SandRidge Energy

WRS 71-5 

No. 19a – Frac Service Company

Stages 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 shoe 7 26 P‐110 6.276

TRUE 2 38.01 Casing‐JoinCasing (bla 7 26 P‐110 6.276

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

TRUE 4 37.02 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 5 36.7 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 6 37.73 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 7 37.19 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 8 37.9 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 9 37.33 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 10 37.13 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 11 36.81 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 12 36.86 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 13 38.29 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 14 38 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 15 37.01 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 16 38.61 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 17 37.16 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 18 37.62 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 19 36.42 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 20 37.5 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 21 36.84 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 22 37.3 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 23 36.94 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 24 38.46 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 25 37.07 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 26 37.18 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 27 37.97 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 28 37.71 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 29 37.08 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 30 37.22 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 31 38.21 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 32 37.21 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 33 35.86 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 34 37.11 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 35 37.66 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 36 37.35 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 37 37.01 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 38 36.35 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 39 36.75 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 40 38.4 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 41 35.34 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 42 36.32 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 43 38.02 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 44 37.05 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 45 36.34 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 46 37.95 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 47 37.65 Casing‐JoinCasing (bla 7 26 P‐110 6.276
TRUE 48 39.28 Casing‐JoinCasing (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
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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

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39.28 7,240 5,410 6.151

1,755.71 9,950 6,230 6.151

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3.6 9,950 6,230 6.151

5,384.39 9,950 6,230 6.151

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7.656

8

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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 4% Crystalline KCl 3,726 30.0

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

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
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 (psi) Plug Bump Pressure (psi) 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) Thickening 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 (psi) Plug Bump Pressure (psi) 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) Thickening 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 Pressure (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 (psi) Plug Bump Pressure (psi) 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) Thickening 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 (psi) Plug Bump Pressure (psi) 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) Thickening 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 (psi) Plug Bump Pressure (psi) 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) Thickening 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 (psi) Plug Bump Pressure (psi) 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) Thickening 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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.

AFE: 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

AFE: 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.

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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.

AFE: 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

AFE: 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.

AFE: 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

AFE: 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.

AFE: 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

AFE: 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.

AFE: 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

AFE: 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

AFE: 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.

AFE: 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

AFE: 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.

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 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

AFE: 091141

19

Drilling Report
WEST RANCH SOUTH 71-5 PRODUCTION CEMENT PROCEDURE

Have at least 800 bbls of fresh water 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” float shoe 

 ~1 joint 7”, 26 ppf, P-110, LTC casing (1 shoe joint)

 ~7” float 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 joint, 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 3,300’ (eleven total)

Once casing is run to TD and full of drilling mud, circulate casing for 1.5 hours with mud. 

Before cementing, have Weatherford 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 ft3

 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. If 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 sets. 

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 Class H Cement w/ additives Fluid Weight: 14.2 lbm/gal 

 Slurry Yield: 1.32 ft3

 Total Mixing Fluid: 5.61 Gal/sk

/sk

 

 

Insert DV closing 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 INTO COMPUTER AND SEND VIA EMAIL

Thanks, 

Richard Hill 

Drilling Engineer 

SandRidge Energy, Inc.

Oklahoma 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 4% Crystalline KCl 3,726 30.0

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

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
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 4% Crystalline KCl 3,726 30.0

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

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
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 4% Crystalline KCl 3,726 30.0

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

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
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
























SandRidge Energy Daily Completions Report

WRS 71-5 - SandRidge Energy

Report Start Date Report End Date Daily Summary 12/1/2009 12/2/2009 NU WH & clean pits. Rig released 12/1/09.12/2/2009 12/3/2009 WOCU. Temporarily drop fr/ report.12/6/2009 12/7/2009

MIRU WSU. NU manual frac valve & NU BOP. TIH w/ bit, sub, DC, XO, XN nipp& tagged DV tool @ 5,343'. TOH w/ 1 jt tbg to 5,311'. SWI & SDFN. Prep f/ DO

12/7/2009 12/8/2009

RU PS. TIH w/ tbg & tagged cmt @ 5,343'. Est circ. Drld 59' cmt to DV tool @ 5Cont TIH w/ 106 jts tbg & CO to 8,795'. Rev circ; dsplc'd w/ 400 bbls 2% KCL. R254 jts tbg, DC & bit; LD 16 jts tbg. SWI & SDFN. Prep to run scraper & f/ WL.

12/8/2009 12/9/2009

TIH w/ WEG, XO, scraper, DC's, XO, XN nipple & 163 jts tbg to 5,343'. Cleaned dressed up DV tool @ 5,402'. Cont TIH w/ scraper to 5,722'. TOH w/ tbg & LD DMIRU WL. RIH w/ CBL/CCL/GR & logged 8,827'-2,500' w/ 1000 psi on csg. TOC 2,704'. SWI & SDFN. Prep to perf.

12/9/2009 12/10/2009

Tstd csg to 4800 psi; bled dn. Perf'd 1st Cab 8,360'-8,380' w/ 1 SP2 ft; 8,500'-8,58,600'-8,630' w/ 2 SPF (100 holes) using 4" csg guns 60 deg phased. POH. RDWEG, XN nipple w/ no-go, sub, AS1X pkr w/ on-off tool, X profile, X nipple & 258 @ 8,327'; EOT @ 8,333'; XN nipple @ 8,332'; X profile @ 8,319' & XN nipple @ 

NU tree. RDMO WSU. SDFN.

12/10/2009 12/11/2009

0 psi - SITP/SICP. MIRU swab. IFL @ sfc. Made 8 runs. EFL @ 8,200'. Press Loaded tbg w/ 22 bbls 2% KCL. BD 1st Cab @ 2920 psi w/ 20 bbls. Est inj rate bpm. 42 TLTR. Swabbed. IFL @ sfc. Made 10 runs; no tail gas. EFL @ 4,800

12/11/2009 12/12/2009

20 psi - BTP; 0 psi - BCP. Swabbed. IFL @ 2,000'. Made 17 runs; no show of g7,600'. RDMO swab. SWI & SDFN. 

12/12/2009 12/13/2009

0 psi - SITP/SICP. MIRU WSU. NU BOP. Rel'd pkr. TOH & LD 250 jts tbg & pkRDMO WSU. WO frac.

12/13/2009 12/14/2009 SI; WO frac 12/21-22. Temporarily drop fr/ report pending further activity.12/22/2009 12/23/2009

Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 147M lbs 100 Mesh, 20/40 TLC & SLsd, 4462 TLTR, 1613 bbls CO2. RU WL. RIH & set 7" CIBP @ 8,330'. POH. Pplug to 4850 psi. Bled off. Perf'd 1st Cab 8,255'-8,270' w/ 3 SPF (45 shots) using deg phased. RD WL. SD due to equip failure. SDFN. WO blender repairs.

12/23/2009 12/24/2009

Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 102M lbs 100 Mesh, 20/40 TLC & SLsd, 4131 TLTR, 1450 bbls CO2. RU WL. RIH & set 7" CBP @ 8,180'. Tstd plug Perf'd 1st Cab 7,910'-7,930' w/ 1 SP2F; 7,986'-8,006'; 8,036'-8,056' w/ 1 SPF; 8,1SPF (90 holes) using 4" csg guns 60 deg phased. RD WL. SDFN. Prep f/ frac.

12/24/2009 12/25/2009

Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 135M lbs 100 Mesh, 20/40 TLC & SLsd, 3742 TLTR, 1299 bbls CO2. RU WL. RIH & set CBP @ 7,800'. Tstd plug to 1st Cab 7,624'-7,654' w/ 1 SPF; 7,708'-7,718' w/ 2 SPF; 7,736'-7,756' w/ 3 SPF (4" csg guns 60 deg phased. RDMO WL. Frac'd w/ 25# linear gel, 30Q CO2, 84M 20/40 TLC & SLC & 40/70 TLC sd, 2956 TLTR, 986 bbls CO2. Screened out 50 flush. Flwg back load after frac.

12/25/2009 12/26/2009 Flwg back load after frac.
SandRidge Energy Daily Completions Report

12/26/2009 12/27/2009

MIRU CTU. Tstd tbg to 3500 psi. RIH w/ CT, tagged 1st plug @ 7,800' & DO; chDO plug @ 8,180', chased to 3rd plug @ 8,330' & DO. CO to 8,750'. POH w/ CTTotal 1367 bbls 7% KCL pmpd. Flwg to tank.

12/27/2009 12/28/2009 Flwg to tank.12/28/2009 12/29/2009 Flwg to tank.12/29/2009 12/30/2009 Flwg to tank.12/30/2009 12/31/2009 Flwg to tank.12/31/2009 1/1/2010 Flwg to tank.1/1/2010 1/2/2010 Flwg to tank.1/2/2010 1/3/2010 Flwg to tank.1/3/2010 1/4/2010 Flwg to tank.1/4/2010 1/5/2010

FCP - 750 psi. MIRU SLU. RIH w/ GR & sinker bars to 8,650'. POH & LD GR. 7,500'-8,650'. RDMO SLU. Flwg to tank.

1/5/2010 1/6/2010

FCP - 660 psi. SWI & 2:00 p.m. MIRU WL. RIH w/ GR to 8,350'. POH. RIH & s8,335'. POH. Dump bailed 2 sx cmt on CIBP. RDMO WL. Opened to tank @ 5

1/6/2010 1/7/2010

MIRU WSU. ND hydraulic frac valve & NU BOP. FIRST SALES @ 4:00 p.m. on to tank due to incr LP. Prep to set CIBP.

1/7/2010 1/8/2010

Flwd to sales 8 hrs. SWI @ 1:00 p.m. MIRU WL. RIH & set 7" CIBP @ 8,200'. dump bailed 2 sx cmt on CIBP. POH. RDMO WL. Flwd to tank 12 hrs.

1/8/2010 1/9/2010

FCP - 380 psi. MIRU SLU. RIH w/ GR & tagged 8,185'. POH. Ran flwg gradienRDMO SLU. Flwg to tank.

1/9/2010 1/10/2010 Flwg to tank through test equip.1/10/2010 1/11/2010 Unable to overcome LP. Turned to tank. SI @ 10 a.m. SDFN. Prep f/ WL.1/11/2010 1/12/2010

SICP - 850 psi. MIRU WL. Ran GR & JB to 4,890'. RIH & set 7" CBP @ 4,870'. Tstd csg to 4800 psi w/ 180 bbls 4% KCL. Perf'd Tesnus 4,696'-4,706'; 4,726'-4,74,768'-4,778'; 4,790'-4,810' w/ 1 SPF (40 holes) using 4" csg guns 60 deg phasedSDFN. Prep to run tbg & pkr.

