## SandRidge Energy WR 31

- 32 No. 19a – Frac Service Company

Stage 1 Superior

## SandRidge Energy WR 22

- 12 No. 9 - Pressure Test of Casing

8.4.06 Riata Daily R eport says: Pressure test ed csg to 4200 psi

. Held ok.

## SandRidge Energy WR 23 -3 No. 9 - Pressure Test of Casing

8.31.04 Riata Daily R eport says: Test cs g to 5000# f/ 15 mins

.

## SandRidge Energy WR 31

- 32 No. 9 - Pressure Test of Casing

10 .15 .0 9 WellView Field Report says: T std csg to 4800 psi, good test.PageofDATE:CUSTOMER:Tank/Transport No.1 2 3Water QualityDate filled:CityWellPondOtherClarity, color, odorCLEAR CLEAR CLEAR CLEAR CLEARSample Temperature, (F)67 67 68 65 66Specific gravity1.100 1.100 1.100 1.100 1.100Initial pH7.1 7.1 7.2 7.4 7.3Iron (Fe++/Fe+++) ppm00000Reducing Agent (Yes or No)Sulfate, ppm<400 <400 <400 <400 <400Chloride, ppm<500 <500 <500 <500 <500Calcium, ppmMagnesium, ppmBF-7L Precipitate > > > > > 1 2 3 4 5 6 7 8 8BacteriaYesNoAerobic: No. per ml/time / / / / / / / / / / / / / / /Anaerobic: No. per ml/time ///////////////Base Gel QualityUse additional copies of this form for each series of tests @ 24 hr. intervals & prior to pumping.Name of product system mixedGellant loading (lbs/1000 gal.)Fluid sampling locationSampling timeSample Temperature, (F)pH3min.Fann reading9min.@300 rpm 30min.60min.X-Link Vortex Closure, min:secX-Link Crown, min:secX-Link pHStageViscosity (cp)pHXL time @ blender, sec.Sample TemperatureTime fluid pumpedTested by:WATER BASED FRAC FLUID QUALITY CONTROL(Attachment to Treatment Report)10/22/2009 FIELD RECEIPT NO:SANDRIDGE ENERGY LEASE NAME & WELL NO: WEST RANCH 31-32TanksNote: Use additional copies of this report for testing additional material lots or tanks.This job will be:Gelled on-the-flyBatch MixedDate water sampled:Source of water:Date Biocide Added:Date Biocide Added:This test data is considered to be a minimum standard. Additional testing or documentation may be required by the customer orfor frac quality assurance. Data recorded electronically with Engineering approved monitoring devices may besubstituted for applicable portions of this form. This testing data is considered to be the minimum needed for the well file.RICKYBiocide added before H2O?Field Pilot TestBatch Mixed Gel Quality TestFrac Fluid Quality(These measurements are made as the job is pumped)Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATE

Superior Rep. Customer Rep. Stage # JOHNNY ANAY A

Co2 Rate CO2 Total Total Rate

BPM BBLS BPM

6.0 6.4 6.5 7.0

6.6 6.5 6.5 6.5 6.5 6.5 6.5 6.5 Energized Stimulation Treatment Report

55-000269 10/22/09

WEST RANCH 31-32 Pecos SANDRIDGE ENERGY

TX
George Castillo 1

Job Descript ion / Remarks

Prime andTest Safety Meeting ANNULUS BPM BBLS BBLS 13:04 7200 139 Pressures (psi) Rate Stage Total

STP

13:33 139 13:33

Casing Depth 5758 5.5 in 15.5# Perf balls on location

Shutdown to change ball gun Tubing Type N/A 16:07 1758 139 Tubing Depth N/A 1765 139 7 134 238 Breakdown Well Data 15:45 1762

Establish rate 16:17 139 Open Wellhead 139 waiting on perf balls

Flush acid 139 6.5 went back to water ball gun not functional 15:29 2223 139 6

16:16 139 15:46
Fixed ball gun Casing Type

New 16:38 1666 139 6.5 126 252 Flush Formation 2nd Cab 16:20 1701 139 6.5 113 127 Ball Drop Well Type 16:18 1680 139 6.6 14 14

3rd set of 20 balls hit perfs Tubing Cap. N/A 16:52 1722 139 6.5 224 4th set of 20 balls hit perfs 16:51 1694 139 6.5 212 Casing Cap. 134 1st set of 20 balls hit perfs Treatment Fluid and Capacities in BBLS 16:49 1685 139 6.5 200 2nd set of 20 balls hit perfs 16:48 1676 139 6.5 188

1 16:54 1831 139 6.5 236 5th set of 20 balls hit perfs Fluid To Load Page 1

15:29 139
acid ball drop 15:33 1780 139 6.4 77 26 26

6

. 5 6.5

35.0 183 80.0 35.0 238 79.0 35.0 304 79.0 36.0 361 80.0 35.0 436 79.7 35.0 504 79.3 36.0 556 80.6 35.0 654 79.2 34.0 710 78.2 34.0 763 78.2 33.0 818 77.4 32.0 874 79.0 31.0 914 79.0 31.0 959 79.0 966 50.0 730 Pad Fluid To Recover 2035 1 16:56 1939 139 6.5 248 6th set of 20 balls hit perfs Pad Volume 478 16:54 1831 139 6

. 5 236 5th set of 20 balls hit perfs Fluid To Load

879 ISIP Treating Fluid 1423 17:15 139 Surg well 16:59 1676 139 Flush 134 17:54 139 45 478 18:12 3564 139 44 68 798 .25# 30/50 White

Acid 8,000 Volume Pumped (Gals) Sweep Treatment Data 18:15 3706 139 44 72 951 .4# 30/50 White 18:13 3670 139 44 81
Sweep Fluid Description 18:19 3692 139 44.3 82 1,131 1# 30/50 White 18:17 3662 139 44.7 98 1,049

Sweep 18:37 3550 139 44.2 70 1,460 1# 20/40 White 18:25 3628 139 44.2 73 1,390 77,490 18:22 3737 139 44.2 120 1,317 1.5# 30/50 White 18:21 3994 139 44.6 66 1,197 Sweep 15# Linear

18:30 3524 139 47 85 1,621 3# 20/40 White 18:28 3466 139 44.4 76 1,536 2# 20/40 White

Flush Proppant Description Volume Pumped (lbs) 18:35 2618 139 50 124 1,883 30/50 Ottawa 21,100 4# 20/40 White Treatment Data 18:33 3464 139 48 74 1,759 4# 20/40 SLC 18:32 3497 139 48 64 1,685

51,080 20/40 SLC 12,472 20/40 Ottawa

Treatment Data

Maximum 3353 Maximum 81.0 5 Min. Activator Treating Presure Injection Rates Shut In Pressures Materials Minimum Minimum ISDP 1925 LSG-1

SUPER FOAM
Operators Max Pressure 6700 15 Min. Super NE

Average 2960 Average 79.0 10 Min.

