 0.15 2,436 0.02 2,690 0.84 2,943 1.11 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 774.98 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 65.00 123.23 1 Jars -

Hydraulic 6 1/2 81.50 32.23

19 DC 6 1/2 65.00 579.03

1 XO Sub 6 1/2 64.00 3.06 1 Float Sub 6 1/2 64.00 5.68 1 Baker 0.34 6 3/4 64.00 30.75 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 71 4.50 16.60 X-95 4.5 2,222 

### Diesel Fuel Received Used 745 Cum On Location 6883 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000
No. 2 Make Ideco Model T-800 Liner Size (in) 6 Rod Dia (in) 2 1/8 Stroke (in) 9.00 SPM (spm) 107 Q (gpm) 336 Pres (psi) 1,500 Stroke (in) 9.00 Slow ... No SPM (spm) 40 Q (gpm) 126 Pres (psi) 1,375 Stroke (in) 9.00 Slow ... No Costs Daily Cost Total 29,138 Field Est To Date 615,745 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/24/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 2,240 Footage (ftKB) 1,008 Drill Hrs (hrs) 17.50 Avg ROP (ft/hr) 57.6 DFS 5

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Dir Slide drlg @ 2240'. Planned Operations Dir Slide. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 06:00 1.00 1.00 Dir Sliding 1,179 1,232 Slide 53', 11 wob, 21 rpm's, 356 gpm's at 1450 psi, 350 diff. 53

06:00 08:00 2.00 3.00 Unplanned 1,232 1,232 Work pipe and reboot control box for v-trak. 08:00 11:30 3.50 6.50 Dir Sliding 1,232 1,405 Slide 173', 11 wob, 121 rpm's, 328 gpm's at 1405 psi, 350 diff. 49.4

11:30 13:00 1.50 8.00 Rtn. Maint. 1,405 1,405 Service rig, repair kelly spinner and adjust pipe spinner. 13:00 14:00 1.00 9.00 Srvys 1,405 1,405 Survey @ 1405'. (fill hydraulic tank) 14:00 18:30 4.50 13.50 Dir Sliding 1,405 1,676 Slide 271', 11 wob, 121 rpm's, 328 gpm's at 1405 psi, 350 diff. 60.2

18:30 19:30 1.00 14.50 Srvys 1,676 1,676 Survey @ 1676' and replace hydraulic hose on kelly spinner. 19:30 20:30 1.00 15.50 Dir Sliding 1,676 1,740 Slide 64', 11 wob, 121 rpm's, 328 gpm's at 1405 psi, 350 diff. 64

20:30 21:00 0.50 16.00 Rtn. Maint. 1,740 1,740 Service rig 21:00 00:00 3.00 19.00 Dir Sliding 1,740 1,930 Slide 64', 11 wob, 121 rpm's, 328 gpm's at 1405 psi, 350 diff. 63.3

00:00 00:30 0.50 19.50 Srvys 1,930 1,930 Survey @ 1930'. 00:30 05:00 4.50 24.00 Dir Sliding 1,930 2,240 Slide 310', 11 wob, 121 rpm's, 328 gpm's at 1405 psi, 350 diff. 68.8



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 51 PV (cp) 20.0 YP (lbf/100ft2) 26 Gel 10 sec 7 Gel 10 min 11 Gel 30 min 15 Filtrate (mL/30min) 4.5 Cake (/32") 2 pH 8.5 Solids (%) 8 LGS (%) 4 MBT (lb/bbl) Oil (%) 2 H20 (%) 83 Chlor (mg/L)

165,000 Ca (mg/L) 560 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 11.87 LCM

Hole Volume (bbl) 62.9 Pit Volume (bbl) 466.0 Storage Volume (bbl) 290.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 1460 50 50 25 2150 60 40 39 24 hr max 51 units @ 1740'
2180 40 50 10 19 2210 60 40 37 2240 50 40 10 29


### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR WOB (min) (1000lbf) 6 WOB (max) (1000lbf) 15 BHA ROP (ft/hr) 39 SPP (psi) 1,450.0 Motor RPM (rpm) 121 RPM (rpm)

PU (max) (1000lbf) 96 SO (1000lbf) 65 Off-Btm Str Wt (1000lbf) 6 Drag (1000lbf) 62 Start (ftKB) 1,232 End (ftKB) 2,240 

### Bit Run # 2 Size (in)

8 3/4 Model

HA-1-Mill tooth Make JZ SN F31786 Jets (/32") 15/15/15 In (ftKB) 1,158 Out (ftKB) 1,179 Drld (ftKB) 21 Drl Hrs (hrs) 1.00 ROP (ft/hr) 21.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A 0 0 NO BHA 

### Bit Run # 1 Size (in)

12 1/4 Model

Mach 132 Halco Make SN 7132 Jets (/32") 0 In (ftKB) 40 Out (ftKB) 1,158 Drld (ftKB) 1,118 Drl Hrs (hrs) 16.50 ROP (ft/hr) 67.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 255 0.25 705 0.75 1,113 1.25 1,405 0.07 1,676 0.11 1,930 0.18 2,151 0.15 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 774.98 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 65.00 123.23 1 Jars -

Hydraulic 6 1/2 81.50 32.23

19 DC 6 1/2 65.00 579.03

1 XO Sub 6 1/2 64.00 3.06 1 Float Sub 6 1/2 64.00 5.68 1 Baker 0.34 6 3/4 64.00 30.75 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 38 4.50 16.60 X-95 4.5 1,204 

### Diesel Fuel Received Used 745 Cum On Location 7628 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 Liner Size (in) 6 Rod Dia (in) 1 7/8 Stroke (in) 10.00 SPM (spm) 42 Q (gpm) 117 Pres (psi) 750 Stroke (in) 10.00 Slow ... No
No. 2 Make Ideco Model T-800 Liner Size (in) 6 Rod Dia (in) 2 1/8 Stroke (in) 9.00 Costs Daily Cost Total 42,079 Field Est To Date 586,607 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/23/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 1,179 Footage (ftKB) 21 Drill Hrs (hrs) 1.00 Avg ROP (ft/hr) 21.0 DFS 4

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Drlg with v-trak @ 1232'. Planned Operations Drlg Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 08:30 3.50 3.50 NU & Test 1,158 1,158 Finish testing kelly valves and all subs. 08:30 12:00 3.50 7.00 Rtn. Maint. 1,158 1,158 Slip and cut drilling line. 12:00 17:00 5.00 12.00 Trip - Other 1,158 1,158 Pick up BHA # 2 and trip in hole w/bit. 17:00 18:00 1.00 13.00 Drilling Cement 1,158 1,179 Drld 21', 10 wob, 45 rpms, 380 psi, 205 gpms, tagged cement @ 1069' and drld guide shoe @ 1118'. 18:00 19:00 1.00 14.00 Rtn. Maint. 1,179 1,179 Service rig 19:00 20:30 1.50 15.50 C&C Hole/Mud 1,179 1,179 Circulate hole clean.

20:30 22:30 2.00 17.50 Trip for Bit 1,179 1,179 Trip out of hole L/D bit #2 and bit sub. 22:30 00:00 1.50 19.00 Trip - Other 1,179 1,179 Pick up Verti trak and test. 00:00 02:00 2.00 21.00 Trip - Other 1,179 1,179 Trip in hole with v-trak 02:00 03:00 1.00 22.00 Trip - Other 1,179 1,179 work on surface eqpt. 03:00 05:00 2.00 24.00 Dir Sliding 1,179 1,232 Slide 52' wob 10, 119 rpm, 325 gpms at 1232 psi. 26



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 48 PV (cp) 20.0 YP (lbf/100ft2) 22 Gel 10 sec 4 Gel 10 min 6 Gel 30 min 8 Filtrate (mL/30min) 4.5 Cake (/32") 2 pH 8.7 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) 0.0 Oil (%) 2 H20 (%) 82 Chlor (mg/L)

167,000 Ca (mg/L) 400 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.2 Mf (mL/mL) 0.6 ECD (lb/gal) LCM 0 Hole Volume (bbl) 50.3 Pit Volume (bbl) 390.0 Storage Volume (bbl) 290.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment



### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR WOB (min) (1000lbf) 6 WOB (max) (1000lbf) 15 BHA ROP (ft/hr) 39 SPP (psi) 1,225.0 Motor RPM (rpm) RPM (rpm) 119 PU (max) (1000lbf) 96 SO (1000lbf) 60 Off-Btm Str Wt (1000lbf) 62 Drag (1000lbf) 1 Start (ftKB) 1,179 End (ftKB) 1,232 

### Bit Run # 2 Size (in)

8 3/4 Model

HA-1-Mill tooth Make JZ SN F31786 Jets (/32") 15/15/15 In (ftKB) 1,158 Out (ftKB) 1,179 Drld (ftKB) 21 Drl Hrs (hrs) 1.00 ROP (ft/hr) 21.0

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A 0 0 NO BHA WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 21 SPP (psi) 380.0 Motor RPM (rpm) RPM (rpm) 45 PU (max) (1000lbf) 50 SO (1000lbf) 50 Off-Btm Str Wt (1000lbf) 50 Drag (1000lbf) 0 Start (ftKB) 1,158 End (ftKB) 1,179 

### Bit Run # 1 Size (in)

12 1/4 Model

Mach 132 Halco Make SN 7132 Jets (/32") 0 In (ftKB) 40 Out (ftKB) 1,158 Drld (ftKB) 1,118 Drl Hrs (hrs) 16.50 ROP (ft/hr) 67.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 255 0.25 705 0.75 1,113 1.25 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 774.98 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 65.00 123.23 1 Jars -

Hydraulic 6 1/2 81.50 32.23

19 DC 6 1/2 65.00 579.03

1 XO Sub 6 1/2 64.00 3.06 1 Float Sub 6 1/2 64.00 5.68 1 Baker 0.34 6 3/4 64.00 30.75 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 12 4.50 16.60 X-95 4.5 316 

### Diesel Fuel Received Used 711 Cum On Location 4175 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 Liner Size (in) 6 Rod Dia (in) 1 7/8 Stroke (in) 10.00 No. 2 Make Ideco Model T-800 Liner Size (in) 6 Rod Dia (in) 2 1/8 Stroke (in) 9.00 Costs Daily Cost Total 52,609 Field Est To Date 544,528 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/22/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 1,158 Footage (ftKB) 0 Drill Hrs (hrs) Avg ROP (ft/hr) DFS 3

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Test bop Planned Operations Pick up BHA,Trip in hole,drlg cmt. Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 07:00 2.00 2.00 WOC 1,158 1,158 Wait on cement. 07:00 11:00 4.00 6.00 NU & Test 1,158 1,158 Cut off and weld on head, let head cool and test (good test). 11:00 23:00 12.00 18.00 NU & Test 1,158 1,158 N/U BOP. 23:00 05:00 6.00 24.00 NU & Test 1,158 1,158 Test bop, 3000 high, 250 low, remove rams from bop and clean inside of BOP.



### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 54 PV (cp) 26.0 YP (lbf/100ft2) 23 Gel 10 sec 4 Gel 10 min 7 Gel 30 min 14 Filtrate (mL/30min) 4.6 Cake (/32") 2 pH 8.3 Solids (%) 18 LGS (%) 9 MBT (lb/bbl) Oil (%) H20 (%) 80 Chlor (mg/L)

179,000 Ca (mg/L) 640 ES (V) HTHP Filt (mL/30min) 4.5 Pf (mL/mL) 0.1 Mf (mL/mL) 0.1 ECD (lb/gal) 11.10 LCM

Hole Volume (bbl) Pit Volume (bbl) 525.0 Storage Volume (bbl)

Compressors 0 Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment hauled 800 bbls from plant Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment



### Bit Run # 3 Size (in)

8 3/4 Model QD505F Make Hughes SN 7125718 Jets (/32")

15/15/15/15/15/15/15 In (ftKB) 1,179 Out (ftKB) 3,685 Drld (ftKB) 2,506 Drl Hrs (hrs) 64.00 ROP (ft/hr) 39.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 5 WT S X 0 WT PR WOB (min) (1000lbf) 6 WOB (max) (1000lbf) 15 BHA ROP (ft/hr) 39 SPP (psi) 1,225.0 Motor RPM (rpm) RPM (rpm) 119 PU (max) (1000lbf) 96 SO (1000lbf) 60 Off-Btm Str Wt (1000lbf) 62 Drag (1000lbf) 1 Start (ftKB) 1,179 End (ftKB) 1,232 

### Bit Run # 1 Size (in)

12 1/4 Model

Mach 132 Halco Make SN 7132 Jets (/32") 0 In (ftKB) 40 Out (ftKB) 1,158 Drld (ftKB) 1,118 Drl Hrs (hrs) 16.50 ROP (ft/hr) 67.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 255 0.25 705 0.75 1,113 1.25 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 774.98 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 4 DC 6 1/2 65.00 123.23 1 Jars -

Hydraulic 6 1/2 81.50 32.23

19 DC 6 1/2 65.00 579.03

1 XO Sub 6 1/2 64.00 3.06 1 Float Sub 6 1/2 64.00 5.68 1 Baker 0.34 6 3/4 64.00 30.75 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 12 4.50 16.60 X-95 4.5 316 

### Diesel Fuel Received Used 512 Cum On Location 4886 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 Liner Size (in) 6 Rod Dia (in) 1 7/8 Stroke (in) 10.00 No. 2 Make Ideco Model T-800 Liner Size (in) 6 Rod Dia (in) 2 1/8 Stroke (in) 9.00 Costs Daily Cost Total 59,492 Field Est To Date 491,919 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/21/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 1,158 Footage (ftKB) 408 Drill Hrs (hrs) 5.50 Avg ROP (ft/hr) 74.2 DFS 2

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time

woc Planned Operations Cut off @ 5:30 am and n/up bop Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 05:30 0.50 0.50 Srvys 750 750 Survey @ 705 05:30 11:00 5.50 6.00 Drilling 750 1,158 Drld 408',wob 4,rpms 40,400 psi,4000 cfm. 74.1 11:00 11:30 0.50 6.50 Trip - Other 1,158 1,158 Blow hole and pump sweep run wls @ 1113 11:30 19:00 7.50 14.00 Trip - Other 1,158 1,158 Trip out of hole to run 9 5/8 casing,pumped out 24 joints drill pipehad trouble with tongs and fuel to floor motor.
19:00 21:00 2.00 16.00 Surf Csg/Cmt 1,158 1,158 Rig up casing crew and lay down machine (held safety meeting with rig crew and all 3rd party) run 28 jts j-55 36# ,casing, shoe set @ 1118'

21:00 21:30 0.50 16.50 C&C Hole/Mud 1,158 1,158 Pumped 289 bbls fresh water mud

21:30 22:30 1.00 17.50 Surf Csg/Cmt 1,158 1,158 hole packed off ,worked pipe to 1118'

22:30 01:30 3.00 20.50 Surf Csg/Cmt 1,158 1,158 Cement with 110 sx ,1 st lead class c 14.2 #, 2 nd lead 500 sx 300% excess,class c 35;65 poz.12.9 # ,Tail 170 sx 100% excess,permium plus c ,13.7 # ,dis place w/80 bbls, circulate 69 sx's to pit
01:30 05:00 3.50 24.00 WOC 1,158 1,158 woc



### Air/Mud Data MW (lb/gal) Vis (s/qt) PV (cp) YP (lbf/100ft2) Gel 10 sec Gel 10 min Gel 30 min Filtrate (mL/30min)

Cake (/32") pH Solids (%) LGS (%) MBT (lb/bbl) Oil (%) H20 (%)

Chlor (mg/L) Ca (mg/L) ES (V) HTHP Filt (mL/30min) Pf (mL/mL) Mf (mL/mL) ECD (lb/gal) LCM

Hole Volume (bbl) Pit Volume (bbl) Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment

Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment



### Bit Run # 1 Size (in)

12 1/4 Model

Mach 132 Halco Make SN 7132 Jets (/32") 0 In (ftKB) 40 Out (ftKB) 1,158 Drld (ftKB) 1,118 Drl Hrs (hrs) 16.50 ROP (ft/hr) 67.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment TD WOB (min) (1000lbf) 4 WOB (max) (1000lbf) 4 BHA ROP (ft/hr) 68 SPP (psi) 350.0 Motor RPM (rpm) RPM (rpm) 40 PU (max) (1000lbf) 85 SO (1000lbf) 80 Off-Btm Str Wt (1000lbf) 83 Drag (1000lbf) 2 Start (ftKB) 750 End (ftKB) 1,158 Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 293 4.50 16.6 X-95 XH 9,145 3 bad jt-s-20 jts G-105 20 #-635'--/50 jts G-105 on loc. Survey Data MD (ftKB) Incl (°) Azm (°) 255 0.25 705 0.75 1,113 1.25 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Surface 9 5/8 36.00 J-55 1,118 

### BHA #1, 12 1/4 Slick BHA No. 1 Drill String Name 12 1/4 Slick Length (ft) 381.56 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 1 DC 8 16.50 2.80 2 DC 8 16.50 60.14 1 XO Sub 8 16.50 3.10 6 DC 6 1/2 16.50 186.30 1 Jars -

Hydraulic 6 1/2 16.50 32.23

3 DC 6 1/2 16.50 90.72 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 4.50 16.60 X-95 XH 

### Diesel Fuel Received Used 886 Cum On Location 5398 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 Liner Size (in) 6 Rod Dia (in) 1 7/8 Stroke (in) 10.00 No. 2 Make Ideco Model T-800 Liner Size (in) 6 Rod Dia (in) 2 1/8 Stroke (in) 9.00 Costs Daily Cost Total 112,689 Field Est To Date 432,427 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# Lariat

Report Date: 10/20/2009 Spud Date: 10/19/2009 Well Name WEST RANCH SOUTH 71-5 Proposed TD (ftKB) 9,200 MD (ftKB) 750 Footage (ftKB) 710 Drill Hrs (hrs) 11.00 Avg ROP (ft/hr) 64.5 DFS 1

Field Name ALLISON RANCH/PINON Corp ID 101577 County/Parish PECOS ST TX Section 71 Blk/Twn BLK 2 Survey/Range TCRR Operations at Report Time Drlg ahead @ 750' ---job # 11254 Planned Operations TD Surface @ 1158' TOH run 9 5/8's pipe Drilling Manager Nick Newland Drilling Engineer Richard Hill Geology Contact Frank Guerrero Field Geologist Will Murley Drilling Supt. Johnny Green Company Man Brian Ehrenberg sr.

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 15:00 10.00 10.00 Rig Up & Down 40 40 Rig up

15:00 18:00 3.00 13.00 Drilling 40 101 Drlg 61' wob 4,rpm 40, psi 300, cfm 3000. 20.3 18:00 19:30 1.50 14.50 Unplanned 101 101 Pump up wt-indictor and anchor,set kelly back ,recalibrate totco,do a 3 point calibration. 19:30 22:30 3.00 17.50 Drilling 101 300 Drlg 199',wob 4,rpms 40, psi 300,cfm 3000. 66.3 22:30 23:00 0.50 18.00 Srvys 300 300 Survey @ 255' 23:00 01:30 2.50 20.50 Drilling 300 475 Drlg 175',wob 4, rpm 40, psi 300, cfm 3000. 70 01:30 02:00 0.50 21.00 Rtn. Maint. 475 475 Service rig 02:00 04:30 2.50 23.50 Drilling 475 750 drlg 275' wob 4,rpms 40, psi 385,cfm 4000. 110 04:30 05:00 0.50 24.00 Srvys 750 750 Survey @ 705'



### Air/Mud Data MW (lb/gal) Vis (s/qt) PV (cp) YP (lbf/100ft2) Gel 10 sec Gel 10 min Gel 30 min Filtrate (mL/30min)

Cake (/32") pH Solids (%) LGS (%) MBT (lb/bbl) Oil (%) H20 (%)

Chlor (mg/L) Ca (mg/L) ES (V) HTHP Filt (mL/30min) Pf (mL/mL) Mf (mL/mL) ECD (lb/gal) LCM

Hole Volume (bbl) Pit Volume (bbl) Storage Volume (bbl) 300.0 Compressors 4 Boosters 1 Nitrogen Units 0 Air/Gas Vol. (mcf) 4,000.000 Pressure (psi) 4,380.00 Comment Pumping 20 bbls water,5 gal soap,3 gal c-202 Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment



### Bit Run # 1 Size (in)

12 1/4 Model

Mach 132 Halco Make SN 7132 Jets (/32") 0 In (ftKB) 40 Out (ftKB) 1,158 Drld (ftKB) 1,118 Drl Hrs (hrs) 16.50 ROP (ft/hr) 67.8

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment TD WOB (min) (1000lbf) 4 WOB (max) (1000lbf) 4 BHA ROP (ft/hr) 68 SPP (psi) 350.0 Motor RPM (rpm) RPM (rpm) 40 PU (max) (1000lbf) 85 SO (1000lbf) 80 Off-Btm Str Wt (1000lbf) 83 Drag (1000lbf) 2 Start (ftKB) 40 End (ftKB) 750 Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment Survey Data MD (ftKB) Incl (°) Azm (°) 255 0.25 705 0.75 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB)



### BHA #1, 12 1/4 Slick BHA No. 1 Drill String Name 12 1/4 Slick Length (ft) 381.56 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 1 DC 8 16.50 2.80 2 DC 8 16.50 60.14 1 XO Sub 8 16.50 3.10 6 DC 6 1/2 16.50 186.30 1 Jars -

Hydraulic 6 1/2 16.50 32.23

3 DC 6 1/2 16.50 90.72 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 11 4.50 16.60 X-95 XH 347 

### Diesel Fuel Received 7,002.0 Used 718 Cum On Location 6284 Last BOP Test End Date 10/22/2009

Mud Pumps No. 1 Make Emsco Model F-1000 Liner Size (in) 6 Rod Dia (in) 1 7/8 Stroke (in) 10.00 No. 2 Make Ideco Model T-800 Liner Size (in) 6 Rod Dia (in) 2 1/8 Stroke (in) 9.00 Costs Daily Cost Total 319,738 Field Est To Date 319,738 AFE Rig Release Estimate Estimate 2,456,197 A FE: 091141 

# 19 Drilling Report

# WEST RANCH SOUTH 71

- 5 P RODUCTION CEMENT PROCEDURE

Have at least 800 bbls of fresh w ater on location for cement job

9-5/8 ” Surface casing set at 1,118’ 8-3/4” hole to 8, 900 ’ currently with 11.2 ppg mud in the hole. Run 7 ” production casing to set at TD.

Run: ~7 ” f loat shoe ~1 joint 7”, 26 ppf, P-110, LTC casing (1 shoe joint) ~7 ” f loat collar ~Run 3490’ 7”, 26 ppf, P-110, LTC (Marker joint at 7,200’ ) ~7” DV tool (set at 5,410’) ~Remainder of 7” to surface

Place centralizers as follows: Shoe jo int

, 8,500’, 8,100’, 7 ,900’, 7,700’ below DV tool, above DV tool, 5,200 ’, 4,800’, 4,400’, 4,000’, 3,600’ and 3,30 0’ ( eleven total)

Once casing is run to TD and full of drilling mud, circulate casing for 1.5 hours with mud.

Before cementing, have Weatherf ord on location to operate DV tool.

RU Halliburton

Fluid 1: Precede cement with 20 bbl Stage 1

Fresh Water Fluid Volume: 20 bbl

Fluid 2: Mix and pump 255 sks 50/50 Poz Class H Cement w/ additives Fluid Weight : 14.2 lbm/gal Slurry Yield: 1.32 ft 3 

## Total Mixing Fluid: 5.61 Gal/sk / sk

Wash tub and lines if necessary

Insert Weatherford wiper plug

Displace plug to the float collar at +/ -8,860 ’ with ~ 339 bbls of drilling mud

Bump and check plug for leakage. I f plug should leak, shut in all and hold pressure for 4 -5 hours from time of plug down , call immediately

. Drop DV tool opening ball and wait for it to fall to DV tool.

Open DV tool and circulate drilling mud through DV tool for 4 .5 hrs from cement pump start time while 1st stage cement se ts.

**Watch flowline for signs of cement above DV tool.**

**Have cementer’s double check water on location before starting second stage.** 

## Fluid 1: Precede cement with 20 bbl Fresh Water Fluid Volume: 20 bbl Stage 2

Fluid 2: Mix and pump 630 sks 50/50 Poz Cl ass H Cement w/ additives Fluid Weight : 14.2 lbm/gal Slurry Yield: 1.32 ft 3 

## Total Mixing Fluid: 5.61 Gal/sk /sk

Insert DV clo sing plug and displace with ~ 207 bbls of fresh water.

Bump and check plug for leakage. If plug should leak, shut in all and hold pressure for 4-6 hours from time of plug down.

RD and MO Cementers.

ND stack and set 65,000 lbs on slips

.

Make final cut.

NU stack and test.

Capture all mud to the frac tank to be used later on the well.

Send in all required reports as soon as the cement job is complete to the Oklahoma City office: Casing Talley Casing Detail Report Cement Job Report Cementing Costs Sheet

SCAN REPORTS I NTO COMPUTER AND SEND VIA EMAIL



# Thanks,

Richard Hill

Drilling Engineer SandRidge Energy, Inc. Oklah oma City, OK (405) 429-5652 Office (405) 471-2116 Cell rhill@sdrge.com

### Stage #: 2 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 8,255' Bottom Perf: 8,270' Displ Coef: SPF: Total # of Holes: 45

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: 0.84 psi/ft ISDP: 3,362 psi Holes Open: Fluid Eff: (%) 43 5 min SIP: 3,163 psi Max Rate: Calc. Perm: mD 10 min SIP: 3,056 psi Max Pressure: Pc (psig) psi 15 min SIP: 2,980 psi

Conc. (ppg) Weight (lbs) Type

-- -

-- - 0.50 3,446 100 mesh

-- - 0.75 6,256 100 mesh

-- - 1.00 8,196 40/70 TLC

-- - 1.25 10,330 40/70 TLC

-- - 1.50 12,103 40/70 TLC

-- - 1.50 10,379 40/70 TLC

-- -

-- -

-- -

BBLS Gal LTR: 173502.0 Gals

LBS

30 % tons CO2

n/a

4,751 psig 5204 psig

47.0 bpm 60 bpm


## ISIP = 4,478 psig

No -3.0

No n/a n/a

How many ball sealers were pumped: Was there ball action seen? n/a

Avg Treating Press= Maximum =

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced? If so, by how many bbls/gal?

hours before flowing back.

Remarks/Notes Shut down after final 40/70 TLC stage for 4.25 hrs to fix augers on blender. Was well flowed back immediately? If not, well was shut-in Total Fluid Pumped: 4,131

Total Proppant: 100,331 Continue on next page if necessary

100 mesh, 40/70 TLC, 20/40 TLC, 20/40 SLC

Foam Quality: Amount of Foam Pumped: 259 DH, 5 CD Type of foam: Type of Proppant:

X-Link Breaker Time: 261.0 25# Linear Gel, 30Q CO2 5,155 65.5 211.0 25# Linear Gel, 30Q CO2 5,053 65.4

183.0 25# Linear Gel, 30Q CO2 4,399 44.2 63.0 2% KCl Substitute 4,657 42.3 246.0 25# Linear Gel, 30Q CO2 5,037 65.5 152.0 25# Linear Gel, 30Q CO2 5,056 66.3

238.0 25# Linear Gel, 30Q CO2 5,038 65.7 139.0 25# Linear Gel, 30Q CO2 4,999 65.6 237.0 25# Linear Gel, 30Q CO2 5,041 65.5 151.0 25# Linear Gel, 30Q CO2 5,046 65.0

235.0 25# Linear Gel, 30Q CO2 5,076 66.9 137.0 25# Linear Gel, 30Q CO2 5,038 66.6 372.0 25# Linear Gel, 30Q CO2 4,793 63.9 433.0 2% KCl Substitute 4,177 36.5

249.0 25# Linear Gel, 30Q CO2 5,122 64.1 107.0 25# Linear Gel, 30Q CO2 5,160 64.1 Volume (bbls) Pressure (psi) Rate (bbl/min) 2,641 3,985

FET ANALYSIS 45 Frac Grad:

Fluid Type 54 4,829

FLUIDS PUMPED PROPPANT PUMPED Liner Top Depth

27 316.2 319.0 MAXIMUM PRESSURE 3 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 12/23/2009 2:55:00 PM 9:07:00 PM

7.000

### Stage #: 2 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Pipe 1 Size: Pipe 2 Size: Top Perf: 8,255' Bottom Perf: 8,270' Displ Coef: SPF: Total # of Holes: 45

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Fluid Type Conc. (ppg) Weight (lbs) Type 1.00 5,188 20/40 TLC 2.00 9,232 20/40 TLC 3.00 8,460 20/40 TLC 4.00 12,237 20/40 TLC 4.00 14,504 20/40 SLC

-- -

Remarks/Notes 65.2 64.0 25# Linear Gel, 30Q CO2 5,116 67.0

319.0 2% KCl Substitute 5,213 55.4 Volume (bbls) Pressure (psi) Rate (bbl/min)

91.0 25# Linear Gel, 30Q CO2 5,018 66.7 67.0 25# Linear Gel, 30Q CO2 5,123 117.0 25# Linear Gel, 30Q CO2 5,209 64.9 96.0 25# Linear Gel, 30Q CO2 5,160 63.8 3

316.2 319.0 MAXIMUM PRESSURE

PROPPANT PUMPED 2,641 3,985

FLUIDS PUMPED (CONTINUED FROM PAGE 1) Liner Depth 12/23/2009 2:55:00 PM

7.000 SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 9:07:00 PM 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

### Stage #: 1 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa 2.0 14,795 20/40 Ottawa 2.5 20,083 20/40 Ottawa 3.0 18,988 20/40 Ottawa 4.0 21,642 20/40 Ottawa 4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm


## ISIP = 3,400 psig

Yes 2.0

No 4 250

FET ANALYSIS Frac Grad:

Volume (bbls) Pressure (psi) Rate (bbl/min)

Avg Treating Press= Maximum = X-Link Breaker Time: n/a FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in How many ball sealers were pumped: Was there ball action seen? n/a Foam Quality: Amount of Foam Pumped: 400 Type of foam: Type of Proppant: 20/40 Ottawa, 20/40 SLC Total Fluid Pumped: 441

Total Proppant: 97,100 57.0 3,726 30.0 4% Crystalline KCl 53.0 3,541 38.1 43.0 3,544 38.2 42.0 3,896 38.4 32.0 3,873 37.1 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 16.0 2,560 2.0 40.0 3,882 38.0

56.0 3,292 38.0 22.0 3,485 38.8 35.0 3,507 37.0 20# Linear gel, 80Q CO2 12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7 4% Crystalline KCl 20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2 3,125 Displ Coef: 0.0383 0.5 - 2 SPF Liner Top Depth 7.000

MAXIMUM PRESSURE 198.0 199.2 

# SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s): Treatment Report

Superior Well Services Jason Stewart

### Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report 1 sec (or 2 sec) data in .csv of .txt form Service Company Treatment Report Service Company Field Ticket 

## areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com; mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com; tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com; scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com

### Stage #: 3 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 7,910' Bottom Perf: 8,140' Displ Coef: SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: 0.66 psi/ft ISDP: 1,807 psi Holes Open: Fluid Eff: (%) 53 5 min SIP: 1,613 psi Max Rate: Calc. Perm: mD 10 min SIP: 1,553 psi Max Pressure: Pc (psig) psi 15 min SIP: 1,490 psi

Conc. (ppg) Weight (lbs) Type

-- -

-- - 0.50 4,100 100 mesh

-- -

-- - 0.75 5,905 100 mesh

-- - 1.00 8,411 40/70 TLC

-- - 1.25 10,451 40/70 TLC

-- - 1.50 12,126 40/70 TLC

-- - 1.50 13,100 40/70 TLC

-- - 1.00 8,205 20/40 TLC

BBLS Gal LTR: 158592.0 Gals

LBS

30 % tons CO2

n/a

3,788 psig 3937 psig

79.5 bpm 84.8 bpm


## ISIP = 3,004 psig

no 0.0

no n/a n/a

How many ball sealers were pumped: Was there ball action seen? n/a

Avg Treating Press= Maximum =

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced? If so, by how many bbls/gal?

hours before flowing back.