1/12/2010 1/13/2010

SICP - 0 psi. TIH w/ WEG, sub, AS1X pkr, T-2 on/off tool, X nipple & 143 jts tbg; 

w/ 5 pts compression. NU tree. Tstd csg & pkr to 800 psi. RU swab. IFL @ sfc. pulled out of rope socket on 11th run. EFL @ 4,100'. Rel'd pkr. TOH w/ 76 jts tbTIH & set pkr @ 4,640' w/ 6 pts compression. ND BOP & NU tree. SDFN. 
SandRidge Energy Daily Completions Report

1/13/2010 1/14/2010

SITP - 0 psi. Loaded annulus w/ 15 bbls 4% KCL. Tstd pkr to 800 psi. RDMO Wswab. IFL @ 500'. Made 6 runs. EFL @ 4,300'. Loaded tbg w/ 15 bbls 4% KCLBD @ 3000 psi & 3 bpm. Cont'd swabbing. IFL @ sfc. Made 6 runs. EFL @ 4,0

1/14/2010 1/15/2010

SITP/SICP. IFL @ 3,600'. Made 4 runs to 4,500'; no tail gas. EFL @ 4,500'. RDSLU. Located X nipple @ 4,571' & XN nipple @ 4,622'. RIH & set press bombs POH. RDMO SLU. SWI & SDFN. 

1/15/2010 1/16/2010 SIFBU.1/16/2010 1/17/2010 SIFBU.1/17/2010 1/18/2010

MIRU SLU. Pulled BHP gauges. MIRU WSU. ND tree. NU manual frac valve & Rel'd AS1X pkr. TOH w/ 132 jts tbg & pkr. ND BOP's & ND hydraulic frac valve. frac sch 1/19.

1/18/2010 1/19/2010 MIRU frac svcs. SDFN.1/19/2010 1/20/2010

Frac'd Tesnus w/ 20# linear gel, 70-85Q CO2, 80M lbs 20/40 Ottawa & 20/40 CR997 bbls CO2. RU WL. RIH w/ CCL & set 7" CFP @ 4,040'. POH. Tstd plug to Tesnus 3,870'-3,880'; 3,920'-3,930' w/ 1 SPF; 3,990'-4,000' w/ 2 SPF (40 holes) udeg phased. RD WL. Frac'd w/ 20# linear gel, 70-85Q CO2, 56M lbs 20/40 Ottasd, 418 TLTR, 795 bbls CO2. RU WL. RIH w/ CCL & set 7" CFP @ 3,740'. POH4800 psi. Perf'd Tesnus 3,494'-3,504'; 3,544'-3,574' w/ 1 SP2F; 3,626'-3,634'; 3,63,690'-3,700' w/ 1 SPF (48 holes) using 4" guns 60 deg phased. RD WL. SWI & frac sch 1/20.

1/20/2010 1/21/2010

Frac'd Tesnus w/ 20# linear gel, 60-85Q CO2, 146M lbs 20/40 Ottawa & CRC sd1747 bbls CO2. MIRU CTU. RIH w/ mill centralizer, extreme motor & CT circ .23 DO 1st CFP @ 3,744'; chased plug. Cont RIH & tagged 2nd CFP @ 4,042' & DOWashed to 3rd CBP @ 4,862'. Circ clean. POH. RDMO CTU. Total 600 BW pmload after frac.

1/21/2010 1/22/2010

FCP - 600 psi. MIRU WSU & WL. RIH w/ dump bailer & tagged 4,779'; 91' fill on POH & LD bailer. RDMO WL. NU hydraulic BOP's. Flwg to tank. Prep to run tb

1/22/2010 1/23/2010

MIRU snub unit. TIH w/ NC, XN nipple w/ PT plug & 147 jts tbg, tagged 4,760' & 4,830'. Circ. TOH & LD 4 jts tbg; EOT @ 4,729'; XN nipple @ 4,697'; 146 jts tbg unit. ND hydraulic BOP & manual frac valve. NU tree. Tied into flowlines. MIRU tagged plug @ 4,672' & fished plug fr/ XN nipple. POH & LD plug. RDMO SLU. pmpd. Flwd to tank; died. SIFBU. 

1/23/2010 1/24/2010

TP - 0 psi; CP - 1000 psi. Pmpd FA dn csg 3 hrs; no ret's. Jetted tbg w/ FA 2 hrsJetted csg 2 hrs; no rec'y. Flwd to tank. Turned to sales.

1/24/2010 1/25/2010 RDMO WSU. Flwg to sales.1/25/2010 1/26/2010 Flwg to sales.1/26/2010 1/27/2010 Flwg to sales.
SandRidge Energy Daily Completions Report

1/27/2010 1/28/2010 Flwg to sales.1/28/2010 1/29/2010 Flwg to sales.1/29/2010 1/30/2010 Flwg to sales.1/30/2010 1/31/2010 Flwg to sales.1/31/2010 2/1/2010 Flwg to sales.2/1/2010 2/2/2010 Flwg to sales.2/2/2010 2/3/2010 Flwg to sales. FINAL REPORT.
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 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 whether 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 4696.00 - 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 71-5 Interval 5

3 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

1.0 EXECUTIVE SUMMARY

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 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 of 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 tons 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 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 71-5 Interval 5

4 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

2.0 WELL INFORMATION

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 71-5 Interval 5

5 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

3.0 PUMPING SCHEDULE

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 71-5 Interval 5

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 Sand 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 71-5 Interval 5

7 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

4.0 ACTUAL STAGE SUMMARY

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 8.91 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 71-5 Interval 5

8 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

5.0 PERFORMANCE HIGHLIGHTS

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 bpm

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 71-5 Interval 5

9 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

6.0 ATTACHMENTS

6.1 Test Lines

1/19/2010

11:08 11:10 11:12 11:14 11:16 11:18 1/19/201011:20

Time

0

1000

2000

3000

4000

5000

6000

7000

8000

9000

Treating Pressure (psig)
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 5

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

1 2 3 4 5 6 7 8 9 10 11

1

Local Event Log

1

Intersection

ISIP 12:31:58

TP

3415
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 5

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

1 2 3 4 5 6 7 8 9 10 11
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

1 2 3 4 5 6 7 8 9 10 11
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

1 2 3 4 5 6 7 8 9 10 11
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 5

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

Net Calc'd BH Pres (psi) A BH Proppant Conc (lb/gal) B Slope of Net Pressure (psi/min) C B

11

10

3 4 5 6 7 8 9

 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 whether 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 6

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 3870.00 - 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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

3 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

1.0 EXECUTIVE SUMMARY

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).

• 6343 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 tons of CO2 used to cool down, and 142 tons pumped downhole. 

The total 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 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 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 71-5 Interval 6

4 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

2.0 WELL INFORMATION

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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

5 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

3.0 PUMPING SCHEDULE

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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

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 2 3870.00 - 4000.00 ft

Stage 

Number

Description Sur CO2 Liq 

Rate Begin

bpm

Sur CO2 

Mass

ton

2 - 1 Breakdown

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 ppg 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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

7 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

4.0 ACTUAL STAGE SUMMARY

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 Volume

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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

8 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

5.0 PERFORMANCE HIGHLIGHTS

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.
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

9 

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 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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

10 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

6.0 ATTACHMENTS

6.1 Pressure Test 

1/19/2010

16:34 16:36 16:38 16:40 1/19/201016:42

Time

0

1000

2000

3000

4000

5000

6000

7000

8000

9000

Treating Pressure (psig)
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

11 

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

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

2 3 4 5 6 7 8 9 10 11

2

Local Event Log

2

Intersection

ISIP 17:22:29

TP

2460
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

12 

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

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

2 3 4 5 6 7 8 9 10 11
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

13 

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

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

2 3 4 5 6 7 8 9 10 11
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

14 

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

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

2 3 4 5 6 7 8 9 10 11
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 6

15 

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 = 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

Net Calc'd BH Pres (psi) A BH Proppant Conc (lb/gal) B Slope of Net Pressure (psi/min) C B

11

10

9

3 4 5 6 7 8

 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 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 whether 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 7

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 3494.00 - 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 71-5 Interval 7

3 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

1.0 EXECUTIVE SUMMARY

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 69.78 min.

The proposed treatment 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 actually 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 treating rate was 37.23 bpm and average WH pressure was 2857 psi.

There was 10 tons of CO2 used to cool down and 312 tons 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, 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 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 71-5 Interval 7

4 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

2.0 WELL INFORMATION

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 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

spf

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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 7

5 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

3.0 PUMPING SCHEDULE

3.1 Designed Pumping 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 Frac 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 13.33 11997 16.3

3 - 11 Flush Treated 4% 

KCL Water

5615 0.00 0.00 40.0

Total 29390 141990
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 7

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 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 Schedule 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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 7

7 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

4.0 ACTUAL STAGE SUMMARY

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

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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 7

8 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

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
SANDRIDGE ENERGY INC 

WEST RANCH SOUTH 71-5 Interval 7

9 

Created: October 25, 2012 at 12:48 PM

INSITE for Stimulation V. 3.4.0 (IFS v3.4.0)

5.0 PERFORMANCE HIGHLIGHTS

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 Description 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 bpm 

-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 27103 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 ATTACHMENTS

6.1 Pressure Test 

1/20/2010

08:30 08:35 08:40 1/20/201008:45

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

2 3 4 5 6 7 8 9 10 11

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

2 3 4 5 6 7 8 9 10 11
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

2 3 4 5 6 7 8 9 10 11
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

2 3 4 5 6 7 8 9 10 11
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

Net Calc'd BH Pres (psi) A BH Proppant Conc (lb/gal) B Slope of Net Pressure (psi/min) C B

11

10

3 4 5 6 7 8 9

 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

Liner Top Depth 0.5 - 2 SPF

7.000

MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services

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

199.2 198.0

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 4% Crystalline KCl 3,726 30.0

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

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
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 4% Crystalline KCl 3,726 30.0

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

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
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. This 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 recover 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) 813-6420 
Customer 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 Description / 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 

11:57am 5152 29 52 239 2,242 Sweep BBLS

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

Base Fluid 30,576 gals

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-1
BLENDER CHEMICALS

60 70 80 90 100 110 120 130 140 

TIME (min)

0123456789

10

Real-Time SUPER FOAM GPT (gal/1000 gal)Real-Time SUPER NE 100 GPT (gal/1000 gal)