OB-2 Final OB BREAKER

# RIATA ENERGY,INC. ESTIMATED DRILLING SUMMARY
Riata Energy Information Lease Information Texas RRC Information Well Name: West Ranch 22-12 

### Field: Wildcat/Pinon (Overthrust) 

### RRC Permit #: 612866 

### API No.: 4237137664 

### County: Pecos 

### Permit Depth: 5,500' 

### AFE No.: WESRAN2212 

### State: Texas 

### Permit Date: Riata No.: 1 

### Lse Ln.: TWC Wtrboard: 1,450' (1450'-2500') 

### Estimated TVD 5000' 

### X & Y : 330' FSL & 550' FEL 

### TWC Form # SC-9853 

### Contractor Rig: Lariat #1 

### Elev.: 4,215' 

### Execption to NA 

### Estimated Geological Objectives - Will Test as encountered Objective Form TVD BHP TVD BHP B/Water Sands +/-1,300' Sandstone +/-3418' B/Cretaceous +/-1,600' B/Wolfcamp +/-1950 T/1st Tesnus +/-2245' B/1st Tesnus +/-2355' T/2nd Tesnus +/-2672' 

### Estimated Casing Program Summary Estimated Cement Program Summary Casing TVD MD Hole Csg Slurr y Details
Conductor 

### 40' 20" 14" Preflush

Lead

Tail

Lead Tail Lead Tail Lead Tail 

### Wellhead Summary BOP Equipment Summary Drilling BHA Summary HoleSec Class Size Rating Test Lo/Hi DP
BelowCon Diverter 5K 4-1/2" 1 8" & 4 6-1/4" BelowSurf Class III 13 5/8" 5K 4-1/2" 6 6-1/4" Below Int Class III 13 5/8" 5K 3-1/2" 9 4-3/4" 

### Air Hole Below Int Class III Below Prod 

### Comments:All Equipment is subject to change due to drilling conditions! Will need more drill collars when on mud Estimated Depths of Other Services Man'd Mud Log Start @ 2,000' Degasser Drill Recorder Adj. Choke Mud Cleaner PVT-Flo Sho Gas Detector Centrifuge Trip Tank 

### Estimated Mud Program Summary Depth Interval Typ e MW Rang e V is WL pH

45 - 55 6 < 8 8.0 - 10.0



### Will always drill out from under casing with a Hammer and air until hole conditions deem otherwise! Estimated Logging Program Pertinent Personnel Phone Numbers Logging Company 

### Schlumberger (432) 694-0000 Name Work Home Mobile Geologist 

### Gene Pait Res. Engineer 

### Malone Mitchell (806) 376-7904 352-0723 236-3830 FE Specialist 

### 1-800-299-1244 James Follis (806) 376-7904 622-2242 584-0297 

### Run Interva l Proposed Tools 1-800-203-4577 Marc Harvey (806) 376-7904 331-1366 236-8589



### Gene Pait (806) 376-7904 622-8767 670-4816



### Estimated Logging Tools are subject to change. Land Summary/Requirements:

Estimated Spud Date & Rig Release Prepared By: James Jackson Estimated Spud Target Drill Days Actual Drill Days 

### Date: 

## Comments: All information is subject to change due to conditions before, during and after drilling. No information herein is intended as anything but an estimate. Sandstone 

### Lithology Lithology

LS/SS/Sh

Sandstone

Description: FOR LAND RELATED QUESTIONS CONTACT PAT GARRARD, LAND MANAGER, 806-433-2169 Sandstone

Intermediate Section 0' - +/-1,500' (8-3/4") 115 gpm Follow Preflush w/110 sks Key Lost Circulation Scavenger. Start cement right behind Scavenger (no spacer). Cement w/ Lead: 280 sks Key Lite w/2%CC & 1/4#/sk Celloflake mixed at 13.0 ppg to yield 1.90 ft3/sk. Tail: 100 sks Key Lite w/2%CC & 1/4#/sk Celloflake mixed at 13.7 ppg to yield 1.65 ft3/sk, (200% excess). Key: (432) 590- 4899.



### 16 DC

7/15/2006 To be determined



### June, 28 2006 Production Section To be determined 2/15/2006 Sec. 22, Blk 2, TC RR



### 6-1/8" 4-1/2" To be calculated off of open hole logs. 

### Objective Form B/2nd Tesnus

Pump 110 bbl fresh water Preflush. Does not need to circulate.

Watch for oil zone @ 2,600' to 3,000' that caused rig to get stuck on the West Ranch 23-10.