Remarks/Notes Blender densometer not working, flush well after 0.5 ppg 100 mesh stage and shut down for 5 minutes to repair. Resumed pumping, blender densometer still not working. Proppant count based on inline densometer. Weight tickets indicate 10,005 lbs 100 mesh, 44,088 lbs 40/70 TLC, 67,907 lbs 20/40 TLC, and 13,455 lbs 20/40 SLC. Was well flowed back immediately? If not, well was shut-in Total Fluid Pumped: 3,776

Total Proppant: 135,455 Continue on next page if necessary

100 mesh, 40/70 TLC, 20/40 TLC, 20/40 SLC

Foam Quality: Amount of Foam Pumped: 228 DH, 4 CD Type of foam: Type of Proppant:

X-Link Breaker Time: 142.0 25# Linear Gel, 30Q CO2 3,858 79.0 88.0 25# Linear Gel, 30Q CO2 3,802 78.9

145.0 25# Linear Gel, 30Q CO2 3,923 79.6 85.0 25# Linear Gel, 30Q CO2 3,870 79.9 140.0 25# Linear Gel, 30Q CO2 3,756 78.6 92.0 25# Linear Gel, 30Q CO2 3,754 78.9

153.0 25# Linear Gel, 30Q CO2 3,796 78.5 90.0 25# Linear Gel, 30Q CO2 3,765 79.0 185.0 25# Linear Gel, 30Q CO2 3,755 79.3 321.0 25# Linear Gel, 30Q CO2 3,468 68.1

121.0 25# Linear Gel, 30Q CO2 3,747 78.5 89.0 25# Linear Gel, 30Q CO2 3,744 79.4 443.0 25# Linear Gel, 30Q CO2 3,184 51.5 456.0 2% KCl Substitute 2,544 40.9

311.0 25# Linear Gel, 30Q CO2 3,621 78.2 148.0 25# Linear Gel, 30Q CO2 3,594 80.8 Volume (bbls) Pressure (psi) Rate (bbl/min) 3,600 1,907

FET ANALYSIS 90 Frac Grad:

Fluid Type 59 2,999

FLUIDS PUMPED PROPPANT PUMPED Liner Top Depth

56 303.0 303.0 MAXIMUM PRESSURE 0.5 - 2 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 12/24/2009 5:25:00 AM 7:18:00 AM

7.000

### Stage #: 3 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Pipe 1 Size: Pipe 2 Size: Top Perf: 7,910' Bottom Perf: 8,140' Displ Coef: SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Fluid Type Conc. (ppg) Weight (lbs) Type 2.00 17,847 20/40 TLC 3.00 21,603 20/40 TLC 4.00 19,395 20/40 TLC 4.00 14,312 20/40 SLC

-- -

Remarks/Notes 80.4 81.0 25# Linear Gel, 30Q CO2 3,751 83.4 Volume (bbls) Pressure (psi) Rate (bbl/min)

303.0 2% KCl Substitute 3,584 55.4 91.0 25# Linear Gel, 30Q CO2 3,719 137.0 25# Linear Gel, 30Q CO2 3,752 78.9 155.0 25# Linear Gel, 30Q CO2 3,848 79.3 0.5 - 2

303.0 303.0 MAXIMUM PRESSURE

PROPPANT PUMPED 3,600 1,907

FLUIDS PUMPED (CONTINUED FROM PAGE 1) Liner Depth 12/24/2009 5:25:00 AM

7.000 SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 7:18:00 AM 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

### Stage #: 1 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa 2.0 14,795 20/40 Ottawa 2.5 20,083 20/40 Ottawa 3.0 18,988 20/40 Ottawa 4.0 21,642 20/40 Ottawa 4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm


## ISIP = 3,400 psig

Yes 2.0

No 4 250

FET ANALYSIS Frac Grad:

Volume (bbls) Pressure (psi) Rate (bbl/min)

Avg Treating Press= Maximum = X-Link Breaker Time: n/a FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in How many ball sealers were pumped: Was there ball action seen? n/a Foam Quality: Amount of Foam Pumped: 400 Type of foam: Type of Proppant: 20/40 Ottawa, 20/40 SLC Total Fluid Pumped: 441

Total Proppant: 97,100 57.0 3,726 30.0 4% Crystalline KCl 53.0 3,541 38.1 43.0 3,544 38.2 42.0 3,896 38.4 32.0 3,873 37.1 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 16.0 2,560 2.0 40.0 3,882 38.0

56.0 3,292 38.0 22.0 3,485 38.8 35.0 3,507 37.0 20# Linear gel, 80Q CO2 12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7 4% Crystalline KCl 20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2 3,125 Displ Coef: 0.0383 0.5 - 2 SPF Liner Top Depth 7.000

MAXIMUM PRESSURE 198.0 199.2 

# SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s): Treatment Report

Superior Well Services Jason Stewart

### Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report 1 sec (or 2 sec) data in .csv of .txt form Service Company Treatment Report Service Company Field Ticket 

## areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com; mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com; tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com; scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com

### Stage #: 4 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 7,624' Bottom Perf: 7,756' Displ Coef: SPF: Total # of Holes: 110

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: 0.77 psi/ft ISDP: 2,603 psi Holes Open: Fluid Eff: (%) 56 5 min SIP: 2,253 psi Max Rate: Calc. Perm: mD 10 min SIP: 2,113 psi Max Pressure: Pc (psig) psi 15 min SIP: 1,990 psi

Conc. (ppg) Weight (lbs) Type

-- -

-- - 0.50 2,382 100 mesh

-- - 0.75 4,593 100 mesh

-- -

-- - 1.00 6,090 40/70 TLC

-- - 1.25 8,756 40/70 TLC

-- - 1.50 9,819 40/70 TLC

-- -

-- - 1.50 10,445 40/70 TLC

-- -

BBLS Gal LTR: 123396.0 Gals

LBS

30 % tons CO2

n/a

5,117 psig 5767 psig

61.7 bpm 81.8 bpm


## ISIP = 4,342 psig

Yes 50.0

No 4 n/a

How many ball sealers were pumped: Was there ball action seen? n/a

Avg Treating Press= Maximum =

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced? If so, by how many bbls/gal?

hours before flowing back.

Remarks/Notes Wellhead isolation tool cups were not set. Shut down during sweep after 0.75 ppg 100 mesh stage for 15 minutes due to leak. Resumed pumping and shut down during sweep after first 1.5 ppg stage for lost blender tub. Proppant for first 100 mesh stage was not recorded on densometers, value is based on weight tickets for 100 mesh less densomter total for second 100 mesh stage. Was well flowed back immediately? If not, well was shut-in Total Fluid Pumped: 2,938

Total Proppant: 75,473 Continue on next page if necessary

100 mesh, 40/70 TLC, 20/40 TLC, 20/40 SLC

Foam Quality: Amount of Foam Pumped: 176 DH, 8 CD Type of foam: Type of Proppant:

X-Link Breaker Time: 144.0 25# Linear Gel, 30Q CO2 4,371 56.0 39.0 25# Linear Gel, 30Q CO2 4,101 47.9

88.0 25# Linear Gel, 30Q CO2 5,266 77.7 122.0 25# Linear Gel, 30Q CO2 5,347 76.8 119.0 25# Linear Gel, 30Q CO2 5,210 80.3 171.0 25# Linear Gel, 30Q CO2 5,171 81.0

104.0 25# Linear Gel, 30Q CO2 5,178 80.4 160.0 25# Linear Gel, 30Q CO2 5,134 80.7 70.0 25# Linear Gel, 30Q CO2 4,467 60.8 88.0 25# Linear Gel, 30Q CO2 5,131 79.4

126.0 25# Linear Gel, 30Q CO2 5,236 80.4 116.0 25# Linear Gel, 30Q CO2 4,594 65.4 370.0 25# Linear Gel, 30Q CO2 5,011 77.3 385.0 2% KCl Substitute 3,625 35.2

240.0 25# Linear Gel, 30Q CO2 4,954 77.0 99.0 25# Linear Gel, 30Q CO2 5,074 82.0 Volume (bbls) Pressure (psi) Rate (bbl/min) 690 2,981

FET ANALYSIS 110 Frac Grad:

Fluid Type 57 4,343

FLUIDS PUMPED PROPPANT PUMPED Liner Top Depth

27 292.0 242.0 MAXIMUM PRESSURE 1 - 3 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 12/24/2009 2:55:00 PM 5:23:00 PM

7.000

### Stage #: 4 Formation: 1st Caballos

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Pipe 1 Size: Pipe 2 Size: Top Perf: 7,624' Bottom Perf: 7,756' Displ Coef: SPF: Total # of Holes: 110

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Fluid Type Conc. (ppg) Weight (lbs) Type 1.00 3,212 20/40 TLC 2.00 6,091 20/40 TLC 3.00 13,991 20/40 TLC 4.00 10,094 20/40 SLC

Remarks/Notes 78.9 84.0 25# Linear Gel, 30Q CO2 5,226 77.8 Volume (bbls) Pressure (psi) Rate (bbl/min)

242.0 2% KCl Substitute 5,256 52.5 69.0 25# Linear Gel, 30Q CO2 5,390 56.0 25# Linear Gel, 30Q CO2 5,387 79.0 46.0 25# Linear Gel, 30Q CO2 5,272 79.3 1 - 3

292.0 242.0 MAXIMUM PRESSURE

PROPPANT PUMPED 690 2,981

FLUIDS PUMPED (CONTINUED FROM PAGE 1) Liner Depth 12/24/2009 2:55:00 PM

7.000 SandRidge Supervisor(s): Paul White (prepared by J. Stewart) Superior Well Services

Displ Coef: 0.0383 5:23:00 PM 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

### Stage #: 1 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa 2.0 14,795 20/40 Ottawa 2.5 20,083 20/40 Ottawa 3.0 18,988 20/40 Ottawa 4.0 21,642 20/40 Ottawa 4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm


## ISIP = 3,400 psig

Yes 2.0

No 4 250

FET ANALYSIS Frac Grad:

Volume (bbls) Pressure (psi) Rate (bbl/min)

Avg Treating Press= Maximum = X-Link Breaker Time: n/a FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in How many ball sealers were pumped: Was there ball action seen? n/a Foam Quality: Amount of Foam Pumped: 400 Type of foam: Type of Proppant: 20/40 Ottawa, 20/40 SLC Total Fluid Pumped: 441

Total Proppant: 97,100 57.0 3,726 30.0 4% Crystalline KCl 53.0 3,541 38.1 43.0 3,544 38.2 42.0 3,896 38.4 32.0 3,873 37.1 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 16.0 2,560 2.0 40.0 3,882 38.0

56.0 3,292 38.0 22.0 3,485 38.8 35.0 3,507 37.0 20# Linear gel, 80Q CO2 12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7 4% Crystalline KCl 20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2 3,125 Displ Coef: 0.0383 0.5 - 2 SPF Liner Top Depth 7.000

MAXIMUM PRESSURE 198.0 199.2 

# SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s): Treatment Report

Superior Well Services Jason Stewart

### Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report 1 sec (or 2 sec) data in .csv of .txt form Service Company Treatment Report Service Company Field Ticket 

## areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com; mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com; tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com; scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.comSandRidge Energy Daily Completions ReportWRS 71-5 - SandRidge EnergyReport Start DateReport End DateDaily SummaryDaily Production Summary12/1/200912/2/2009NU WH & clean pits. Rig released 12/1/09.12/2/200912/3/2009WOCU. Temporarily drop fr/ report.12/6/200912/7/2009MIRU WSU. NU manual frac valve & NU BOP. TIH w/ bit, sub, DC, XO, XN nipple & 162 jts tbg& tagged DV tool @ 5,343'. TOH w/ 1 jt tbg to 5,311'. SWI & SDFN. Prep f/ DO.12/7/200912/8/2009RU PS. TIH w/ tbg & tagged cmt @ 5,343'. Est circ. Drld 59' cmt to DV tool @ 5,402' & DO.Cont TIH w/ 106 jts tbg & CO to 8,795'. Rev circ; dsplc'd w/ 400 bbls 2% KCL. RD PS. POH w/254 jts tbg, DC & bit; LD 16 jts tbg. SWI & SDFN. Prep to run scraper & f/ WL.12/8/200912/9/2009TIH w/ WEG, XO, scraper, DC's, XO, XN nipple & 163 jts tbg to 5,343'. Cleaned cmt off csg &dressed up DV tool @ 5,402'. Cont TIH w/ scraper to 5,722'. TOH w/ tbg & LD DC & scraper.MIRU WL. RIH w/ CBL/CCL/GR & logged 8,827'-2,500' w/ 1000 psi on csg. TOC @ 6,750' &2,704'. SWI & SDFN. Prep to perf.12/9/200912/10/2009Tstd csg to 4800 psi; bled dn. Perf'd 1st Cab 8,360'-8,380' w/ 1 SP2 ft; 8,500'-8,530' w/ 1 SPF;8,600'-8,630' w/ 2 SPF (100 holes) using 4" csg guns 60 deg phased. POH. RDMO WL. TIH w/WEG, XN nipple w/ no-go, sub, AS1X pkr w/ on-off tool, X profile, X nipple & 258 jts tbg; set pkr@ 8,327'; EOT @ 8,333'; XN nipple @ 8,332'; X profile @ 8,319' & XN nipple @ 8,285'. ND BOP.NU tree. RDMO WSU. SDFN.12/10/2009 12/11/20090 psi - SITP/SICP. MIRU swab. IFL @ sfc. Made 8 runs. EFL @ 8,200'. Press csg to 500 psi.Loaded tbg w/ 22 bbls 2% KCL. BD 1st Cab @ 2920 psi w/ 20 bbls. Est inj rate @ 4400 psi & 4.7bpm. 42 TLTR. Swabbed. IFL @ sfc. Made 10 runs; no tail gas. EFL @ 4,800'. SWI & SDFN. Rec'd 0 MCF, 0 BO, 77 BLW (35 BWOL); SI.12/11/200912/12/200920 psi - BTP; 0 psi - BCP. Swabbed. IFL @ 2,000'. Made 17 runs; no show of gas. EFL @7,600'. RDMO swab. SWI & SDFN.Rec'd 0 MCF, 0 BO, 64 BW (99 BWOL); SI.12/12/200912/13/20090 psi - SITP/SICP. MIRU WSU. NU BOP. Rel'd pkr. TOH & LD 250 jts tbg & pkr. ND BOP.RDMO WSU. WO frac.12/13/200912/14/2009SI; WO frac 12/21-22. Temporarily drop fr/ report pending further activity.12/22/200912/23/2009Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 147M lbs 100 Mesh, 20/40 TLC & SLC & 40/70 TLCsd, 4462 TLTR, 1613 bbls CO2. RU WL. RIH & set 7" CIBP @ 8,330'. POH. Press tstd csg &plug to 4850 psi. Bled off. Perf'd 1st Cab 8,255'-8,270' w/ 3 SPF (45 shots) using 4" csg guns 60deg phased. RD WL. SD due to equip failure. SDFN. WO blender repairs.12/23/200912/24/2009Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 102M lbs 100 Mesh, 20/40 TLC & SLC & 40/70 TLCsd, 4131 TLTR, 1450 bbls CO2. RU WL. RIH & set 7" CBP @ 8,180'. Tstd plug to 4860 psi.Perf'd 1st Cab 7,910'-7,930' w/ 1 SP2F; 7,986'-8,006'; 8,036'-8,056' w/ 1 SPF; 8,120'-8,140' w/ 2SPF (90 holes) using 4" csg guns 60 deg phased. RD WL. SDFN. Prep f/ frac.12/24/200912/25/2009Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 135M lbs 100 Mesh, 20/40 TLC & SLC & 40/70 TLCsd, 3742 TLTR, 1299 bbls CO2. RU WL. RIH & set CBP @ 7,800'. Tstd plug to 4842 psi. Perf'd1st Cab 7,624'-7,654' w/ 1 SPF; 7,708'-7,718' w/ 2 SPF; 7,736'-7,756' w/ 3 SPF (110 holes) using4" csg guns 60 deg phased. RDMO WL. Frac'd w/ 25# linear gel, 30Q CO2, 84M lbs 100 Mesh,20/40 TLC & SLC & 40/70 TLC sd, 2956 TLTR, 986 bbls CO2. Screened out 50 bbls short offlush. Flwg back load after frac.Rec'd 0 MCF, 0 BO, 246 BLW (2710 LLTR) on 12/64 choke@ 3000 psi - FCP.12/25/200912/26/2009Flwg back load after frac.Rec'd 0 MCF, 0 BO, 564 BLW (2146 LLTR); lt sd on 12/64choke @ 1400 psi - FCP.1 of 4SandRidge Energy Daily Completions Report12/26/2009 12/27/2009MIRU CTU. Tstd tbg to 3500 psi. RIH w/ CT, tagged 1st plug @ 7,800' & DO; chased to 8,155'.DO plug @ 8,180', chased to 3rd plug @ 8,330' & DO. CO to 8,750'. POH w/ CT. RDMO CTU.Total 1367 bbls 7% KCL pmpd. Flwg to tank.Rec'd 0 MCF, 0 BO, 3285 BLW (10317 LLTR); lt sd on 12/64choke @ 1400 psi - FCP.12/27/2009 12/28/2009 Flwg to tank.Rec'd 0 MCF, 0 BO, 538 BLW (9779 LLTR); lt sd on 14/64choke @ 1100 psi - FCP.12/28/2009 12/29/2009 Flwg to tank.Rec'd 0 MCF, 0 BO, 568 BLW (9211 LLTR) on 14/64 choke@ 1000 psi - FCP.12/29/2009 12/30/2009 Flwg to tank.Rec'd 0 MCF, 0 BO, 719 BLW (8492 LLTR) on 18/64 choke@ 900 psi - FCP.12/30/2009 12/31/2009 Flwg to tank.Rec'd 0 MCF, 0 BO, 715 BLW (7777 LLTR) on 18/64 choke@ FCP - 875 psi.12/31/2009 1/1/2010 Flwg to tank.Rec'd 0 MCF, 0 BO, 961 BLW (6816 LLTR), 24 hrs on 22/64choke @ FCP - 975 psi.1/1/2010 1/2/2010 Flwg to tank.Rec'd 0 MCF, 0 BO, 813 BLW (6003 LLTR), 24 hrs on 26/64choke @ FCP - 950 psi.1/2/2010 1/3/2010 Flwg to tank.Rec'd 0 MCF, 0 BO, 819 BLW (5184 LLTR), 24 hrs on 26/64choke @ FCP - 865 psi.1/3/2010 1/4/2010 Flwg to tank.Rec'd 0 MCF, 0 BO, 796 BLW (4388 LLTR), 24 hrs on 26/64choke @ FCP - 900 psi.1/4/2010 1/5/2010FCP - 750 psi. MIRU SLU. RIH w/ GR & sinker bars to 8,650'. POH & LD GR. Ran prodn log7,500'-8,650'. RDMO SLU. Flwg to tank.Rec'd 0 MCF, 0 BO, 568 BLW (3820 LLTR), 24 hrs on 26/64choke @ FCP - 680 psi.1/5/2010 1/6/2010FCP - 660 psi. SWI & 2:00 p.m. MIRU WL. RIH w/ GR to 8,350'. POH. RIH & set 7" CIBP @8,335'. POH. Dump bailed 2 sx cmt on CIBP. RDMO WL. Opened to tank @ 5:30 p.m.Rec'd 0 MCF, 0 BO, 454 BLW (3366 LLTR), 12 hrs on 26/64choke @ FCP - 600 psi.1/6/2010 1/7/2010MIRU WSU. ND hydraulic frac valve & NU BOP. FIRST SALES @ 4:00 p.m. on 1/6/2010. Flwgto tank due to incr LP. Prep to set CIBP.1004 MCF (spot), 0 BO, 356 BLW (3010 LLTR), 11 hrs on26/64 choke @ FCP - 520 psi.1/7/2010 1/8/2010Flwd to sales 8 hrs. SWI @ 1:00 p.m. MIRU WL. RIH & set 7" CIBP @ 8,200'. POH. RIH &dump bailed 2 sx cmt on CIBP. POH. RDMO WL. Flwd to tank 12 hrs.0 MCF, 0 BO, 272 BLW (2738 LLTR), 8 hrs on 26/64 choke@ FCP - 440 psi.1/8/2010 1/9/2010FCP - 380 psi. MIRU SLU. RIH w/ GR & tagged 8,185'. POH. Ran flwg gradient survey.RDMO SLU. Flwg to tank.0 MCF, 0 BO, 200 BLW (2538 LLTR), 24 hrs on 26/64 choke@ FCP - 440 psi.1/9/2010 1/10/2010 Flwg to tank through test equip.0 MCF, 0 BO, 131 BLW (2407 LLTR), 24 hrs on 21/64 choke@ FCP - 200 psi.1/10/2010 1/11/2010 Unable to overcome LP. Turned to tank. SI @ 10 a.m. SDFN. Prep f/ WL.0 MCF, 0 BO, 11 BLW (2396 LLTR), 24 hrs on 32/64 choke@ FCP - 160 psi.1/11/2010 1/12/2010SICP - 850 psi. MIRU WL. Ran GR & JB to 4,890'. RIH & set 7" CBP @ 4,870'. Blew dn csg.Tstd csg to 4800 psi w/ 180 bbls 4% KCL. Perf'd Tesnus 4,696'-4,706'; 4,726'-4,736' w/ 1 SP2F;4,768'-4,778'; 4,790'-4,810' w/ 1 SPF (40 holes) using 4" csg guns 60 deg phased. RDMO WL.SDFN. Prep to run tbg & pkr.0 MCF, 0 BO, 11 BLW (2396 LLTR), 24 hrs on 32/64 choke@ FCP - 850 psi.1/12/2010 1/13/2010SICP - 0 psi. TIH w/ WEG, sub, AS1X pkr, T-2 on/off tool, X nipple & 143 jts tbg; set pkr @ 4,629'w/ 5 pts compression. NU tree. Tstd csg & pkr to 800 psi. RU swab. IFL @ sfc. Made 11 runs;pulled out of rope socket on 11th run. EFL @ 4,100'. Rel'd pkr. TOH w/ 76 jts tbg; rec'd tools.TIH & set pkr @ 4,640' w/ 6 pts compression. ND BOP & NU tree. SDFN. 0 MCF, 0 BO, 23 BLW (2373 LLTR).2 of 4SandRidge Energy Daily Completions Report1/13/2010 1/14/2010SITP - 0 psi. Loaded annulus w/ 15 bbls 4% KCL. Tstd pkr to 800 psi. RDMO WSU. MIRUswab. IFL @ 500'. Made 6 runs. EFL @ 4,300'. Loaded tbg w/ 15 bbls 4% KCL. Pmpd 5 BF &BD @ 3000 psi & 3 bpm. Cont'd swabbing. IFL @ sfc. Made 6 runs. EFL @ 4,000'. SWI & 0 MCF, 0 BO, 33 BLW (2360 LLTR); SI.1/14/2010 1/15/2010SITP/SICP. IFL @ 3,600'. Made 4 runs to 4,500'; no tail gas. EFL @ 4,500'. RDMO swab. RUSLU. Located X nipple @ 4,571' & XN nipple @ 4,622'. RIH & set press bombs abv XN nipple.POH. RDMO SLU. SWI & SDFN. 0 MCF, 0 BO, 4 BLW (2356 LLTR); SI.1/15/2010 1/16/2010 SIFBU.0 MCF, 0 BO, 0 BLW (2356 LLTR); SITP - 10 psi; SICP - 0psi.1/16/2010 1/17/2010 SIFBU.0 MCF, 0 BO, 0 BLW (2356 LLTR); SITP - 35 psi; SICP - 0psi.1/17/2010 1/18/2010MIRU SLU. Pulled BHP gauges. MIRU WSU. ND tree. NU manual frac valve & hydraulic BOP.Rel'd AS1X pkr. TOH w/ 132 jts tbg & pkr. ND BOP's & ND hydraulic frac valve. SDFN. Prep f/frac sch 1/19.0 MCF, 0 BO, 0 BLW (2356 LLTR); SITP - 10 psi; SICP - 0psi.1/18/2010 1/19/2010 MIRU frac svcs. SDFN.1/19/2010 1/20/2010Frac'd Tesnus w/ 20# linear gel, 70-85Q CO2, 80M lbs 20/40 Ottawa & 20/40 CRC sd, 555 TLTR,997 bbls CO2. RU WL. RIH w/ CCL & set 7" CFP @ 4,040'. POH. Tstd plug to 4800 psi. Perf'dTesnus 3,870'-3,880'; 3,920'-3,930' w/ 1 SPF; 3,990'-4,000' w/ 2 SPF (40 holes) using 4" guns 60deg phased. RD WL. Frac'd w/ 20# linear gel, 70-85Q CO2, 56M lbs 20/40 Ottawa & 20/40 CRCsd, 418 TLTR, 795 bbls CO2. RU WL. RIH w/ CCL & set 7" CFP @ 3,740'. POH. Tstd plug to4800 psi. Perf'd Tesnus 3,494'-3,504'; 3,544'-3,574' w/ 1 SP2F; 3,626'-3,634'; 3,662'-3,672';3,690'-3,700' w/ 1 SPF (48 holes) using 4" guns 60 deg phased. RD WL. SWI & SDFN. WOfrac sch 1/20.1/20/2010 1/21/2010Frac'd Tesnus w/ 20# linear gel, 60-85Q CO2, 146M lbs 20/40 Ottawa & CRC sd, 645 TLTR,1747 bbls CO2. MIRU CTU. RIH w/ mill centralizer, extreme motor & CT circ .23 bpm, tagged &DO 1st CFP @ 3,744'; chased plug. Cont RIH & tagged 2nd CFP @ 4,042' & DO; chased plug.Washed to 3rd CBP @ 4,862'. Circ clean. POH. RDMO CTU. Total 600 BW pmpd. Flwg backload after frac.0 MCF, 0 BO, 1160 BLW (2769 LLTR), lt sd on 24/64 choke@ FCP - 600 psi.1/21/2010 1/22/2010FCP - 600 psi. MIRU WSU & WL. RIH w/ dump bailer & tagged 4,779'; 91' fill on CBP @ 4,870'.POH & LD bailer. RDMO WL. NU hydraulic BOP's. Flwg to tank. Prep to run tbg.0 MCF, 0 BO, 333 BLW (2436 LLTR) on 24/64 choke @ FCP300 psi.1/22/2010 1/23/2010MIRU snub unit. TIH w/ NC, XN nipple w/ PT plug & 147 jts tbg, tagged 4,760' & washed to4,830'. Circ. TOH & LD 4 jts tbg; EOT @ 4,729'; XN nipple @ 4,697'; 146 jts tbg IH. RD snubunit. ND hydraulic BOP & manual frac valve. NU tree. Tied into flowlines. MIRU SLU. RIH,tagged plug @ 4,672' & fished plug fr/ XN nipple. POH & LD plug. RDMO SLU. Total 58 BFpmpd. Flwd to tank; died. SIFBU. 0 MCF, 0 BO, 120 BLW (2316 LLTR); SICP - 1000 psi.1/23/2010 1/24/2010TP - 0 psi; CP - 1000 psi. Pmpd FA dn csg 3 hrs; no ret's. Jetted tbg w/ FA 2 hrs; rec'd 78 BF.Jetted csg 2 hrs; no rec'y. Flwd to tank. Turned to sales.0 MCF, 0 BO, 124 BLW (2192 LLTR); FTP - 300 psi; SICP -550 psi.1/24/2010 1/25/2010 RDMO WSU. Flwg to sales.223 MCF, 0 BO, 81 BLW (2111 LLTR), 6 hrs on 24/64 choke@ FTP - 300 psi; SICP - 600 psi; LP - 142 psi.1/25/2010 1/26/2010 Flwg to sales.637 MCF, 0 BO, 55 BLW (2056 LLTR), 22 hrs on 1" choke @FTP - 100 psi; SICP - 500 psi; LP - 105 psi.1/26/2010 1/27/2010 Flwg to sales.505 MCF, 0 BO, 52 BLW (2004 LLTR), 20 hrs on 1" choke @FTP - 160 psi; SICP - 400 psi; LP - 100 psi.3 of 4SandRidge Energy Daily Completions Report1/27/2010 1/28/2010 Flwg to sales.477 MCF, 0 BO, 33 BLW (1971 LLTR), 20 hrs on 1" choke @FTP - 110 psi; SICP - 250 psi; LP - 98 psi.1/28/2010 1/29/2010 Flwg to sales.551 MCF, 0 BO, 27 BLW (1944 LLTR), 24 hrs on 1" choke @FTP - 100 psi; SICP - 230 psi; LP - 95 psi.1/29/2010 1/30/2010 Flwg to sales.518 MCF, 0 BO, 26 BLW (1918 LLTR), 24 hrs on 1" choke @FTP - 100 psi; SICP - 225 psi; LP - 85 psi.1/30/2010 1/31/2010 Flwg to sales.463 MCF, 0 BO, 20 BLW (1898 LLTR), 24 hrs on 1" choke @FTP - 115 psi; SICP - 220 psi; LP - 91 psi.1/31/2010 2/1/2010 Flwg to sales.485 MCF, 0 BO, 18 BLW (1890 LLTR), 24 hrs on 1" choke @FTP - 95 psi; SICP - 190 psi; LP - 87 psi.2/1/2010 2/2/2010 Flwg to sales.477 MCF, 0 BO, 17 BLW (1873 LLTR), 24 hrs on 1" choke @FTP - 95 psi; SICP - 180 psi; LP - 88 psi.2/2/2010 2/3/2010 Flwg to sales. FINAL REPORT.458 MCF, 0 BO, 15 BLW (1858 LLTR), 24 hrs on 1" choke @FTP - 105 psi; SICP - 190 psi; LP - 89 psi.4 of 4

### 12/24/09

WELL NAME: REPORT DATE: 

### 12/24/2009-12/25/2009
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 0 0 15,291 07:00 0 0 15,291 08:00 0 0 15,291 09:00 0 0 15,291 10:00 0 0 15,291 11:00 0 0 15,291 12:00 0 0 15,291 13:00 0 0 15,291 14:00 0 0 15,291 15:00 0 0 15,291 16:00 0 0 15,291 17:00 0 0 15,291 18:00 0 0 15,291 19:00 0 0 15,291 20:00 0 0 15,291 21:00 0 0 15,291 Open 21:30/SICP 2500 22:00 12 2,200 18 18 18 15,273 23:00 12 2,200 45 63 63 15,228 24:00 12 2,500 39 102 102 15,189 01:00 12 3,000 34 136 136 15,155 Gauge double checked 02:00 12 3,500 30 166 166 15,125 03:00 12 4,000 20 186 186 15,105 04:00 12 3,500 30 216 216 15,075 No Sand 05:00 12 3,000 30 246 246 15,045 Wet CO2 Sample