Real-Time OBReal-Time AC

MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009
DENSITY PLOTS

70 80 90 100 110 120 130 

TIME (min)

01234567

BLENDER DENSITY (lb/gal)

Real-Time BLENDER DENSITY (lb/gal) Real-Time IN

MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009
BOTTOM HOLE QUALITY PL

60 70 80 90 100 110 120 130 140 

TIME (min)

005

10

1020153020402550306035704080459050

100

Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)

Real-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009
HYDRATION CHEMICALS

60 70 80 90 100 110 120 130 140 

TIME (min)

02468

101214161820

LSG GPT (gal/1000 gal)

Real-Time LSG GPT (gal/1000 gal) Real-Time SU

MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009
WEST RANCH SOUTH 71-5 ST

0 10 20 30 40 50 60 70 80 90 100 110 120 130 

TIME (min)

00

1000

5

2000

10

3000

15

4000

20

5000

25

6000

30

7000

35

8000

40

9000

45

10000

50

Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)

Real-Time FOReal-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009
Net Pressure vs Time

1 10 100 

Time (min)

10

100

1000

10000

Net Pressure (psi)

Measured Net Pressure (psi) BH Conc. (lbm

MWell - MWELL WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009
BHTP & SP WEST RANCH SOUTH 7

0 10 20 30 40 50 60 70 80 90 100 110 120 130 

Time (min)

0

100020003000400050006000700080009000

100001100012000

Pressure (psi)

Measured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)

Measured SurfBH Conc. (lbmMeasured Surf

MWell - MWELL WEST RANCH SOUTH 71-5 STG.1 - 12/22/2009
CUSTOMER WELL NAME DATE FIELD RECIEPT # FLUID TECH

SANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX

1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th s

 Water bbls. Per stges.>> 

SYSTEM:

Chemicals BEG. ENDING 

LSG-1 4000 3054 946 

OB/OB-2 500 460 40 

ACTIVATOR 201 179 22 

SUPER FOAM 1319 1006 313 

SUPER 100 NE 1780 1446 334 

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 

0 0 0 0 

Comments :
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

oversize <.1% Yes/No Yes

sieve analysis meet fines<1%

specifications? Attach all. Yes

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

0 fines

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

0.8 1.60 Total 

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 

0.09 0.18

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

pH pass fail

Pan

Total wt. Gram

pass

Total wt. Gram

Turbidity

pH pass

50.0 99.94

fail

0.8 1.60 50

pass fail

0 fines

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

specifications? Attach all. insize>90% Yes

Does the manufacturer's Yes/No Yes

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

50 grams of sample
Total Variance: 1.38% 

DATE: FLUID TECH:FIELD RECEIPT NO:

2 3 4 5 6 7 8 9 10 

PLANNED FLOW 

PROPOSED START HOSES END TOTAL LOSSES PUMPED VOLUME METER 

VOLUME LOADED USED DOWNHOLE FOR FLUID MEASURED 

PUMPED VOLUME 

877 4000 3990 3054 946 10 936 946 

35 500 500 460 40 0 40 40 12 201 200 179 22 1 21 22 

280 1319 1315 1006 313 4 309 313 292 1780 1780 1446 334 0 334 334 

13 14 

1

CUSTOMER:

SUPER FOAMLSG-1OB/OB-2ACTIVATORSUPER 100 NE

PROPPANT (lbs)

PRODUCT

SANDRIDGE

PRODUCT VARIANCE CALCULATIONS

CHEMICALS

12/22/2009

LEASE NAME & WELL NO: WEST RANCH SOUTH 71-5

MEASURED VOLUMES

CHEM-ADD OPERATOR:

15 16 17 18 19

PROPPANT TYPE S.G. PRE-JOB AMOUNT ON POST-JOB AMOUNT 

20/40 TLC 2.6520/40 SLC 2.65100 MESH 2.640/70 TLC 2.65CLEAN VOLUME 

Comments:

28

DOWNHOLE VOLUME

4,619.0

FLOW METER SLURRY 

10,514

SLURRY VOLUME (bbls)

29

25# LINEAR GEL

4,841

BASE FLUID DESCRIPTION BEGINNING VOLUME AFTER LOADING

DENSIO

TOT

26

4,841.0

SPILLAGE

42,000

30 40

22

LOCATION DOWNHOLE IN SAND KING (est.) (est.on the ground)

23 25

TOTAL SLURRY

15,300 4,841

CLEAN VOLUME (bbls)

PROPPANT VOLUME

21

FLOW METE

4,46

PUMPED 

15,355

24

46,840

ENDING VOLUME

168,200216,080
Pag

DATE:CUSTOMER:Tank/Transport No. 1 2 3 4 5 6 7 8 9 10 11 12 Water Quality Date filled: City Well 

Clarity, color, odor CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR Sample Temperature, (F) 60 60 60 60 60 60 60 60 60 60 60 60 Specific gravity 1.010 1.010 1.000 1.010 1.010 1.010 1.010 1.000 1.000 1.001 1.001 1.010 

Initial pH 6.8 6.9 7 7 7 6.8 7 7 7 6.9 7.000 7.000 Iron (Fe++/Fe+++) ppm 0 00000000000Reducing Agent (Yes or No)Sulfate, ppm <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 Chloride, ppm 9000 9000 200 9000 9000 9000 9000 200 200 800 9000 9000 Calcium, ppmMagnesium, ppmBF-7L Precipitate > > > > >Bacteria 

 Aerobic: No. per ml/time / / / / / / / / / / / /  Anaerobic: No. per ml/time / / / / / / / / / / / / 

Base Gel Quality Use additional copies of this form for each series of tests @ 2Name of product system mixed # LINEAR GEL

Gellant loading (lbs/1000 gal.) 6.25GPTFluid sampling location PILOTSampling time 5AMSample Temperature, (F) 60pH 7

3 min. 21

Fann reading 9 min. 25

@ 300 rpm 30 min. 28

60 min. 30

X-Link Vortex Closure, min:secX-Link Crown, min:secX-Link pHStageViscosity (cp)pHXL time @ blender, sec.Sample TemperatureTime fluid pumped

Tested by:

Tanks Note: Use additional copies of this report for testing additional material lots or tanks. This job will be: Gelled on-the-fly 

SANDRIDGE LEASE 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 71-5

This test data is considered to be a minimum standard. Additional testing or documentation may be required by the customer or for frac quality assurance. Data recorded electronically with Engineering approved msubstituted for applicable portions of this form. This testing data is considered to be the minimum needed for the well file.

Biocide added before H2O?

Field Pilot Test Batch Mixed Gel Quality Test

Frac Fluid Quality (These measurements are made as the job is pumped)
Pag

DATE:CUSTOMER:Tank/Transport No. 17 18 19 20 21 22 23 24 25 26 27 28 Water Quality Date filled: City Well 

Clarity, color, odor CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR Sample Temperature, (F) 60 60 60 60 60 60 60 60 60 60 60 60 Specific gravity 1.002 1.002 1.000 1.001 1.002 1.001 1.200 1.010 1.001 1.001 1.010 1.010 

Initial pH 6.8 6.9 7 7 7 6.8 7 7 7 6.9 7.000 7.000 Iron (Fe++/Fe+++) ppm 0 00000000000Reducing Agent (Yes or No)Sulfate, ppm <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 <200 Chloride, ppm 1000 1000 200 800 1000 800 150000 9000 800 800 9000 9000 Calcium, ppmMagnesium, ppmBF-7L Precipitate > > > > >Bacteria 

 Aerobic: No. per ml/time / / / / / / / / / / / /  Anaerobic: No. per ml/time / / / / / / / / / / / / 

Base Gel Quality Use additional copies of this form for each series of tests @ 2Name of product system mixed # LINEAR GEL

Gellant loading (lbs/1000 gal.) 6.25GPTFluid sampling location PILOTSampling time 5AMSample Temperature, (F) 60pH 7

3 min. 21

Fann reading 9 min. 25

@ 300 rpm 30 min. 28

60 min. 30

X-Link Vortex Closure, min:secX-Link Crown, min:secX-Link pHStageViscosity (cp)pHXL time @ blender, sec.Sample TemperatureTime fluid pumped

Tested by: 

Date Biocide Added: Date Biocide Added: Biocide added before H2O?

Field Pilot Test Batch Mixed Gel Quality Test

Frac Fluid Quality (These measurements are made as the job is pumped)

Tanks Note: Use additional copies of this report for testing additional material lots or tanks. This job will be: Gelled on-the-fly 

This test data is considered to be a minimum standard. Additional testing or documentation may be required by the customer or for frac quality assurance. Data recorded electronically with Engineering approved msubstituted 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 71-5
Pump Schedule

Customer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.1Formation: 1ST CABALLOSFluid Type: 25# LIN/30 Q