Production



### Size & Rating

11" 3K x 9-5/8" SOW



### Mud Inj. Rate +/-5,000'

11" 5K x 7-1/16" 5K

11" 3K x 11" 5K

Air / Air-Mist Surface 

### +/-1,500' 8-3/4" 7"

Protective

Protective

Air / Gas / Brine-Starch-Salt Gel Mud



### Mud injection rate above achieves 100 ft/min annular velocity. Maintain 5% oil in system. +/-1,500'-+/-5,000' (6-1/8") 9.8 - 10.4

## TRUE 1 1.5 Guide Sho e Casing sho e 4 1/2 11.6 N

‐ 80 4 TRUE 2 43 Casing Join Casing (bla 4 1/2 11.6 N

‐ 80 4 TRUE 3 1.5 Float Colla r Float colla r 4 1/2 11.6 N

‐ 80 4 TRUE 4 4,746.00 Casing Join Casing (bla 4 1/2 11.6 N

‐ 80 4 TRUE 5 Casing Join Casing (bla 4 1/2 11.6 N

‐ 80 4

## Other 1.5 4,790.50 4,792.00 0 0 Casing 44.5 4,747.50 4,790.50 0.2 0.5 Other 46 4,746.00 4,747.50 0.2 0.5 Casing 4,792.00 0 4,746.00 19.8 55.6 Casing 4,792.00 0 0 19.8 55.6

## C2A3EE28 3 D1BE71DA 7 3DC0FB0961114ECA86885C76BA07685F C2A3EE28 3 D1BE71DA 7 5A6923F58B2F40F1AB64A7A3D5626F36 C2A3EE28 3 D1BE71DA 7 D597660A469B4859839D2C31771A6339 C2A3EE28 3 D1BE71DA 7 512233692B064D0A8A87C5224954C1B1 C2A3EE28 3 D1BE71DA 7 512233692B064D0A8A87C5224954C1B1

## 1 1

## 1.5 6,350 43 6,350 1.5 6,350 4,746 6,350 4,746 6,350

## 4 3 2 1 1

## ######## ######## ######## jacosta ######## ######## jacosta ######## ######## ######## jacosta ######## ######## jacosta ######## ######## ######## jacosta ######## ######## jacosta ######## ######## ######## jacosta ######## ######## jacosta ######## ######## ######## jacosta ######## ######## jacosta

## C2A3EE28 3 A071B89E 5 9B30EC4BC3534E8CB72E2B9E794EA1BD 2.15E+09 C2A3EE28 3 BA89F5AD 0 1D46B96EF62245F998C90427418437CB 2.15E+09 C2A3EE28 3 5F2B0321 3 8A13EA0BF91348BEB3121D1576FECBF0 2.15E+09 C2A3EE28 3 FEDA80B5 8 7B67960E09354BD4A6346FFCBD491174 2.15E+09

## TRUE 1 1.5 Float Shoe Casing sho e 5 1/2 TRUE 2 36.92 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 3 38 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 4 1.1 Float Colla r Float colla r 5 1/2 17 N

‐ 80 4.892 TRUE 5 35.96 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 6 38.15 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 7 37.95 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 8 39.28 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 9 39.33 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 10 38.87 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 11 38.78 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 12 39.28 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 13 38.26 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 14 39.7 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 15 39.7 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 16 38.75 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 17 39.42 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 18 38.94 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 19 37 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 20 37.58 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 21 37.42 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 22 36.89 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 23 37.98 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 24 37.39 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 25 38.83 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 26 35.67 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 27 37.55 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 28 41.81 Marker Joi n Casing (re d 5 1/2 17 N

‐ 80 4.892 TRUE 29 37.15 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 30 38.34 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 31 39.8 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 32 39.02 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 33 37.8 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 34 36.05 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 35 39.63 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 36 32.58 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 37 38.15 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 38 38.15 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 39 41.23 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 40 40.72 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 41 41.13 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 42 41.18 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 43 41.1 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 44 41.21 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 45 41.08 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 46 37.23 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 47 39.75 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892

## TRUE 48 39.05 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 49 36.25 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 50 36.87 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 51 37.27 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 52 39.43 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 53 36.83 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 54 36.07 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 55 37.78 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 56 36.8 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 57 39.68 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 58 36.38 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 59 37.09 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 60 37.18 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 61 38.17 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 62 39.61 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 63 36.47 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 64 37.83 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 65 37.42 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 66 37.96 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 67 36.81 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 68 37.55 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 69 37.73 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 70 37.6 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 71 37.37 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 72 39.28 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 73 38.75 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 74 37.23 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 75 38.75 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 76 38.67 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 77 39.39 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 78 37.1 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 79 38.75 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 80 37.05 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 81 37.02 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 82 37.18 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 83 37.47 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 84 38.03 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 85 37.88 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 86 39.7 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 87 39.78 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 88 39.84 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 89 37.8 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 90 39.45 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 91 36.06 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 92 37.71 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 93 38.76 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 94 37.29 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892

## TRUE 95 37.42 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 96 37 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 97 37.67 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 98 37.67 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 99 39.2 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 100 39.55 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 101 37.37 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 102 39.2 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 103 38.72 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 104 37.56 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 105 39.78 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 106 36.39 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 107 36.59 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 108 39.36 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 109 37.95 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 110 37.04 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 111 37.72 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 112 37.67 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 113 37.18 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 114 37.12 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 115 39.39 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 116 36.55 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 117 37.78 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 118 37.2 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 119 41.28 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 120 41.18 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 121 41.22 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 122 38.11 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 123 2.25 Stage Tool Stage colla 5 1/2 17 P

‐ 110 4.892 TRUE 124 38.25 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 125 38.47 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 126 38.4 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 127 37.5 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 128 36.87 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 129 36.56 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 130 37.17 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 131 37.83 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 132 37.12 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 133 39.6 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 134 36.39 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 135 37.2 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 136 37.2 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 137 37.73 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 138 38.13 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 139 36.43 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 140 36.57 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 141 37.97 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892

## TRUE 142 38.13 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 143 37.18 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 144 36.92 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 145 38.03 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 146 36.54 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 147 38.87 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 148 38.13 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 149 37.69 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 150 39.61 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 151 36.77 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 152 37.05 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 153 39.33 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 154 37.03 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 155 39.23 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 156 37.44 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 157 38.3 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 158 38.08 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 159 38.13 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 160 37.76 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 TRUE 161 37.02 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 FALSE 37.28 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 FALSE 39.97 Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892 FALSE Casing