TOTAL LOAD TO RECOVER: 15291 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 246 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 246 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 15045 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 2 %

Jordan Rivera 432-360-5347 TL =15291 BBLS. DLR = 246 BBLS. TLR = 246 BBLS 15045 BBLS. 2% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris Yanez 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 12/25/09

WELL NAME: REPORT DATE: 

### 12/25/2009-12/26/2009
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 12 2,500 36 36 282 15,009 07:00 12 2,000 30 66 312 14,979 08:00 12 1,800 29 95 341 14,950 Light Sand 09:00 12 1,750 20 115 361 14,930 100% CO2 10:00 12 1,600 31 146 392 14,899 11:00 12 1,550 27 173 419 14,872 12:00 12 1,550 22 195 441 14,850 Light Sand 13:00 12 1,550 22 217 463 14,828 14:00 12 1,450 24 241 487 14,804 15:00 12 1,500 26 267 513 14,778 16:00 12 1,500 23 290 536 14,755 17:00 12 1,500 22 312 558 14,733 18:00 12 1,500 22 334 580 14,711 Light Sand 19:00 12 1,400 23 357 603 14,688 20:00 12 1,400 25 382 628 14,663 21:00 12 1,400 21 403 649 14,642 22:00 12 1,400 20 423 669 14,622 23:00 12 1,400 24 447 693 14,598 24:00 12 1,400 25 472 718 14,573 01:00 12 1,400 18 490 736 14,555 02:00 12 1,400 18 508 754 14,537 03:00 12 1,400 18 526 772 14,519 04:00 12 1,400 18 544 790 14,501 Light Sand 05:00 12 1,400 20 564 810 14,481 100% CO2

TOTAL LOAD TO RECOVER: 15291 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 564 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 810 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 14481 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 5 %

Jordan Rivera 432-360-5347 TL =15291 BBLS. DLR = 564 BBLS. TLR = 810 BBLS. LTR = 14481 BBLS. 5% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris Yanez 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 12/26/09

WELL NAME: REPORT DATE: 

### 12/26/2009-12/27/2009
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 12 1,400 24 24 834 14,457 Flowing to flowback tank 07:00 12 1,350 19 43 853 14,438 08:00 12 1,300 23 66 876 14,415 09:00 12 1,350 9 75 885 14,406 10:00 14 1,350 9 84 894 14,397 Light Sand 11:00 16 1,250 22 106 916 14,375 12:00 16 1,200 22 128 938 14,353 100% CO2 (Digital) 13:00 16 1,200 24 152 962 14,329 14:00 16 1,200 25 177 987 14,304 15:00 ADJ 177 987 14,304 Drillout/Cleanout 16:00 ADJ 177 987 14,304 17:00 ADJ 177 987 14,304 18:00 ADJ 177 987 14,304 Light Sand 19:00 ADJ 177 987 14,304 20:00 ADJ 177 987 14,304 21:00 ADJ 177 987 14,304 22:00 ADJ 177 987 14,304 23:00 ADJ 177 987 14,304 24:00 ADJ 177 987 14,304 01:00 ADJ 177 987 14,304 02:00 12 1,400 3,044 3,221 4,031 12,627 1367 bbls pumped 03:00 12 1,400 20 3,241 4,051 12,607 04:00 12 1,350 24 3,265 4,075 12,583 Light Sand 05:00 12 1,350 20 3,285 4,095 12,563 100% CO2 (Digital)

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 3285 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 4095 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 12563 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 25 % 1st, 2nd, 3rd, and 4th Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

Jordan Rivera 432-360-5347 TL =16658 BBLS. DLR = 3285 BBLS. TLR = 4095 BBLS. LTR = 12563 BBLS. 25% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris Yanez 432-238-1392

### 12/27/09

WELL NAME: REPORT DATE: 

### 12/27/2009-12/28/2009
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 12 1,350 20 20 4,115 12,543 07:00 12 1,300 22 42 4,137 12,521 08:00 12 1,300 24 66 4,161 12,497 Light Sand 09:00 12 1,250 20 86 4,181 12,477 10:00 12 1,250 22 108 4,203 12,455 100% CO2 11:00 12 1,200 18 126 4,221 12,437 12:00 12 1,200 10 136 4,231 12,427 13:00 14 1,200 25 161 4,256 12,402 14:00 14 1,200 21 182 4,277 12,381 Light Sand 15:00 14 1,200 39 221 4,316 12,342 16:00 12 1,200 26 247 4,342 12,316 17:00 12 1,200 27 274 4,369 12,289 18:00 12 1,200 25 299 4,394 12,264 Light Sand 19:00 12 1,200 20 319 4,414 12,244 20:00 12 1,200 15 334 4,429 12,229 21:00 12 1,200 16 350 4,445 12,213 100% CO2 22:00 14 1,200 30 380 4,475 12,183 23:00 14 1,200 20 400 4,495 12,163 24:00 14 1,200 22 422 4,517 12,141 01:00 14 1,200 32 454 4,549 12,109 Light Sand 02:00 14 1,200 19 473 4,568 12,090 03:00 14 1,200 19 492 4,587 12,071 04:00 14 1,200 21 513 4,608 12,050 05:00 14 1,100 25 538 4,633 12,025 Light Sand

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 538 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 4633 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 12025 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 28 % 1st, 2nd, 3rd, and 4th

Jordan Rivera 432-360-5347 TL =16658 BBLS. DLR = 538 BBLS. TLR = 4633 BBLS. LTR = 12025 BBLS. 28% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris Yanez 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 12/28/09

WELL NAME: REPORT DATE: 

### 12/28/2009-12/29/2009
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 14 1,100 22 22 4,655 12,003 07:00 14 1,100 24 46 4,679 11,979 08:00 14 1,100 21 67 4,700 11,958 Light Sand 09:00 14 1,100 28 95 4,728 11,930 10:00 14 1,100 20 115 4,748 11,910 11:00 14 1,100 25 140 4,773 11,885 12:00 14 1,100 24 164 4,797 11,861 100% CO2 13:00 14 1,100 24 188 4,821 11,837 14:00 14 1,100 24 212 4,845 11,813 No Sand 15:00 14 1,100 25 237 4,870 11,788 16:00 14 1,100 29 266 4,899 11,759 17:00 14 1,100 27 293 4,926 11,732 18:00 14 1,100 22 315 4,948 11,710 No Sand 19:00 14 1,100 18 333 4,966 11,692 20:00 14 1,100 18 351 4,984 11,674 No Sand 21:00 14 1,000 25 376 5,009 11,649 22:00 14 1,000 25 401 5,034 11,624 23:00 14 1,000 25 426 5,059 11,599 24:00 14 1,000 25 451 5,084 11,574 No Sand 01:00 14 1,000 25 476 5,109 11,549 02:00 14 1,000 27 503 5,136 11,522 03:00 14 1,000 25 528 5,161 11,497 100% CO2 04:00 14 1,000 19 547 5,180 11,478 No Sand 05:00 14 1,000 21 568 5,201 11,457

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 568 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 5201 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 11457 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 31 % 1st, 2nd, 3rd, and 4th

Jordan Rivera 432-360-5347 TL =16658 BBLS. DLR = 568 BBLS. TLR = 5201 BBLS. LTR = 11457 BBLS. 31% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris Yanez 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 12/29/09

WELL NAME: REPORT DATE: 

### 12/29/2009-12/30/2009
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 14 950 19 19 5,220 11,438 07:00 14 950 18 37 5,238 11,420 08:00 14 950 22 59 5,260 11,398 No Sand 09:00 14 950 25 84 5,285 11,373 10:00 14 950 25 109 5,310 11,348 11:00 14 950 20 129 5,330 11,328 12:00 14 950 21 150 5,351 11,307 100% CO2 13:00 14 950 20 170 5,371 11,287 14:00 14 950 15 185 5,386 11,272 15:00 16 950 15 200 5,401 11,257 16:00 18 900 41 241 5,442 11,216 17:00 18 900 50 291 5,492 11,166 18:00 18 900 50 341 5,542 11,116 No Sand 19:00 18 900 44 385 5,586 11,072 20:00 18 900 43 428 5,629 11,029 21:00 18 900 33 461 5,662 10,996 22:00 18 900 30 491 5,692 10,966 23:00 18 900 31 522 5,723 10,935 24:00 18 900 37 559 5,760 10,898 100% CO2 01:00 18 900 30 589 5,790 10,868 02:00 18 900 30 619 5,820 10,838 03:00 18 900 30 649 5,850 10,808 04:00 18 900 28 677 5,878 10,780 No Sand 05:00 18 900 42 719 5,920 10,738 Choke Check Good

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 719 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 5920 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 10738 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 36 % 1st, 2nd, 3rd, and 4th

Jordan Rivera 432-360-5347 TL =16658 BBLS. DLR = 719 BBLS. TLR = 5920 BBLS. LTR = 10738 BBLS. 36% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris Yanez 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 12/30/09

WELL NAME: REPORT DATE: 

### 12/30/2009-12/31/2009
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 18 900 38 38 5,958 10,700 07:00 18 900 25 63 5,983 10,675 08:00 18 900 25 88 6,008 10,650 No Sand 09:00 18 900 40 128 6,048 10,610 10:00 18 900 31 159 6,079 10,579 11:00 18 900 30 189 6,109 10,549 12:00 18 900 40 229 6,149 10,509 93% CO2 13:00 18 900 35 264 6,184 10,474 14:00 18 900 35 299 6,219 10,439 15:00 18 900 30 329 6,249 10,409 16:00 18 900 36 365 6,285 10,373 No Sand 17:00 18 900 30 395 6,315 10,343 18:00 18 900 30 425 6,345 10,313 19:00 18 900 25 450 6,370 10,288 20:00 18 900 31 481 6,401 10,257 No Sand 21:00 18 900 25 506 6,426 10,232 22:00 18 875 25 531 6,451 10,207 23:00 18 875 31 562 6,482 10,176 24:00 18 875 28 590 6,510 10,148 95% CO2 01:00 18 875 24 614 6,534 10,124 02:00 18 875 24 638 6,558 10,100 03:00 18 875 23 661 6,581 10,077 04:00 18 875 23 684 6,604 10,054 No Sand 05:00 18 875 31 715 6,635 10,023

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 715 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 6635 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 10023 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 40 % 1st, 2nd, 3rd, and 4th

Chris 432-238-1392 TL =16658 BBLS. DLR = 715 BBLS. TLR = 6635 BBLS. LTR = 10023 BBLS. 40% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Demetrio 432-360-5115 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 12/31/09

WELL NAME: REPORT DATE: 

### 12/31/2009 - 1/1/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 18 875 31 31 6,666 9,992 07:00 18 875 18 49 6,684 9,974 Changed choke to 20/64 08:00 20 850 35 84 6,719 9,939 No Sand

09:00 20 850 30 114 6,749 9,909 Changed choke to 22/64. Instructed by C.Watts 10:00 22 850 51 165 6,800 9,858 11:00 22 850 35 200 6,835 9,823 12:00 22 850 51 251 6,886 9,772 No Sand, CO2 94% 13:00 22 900 35 286 6,921 9,737 14:00 22 900 51 337 6,972 9,686 CO2 95% 15:00 22 900 51 388 7,023 9,635 16:00 22 900 47 435 7,070 9,588 No Sand 17:00 22 925 42 477 7,112 9,546 18:00 22 925 40 517 7,152 9,506 19:00 22 925 41 558 7,193 9,465 20:00 22 925 30 588 7,223 9,435 No Sand 21:00 22 925 41 629 7,264 9,394 22:00 22 950 66 695 7,330 9,328 23:00 22 950 50 745 7,380 9,278 24:00 22 950 41 786 7,421 9,237 No Sand 01:00 22 975 36 822 7,457 9,201 02:00 22 975 35 857 7,492 9,166 03:00 22 975 36 893 7,528 9,130 04:00 22 975 34 927 7,562 9,096 05:00 22 975 34 961 7,596 9,062 CO2 95%

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 961 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 7596 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 9062 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 46 % 1st, 2nd, 3rd, and 4th Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

Chris 432-238-1392 TL =16658 BBLS. DLR = 961 BBLS. TLR = 9062 BBLS. LTR = 7596 BBLS. 46% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Demetrio 432-360-5115

### 01/01/10

WELL NAME: REPORT DATE: 

### 1/1/2010 - 1/2/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 22 975 40 40 7,636 9,022 07:00 22 975 36 76 7,672 8,986 08:00 22 975 30 106 7,702 8,956 No Sand 09:00 22 975 36 142 7,738 8,920 10:00 22 975 34 176 7,772 8,886 11:00 22 975 30 206 7,802 8,856 12:00 22 975 34 240 7,836 8,822 CO2 93%, No Sand 13:00 22 950 34 274 7,870 8,788 14:00 22 950 30 304 7,900 8,758 15:00 22 950 28 332 7,928 8,730

16:00 22 950 28 360 7,956 8,702 No Sand, Changed choke to 26/64 as instructed G.Wooten 17:00 26 925 45 405 8,001 8,657 18:00 26 925 38 443 8,039 8,619 19:00 26 925 34 477 8,073 8,585 20:00 26 925 36 513 8,109 8,549 No Sand 21:00 26 925 34 547 8,143 8,515 22:00 26 925 32 579 8,175 8,483 23:00 26 925 32 611 8,207 8,451 24:00 26 925 35 646 8,242 8,416 No Sand, CO2 93% 01:00 26 950 30 676 8,272 8,386 02:00 26 950 36 712 8,308 8,350 03:00 26 950 36 748 8,344 8,314 04:00 26 950 35 783 8,379 8,279 No Sand 05:00 26 950 30 813 8,409 8,249

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 813 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 8409 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 8249 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 50 % 1st, 2nd, 3rd, and 4th

Gary 432-360-6272 TL =16658 BBLS. DLR = 813 BBLS. TLR = 8409 BBLS. LTR = 8249 BBLS. 50% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Demetrio 432-360-5115 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 01/02/10

WELL NAME: REPORT DATE: 

### 1/2/2010 - 1/3/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 950 34 34 8,443 8,215 07:00 26 950 38 72 8,481 8,177 08:00 26 925 35 107 8,516 8,142 09:00 26 925 35 142 8,551 8,107 10:00 26 900 30 172 8,581 8,077 11:00 26 875 30 202 8,611 8,047 12:00 26 850 30 232 8,641 8,017 CO2 83% 13:00 26 860 40 272 8,681 7,977 14:00 26 875 38 310 8,719 7,939 15:00 26 875 36 346 8,755 7,903 No Sand 16:00 26 875 36 382 8,791 7,867 17:00 26 875 35 417 8,826 7,832 18:00 26 875 32 449 8,858 7,800 19:00 26 860 39 488 8,897 7,761 20:00 26 860 39 527 8,936 7,722 No Sand 21:00 26 865 38 565 8,974 7,684 22:00 26 865 38 603 9,012 7,646 23:00 26 865 34 637 9,046 7,612 24:00 26 865 32 669 9,078 7,580 No Sand, CO2 88% 01:00 26 865 30 699 9,108 7,550 02:00 26 865 30 729 9,138 7,520 03:00 26 865 30 759 9,168 7,490 04:00 26 865 30 789 9,198 7,460 05:00 26 865 30 819 9,228 7,430 No Sand, CO2 88%

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 819 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 9228 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 7430 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 55 % 1st, 2nd, 3rd, and 4th Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

Gary 432-360-6272 TL =16658 BBLS. DLR = 819 BBLS. TLR = 9228 BBLS. LTR = 7430 BBLS. 55% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Demetrio 432-360-5115

### 01/03/10

WELL NAME: REPORT DATE: 

### 1/3/2010 - 1/4/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 875 38 38 9,266 7,392 07:00 26 875 40 78 9,306 7,352 08:00 26 880 40 118 9,346 7,312 09:00 26 880 35 153 9,381 7,277 10:00 26 880 35 188 9,416 7,242 No Sand 11:00 26 880 40 228 9,456 7,202 12:00 26 880 35 263 9,491 7,167 CO2 76% 13:00 26 880 35 298 9,526 7,132 14:00 26 880 35 333 9,561 7,097 CO2 76% 15:00 26 880 36 369 9,597 7,061 16:00 26 880 39 408 9,636 7,022 17:00 26 880 35 443 9,671 6,987 18:00 26 880 35 478 9,706 6,952 CO2 76% 19:00 26 880 34 512 9,740 6,918 20:00 26 880 34 546 9,774 6,884 21:00 26 880 32 578 9,806 6,852 22:00 26 880 32 610 9,838 6,820 23:00 26 880 30 640 9,868 6,790 24:00 26 880 30 670 9,898 6,760 01:00 26 880 26 696 9,924 6,734 02:00 26 880 25 721 9,949 6,709 03:00 26 900 25 746 9,974 6,684 04:00 26 900 25 771 9,999 6,659 05:00 26 900 25 796 10,024 6,634 CO2 64%

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 796 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 10024 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 6634 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 60 % 1st, 2nd, 3rd, and 4th

Gary 432-360-6272 TL =16658 BBLS. DLR = 796 BBLS. TLR = 10024 BBLS. LTR = 664 BBLS. 60% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Demetrio 432-360-5115 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 01/04/10

WELL NAME: REPORT DATE: 

### 1/4/2010 - 1/5/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 880 25 38 10,049 6,609 Flowing to flowback tank. 07:00 26 820 28 66 10,077 6,581 08:00 26 820 28 94 10,105 6,553 09:00 26 820 28 122 10,133 6,525 10:00 26 780 25 147 10,158 6,500 Production Log in progress 11:00 26 740 20 167 10,178 6,480 No Sand 12:00 26 750 26 193 10,204 6,454 86% CO2 13:00 26 750 30 223 10,234 6,424 14:00 26 760 25 248 10,259 6,399 15:00 SI 760 20 268 10,279 6,379 SI for production log 16:00 SI 820 268 10,279 6,379 17:00 SI 850 268 10,279 6,379 Open 17:30 back to tanks 18:00 26 700 12 280 10,291 6,367 19:00 26 720 35 315 10,326 6,332 20:00 26 680 23 338 10,349 6,309 21:00 26 680 32 370 10,381 6,277 22:00 26 690 27 397 10,408 6,250 23:00 26 700 28 425 10,436 6,222 24:00 26 680 28 453 10,464 6,194 No Sand 01:00 26 680 25 478 10,489 6,169 02:00 26 680 25 503 10,514 6,144 03:00 26 680 25 528 10,539 6,119 04:00 26 680 20 548 10,559 6,099 05:00 26 680 20 568 10,579 6,079 82% CO2

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 568 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 10579 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 6079 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 64 % 1st, 2nd, 3rd, and 4th

Gary 432-360-6272 TL =16658 BBLS. DLR = 568 BBLS. TLR = 10579 BBLS. LTR = 6079 BBLS. 64% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 01/05/10

WELL NAME: REPORT DATE: 

### 1/5/2010 - 1/6/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 680 34 38 10,613 6,045 Flowing to flowback tank. 07:00 26 660 32 70 10,645 6,013 08:00 26 660 32 102 10,677 5,981 No Sand 09:00 26 660 25 127 10,702 5,956 10:00 26 640 26 153 10,728 5,930 11:00 26 640 22 175 10,750 5,908 12:00 26 640 26 201 10,776 5,882 80% CO2 13:00 26 640 21 222 10,797 5,861 14:00 26 660 20 242 10,817 5,841 Shut-in for wireline @ 14:00 15:00 SI 242 10,817 5,841 16:00 SI 242 10,817 5,841 17:00 SI 242 10,817 5,841 SICP 840/Open 17:30 18:00 26 720 7 249 10,824 5,834 19:00 26 540 10 259 10,834 5,824 20:00 26 520 20 279 10,854 5,804 21:00 26 680 30 309 10,884 5,774 22:00 26 700 15 324 10,899 5,759 23:00 26 640 15 339 10,914 5,744 24:00 26 620 15 354 10,929 5,729 01:00 26 620 18 372 10,947 5,711 02:00 26 620 23 395 10,970 5,688 03:00 26 620 18 413 10,988 5,670 04:00 26 600 20 433 11,008 5,650 No Sand 05:00 26 600 21 454 11,029 5,629 79% CO2/Good gas

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 454 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 11029 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 5629 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 66 % 1st, 2nd, 3rd, and 4th

Gary 432-360-6272 TL =16658 BBLS. DLR = 454 BBLS. TLR = 11029 BBLS. LTR = 5629 BBLS. 66% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

### 01/06/10

WELL NAME: REPORT DATE: 

### 1/6/2010 - 1/7/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 600 15 38 11,044 5,614 07:00 26 580 1,671 21 59 11,065 5,593 Turn into test separator 07:00 08:00 26 560 1,702 15 74 11,080 5,578 09:00 26 550 1,697 20 94 11,100 5,558 10:00 26 540 1,609 20 114 11,120 5,538 11:00 26 550 1,619 18 132 11,138 5,520 12:00 26 550 1,619 17 149 11,155 5,503 72% CO2 13:00 26 550 1,619 19 168 11,174 5,484 14:00 26 550 1,599 20 188 11,194 5,464 Shut-in 14:00 to rig up to sales 15:00 SI 570 188 11,194 5,464 16:00 26 580 1,004 188 11,194 5,464 First Del 16:00/SICP 580 17:00 26 575 851 8 196 11,202 5,456 61% CO2/LP 484 18:00 26 540 799 20 216 11,222 5,436 19:00 26 540 758 20 236 11,242 5,416 20:00 26 550 772 12 248 11,254 5,404 21:00 26 550 797 8 256 11,262 5,396 22:00 26 550 797 8 264 11,270 5,388 23:00 26 570 854 19 283 11,289 5,369 24:00 26 580 250 14 297 11,303 5,355 63% CO2 01:00 26 550 910 14 311 11,317 5,341 02:00 26 480 529 13 324 11,330 5,328 03:00 26 500 315 18 342 11,348 5,310 04:00 26 520 585 14 356 11,362 5,296 05:00 26 520 420 18 374 11,380 5,278

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 374 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 11380 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 5278 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 68 % 1st, 2nd, 3rd, and 4th Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

Gary 432-360-6272 TL =16658 BBLS. DLR = 374 BBLS. TLR = 11380 BBLS. LTR = 5278 BBLS. 68% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris 432-238-1392

### 01/07/10

WELL NAME: REPORT DATE: 

### 1/7/2010 - 1/8/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 480 704 16 16 11,396 5,262 Flowing to sales 07:00 26 480 629 20 36 11,416 5,242 08:00 26 490 568 15 51 11,431 5,227 09:00 26 480 869 15 66 11,446 5,212 10:00 26 420 362 15 81 11,461 5,197 11:00 36 475 999 5 86 11,466 5,192 58% CO2 12:00 36 460 872 21 107 11,487 5,171 No Sand 13:00 36 425 0 14 121 11,501 5,157 LP 425/Shut-in for wireline 14:00 SI 550 121 11,501 5,157 15:00 121 11,501 5,157 16:00 121 11,501 5,157 17:00 26 640 121 11,501 5,157 Open to tanks @ 17:00 18:00 26 560 16 137 11,517 5,141 67% CO2 19:00 26 500 10 147 11,527 5,131 20:00 26 320 10 157 11,537 5,121 21:00 26 450 20 177 11,557 5,101 22:00 26 520 20 197 11,577 5,081 23:00 26 450 15 212 11,592 5,066 24:00 26 450 10 222 11,602 5,056 01:00 26 490 10 232 11,612 5,046 02:00 26 500 10 242 11,622 5,036 03:00 26 460 10 252 11,632 5,026 04:00 26 460 10 262 11,642 5,016 05:00 26 440 10 272 11,652 5,006

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 272 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 11652 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 5006 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 70 % 3rd, and 4th Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

Gary 432-360-6272 TL =16658 BBLS. DLR = 272 BBLS. TLR = 11652 BBLS. LTR = 5006 BBLS. 70% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris 432-238-1392

### 01/08/10

WELL NAME: REPORT DATE: 

### 1/8/2010 - 1/9/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 420 15 15 11,667 4,991 Flowing to flowback tanks 07:00 26 410 15 30 11,682 4,976 08:00 26 400 9 39 11,691 4,967 09:00 26 380 9 48 11,700 4,958 Slickline- Flowing Gradient 10:00 26 370 9 57 11,709 4,949 11:00 26 360 9 66 11,718 4,940 12:00 26 360 9 75 11,727 4,931 71% CO2 13:00 26 360 8 83 11,735 4,923 14:00 26 350 5 88 11,740 4,918 15:00 26 340 9 97 11,749 4,909 16:00 26 340 9 106 11,758 4,900 17:00 26 330 9 115 11,767 4,891 18:00 26 330 9 124 11,776 4,882 70% CO2 19:00 26 320 6 130 11,782 4,876 20:00 26 320 4 134 11,786 4,872 21:00 26 310 10 144 11,796 4,862 22:00 26 310 9 153 11,805 4,853 23:00 26 300 10 163 11,815 4,843 24:00 26 300 4 167 11,819 4,839 01:00 26 300 5 172 11,824 4,834 02:00 26 300 5 177 11,829 4,829 03:00 26 290 10 187 11,839 4,819 04:00 26 290 5 192 11,844 4,814 CO2 70% 05:00 26 290 8 200 11,852 4,806

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 200 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 11852 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 4806 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 71 % 3rd, and 4th Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

Gary 432-360-6272 TL =16658 BBLS. DLR = 200 BBLS. TLR = 11852 BBLS. LTR = 4806 BBLS. 71% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris 432-238-1392

### 01/09/10

WELL NAME: REPORT DATE: 

### 1/9/2010 - 1/10/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 26 280 4 4 11,856 4,802 Flowing to flowback tanks 07:00 26 270 4 8 11,860 4,798 08:00 26 270 6 14 11,866 4,792 09:00 26 260 9 23 11,875 4,783 10:00 26 260 6 29 11,881 4,777 70% CO2 11:00 26 260 5 34 11,886 4,772 12:00 26 260 4 38 11,890 4,768 13:00 26 260 5 43 11,895 4,763 14:00 26 250 4 47 11,899 4,759 15:00 26 250 5 52 11,904 4,754 Turn to test separator/SICP 300 16:00 26 280 409 0 52 11,904 4,754 180 Back Pressure 17:00 26 240 278 9 61 11,913 4,745 18:00 26 210 236 8 69 11,921 4,737 19:00 26 240 289 5 74 11,926 4,732 20:00 26 240 289 5 79 11,931 4,727 21:00 32 220 334 4 83 11,935 4,723 22:00 32 210 289 9 92 11,944 4,714 23:00 32 210 289 4 96 11,948 4,710 24:00 32 210 289 5 101 11,953 4,705 01:00 32 200 312 9 110 11,962 4,696 02:00 32 200 289 9 119 11,971 4,687 03:00 32 200 312 4 123 11,975 4,683 04:00 32 200 312 4 127 11,979 4,679 CO2 70% 05:00 32 200 312 4 131 11,983 4,675

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 131 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 11983 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 4675 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 72 % 3rd, and 4th Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

Gary 432-360-6272 TL =16658 BBLS. DLR = 131 BBLS. TLR = 11983 BBLS. LTR = 4675 BBLS. 72% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris 432-238-1392

### 01/10/10

WELL NAME: REPORT DATE: 

### 1/10/2010 - 1/11/2010
ZONE NAME: COUNTY 

### Pecos
STAGE NUMBER: FIELD: Pinion
PERFS INTERVALS STATE: TEXAS COMMENTS:

TIME CHOKE SIZE (1/64 in) TUBING PRESS

(psi) CASING PRESS

(psi) GAS (mcfd) OIL (bbls/hr) WATER (bbls/hr) DAILY LOAD REC (bbls) TOTAL LOAD REC (bbls) LOAD TO REC (bbls) COMMENTS

06:00 32 190 289 3 3 11,986 4,672 Flowing to flowback tank 07:00 32 190 264 2 5 11,988 4,670 08:00 32 180 264 2 7 11,990 4,668 09:00 32 170 2 9 11,992 4,666 WHP < BP/Bypass separater 10:00 32 160 2 11 11,994 4,664 Shut-in well @ 10:15/Release 11:00 11 11,994 4,664 12:00 11 11,994 4,664 13:00 11 11,994 4,664 14:00 11 11,994 4,664 15:00 11 11,994 4,664 16:00 11 11,994 4,664 17:00 11 11,994 4,664 18:00 11 11,994 4,664 19:00 11 11,994 4,664 20:00 11 11,994 4,664 21:00 11 11,994 4,664 22:00 11 11,994 4,664 23:00 11 11,994 4,664 24:00 11 11,994 4,664 01:00 11 11,994 4,664 02:00 11 11,994 4,664 03:00 11 11,994 4,664 04:00 11 11,994 4,664 05:00 11 11,994 4,664

TOTAL LOAD TO RECOVER: 16658 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 11 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 11994 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 4664 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 72 % 3rd, and 4th

Gary 432-360-6272 TL =16658 BBLS. DLR = 11 BBLS. TLR = 11994 BBLS. LTR = 4664 BBLS. 72% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Chris 432-238-1392 Today's Date: 

# SANDRIDGE ENERGY, INC.
FLOWBACK REPORT

West Ranch South 71-5

# SANDRIDGE ENERGY INC P.O. Box 548807 Oklahoma City, OK 73154

WEST RANCH SOUTH 71-5
Tesnus Interval – (4696’ – 4810’) Pecos County, Texas

Sales Order: 7119075



# Post Job Report

For: Jason Stewart Date: Tuesday, January 19, 2010

Notice: Although th e information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report w hether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s own risk.

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 5

2 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) Table of Contents

1.0 Executive Summary

................................................................................................ ........................................ 3 2.0 Well Information

................................................................................................ ............................................. 4

2.1 Customer Information

................................................................................................ ..................................... 4 2.2 Pipe Information

................................................................................................ .............................................. 4 2.3 Perforation Intervals

................................................................................................ ........................................ 4 3.0 Pumping Schedule

................................................................................................ ........................................... 5

3.1 Designed Pumping Schedule Treatment 1 4696.00 - 4810.00 ft

..................................................................... 5 3.2 Designed Surface CO2 Schedule Treatment 1 4696.00 - 4810.00 ft

............................................................... 6 3.3 Designed BH Foam Schedule Treatment 1 4 696.00 - 4810.00 ft

.................................................................... 6 4.0 Actual Stage Summary

................................................................................................ .................................... 7

4.1 Stage Summary

................................................................................................ ............................................... 7 4.2 Foam Stage Summary

................................................................................................ ..................................... 7 5.0 Performance Highlights

................................................................................................ ................................... 8

5.1 Treatment Summary

................................................................................................ ........................................ 8 6.0 Attachments

................................................................................................ ..................................................... 9

6.1 Test Lines

................................................................................................ ........................................................ 9 6.2 Job Summary

................................................................................................ ................................................. 10 6.3 Rate Profile

................................................................................................ .................................................... 11 6.4 Chemical Additives - Pre Gel

........................................................................................................................ 12 6.5 Chemical Additives - Blender

....................................................................................................................... 13 6.6 Net Pressure Plot

................................................................................................ ........................................... 14

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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3 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 1.0 E XECUTIVE 

# S UMMARY

Jason Stewart SANDRIDGE ENERGY INC EBUS INESS P.O. Box 548807 Oklahoma City , OK 73154

Dear Jason Stewart,

Halliburton appreciates the opportunity to perform the stimulation treatment on the WEST RANCH SOUTH 71

- 5. A pre

- job safety meeting was held where details of the job were discussed, potential safety hazards were reviewed, and environmental compliance procedures were outlined. Pump time was 49.00 min.