STAGE Clean Foam BH SAND BH SAND BLENDER BLENDER PROP PROP SLURRY CLEAN CO2 N2 CLEAN SLURRY SLU

DESCRIPTION Volume CONC CONC CONC CONC TOTAL TOTAL RATE RATE RATE RATE VOLUME VOLUME VO

Gallons BEGIN END BEGIN END stage cum bpm bpm bpm scfm bbls bbls c

BD/FET 10000 0.00 0.00 0.00 0.00 0 0 50.0 50.0 0.0 238.1 238.1 23

PAD 25000 0.00 0.00 0.00 0.00 0 0 56.0 49.0 24.0 416.7 416.7 65

.5# 100 MESH 8000 0.50 0.50 0.71 0.71 4000 4000 56.5 47.9 23.4 133.3 137.6 79

SWEEP 15000 0.00 0.00 0.00 0.00 0 4000 56.0 49.0 24.0 250.0 250.0 10

.75# 100 MESH 8000 0.75 0.75 1.07 1.07 6000 10000 56.8 47.4 23.2 133.3 139.8 11

SWEEP 15000 0.00 0.00 0.00 0.00 0 10000 56.0 49.0 24.0 250.0 250.0 14

1# 40/70 TLC 8000 1.00 1.00 1.43 1.43 8000 18000 57.1 46.9 22.9 133.3 142.0 15

SWEEP 15000 0.00 0.00 0.00 0.00 0 18000 56.0 49.0 24.0 250.0 250.0 18

1.25# 40/70 TLC 8000 1.25 1.25 1.79 1.79 10000 28000 57.3 46.4 22.6 133.3 144.2 19

SWEEP 15000 0.00 0.00 0.00 0.00 0 28000 56.0 49.0 24.0 250.0 250.0 22

1.5# 40/70 TLC 8000 1.50 1.50 2.14 2.14 12000 40000 57.6 45.9 22.4 133.3 146.4 23

SWEEP 15000 0.00 0.00 0.00 0.00 0 40000 56.0 49.0 24.0 250.0 250.0 26

1.5# 40/70 TLC 8000 1.50 1.50 2.14 2.14 12000 52000 57.6 45.9 22.4 133.3 146.4 27

SWEEP 15000 0.00 0.00 0.00 0.00 0 52000 56.0 49.0 24.0 250.0 250.0 30

1# 20/40 TLC 10000 1.00 1.00 1.43 1.43 10000 62000 57.1 46.9 22.9 166.7 177.5 31

2# 20/40 TLC 10000 2.00 2.00 2.86 2.86 20000 82000 58.0 44.9 21.9 166.7 188.4 33

3# 20/40 TLC 8000 3.00 3.00 4.29 4.29 24000 106000 58.9 43.1 21.0 133.3 159.4 35

4# 20/40 TLC 6000 4.00 4.00 5.71 5.71 24000 130000 59.8 41.4 20.2 100.0 126.1 36

4# 20/40 SLC 3500 4.00 4.00 5.71 5.71 14000 144000 59.7 41.4 20.2 58.3 73.7 37

FLUSH 13400 0.00 0.00 0.00 0.00 0 144000 80.0 70.0 0.0 319.0 319.0 40

Design Totals --> 223900 144000 0 3898.8 4055.2 Actual Totals -->

Depths (ft) # of Perfs Displacement (bbls) Pump Via 

Top Perf 8360 100 Tubing Casing

Bottom Perf 8630 Casing 319.85 Blen

N/A Annulus

Flu

O.D. (in.) Weight (lbs/ft) Bbls/ft I.D. (in.)

Casing 7 0.03826 6.276 Flush (bbls) HydraTubing Top 319.9

Annulus Bottom 330.2

26
Superior Well Services

Additive Schedule

Customer Name: SANDRIDGE 12/22/2009Well Name: WEST RANCH 71-5 STG.1 Formation: 1ST CABALLOS

Additive: LSG-1(GEL) Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 6.25 109.38 12.08 12.60 13.13 13.65 14.18 109.38

0.71 5600 6.25 35.00 11.71 12.21 12.71 13.23 13.73 144.380.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 210.001.07 5600 6.25 35.00 11.52 12.02 12.52 13.02 13.52 245.000.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 310.631.43 5600 6.25 35.00 11.34 11.84 12.31 12.81 13.31 345.630.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 411.251.79 5600 6.25 35.00 11.16 11.66 12.13 12.63 13.10 446.250.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 511.882.14 5600 6.25 35.00 11.00 11.47 11.94 12.44 12.92 546.880.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 612.502.14 5600 6.25 35.00 11.00 11.47 11.94 12.44 12.92 647.500.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 713.131.43 7000 6.25 43.75 11.34 11.84 12.31 12.81 13.31 756.88

2.86 7000 6.25 43.75 10.68 11.16 11.60 12.08 12.55 800.634.29 5600 6.25 35.00 10.11 10.55 10.97 11.42 11.87 835.635.71 4200 6.25 26.25 9.58 10.00 10.42 10.84 11.24 861.885.71 2450 6.25 15.31 9.56 9.98 10.40 10.82 11.21 877.190.00 13400 0.00 0.00 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 877.19

877.19

Additive: ACTIVATOR Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.71 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.07 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.79 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 7000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.86 7000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.004.29 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 4200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 2450 5.00 12.25 7.64 7.98 8.32 8.65 8.97 12.250.00 13400 0.00 0.00 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 12.25

12.25

Additive: SUPER NE Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 2.00 20.00 3.86 4.03 4.20 4.37 4.54 20.00

0.00 17500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 20.000.71 5600 2.00 11.20 3.75 3.91 4.07 4.23 4.39 31.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 52.201.07 5600 2.00 11.20 3.69 3.85 4.01 4.17 4.33 63.400.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 84.401.43 5600 2.00 11.20 3.63 3.79 3.94 4.10 4.26 95.600.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 116.60

1.79 5600 2.00 11.20 3.57 3.73 3.88 4.04 4.19 127.800.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 148.802.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 160.000.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 181.002.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 192.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 213.201.43 7000 2.00 14.00 3.63 3.79 3.94 4.10 4.26 227.20

2.86 7000 2.00 14.00 3.42 3.57 3.71 3.86 4.02 241.204.29 5600 2.00 11.20 3.23 3.38 3.51 3.65 3.80 252.405.71 4200 2.00 8.40 3.07 3.20 3.33 3.47 3.60 260.805.71 2450 2.00 4.90 3.06 3.19 3.33 3.46 3.59 265.700.00 13400 2.00 26.80 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 292.50

292.50

Fluid Technician: FOXField Receipt #: STG.1 Prepared By: SOTELO

Customer Name: SANDRIDGE 12/22/2009
Superior Well Services

Additive Schedule

Well Name: WEST RANCH 71-5 STG.1 Formation: 1ST CABALLOS

Additive: OB1/OB2 Planned Additive Rates (PPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 0.25 4.38 0.48 0.50 0.53 0.55 0.57 4.380.71 5600 0.25 1.40 0.47 0.49 0.51 0.53 0.55 5.780.00 10500 0.25 2.63 0.48 0.50 0.53 0.55 0.57 8.401.07 5600 0.25 1.40 0.46 0.48 0.50 0.52 0.54 9.800.00 10500 0.25 2.63 0.48 0.50 0.53 0.55 0.57 12.431.43 5600 0.25 1.40 0.45 0.47 0.49 0.51 0.53 13.830.00 10500 0.25 2.63 0.48 0.50 0.53 0.55 0.57 16.451.79 5600 0.25 1.40 0.45 0.47 0.49 0.51 0.52 17.850.00 10500 0.25 2.63 0.48 0.50 0.53 0.55 0.57 20.482.14 5600 0.25 1.40 0.44 0.46 0.48 0.50 0.52 21.880.00 10500 0.25 2.63 0.48 0.50 0.53 0.55 0.57 24.502.14 5600 0.25 1.40 0.44 0.46 0.48 0.50 0.52 25.900.00 10500 0.25 2.63 0.48 0.50 0.53 0.55 0.57 28.531.43 7000 0.25 1.75 0.45 0.47 0.49 0.51 0.53 30.28

2.86 7000 0.25 1.75 0.43 0.45 0.46 0.48 0.50 32.034.29 5600 0.25 1.40 0.40 0.42 0.44 0.46 0.47 33.435.71 4200 0.25 1.05 0.38 0.40 0.42 0.43 0.45 34.485.71 2450 0.25 0.61 0.38 0.40 0.42 0.43 0.45 35.090.00 13400 0.00 0.00 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 35.09

Additive: SUPER FOAM Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 2.00 35.00 3.86 4.03 4.20 4.37 4.54 35.000.71 5600 2.00 11.20 3.75 3.91 4.07 4.23 4.39 46.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 67.201.07 5600 2.00 11.20 3.69 3.85 4.01 4.17 4.33 78.400.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 99.401.43 5600 2.00 11.20 3.63 3.79 3.94 4.10 4.26 110.60

0.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 131.601.79 5600 2.00 11.20 3.57 3.73 3.88 4.04 4.19 142.800.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 163.802.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 175.000.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 196.002.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 207.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 228.201.43 7000 2.00 14.00 3.63 3.79 3.94 4.10 4.26 242.20

2.86 7000 2.00 14.00 3.42 3.57 3.71 3.86 4.02 256.204.29 5600 2.00 11.20 3.23 3.38 3.51 3.65 3.80 267.405.71 4200 2.00 8.40 3.07 3.20 3.33 3.47 3.60 275.805.71 2450 2.00 4.90 3.06 3.19 3.33 3.46 3.59 280.700.00 13400 0.00 0.00 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 280.70

Additive: Planned Additive Rates ()

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

Fluid Technician: FOXField Receipt #: STG.1 Prepared By: SOTELO
Step Down Diagnostic - Surf

0 10 20 30 40 

Rate (bpm)

0

200400600800

10001200140016001800

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. This 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 recover 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) 813-6420 
Customer 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 Description / 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 Blender

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 

4:02pm 5155 27 46 162 2,121 1.25 ppg 40/70 TLC BBLS

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

9:01pm 5126 27 60 317 4,247 Flush Fluid Description

Base Fluid 32,130 gals 

Waited for Blender to arrive from

( Comments ) 

due to Blender Augers. Proppant Description Volume Pumped (lbs)

Blender densometer did not work 100 mesh 

Odessa TX 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-1
DENSITY PLOTS

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 3

TIME (min)

01234567

BLENDER DENSITY (lb/gal)

Real-Time BLENDER DENSITY (lb/gal) Real-Time IN

MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009
BLENDER CHEMICALS

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 

TIME (min)

012345

SUPER FOAM GPT (gal/1000 gal)

Real-Time SUPER FOAM GPT (gal/1000 gal) Real-Time OB1

Real-Time ACT

MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009
WEST RANCH SOUTH 71-5 ST

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 32

TIME (min)

00

1000

5

2000

10

3000

15

4000

20

5000

25

6000

30

7000

35

8000

40

9000

45

10000

50

Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)

Real-Time FOReal-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009
HYDRATION CHEMICALS

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 32

TIME (min)

02468

101214161820

LSG GPT (gal/1000 gal)

Real-Time LSG GPT (gal/1000 gal) Real-Time SU

MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009
BOTTOM HOLE QUALITY PL

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 32

TIME (min)

005

10

1020153020402550306035704080459050

100

Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)

Real-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009
Net Pressure vs Time

1 10 100 

Time (min)

10

100

1000

10000

Net Pressure (psi)

Measured Net Pressure (psi) BH Conc. (lbm

MWell - MWELL WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009
BHTP & SP WEST RANCH SOUTH 7

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 

Time (min)

0

100020003000400050006000700080009000

10000

Pressure (psi)

Measured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)

Measured SurfBH Conc. (lbmMeasured Surf

MWell - MWELL WEST RANCH SOUTH 71-5 STG.2 - 12/23/2009
Step Down Diagnostic - Surf

0 10 20 30 40 

Rate (bpm)

0

100200300400500600700800

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 - 12/23/2009
Pump Schedule

Customer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.2Formation: 1ST CABALLOSFluid Type: 25# LIN/30 Q