‐ Joi n Casing (bla 5 1/2 17 N

‐ 80 4.892

## Other LT&C 5 1/2 FALSE 1.5 6,018.50 6,020.00 0 0 Casing LT&C 5 1/2 TRUE 38.42 5,981.60 6,018.50 0.3 0.6 Casing LT&C 5 1/2 FALSE 76.42 5,943.60 5,981.60 0.5 1.3 Other LT&C 5 1/2 FALSE 77.52 5,942.50 5,943.60 0.5 1.3 Casing LT&C 5 1/2 FALSE 113.48 5,906.50 5,942.50 0.7 1.9 Casing LT&C 5 1/2 FALSE 151.63 5,868.40 5,906.50 1 2.6 Casing LT&C 5 1/2 TRUE 189.58 5,830.40 5,868.40 1.2 3.2 Casing LT&C 5 1/2 FALSE 228.86 5,791.10 5,830.40 1.4 3.9 Casing LT&C 5 1/2 FALSE 268.19 5,751.80 5,791.10 1.7 4.5 Casing LT&C 5 1/2 FALSE 307.06 5,712.90 5,751.80 1.9 5.2 Casing LT&C 5 1/2 TRUE 345.84 5,674.20 5,712.90 2.2 5.9 Casing LT&C 5 1/2 FALSE 385.12 5,634.90 5,674.20 2.4 6.5 Casing LT&C 5 1/2 FALSE 423.38 5,596.60 5,634.90 2.6 7.2 Casing LT&C 5 1/2 FALSE 463.08 5,556.90 5,596.60 2.9 7.8 Casing LT&C 5 1/2 TRUE 502.78 5,517.20 5,556.90 3.1 8.5 Casing LT&C 5 1/2 FALSE 541.53 5,478.50 5,517.20 3.4 9.2 Casing LT&C 5 1/2 FALSE 580.95 5,439.10 5,478.50 3.6 9.9 Casing LT&C 5 1/2 FALSE 619.89 5,400.10 5,439.10 3.8 10.5 Casing LT&C 5 1/2 TRUE 656.89 5,363.10 5,400.10 4.1 11.1 Casing LT&C 5 1/2 FALSE 694.47 5,325.50 5,363.10 4.3 11.8 Casing LT&C 5 1/2 FALSE 731.89 5,288.10 5,325.50 4.5 12.4 Casing LT&C 5 1/2 FALSE 768.78 5,251.20 5,288.10 4.8 13 Casing LT&C 5 1/2 TRUE 806.76 5,213.20 5,251.20 5 13.7 Casing LT&C 5 1/2 FALSE 844.15 5,175.90 5,213.20 5.2 14.3 Casing LT&C 5 1/2 FALSE 882.98 5,137.00 5,175.90 5.5 15 Casing LT&C 5 1/2 FALSE 918.65 5,101.40 5,137.00 5.7 15.6 Casing LT&C 5 1/2 TRUE 956.2 5,063.80 5,101.40 5.9 16.2 Other LT&C 5 1/2 FALSE 998.01 5,022.00 5,063.80 6.2 16.9 Casing LT&C 5 1/2 FALSE 1,035.16 4,984.80 5,022.00 6.4 17.6 Casing LT&C 5 1/2 FALSE 1,073.50 4,946.50 4,984.80 6.6 18.2 Casing LT&C 5 1/2 TRUE 1,113.30 4,906.70 4,946.50 6.9 18.9 Casing LT&C 5 1/2 FALSE 1,152.32 4,867.70 4,906.70 7.1 19.6 Casing LT&C 5 1/2 FALSE 1,190.12 4,829.90 4,867.70 7.3 20.2 Casing LT&C 5 1/2 FALSE 1,226.17 4,793.80 4,829.90 7.6 20.8 Casing LT&C 5 1/2 FALSE 1,265.80 4,754.20 4,793.80 7.8 21.5 Casing LT&C 5 1/2 FALSE 1,298.38 4,721.60 4,754.20 8 22.1 Casing LT&C 5 1/2 FALSE 1,336.53 4,683.50 4,721.60 8.2 22.7 Casing LT&C 5 1/2 FALSE 1,374.68 4,645.30 4,683.50 8.5 23.4 Casing LT&C 5 1/2 FALSE 1,415.91 4,604.10 4,645.30 8.7 24.1 Casing LT&C 5 1/2 FALSE 1,456.63 4,563.40 4,604.10 9 24.7 Casing LT&C 5 1/2 FALSE 1,497.76 4,522.20 4,563.40 9.2 25.4 Casing LT&C 5 1/2 FALSE 1,538.94 4,481.10 4,522.20 9.5 26.1 Casing LT&C 5 1/2 FALSE 1,580.04 4,440.00 4,481.10 9.7 26.8 Casing LT&C 5 1/2 FALSE 1,621.25 4,398.80 4,440.00 10 27.5 Casing LT&C 5 1/2 FALSE 1,662.33 4,357.70 4,398.80 10.2 28.2 Casing LT&C 5 1/2 FALSE 1,699.56 4,320.40 4,357.70 10.5 28.9 Casing LT&C 5 1/2 FALSE 1,739.31 4,280.70 4,320.40 10.7 29.6