The proposed treatment for Stage 5 consisted of:

**•** 4750 gal of Water Frac G - R (11).

**•** 8700 gal of Water Frac G - R (11) carrying 67497 lb of OTTAWA 20/40

.

**•** 900 gal of Water Frac G - R (11) carrying 11997 lb of Super LC 20/40

.

**•** 7546 gal of Treated 4% KCL Water.

The treatment actually pumped consisted of:

**•** 5532 gal of Water Frac G - R (11).

**•** 8705 gal of Water Frac G - R (11) carrying 66491 lb o f OTTAWA 20/40

.

**•** 1535 gal of Water Frac G - R (11) carrying 13392 lb of Super LC 20/40

.

**•** 7558 gal of Treated 4% KCL Water.

There was 12 ton s of CO2 used to cool down, and 178 tons pumped downhole. The total liquid load to recover is 23331 gal. The average WH pressure was 3988 psi and the average WH rate was 37.6 bpm. ISIP was recorded at 3415 psi.

Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids.

Halliburton maintains a continuous quality improvement process and appr eciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects.

Respectfully,

Levi Davenport Technical Professional 432.631.9516

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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4 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 2.0 W ELL 

# I NFORMATION



# 2.1 Customer Information
Customer SANDRIDGE ENERGY INC EBUSINESS 

# Sales Order 7119075 

# Well Name WEST RANCH SOUTH 

# Well Number 71 -5 

# Start Time 19

- Jan

- 2010 

# County Pecos 

# State Texas 

# UWI/API 4237138589 

# Country United States of America 

# Customer Representative Jason Stewart 

# Halliburton Representative RODRIGUEZ



# 2.2 Pipe Information
Equipment Top MD ft Bottom MD ft OD in ID in Grade Weight lb/ft

Casing 0.0 8883.0 7.000 6.276 P- 110 26.00



# 2.3 Perforation Intervals
Top MD ft Bottom MD ft Perf Density spf Perf Phasing

° Perf Formation

4696.0 4706.0 0.5 1 Stage 5 - Tesnus 4726.0 4736.0 0.5 1 Stage 5 - Tesnus 4768.0 4778.0 1.0 1 Stage 5 - Tesnus 4790.0 4810.0 1.0 1 Stage 5 - Tesnus

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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5 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 3.0 P UMPING 

# S CHEDULE



# 3.1 Designed Pumping Schedule Treatment 1 4696.00 - 4810.00 ft

Stage Number Description Fluid System Clean Volume gal Prop Conc Start lb/gal Prop Conc End lb/gal Prop Mass lb Rate Stage Start bpm
1 - 1 Breakdown Water Frac G - R (11) 1000 0.00 0.00 5.0

1 - 2 Pad Water Frac G - R (11) 2250 0. 00 0.00 6.0

1 - 3 Sand Slug Water Frac G - R (11) 1200 5.00 5.00 6000 9.4

1 - 4 Pad Water Frac G - R (11) 1500 0.00 0.00 8.0

1 - 5 1 ppg Water Frac G - R (11) 1500 4.00 4.00 6000 11.3

1 - 6 2 ppg Water Frac G - R (11) 1800 6.67 6.67 12006 14.3

1 - 7 2.5 ppg Water Frac G - R (11) 1500 8.33 8.33 12495 14.8

1 - 8 3 ppg Water Frac G - R (11) 1500 10.00 10.00 15000 15.3

1 - 9 4 ppg Water Frac G - R (11) 1200 13.33 13.33 15996 16.3

1 - 10 4 ppg CRC Water Frac G - R (11) 900 13.33 13.33 11997 16.3

1 - 11 Flush Treated 4% KCL Water 7546 0.00 0.00 40.0

Total 21896 79494

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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6 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 3.2 Designed Surface CO2 Schedule Treatment 1 4696.00 - 4810.00 ft

Stage Number Description Sur CO2 Liq Rate Begin bpm Sur CO2 Mass

ton
1 - 1 Breakdown 1 - 2 Pad 32.0 51.5 1

- 3 Sa nd Slug 29.0 19.5 1 - 4 Pad 30.0 24.1 1 - 5 1 ppg 27.0 18.2 1 - 6 2 ppg 24.0 16.9 1 - 7 2.5 ppg 24.0 14.3 1 - 8 3 ppg 23.0 14.0 1 - 9 4 ppg 22.0 11.2 1 - 10 4 ppg CRC 22.0 8.4 1 - 11 Flush 178.2



# 3.3 Designed BH Foam Schedule Treatment 1 4696.00 - 4810.00 ft

Stage Number Description BH Clean Foam Vol gal BH Foam Rate Begin bpm BH Prop Conc Begin lb/gal
1 - 1 Breakdown 1 - 2 Pad 16824 45 0.00 1 - 3 Sand Slug 6730 44 0.89 1 - 4 Pad 8332 44 0.00 1 - 5 1 ppg 6645 44 0.90 1 - 6 2 ppg 6573 43 1 .83 1 - 7 2.5 ppg 5562 44 2.25 1 - 8 3 ppg 5472 43 2.74 1 - 9 4 ppg 4392 43 3.64 1 - 10 4 ppg CRC 3293 43 3.64 1 - 11 Flush 63824

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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7 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 4.0 A CTUAL 

# S TAGE 

# S UMMARY



# 4.1 Stage Summary
Stage Number Avg Treating Pressure psi Avg Slurry Rate bpm Clean Volume gal Avg Concentration lb/gal Proppant Mass Pumped lb
1 - 1 2211 6.8 2188 0.00 0 1 - 2 4175 6.5 2151 0.31 10 1 - 3 3998 9.5 1205 3.45 4026 1

- 4 3893 9.4 1193 0.49 88 1 - 5 3955 11.8 1501 4.29 6550 1 - 6 3895 14.7 1802 5.91 10635 1 - 7 3900 14.8 1498 8.9 1 13268 1 - 8 3923 15.0 1502 10.74 16112 1 - 9 3981 16.1 1197 13.29 15900 1 - 10 4046 16.9 1535 9.85 13392 1 - 11 4886 25.2 7558 0.57 11

Total 23331 79991



# 4.2 Foam Stage Summary
Stage Number Avg Well Head Rate bpm WH Volume gal CO2 Mass ton
1 - 1 6.8 2188 0.0 1 - 2 36.0 11890 42.3 1

- 3 39.1 5733 18.7 1 - 4 38.8 4923 15.9 1 - 5 40.2 6108 18.4 1 - 6 41.1 6372 17.4 1 - 7 40.4 5715 15.4 1 - 8 39.5 5858 15.4 1 - 9 39.0 4641 11.6 1 - 10 36.8 4695 10.8 1 - 11 25.2 7559 0.0 65682 165.9

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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8 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 5.0 P ERFORM ANCE 

# H IGHLIGHTS



# 5.1 Treatment Summary
Start Time 19

- Jan

- 10 10:04:56 

# End Time 19

- Jan

- 10 12:50:39 

# Pump Time 49.00 

# min Max Treating Pressure 7551 

# psi Avg Treating Pressure 3988 

# psi Clean Volume 23331 

# gal Max Slurry Rate 16.89 

# bpm Avg Slurry Rate 11.46 

# bp m Slurry Volume 26975 

# gal Max Proppant Concentration 4.55 

# lb/gal Proppant Mass Pumped 79991 

# lb Load to Recover 23331 

# gal

Disclaimer: The average and maximum values (except volumes and bottom hole values) are based on the start and end averaging times.

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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9 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.0 A TTACHMENTS



# 6.1 Test Lines

1/19/2010 11:08 11:10 11:12 11:14 11:16 11:18
1/19/2010 11:20
Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Treating Pressure (psig)

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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10 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.2 Job Summary

1/19/2010 11:50 12:00 12:10 12:20
1/19/2010 12:30
Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 A

0 20 40 60 80 100 120 B

0

2 4 6 8 10 12 14 16 18 C Treating Pressure (psig) Wellhead Rate (bpm) Wellhead Proppant Conc (lb/gal) BH Proppant Conc (lb/gal) A B C C

11 10 9 8 7 6 5 4 3 2 1 1

Local Event Log

1 Intersection

ISIP 12:31:58 TP

3415

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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11 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.3 Rate Profile

1/19/2010 11:50 12:00 12:10 12:20
1/19/2010 12:30
Time 0 10 20 30 40 50 A

0 10 20 30 40 50 60 70 80 90 100 B Wellhead Rate (bpm) Slurry Rate (bpm) CO2 Liquid Rate (bpm) Predicted BH Int Phase (%) A A A B

11 10 9 8 7 6 5 4 3 2 1

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 5

12 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.4 Chemical Additives - Pre Gel

1/19/2010 11:45 11:50 11:55 12:00 12:05 12:10 12:15 12:20
1/19/2010 12:25
Time 0 1 2 3 4 A

0 2 4 6 8 10 12 14 16 18 20 C Losurf-300D Conc (gal/Mgal) Cla-Sta(R) XP Conc (gal/Mgal) B2 WG-36 Conc -DA1 (lb/Mgal) A A C

11 10 9 8 7 6 5 4 3 2 1

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 5

13 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.5 Chemical Additives - Blender

1/19/2010 11:45 11:50 11:55 12:00 12:05 12:10 12:15 12:20
1/19/2010 12:25
Time 0 1 2 3 4 A

0 2 4 6 8 10 12 14 16 18 20 C SUPERSET W Conc (gal/Mgal) Optiflo HTE Conc (lb/Mgal) HPH (0.125:39.875) Conc (gal/Mgal) C A A

11 10 9 8 7 6 5 4 3 2 1

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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14 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.6 Net Pressure Plot

2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 1 10 100 Time (min) (0 = 710) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

100 1000 10000 A

0 5 10 15 20 25 B Net Calc'd BH Pres (psi) BH Proppant Conc (lb/gal) Slope of Net Pressure (psi/min) A B C

11 10
9 8 7 6 5 4 3 Closure Pressure = 4000 psi

0 Time = 01/19/10 11:50:00

# SANDRIDGE ENERGY INC P.O. Box 548807 Oklahoma City, OK 73154

WEST RANCH SOUTH 71-5
Tesnus Interval (3870’ – 4000’) Pecos County, Texas

Sales Order: 7119075



# Post Job Report

For: Jason Stewart Date: Tuesday, January 19, 2010

Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whe ther in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s own risk.

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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2 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) Table of Contents

1.0 Executive Summary

................................................................................................ ........................................ 3 2 .0 Well Information

................................................................................................ ............................................. 4

2.1 Customer Information

................................................................................................ ..................................... 4 2.2 Pipe Information

................................................................................................ .............................................. 4 2.3 Perforation Intervals

................................................................................................ ........................................ 4 3.0 Pumping Schedule

................................................................................................ ........................................... 5

3.1 Designed Pumping Schedule Treatment 2 3870.00 - 4000.00 ft

..................................................................... 5 3.2 Designed Surface CO2 Schedule Treatment 2 3870.00 - 4000.00 ft

............................................................... 6 3.3 Designed BH Foam Schedule Treatment 2 387 0.00 - 4000.00 ft

.................................................................... 6 4.0 Actual Stage Summary

................................................................................................ .................................... 7

4.1 Stage Summary

................................................................................................ ............................................... 7 4.2 Foam Stage Summary

................................................................................................ ..................................... 7 5.0 Performance Highlights

................................................................................................ ................................... 8

5.1 Treatment Summary

................................................................................................ ........................................ 8 5.2 Job Event Log

................................................................................................ .................................................. 9 6.0 Attachments

................................................................................................ ................................................... 10

6.1 Pressure Test

................................................................................................ ................................................. 10 6.2 Job Summary

................................................................................................ ................................................. 11 6.3 Rate Profile

................................................................................................ .................................................... 12 6.4 Chemical Additives - Pre Gel

........................................................................................................................ 13 6.5 Chemical Additives - Blender

....................................................................................................................... 14 6.6 Net Pressure Plot

................................................................................................ ........................................... 15

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# 1.0 E XECU TIVE 

# S UMMARY

Jason Stewart SANDRIDGE ENERGY INC EBUSINESS P.O. Box 548807 Oklahoma City , OK 73154

Dear Jason Stewart,

Halliburton appreciates the opportunity to perform the stimulation treatment on the WEST RANCH SOUTH 71

- 5. A pre

- job safety meeting was held where details of the job were discussed, potential safety hazards were reviewed, and environmental compliance procedures were outlined. Pump time was 34.25 min.

The proposed treatment for Stage 6 consisted of:

**•** 4750 gal of Water Frac G - R (11)

.

**•** 6300 gal of Water Frac G - R (11) carrying 49997 lb of OTTAWA 20/40

.

**•** 750 gal of Water Frac G - R (11) carrying 9998 lb of SUPER LC 20/40

.

**•** 6219 gal of Treated 4% KCL Water.

The treatment actually pumped consisted of:

**•** 3591 gal of Water Frac G - R (11).

**•** 6 343 gal of Water Frac G - R (11) carrying 46696 lb of OTTAWA 20/40

.

**•** 1421 gal of Water Frac G - R (11) carrying 8763 lb of SUPER LC 20/40

.

**•** 6242 gal of Treated 4% KCL Water.

There was 10 ton s of CO2 used to cool down, and 142 tons pumped downhole. The tota l liquid load to recover is 17597 gal. The average WH pressure was 2937 psi and the average WH rate was 38.06 bpm. The ISIP was recorded at 2460 psi.

Halliburton is strongly committed to quality control on location. Before and after each job all chemic als, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids.

Halliburton mai ntains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects

. Respectfully,

Levi Davenport Technical Professional 432.631.9516

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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# 2.0 W ELL 

# I NFORMATION



# 2.1 Customer Information
Customer SANDRIDGE ENERGY INC EBUSINESS 

# Sales Order 7119075 

# Well Name WEST RANCH SOUTH 

# Well Number 71 -5 

# Start Time 19

- Jan

- 2010 

# County Pecos 

# State Texas 

# UWI/API 4237138589 

# Country United States of America 

# Customer Representative Jason Stewart 

# Halliburton Representative RODRIGUEZ



# 2.2 Pipe Information
Equipment Top MD ft Bottom MD ft OD in ID in Grade Weight lb/ft

Trt Interval 3870.0 4000.0 0.000 0.000 0.00 Casing 0.0 8883.0 7.000 6.276 P- 110 26.00



# 2.3 Perforation Intervals
Top MD ft Bottom MD ft Perf Density spf Perf Formation

3870.0 3880.0 1.0 Stage 6 - Tesnus 3920.0 3930.0 1.0 Stage 6 - Tesnus 3990.0 4000.0 2.0 Stage 6 - Tesnus

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# 3.0 P UMPING 

# S CHEDULE



# 3.1 Designed Pumping Schedule Treatment 2 3870.00 - 4000.00 ft

Stage Number Description Fluid System Clean Volume gal Prop Conc Start lb/gal Prop Conc End lb/gal Prop Mass lb Rate Stage Start bpm
2 - 1 Breakdown Water Frac G - R (11) 1000 0.00 0.00 5 .0

2 - 2 Pad Water Frac G - R (11) 2250 0.00 0.00 6.0

2 - 3 Sand Slug Water Frac G - R (11) 800 5.00 5.00 4000 9.4

2 - 4 Pad Water Frac G - R (11) 1500 0.00 0.00 8.0

2 - 5 1 ppg Water Frac G - R (11) 1000 4.00 4.00 4000 11.3

2 - 6 2 ppg Water Frac G - R (11) 1200 6.67 6.67 8004 14.3

2 - 7 2.5 ppg Water Frac G - R (11) 1200 8.33 8.33 9996 14.8

2 - 8 3 ppg Water Frac G - R (11) 1200 10.00 10.00 12000 15.3

2 - 9 4 ppg Water Frac G - R (11) 900 13.33 13.33 11997 16.3

2 - 10 4 ppg CRC Water Frac G - R (11) 750 13.33 13.33 9998 16.3

2 - 11 Flush Treated 4% KCL Water 6219 0.00 0.00 40.0

Total 18019 59995

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# 3.2 Designed Surface CO2 Schedule Treatment 2 3870.00 - 4000.00 ft

Stage Number Description Sur CO2 Liq Rate Begin bpm Sur CO2 Mass

ton
2 - 1 Brea kdown 2 - 2 Pad 31.0 49.9 2

- 3 Sand Slug 28.0 12.6 2 - 4 Pad 29.0 23.3 2 - 5 1 ppg 26.0 11.7 2 - 6 2 ppg 23.0 10.8 2 - 7 2.5 ppg 23.0 11.0 2 - 8 3 ppg 22.0 10.7 2 - 9 4 ppg 22.0 8.4 2 - 10 4 ppg CRC 22.0 7.0 2 - 11 Flush 145.3



# 3.3 Designed BH Foam Schedule Treatment 2 3870.00 - 4000.00 ft

Stage Number Description BH Clean Foam Vol gal BH Foam Rate Begin bpm BH Prop Conc Begin lb/gal
2 - 1 Breakdown 2 - 2 Pad 16558 44 0.00 2 - 3 Sand Slug 4407 44 0.91 2 - 4 Pad 8193 44 0.00 2 - 5 1 pp g 4347 43 0.92 2 - 6 2 ppg 4290 42 1.87 2 - 7 2.5 ppg 4356 43 2.29 2 - 8 3 ppg 4280 42 2.80 2 - 9 4 ppg 3302 43 3.63 2 - 10 4 ppg CRC 2771 43 3.61 2 - 11 Flush 52504

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# 4.0 A CTUAL 

# S TAGE 

# S UMMARY



# 4.1 Stage Summary
Stage Number Avg Treating Pressure psi Avg Slurry Rate bpm Clean Volume gal Avg Concentration lb/gal Proppant Mass Pumped lb
2 - 1 2926 5.3 612 0.00 0 2 - 2 3408 5.9 1487 0.20 13 2 - 3 3074 8.7 1118 3.06 3501 2

- 4 2926 9.6 1492 0.80 210 2 - 5 2824 12.1 931 4.70 4213 2 - 6 2721 14.0 1046 7.46 7794 2 - 7 2602 14.6 1205 8.88 10696 2 - 8 2626 16.4 1209 10.20 12337 2 - 9 2692 16.4 834 9.89 8155 2 - 10 2847 16.5 1421 8.81 8763 2 - 11 3173 36.5 6242 0.00 0

Total 17597 55683



# 4.2 Foam Stage Summary
Stage Number Avg Well Head Rate bpm WH Volu me gal CO2 Mass ton
2 - 1 6.3 718 0.5 2 - 2 37.4 9498 34.5 2

- 3 39.7 5835 19.4 2 - 4 39.2 6153 19.6 2 - 5 40.2 3730 10.9 2 - 6 40.1 4021 10.9 2 - 7 39.8 4600 12.1 2 - 8 39.7 4281 10.4 2 - 9 39.5 2907 7.0 2 - 10 38.1 4217 9.9 2 - 11 36.5 6243 0. 0 52203 135.1

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# 5.0 P ERFORMANCE 

# H IGHLIGHTS



# 5.1 Treatment Summary
Start Time 19

- Jan

- 10 12:50:40 

# End Time 19

- Jan

- 10 17:34:40 

# Pump Time 34.25 

# min Max Treating Pressure 3972 

# psi Avg Treating Pressure 2937 

# psi Clean Volume 17597 

# gal Max Slurry Rate 16.57 

# bpm Avg Slurry Rate 11.37 

# bpm Slurry Volume 20133 

# gal Max Proppant Concentration 3.96 

# lb/gal Proppant Mass Pumped 55683 

# lb Load to Recover 17597 

# gal Avg Combined Rate 38.06 

# bpm Max Combined Rate 40.48 

# bpm

Disclaimer: The average and maximum values (except volumes and bottom hole values) are based on the start and end averaging times.

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# 5.2 Job Event Log

Time Description Comment Treating Pressure psi Slurry Rate bpm Treatment Clean Volume gal Treatment Proppant lb

19

- Jan

- 10 12:50:59 Pause Suspending Job 0 0 .0 0 0

14:14:06 Resume Resuming Job

- 18 0.0 0 0 14:20:10 Stage 1 Breakdown

- 23 0.0 0 0 16:50:49 Stage 2 Pad 4073 5.8 616 0 16:56:51 Stage 3 Sand Slug 3077 5.9 2103 15 17:00:21 Stage 4 Pad 3029 9.3 3223 3527 17:04:06 Stage 5 1 ppg 2878 12.3 4719 3738 17:06:17 Stage 6 2 ppg 2796 12.0 5640 7937 17:08:40 Stage 7 2.5 ppg 2637 14.7 6686 15731 17:11:25 Stage 8 3 ppg 2568 14.6 7890 26428 17:13:59 Stage 9 4 ppg 2649 16.6 9100 38765 17:15:45 Stage 10 4 ppg CRC 2727 16.5 9944 46968 17:18:23 Stage 11 Flush 2416 19.9 11370 55683 17:30:02 Other Max Rate 16.57 bpm / Avg Rate 11.37 -9 0.0 17597 55683

17:31:39 Other Max Comb. 40.48 bpm / Avg Comb. 38.06 bpm -9 0.0 17597 55683

17:32:40 Other Total Load 419 bbls -9 0.0 17597 55683 17:33:21 Other Total Sand 556. 83 sks -8 0.0 17597 55683 17:33:30 Other ISIP 2460 -8 0.0 17597 55683

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# 6.0 A TTACHMENTS



# 6.1 Pressure Test

1/19/2010 16:34 16:36 16:38 16:40
1/19/2010 16:42
Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Treating Pressure (psig)

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# 6.2 Job Summary

1/19/2010 16:50 16:55 17:00 17:05 17:10 17:15
1/19/2010 17:20
Time 0 1000 2000 3000 4000 5000 A

0 10 20 30 40 50 60 70 80 90 100 B

0

2 4 6 8 10 12 14 C Treating Pressure (psig) Wellhead Rate (bpm) Wellhead Proppant Conc (lb/gal) BH Proppant Conc (lb/gal) A B C C

11 10 9 8 7 6 5 4 3 2 2

Local Event Log

2 Intersection

ISIP 17:22:29 TP

2460

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# 6.3 Rate Profile

1/19/2010 16:50 16:55 17:00 17:05 17:10 17:15
1/19/2010 17:20
Time 0 10 20 30 40 50 A

0 10 20 30 40 50 60 70 80 90 100 B Wellhead Rate (bpm) Slurry Rate (bpm) CO2 Liquid Rate (bpm) Predicted BH Int Phase (%) A A A B

11 10 9 8 7 6 5 4 3 2

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# 6.4 Chemical Additives - Pre Gel

1/19/2010 16:55 17:00 17:05 17:10 17:15
1/19/2010 17:20
Time 0 1 2 3 4 A

0 2 4 6 8 10 12 14 16 18 20 C Losurf-300D Conc (gal/Mgal) Cla-Sta(R) XP Conc (gal/Mgal) B2 WG-36 Conc -DA1 (lb/Mgal) A A C

11 10 9 8 7 6 5 4 3 2

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# 6.5 Chemical Additives - Blender

1/19/2010 16:55 17:00 17:05 17:10 17:15
1/19/2010 17:20
Time 0 1 2 3 4 A

0 2 4 6 8 10 12 14 16 18 20 C SUPERSET W Conc (gal/Mgal) Optiflo HTE Conc (lb/Mgal) HPH (0.125:39.875) Conc (gal/Mgal) C A A

11 10 9 8 7 6 5 4 3 2

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# 6.6 Net Pressure Plot

2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 1 10 100 Time (min) (0 = 1010) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

100 1000 10000 A

0 5 10 15 20 25 B Net Calc'd BH Pres (psi) BH Proppant Conc (lb/gal) Slope of Net Pressure (psi/min) A B C

11
10 9
8 7 6 5 4 3 Closure Pressure = 4000 psi

0 Time = 01/19/10 16:50:00

# SANDRIDGE ENERGY INC P.O. Box 548807 Oklahoma City, OK 73154

WEST RANCH SOUTH 71-5
Tesnus Interval – (3494’ – 3700’) Pecos County, Texas

Sales Order: 7119075



# Post Job Report

For: Jason Stewart Date: Tuesday, January 19, 2010

Notice: Although th e information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report w hether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s own risk.

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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2 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) Table of Contents

1.0 Executive Summary

................................................................................................ ........................................ 3 2.0 Well Information

................................................................................................ ............................................. 4

2.1 Customer Information

................................................................................................ ..................................... 4 2.2 Pipe Information

................................................................................................ .............................................. 4 2.3 Perforation Intervals

................................................................................................ ........................................ 4 3.0 Pumping Schedule

................................................................................................ ........................................... 5

3.1 Designed Pumping Schedule Treatment 3 3494.00 - 3700.00 ft

..................................................................... 5 3.2 Designed Surface CO2 Schedule Treatment 3 3494.00 - 3700.00 ft

............................................................... 6 3.3 Designed BH Foam Schedule Treatment 3 3 494.00 - 3700.00 ft

.................................................................... 6 4.0 Actual Stage Summary

................................................................................................ .................................... 7

4.1 Stage Summary

................................................................................................ ............................................... 7 4.2 Foam Stage Summary

................................................................................................ ..................................... 7 4.3 BH Foam Stage Summary

............................................................................................................................... 8 5.0 Performance Highlights

................................................................................................ ................................... 9

5.1 Treatment Summary

................................................................................................ ........................................ 9 5.2 Job Event Log

................................................................................................ ................................................ 10 6.0 Attachments

................................................................................................ ................................................... 11

6.1 Pressure Test

................................................................................................ ................................................. 11 6.2 Job Summary

................................................................................................ ................................................. 12 6.3 Rate Profile

................................................................................................ .................................................... 13 6.4 Chemical Additives - Blender

....................................................................................................................... 14 6.5 Chemical Additives - Pre gel

......................................................................................................................... 15 6 .6 Net Pressure Plot

................................................................................................ ........................................... 16

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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# 1.0 E XECUTIVE 

# S UMMARY

Jason Stewart SANDRIDGE ENERGY INC EBUSINESS P.O. Box 548807 Oklahoma City , OK 73154

Dear Jason Stewart,

Halliburton appreciates the opportunity to perform the stimulation treat ment on the WEST RANCH SOUTH 71

- 5. A pre

- job safety meeting was held where details of the job were discussed, potential safety hazards were reviewed, and environmental compliance procedures were outlined. Pump time was 69.78 min.

The proposed treatmen t for Stage 7 consisted of:

**•** 6000 gal of Water Frac G - R (11).

**•** 16875 gal of Water Frac G - R (11) carrying 129993 lb of OTTAWA 20/40

.

**•** 900 gal of Water Frac G - R (11) carrying 11997 lb of SUPER LC 20/40

.

**•** 5615 gal of Treated 4% KCL Water.

The treatment ac tually pumped consisted of:

**•** 5743 gal of Water Frac G - R (11).

**•** 17028 gal of Water Frac G - R (11) carrying 129156 lb of OTTAWA 20/40

.

**•** 1624 gal of Water Frac G - R (11) carrying 18543 lb of SUPER LC 20/40

.

**•** 2707 gal of Treated 4% KCL Water.

The average WH t reating rate was 37.23 bpm and average WH pressure was 2857 psi. There was 10 tons of CO2 used to cool down and 312 ton s of CO2 pumped down hole. The total liquid load to recover is 27103 gal. The ISIP was recorded at 3088 psi. The well was flushed using CO2, with a 20 bbl water cap.

Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, cros slink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids.

Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Hallibur ton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects.