STAGE Clean Foam BH SAND BH SAND BLENDER BLENDER PROP PROP SLURRY CLEAN CO2 N2 CLEAN SLURRY SLU

DESCRIPTION Volume CONC CONC CONC CONC TOTAL TOTAL RATE RATE RATE RATE VOLUME VOLUME VO

Gallons BEGIN END BEGIN END stage cum bpm bpm bpm scfm bbls bbls c

BD/FET 10000 0.00 0.00 0.00 0.00 0 0 50.0 50.0 0.0 238.1 238.1 23

PAD 20000 0.00 0.00 0.00 0.00 0 0 45.5 45.5 20.0 333.3 333.3 57

.5# 100 MESH 8000 0.50 0.50 0.71 0.71 4000 4000 45.9 44.5 20.0 133.3 137.6 70

SWEEP 15000 0.00 0.00 0.00 0.00 0 4000 45.5 45.5 20.0 250.0 250.0 95

.75# 100 MESH 8000 0.75 0.75 1.07 1.07 6000 10000 46.1 44.0 20.0 133.3 139.8 10

SWEEP 15000 0.00 0.00 0.00 0.00 0 10000 45.5 45.5 20.0 250.0 250.0 13

1# 40/70 TLC 8000 1.00 1.00 1.43 1.43 8000 18000 46.3 43.5 19.0 133.3 142.0 14

SWEEP 15000 0.00 0.00 0.00 0.00 0 18000 45.5 45.5 20.0 250.0 250.0 17

1.25# 40/70 TLC 8000 1.25 1.25 1.79 1.79 10000 28000 46.5 43.0 19.0 133.3 144.2 18

SWEEP 15000 0.00 0.00 0.00 0.00 0 28000 45.5 45.5 20.0 250.0 250.0 21

1.5# 40/70 TLC 8000 1.50 1.50 2.14 2.14 12000 40000 46.7 42.6 19.0 133.3 146.4 22

SWEEP 15000 0.00 0.00 0.00 0.00 0 40000 45.5 45.5 20.0 250.0 250.0 25

1.5# 40/70 TLC 8000 1.50 1.50 2.14 2.14 12000 52000 46.7 42.6 19.0 133.3 146.4 26

SWEEP 15000 0.00 0.00 0.00 0.00 0 52000 45.5 45.5 20.0 250.0 250.0 29

1# 20/40 TLC 3500 1.00 1.00 1.43 1.43 3500 55500 46.3 43.5 19.0 58.3 62.1 292# 20/40 TLC 3500 2.00 2.00 2.86 2.86 7000 62500 47.1 41.7 19.0 58.3 65.9 30

3# 20/40 TLC 2500 3.00 3.00 4.29 4.29 7500 70000 47.8 40.0 18.0 41.7 49.8 314# 20/40 TLC 2500 4.00 4.00 5.71 5.71 10000 80000 48.5 38.5 17.0 41.7 52.5 31

4# 20/40 SLC 2500 4.00 4.00 5.71 5.71 10000 90000 48.5 38.4 17.0 41.7 52.6 32

FLUSH 13230 0.00 0.00 0.00 0.00 0 90000 50.0 65.0 0.0 315.0 315.0 35

Design Totals --> 195730 90000 0 3428.1 3525.9 Actual Totals -->

Depths (ft) # of Perfs Displacement (bbls) Pump Via 

Top Perf 8255 45 Tubing Casing

Bottom Perf 8270 Casing 315.84 Blen

N/A Annulus

Flu

O.D. (in.) Weight (lbs/ft) Bbls/ft I.D. (in.)

Casing 7 0.03826 6.276 Flush (bbls) HydraTubing Top 315.8

Annulus Bottom 316.4

26
Superior Well Services

Additive Schedule

Customer Name: SANDRIDGE 12/22/2009Well Name: WEST RANCH 71-5 STG.2 Formation: 1ST CABALLOS

Additive: LSG-1(GEL) Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 6.25 87.50 12.08 12.60 13.13 13.65 14.18 87.50

0.71 5600 6.25 35.00 11.71 12.21 12.71 13.23 13.73 122.500.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 188.131.07 5600 6.25 35.00 11.52 12.02 12.52 13.02 13.52 223.130.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 288.751.43 5600 6.25 35.00 11.34 11.84 12.31 12.81 13.31 323.750.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 389.381.79 5600 6.25 35.00 11.16 11.66 12.13 12.63 13.10 424.380.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 490.002.14 5600 6.25 35.00 11.00 11.47 11.94 12.44 12.92 525.000.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 590.632.14 5600 6.25 35.00 11.00 11.47 11.94 12.44 12.92 625.630.00 10500 6.25 65.63 12.08 12.60 13.13 13.65 14.18 691.251.43 2450 6.25 15.31 11.34 11.84 12.31 12.81 13.31 706.56

2.86 2450 6.25 15.31 10.68 11.16 11.60 12.08 12.55 721.884.29 1750 6.25 10.94 10.11 10.55 10.97 11.42 11.87 732.815.71 1750 6.25 10.94 9.58 10.00 10.42 10.84 11.24 743.755.71 1750 6.25 10.94 9.56 9.98 10.40 10.82 11.21 754.690.00 13230 0.00 0.00 0.00 0.00 0.00 0.00 0.00 754.69

754.69

Additive: ACTIVATOR Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.71 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.07 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.79 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 2450 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.86 2450 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.004.29 1750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 1750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 1750 5.00 8.75 7.64 7.98 8.32 8.65 8.97 8.750.00 13230 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.75

8.75

Additive: SUPER NE Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 2.00 20.00 3.86 4.03 4.20 4.37 4.54 20.00

0.00 14000 2.00 28.00 3.86 4.03 4.20 4.37 4.54 48.000.71 5600 2.00 11.20 3.75 3.91 4.07 4.23 4.39 59.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 80.201.07 5600 2.00 11.20 3.69 3.85 4.01 4.17 4.33 91.400.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 112.40

1.43 5600 2.00 11.20 3.63 3.79 3.94 4.10 4.26 123.600.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 144.601.79 5600 2.00 11.20 3.57 3.73 3.88 4.04 4.19 155.800.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 176.802.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 188.000.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 209.002.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 220.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 241.201.43 2450 2.00 4.90 3.63 3.79 3.94 4.10 4.26 246.102.86 2450 2.00 4.90 3.42 3.57 3.71 3.86 4.02 251.004.29 1750 2.00 3.50 3.23 3.38 3.51 3.65 3.80 254.505.71 1750 2.00 3.50 3.07 3.20 3.33 3.47 3.60 258.005.71 1750 2.00 3.50 3.06 3.19 3.33 3.46 3.59 261.500.00 13230 2.00 26.46 3.86 4.03 4.20 4.37 4.54 287.96

287.96

Fluid Technician: FOXField Receipt #: STG.2 Prepared By: SOTELO

Customer Name: SANDRIDGE 12/22/2009
Superior Well Services

Additive Schedule

Well Name: WEST RANCH 71-5 STG.2 Formation: 1ST CABALLOS

Additive: OB1/OB2 Planned Additive Rates (PPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 0.50 7.00 0.97 1.01 1.05 1.09 1.13 7.000.71 5600 0.50 2.80 0.94 0.98 1.02 1.06 1.10 9.800.00 10500 0.50 5.25 0.97 1.01 1.05 1.09 1.13 15.051.07 5600 0.50 2.80 0.92 0.96 1.00 1.04 1.08 17.850.00 10500 0.50 5.25 0.97 1.01 1.05 1.09 1.13 23.101.43 5600 0.50 2.80 0.91 0.95 0.98 1.02 1.06 25.900.00 10500 0.50 5.25 0.97 1.01 1.05 1.09 1.13 31.151.79 5600 0.75 4.20 1.34 1.40 1.46 1.52 1.57 35.350.00 10500 0.75 7.88 1.45 1.51 1.58 1.64 1.70 43.232.14 5600 0.75 4.20 1.32 1.38 1.43 1.49 1.55 47.430.00 10500 0.75 7.88 1.45 1.51 1.58 1.64 1.70 55.302.14 5600 0.75 4.20 1.32 1.38 1.43 1.49 1.55 59.500.00 10500 0.75 7.88 1.45 1.51 1.58 1.64 1.70 67.381.43 2450 0.75 1.84 1.36 1.42 1.48 1.54 1.60 69.212.86 2450 1.25 3.06 2.14 2.23 2.32 2.42 2.51 72.284.29 1750 1.25 2.19 2.02 2.11 2.19 2.28 2.37 74.465.71 1750 1.25 2.19 1.92 2.00 2.08 2.17 2.25 76.655.71 1750 1.25 2.19 1.91 2.00 2.08 2.16 2.24 78.840.00 13230 0.00 0.00 0.00 0.00 0.00 0.00 0.00 78.84

Additive: SUPER FOAM Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 2.00 28.00 3.86 4.03 4.20 4.37 4.54 28.000.71 5600 2.00 11.20 3.75 3.91 4.07 4.23 4.39 39.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 60.201.07 5600 2.00 11.20 3.69 3.85 4.01 4.17 4.33 71.400.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 92.401.43 5600 2.00 11.20 3.63 3.79 3.94 4.10 4.26 103.60

0.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 124.601.79 5600 2.00 11.20 3.57 3.73 3.88 4.04 4.19 135.800.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 156.802.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 168.000.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 189.002.14 5600 2.00 11.20 3.52 3.67 3.82 3.98 4.13 200.200.00 10500 2.00 21.00 3.86 4.03 4.20 4.37 4.54 221.201.43 2450 2.00 4.90 3.63 3.79 3.94 4.10 4.26 226.102.86 2450 2.00 4.90 3.42 3.57 3.71 3.86 4.02 231.004.29 1750 2.00 3.50 3.23 3.38 3.51 3.65 3.80 234.505.71 1750 2.00 3.50 3.07 3.20 3.33 3.47 3.60 238.005.71 1750 2.00 3.50 3.06 3.19 3.33 3.46 3.59 241.500.00 13230 0.00 0.00 0.00 0.00 0.00 0.00 0.00 241.50

Additive: Planned Additive Rates ()

PPG VOLUME LOAD AMOUNT 46 BPM 48 BPM 50 BPM 52 BPM 54 BPM Actual GONE

Fluid Technician: FOXField Receipt #: STG.2 Prepared By: SOTELO
CUSTOMER WELL NAME DATE FIELD RECIEPT # FLUID TECH

SANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX

1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th s

 Water bbls. Per stges.>> 

SYSTEM:

Chemicals BEG. ENDING 

LSG-1 3054 2176 878 

OB/OB-2 460 380 80 

ACTIVATOR 179 150 29 

SUPER FOAM 1006 738 268 

SUPER 100 NE 1446 1155 291 

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 

0 0 0 0 

Comments :
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. This 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 recover 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) 813-6420 
Customer 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 