## Casing LT&C 5 1/2 FALSE 1,778.36 4,241.60 4,280.70 11 30.2 Casing LT&C 5 1/2 FALSE 1,814.61 4,205.40 4,241.60 11.2 30.8 Casing LT&C 5 1/2 FALSE 1,851.48 4,168.50 4,205.40 11.4 31.5 Casing LT&C 5 1/2 FALSE 1,888.75 4,131.30 4,168.50 11.6 32.1 Casing LT&C 5 1/2 FALSE 1,928.18 4,091.80 4,131.30 11.9 32.8 Casing LT&C 5 1/2 FALSE 1,965.01 4,055.00 4,091.80 12.1 33.4 Casing LT&C 5 1/2 FALSE 2,001.08 4,018.90 4,055.00 12.3 34 Casing LT&C 5 1/2 FALSE 2,038.86 3,981.10 4,018.90 12.5 34.6 Casing LT&C 5 1/2 FALSE 2,075.66 3,944.30 3,981.10 12.8 35.3 Casing LT&C 5 1/2 FALSE 2,115.34 3,904.70 3,944.30 13 35.9 Casing LT&C 5 1/2 FALSE 2,151.72 3,868.30 3,904.70 13.2 36.6 Casing LT&C 5 1/2 FALSE 2,188.81 3,831.20 3,868.30 13.5 37.2 Casing LT&C 5 1/2 FALSE 2,225.99 3,794.00 3,831.20 13.7 37.8 Casing LT&C 5 1/2 FALSE 2,264.16 3,755.80 3,794.00 13.9 38.5 Casing LT&C 5 1/2 FALSE 2,303.77 3,716.20 3,755.80 14.2 39.2 Casing LT&C 5 1/2 FALSE 2,340.24 3,679.80 3,716.20 14.4 39.8 Casing LT&C 5 1/2 FALSE 2,378.07 3,641.90 3,679.80 14.6 40.4 Casing LT&C 5 1/2 FALSE 2,415.49 3,604.50 3,641.90 14.9 41.1 Casing LT&C 5 1/2 FALSE 2,453.45 3,566.60 3,604.50 15.1 41.7 Casing LT&C 5 1/2 FALSE 2,490.26 3,529.70 3,566.60 15.3 42.3 Casing LT&C 5 1/2 FALSE 2,527.81 3,492.20 3,529.70 15.6 43 Casing LT&C 5 1/2 FALSE 2,565.54 3,454.50 3,492.20 15.8 43.6 Casing LT&C 5 1/2 FALSE 2,603.14 3,416.90 3,454.50 16 44.2 Casing LT&C 5 1/2 FALSE 2,640.51 3,379.50 3,416.90 16.2 44.9 Casing LT&C 5 1/2 FALSE 2,679.79 3,340.20 3,379.50 16.5 45.5 Casing LT&C 5 1/2 FALSE 2,718.54 3,301.50 3,340.20 16.7 46.2 Casing LT&C 5 1/2 FALSE 2,755.77 3,264.20 3,301.50 16.9 46.8 Casing LT&C 5 1/2 FALSE 2,794.52 3,225.50 3,264.20 17.2 47.5 Casing LT&C 5 1/2 FALSE 2,833.19 3,186.80 3,225.50 17.4 48.2 Casing LT&C 5 1/2 FALSE 2,872.58 3,147.40 3,186.80 17.7 48.8 Casing LT&C 5 1/2 FALSE 2,909.68 3,110.30 3,147.40 17.9 49.5 Casing LT&C 5 1/2 FALSE 2,948.43 3,071.60 3,110.30 18.1 50.1 Casing LT&C 5 1/2 FALSE 2,985.48 3,034.50 3,071.60 18.4 50.7 Casing LT&C 5 1/2 FALSE 3,022.50 2,997.50 3,034.50 18.6 51.4 Casing LT&C 5 1/2 FALSE 3,059.68 2,960.30 2,997.50 18.8 52 Casing LT&C 5 1/2 FALSE 3,097.15 2,922.90 2,960.30 19 52.6 Casing LT&C 5 1/2 FALSE 3,135.18 2,884.80 2,922.90 19.3 53.3 Casing LT&C 5 1/2 FALSE 3,173.06 2,846.90 2,884.80 19.5 53.9 Casing LT&C 5 1/2 FALSE 3,212.76 2,807.20 2,846.90 19.8 54.6 Casing LT&C 5 1/2 FALSE 3,252.54 2,767.50 2,807.20 20 55.3 Casing LT&C 5 1/2 FALSE 3,292.38 2,727.60 2,767.50 20.2 56 Casing LT&C 5 1/2 FALSE 3,330.18 2,689.80 2,727.60 20.5 56.6 Casing LT&C 5 1/2 FALSE 3,369.63 2,650.40 2,689.80 20.7 57.3 Casing LT&C 5 1/2 FALSE 3,405.69 2,614.30 2,650.40 20.9 57.9 Casing LT&C 5 1/2 FALSE 3,443.40 2,576.60 2,614.30 21.2 58.5 Casing LT&C 5 1/2 FALSE 3,482.16 2,537.80 2,576.60 21.4 59.2 Casing LT&C 5 1/2 FALSE 3,519.45 2,500.60 2,537.80 21.6 59.8