Respectfully,

Levi Davenport Technical Professional 432.631.9516

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

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# 2.0 W ELL 

# I NFORMATION



# 2.1 Customer Information
Customer SANDRIDGE ENERGY INC EBUSINESS 

# Sales Order 7119075 

# Well Name WEST RANCH SOUTH 

# Well Number 71 -5 

# Start Time 19

- Jan

- 2010 

# County Pecos 

# State Texas 

# UWI/API 4237138589 

# Country United States of America 

# Customer Representative Jason Stewart 

# Halliburton R epresentative RODRIGUEZ



# 2.2 Pipe Information
Equipment Top MD ft Bottom MD ft OD in ID in Grade Weight lb/ft

Trt Interval 3494.0 3700.0 0.000 0.000 0.00 Casing 0.0 8883.0 7.000 6.276 P- 110 26.00



# 2.3 Perforation Intervals
Top MD ft Bottom MD ft Perf Density sp f Perf Phasing

° Perf Formation

3494.0 3504.0 0.5 1 Stage 7 - Tesnus 3544.0 3574.0 0.5 1 Stage 7 - Tesnus 3626.0 3634.0 1.0 1 Stage 7 - Tesnus 3662.0 3672.0 1.0 1 Stage 7 - Tesnus 3690.0 3700.0 1.0 1 Stage 7 - Tesnus

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# 3.0 P UMPING 

# S CHEDULE



# 3.1 Designed Pumpin g Schedule Treatment 3 3494.00 - 3700.00 ft

Stage Number Description Fluid System Clean Volume gal Prop Conc Start lb/gal Prop Conc End lb/gal Prop Mass lb Rate Stage Start bpm
3 - 1 Breakdown Water Frac G - R (11) 1000 0.00 0.00 5.0

3 - 2 Pad Water Fra c G - R (11) 3000 0.00 0.00 6.0

3 - 3 Sand Slug Water Frac G - R (11) 2500 5.00 5.00 12500 9.4

3 - 4 Pad Water Frac G - R (11) 2000 0.00 0.00 8.0

3 - 5 1 ppg Water Frac G - R (11) 3125 4.00 4.00 12500 11.3

3 - 6 2 ppg Water Frac G - R (11) 3000 6.67 6.67 20010 14.3

3 - 7 2.5 ppg Water Frac G - R (11) 3000 8.33 8.33 24990 14.8

3 - 8 3 ppg Water Frac G - R (11) 3000 10.00 10.00 30000 15.3

3 - 9 4 ppg Water Frac G - R (11) 2250 13.33 13.33 29993 16.3

3 - 10 4 ppg CRC Water Frac G - R (11) 900 13.33 1 3.33 11997 16.3

3 - 11 Flush Treated 4% KCL Water 5615 0.00 0.00 40.0

Total 29390 141990

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# 3.2 Designed Surface CO2 Schedule Treatment 3 3494.00 - 3700.00 ft

Stage Number Description Sur CO2 Liq Rate Begin bpm Sur CO2 Mass

ton
3 - 1 Breakdown 3 - 2 Pad 30.0 64.3 3

- 3 Sand Slug 28.0 39.3 3 - 4 Pad 29.0 31.1 3 - 5 1 ppg 26.0 36.4 3 - 6 2 ppg 23.0 26.9 3 - 7 2.5 ppg 23.0 27.5 3 - 8 3 ppg 22.0 26.8 3 - 9 4 ppg 21.0 20.1 3 - 10 4 ppg CRC 21.0 8.0 3 - 11 Flush 280.5



# 3.3 Designed BH Foam Schedu le Treatment 3 3494.00 - 3700.00 ft

Stage Number Description BH Clean Foam Vol gal BH Foam Rate Begin bpm BH Prop Conc Begin lb/gal
3 - 1 Breakdown 3 - 2 Pad 21605 43 0.00 3 - 3 Sand Slug 13860 44 0.90 3 - 4 Pad 10993 44 0.00 3 - 5 1 ppg 13666 43 0 .91 3 - 6 2 ppg 10785 43 1.86 3 - 7 2.5 ppg 10950 43 2.28 3 - 8 3 ppg 10759 42 2.79 3 - 9 4 ppg 8084 42 3.71 3 - 10 4 ppg CRC 3223 42 3.72 3 - 11 Flush 103925

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# 4.0 A CTUAL 

# S TAGE 

# S UMMARY



# 4.1 Stage Summary
Stage Number Avg Treating Pressure psi Avg Slu rry Rate bpm Clean Volume gal Avg Concentration lb/gal Proppant Mass Pumped lb
3 - 1 1542 5.3 799 0.00 0 3 - 2 2911 6.2 2948 1.00 30 3 - 3 2803 9.0 2583 4.67 11957 3

- 4 2875 8.3 1996 0.64 188 3 - 5 2827 12.1 3123 3.32 10311 3 - 6 2721 14.0 3000 6.79 20358 3 - 7 2707 14.1 3001 8.52 25557 3 - 8 2731 15.1 2999 10.16 30451 3 - 9 2834 16.0 2322 13.15 30522 3 - 10 3069 15.8 1624 11.79 18543 3 - 11 3856 15.8 2707 2.19 223

Total 27103 148140



# 4.2 Foam Stage Summary
Stage Number Avg Well Head Rate bpm WH Volume gal CO2 Mass ton
3 - 1 18.1 2712 8.1 3 - 2 36.9 17647 62.7 3

- 3 37.3 12911 41.4 3 - 4 38.8 9336 31.0 3 - 5 39.3 11715 34.0 3 - 6 38.7 10809 28.7 3 - 7 38.6 11391 30.1 3 - 8 39.0 11332 28.9 3 - 9 38.9 9022 22.1 3 - 10 38.4 6036 14.8 3 - 11 32.5 5596 12.1 108505 314.0

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# 4.3 BH Foam Stage Summary
Stage Number Avg BH Rate bpm BH Volume gal BH CO2 Mass ton BH CO2 Quality %
3

- 1 37.5 2774 70.5 3 - 2 37.3 17786 83.5 3 - 3 37.0 12604 78.7 3 - 4 38.3 9080 78.2 3

- 5 37.9 11373 71.6 3 - 6 37.7 10506 69.0 3 - 7 37.8 11096 70.0 3 - 8 38.0 11030 69.2 3 - 9 37.7 8774 68.9 3 - 10 15.8 5418 64.4

Total 100441 300.6

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# 5.0 P ERFORMANCE 

# H IGHLIGHTS



# 5.1 Treatment Summary
Start Time 19

- Jan

- 10 17:34:41 

# End Time 20

- Jan

- 10 10:03:44 

# Pump Time 69.78 

# min Max Treating Pressure 4920 

# psi Avg Treating Pressure 2857 

# psi Clean Volume 27103 

# gal Max Slurry Rate 16.0 

# bpm Avg Slurry Rate 11.73 

# bpm Slurry Volume 33844 

# gal Max Proppant Concentration 4.22 

# lb/gal Proppant Mass Pumped 148140 

# lb Proppant in Wellbore 880 

# lb Load to Recover 27103 

# gal Avg Combined Rate 37.23 

# bpm Max Combined Rate 40.68 

# bpm

Disclaimer: The average and maximum values (except volumes and bottom hole values) are based on the start and end averaging times.

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 7

10 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 5.2 Job Event Log

Time De scription Comment Treating Pressure psi Slurry Rate bpm CO2 Liquid

Rate bpm Treatmen t Clean Volume gal Treatmen t CO2 Mass

ton Treatmen t Proppant lb
19

- Jan

- 10 17:34:50 Pause Suspending Job 0 0.0 0.0 0 0.0 0

18:48:26 Resume Resuming Job

- 7 0.0 0.0 0 0.0 0 19:01:23 Pause Suspending Job 0 0.0 0.0 0 0.0 0 20

- Jan

- 10 07:56:46 Resume Resuming Job 0 0.0 0.0 0 0.0 0

08:22:02 Stage 1 Breakdown 138 0.0 0.0 0 0.0 0 08:46:50 Stage 2 Pad 3721 5.4 33.5 799 8.1 0 08:58:14 Stage 3 Sand Slug 2806 9.0 27.0 3753 70.9 38 09:06:28 Stage 4 Pad 2789 9.0 26.9 6336 112.2 11997 09:12:11 Stage 5 1 ppg 2943 11.8 26.3 8334 143.2 12181 09:19:17 Stage 6 2 ppg 2788 13.7 23.5 11449 177.2 22486 09:25:56 Stage 7 2.5 ppg 2712 14.0 23.3 14448 205.8 42844 09:32:58 Stage 8 3 ppg 2720 14 .9 22.8 17458 236.0 68481 09:39:53 Stage 9 4 ppg 2778 15.9 21.8 20457 264.9 98942 09:45:25 Stage 10 4 ppg CRC 2900 16.0 21.7 22779 287.1 129474 09:49:09 Stage 11 Flush 3357 15.8 21.4 24406 301.9 147942 10:01:08 Other Max Rate 16 bpm / Avg Rate 11.73 bp m - 45 0.0 0.0 27103 314.0 148140

10:02:16 Other Max Comb. Rate 40.68 bpm / Avg Comb. Rate 37.23 bpm - 45 0.0 0.0 27103 314.0 148140

10:02:33 Other Max PSI 4141 / Avg PSI 2857

- 45 0.0 0.0 27103 314.0 148140 10:02:43 Other Total Load 645 bbls

- 45 0.0 0.0 2 7103 314.0 148140 10:03:13 Other Total Sand 1481 .4sks

- 45 0.0 0.0 27103 314.0 148140 10:03:21 Other ISIP 3088

- 45 0.0 0.0 27103 314.0 148140 10:03:47 End Job Ending Job

- 45 0.0 0.0 27103 314.0 148140

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 7

11 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.0 A TTACHMENTS



# 6.1 Pressure Test

1/20/2010 08:30 08:35 08:40
1/20/2010 08:45
Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Treating Pressure (psig)

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 7

12 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.2 Job Summary

1/20/2010 08:50 09:00 09:10 09:20 09:30 09:40
1/20/2010 09:50
Time 0 1000 2000 3000 4000 5000 A

0 10 20 30 40 50 60 70 80 90 100 B

0

2 4 6 8 10 12 14 16 18 C Treating Pressure (psig) Wellhead Rate (bpm) Wellhead Proppant Conc (lb/gal) BH Proppant Conc (lb/gal) A B C C

11 10 9 8 7 6 5 4 3 2 3

Local Event Log

3 Intersection

ISIP 09:53:25 TP
3089

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 7

13 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.3 Rate Profile

1/20/2010 08:50 09:00 09:10 09:20 09:30 09:40
1/20/2010 09:50
Time 0 10 20 30 40 50 A

0 10 20 30 40 50 60 70 80 90 100 B Wellhead Rate (bpm) Slurry Rate (bpm) CO2 Liquid Rate (bpm) Predicted BH Int Phase (%) A A A B

11 10 9 8 7 6 5 4 3 2

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 7

14 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.4 Chemical Additives - Blender

1/20/2010 08:50 09:00 09:10 09:20 09:30 09:40
1/20/2010 09:50
Time 0 1 2 3 4 A

0 2 4 6 8 10 12 14 16 18 20 C SUPERSET W Conc (gal/Mgal) Optiflo HTE Conc (lb/Mgal) HPH (0.125:39.875) Conc (gal/Mgal) C A A

11 10 9 8 7 6 5 4 3 2

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 7

15 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.5 Chemical Additives - Pre gel

1/20/2010 08:50 09:00 09:10 09:20 09:30 09:40
1/20/2010 09:50
Time 0 1 2 3 4 A

0 2 4 6 8 10 12 14 16 18 20 C Losurf-300D Conc (gal/Mgal) Cla-Sta(R) XP Conc (gal/Mgal) B2 WG-36 Conc -DA1 (lb/Mgal) A A C

11 10 9 8 7 6 5 4 3 2

### SANDRIDGE ENERGY INC WEST RANCH SOUTH 71

- 5 Interval 7

16 Created: October 25, 2012 at 12:48 PM INSITE for Stimulation V. 3.4.0 (IFS v3.4.0) 

# 6.6 Net Pressure Plot

2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 1 10 100 Time (min) (0 = 526) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

100 1000 10000 A

0 5 10 15 20 25 B Net Calc'd BH Pres (psi) BH Proppant Conc (lb/gal) Slope of Net Pressure (psi/min) A B C

11 10
9 8 7 6 5 4 3 Closure Pressure = 3000 psi

0 Time = 01/20/10 08:46:00

### Stage #: 5 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 4,696' Bottom Perf: 4,810' Displ Coef: SPF: Total # of Holes: 40

Displacement to top perf: bbls Actual Displacement: bbls 7,900 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Conc. (ppg) Weight (lbs) Type

1ppg 4,066 20/40 Ottawa

1ppg 6,608 20/40 Ottawa 2ppg 10,586 20/40 Ottawa 2.5ppg 13,317 20/40 Ottawa 3ppg 16,112 20/40 Ottawa 4ppg 15,900 20/40 Ottawa 4ppg 13,402 20/40 CRC

BBLS Gal LTR: 23310.0 Gals

LBS

85-70 % tons CO2

3,988 psig 7551 psig

38.0 bpm 40 bpm


## ISIP = 3,415 psig

Yes 1.0

No 180.0 MAXIMUM PRESSURE Liner Top Depth .5-1spf 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

SandRidge Supervisor(s): Johnny Anaya Halliburton

Displ Coef: 0.0383 1/19/2010 11:49:00 AM 12:38:00 PM

7"

4,300

FET ANALYSIS Frac Grad:

FLUIDS PUMPED PROPPANT PUMPED Volume (bbls) Rate (bbl/min) Pressure (Psi) 0 179.7

51.0 Pad 20# Linear Gel/85Q CO2 38 4143.0 52.0 PI 4% Crystaline KCL Water 5 4300.0

28.0 Pad 20# Linear Gel/80Q CO2 38 3900.0 29.0 1ppg 20# Linear Gel/80Q CO2 39 4100.0

43.0 2ppg 20# Linear Gel/70Q CO2 40 3956.0 36.0 1ppg 20# Linear Gel/75Q CO2 38 3882.0

36.0 3ppg 20# Linear Gel/70Q CO2 39 3902.0 36.0 2.5ppg 20# Linear Gel/70Q CO2 40 3882.0

36.0 4ppg 20# Linear Gel/70Q CO2 38 4047.0 29.0 4ppg 20# Linear Gel/70Q CO2 37 3890.0

179.0 Flush 4% Crystaline KCL Water 32 4527.0

555

Total Proppant: 79,991 Type of Proppant: *66,589# 20/40 Ottawa, *13,402# 20/40 CRC

Foam Quality: Amount of Foam Pumped: 178DH/12CD Type of foam:

X-Link Breaker Time:

Avg Treating Press= Maximum =

Was Treatment Underdisplaced? If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in Fluid Type

Continue on next page if necessary

Avg Treating Rate = Maximum = How many ball sealers were pumped: Was there ball action seen? Total Fluid Pumped:

hours before flowing back.

Remarks/Notes

### Stage #: 5 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Pipe 1 Size: Pipe 2 Size: Top Perf: 4,696' Bottom Perf: 4,810' Displ Coef: SPF: Total # of Holes: 40

Displacement to top perf: bbls Actual Displacement: bbls 7,900 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Fluid Type Conc. (ppg) Weight (lbs) Type SandRidge Supervisor(s): Johnny Anaya Halliburton

Displ Coef: 0.0383 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

12:38:00 PM

7"

PROPPANT PUMPED Liner Depth 1/19/2010 11:49:00 AM

0 4,300 .5-1spf

179.7 180.0 MAXIMUM PRESSURE

FLUIDS PUMPED (CONTINUED FROM PAGE 1) Volume (bbls) Pressure (psi) Rate (bbl/min)

Remarks/Notes

### Stage #: 1 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa 2.0 14,795 20/40 Ottawa 2.5 20,083 20/40 Ottawa 3.0 18,988 20/40 Ottawa 4.0 21,642 20/40 Ottawa 4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm


## ISIP = 3,400 psig

Yes 2.0

No 4 12/22/2009 10:10:00 AM

Displ Coef: 0.0383 0.5 - 2 SPF Liner Top Depth 7.000

MAXIMUM PRESSURE 

# SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s): Treatment Report

Superior Well Services Jason Stewart

56.0 3,292 38.0 22.0 3,485 38.8 35.0 3,507 37.0 20# Linear gel, 80Q CO2 12:36:00 PM

45.0 3,439 39.7 4% Crystalline KCl 20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2 3,125 198.0 199.2

53.0 3,541 38.1 43.0 3,544 38.2 42.0 3,896 38.4 32.0 3,873 37.1 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 57.0 3,726 30.0 4% Crystalline KCl

Total Fluid Pumped: 441

Total Proppant: 97,100 Type of Proppant: 20/40 Ottawa, 20/40 SLC

Foam Quality: Amount of Foam Pumped: 400 Type of foam:

X-Link Breaker Time: n/a

n/a

Avg Treating Press= Maximum = FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum =

hours before flowing back.

Remarks/Notes Was Treatment Underdisplaced? If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in How many ball sealers were pumped: Was there ball action seen? 250

FET ANALYSIS Frac Grad:

3,882 38.0 Volume (bbls) Pressure (psi) Rate (bbl/min) 16.0 2,560 2.0 40.0

### Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report 1 sec (or 2 sec) data in .csv of .txt form Service Company Treatment Report Service Company Field Ticket 

## areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com; mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com; tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com; scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com

### Stage #: 6 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 3,870' Bottom Perf: 4,000' Displ Coef: SPF: Total # of Holes: 40

Displacement to top perf: bbls Actual Displacement: bbls 7,900 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Conc. (ppg) Weight (lbs) Type

1ppg 3,599 20/40 Ottawa

1ppg 4,451 20/40 Ottawa 2ppg 7,666 20/40 Ottawa 2.5ppg 10,766 20/40 Ottawa 3ppg 12,283 20/40 Ottawa 4ppg 8,155 20/40 Ottawa 4ppg 8,763 20/40 SLC

BBLS Gal LTR: 17556.0 Gals

LBS

85-70 % tons CO2

2,937 psig 3972 psig

38.1 bpm 40.5 bpm


## ISIP = 2,460 psig

No 0.0

No How many ball sealers were pumped: Was there ball action seen?

Avg Treating Press= Maximum =

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced? If so, by how many bbls/gal?

hours before flowing back.

Remarks/Notes Was well flowed back immediately? If not, well was shut-in Total Fluid Pumped: 418

Total Proppant: 55,683 Continue on next page if necessary

*46,920# 20/40 Ottawa, *8763# 20/40 SLC

Foam Quality: Amount of Foam Pumped: 142DH/10CD Type of foam: Type of Proppant:

X-Link Breaker Time: 33.0 4ppg 20# Linear Gel/70Q CO2 39 2740.0 20.0 4ppg 20# Linear Gel/70Q CO2 39 2662.0

148.0 Flush 4% Crystaline KCL Water 38 3107.0 25.0 2ppg 20# Linear Gel/70Q CO2 39 2777.0 22.0 1ppg 20# Linear Gel/75Q CO2 39 2863.0

28.0 3ppg 20# Linear Gel/70Q CO2 39 2601.0 29.0 2.5ppg 20# Linear Gel/70Q CO2 39 2632.0 36.0 Pad 20# Linear Gel/85Q CO2 37 3535.0 15.0 BD 4% Crystaline KCL Water 5 2949.0

35.0 Pad 20# Linear Gel/80Q CO2 38 3019.0 27.0 1ppg 20# Linear Gel/80Q CO2 38 3076.0 Volume (bbls) Rate (bbl/min) Pressure (Psi) 1,600 2,949

FET ANALYSIS Frac Grad:

Fluid Type FLUIDS PUMPED PROPPANT PUMPED Liner Top Depth

148.1 148.0 MAXIMUM PRESSURE 1-2spf 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

SandRidge Supervisor(s): Johnny Anaya Halliburton

Displ Coef: 0.0383 1/19/2010 4:50:00 PM 5:30:00 PM

7"

### Stage #: 6 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Pipe 1 Size: Pipe 2 Size: Top Perf: 3,870' Bottom Perf: 4,000' Displ Coef: SPF: Total # of Holes: 40

Displacement to top perf: bbls Actual Displacement: bbls 7,900 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

Remarks/Notes Volume (bbls) Pressure (psi) Rate (bbl/min) 1-2spf

148.1 148.0 MAXIMUM PRESSURE

PROPPANT PUMPED 1,600 2,949

FLUIDS PUMPED (CONTINUED FROM PAGE 1) Liner Depth 1/19/2010 4:50:00 PM

7" SandRidge Supervisor(s): Johnny Anaya Halliburton

Displ Coef: 0.0383 5:30:00 PM 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

### Stage #: 1 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa 2.0 14,795 20/40 Ottawa 2.5 20,083 20/40 Ottawa 3.0 18,988 20/40 Ottawa 4.0 21,642 20/40 Ottawa 4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm


## ISIP = 3,400 psig

Yes 2.0

No 4 250

FET ANALYSIS Frac Grad:

Volume (bbls) Pressure (psi) Rate (bbl/min)

Avg Treating Press= Maximum = X-Link Breaker Time: n/a FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in How many ball sealers were pumped: Was there ball action seen? n/a Foam Quality: Amount of Foam Pumped: 400 Type of foam: Type of Proppant: 20/40 Ottawa, 20/40 SLC Total Fluid Pumped: 441

Total Proppant: 97,100 57.0 3,726 30.0 4% Crystalline KCl 53.0 3,541 38.1 43.0 3,544 38.2 42.0 3,896 38.4 32.0 3,873 37.1 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 16.0 2,560 2.0 40.0 3,882 38.0

56.0 3,292 38.0 22.0 3,485 38.8 35.0 3,507 37.0 20# Linear gel, 80Q CO2 12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7 4% Crystalline KCl 20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2 3,125 Displ Coef: 0.0383 0.5 - 2 SPF Liner Top Depth 7.000

MAXIMUM PRESSURE 198.0 199.2 

# SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s): Treatment Report

Superior Well Services Jason Stewart

### Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report 1 sec (or 2 sec) data in .csv of .txt form Service Company Treatment Report Service Company Field Ticket 

## areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com; mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com; tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com; scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com

### Stage #: 7 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 3,494' Bottom Perf: 3,700' Displ Coef: SPF: Total # of Holes: 48

Displacement to top perf: bbls Actual Displacement: bbls 7,900 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Conc. (ppg) Weight (lbs) Type

1ppg 12,905 20/40 Ottawa

1ppg 11,126 20/40 Ottawa 2ppg 21,071 20/40 Ottawa 2.5ppg 26,329 20/40 Ottawa 3ppg 31,222 20/40 Ottawa 4ppg 31,298 20/40 Ottawa 4ppg 11,955 20/40 CRC

BBLS Gal LTR: 27090.0 Gals

LBS

85-70 % tons CO2

2,857 psig 4141 psig

37.3 bpm 40.5 bpm


## ISIP = 3,088 psig

Yes 2.0

No 4 How many ball sealers were pumped: Was there ball action seen?

Avg Treating Press= Maximum =

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced? If so, by how many bbls/gal?

hours before flowing back.

Remarks/Notes Was well flowed back immediately? If not, well was shut-in Total Fluid Pumped: 645

Total Proppant: 145,906 Continue on next page if necessary

*133,951# 20/40 Ottawa, *11,955# 20/40 SLC

Foam Quality: Amount of Foam Pumped: 312DH/10CD Type of foam: Type of Proppant:

X-Link Breaker Time: 39.0 4ppg 20# Linear Gel/70Q CO2 38 2963.0 55.0 4ppg 20# Linear Gel/70Q CO2 38 2784.0

64.0 Flush 4% Cryst. KCL/60Q CO2 38 3426.0 71.0 2ppg 20# Linear Gel/70Q CO2 38 2760.0 74.0 1ppg 20# Linear Gel/75Q CO2 38 2929.0

71.0 3ppg 20# Linear Gel/70Q CO2 38 2718.0 72.0 2.5ppg 20# Linear Gel/70Q CO2 38 2708.0 70.0 Pad 20# Linear Gel/85Q CO2 37 3236.0 19.0 BD 4% Crystaline KCL Water 5 2296.0

48.0 Pad 20# Linear Gel/80Q CO2 37 2786.0 62.0 1ppg 20# Linear Gel/80Q CO2 37 2811.0 Volume (bbls) Rate (bbl/min) Pressure (Psi) 520 2,296

FET ANALYSIS Frac Grad:

Fluid Type FLUIDS PUMPED PROPPANT PUMPED Liner Top Depth

133.7 132.0 MAXIMUM PRESSURE 1spf 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

SandRidge Supervisor(s): Johnny Anaya Halliburton

Displ Coef: 0.0383 1/20/2010 8:50:00 AM 9:53:00 AM

7"

### Stage #: 7 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Pipe 1 Size: Pipe 2 Size: Top Perf: 3,494' Bottom Perf: 3,700' Displ Coef: SPF: Total # of Holes: 48

Displacement to top perf: bbls Actual Displacement: bbls 7,900 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

Remarks/Notes Volume (bbls) Pressure (psi) Rate (bbl/min) 1spf

133.7 132.0 MAXIMUM PRESSURE

PROPPANT PUMPED 520 2,296

FLUIDS PUMPED (CONTINUED FROM PAGE 1) Liner Depth 1/20/2010 8:50:00 AM

7" SandRidge Supervisor(s): Johnny Anaya Halliburton

Displ Coef: 0.0383 9:53:00 AM 

# SandRidge Energy, inc.
Treatment Report Well Name: West Ranch South 71-5

### Stage #: 1 Formation: Tesnus

Stimulation Company:

Date: Start Time: End Time: Treatment Type: Sand Frac

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250' Displ Coef: SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls 5,700 psi Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi Holes Open: Fluid Eff: (%) 5 min SIP: psi Max Rate: Calc. Perm: mD 10 min SIP: psi Max Pressure: Pc (psig) psi 15 min SIP: psi

Fluid Type Conc. (ppg) Weight (lbs) Type

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa 2.0 14,795 20/40 Ottawa 2.5 20,083 20/40 Ottawa 3.0 18,988 20/40 Ottawa 4.0 21,642 20/40 Ottawa 4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm


## ISIP = 3,400 psig

Yes 2.0

No 4 250

FET ANALYSIS Frac Grad:

Volume (bbls) Pressure (psi) Rate (bbl/min)

Avg Treating Press= Maximum = X-Link Breaker Time: n/a FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum =

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in How many ball sealers were pumped: Was there ball action seen? n/a Foam Quality: Amount of Foam Pumped: 400 Type of foam: Type of Proppant: 20/40 Ottawa, 20/40 SLC Total Fluid Pumped: 441

Total Proppant: 97,100 57.0 3,726 30.0 4% Crystalline KCl 53.0 3,541 38.1 43.0 3,544 38.2 42.0 3,896 38.4 32.0 3,873 37.1 20# Linear gel, 70Q CO2 20# Linear gel, 70Q CO2 16.0 2,560 2.0 40.0 3,882 38.0

56.0 3,292 38.0 22.0 3,485 38.8 35.0 3,507 37.0 20# Linear gel, 80Q CO2 12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7 4% Crystalline KCl 20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2 3,125 Displ Coef: 0.0383 0.5 - 2 SPF Liner Top Depth 7.000

MAXIMUM PRESSURE 198.0 199.2 

# SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s): Treatment Report

Superior Well Services Jason Stewart

### Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report 1 sec (or 2 sec) data in .csv of .txt form Service Company Treatment Report Service Company Field Ticket 

## areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com; mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com; tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com; scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com

## December 22, 2009 POST TREATMENT REPORT Sand Ridge Energy West Ranch South 71-5 Stg.1 Pecos County, Tx. Treatment Date: December 22, 2009

Attn: West Ranch South 71-5 Stg.1

The stimulation of the West Ranch South 71-5 stg. #1 well consisted of 4,619 bbls of 25#/30Q Linear Gel fluid and 294 tons of CO2. Th is fluid was laden with 10,742 lbs of 100 mesh sand in a .5, .75 lb hold, also 41,029 lbs of 40/70 TLC sand in a 1, 1.25, 1.5 lb hold, also 78,000 lbs of 20/40 TLC sand in a 1-4 lb hold, and 14,121 lbs of 20/40 SLC sand in a 4 lb hold. It was pumped at an average rate of 74.9 bpm, and an average surface pressure of 5,095 psi. The ISIP was 3,641 psi and the approximate load to recove r is 4,462 bbls. Please find the attached Meyers charts recorded during the job for stg. #1.

Superior Well Services appreciates the opportunity to perform pumping services for you in a cost-effective manner that focuses on quality and safety.

Please contact the Midland Engineering Department if you have any questions,

Thank you, Ricky Herrera Field Service Tech Midland, TX (432) 813-6420Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATE

Superior Rep. Customer Rep. Stage # Joe Smith

Co2 Rate CO2 Total Total Rate

BPM BBLS BPM

56 19 28 63 20 44 64 22 64 74 22 75 74 22 94 74 22 107 74 22 125 74 23 137 75 22 158 74 23 170 75 23 189 75 Stimulation Treatment Report

55-000296 12/22/09

West Ranch 71-5 Pecos Sandridge Energy

TX

Cesar Pando 1

Job Descript ion / Remarks

Arrived on Location

Safety Meeting ANNULUS BPM BBLS BBLS 3:00am

Time Pressures (psi) Rate Stage Total

STP

3:15am 3:40am Finished Rig Up Well Data 8:00am Prime/Testlines 7:30am Rig Up Equipment

Tubing Depth N/A 10:11am 250 29 56 407 FET/ Pad Packer Depth Safety Meeting Tubing Type N/A 10:10am 206 29 Open wellhead 10:00am

.5 ppg 100 mesh Casing Depth 8360 ft 11:37am 4875 29 52 264 1,442 Sweep 11:32am 5273 29 44 212 1,178 N/A 11:17am 3124 29 44 559 966 Pad Casing Type 7 26lb

new 11:45am 5200 29 52 252 1,840 Sweep Formation Caballos 11:42am 5315 29 52 146 1,588 .75 ppg 100 mesh Well Type

1.25 ppg 40/70 TLC Tubing Cap. N/A 12:00pm 5116 29 52 269 2,674 sweep 11:59am 5090 29 52 163 2,405 Casing Cap. 321 bbls 1.0 ppg 40/70 TLC Treatment Fluid and Capacities in BBLS 11:57am 5152 29 52 239 2,242 Sweep 11:49am 5250 29 52 163 2,003

25 bbls 12 08 5090 29 52 252 3 073 S 12:05pm 5222 29 52 147 2,821 1.5 ppg 40/70 TLC Fluid To Load Page 1

23 189 75 23 201 75 23 220 75 21 236 73 22 250 75 20 262 74 20 270 74 20 276 74 54 3,681 1.0 ppg 20/40 TLC Fluid To Recover 4462 bbls 12:08pm 5090 29 52 252 3,073 Sweep Pad Volume 2494 bbls

4,068 1.5 ppg 40/70 TLC Treating Fluid 1808 bbls 12:16pm 5006 29 52 252 3,477 sweep 12:13pm 5143 29 52 152 3,225
Flush 321 bbls 12:21pm 5167 29 52 204 12:24pm 5028 29 53 202 3,883 2.0 ppg 20/40 TLC

25 # Gel 163,590 gals Volume Pumped (Gals) 3.0 ppg 20/40 TLC Treatment Data 12:31pm 4820 29 54 131 4,199 4.0 ppg 20/40 TLC 12:28pm 4878 29 54 185

4.0 ppg 20/40 SLC Fluid Description

12:36 4397 29 54 321 4,623 Flush 12:34pm 4712 29 54 103 4,302

30,576 gals Base Fluid

Proppant Description Volume Pumped (lbs) ( Comments ) 100 Mesh 10,742 lbs Treatment Data

41029 lbs getting started 20/40 TLC 78,000 lbs had to wait on water tests before 40/70 TLC

Treatment Data 20/40 SLC 14,121 lbs

Maximum 5315 Maximum 56 5 Min. SuperNE-1 Treating Presure Injection Rates Shut In Pressures Materials
Minimum 206 Minimum 44 ISDP 3641 psi LSG SuperFoam

SuperSet Act

Operators Max Pressure 6200 psi 15 Min. Gel Average 4491 Average 52 10 Min.

OB-2 Final OB-1BLENDER CHEMICALS60708090100110120130140150160TIME (min)0123456789100.000.511.021.532.042.553.063.574.084.595.010Real-Time SUPER FOAM GPT (gal/1000 gal)Real-Time SUPER NE 100 GPT (gal/1000 gal)Real-Time OB1/OB2 PPT (lb/gal)Real-Time ACTIVATOR GPT (gal/1000gaMView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009DENSITY PLOTS708090100110120130140150TIME (min)01234567 BLENDER DENSITY (lb/gal)01234567 INLINE DENSITY (lb/gal)Real-Time BLENDER DENSITY (lb/gal)Real-Time INLINE DENSITY (lb/gal)MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009BOTTOM HOLE QUALITY PLOT60708090100110120130140150160TIME (min)0051010201530204025503060357040804590501000102030405060708090100Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009HYDRATION CHEMICALS60708090100110120130140150160TIME (min)02468101214161820 LSG GPT (gal/1000 gal)012345678910 SUPER NE 100 GPT (gal/1000 gal)Real-Time LSG GPT (gal/1000 gal)Real-Time SUPER NE 100 GPT (gal/1000MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009WEST RANCH SOUTH 71-5 STG.10102030405060708090100110120130140150160TIME (min)001000520001030001540002050002560003070003580004090004510000500102030405060708090100Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)Real-Time FOAM RATE (bpm)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009Net Pressure vs Time1101001000Time (min)10100100010000 Net Pressure (psi)0.010.1110 Concentration (lbm/gal)Measured Net Pressure (psi)BH Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009BHTP & SP WEST RANCH SOUTH 71-5 STG.10102030405060708090100110120130140150160Time (min)0100020003000400050006000700080009000100001100012000 Pressure (psi)00204408601280161002012024 Rate & ConcentrationMeasured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)Measured Surface Slurry Rate (bpm)BH Conc. (lbm/gal)Measured Surface Slurry Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009CUSTOMERWELL NAMEDATEFIELD RECIEPT #FLUID TECHSANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th stge 12th stge Total BBLSWater bbls. Per stges.>>0SYSTEM:Chemicals BEG. ENDINGTotal UsedLSG-1 4000 3054 946946OB/OB-2 500 460 4040ACTIVATOR 201 179 2222SUPER FOAM 1319 1006 313313SUPER 100 NE 1780 1446 334334#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!000000000Comments :

### Page of

Propant placed in the district proppant silos shall be tested at a minimum interval of every 250,000 pounds. X

Size lb Size lb No

94.0% 0.0%

Recognized proppant or gravel sizes: 6/12, 8/16, 12/20, 16/20, 16/30, 20/40, 30/50, 40/70, or 50/70 (40/60 for gravel)

*Recombine all proppant samples to represent 100,000 lbs or fraction. Gravel samples should represent 2,000 lbs or fraction. DISTRICT PROPPANT SILO: UNIT/COMPARTMENT:

Amount Retained Total weight , each size

fines 30 Sieve Analysis

Sieve mesh 50 grams of sample Weight

Combine all samples Weight slip available? Attach all. Yes/ N Net weight delivered VENDOR: LEASE NAME & WELL NO:

Brady Ottawa

Trucking company

Weight Nominal size from list below Ceramic proppant Sintered bauxite Other (specify) Proppant 100 mesh sand If proppant, select type Gravel

Resin coated sand 

# QUALITY CONTROL OF PROPPANT/GRAVEL/ 100 MESH SAND (Attachment to Treatment Report)

CUSTOMER:

FIELD RECEIPT NO:

If gravel, select type Ottawa Resieved Other (specify) Curable

Note: Use additional copies of this form for additional trucks,sizes,or vendors Truck number No. No. No. No. No.