6:42am 3860 30 56 154 2,952 1.0 ppg 20/40 TLC BBLS

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 Description / 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 ) 

Base Fluid 31,836 gals 

Fluid Description

Linear Gel # 25 127,848 gals 

Volume Pumped (Gals)

Treatment Data

6:54am 3757 30 64 303 3,802 Flush Treating Fluid 1606 bbls 

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 bbls 
BLENDER CHEMICALS

30 40 50 60 70 80 9

TIME (min)

012345

SUPER FOAM GPT (gal/1000 gal)

Real-Time SUPER FOAM GPT (gal/1000 gal) Real-Time OB1

Real-Time ACT

MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009
HYDRATION CHEMICALS

0 10 20 30 40 50 60 70 80 

TIME (min)

02468

101214161820

LSG GPT (gal/1000 gal)

Real-Time LSG GPT (gal/1000 gal) Real-Time SU

MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009
DENSITY PLOTS

50 60 70 80 90 

TIME (min)

01234567

BLENDER DENSITY (lb/gal)

Real-Time BLENDER DENSITY (lb/gal) Real-Time IN

MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009
BOTTOM HOLE QUALITY PL

0 10 20 30 40 50 60 70 80 

TIME (min)

005

10

1020153020402550306035704080459050

100

Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)

Real-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009
WEST RANCH SOUTH 71-5 ST

0 10 20 30 40 50 60 70 80 

TIME (min)

00

1000

5

2000

10

3000

15

4000

20

5000

25

6000

30

7000

35

8000

40

9000

45

10000

50

Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)

Real-Time FOReal-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009
Net Pressure vs Time

0.1 1 10 

Time (min)

100

1000

10000

Net Pressure (psi)

Measured Net Pressure (psi) BH Conc. (lb

MWell - MWELL WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009
BHTP & SP WEST RANCH SOUTH 7

0 10 20 30 40 50 60 70 80 

Time (min)

0

100020003000400050006000700080009000

10000

Pressure (psi)

Measured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)

Measured SurfBH Conc. (lbmMeasured Surf

MWell - MWELL WEST RANCH SOUTH 71-5 STG.3 - 12/24/2009
CUSTOMER WELL NAME DATE FIELD RECIEPT # FLUID TECH

SANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX

1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th s

 Water bbls. Per stges.>> 

SYSTEM:

Chemicals BEG. ENDING 

LSG-1 2176 1365 811 

OB/OB-2 380 291 89 

ACTIVATOR 150 128 22 

SUPER FOAM 738 425 313 

SUPER 100 NE 1155 798 357 

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 

0 0 0 0 

Comments :
Step Down Diagnostic - Surf

0 10 20 30 40 

Rate (bpm)

0

4080

120160200240

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 - 12/24/2009
Pump Schedule

Customer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.3Formation: 1ST CABALLOSFluid Type: 25# LIN/30 Q

STAGE Clean Foam BH SAND BH SAND BLENDER BLENDER PROP PROP SLURRY CLEAN CO2 N2 CLEAN SLURRY SLU

DESCRIPTION Volume CONC CONC CONC CONC TOTAL TOTAL RATE RATE RATE RATE VOLUME VOLUME VO

Gallons BEGIN END BEGIN END stage cum bpm bpm bpm scfm bbls bbls c

BD/FET 10000 0.00 0.00 0.00 0.00 0 0 50.0 50.0 0.0 238.1 238.1 23

PAD 25000 0.00 0.00 0.00 0.00 0 0 56.0 56.0 25.0 416.7 416.7 65

.5# 100 MESH 8000 0.50 0.50 0.71 0.71 4000 4000 56.5 54.8 24.0 133.3 137.6 79

SWEEP 12500 0.00 0.00 0.00 0.00 0 4000 56.0 56.0 25.0 208.3 208.3 10

.75# 100 MESH 8000 0.75 0.75 1.07 1.07 6000 10000 56.8 54.2 24.0 133.3 139.8 11

SWEEP 12500 0.00 0.00 0.00 0.00 0 10000 56.0 56.0 25.0 208.3 208.3 13

1# 40/70 TLC 8000 1.00 1.00 1.43 1.43 8000 18000 57.0 53.6 24.0 133.3 142.0 14

SWEEP 12500 0.00 0.00 0.00 0.00 0 18000 56.0 56.0 25.0 208.3 208.3 16

1.25# 40/70 TLC 8000 1.25 1.25 1.79 1.79 10000 28000 57.3 53.0 23.0 133.3 144.2 18

SWEEP 12500 0.00 0.00 0.00 0.00 0 28000 56.0 56.0 25.0 208.3 208.3 20

1.5# 40/70 TLC 8000 1.50 1.50 2.14 2.14 12000 40000 57.5 52.4 23.0 133.3 146.4 21

SWEEP 12500 0.00 0.00 0.00 0.00 0 40000 56.0 56.0 25.0 208.3 208.3 24

1.5# 40/70 TLC 8000 1.50 1.50 2.14 2.14 12000 52000 57.5 52.4 23.0 133.3 146.4 25

SWEEP 12500 0.00 0.00 0.00 0.00 0 52000 56.0 56.0 25.0 208.3 208.3 27

1# 20/40 TLC 10000 1.00 1.00 1.43 1.43 10000 62000 57.0 53.6 24.0 166.7 177.5 29

2# 20/40 TLC 8500 2.00 2.00 2.86 2.86 17000 79000 58.0 51.3 23.0 141.7 160.1 30

3# 20/40 TLC 7500 3.00 3.00 4.29 4.29 22500 101500 58.9 49.3 22.0 125.0 149.4 32

4# 20/40 TLC 4500 4.00 4.00 5.71 5.71 18000 119500 59.7 47.4 21.0 75.0 94.5 33

4# 20/40 SLC 3000 4.00 4.00 5.71 5.71 12000 131500 59.7 47.3 21.0 50.0 63.2 34

FLUSH 12775 0.00 0.00 0.00 0.00 0 131500 50.0 80.0 0.0 304.2 304.2 37

Design Totals --> 204275 131500 0 3567.3 3710.1 Actual Totals -->

Depths (ft) # of Perfs Displacement (bbls) Pump Via 

Top Perf 7910 90 Tubing Casing

Bottom Perf 8140 Casing 302.64 Blen

N/A Annulus

Flu

O.D. (in.) Weight (lbs/ft) Bbls/ft I.D. (in.)

Casing 7 0.03826 6.276 Flush (bbls) Hydra

Tubing Top 302.6

Annulus Bottom 311.4

26
Superior Well Services

Additive Schedule

Customer Name: SANDRIDGE 12/24/2009Well Name: WEST RANCH 71-5 STG.3 Formation: 1ST CABALLOS

Additive: LSG-1(GEL) Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 6.25 109.38 13.39 13.91 14.44 14.96 15.49 109.38

0.71 5600 6.25 35.00 12.97 13.47 13.99 14.49 15.02 144.380.00 8750 6.25 54.69 13.39 13.91 14.44 14.96 15.49 199.061.07 5600 6.25 35.00 12.76 13.26 13.78 14.28 14.78 234.060.00 8750 6.25 54.69 13.39 13.91 14.44 14.96 15.49 288.751.43 5600 6.25 35.00 12.57 13.07 13.55 14.04 14.54 323.750.00 8750 6.25 54.69 13.39 13.91 14.44 14.96 15.49 378.441.79 5600 6.25 35.00 12.39 12.86 13.36 13.83 14.33 413.440.00 8750 6.25 54.69 13.39 13.91 14.44 14.96 15.49 468.132.14 5600 6.25 35.00 12.21 12.68 13.15 13.62 14.10 503.130.00 8750 6.25 54.69 13.39 13.91 14.44 14.96 15.49 557.812.14 5600 6.25 35.00 12.21 12.68 13.15 13.62 14.10 592.810.00 8750 6.25 54.69 13.39 13.91 14.44 14.96 15.49 647.501.43 7000 6.25 43.75 12.57 13.07 13.55 14.04 14.54 691.25

2.86 5950 6.25 37.19 11.84 12.31 12.78 13.23 13.70 728.444.29 5250 6.25 32.81 11.21 11.63 12.08 12.52 12.97 761.255.71 3150 6.25 19.69 10.63 11.03 11.45 11.87 12.29 780.945.71 2100 6.25 13.13 10.61 11.00 11.42 11.84 12.26 794.060.00 12775 0.00 0.00 0.00 0.00 0.00 0.00 0.00 794.06

794.06

Additive: ACTIVATOR Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.71 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 8750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.07 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 8750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 8750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.79 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 8750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 8750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 8750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 7000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.86 5950 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.004.29 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 3150 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 2100 5.00 10.50 8.48 8.80 9.14 9.47 9.81 10.500.00 12775 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.50

10.50

Additive: SUPER NE Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 2.00 20.00 4.28 4.45 4.62 4.79 4.96 20.00

0.00 17500 2.00 35.00 4.28 4.45 4.62 4.79 4.96 55.000.71 5600 2.00 11.20 4.15 4.31 4.48 4.64 4.80 66.200.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 83.701.07 5600 2.00 11.20 4.08 4.24 4.41 4.57 4.73 94.900.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 112.40

1.43 5600 2.00 11.20 4.02 4.18 4.33 4.49 4.65 123.600.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 141.101.79 5600 2.00 11.20 3.96 4.12 4.28 4.43 4.59 152.300.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 169.802.14 5600 2.00 11.20 3.91 4.06 4.21 4.36 4.51 181.000.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 198.502.14 5600 2.00 11.20 3.91 4.06 4.21 4.36 4.51 209.700.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 227.201.43 7000 2.00 14.00 4.02 4.18 4.33 4.49 4.65 241.20

2.86 5950 2.00 11.90 3.79 3.94 4.09 4.23 4.38 253.104.29 5250 2.00 10.50 3.59 3.72 3.86 4.01 4.15 263.605.71 3150 2.00 6.30 3.40 3.53 3.66 3.80 3.93 269.905.71 2100 2.00 4.20 3.39 3.52 3.65 3.79 3.92 274.100.00 12775 2.00 25.55 4.28 4.45 4.62 4.79 4.96 299.65