## Casing LT&C 5 1/2 FALSE 3,556.87 2,463.10 2,500.60 21.9 60.5 Casing LT&C 5 1/2 FALSE 3,593.87 2,426.10 2,463.10 22.1 61.1 Casing LT&C 5 1/2 FALSE 3,631.54 2,388.50 2,426.10 22.3 61.7 Casing LT&C 5 1/2 FALSE 3,669.21 2,350.80 2,388.50 22.6 62.4 Casing LT&C 5 1/2 FALSE 3,708.41 2,311.60 2,350.80 22.8 63 Casing LT&C 5 1/2 FALSE 3,747.96 2,272.00 2,311.60 23 63.7 Casing LT&C 5 1/2 FALSE 3,785.33 2,234.70 2,272.00 23.3 64.3 Casing LT&C 5 1/2 FALSE 3,824.53 2,195.50 2,234.70 23.5 65 Casing LT&C 5 1/2 FALSE 3,863.25 2,156.80 2,195.50 23.7 65.7 Casing LT&C 5 1/2 FALSE 3,900.81 2,119.20 2,156.80 24 66.3 Casing LT&C 5 1/2 FALSE 3,940.59 2,079.40 2,119.20 24.2 67 Casing LT&C 5 1/2 FALSE 3,976.98 2,043.00 2,079.40 24.4 67.6 Casing LT&C 5 1/2 FALSE 4,013.57 2,006.40 2,043.00 24.7 68.2 Casing LT&C 5 1/2 FALSE 4,052.93 1,967.10 2,006.40 24.9 68.9 Casing LT&C 5 1/2 FALSE 4,090.88 1,929.10 1,967.10 25.1 69.5 Casing LT&C 5 1/2 FALSE 4,127.92 1,892.10 1,929.10 25.4 70.2 Casing LT&C 5 1/2 FALSE 4,165.64 1,854.40 1,892.10 25.6 70.8 Casing LT&C 5 1/2 FALSE 4,203.31 1,816.70 1,854.40 25.8 71.5 Casing LT&C 5 1/2 FALSE 4,240.49 1,779.50 1,816.70 26.1 72.1 Casing LT&C 5 1/2 FALSE 4,277.61 1,742.40 1,779.50 26.3 72.7 Casing LT&C 5 1/2 FALSE 4,317.00 1,703.00 1,742.40 26.5 73.4 Casing LT&C 5 1/2 FALSE 4,353.55 1,666.50 1,703.00 26.8 74 Casing LT&C 5 1/2 FALSE 4,391.33 1,628.70 1,666.50 27 74.7 Casing LT&C 5 1/2 FALSE 4,428.53 1,591.50 1,628.70 27.2 75.3 Casing LT&C 5 1/2 FALSE 4,469.81 1,550.20 1,591.50 27.5 76 Casing LT&C 5 1/2 FALSE 4,510.99 1,509.00 1,550.20 27.7 76.7 Casing LT&C 5 1/2 FALSE 4,552.21 1,467.80 1,509.00 28 77.4 Casing LT&C 5 1/2 FALSE 4,590.32 1,429.70 1,467.80 28.2 78 Other LT&C 5 1/2 FALSE 4,592.57 1,427.40 1,429.70 28.2 78.1 Casing LT&C 5 1/2 TRUE 4,630.82 1,389.20 1,427.40 28.5 78.7 Casing LT&C 5 1/2 FALSE 4,669.29 1,350.70 1,389.20 28.7 79.4 Casing LT&C 5 1/2 FALSE 4,707.69 1,312.30 1,350.70 28.9 80 Casing LT&C 5 1/2 FALSE 4,745.19 1,274.80 1,312.30 29.2 80.7 Casing LT&C 5 1/2 FALSE 4,782.06 1,237.90 1,274.80 29.4 81.3 Casing LT&C 5 1/2 FALSE 4,818.62 1,201.40 1,237.90 29.6 81.9 Casing LT&C 5 1/2 FALSE 4,855.79 1,164.20 1,201.40 29.8 82.6 Casing LT&C 5 1/2 FALSE 4,893.62 1,126.40 1,164.20 30.1 83.2 Casing LT&C 5 1/2 FALSE 4,930.74 1,089.30 1,126.40 30.3 83.8 Casing LT&C 5 1/2 FALSE 4,970.34 1,049.70 1,089.30 30.5 84.5 Casing LT&C 5 1/2 FALSE 5,006.73 1,013.30 1,049.70 30.8 85.1 Casing LT&C 5 1/2 FALSE 5,043.93 976.1 1,013.30 31 85.8 Casing LT&C 5 1/2 FALSE 5,081.13 938.9 976.1 31.2 86.4 Casing LT&C 5 1/2 FALSE 5,118.86 901.1 938.9 31.5 87 Casing LT&C 5 1/2 FALSE 5,156.99 863 901.1 31.7 87.7 Casing LT&C 5 1/2 FALSE 5,193.42 826.6 863 31.9 88.3 Casing LT&C 5 1/2 FALSE 5,229.99 790 826.6 32.1 88.9 Casing LT&C 5 1/2 FALSE 5,267.96 752 790 32.4 89.6

## Casing LT&C 5 1/2 FALSE 5,306.09 713.9 752 32.6 90.2 Casing LT&C 5 1/2 FALSE 5,343.27 676.7 713.9 32.8 90.8 Casing LT&C 5 1/2 FALSE 5,380.19 639.8 676.7 33.1 91.5 Casing LT&C 5 1/2 FALSE 5,418.22 601.8 639.8 33.3 92.1 Casing LT&C 5 1/2 FALSE 5,454.76 565.2 601.8 33.5 92.7 Casing LT&C 5 1/2 FALSE 5,493.63 526.4 565.2 33.8 93.4 Casing LT&C 5 1/2 FALSE 5,531.76 488.2 526.4 34 94 Casing LT&C 5 1/2 FALSE 5,569.45 450.6 488.2 34.2 94.7 Casing LT&C 5 1/2 FALSE 5,609.06 410.9 450.6 34.5 95.4 Casing LT&C 5 1/2 FALSE 5,645.83 374.2 410.9 34.7 96 Casing LT&C 5 1/2 FALSE 5,682.88 337.1 374.2 34.9 96.6 Casing LT&C 5 1/2 FALSE 5,722.21 297.8 337.1 35.2 97.3 Casing LT&C 5 1/2 FALSE 5,759.24 260.8 297.8 35.4 97.9 Casing LT&C 5 1/2 FALSE 5,798.47 221.5 260.8 35.6 98.6 Casing LT&C 5 1/2 FALSE 5,835.91 184.1 221.5 35.9 99.2 Casing LT&C 5 1/2 FALSE 5,874.21 145.8 184.1 36.1 99.9 Casing LT&C 5 1/2 FALSE 5,912.29 107.7 145.8 36.3 100.5 Casing LT&C 5 1/2 FALSE 5,950.42 69.6 107.7 36.6 101.2 Casing LT&C 5 1/2 FALSE 5,988.18 31.8 69.6 36.8 101.8 Casing LT&C 5 1/2 FALSE 6,025.20

‐ 5.2 31.8 37 102.4 Casing LT&C 5 1/2 FALSE Casing LT&C 5 1/2 FALSE Casing LT&C 5 1/2

## A36F52C4 A06401CEB 0 3BBDFB1FA3984B2C9A1552CBA7 5 5 1/2 LT&C A36F52C4 A06401CEB 0 90336FA1A3754ECC8820994E5A 4 5 1/2 LT&C A36F52C4 A06401CEB 0 90336FA1A3754ECC8820994E5A 4 5 1/2 LT&C A36F52C4 A06401CEB 0 484E32E45B644ED998579FBFDFE 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 702555DB4964400BB1C3DD4115 5 1/2 LT&C A36F52C4 A06401CEB 0 5927C511923D413B9DA09D676E 4 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C

## A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C

## A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 EACE28989EB14748B8F52B0C48 8 5 1/2 LT&C A36F52C4 A06401CEB 0 6CB4A0C700B248488AE8DA102D 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C

## A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C A36F52C4 A06401CEB 0 F357217C142D444682BFBBA237 A 5 1/2 LT&C

## 1 2 2 1 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23 23

1 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94

## 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94

## 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94

1 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38

## 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38 38

## 1.5 74.92 7,740 6,280 4.767 74.92 7,740 6,280 4.767 1.1 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767 878.68 7,740 6,280 4.767