Yes Is total weight for each size appropriate for job requirements? Is the content color right Yes/No Yes

Does the manufacturer's Yes of the truck proper? low dust Yes/No appearance right Yes/No Yes

insize>90% no contamination Yes/No Yes

Yes/No Yes Yes/No Yes oversize <.1% sieve analysis meet fines<1% Yes specifications? Attach all. Sample taken? Yes/No Yes/No Yes

Spot check manufacturer's sieve analysis at a minimum of every 250,000 lbs. If not appropriate, correct problem before sieve analysis. If the manufacturer's sieve analysis does not meet specifications, perform sieve analysis. 

### Is the truck content acceptable? Yes/No Yes

0.00

50.0

pass fail fines 0 1.1 2.20

100.00 

# }

0.00

Tested By: FOX pass fail pass Total wt. Gram Turbidity 19.5 1.1

8.00 47.00 39.00 2.20 50

0 Gram

4 23.5

Turbidity 40 50 60 70

pH Pan Total wt. Gram Combine all samples grams of sample Amount Retained Sieve Analysis

40/70 TLC Sieve mesh 0 Total 1.60 0.8 0.00 %

In-Size

100 % 0.00 Gram

0.00 Total 0.00 In-Size 0.00 

# } 0.00 0.00

pH pass fail 0.0 0.00 Pan 0.00

fail

### Page of

Propant placed in the district proppant silos shall be tested at a minimum interval of every 250,000 pounds. X

X

Size lb Size lb No

94.8% 93.4%

Recognized proppant or gravel sizes: 6/12, 8/16, 12/20, 16/20, 16/30, 20/40, 30/50, 40/70, or 50/70 (40/60 for gravel)

*Recombine all proppant samples to represent 100,000 lbs or fraction. Gravel samples should represent 2,000 lbs or fraction. 40 20 2.1 4.20 In-Size

fail 30 19.5 39.00 

# } 35 4.4 8.80

0.00 0.07 0.14 Total

22.8 45.60

0 0 0 0.00 Gram %

16 3.40

4.2 20.5 

# }

8.40 41.00 22.7 Total Combine all samples grams of sample Amount Retained Gram

In-Size 0.18 0.09 Sieve Analysis

20/40 SLC Sieve mesh 0 50

0.00 % 0

1.7

50.0 Turbidity 20 30 35 40 50

Tested By: FOX pass fail pH Pan Total wt. Gram pass Total wt. Gram Turbidity pH pass 50.0 99.94 fail 0.8 1.60 50

pass fail fines 0 99.98 0.00 Pan Yes

1.1 2.20 Yes/No

fines Combine all samples

45.40 Sample taken? Yes/No Yes/No

Spot check manufacturer's sieve analysis at a minimum of every 250,000 lbs. If not appropriate, correct problem before sieve analysis. If the manufacturer's sieve analysis does not meet specifications, perform sieve analysis. 

### Is the truck content acceptable? oversize <.1% sieve analysis meet fines<1% Yes/No Yes specifications? Attach all. insize>90% Yes/No Yes Does the manufacturer's

Yes Yes Yes/No Yes appearance right Yes/No Yes no contamination Yes Yes of the truck proper? low dust Yes/No Yes Is total weight for each size appropriate for job requirements? Is the content color right Yes/No No.

Weight slip available? Attach all. Yes/ N Note: Use additional copies of this form for additional trucks,sizes,or vendors Truck number No. No. No. No. Proppant 100 mesh sand

Other (specify) Curable If proppant, select type

Ottawa Gravel

Ceramic proppant Sintered bauxite Other (specify) VENDOR: LEASE NAME & WELL NO:

Brady UNIT/COMPARTMENT:

If gravel, select type Ottawa

Resin coated sand FIELD RECEIPT NO:

Trucking company 

# QUALITY CONTROL OF PROPPANT/GRAVEL/ 100 MESH SAND (Attachment to Treatment Report)

CUSTOMER:

Weight Net weight delivered

Weight Nominal size from list below DISTRICT PROPPANT SILO:

16 Sieve Analysis

20/40 TLC Sieve mesh Resieved

Amount Retained Total weight , each size

grams of sample 50Total Variance: 1.38%PAGE:DATE:FLUID TECH:FIELD RECEIPT NO:2 3 4 5 6 7 8 9 10 11 12PLANNED FLOWPROPOSED START HOSES END TOTAL LOSSES PUMPED VOLUME METER PLANNED FLOW METERVOLUME LOADED USED DOWNHOLE FOR FLUID MEASURED VS. VS.PUMPED VOLUME DOWNHOLE DOWNHOLE877 4000 3990 3054 946 10 936 946 -1.06%35 500 500 460 40 0 40 40 0.00%12 201 200 179 22 1 21 22 -4.55%280 1319 1315 1006 313 4 309 313 -1.28%292 1780 1780 1446 334 0 334 334 0.00%13 14201CUSTOMER:SUPER FOAMLSG-1OB/OB-2ACTIVATORSUPER 100 NEPROPPANT (lbs)PRODUCTSANDRIDGEPRODUCT VARIANCE CALCULATIONSCHEMICALSCALCULATED VARIANCE%FOXCALVIN/HERBIE12/22/2009WEST RANCH SOUTH 71-5LEASE NAME & WELL NO:MEASURED VOLUMESCHEM-ADD OPERATOR:15 16 17 18 19PROPPANT TYPE S.G. PRE-JOB AMOUNT ON POST-JOB AMOUNTVARIANCE %20/40 TLC 2.6520/40 SLC 2.65100 MESH 2.640/70 TLC 2.6527VARIANCE %-7.83%41CLEAN VOLUMEVARIANCE %-4.59%Comments:28DOWNHOLE VOLUME4,619.0FLOW METER SLURRY VOLUME10,514SLURRY VOLUME (bbls)2925# LINEAR GEL4,841BEGINNING VOLUME AFTER LOADINGBASE FLUID DESCRIPTIONDENSIOMETERTOTAL264,841.0SPILLAGE42,00030 4022(est.on the ground)LOCATION DOWNHOLEIN SAND KING (est.)23 25TOTAL SLURRY4,84115,300CLEAN VOLUME (bbls)PROPPANT VOLUME21FLOW METER VOLUME4,462PUMPED15,3552446,840ENDING VOLUME168,200216,080PageofDATE:CUSTOMER:Tank/Transport No. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16Water QualityDate filled:CityWellPondOtherClarity, color, odorCLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEARSample Temperature, (F) 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60Specific gravity1.010 1.010 1.000 1.010 1.010 1.010 1.010 1.000 1.000 1.001 1.001 1.010 1.010 1.002 1.002 1.002Initial pH6.8 6.9 7 7 7 6.8 7 7 7 6.9 7.000 7.000 7.000 7.000 7.000 7.000Iron (Fe++/Fe+++) ppm0000000000000000Reducing Agent (Yes or No)Sulfate, ppm<200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200Chloride, ppm9000 9000 200 9000 9000 9000 9000 200 200 800 9000 9000 9000 1000 1000 1000Calcium, ppmMagnesium, ppmBF-7L Precipitate > > > > >BacteriaYesNoAerobic: No. per ml/time / / / / / / / / / / / / / / /Anaerobic: No. per ml/time///////////////Base Gel QualityUse additional copies of this form for each series of tests @ 24 hr. intervals & prior to pumping.Name of product system mixed#LINEAR GELGellant loading (lbs/1000 gal.) 6.25GPTFluid sampling location PILOTSampling time 5AMSample Temperature, (F) 60pH 73min.21Fann reading 9min.25@ 300 rpm 30min.2860min.30X-Link Vortex Closure, min:secX-Link Crown, min:secX-Link pHStageViscosity (cp)pHXL time @ blender, sec.Sample TemperatureTime fluid pumpedTested by:TanksNote: Use additional copies of this report for testing additional material lots or tanks.This job will be:Gelled on-the-flyBatch MixedSANDRIDGELEASE NAME & WELL NO:Date water sampled:Source of water:Date Biocide Added:Date Biocide Added:WATER BASED FRAC FLUID QUALITY CONTROL(Attachment to Treatment Report)12/22/2009 FIELD RECEIPT NO:WEST RANCH SOUTH 71-5This test data is considered to be a minimum standard. Additional testing or documentation may be required by the customer orfor frac quality assurance. Data recorded electronically with Engineering approved monitoring devices may besubstituted for applicable portions of this form. This testing data is considered to be the minimum needed for the well file.FOXBiocide added before H2O?Field Pilot Test Batch Mixed Gel Quality TestFrac Fluid Quality(These measurements are made as the job is pumped)PageofDATE:CUSTOMER:Tank/Transport No. 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32Water QualityDate filled:CityWellPondOtherClarity, color, odorCLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEARSample Temperature, (F) 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60Specific gravity1.002 1.002 1.000 1.001 1.002 1.001 1.200 1.010 1.001 1.001 1.010 1.010 1.010 1.002 1.002 1.002Initial pH6.8 6.9 7 7 7 6.8 7 7 7 6.9 7.000 7.000 7.000 7.000 7.000 7.000Iron (Fe++/Fe+++) ppm0000000000000000Reducing Agent (Yes or No)Sulfate, ppm<200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200Chloride, ppm1000 1000 200 800 1000 800 150000 9000 800 800 9000 9000 9000 1000 1000 1000Calcium, ppmMagnesium, ppmBF-7L Precipitate > > > > >BacteriaYesNoAerobic: No. per ml/time / / / / / / / / / / / / / / /Anaerobic: No. per ml/time///////////////Base Gel QualityUse additional copies of this form for each series of tests @ 24 hr. intervals & prior to pumping.Name of product system mixed#LINEAR GELGellant loading (lbs/1000 gal.) 6.25GPTFluid sampling location PILOTSampling time 5AMSample Temperature, (F) 60pH 73min.21Fann reading 9min.25@ 300 rpm 30min.2860min.30X-Link Vortex Closure, min:secX-Link Crown, min:secX-Link pHStageViscosity (cp)pHXL time @ blender, sec.Sample TemperatureTime fluid pumpedTested by: FOXDate Biocide Added: Date Biocide Added: Biocide added before H2O?Field Pilot Test Batch Mixed Gel Quality TestFrac Fluid Quality(These measurements are made as the job is pumped)TanksNote: Use additional copies of this report for testing additional material lots or tanks.This job will be:Gelled on-the-flyBatch MixedThis test data is considered to be a minimum standard. Additional testing or documentation may be required by the customer orfor frac quality assurance. Data recorded electronically with Engineering approved monitoring devices may besubstituted for applicable portions of this form. This testing data is considered to be the minimum needed for the well file.Date water sampled:Source of water:WATER BASED FRAC FLUID QUALITY CONTROL(Attachment to Treatment Report)12/22/2009 FIELD RECEIPT NO:SANDRIDGE LEASE NAME & WELL NO: WEST RANCH SOUTH 71-5Pump ScheduleCustomer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.1Formation: 1ST CABALLOSFluid Type: 25# LIN/30QSTAGEClean FoamBH SAND BH SANDBLENDER BLENDERPROP PROPSLURRYCLEANCO2N2CLEANSLURRYSLURRYCO2CO2 STAGEBHDESCRIPTIONVolumeCONC CONCCONC CONCTOTAL TOTALRATERATERATERATEVOLUMEVOLUME VOLUMETonsTons TIMEQUALITYGallonsBEGINENDBEGINENDstage cumbpmbpmbpmscfmbblsbbls cumstagecum minBD/FET100000.00 0.000.00 0.000 050.050.00.0 238.1238.1 238.10.00.0 0:04:460PAD250000.00 0.000.00 0.000 056.049.024.0 416.7416.7 654.831.731.7 0:07:2630.5# 100 MESH80000.50 0.500.71 0.714000 400056.547.923.4 133.3137.6 792.410.141.8 0:02:2630SWEEP150000.00 0.000.00 0.000 400056.049.024.0 250.0250.0 1042.419.060.9 0:04:2830.75# 100 MESH80000.75 0.751.07 1.076000 1000056.847.423.2 133.3139.8 1182.210.171.0 0:02:2830SWEEP150000.00 0.000.00 0.000 1000056.049.024.0 250.0250.0 1432.219.090.0 0:04:28301# 40/70 TLC80001.00 1.001.43 1.438000 1800057.146.922.9 133.3142.0 1574.210.1100.2 0:02:2930SWEEP150000.00 0.000.00 0.000 1800056.049.024.0250.0250.0 1824.219.0119.2 0:04:28301.25# 40/70 TLC80001.25 1.251.79 1.7910000 2800057.346.422.6133.3144.2 1968.410.1129.3 0:02:3130SWEEP150000.00 0.000.00 0.000 2800056.049.024.0250.0250.0 2218.419.0148.3 0:04:28301.5# 40/70 TLC80001.50 1.502.14 2.1412000 4000057.645.922.4133.3146.4 2364.810.1158.4 0:02:3230SWEEP150000.00 0.000.00 0.000 4000056.049.024.0250.0250.0 2614.819.0177.5 0:04:28301.5# 40/70 TLC80001.50 1.502.14 2.1412000 5200057.645.922.4133.3146.4 2761.110.1187.6 0:02:3230SWEEP150000.00 0.000.00 0.000 5200056.049.024.0250.0250.0 3011.119.0206.6 0:04:28301# 20/40 TLC100001.00 1.001.43 1.4310000 6200057.146.922.9166.7177.5 3188.712.6219.3 0:03:06302# 20/40 TLC100002.00 2.002.86 2.8620000 8200058.044.921.9166.7188.4 3377.112.6231.9 0:03:15303# 20/40 TLC80003.00 3.004.29 4.2924000 10600058.943.121.0133.3159.4 3536.410.1242.0 0:02:42304# 20/40 TLC60004.00 4.005.71 5.7124000 13000059.841.420.2100.0126.1 3662.57.6249.5 0:02:06304# 20/40 SLC35004.00 4.005.71 5.7114000 14400059.741.420.258.373.7 3736.24.4254.0 0:01:1430FLUSH134000.00 0.000.00 0.000 14400080.070.00.0319.0319.0 4055.20.0254.0 0:03:590DesignTotals -->22390014400003898.84055.2254.01:10:19ActualTotals -->Depths(ft)# of PerfsDisplacement (bbls)PumpViaPrepared By:SOTELOTopPerf8360100TubingCasingBottom Perf8630Casing319.85Blender Operator:BROWNN/AAnnulusFluid Technician:FOXO.D.(in.)Weight(lbs/ft)Bbls/ft I.D.(in.)Casing70.03826 6.276Flush (bbls)Hydration Operator:FOXTubingTop 319.9AnnulusBottom 330.226Superior Well ServicesAdditive ScheduleCustomer Name: SANDRIDGE12/22/2009Well Name: WEST RANCH 71-5 STG.1 Formation: 1ST CABALLOSAdditive: LSG-1(GEL)Planned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175006.25109.38 12.08 12.6013.1313.65 14.18109.380.7156006.2535.00 11.71 12.2112.7113.23 13.73144.380.00105006.2565.63 12.08 12.6013.1313.65 14.18210.001.0756006.2535.00 11.52 12.0212.5213.02 13.52245.000.00105006.2565.63 12.08 12.6013.1313.65 14.18310.631.4356006.2535.00 11.34 11.8412.3112.81 13.31345.630.00105006.2565.63 12.08 12.6013.1313.65 14.18411.251.7956006.2535.00 11.16 11.6612.1312.63 13.10446.250.00105006.2565.63 12.08 12.6013.1313.65 14.18511.882.1456006.2535.00 11.00 11.4711.9412.44 12.92546.880.00105006.2565.63 12.08 12.6013.1313.65 14.18612.502.1456006.2535.00 11.00 11.4711.9412.44 12.92647.500.00105006.2565.63 12.08 12.6013.1313.65 14.18713.131.4370006.2543.75 11.34 11.8412.3112.81 13.31756.882.8670006.2543.75 10.68 11.1611.6012.08 12.55800.634.2956006.2535.00 10.11 10.5510.9711.42 11.87835.635.7142006.2526.25 9.58 10.0010.4210.84 11.24861.885.7124506.2515.31 9.56 9.9810.4010.82 11.21877.190.00134000.000.00 #VALUE! #VALUE!#VALUE!#VALUE! #VALUE!877.19877.19Additive: ACTIVATORPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175000.000.00 0.00 0.000.000.00 0.000.000.7156000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.0756000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.4356000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.7956000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.002.1456000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.002.1456000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.4370000.000.00 0.00 0.000.000.00 0.000.002.8670000.000.00 0.00 0.000.000.00 0.000.004.2956000.000.00 0.00 0.000.000.00 0.000.005.7142000.000.00 0.00 0.000.000.00 0.000.005.7124505.0012.25 7.64 7.988.328.65 8.9712.250.00134000.000.00 #VALUE! #VALUE!#VALUE!#VALUE! #VALUE!12.2512.25Additive: SUPER NEPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100002.0020.00 3.86 4.034.204.37 4.5420.000.00175000.000.00 0.00 0.000.000.00 0.0020.000.7156002.0011.20 3.75 3.914.074.23 4.3931.200.00105002.0021.00 3.86 4.034.204.37 4.5452.201.0756002.0011.20 3.69 3.854.014.17 4.3363.400.00105002.0021.00 3.86 4.034.204.37 4.5484.401.4356002.0011.20 3.63 3.793.944.10 4.2695.600.00105002.0021.00 3.86 4.034.204.37 4.54116.601.7956002.0011.20 3.57 3.733.884.04 4.19127.800.00105002.0021.00 3.86 4.034.204.37 4.54148.802.1456002.0011.20 3.52 3.673.823.98 4.13160.000.00105002.0021.00 3.86 4.034.204.37 4.54181.002.1456002.0011.20 3.52 3.673.823.98 4.13192.200.00105002.0021.00 3.86 4.034.204.37 4.54213.201.4370002.0014.00 3.63 3.793.944.10 4.26227.202.8670002.0014.00 3.42 3.573.713.86 4.02241.204.2956002.0011.20 3.23 3.383.513.65 3.80252.405.7142002.008.40 3.07 3.203.333.47 3.60260.805.7124502.004.90 3.06 3.193.333.46 3.59265.700.00134002.0026.80 #VALUE! #VALUE!#VALUE!#VALUE! #VALUE!292.50292.50Fluid Technician:FOXField Receipt #:STG.1Prepared By:SOTELOCustomer Name: SANDRIDGE12/22/2009Superior Well ServicesAdditive ScheduleWell Name: WEST RANCH 71-5 STG.1Formation: 1ST CABALLOSAdditive: OB1/OB2Planned Additive Rates (PPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175000.254.38 0.48 0.500.530.55 0.574.380.7156000.251.40 0.47 0.490.510.53 0.555.780.00105000.252.63 0.48 0.500.530.55 0.578.401.0756000.251.40 0.46 0.480.500.52 0.549.800.00105000.252.63 0.48 0.500.530.55 0.5712.431.4356000.251.40 0.45 0.470.490.51 0.5313.830.00105000.252.63 0.48 0.500.530.55 0.5716.451.7956000.251.40 0.45 0.470.490.51 0.5217.850.00105000.252.63 0.48 0.500.530.55 0.5720.482.1456000.251.40 0.44 0.460.480.50 0.5221.880.00105000.252.63 0.48 0.500.530.55 0.5724.502.1456000.251.40 0.44 0.460.480.50 0.5225.900.00105000.252.63 0.48 0.500.530.55 0.5728.531.4370000.251.75 0.45 0.470.490.51 0.5330.282.8670000.251.75 0.43 0.450.460.48 0.5032.034.2956000.251.40 0.40 0.420.440.46 0.4733.435.7142000.251.05 0.38 0.400.420.43 0.4534.485.7124500.250.61 0.38 0.400.420.43 0.4535.090.00134000.000.00 #VALUE! #VALUE!#VALUE!#VALUE! #VALUE!35.09Additive: SUPER FOAMPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175002.0035.00 3.86 4.034.204.37 4.5435.000.7156002.0011.20 3.75 3.914.074.23 4.3946.200.00105002.0021.00 3.86 4.034.204.37 4.5467.201.0756002.0011.20 3.69 3.854.014.17 4.3378.400.00105002.0021.00 3.86 4.034.204.37 4.5499.401.4356002.0011.20 3.63 3.793.944.10 4.26110.600.00105002.0021.00 3.86 4.034.204.37 4.54131.601.7956002.0011.20 3.57 3.733.884.04 4.19142.800.00105002.0021.00 3.86 4.034.204.37 4.54163.802.1456002.0011.20 3.52 3.673.823.98 4.13175.000.00105002.0021.00 3.86 4.034.204.37 4.54196.002.1456002.0011.20 3.52 3.673.823.98 4.13207.200.00105002.0021.00 3.86 4.034.204.37 4.54228.201.4370002.0014.00 3.63 3.793.944.10 4.26242.202.8670002.0014.00 3.42 3.573.713.86 4.02256.204.2956002.0011.20 3.23 3.383.513.65 3.80267.405.7142002.008.40 3.07 3.203.333.47 3.60275.805.7124502.004.90 3.06 3.193.333.46 3.59280.700.00134000.000.00 #VALUE! #VALUE!#VALUE!#VALUE! #VALUE!280.70Additive:Planned Additive Rates ()PPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONEFluid Technician:FOXField Receipt #:STG.1Prepared By:SOTELOStep Down Diagnostic - Surface0102030405060Rate (bpm)020040060080010001200140016001800 Pressure Loss (psi)DP NW Data Points (psi)DP NW: Alpha = 0.880444DP Total NW Data Points (psi)DP Total NW (psi)DP Perf Ideal (psi)Number of perfs = 18Discharge Coeff. = 0.5Perf diameter = 0.48 (in.)MinFrac - 12/22/2009

## December 23, 2009 POST TREATMENT REPORT Sand Ridge Energy West Ranch South 71-5 Stg.2 Pecos County, Tx. Treatment Date: December 23, 2009

Attn: West Ranch South 71-5 Stg.2

The stimulation of the West Ranch South 71-5 stg. #2 well consisted of 4,240 bbls of 25#/30Q Linear Gel fluid and 259 tons of CO2. Th is fluid was laden with 10,334 lbs of 100 mesh sand in a .5, .75 lb hold, also 41,795 lbs of 40/70 TLC sand in a 1, 1.25, 1.5 lb hold, also 38.220 lbs of 20/40 TLC sand in a 1-4 lb hold, and 11,401 lbs of 20/40 SLC sand in a 4 lb hold. It was pumped at an average rate of 65.4 bpm, and an average surface pressure of 5,078 psi. The ISIP was 4,478 psi and the approximate load to recove r is 4,131 bbls. Please find the attached Meyers charts recorded during the job for stg. #2.

Superior Well Services appreciates the opportunity to perform pumping services for you in a cost-effective manner that focuses on quality and safety.

Please contact the Midland Engineering Department if you have any questions,

Thank you, Ricky Herrera Field Service Tech Midland, TX (432) 813-6420Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATE

Superior Rep. Customer Rep. Stage #

Co2 Rate CO2 Total Total Rate

BPM BBLS BPM

19 30 63 20 39 64 19 58 64 19 70 65 20 87 66 20 98 66 20 116 66 19 128 65 19 146 65 19 157 65 18 174 64 19 190 65 Stimulation Treatment Report

55-000296 12/23/09

West Ranch 71-5 Pecos Sandridge Energy

TX

Cesar Pando 2

Job Descript ion / Remarks

Arrived on location waiting on Blender to arrive ANNULUS BPM BBLS BBLS 11:00am

Time Pressures (psi) Rate Stage Total

STP

12:54pm 1:20pm Prime/Test lines Well Data 2:40pm Safety Meeting 2:00pm Rigged up Blende r

Tubing Depth N/A 3:23pm 2959 27 44 373 821 Pad Packer Depth Open Wellhead Tubing Type N/A 2:56pm 2650 27 54 448 Pad / Fet 2:55pm 2600 27

sweep Casing Depth 8255 ft 3:45pm 5078 27 46 158 1,339 .75 ppg 100 mesh 3:40pm 5151 27 45 250 1,181 N/A 3:37pm 5204 27 44 110 931 .5 ppg 100 mesh Casing Type 7.0 11.6 lb

new 3:54pm 5094 27 46 145 1,723 1.0 ppg 40/70 TLC Formation Caballos 3:49pm 5008 27 46 239 1,578 sweep Well Type

sweep Tubing Cap. 34 bbls 4:11pm 5046 27 46 157 2,526 1.5 ppg 40/70 TLC 4:05pm 4964 27 46 248 2,369 Casing Cap. 317 bbls sweep Treatment Fluid and Capacities in BBLS 4:02pm 5155 27 46 162 2,121 1.25 ppg 40/70 TLC 3:57pm 5000 27 46 236 1,959

N/A 4 19 5135 27 46 221 2 986 1 5 40/70 TLC 4:14pm 4963 27 46 239 2,765 sweep Fluid To Load Page 1

19 190 65 18 209 64 18 219 64 17 235 63 18 240 64 18 245 65 18 252 66 60 3,707 2.0 ppg 20/40 TLC Fluid To Recover 4:19pm 5135 27 46 221 2,986 1.5 ppg 40/70 TLC Pad Volume 2541 bbls

3,841 sweep Treating Fluid 1389 bbls 8:50pm 5166 27 46 96 3,590 1.0 ppg 20/40 TLC 4:23pm 4930 27 46 508 3,494
Flush 317 bbls 8:54pm 5188 27 46 117 8:56pm 5146 27 46 68 3,775 3.0 ppg 20/40 TLC

Linear Gel # 25 146,244 gals Volume Pumped (Gals) 4.0 ppg 20/40 TLC Treatment Data 8:59pm 5085 27 48 89 3,930 4.0 ppg 20/40 SLC 8:58pm 5127 27 47 66

Flush Fluid Description 9:01pm 5126 27 60 317 4,247

32,130 gals Base Fluid

Waited for Blender to arrive from ( Comments )

due to Blender Augers. Proppant Description Volume Pumped (lbs) Blender densometer did not work 100 mesh Odessa T X Treatment Data Had to Shutdown during stage

20/40 TLC 40/70 TLC

Treatment Data 20/40 SLC

Maximum 5204 Maximum 60 5 Min. SuperNE-1 Treating Presure Injection Rates Shut In Pressures Materials
Minimum 2600 Minimum 44 ISDP 4478 psi LSG SuperFoam

SuperSet Act

Operators Max Pressure 5,500 psi 15 Min. Gel Average 4751 Average 47 10 Min.