299.65

Fluid Technician: FOXField Receipt #: STG.3 Prepared By: SOTELO

Customer Name: SANDRIDGE 12/24/2009
Superior Well Services

Additive Schedule

Well Name: WEST RANCH 71-5 STG.3 Formation: 1ST CABALLOS

Additive: OB1/OB2 Planned Additive Rates (PPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 0.50 8.75 1.07 1.11 1.16 1.20 1.24 8.750.71 5600 0.50 2.80 1.04 1.08 1.12 1.16 1.20 11.550.00 8750 0.50 4.38 1.07 1.11 1.16 1.20 1.24 15.931.07 5600 0.50 2.80 1.02 1.06 1.10 1.14 1.18 18.730.00 8750 0.50 4.38 1.07 1.11 1.16 1.20 1.24 23.101.43 5600 0.50 2.80 1.01 1.05 1.08 1.12 1.16 25.900.00 8750 0.50 4.38 1.07 1.11 1.16 1.20 1.24 30.281.79 5600 0.75 4.20 1.49 1.54 1.60 1.66 1.72 34.480.00 8750 0.75 6.56 1.61 1.67 1.73 1.80 1.86 41.042.14 5600 0.75 4.20 1.46 1.52 1.58 1.63 1.69 45.240.00 8750 0.75 6.56 1.61 1.67 1.73 1.80 1.86 51.802.14 5600 0.75 4.20 1.46 1.52 1.58 1.63 1.69 56.000.00 8750 0.75 6.56 1.61 1.67 1.73 1.80 1.86 62.561.43 7000 0.75 5.25 1.51 1.57 1.63 1.69 1.75 67.812.86 5950 1.25 7.44 2.37 2.46 2.56 2.65 2.74 75.254.29 5250 1.25 6.56 2.24 2.33 2.42 2.50 2.59 81.815.71 3150 1.25 3.94 2.13 2.21 2.29 2.37 2.46 85.755.71 2100 1.25 2.63 2.12 2.20 2.28 2.37 2.45 88.380.00 12775 0.00 0.00 0.00 0.00 0.00 0.00 0.00 88.38

Additive: SUPER FOAM Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 17500 2.00 35.00 4.28 4.45 4.62 4.79 4.96 35.000.71 5600 2.00 11.20 4.15 4.31 4.48 4.64 4.80 46.200.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 63.701.07 5600 2.00 11.20 4.08 4.24 4.41 4.57 4.73 74.900.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 92.401.43 5600 2.00 11.20 4.02 4.18 4.33 4.49 4.65 103.60

0.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 121.101.79 5600 2.00 11.20 3.96 4.12 4.28 4.43 4.59 132.300.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 149.802.14 5600 2.00 11.20 3.91 4.06 4.21 4.36 4.51 161.000.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 178.502.14 5600 2.00 11.20 3.91 4.06 4.21 4.36 4.51 189.700.00 8750 2.00 17.50 4.28 4.45 4.62 4.79 4.96 207.201.43 7000 2.00 14.00 4.02 4.18 4.33 4.49 4.65 221.20

2.86 5950 2.00 11.90 3.79 3.94 4.09 4.23 4.38 233.104.29 5250 2.00 10.50 3.59 3.72 3.86 4.01 4.15 243.605.71 3150 2.00 6.30 3.40 3.53 3.66 3.80 3.93 249.905.71 2100 2.00 4.20 3.39 3.52 3.65 3.79 3.92 254.100.00 12775 0.00 0.00 0.00 0.00 0.00 0.00 0.00 254.10

Additive: Planned Additive Rates ()

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

Fluid Technician: FOXField Receipt #: STG.3 Prepared 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. This 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 recover 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) 813-6420 
Customer 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 

5:13pm 5258 30 56 50 2,551 1.0 ppg 20/40 TLC BBLS

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 Description / 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 ) 

Base Fluid 26,880 gals 

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 bbls 
BOTTOM HOLE QUALITY PL

0 10 20 30 40 50 60 70 80 90 100 110 120 130 

TIME (min)

005

10

1020153020402550306035704080459050

100

Real-Time BLENDER DENSITY (lb/gal)Real-Time BOTTOM HOLE QUALITY (%)

Real-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009
DENSITY PLOTS

80 90 100 110 120 130 

TIME (min)

01234567

BLENDER DENSITY (lb/gal)

Real-Time BLENDER DENSITY (lb/gal) Real-Time IN

MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009
HYDRATION CHEMICALS

0 10 20 30 40 50 60 70 80 90 100 110 120 130 

TIME (min)

02468

101214161820

LSG GPT (gal/1000 gal)

Real-Time LSG GPT (gal/1000 gal) Real-Time SU

MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009
BLENDER CHEMICALS

50 60 70 80 90 100 110 120 130 140 

TIME (min)

012345

SUPER FOAM GPT (gal/1000 gal)

Real-Time SUPER FOAM GPT (gal/1000 gal) Real-Time OB1

Real-Time ACT

MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009
WEST RANCH SOUTH 71-5 ST

0 10 20 30 40 50 60 70 80 90 100 110 120 130 

TIME (min)

00

1000

5

2000

10

3000

15

4000

20

5000

25

6000

30

7000

35

8000

40

9000

45

10000

50

Real-Time PRESSURE (psi)Real-Time BLENDER DENSITY (lb/gal)Real-Time ANNULUS PRESSURE (psi)

Real-Time FOReal-Time SLReal-Time CO

MView - MVIEW WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009
Net Pressure vs Time

1 10 100 

Time (min)

100

1000

10000

Net Pressure (psi)

Measured Net Pressure (psi) BH Conc. (lb

MWell - MWELL WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009
BHTP & SP WEST RANCH SOUTH 7

0 10 20 30 40 50 60 70 80 90 100 110 120 130 

Time (min)

0

100020003000400050006000700080009000

10000

Pressure (psi)

Measured Surface Pres. (psi)Calc BHTP from Surface Pressure (psi)

Measured SurfBH Conc. (lbmMeasured Surf

MWell - MWELL WEST RANCH SOUTH 71-5 STG.4 - 12/24/2009
CUSTOMER WELL NAME DATE FIELD RECIEPT # FLUID TECH

SANDRIDGE WEST RANCH SOUTH 71-5 12/22/09 FOX

1st stge 2nd stge 3rd stge 4th stge 5th stge 6th stge 7th stge 8th stge 9th stge 10th stge 11th s

 Water bbls. Per stges.>> 

SYSTEM:

Chemicals BEG. ENDING 

LSG-1 4000 545 946 878 811 820 

OB/OB-2 500 216 40 80 89 75 

ACTIVATOR 201 114 22 29 22 14 

SUPER FOAM 1319 201 313 268 313 224 

SUPER 100 NE 1780 559 334 291 357 239 

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 

0 0 0 0 

Comments :
DATE:

FIELD RECEIPT #:

FLUID TECH:

Net Usage

3455

284

87

1118

1221

0

0

0

0

0

0

0

0

12/22/2009 SANDRIDGE

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 Sheet
Total Variance: 1.11% 

DATE: FLUID TECH:FIELD RECEIPT NO:

2 3 4 5 6 7 8 9 10 

PLANNED FLOW 

PROPOSED START HOSES END TOTAL LOSSES PUMPED VOLUME METER 

VOLUME LOADED USED DOWNHOLE FOR FLUID MEASURED 

PUMPED VOLUME 

3093 4000 3990 545 3455 10 3445 3425 

277 500 500 216 284 0 284 284 

41 201 200 114 87 1 86 90 

1000 1319 1315 201 1118 4 1114 1120 1149 1780 1780 559 1221 0 1221 1221 

13 14 15 16 17 18 19 

SUPER 100 NE

PROPPANT (lbs)

PRODUCT VARIANCE CALCULATIONS

CHEMICALS

12/22/2009

LEASE NAME & WELL NO: WEST RANCH SOUTH 71-5

MEASURED VOLUMES

CHEM-ADD OPERATOR:

SANDRIDGE

PRODUCT

LSG-1OB/OB-2ACTIVATOR

1

CUSTOMER:

SUPER FOAM

PROPPANT TYPE S.G. PRE-JOB AMOUNT ON POST-JOB AMOUNT 

20/40 TLC 2.65 20/40 SLC 2.65 100 MESH 2.6 40/70 TLC 2.65 

CLEAN VOLUME Comments:

168,2

15,355

5,000

24

0 1,000

46,840

ENDING VOLUME

168,200 2,000

PROPPANT VOLUME

45,840

211,080

15,1

216,080

30

41,000

166,200

21 26

FLOW METE

00

SPILLAGE DENSIO

LOCATION DOWNHOLE

PUMPED 

IN SAND KING (est.)

46,8

23 25

TOTAL SLURRY

15,300 15,062

CLEAN VOLUME (bbls)

42,000

15,566.2

40

22

42,0

(est.on the ground)

0 211,0

1,000

TOT

BASE FLUID DESCRIPTION

15,062

BEGINNING VOLUME AFTER LOADING

28

297,920

DOWNHOLE VOLUME

FLOW METER SLURRY 

238

SLURRY VOLUME (bbls)

29

25# LINEAR GEL
Regression Analysis - Surface

0 1 2

3

4

Nolte G Time

20002100220023002400250026002700

Surface Pressure (psi)

Surface Pressure ISIP - G dP/dG

ISIP

TC

1A

1B

2A

2B

Pump Time (tp) 2.3244 (Closure Time (tc) 7.807 (Delta Closure Time (

∆tc) 5.4826 (

Surface ISIP (ISIP|s) 2596.1 (Surface Closure (Pc) 2239.5 (BH ISIP (ISIP|bh) 4762.7 (BH Closure (Pc) 4406.1 (Net Pressure (

∆p) 356.59 (

Stress Gradient 0.88123 (Efficiency* 0.562

Slope 1 -144.99Slope 2 -101.85Slope 3Slope 4

MinFrac - 12/24/2009
Step Down Diagnostic - Surf

0 10 20 30 40 

Rate (bpm)

0

100200300400500600700800900

1000

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 - 12/24/2009
Pump Schedule

Customer Name: SANDRIDGEWell Name: WEST RANCH 71-5 STG.4Formation: 1ST CABALLOSFluid Type: 25# LIN/30 Q