41.81 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767

## 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767

## 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 3,592.31 7,740 6,280 4.767 2.25 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767

## 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767 1,408.43 7,740 6,280 4.767

## 3,480 8 6.05 3,480 7 6.05 3,480 7 6.05 3,480 6 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 6.05 3,480 5 3,480 4 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3

## 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3

## 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 6.05 3,480 3 3,480 2 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1

## 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1 6.05 3,480 1

## ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig

## ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig

## ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig

## ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig ######## ######## ######## mharvey ######## ######## Rig

## A36F52C4 A 3BBDFB1F A 6108298ED6C04208AEDA016D6E2C9318 1 A36F52C4 A 90336FA1 A DADFCC96BBE84713AC11AB90A030BF7D 2 A36F52C4 A 90336FA1 A 5DB4A4341E8D4513A019A5B3F40DB68C 1 A36F52C4 A484E32E4 5 E51682297F404B739E681584BB2F0F6D 1 A36F52C4 A 702555DB 4 1435303B08BC418CAC04301ECDBA1857 23 A36F52C4 A 702555DB 4 EA92ACAC772540F9B84676CD9CFC8F76 22 A36F52C4 A 702555DB 4 44D5B819F87A4C46A1851DD0E1B78C36 21 A36F52C4 A 702555DB 4 B061F73A4DCA497D95C3F7C82B380E17 20 A36F52C4 A 702555DB 48736457698744AE3B797AD61E73E4D3F 19 A36F52C4 A 702555DB 4 20D6E57EB5E44842AF300835F732A270 18 A36F52C4 A 702555DB 4 313CEA1C91D5478BA3597CED73FBC5A0 17 A36F52C4 A 702555DB 405D1152A65CB49B2996F6C8ACA58F1C2 16 A36F52C4 A 702555DB 4 2FB742BB59C0461FBCDC4DA80C8C0C76 15 A36F52C4 A 702555DB 4 F9BB1F1694B740F2A3B1E75B80049201 14 A36F52C4 A 702555DB 4 DBE2539C081A4BBE93FC126E371D3FAB 13 A36F52C4 A 702555DB 4 A4B075122DC14FEFB1E732614D726DB2 12 A36F52C4 A 702555DB 4 3A747ECAC9F641F5B7679A98E2D9C439 11 A36F52C4 A 702555DB 4 B846857152FA4E2ABA2596E5F10597EC 10 A36F52C4 A 702555DB 4 F34A4CF0F28B409A86687E4037298CAE 9 A36F52C4 A 702555DB 4 5A9CB45B1AEC4A2B9BFC85F88F5AE16B 8 A36F52C4 A 702555DB 4 4969771461D34A0883CC60A262E9E68D 7 A36F52C4 A 702555DB 48983AC688C91446E82ECFEB4A14B8342 6 A36F52C4 A 702555DB 494D40C3AE5674E90B6A37D1181CDF08B 5 A36F52C4 A 702555DB 4 D07B4F0DAAB3401D8D533BE6A5E8BE7E 4 A36F52C4 A 702555DB 4 E077DD4E232E42D2A6A5DC2C7536D595 3 A36F52C4 A 702555DB 4 2F0CBD496E7C48E097D4C68C22F65BB9 2 A36F52C4 A 702555DB 49BA67530AB3946C483BB6C85FBAF918B 1 A36F52C4 A 5927C511 9 A0C6BF12C4E640CD80F1E6F4B61D5736 1 A36F52C4 A EACE2898 9 01F2F3C0305A4254A10E01CAB8919012 94 A36F52C4 A EACE2898 9 B1614B1163B04446871E839F5BDD68DC 93 A36F52C4 A EACE2898 9 E4F92461FEED40A8A1225A2D9D749004 92 A36F52C4 A EACE2898 9 FA4755396502436D88EBE4F766F02C5E 91 A36F52C4 A EACE2898 9 22B3B75E0A9F4AD1A632F1B5AA615576 90 A36F52C4 A EACE2898 9 5725553022544F06993905628F623022 89 A36F52C4 A EACE2898 9 40C1985F19D84C9DAE72137F28BF0539 88 A36F52C4 A EACE2898 9 ED182612FF324C86880BBD391B236C77 87 A36F52C4 A EACE2898 9 E9A3BAE528AC4DD1B8FFE6D1B0874F7A 86 A36F52C4 A EACE2898 9 5CFDD1F65C574F33B131CA02E6B77185 85 A36F52C4 A EACE2898 9 1E8593A2C28C4C8AA81C6A2E5427ABC8 84 A36F52C4 A EACE2898 9 82CABBF567A7479C8B5AC37DF92DDCD0 83 A36F52C4 A EACE2898 9 6684DAEA0B7440C18A22B81E223565D2 82 A36F52C4 A EACE2898 9 97400D96AF8C4E54805D36152C4B48E8 81 A36F52C4 A EACE2898 9 78C7C32ADA144747BEA982CCFC18156C 80 A36F52C4 A EACE2898 9 9D744C962E4E498A8EE9ED22BF2BA549 79 A36F52C4 A EACE2898 9 29C91D3BFD24460589993F1E79E955A6 78 A36F52C4 A EACE2898 9 3938BC83945B48919F908638F2C7CEAB 77 A36F52C4 A EACE2898 9 0434B0D9813A4BD4A342A7700D388D1E 76