OB-2 Final OB-1DENSITY PLOTS020406080100120140160180200220240260280300320340360380TIME (min)01234567 BLENDER DENSITY (lb/gal)01234567 INLINE DENSITY (lb/gal)Real-Time BLENDER DENSITY (lb/gal)Real-Time INLINE DENSITY (lb/gal)MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009BLENDER CHEMICALS020406080100120140160180200220240260280300320340360380TIME (min)012345 SUPER FOAM GPT (gal/1000 gal)0012243648510Real-Time SUPER FOAM GPT (gal/1000 gal)Real-Time OB1/OB2 PPT (lb/gal)Real-Time ACTIVATOR GPT (gal/1000gaMView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009WEST RANCH SOUTH 71-5 STG.2020406080100120140160180200220240260280300320340360380TIME (min)001000520001030001540002050002560003070003580004090004510000500102030405060708090100Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)Real-Time FOAM RATE (bpm)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009HYDRATION CHEMICALS020406080100120140160180200220240260280300320340360380TIME (min)02468101214161820 LSG GPT (gal/1000 gal)012345678910 SUPER NE 100 GPT (gal/1000 gal)Real-Time LSG GPT (gal/1000 gal)Real-Time SUPER NE 100 GPT (gal/1000MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009BOTTOM HOLE QUALITY PLOT020406080100120140160180200220240260280300320340360380TIME (min)0051010201530204025503060357040804590501000102030405060708090100Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009Net Pressure vs Time1101001000Time (min)10100100010000 Net Pressure (psi)0.010.1110 Concentration (lbm/gal)Measured Net Pressure (psi)BH Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009BHTP & SP WEST RANCH SOUTH 71-5 STG.2020406080100120140160180200220240260280300320340360380Time (min)010002000300040005000600070008000900010000 Pressure (psi)00.0102.5205.0307.54010.05012.56015.07017.58020.09022.510025.0 Rate & ConcentrationMeasured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)Measured Surface Slurry Rate (bpm)BH Conc. (lbm/gal)Measured Surface Slurry Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009Step Down Diagnostic - Surface0102030405060Rate (bpm)0100200300400500600700800 Pressure Loss (psi)DP NW Data Points (psi)DP NW: Alpha = 0.500586DP Total NW Data Points (psi)DP Total NW (psi)DP Perf Ideal (psi)Number of perfs = 27Discharge Coeff. = 0.5Perf diameter = 0.48 (in.)MinFrac - 12/23/2009Pump ScheduleCustomer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.2Formation: 1ST CABALLOSFluid Type: 25# LIN/30QSTAGEClean FoamBH SAND BH SANDBLENDER BLENDERPROP PROPSLURRYCLEANCO2N2CLEANSLURRYSLURRYCO2CO2 STAGEBHDESCRIPTIONVolumeCONC CONCCONC CONCTOTAL TOTALRATERATERATERATEVOLUMEVOLUME VOLUMETonsTons TIMEQUALITYGallonsBEGINENDBEGINENDstage cumbpmbpmbpmscfmbblsbbls cumstagecum minBD/FET100000.00 0.000.00 0.000 050.050.00.0 238.1238.1 238.10.00.0 0:04:460PAD200000.00 0.000.00 0.000 045.545.520.0 333.3333.3 571.426.026.0 0:07:1930.5# 100 MESH80000.50 0.500.71 0.714000 400045.944.520.0 133.3137.6 709.110.736.7 0:03:0030SWEEP150000.00 0.000.00 0.000 400045.545.520.0 250.0250.0 959.119.556.2 0:05:2930.75# 100 MESH80000.75 0.751.07 1.076000 1000046.144.020.0 133.3139.8 1098.910.867.0 0:03:0230SWEEP150000.00 0.000.00 0.000 1000045.545.520.0 250.0250.0 1348.919.586.5 0:05:29301# 40/70 TLC80001.00 1.001.43 1.438000 1800046.343.519.0 133.3142.0 1490.910.396.8 0:03:0430SWEEP150000.00 0.000.00 0.000 1800045.545.520.0250.0250.0 1740.919.5116.3 0:05:29301.25# 40/70 TLC80001.25 1.251.79 1.7910000 2800046.543.019.0133.3144.2 1885.110.5126.8 0:03:0630SWEEP150000.00 0.000.00 0.000 2800045.545.520.0250.0250.0 2135.119.5146.3 0:05:29301.5# 40/70 TLC80001.50 1.502.14 2.1412000 4000046.742.619.0133.3146.4 2281.510.6156.9 0:03:0830SWEEP150000.00 0.000.00 0.000 4000045.545.520.0250.0250.0 2531.519.5176.4 0:05:29301.5# 40/70 TLC80001.50 1.502.14 2.1412000 5200046.742.619.0133.3146.4 2677.810.6187.0 0:03:0830SWEEP150000.00 0.000.00 0.000 5200045.545.520.0250.0250.0 2927.819.5206.5 0:05:29301# 20/40 TLC35001.00 1.001.43 1.433500 5550046.343.519.058.362.1 2989.94.5211.0 0:01:20302# 20/40 TLC35002.00 2.002.86 2.867000 6250047.141.719.058.365.9 3055.94.7215.7 0:01:24303# 20/40 TLC25003.00 3.004.29 4.297500 7000047.840.018.041.749.8 3105.73.3219.1 0:01:02304# 20/40 TLC25004.00 4.005.71 5.7110000 8000048.538.517.041.752.5 3158.23.3222.3 0:01:05304# 20/40 SLC25004.00 4.005.71 5.7110000 9000048.538.417.041.752.6 3210.93.3225.6 0:01:0530FLUSH132300.00 0.000.00 0.000 9000050.065.00.0315.0315.0 3525.90.0225.6 0:06:180DesignTotals -->1957309000003428.13525.9225.61:15:43ActualTotals -->Depths(ft)# of PerfsDisplacement (bbls)PumpViaPrepared By:SOTELOTopPerf825545TubingCasingBottom Perf8270Casing315.84Blender Operator:BROWNN/AAnnulusFluid Technician:FOXO.D.(in.)Weight(lbs/ft)Bbls/ft I.D.(in.)Casing70.03826 6.276Flush (bbls)Hydration Operator:FOXTubingTop 315.8AnnulusBottom 316.426Superior Well ServicesAdditive ScheduleCustomer Name: SANDRIDGE12/22/2009Well Name: WEST RANCH 71-5 STG.2 Formation: 1ST CABALLOSAdditive: LSG-1(GEL)Planned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140006.2587.50 12.08 12.6013.1313.65 14.1887.500.7156006.2535.00 11.71 12.2112.7113.23 13.73122.500.00105006.2565.63 12.08 12.6013.1313.65 14.18188.131.0756006.2535.00 11.52 12.0212.5213.02 13.52223.130.00105006.2565.63 12.08 12.6013.1313.65 14.18288.751.4356006.2535.00 11.34 11.8412.3112.81 13.31323.750.00105006.2565.63 12.08 12.6013.1313.65 14.18389.381.7956006.2535.00 11.16 11.6612.1312.63 13.10424.380.00105006.2565.63 12.08 12.6013.1313.65 14.18490.002.1456006.2535.00 11.00 11.4711.9412.44 12.92525.000.00105006.2565.63 12.08 12.6013.1313.65 14.18590.632.1456006.2535.00 11.00 11.4711.9412.44 12.92625.630.00105006.2565.63 12.08 12.6013.1313.65 14.18691.251.4324506.2515.31 11.34 11.8412.3112.8113.31706.562.8624506.2515.31 10.68 11.1611.6012.08 12.55721.884.2917506.2510.94 10.11 10.5510.9711.42 11.87732.815.7117506.2510.94 9.58 10.0010.4210.84 11.24743.755.7117506.2510.94 9.56 9.9810.4010.82 11.21754.690.00132300.000.00 0.00 0.000.000.00 0.00754.69754.69Additive: ACTIVATORPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140000.000.00 0.00 0.000.000.00 0.000.000.7156000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.0756000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.4356000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.7956000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.002.1456000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.002.1456000.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.4324500.000.00 0.00 0.000.000.000.000.002.8624500.000.00 0.00 0.000.000.00 0.000.004.2917500.000.00 0.00 0.000.000.00 0.000.005.7117500.000.00 0.00 0.000.000.00 0.000.005.7117505.008.75 7.64 7.988.328.65 8.978.750.00132300.000.00 0.00 0.000.000.00 0.008.758.75Additive: SUPER NEPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100002.0020.00 3.86 4.034.204.37 4.5420.000.00140002.0028.00 3.86 4.034.204.37 4.5448.000.7156002.0011.20 3.75 3.914.074.23 4.3959.200.00105002.0021.00 3.86 4.034.204.37 4.5480.201.0756002.0011.20 3.69 3.854.014.17 4.3391.400.00105002.0021.00 3.86 4.034.204.37 4.54112.401.4356002.0011.20 3.63 3.793.944.10 4.26123.600.00105002.0021.00 3.86 4.034.204.37 4.54144.601.7956002.0011.20 3.57 3.733.884.04 4.19155.800.00105002.0021.00 3.86 4.034.204.37 4.54176.802.1456002.0011.20 3.52 3.673.823.98 4.13188.000.00105002.0021.00 3.86 4.034.204.37 4.54209.002.1456002.0011.20 3.52 3.673.823.98 4.13220.200.00105002.0021.00 3.86 4.034.204.37 4.54241.201.4324502.004.90 3.63 3.793.944.104.26246.102.8624502.004.90 3.42 3.573.713.86 4.02251.004.2917502.003.50 3.23 3.383.513.65 3.80254.505.7117502.003.50 3.07 3.203.333.47 3.60258.005.7117502.003.50 3.06 3.193.333.46 3.59261.500.00132302.0026.46 3.86 4.034.204.37 4.54287.96287.96Fluid Technician:FOXField Receipt #:STG.2Prepared By:SOTELOCustomer Name: SANDRIDGE12/22/2009Superior Well ServicesAdditive ScheduleWell Name: WEST RANCH 71-5 STG.2Formation: 1ST CABALLOSAdditive: OB1/OB2Planned Additive Rates (PPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140000.507.00 0.97 1.011.051.09 1.137.000.7156000.502.80 0.94 0.981.021.06 1.109.800.00105000.505.25 0.97 1.011.051.09 1.1315.051.0756000.502.80 0.92 0.961.001.04 1.0817.850.00105000.505.25 0.97 1.011.051.09 1.1323.101.4356000.502.80 0.91 0.950.981.02 1.0625.900.00105000.505.25 0.97 1.011.051.09 1.1331.151.7956000.754.20 1.34 1.401.461.52 1.5735.350.00105000.757.88 1.45 1.511.581.64 1.7043.232.1456000.754.20 1.32 1.381.431.49 1.5547.430.00105000.757.88 1.45 1.511.581.64 1.7055.302.1456000.754.20 1.32 1.381.431.49 1.5559.500.00105000.757.88 1.45 1.511.581.64 1.7067.381.4324500.751.84 1.36 1.421.481.541.6069.212.8624501.253.06 2.14 2.232.322.42 2.5172.284.2917501.252.19 2.02 2.112.192.28 2.3774.465.7117501.252.19 1.92 2.002.082.17 2.2576.655.7117501.252.19 1.91 2.002.082.16 2.2478.840.00132300.000.00 0.00 0.000.000.00 0.0078.84Additive: SUPER FOAMPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140002.0028.00 3.86 4.034.204.37 4.5428.000.7156002.0011.20 3.75 3.914.074.23 4.3939.200.00105002.0021.00 3.86 4.034.204.37 4.5460.201.0756002.0011.20 3.69 3.854.014.17 4.3371.400.00105002.0021.00 3.86 4.034.204.37 4.5492.401.4356002.0011.20 3.63 3.793.944.10 4.26103.600.00105002.0021.00 3.86 4.034.204.37 4.54124.601.7956002.0011.20 3.57 3.733.884.04 4.19135.800.00105002.0021.00 3.86 4.034.204.37 4.54156.802.1456002.0011.20 3.52 3.673.823.98 4.13168.000.00105002.0021.00 3.86 4.034.204.37 4.54189.002.1456002.0011.20 3.52 3.673.823.98 4.13200.200.00105002.0021.00 3.86 4.034.204.37 4.54221.201.4324502.004.90 3.63 3.793.944.104.26226.102.8624502.004.90 3.42 3.573.713.86 4.02231.004.2917502.003.50 3.23 3.383.513.65 3.80234.505.7117502.003.50 3.07 3.203.333.47 3.60238.005.7117502.003.50 3.06 3.193.333.46 3.59241.500.00132300.000.00 0.00 0.000.000.00 0.00241.50Additive:Planned Additive Rates ()PPGVOLUME LOAD AMOUNT 46 BPM 48 BPM50 BPM52 BPM 54 BPM ActualGONEFluid Technician:FOXField Receipt #:STG.2Prepared By:SOTELOCUSTOMERWELL NAMEDATEFIELD RECIEPT #FLUID TECHSANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th stge 12th stge Total BBLSWater bbls. Per stges.>>0SYSTEM:Chemicals BEG. ENDINGTotal UsedLSG-1 3054 2176 878878OB/OB-2 460 380 8080ACTIVATOR 179 150 2929SUPER FOAM 1006 738 268268SUPER 100 NE 1446 1155 291291#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!000000000Comments :

## December 24, 2009 POST TREATMENT REPORT Sand Ridge Energy West Ranch South 71-5 Stg.3 Pecos County, Tx. Treatment Date: December 24, 2009

Attn: West Ranch South 71-5 Stg.3

The stimulation of the West Ranch South 71-5 stg. #3 well consisted of 3,899 bbls of 25#/30Q Linear Gel fluid and 232 tons of CO2. Th is fluid was laden with 10,005 lbs of 100 mesh sand in a .5, .75 lb hold, also 44,088 lbs of 40/70 TLC sand in a 1, 1.25, 1.5 lb hold, also 67,907 lbs of 20/40 TLC sand in a 1-4 lb hold, and 13,455 lbs of 20/40 SLC sand in a 4 lb hold. It was pumped at an average rate of 79.5 bpm, and an average surface pressure of 3,788 psi. The ISIP was 3,004 psi and the approximate load to recove r is 3,742 bbls. Please find the attached Meyers charts recorded during the job for stg. #3.

Superior Well Services appreciates the opportunity to perform pumping services for you in a cost-effective manner that focuses on quality and safety.

Please contact the Midland Engineering Department if you have any questions,

Thank you, Ricky Herrera Field Service Tech Midland, TX (432) 813-6420Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATE

Superior Rep. Customer Rep. Stage #

Co2 Rate CO2 Total Total Rate

BPM BBLS BPM

25 30 81 25 42 81 24 92 79 24 106 79 24 113 79 23 122 78 23 130 78 23 140 78 23 147 78 23 159 78 23 165 78 23 177 79 23 183 79 23 195 79 23 208 79 23 220 79 24 228 82 23 236 82 Page 1

N/A

6 52 3708 30 59 98 3 499 4 0 20/40 SLC 6:49am 3792 30 58 112 3,401 4.0 ppg 20/40 TLC Fluid To Load sweep Treatment Fluid and Capacities in BBLS 6:42am 3860 30 56 154 2,952 1.0 ppg 20/40 TLC 6:39am 3832 30 56 87 2,798

2.0 ppg 20/40 TLC Tubing Cap. N/A 6:46am 3919 30 56 161 3,289 3.0 ppg 20/40 TLC 6:43am 3908 30 56 176 3,128 Casing Cap. 304 bbls new 6:37am 3804 30 56 156 2,711 1.5 ppg 40/70 TLC Formation Caballos 6:34am 3779 30 55 89 2,555 sweep Well Type N/A 6:29am 3746 30 55 140 2,224 1.25 ppg 40/70 TLC Casing Type 7.0 11.6 lb Casing Depth 8140 ft 6:33am 3767 30 55 151 2,466 1.5 ppg 40/70 TLC 6:30am 3755 30 55 91 2,315 1,991 1.0 ppg 40/70 TLC 6:21am 3782 30 55 90 1,869

sweep 3812 30 56 149 960 .5 ppg 100 mesh

Tubing Depth N/A 6:26am 3757 30 55 93 2,084 sweep Packer Depth sweep Tubing Type N/A 6:25am 3728 30 55 122 sweep Well Data 6:05am 3614 30 55 187 1,779 .75 ppg 100 mesh 6:02am 3566 30 55 632 1,592 ANNULUS BPM BBLS BBLS 5:24am 1006 30 455

Time Pressures (psi) Rate Stage Total

STP

5:25am 1050 30 56 356 811 5:56am Stimulation Treatment Report

55-000296 12/24/09

West Ranch 71-5 Pecos Sandridge Energy

TX

Cesar Pando 3

Job Descript ion / Remarks

Pad / Fet

Pad

23 236 82

Final OB-1 SuperSet Act

Operators Max Pressure 5,500 psi 15 Min. Gel Average 3771 Average 56 10 Min.

OB-2 Treating Presure Injection Rates Shut In Pressures Materials
Minimum 1006 Minimum 55 ISDP 3004 psi LSG SuperFoam
Maximum 3919 Maximum 64 5 Min. SuperNE-1 20/40 SLC

Treatment Data 20/40 TLC 40/70 TLC had to shut down. Treatment Data
Proppant Description Volume Pumped (lbs) 100 mesh Blender densometer did not work ( Comments ) 31,836 gals Base Fluid Fluid Description Linear Gel # 25 127,848 gals Volume Pumped (Gals) Treatment Data Flush Treating Fluid 1606 bbls 6:54am 3757 30 64 303 3,802
Flush 303 bbls Fluid To Recover 3742 bbls 6:52am 3708 30 59 98 3,499 4.0 ppg 20/40 SLC Pad Volume 1893 bblsBLENDER CHEMICALS30405060708090100TIME (min)012345 SUPER FOAM GPT (gal/1000 gal)0012243648510Real-Time SUPER FOAM GPT (gal/1000 gal)Real-Time OB1/OB2 PPT (lb/gal)Real-Time ACTIVATOR GPT (gal/1000gaMView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009HYDRATION CHEMICALS0102030405060708090100TIME (min)02468101214161820 LSG GPT (gal/1000 gal)012345678910 SUPER NE 100 GPT (gal/1000 gal)Real-Time LSG GPT (gal/1000 gal)Real-Time SUPER NE 100 GPT (gal/1000MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009DENSITY PLOTS5060708090100TIME (min)01234567 BLENDER DENSITY (lb/gal)01234567 INLINE DENSITY (lb/gal)Real-Time BLENDER DENSITY (lb/gal)Real-Time INLINE DENSITY (lb/gal)MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009BOTTOM HOLE QUALITY PLOT0102030405060708090100TIME (min)0051010201530204025503060357040804590501000102030405060708090100Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009WEST RANCH SOUTH 71-5 STG.30102030405060708090100TIME (min)001000520001030001540002050002560003070003580004090004510000500102030405060708090100Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)Real-Time FOAM RATE (bpm)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009Net Pressure vs Time0.1110100Time (min)100100010000 Net Pressure (psi)0.1110 Concentration (lbm/gal)Measured Net Pressure (psi)BH Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009BHTP & SP WEST RANCH SOUTH 71-5 STG.30102030405060708090100Time (min)010002000300040005000600070008000900010000 Pressure (psi)00.0102.5205.0307.54010.05012.56015.07017.58020.09022.510025.0 Rate & ConcentrationMeasured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)Measured Surface Slurry Rate (bpm)BH Conc. (lbm/gal)Measured Surface Slurry Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009CUSTOMERWELL NAMEDATEFIELD RECIEPT #FLUID TECHSANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th stge 12th stge Total BBLSWater bbls. Per stges.>>0SYSTEM:Chemicals BEG. ENDINGTotal UsedLSG-1 2176 1365 811811OB/OB-2 380 291 8989ACTIVATOR 150 128 2222SUPER FOAM 738 425 313313SUPER 100 NE 1155 798 357357#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!000000000Comments :Step Down Diagnostic - Surface0102030405060Rate (bpm)04080120160200240 Pressure Loss (psi)DP NW Data Points (psi)DP NW: Alpha = 0.579505DP Total NW Data Points (psi)DP Total NW (psi)DP Perf Ideal (psi)Number of perfs = 56Discharge Coeff. = 0.5Perf diameter = 0.48 (in.)MinFrac - 12/24/2009Pump ScheduleCustomer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.3Formation: 1ST CABALLOSFluid Type: 25# LIN/30QSTAGEClean FoamBH SAND BH SANDBLENDER BLENDERPROP PROPSLURRYCLEANCO2N2CLEANSLURRYSLURRYCO2CO2 STAGEBHDESCRIPTIONVolumeCONC CONCCONC CONCTOTAL TOTALRATERATERATERATEVOLUMEVOLUME VOLUMETonsTons TIMEQUALITYGallonsBEGINENDBEGINENDstage cumbpmbpmbpmscfmbblsbbls cumstagecum minBD/FET100000.00 0.000.00 0.000 050.050.00.0 238.1238.1 238.10.00.0 0:04:460PAD250000.00 0.000.00 0.000 056.056.025.0 416.7416.7 654.833.033.0 0:07:2630.5# 100 MESH80000.50 0.500.71 0.714000 400056.554.824.0 133.3137.6 792.410.443.4 0:02:2630SWEEP125000.00 0.000.00 0.000 400056.056.025.0 208.3208.3 1000.716.559.9 0:03:4330.75# 100 MESH80000.75 0.751.07 1.076000 1000056.854.224.0 133.3139.8 1140.510.570.4 0:02:2830SWEEP125000.00 0.000.00 0.000 1000056.056.025.0 208.3208.3 1348.916.587.0 0:03:43301# 40/70 TLC80001.00 1.001.43 1.438000 1800057.053.624.0 133.3142.0 1490.910.697.6 0:02:2930SWEEP125000.00 0.000.00 0.000 1800056.056.025.0208.3208.3 1699.216.5114.1 0:03:43301.25# 40/70 TLC80001.25 1.251.79 1.7910000 2800057.353.023.0133.3144.2 1843.410.3124.4 0:02:3130SWEEP125000.00 0.000.00 0.000 2800056.056.025.0208.3208.3 2051.816.5140.9 0:03:43301.5# 40/70 TLC80001.50 1.502.14 2.1412000 4000057.552.423.0133.3146.4 2198.110.4151.3 0:02:3330SWEEP125000.00 0.000.00 0.000 4000056.056.025.0208.3208.3 2406.516.5167.8 0:03:43301.5# 40/70 TLC80001.50 1.502.14 2.1412000 5200057.552.423.0133.3146.4 2552.810.4178.2 0:02:3330SWEEP125000.00 0.000.00 0.000 5200056.056.025.0208.3208.3 2761.116.5194.7 0:03:43301# 20/40 TLC100001.00 1.001.43 1.4310000 6200057.053.624.0166.7177.5 2938.713.3208.0 0:03:07302# 20/40 TLC85002.00 2.002.86 2.8617000 7900058.051.323.0141.7160.1 3098.811.3219.3 0:02:46303# 20/40 TLC75003.00 3.004.29 4.2922500 10150058.949.322.0125.0149.4 3248.29.9229.2 0:02:32304# 20/40 TLC45004.00 4.005.71 5.7118000 11950059.747.421.075.094.5 3342.85.9235.1 0:01:35304# 20/40 SLC30004.00 4.005.71 5.7112000 13150059.747.321.050.063.2 3405.93.9239.1 0:01:0330FLUSH127750.00 0.000.00 0.000 13150050.080.00.0304.2304.2 3710.10.0239.1 0:06:050DesignTotals -->20427513150003567.33710.1239.11:06:37ActualTotals -->Depths(ft)# of PerfsDisplacement (bbls)PumpViaPrepared By:SOTELOTopPerf791090TubingCasingBottom Perf8140Casing302.64Blender Operator:BROWNN/AAnnulusFluid Technician:FOXO.D.(in.)Weight(lbs/ft)Bbls/ft I.D.(in.)Casing70.03826 6.276Flush (bbls)Hydration Operator:HERBIETubingTop 302.6AnnulusBottom 311.426Superior Well ServicesAdditive ScheduleCustomer Name: SANDRIDGE12/24/2009Well Name: WEST RANCH 71-5 STG.3 Formation: 1ST CABALLOSAdditive: LSG-1(GEL)Planned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175006.25109.38 13.39 13.9114.4414.96 15.49109.380.7156006.2535.00 12.97 13.4713.9914.49 15.02144.380.0087506.2554.69 13.39 13.9114.4414.96 15.49199.061.0756006.2535.00 12.76 13.2613.7814.28 14.78234.060.0087506.2554.69 13.39 13.9114.4414.96 15.49288.751.4356006.2535.00 12.57 13.0713.5514.04 14.54323.750.0087506.2554.69 13.39 13.9114.4414.96 15.49378.441.7956006.2535.00 12.39 12.8613.3613.83 14.33413.440.0087506.2554.69 13.39 13.9114.4414.96 15.49468.132.1456006.2535.00 12.21 12.6813.1513.62 14.10503.130.0087506.2554.69 13.39 13.9114.4414.96 15.49557.812.1456006.2535.00 12.21 12.6813.1513.62 14.10592.810.0087506.2554.69 13.39 13.9114.4414.96 15.49647.501.4370006.2543.75 12.57 13.0713.5514.0414.54691.252.8659506.2537.19 11.84 12.3112.7813.23 13.70728.444.2952506.2532.81 11.21 11.6312.0812.52 12.97761.255.7131506.2519.69 10.63 11.0311.4511.87 12.29780.945.7121006.2513.13 10.61 11.0011.4211.84 12.26794.060.00127750.000.00 0.00 0.000.000.00 0.00794.06794.06Additive: ACTIVATORPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175000.000.00 0.00 0.000.000.00 0.000.000.7156000.000.00 0.00 0.000.000.00 0.000.000.0087500.000.00 0.00 0.000.000.00 0.000.001.0756000.000.00 0.00 0.000.000.00 0.000.000.0087500.000.00 0.00 0.000.000.00 0.000.001.4356000.000.00 0.00 0.000.000.00 0.000.000.0087500.000.00 0.00 0.000.000.00 0.000.001.7956000.000.00 0.00 0.000.000.00 0.000.000.0087500.000.00 0.00 0.000.000.00 0.000.002.1456000.000.00 0.00 0.000.000.00 0.000.000.0087500.000.00 0.00 0.000.000.00 0.000.002.1456000.000.00 0.00 0.000.000.00 0.000.000.0087500.000.00 0.00 0.000.000.00 0.000.001.4370000.000.00 0.00 0.000.000.000.000.002.8659500.000.00 0.00 0.000.000.00 0.000.004.2952500.000.00 0.00 0.000.000.00 0.000.005.7131500.000.00 0.00 0.000.000.00 0.000.005.7121005.0010.50 8.48 8.809.149.47 9.8110.500.00127750.000.00 0.00 0.000.000.00 0.0010.5010.50Additive: SUPER NEPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100002.0020.00 4.28 4.454.624.79 4.9620.000.00175002.0035.00 4.28 4.454.624.79 4.9655.000.7156002.0011.20 4.15 4.314.484.64 4.8066.200.0087502.0017.50 4.28 4.454.624.79 4.9683.701.0756002.0011.20 4.08 4.244.414.57 4.7394.900.0087502.0017.50 4.28 4.454.624.79 4.96112.401.4356002.0011.20 4.02 4.184.334.49 4.65123.600.0087502.0017.50 4.28 4.454.624.79 4.96141.101.7956002.0011.20 3.96 4.124.284.43 4.59152.300.0087502.0017.50 4.28 4.454.624.79 4.96169.802.1456002.0011.20 3.91 4.064.214.36 4.51181.000.0087502.0017.50 4.28 4.454.624.79 4.96198.502.1456002.0011.20 3.91 4.064.214.36 4.51209.700.0087502.0017.50 4.28 4.454.624.79 4.96227.201.4370002.0014.00 4.02 4.184.334.494.65241.202.8659502.0011.90 3.79 3.944.094.23 4.38253.104.2952502.0010.50 3.59 3.723.864.01 4.15263.605.7131502.006.30 3.40 3.533.663.80 3.93269.905.7121002.004.20 3.39 3.523.653.79 3.92274.100.00127752.0025.55 4.28 4.454.624.79 4.96299.65299.65Fluid Technician:FOXField Receipt #:STG.3Prepared By:SOTELOCustomer Name: SANDRIDGE12/24/2009Superior Well ServicesAdditive ScheduleWell Name: WEST RANCH 71-5 STG.3Formation: 1ST CABALLOSAdditive: OB1/OB2Planned Additive Rates (PPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175000.508.75 1.07 1.111.161.20 1.248.750.7156000.502.80 1.04 1.081.121.16 1.2011.550.0087500.504.38 1.07 1.111.161.20 1.2415.931.0756000.502.80 1.02 1.061.101.14 1.1818.730.0087500.504.38 1.07 1.111.161.20 1.2423.101.4356000.502.80 1.01 1.051.081.12 1.1625.900.0087500.504.38 1.07 1.111.161.20 1.2430.281.7956000.754.20 1.49 1.541.601.66 1.7234.480.0087500.756.56 1.61 1.671.731.80 1.8641.042.1456000.754.20 1.46 1.521.581.63 1.6945.240.0087500.756.56 1.61 1.671.731.80 1.8651.802.1456000.754.20 1.46 1.521.581.63 1.6956.000.0087500.756.56 1.61 1.671.731.80 1.8662.561.4370000.755.25 1.51 1.571.631.691.7567.812.8659501.257.44 2.37 2.462.562.65 2.7475.254.2952501.256.56 2.24 2.332.422.50 2.5981.815.7131501.253.94 2.13 2.212.292.37 2.4685.755.7121001.252.63 2.12 2.202.282.37 2.4588.380.00127750.000.00 0.00 0.000.000.00 0.0088.38Additive: SUPER FOAMPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00175002.0035.00 4.28 4.454.624.79 4.9635.000.7156002.0011.20 4.15 4.314.484.64 4.8046.200.0087502.0017.50 4.28 4.454.624.79 4.9663.701.0756002.0011.20 4.08 4.244.414.57 4.7374.900.0087502.0017.50 4.28 4.454.624.79 4.9692.401.4356002.0011.20 4.02 4.184.334.49 4.65103.600.0087502.0017.50 4.28 4.454.624.79 4.96121.101.7956002.0011.20 3.96 4.124.284.43 4.59132.300.0087502.0017.50 4.28 4.454.624.79 4.96149.802.1456002.0011.20 3.91 4.064.214.36 4.51161.000.0087502.0017.50 4.28 4.454.624.79 4.96178.502.1456002.0011.20 3.91 4.064.214.36 4.51189.700.0087502.0017.50 4.28 4.454.624.79 4.96207.201.4370002.0014.00 4.02 4.184.334.494.65221.202.8659502.0011.90 3.79 3.944.094.23 4.38233.104.2952502.0010.50 3.59 3.723.864.01 4.15243.605.7131502.006.30 3.40 3.533.663.80 3.93249.905.7121002.004.20 3.39 3.523.653.79 3.92254.100.00127750.000.00 0.00 0.000.000.00 0.00254.10Additive:Planned Additive Rates ()PPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONEFluid Technician:FOXField Receipt #:STG.3Prepared By:SOTELO

## December 24, 2009 POST TREATMENT REPORT Sand Ridge Energy West Ranch South 71-5 Stg.4 Pecos County, Tx. Treatment Date: December 24, 2009

Attn: West Ranch South 71-5 Stg.4

The stimulation of the West Ranch South 71-5 stg. #4 well consisted of 3,036 bbls of 25#/30Q Linear Gel fluid and 184 tons of CO2. Th is fluid was laden with 6,975 lbs of 100 mesh sand in a .5, .75 lb hold, also 34,171 lbs of 40/70 TLC sand in a 1, 1.25, 1.5 lb hold, also 33,120 lbs of 20/40 TLC sand in a 1-4 lb hold, and 9,488 lbs of 20/40 SLC sand in a 4 lb hold. It was pumped at an average rate of 61.7 bpm, and an average surface pressure of 5,117 psi. The ISIP was 4,342 psi and the approximate load to recove r is 2,956 bbls. Please find the attached Meyers charts recorded during the job for stg. #4.

Superior Well Services appreciates the opportunity to perform pumping services for you in a cost-effective manner that focuses on quality and safety.

Please contact the Midland Engineering Department if you have any questions,

Thank you, Ricky Herrera Field Service Tech Midland, TX (432) 813-6420Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATE

Superior Rep. Customer Rep. Stage #

Co2 Rate CO2 Total Total Rate

BPM BBLS BPM

24 28 86 24 35 81 24 55 81 24 62 79 24 80 80 25 89 80 23 103 79 24 113 80 24 125 80 24 134 80 24 148 80 22 156 78 23 162 79 23 166 79 23 170 79 23 177 79 23 183 79 60 Page 1

N/A

5 19 4767 30 60 252 3 047 Fl h 5;17pm 5300 30 56 96 2,795 4.0 ppg 20/40 SLC Fluid To Load sweep Treatment Fluid and Capacities in BBLS 5:13pm 5258 30 56 50 2,551 1.0 ppg 20/40 TLC 5:12pm 5160 30 56 90 2,501

2.0 ppg 20/40 TLC Tubing Cap. N/A 5:15pm 5444 30 56 84 2,699 3.0 ppg 20/40 TLC 5:14pm 5313 30 56 64 2,615 Casing Cap. 292 bbls new 5:09pm 5401 30 56 132 2,411 1.5 ppg 40/70 TLC Formation Caballos 5:01pm 5097 30 56 183 2,279 sweep Well Type N/A 4:54pm 5232 30 56 129 1,753 1.25 ppg 40/70 TLC Casing Type 7.0 11.6 lb Casing Depth 7756 ft 4:59pm 5190 30 56 114 2,096 1.5 ppg 40/70 TLC 4:56pm 5160 30 56 229 1,982 1,452 1.0 ppg 40/70 TLC 4:29pm 5098 30 56 187 1,320

sweep 5153 30 57 140 799 .5 ppg 100 mesh

Tubing Depth N/A 4:52pm 5157 30 56 172 1,624 sweep Packer Depth sweep Tubing Type N/A 4:49pm 5281 30 55 132 sweep Well Data 4:27pm 5173 30 55 93 1,133 .75 ppg 100 mesh 4:23pm 5041 30 57 241 1,040 ANNULUS BPM BBLS BBLS 2:56pm 720 30 54 388

Time Pressures (psi) Rate Stage Total

STP

3:45pm 1835 30 58 271 659 4:21pm Stimulation Treatment Report

55-000296 12/24/09

West Ranch 71-5 Pecos Sandridge Energy

TX

Cesar Pando 4

Job Descript ion / Remarks

Pad / Fet

Pad

60

Final OB-1 SuperSet Act

Operators Max Pressure 5,500 psi 15 Min. Gel Average 5190 Average 56 10 Min.