STAGE Clean Foam BH SAND BH SAND BLENDER BLENDER PROP PROP SLURRY CLEAN CO2 N2 CLEAN SLURRY SLU

DESCRIPTION Volume CONC CONC CONC CONC TOTAL TOTAL RATE RATE RATE RATE VOLUME VOLUME VO

Gallons BEGIN END BEGIN END stage cum bpm bpm bpm scfm bbls bbls c

BD/FET 10000 0.00 0.00 0.00 0.00 0 0 50.0 50.0 0.0 238.1 238.1 23

PAD 20000 0.00 0.00 0.00 0.00 0 0 56.0 56.0 24.0 333.3 333.3 57

.5# 100 MESH 3990 0.50 0.50 0.71 0.71 1995 1995 56.5 54.8 24.0 66.5 68.7 64

SWEEP 15000 0.00 0.00 0.00 0.00 0 1995 56.0 56.0 24.0 250.0 250.0 89

.75# 100 MESH 3990 0.75 0.75 1.07 1.07 2992.5 4987.5 56.8 54.2 24.0 66.5 69.7 95

SWEEP 15000 0.00 0.00 0.00 0.00 0 4987.5 56.0 56.0 24.0 250.0 250.0 12

1# 40/70 TLC 6636 1.00 1.00 1.43 1.43 6636 11623.5 57.0 53.6 23.0 110.6 117.8 13

SWEEP 15000 0.00 0.00 0.00 0.00 0 11623.5 56.0 56.0 24.0 250.0 250.0 15

1.25# 40/70 TLC 6636 1.25 1.25 1.79 1.79 8295 19918.5 57.3 53.0 23.0 110.6 119.6 16

SWEEP 15000 0.00 0.00 0.00 0.00 0 19918.5 56.0 56.0 24.0 250.0 250.0 19

1.5# 40/70 TLC 6636 1.50 1.50 2.14 2.14 9954 29872.5 57.5 52.4 23.0 110.6 121.4 20

SWEEP 15000 0.00 0.00 0.00 0.00 0 29872.5 56.0 56.0 24.0 250.0 250.0 23

1.5# 40/70 TLC 6636 1.50 1.50 2.14 2.14 9954 39826.5 57.5 52.4 23.0 110.6 121.4 24

SWEEP 15000 0.00 0.00 0.00 0.00 0 39826.5 56.0 56.0 24.0 250.0 250.0 26

1# 20/40 TLC 3318 1.00 1.00 1.43 1.43 3318 43144.5 57.0 53.6 23.0 55.3 58.9 272# 20/40 TLC 3318 2.00 2.00 2.86 2.86 6636 49780.5 58.0 51.3 22.0 55.3 62.5 28

3# 20/40 TLC 3318 3.00 3.00 4.29 4.29 9954 59734.5 58.9 49.3 22.0 55.3 66.1 284# 20/40 TLC 3318 4.00 4.00 5.71 5.71 13272 73006.5 59.7 47.4 21.0 55.3 69.7 29

4# 20/40 SLC 2500 4.00 4.00 5.71 5.71 10000 83006.5 59.7 47.3 21.0 41.7 52.6 29

FLUSH 12306 0.00 0.00 0.00 0.00 0 83006.5 80.0 80.0 0.0 293.0 293.0 32

Design Totals --> 182602 83007 0 3202.7 3292.9 Actual Totals -->

Depths (ft) # of Perfs Displacement (bbls) Pump Via 

Top Perf 7624 110 Tubing Casing

Bottom Perf 7756 Casing 291.69 Blen

N/A Annulus

Flu

O.D. (in.) Weight (lbs/ft) Bbls/ft I.D. (in.)

Casing 7 0.03826 6.276 Flush (bbls) Hydra

Tubing Top 291.7

Annulus Bottom 296.7

26
Superior Well Services

Additive Schedule

Customer Name: SANDRIDGE 12/24/2009Well Name: WEST RANCH 71-5 STG.4 Formation: 1ST CABALLOS

Additive: LSG-1(GEL) Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 6.25 87.50 13.39 13.91 14.44 14.96 15.49 87.50

0.71 2793 6.25 17.46 12.97 13.47 13.99 14.49 15.02 104.960.00 10500 6.25 65.63 13.39 13.91 14.44 14.96 15.49 170.581.07 2793 6.25 17.46 12.76 13.26 13.78 14.28 14.78 188.040.00 10500 6.25 65.63 13.39 13.91 14.44 14.96 15.49 253.661.43 4645 6.25 29.03 12.57 13.07 13.55 14.04 14.54 282.700.00 10500 6.25 65.63 13.39 13.91 14.44 14.96 15.49 348.321.79 4645 6.25 29.03 12.39 12.86 13.36 13.83 14.33 377.350.00 10500 6.25 65.63 13.39 13.91 14.44 14.96 15.49 442.982.14 4645 6.25 29.03 12.21 12.68 13.15 13.62 14.10 472.010.00 10500 6.25 65.63 13.39 13.91 14.44 14.96 15.49 537.642.14 4645 6.25 29.03 12.21 12.68 13.15 13.62 14.10 566.670.00 10500 6.25 65.63 13.39 13.91 14.44 14.96 15.49 632.291.43 2323 6.25 14.52 12.57 13.07 13.55 14.04 14.54 646.81

2.86 2323 6.25 14.52 11.84 12.31 12.78 13.23 13.70 661.334.29 2323 6.25 14.52 11.21 11.63 12.08 12.52 12.97 675.845.71 2323 6.25 14.52 10.63 11.03 11.45 11.87 12.29 690.365.71 1750 6.25 10.94 10.61 11.00 11.42 11.84 12.26 701.300.00 12306 0.00 0.00 0.00 0.00 0.00 0.00 0.00 701.30

701.30

Additive: ACTIVATOR Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.71 2793 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.07 2793 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 4645 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.79 4645 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 4645 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.14 4645 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.000.00 10500 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.001.43 2323 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.002.86 2323 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.004.29 2323 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 2323 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.005.71 1750 5.00 8.75 8.48 8.80 9.14 9.47 9.81 8.750.00 12306 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.75

8.75

Additive: SUPER NE Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 2.00 20.00 4.28 4.45 4.62 4.79 4.96 20.00

0.00 14000 2.00 28.00 4.28 4.45 4.62 4.79 4.96 48.000.71 2793 2.00 5.59 4.15 4.31 4.48 4.64 4.80 53.590.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 74.591.07 2793 2.00 5.59 4.08 4.24 4.41 4.57 4.73 80.170.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 101.17

1.43 4645 2.00 9.29 4.02 4.18 4.33 4.49 4.65 110.460.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 131.461.79 4645 2.00 9.29 3.96 4.12 4.28 4.43 4.59 140.750.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 161.752.14 4645 2.00 9.29 3.91 4.06 4.21 4.36 4.51 171.040.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 192.042.14 4645 2.00 9.29 3.91 4.06 4.21 4.36 4.51 201.330.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 222.331.43 2323 2.00 4.65 4.02 4.18 4.33 4.49 4.65 226.982.86 2323 2.00 4.65 3.79 3.94 4.09 4.23 4.38 231.624.29 2323 2.00 4.65 3.59 3.72 3.86 4.01 4.15 236.275.71 2323 2.00 4.65 3.40 3.53 3.66 3.80 3.93 240.915.71 1750 2.00 3.50 3.39 3.52 3.65 3.79 3.92 244.410.00 12306 2.00 24.61 4.28 4.45 4.62 4.79 4.96 269.03

269.03

Fluid Technician: FOXField Receipt #: STG.24 Prepared By: SOTELO

Customer Name: SANDRIDGE 12/24/2009
Superior Well Services

Additive Schedule

Well Name: WEST RANCH 71-5 STG.4 Formation: 1ST CABALLOS

Additive: OB1/OB2 Planned Additive Rates (PPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 0.50 7.00 1.07 1.11 1.16 1.20 1.24 7.000.71 2793 0.50 1.40 1.04 1.08 1.12 1.16 1.20 8.400.00 10500 0.50 5.25 1.07 1.11 1.16 1.20 1.24 13.651.07 2793 0.50 1.40 1.02 1.06 1.10 1.14 1.18 15.040.00 10500 0.50 5.25 1.07 1.11 1.16 1.20 1.24 20.291.43 4645 0.50 2.32 1.01 1.05 1.08 1.12 1.16 22.620.00 10500 0.50 5.25 1.07 1.11 1.16 1.20 1.24 27.871.79 4645 0.75 3.48 1.49 1.54 1.60 1.66 1.72 31.350.00 10500 0.75 7.88 1.61 1.67 1.73 1.80 1.86 39.222.14 4645 0.75 3.48 1.46 1.52 1.58 1.63 1.69 42.710.00 10500 0.75 7.88 1.61 1.67 1.73 1.80 1.86 50.582.14 4645 0.75 3.48 1.46 1.52 1.58 1.63 1.69 54.070.00 10500 0.75 7.88 1.61 1.67 1.73 1.80 1.86 61.941.43 2323 0.75 1.74 1.51 1.57 1.63 1.69 1.75 63.682.86 2323 1.25 2.90 2.37 2.46 2.56 2.65 2.74 66.594.29 2323 1.25 2.90 2.24 2.33 2.42 2.50 2.59 69.495.71 2323 1.25 2.90 2.13 2.21 2.29 2.37 2.46 72.395.71 1750 1.25 2.19 2.12 2.20 2.28 2.37 2.45 74.580.00 12306 0.00 0.00 0.00 0.00 0.00 0.00 0.00 74.58

Additive: SUPER FOAM Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 2.00 28.00 4.28 4.45 4.62 4.79 4.96 28.000.71 2793 2.00 5.59 4.15 4.31 4.48 4.64 4.80 33.590.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 54.591.07 2793 2.00 5.59 4.08 4.24 4.41 4.57 4.73 60.170.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 81.171.43 4645 2.00 9.29 4.02 4.18 4.33 4.49 4.65 90.460.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 111.46

1.79 4645 2.00 9.29 3.96 4.12 4.28 4.43 4.59 120.750.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 141.752.14 4645 2.00 9.29 3.91 4.06 4.21 4.36 4.51 151.040.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 172.042.14 4645 2.00 9.29 3.91 4.06 4.21 4.36 4.51 181.330.00 10500 2.00 21.00 4.28 4.45 4.62 4.79 4.96 202.331.43 2323 2.00 4.65 4.02 4.18 4.33 4.49 4.65 206.982.86 2323 2.00 4.65 3.79 3.94 4.09 4.23 4.38 211.624.29 2323 2.00 4.65 3.59 3.72 3.86 4.01 4.15 216.275.71 2323 2.00 4.65 3.40 3.53 3.66 3.80 3.93 220.915.71 1750 2.00 3.50 3.39 3.52 3.65 3.79 3.92 224.410.00 12306 0.00 0.00 0.00 0.00 0.00 0.00 0.00 224.41

Additive: Planned Additive Rates ()

PPG VOLUME LOAD AMOUNT 51 BPM 53 BPM 55 BPM 57 BPM 59 BPM Actual GONE

Fluid Technician: FOXField Receipt #: STG.24 Prepared 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: Piňon 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: Piňon 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.