OB-2 Treating Presure Injection Rates Shut In Pressures Materials
Minimum 720 Minimum 54 ISDP 4342 psi LSG SuperFoam
Maximum 5444 Maximum 60 5 Min. SuperNE-1 with 5,200 lbs in wellbore 20/40 SLC 9,488 lbs

Treatment Data 34,171 lbs Screened out well during flush 20/40 TLC 33,120lbs tub. 40/70 TLC wellhead Treatment Data Shut down during Job for leak on a chickson on the Missel Proppant Description Volume Pumped (lbs) Shut down during Job, Blender lost 100 mesh 6975 lbs Shut down during Job for leak on ( Comments ) 26,880 gals Base Fluid Fluid Description Linear Gel # 25 101,094 gals Volume Pumped (Gals) Treatment Data Treating Fluid 1034 bbls Flush 252 bbls Fluid To Recover 2964 bbls 5:19pm 4767 30 60 252 3,047 Flush Pad Volume 1761 bblsBOTTOM HOLE QUALITY PLOT0102030405060708090100110120130140150160TIME (min)0051010201530204025503060357040804590501000102030405060708090100Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009DENSITY PLOTS8090100110120130140150TIME (min)01234567 BLENDER DENSITY (lb/gal)01234567 INLINE DENSITY (lb/gal)Real-Time BLENDER DENSITY (lb/gal)Real-Time INLINE DENSITY (lb/gal)MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009HYDRATION CHEMICALS0102030405060708090100110120130140150160TIME (min)02468101214161820 LSG GPT (gal/1000 gal)012345678910 SUPER NE 100 GPT (gal/1000 gal)Real-Time LSG GPT (gal/1000 gal)Real-Time SUPER NE 100 GPT (gal/1000MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009BLENDER CHEMICALS5060708090100110120130140150160TIME (min)012345 SUPER FOAM GPT (gal/1000 gal)0012243648510Real-Time SUPER FOAM GPT (gal/1000 gal)Real-Time OB1/OB2 PPT (lb/gal)Real-Time ACTIVATOR GPT (gal/1000gaMView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009WEST RANCH SOUTH 71-5 STG.40102030405060708090100110120130140150160TIME (min)001000520001030001540002050002560003070003580004090004510000500102030405060708090100Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)Real-Time FOAM RATE (bpm)Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009Net Pressure vs Time1101001000Time (min)100100010000 Net Pressure (psi)0.1110 Concentration (lbm/gal)Measured Net Pressure (psi)BH Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009BHTP & SP WEST RANCH SOUTH 71-5 STG.40102030405060708090100110120130140150160Time (min)010002000300040005000600070008000900010000 Pressure (psi)00.0102.5205.0307.54010.05012.56015.07017.58020.09022.510025.0 Rate & ConcentrationMeasured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)Measured Surface Slurry Rate (bpm)BH Conc. (lbm/gal)Measured Surface Slurry Conc. (lbm/gal)MWell - MWELL WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009CUSTOMERWELL NAMEDATEFIELD RECIEPT #FLUID TECHSANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th stge 12th stge Total BBLSWater bbls. Per stges.>>0SYSTEM:Chemicals BEG. ENDINGTotal UsedLSG-1 4000 545 946 878 811 8203455OB/OB-2 500 216 40 80 89 75284ACTIVATOR 201 114 22 29 22 1487SUPER FOAM 1319 201 313 268 313 2241118SUPER 100 NE 1780 559 334 291 357 2391221#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!0#VALUE!000000000Comments :DATE:
FIELD RECEIPT #:
FLUID TECH:



### Net Usage

3455

284

87

1118

1221

0

0

0

0

0

0

0

0 SANDRIDGE 12/22/2009

CHEM-ADD OPERATOR: CUSTOMER:
LEASE NAME & WELL #:
FOX WEST RANCH SOUTH 71-5
CALVIN/HERBIE



### OB/OB-2
ACTIVATOR
SUPER FOAM LSG-1 Loaded

4000 Returned

545 Product Description

SUPER 100 NE 500

201

1319

1780 216

114

201

559

Fluid Tech Signature : 

# Load SheetTotal Variance: 1.11%PAGE:DATE:FLUID TECH:FIELD RECEIPT NO:2 3 4 5 6 7 8 9 10 11 12PLANNED FLOWPROPOSED START HOSES END TOTAL LOSSES PUMPED VOLUME METER PLANNED FLOW METERVOLUME LOADED USED DOWNHOLE FOR FLUID MEASURED VS. VS.PUMPED VOLUME DOWNHOLE DOWNHOLE3093 4000 3990 545 3455 10 3445 3425 0.58%277 500 500 216 284 0 284 284 0.00%41 201 200 114 87 1 86 90 -4.44%1000 1319 1315 201 1118 4 1114 1120 -0.54%1149 1780 1780 559 1221 0 1221 1221 0.00%13 14201915 16 17 18SUPER 100 NEPROPPANT (lbs)PRODUCT VARIANCE CALCULATIONSCHEMICALSCALCULATED VARIANCE%FOXCALVIN/HERBIE12/22/2009WEST RANCH SOUTH 71-5LEASE NAME & WELL NO:MEASURED VOLUMESCHEM-ADD OPERATOR:SANDRIDGEPRODUCTLSG-1OB/OB-2ACTIVATOR1CUSTOMER:SUPER FOAMPROPPANT TYPE S.G. PRE-JOB AMOUNT ON POST-JOB AMOUNTVARIANCE %20/40 TLC 2.650.00%20/40 SLC 2.652.18%100 MESH 2.62.44%40/70 TLC 2.651.20%27VARIANCE %0.39%41CLEAN VOLUMEVARIANCE %Comments:168,20015,3555,000240 1,00046,840ENDING VOLUME168,200 2,000PROPPANT VOLUME45,840211,08015,120216,0803041,000166,2002621FLOW METER VOLUME00SPILLAGE DENSIOMETERLOCATION DOWNHOLEPUMPEDIN SAND KING (est.)46,84023 25TOTAL SLURRY15,06215,300CLEAN VOLUME (bbls)42,00015,566.2402242,000(est.on the ground)211,08001,000TOTALBASE FLUID DESCRIPTION15,062BEGINNING VOLUME AFTER LOADING28297,920DOWNHOLE VOLUMEFLOW METER SLURRY VOLUME238SLURRY VOLUME (bbls)2925# LINEAR GELRegression Analysis - Surface012345Nolte G Time20002100220023002400250026002700 Surface Pressure (psi)20002100220023002400250026002700 ISIP - G dP/dGSurface PressureISIP - G dP/dGISIPTC1A1B2A2BPump Time (tp) 2.3244 (min)Closure Time (tc) 7.807 (min)Delta Closure Time (∆tc) 5.4826 (min)Surface ISIP (ISIP|s) 2596.1 (psi)Surface Closure (Pc) 2239.5 (psi)BH ISIP (ISIP|bh) 4762.7 (psi)BH Closure (Pc) 4406.1 (psi)Net Pressure (∆p) 356.59 (psi)Stress Gradient 0.88123 (psi/ft)Efficiency*0.562Slope 1 -144.99Slope 2 -101.85Slope 3Slope 4MinFrac - 12/24/2009Step Down Diagnostic - Surface0102030405060Rate (bpm)01002003004005006007008009001000 Pressure Loss (psi)DP NW Data Points (psi)DP NW: Alpha = 0.591406DP Total NW Data Points (psi)DP Total NW (psi)DP Perf Ideal (psi)Number of perfs = 27Discharge Coeff. = 0.5Perf diameter = 0.48 (in.)MinFrac - 12/24/2009Pump ScheduleCustomer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.4Formation: 1ST CABALLOSFluid Type: 25# LIN/30QSTAGEClean FoamBH SAND BH SANDBLENDER BLENDERPROP PROPSLURRYCLEANCO2N2CLEANSLURRYSLURRYCO2CO2 STAGEBHDESCRIPTIONVolumeCONC CONCCONC CONCTOTAL TOTALRATERATERATERATEVOLUMEVOLUME VOLUMETonsTons TIMEQUALITYGallonsBEGINENDBEGINENDstage cumbpmbpmbpmscfmbblsbbls cumstagecum minBD/FET100000.00 0.000.00 0.000 050.050.00.0 238.1238.1 238.10.00.0 0:04:460PAD200000.00 0.000.00 0.000 056.056.024.0 333.3333.3 571.425.425.4 0:05:5730.5# 100 MESH39900.50 0.500.71 0.711995 199556.554.824.0 66.568.7 640.15.230.6 0:01:1330SWEEP150000.00 0.000.00 0.000 199556.056.024.0 250.0250.0 890.119.049.6 0:04:2830.75# 100 MESH39900.75 0.751.07 1.072992.5 4987.556.854.224.0 66.569.7 959.85.254.8 0:01:1430SWEEP150000.00 0.000.00 0.000 4987.556.056.024.0 250.0250.0 1209.819.073.8 0:04:28301# 40/70 TLC66361.00 1.001.43 1.436636 11623.557.053.623.0 110.6117.8 1327.68.482.3 0:02:0430SWEEP150000.00 0.000.00 0.000 11623.556.056.024.0250.0250.0 1577.619.0101.3 0:04:28301.25# 40/70 TLC66361.25 1.251.79 1.798295 19918.557.353.023.0110.6119.6 1697.28.5109.8 0:02:0530SWEEP150000.00 0.000.00 0.000 19918.556.056.024.0250.0250.0 1947.219.0128.9 0:04:28301.5# 40/70 TLC66361.50 1.502.14 2.149954 29872.557.552.423.0110.6121.4 2068.68.6137.5 0:02:0730SWEEP150000.00 0.000.00 0.000 29872.556.056.024.0250.0250.0 2318.619.0156.5 0:04:28301.5# 40/70 TLC66361.50 1.502.14 2.149954 39826.557.552.423.0110.6121.4 2440.08.6165.2 0:02:0730SWEEP150000.00 0.000.00 0.000 39826.556.056.024.0250.0250.0 2690.019.0184.2 0:04:28301# 20/40 TLC33181.00 1.001.43 1.433318 43144.557.053.623.055.358.9 2748.94.2188.4 0:01:02302# 20/40 TLC33182.00 2.002.86 2.866636 49780.558.051.322.055.362.5 2811.44.2192.6 0:01:05303# 20/40 TLC33183.00 3.004.29 4.299954 59734.558.949.322.055.366.1 2877.54.4197.0 0:01:07304# 20/40 TLC33184.00 4.005.71 5.7113272 73006.559.747.421.055.369.7 2947.34.4201.4 0:01:10304# 20/40 SLC25004.00 4.005.71 5.7110000 83006.559.747.321.041.752.6 2999.93.3204.7 0:00:5330FLUSH123060.00 0.000.00 0.000 83006.580.080.00.0293.0293.0 3292.90.0204.7 0:03:400DesignTotals -->1826028300703202.73292.9204.70:57:14ActualTotals -->Depths(ft)# of PerfsDisplacement (bbls)PumpViaPrepared By:SOTELOTopPerf7624110TubingCasingBottom Perf7756Casing291.69Blender Operator:BROWNN/AAnnulusFluid Technician:FOXO.D.(in.)Weight(lbs/ft)Bbls/ft I.D.(in.)Casing70.03826 6.276Flush (bbls)Hydration Operator:HERBIETubingTop 291.7AnnulusBottom 296.726Superior Well ServicesAdditive ScheduleCustomer Name: SANDRIDGE12/24/2009Well Name: WEST RANCH 71-5 STG.4 Formation: 1ST CABALLOSAdditive: LSG-1(GEL)Planned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140006.2587.50 13.39 13.9114.4414.96 15.4987.500.7127936.2517.46 12.97 13.4713.9914.49 15.02104.960.00105006.2565.63 13.39 13.9114.4414.96 15.49170.581.0727936.2517.46 12.76 13.2613.7814.28 14.78188.040.00105006.2565.63 13.39 13.9114.4414.96 15.49253.661.4346456.2529.03 12.57 13.0713.5514.04 14.54282.700.00105006.2565.63 13.39 13.9114.4414.96 15.49348.321.7946456.2529.03 12.39 12.8613.3613.83 14.33377.350.00105006.2565.63 13.39 13.9114.4414.96 15.49442.982.1446456.2529.03 12.21 12.6813.1513.62 14.10472.010.00105006.2565.63 13.39 13.9114.4414.96 15.49537.642.1446456.2529.03 12.21 12.6813.1513.62 14.10566.670.00105006.2565.63 13.39 13.9114.4414.96 15.49632.291.4323236.2514.52 12.57 13.0713.5514.0414.54646.812.8623236.2514.52 11.84 12.3112.7813.23 13.70661.334.2923236.2514.52 11.21 11.6312.0812.52 12.97675.845.7123236.2514.52 10.63 11.0311.4511.87 12.29690.365.7117506.2510.94 10.61 11.0011.4211.84 12.26701.300.00123060.000.00 0.00 0.000.000.00 0.00701.30701.30Additive: ACTIVATORPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140000.000.00 0.00 0.000.000.00 0.000.000.7127930.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.0727930.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.4346450.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.7946450.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.002.1446450.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.002.1446450.000.00 0.00 0.000.000.00 0.000.000.00105000.000.00 0.00 0.000.000.00 0.000.001.4323230.000.00 0.00 0.000.000.000.000.002.8623230.000.00 0.00 0.000.000.00 0.000.004.2923230.000.00 0.00 0.000.000.00 0.000.005.7123230.000.00 0.00 0.000.000.00 0.000.005.7117505.008.75 8.48 8.809.149.47 9.818.750.00123060.000.00 0.00 0.000.000.00 0.008.758.75Additive: SUPER NEPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100002.0020.00 4.28 4.454.624.79 4.9620.000.00140002.0028.00 4.28 4.454.624.79 4.9648.000.7127932.005.59 4.15 4.314.484.64 4.8053.590.00105002.0021.00 4.28 4.454.624.79 4.9674.591.0727932.005.59 4.08 4.244.414.57 4.7380.170.00105002.0021.00 4.28 4.454.624.79 4.96101.171.4346452.009.29 4.02 4.184.334.49 4.65110.460.00105002.0021.00 4.28 4.454.624.79 4.96131.461.7946452.009.29 3.96 4.124.284.43 4.59140.750.00105002.0021.00 4.28 4.454.624.79 4.96161.752.1446452.009.29 3.91 4.064.214.36 4.51171.040.00105002.0021.00 4.28 4.454.624.79 4.96192.042.1446452.009.29 3.91 4.064.214.36 4.51201.330.00105002.0021.00 4.28 4.454.624.79 4.96222.331.4323232.004.65 4.02 4.184.334.494.65226.982.8623232.004.65 3.79 3.944.094.23 4.38231.624.2923232.004.65 3.59 3.723.864.01 4.15236.275.7123232.004.65 3.40 3.533.663.80 3.93240.915.7117502.003.50 3.39 3.523.653.79 3.92244.410.00123062.0024.61 4.28 4.454.624.79 4.96269.03269.03Fluid Technician:FOXField Receipt #:STG.24Prepared By:SOTELOCustomer Name: SANDRIDGE12/24/2009Superior Well ServicesAdditive ScheduleWell Name: WEST RANCH 71-5 STG.4Formation: 1ST CABALLOSAdditive: OB1/OB2Planned Additive Rates (PPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140000.507.00 1.07 1.111.161.20 1.247.000.7127930.501.40 1.04 1.081.121.16 1.208.400.00105000.505.25 1.07 1.111.161.20 1.2413.651.0727930.501.40 1.02 1.061.101.14 1.1815.040.00105000.505.25 1.07 1.111.161.20 1.2420.291.4346450.502.32 1.01 1.051.081.12 1.1622.620.00105000.505.25 1.07 1.111.161.20 1.2427.871.7946450.753.48 1.49 1.541.601.66 1.7231.350.00105000.757.88 1.61 1.671.731.80 1.8639.222.1446450.753.48 1.46 1.521.581.63 1.6942.710.00105000.757.88 1.61 1.671.731.80 1.8650.582.1446450.753.48 1.46 1.521.581.63 1.6954.070.00105000.757.88 1.61 1.671.731.80 1.8661.941.4323230.751.74 1.51 1.571.631.691.7563.682.8623231.252.90 2.37 2.462.562.65 2.7466.594.2923231.252.90 2.24 2.332.422.50 2.5969.495.7123231.252.90 2.13 2.212.292.37 2.4672.395.7117501.252.19 2.12 2.202.282.37 2.4574.580.00123060.000.00 0.00 0.000.000.00 0.0074.58Additive: SUPER FOAMPlanned Additive Rates (GPT)VOLUMEPPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONE0.00100000.000.00 0.00 0.000.000.00 0.000.000.00140002.0028.00 4.28 4.454.624.79 4.9628.000.7127932.005.59 4.15 4.314.484.64 4.8033.590.00105002.0021.00 4.28 4.454.624.79 4.9654.591.0727932.005.59 4.08 4.244.414.57 4.7360.170.00105002.0021.00 4.28 4.454.624.79 4.9681.171.4346452.009.29 4.02 4.184.334.49 4.6590.460.00105002.0021.00 4.28 4.454.624.79 4.96111.461.7946452.009.29 3.96 4.124.284.43 4.59120.750.00105002.0021.00 4.28 4.454.624.79 4.96141.752.1446452.009.29 3.91 4.064.214.36 4.51151.040.00105002.0021.00 4.28 4.454.624.79 4.96172.042.1446452.009.29 3.91 4.064.214.36 4.51181.330.00105002.0021.00 4.28 4.454.624.79 4.96202.331.4323232.004.65 4.02 4.184.334.494.65206.982.8623232.004.65 3.79 3.944.094.23 4.38211.624.2923232.004.65 3.59 3.723.864.01 4.15216.275.7123232.004.65 3.40 3.533.663.80 3.93220.915.7117502.003.50 3.39 3.523.653.79 3.92224.410.00123060.000.00 0.00 0.000.000.00 0.00224.41Additive:Planned Additive Rates ()PPGVOLUME LOAD AMOUNT 51 BPM 53 BPM55 BPM57 BPM 59 BPM ActualGONEFluid Technician:FOXField Receipt #:STG.24Prepared By:SOTELO

### WELLBORE SCHEMATIC

GL: 4127 WELL NAME: WEST RANCH SOUTH 71- 5 SPOT: 825' FNL & 800' FEL ZONE: OPERATOR: SandRidge Energy KB: 4147 CORPORATE ID: LOCATION: Sec 71, Blk 2, TC RR CO Survey, A-3386 GL: 4,127' SPUD DATE: 10/19/09 API NO: FIELD: Pi ň on KB: 4,147' RR DATE: 12/01/09 WI: COUNTY: Pecos TD: 8,900' MICU: RI: STATE: Texas PBTD: 8,827' COMPL DATE: PIPE RECORD CEMENT & HOLE DATA CSG OD GRADE THD WT/FT TOP BTM # JTS BIT SZE DEPTH SXS TOC

Surf. 9.625'' J-55 LT&C 36.00# 0' 1,118' 28 12.250'' 1,158' 780 0' 9-5/8" @ 1,118' Prod. 7.000'' P-110 LT&C 26.00# 0' 8,883' 237 Prod. 7.000'' N-80 LT&C 26.00# see below see below 2

Well tools: Marker joint at 7,164' is 7" 26# N-80, all other casing is 7" 26# P-110. DV tool at 5,404' cemented with 710 sks 50:50 Poz:Class "H" (Stage 2). Stage 1 cemented with 280 sks 50:50 Poz:Class "H" WELL HISTORY

DATE WORK DETAIL PROD. RESULTS

TOC @ 2,704'

Drilling Notations:

DV Tool @ 5,404'

Stimulation Treatment PERFORATION HISTORY

Date Zone Sand (klbs) Fluid (bbls) Total Fluid Type (Pad/Prepad/Frac/Flush) Prop Type AIR(bpm)/ AIP(psig) Frac Grad/ ISIP DATE TOP BTM ZONE SPF(count)/ Phasing Status

Frac Job Remarks (Screenouts or problems in Frac job):

CIBP Record Date Depth Type

TOC @ 6,750'

Remarks:

Downhole Jewelry (Bottom to top)

Length Depth Description ID Drift Collapse* Burst* Tensile* Material (Lone Star Steel Handbook) (in) (in) (psi) (psi) (Klbs)

'' #

'' #
9.625'' J-55 LT&C 36# 8.921 8.765 2,020 3,520 453
7'' P-110 LT&C 26# 6.276 6.151 6,230 9,950 693
7'' N-80 LT&C 26# 6.276 6.151 5,410 7,240 519

'' # * Safety Factor Not Included

REMARKS

ENGINEER: J. Stewart
GEOLOGIST: F. Guerrero

LANDMAN:

PREPARED BY: J. Stewart PBTD @ 8,827' PREPARED DATE: 12/10/2009 UPDATED: 7" @ 8,883' UPDATED: UPDATED: TD @ 8,900' UPDATED: UPDATED: 6,750' & 2,704' - CBL 56.73% CURRENT 1st Caballos, Tesnus 101577 42-371-38589 69.50%

8.750'' 8,900' 990 50:50 Poz:Class "H" TYPE

Class "C", 35:65 Poz:Class "C"

Date Removed Notes

Marker joint at 7,164' TUBULAR GOODS PERFORMANCE

Packer Detail:

Temperature: 175° F at 8,870' - OH Logs

### WELLBORE SCHEMATIC

GL: 4127 WELL NAME: WEST RANCH SOUTH 71-5 SPOT: 825' FNL & 800' FEL ZONE: OPERATOR: SandRidge Energy KB: 4147 CORPORATE ID: LOCATION: Sec 71, Blk 2, TC RR CO Survey, A-3386 GL: 4,127' SPUD DATE: 10/19/09 API NO: FIELD: Pi ň on KB: 4,147' RR DATE: 12/01/09

WI: COUNTY: Pecos TD: 8,900' MICU: RI: STATE: Texas PBTD: 4,870' COMPL DATE: PIPE RECORD CEMENT & HOLE DATA CSG OD GRADE THD WT/FT TOP BTM # JTS BIT SZE DEPTH SXS TOC

Surf. 9.625'' J-55 LT&C 36.00# 0' 1,118' 28 12.250'' 1,158' 780 0' Prod. 7.000'' P-110 LT&C 26.00# 0' 8,883' 237 9-5/8" @ 1,118' Prod. 2-3/8" L-80 EUE 8RD 4.7# 0' 4,712' 146

Well tools: Marker joint at 7,164' is 7" 26# N-80, all other casing is 7" 26# P-110. DV tool at 5,404' cemented with 710 sks 50:50 Poz:Class "H" (Stage 2). Stage 1 cemented with 280 sks 50:50 Poz:Class "H" WELL HISTORY

DATE WORK DETAIL PROD. RESULTS 12/07/09 12/09/09

12/10/09 12/12/09 12/22/09

12/23/09

12/24/09

TOC @ 2,704' 12/26/09 01/05/10 01/07/10 01/11/10 01/12/10 01/13/10 01/17/10 01/19/10 3,494' 3,700'

3,870' 4,000' 01/20/10

01/22/10 03/23/10

Drilling Notations: XN nipple @ 4681'

4,696' Stimulation Treatment PERFORATION HISTORY

4,810' Date Zone Sand (klbs) Fluid (bbls) Total Fluid Type (Pad/Prepad/Frac/Flush) Prop Type AIR(bpm)/ AIP(psig) Frac Grad/ ISIP DATE TOP BTM ZONE SPF(count)/ Phasing Status

EOT @ 4,712' 12/22/09 1st Cab 144 4462 25# linear, 30Q CO2 20/40 TLC 75 / 5095 / 3641 12/09/09 8,360' 8,380' 1st Caballos 0.5 SPF / 60° Inactive PBTD @ 4744' 12/23/09 1st Cab 102 4131 25# linear, 30Q CO2 20/40 TLC 65 / 5078 / 4478 12/09/09 8,500' 8,530' 1st Caballos 1 SPF / 60° Inactive CBP @ 4,870' 12/24/09 1st Cab 135 3742 25# linear, 30Q CO2 20/40 TLC 80 / 3788 / 3004 12/09/09 8,600' 8,630' 1st Caballos 2 SPF / 60° Inactive 12/24/09 1st Cab 84 2956 25# linear, 30Q CO2 20/40 TLC 62 / 5117 / 4342 1/19/10 Tesnus 80 555 20# linear, 70-85Q CO2 20/40 Ottawa 38 / 3988 / 3415 12/22/09 8,255' 8,270' 1st Caballos 3 SPF / 60° Inactive DV Tool @ 5,404' 1/19/10 Tesnus 56 418 20# linear, 70-85Q CO2 20/40 Ottawa 38 / 2937 / 2460 1/20/10 Tesnus 146 645 20# linear, 70-85Q CO2 20/40 Ottawa 37 / 2857 / 3088 12/23/09 7,910' 7,930' 1st Caballos 0.5 SPF / 60° Active 12/23/09 7,986' 8,006' 1st Caballos 1 SPF / 60° Active 12/23/09 8,036' 8,056' 1st Caballos 1 SPF / 60° Active Frac Job Remarks (Screenouts or problems in Frac job): 12/23/09 8,120' 8,140' 1st Caballos 2 SPF / 60° Active

12/24/09 7,624' 7,654' 1st Caballos 1 SPF / 60° Active 12/24/09 7,708' 7,718' 1st Caballos 2 SPF / 60° Active 12/24/09 7,736' 7,756' 1st Caballos 3 SPF / 60° Active
CIBP Record Date Depth Type 01/11/10 4,696' 4,706' Tesnus 0.5 SPF / 60° Active

12/22/09 8,330' CBP 01/11/10 4,726' 4,736' Tesnus 0.5 SPF / 60° Active 12/23/09 8,180' CBP 01/11/10 4,768' 4,778' Tesnus 1 SPF / 60° Active 12/24/09 7,800' CBP 01/11/10 4,790' 4,810' Tesnus 1 SPF / 60° Active 01/05/10 8,335' CIBP 01/07/10 8,200' CIBP 01/19/10 3,870' 3,880' Tesnus 1 SPF / 60° Active TOC @ 6,750' 01/11/10 4,870' CBP 01/19/10 3,920' 3,930' Tesnus 1 SPF / 60° Active 01/19/10 4,040' CFP 01/19/10 3,990' 4,000' Tesnus 2 SPF / 60° Active 01/19/10 3,740' CFP 01/19/10 3,494' 3,504' Tesnus 0.5 SPF / 60° Active

Remarks: 01/19/10 3,544' 3,574' Tesnus 0.5 SPF / 60° Active 01/19/10 3,626' 3,634' Tesnus 1 SPF / 60° Active 01/19/10 3,662' 3,672' Tesnus 1 SPF / 60° Active 01/19/10 3,690' 3,700' Tesnus 1 SPF / 60° Active Downhole Jewelry (Bottom to top) Length Depth Description ID Drift Collapse* Burst* Tensile*
4,729' Material (Lone Star Steel Handbook) (in) (in) (psi) (psi) (Klbs)
7,624' '' #
7,756' 4,697' 9.625'' J-55 LT&C 36# 8.921 8.765 2,020 3,520 453
4,712' 7'' P-110 LT&C 26# 6.276 6.151 6,230 9,950 693
7,910' 2-3/8"'' L-80 EUE 8RD 4.7## 6.276 6.151 5,410 7,240 519
8,140' '' # CIBP @ 8,200' * Safety Factor Not Included

8,255' REMARKS
8,270' CIBP @ 8,335' ENGINEER: J. Stewart

8,360' GEOLOGIST: F. Guerrero 8,630' LANDMAN:

PREPARED BY: J. Stewart PBTD @ 8,827' PREPARED DATE: 12/10/2009 UPDATED: 7" @ 8,883' UPDATED: J. Stewart 1/21/2010 UPDATED: TD @ 8,900' UPDATED: UPDATED: Pull tubing and packer Class "C", 35:65 Poz:Class "C"

8.750'' 8,900' 990 50:50 Poz:Class "H"

Breakdown 1st Caballos 8360 - 8630 with 20 bbls 2% KCl. Swab back load with no production results. 56.73% CURRENT 1st Caballos, Tesnus 101577 42-371-38589 69.50%

TYPE

6,750' & 2,704' - CBL

Drill out DV tool at 5404 and dress off (Poor cement bond from 7650 - 8110) Perforate 1st Caballos 8360 - 8630 RIH with packer on 2-3/8" tubing setting packer at 8327

Breakdown Tesnus 4696 - 4810 with 5 bbls 4% KCl. Swab back load with no production results. Pull tubing and packer Frac 1st Caballos 8360 - 8630 with 144M lbs 100 mesh, 40/70 TLC, 20/40 TLC, and 20/40 SLC in 25# linear gel, 30Q CO2. Set CBP at 8330 Perforate 1st Caballos 8255 - 8270 Frac 1st Caballos 8255 - 8270 with 102M lbs 100 mesh, 40/70 TLC, 20/40 TLC, and 20/40 SLC in 25# linear gel, 30Q CO2. Set CBP at 8180 Perforate 1st Caballos 7910 - 8140

Frac Tesnus 4696 - 4810 with 80M lbs 20/40 Ottawa and CRC in 20# linear gel, 70-85Q CO2. Frac 1st Caballos 7910 - 8140 with 135M lbs 100 mesh, 40/70 TLC, 20/40 TLC, and 20/40 SLC in 25# linear gel, 30Q CO2. Set CBP at 7800 Perforate 1st Caballos 7624 - 7756 Frac 1st Caballos 7624 - 7756 with 84M lbs 100 mesh, 40/70 TLC, 20/40 TLC, and 20/40 SLC in 25# linear gel, 30Q CO2. With coil tubing, drill out plugs and clean out to 8750. Set CIBP at 8335. Spot 2 sks cement above. Set CIBP at 8200. Spot 2 sks cement above. Set CBP at 4870 and perforate Tesnus 4696 - 4810. Set packer on 2-3/8" tbg at 4629 and swab test Tesnus (swabbed dry, no pressure).

12/26/2009 isolate lower intervals during uphole frac Set CFP at 4040 Perforate Tesnus 3870 - 4000 Frac Tesnus 3870 - 4000 with 56M lbs 20/40 Ottawa and CRC in 20# linear gel, 70-85Q CO2. Set CFP at 3740 Perforate Tesnus 3494 - 3700

12/26/2009 isolate lower intervals during uphole frac
12/26/2009 isolate lower intervals during uphole frac

Temperature: 175° F at 8,870' - OH Logs Composite Bridge Plug (not CIBP).

1/20/2010 isolate lower intervals during uphole frac 1/20/2010 isolate lower intervals during uphole frac

Marker joint at 7,164' n/a abandon 1st Cab 8360 - 8630. 2 sks cmt
n/a abandon 1st Cab 8255 - 8270. 2 sks cmt

TUBULAR GOODS PERFORMANCE

Notched collar 1 jt 2-3/8" 4.7# L-80 tbg 1.791" ID XN-nipple Date Removed Notes

146 jts 2-3/8" 4.7# L-80 tbg n/a

Packer Detail: Drill out CFPs at 3740 and 4040, leaving CBP at 4870 in place. Frac Tesnus 3494 - 3700 with 146M lbs 20/40 Ottawa and CRC in 20# linear gel, 70-85Q CO2.

Wash out to 4830 (leaving 40' fill above CBP at 4870) and pick up to 4729 and configure tubing as indicated below. RIH w/tbg end locater, tag @4744', locate EOT @4712', ran 1.916" broach to XN @4681', drop ball/seat spring and plunger, chase to XN.