## A36F52C4 A EACE2898 9 1A3A594917384335B56C754026C3E631 75 A36F52C4 A EACE2898 9 72924B2A78934248A30A4D46E2EB6DE8 74 A36F52C4 A EACE2898 9 1D124FF5200041D19E8810807E095611 73 A36F52C4 A EACE2898 9 C13481CD465B49A1B010D1D1F16632D9 72 A36F52C4 A EACE2898 9 F307018079C2455891328478AC1A9C28 71 A36F52C4 A EACE2898 9 C8109E9069DE4922A622C6DC195D0294 70 A36F52C4 A EACE2898 9 24551FDAA2884BBCA8A0C99F71EDB07E 69 A36F52C4 A EACE2898 9 4F83977F6B534D33B1FC5F5FF6B84FD4 68 A36F52C4 A EACE2898 9 29DE9F5558FD4461ADBD04D14E82C873 67 A36F52C4 A EACE2898 9 76AF054CE43A4E609E5FF4F2C0979CD2 66 A36F52C4 A EACE2898 9 B5B1EBB316084A0B8850693C5FD64DF5 65 A36F52C4 A EACE2898 9 B7AB6BBC436F41CEB167535C4F3613D6 64 A36F52C4 A EACE2898 9 CECDE601EB284748B4F4C1503B112ED4 63 A36F52C4 A EACE2898 9 DDABFF4E8C764FAA8A8915E327A680C5 62 A36F52C4 A EACE2898 9 C712D836768D4703BF4CDB91B99909EA 61 A36F52C4 A EACE2898 9 43504580C8B94575AE1D6602CE0A8112 60 A36F52C4 A EACE2898 9 80074E50CBE640F5A0970EA04F20EACE 59 A36F52C4 A EACE2898 9 38A9E82414284FADB3D30F2F06EAA6E9 58 A36F52C4 A EACE2898 9 DC28C5097C6B42BE84A64522BF4EC729 57 A36F52C4 A EACE2898 9 1F867EDF40DA4A468C199B5CB4D056BB 56 A36F52C4 A EACE2898 9 9BDB7994E01148AD8CDED71E7B053D25 55 A36F52C4 A EACE2898 9 1B5BACC1F1B745679C3867B241E6E0CB 54 A36F52C4 A EACE2898 9 6CB40F5B95434FC89FCBDAB15CE91357 53 A36F52C4 A EACE2898 9 348C05C0595E477DAE99502B6FFF3011 52 A36F52C4 A EACE2898 9 67C7B092C35F4496B3A091446F42AF09 51 A36F52C4 A EACE2898 9 394D774D705D4B89A3DFC767A4953E9A 50 A36F52C4 A EACE2898 9 8BB0AD8BFE10400A807B96E9F1B6DFF7 49 A36F52C4 A EACE2898 9 39038379C36A4F7CBE00782CF0CF2C97 48 A36F52C4 A EACE2898 9 12E8F8D178684FE0981D3000EF47DD49 47 A36F52C4 A EACE2898 9 2642867BA7D34D1BB5C592C64AE1A4C6 46 A36F52C4 A EACE2898 9 7CB856087B7D443485432C8FE2689EB4 45 A36F52C4 A EACE2898 9 6CB1023E5A094C8B80D855C86807F40F 44 A36F52C4 A EACE2898 9 C8084F581EAB4FF39B07552A10685829 43 A36F52C4 A EACE2898 9 6198231D50D64A5E9B51D4D829386259 42 A36F52C4 A EACE2898 9 FE7F80A3C3134A209010603BAD993F54 41 A36F52C4 A EACE2898 9 722977D9EEE24109B06028099CE3BB8F 40 A36F52C4 A EACE2898 9 C0E598A438314B0AB68AD574725AD4E3 39 A36F52C4 A EACE2898 9 69EF651E922141CB811ADAC01AE9EF02 38 A36F52C4 A EACE2898 9 410C308BE5B64043A03C09AA05C457FA 37 A36F52C4 A EACE2898 9 844E45EC8ADF4F698568336E4E6CD2DD 36 A36F52C4 A EACE2898 9 81477B6B96AD4C4F9E2349D267B2054D 35 A36F52C4 A EACE2898 9 314F143076354409909466CEC677ADC7 34 A36F52C4 A EACE2898 9 CD6EE746C81A4F608F57621B9A26F105 33 A36F52C4 A EACE2898 9 F06B9E05DC5240D4960F187DF2D8DA3C 32 A36F52C4 A EACE2898 9 E02F63F2E7BF4C31956A4DC0AF65AA30 31 A36F52C4 A EACE2898 9 D39EFCF94A5D4BA49CEEE2FEC68F9023 30 A36F52C4 A EACE2898 9 AC9EDB59F4A4494BA3DA5E17CB116026 29

## A36F52C4 A EACE2898 9 6CD3AE79D48D4974837E8E067D655424 28 A36F52C4 A EACE2898 9 369F3309533A4D1287962AEAE9367383 27 A36F52C4 A EACE2898 9 D1B2D3FA3B6142289D4EC8924BDE13CD 26 A36F52C4 A EACE2898 9 4960EC5F1EC1425D9491C503832F477A 25 A36F52C4 A EACE2898 9 0D80363FA663482094B107286D78131B 24 A36F52C4 A EACE2898 9 3B435DD61F49428FBDE1B271145AED69 23 A36F52C4 A EACE2898 9 D1433423A586451F8170ABBDA3481C18 22 A36F52C4 A EACE2898 9 1BBCF10BF6E342529E6BD44377FAC94B 21 A36F52C4 A EACE2898 9 520F0FEEBF244620810736BC3FCB82AA 20 A36F52C4 A EACE2898 9 BD64CAF557CE4DD098E14669988521F3 19 A36F52C4 A EACE2898 9 5EC868169B1B43A0B463CD193128FDBE 18 A36F52C4 A EACE2898 9 4A460162ECF34EA2AAF654AEF95589E1 17 A36F52C4 A EACE2898 9 760CF43C0CC04B918DAB5BA1606585BA 16 A36F52C4 A EACE2898 9 410703DA4B9C4735891E261C900F2FD7 15 A36F52C4 A EACE2898 9 9D91CDBFCD2846BDBD5EA3E9F99A68FD 14 A36F52C4 A EACE2898 9 FEA0540EDDEC4C09A7977779973D72A4 13 A36F52C4 A EACE2898 9 BFAD876BA0A6401E8D6557545664FB1F 12 A36F52C4 A EACE2898 9 7C7C31D033AA4F08B8C67AA9F2300F02 11 A36F52C4 A EACE2898 9 7D241BD511494E139004230942CA903D 10 A36F52C4 A EACE2898 9 43C348A84693487C957CEE750F6AEC8B 9 A36F52C4 A EACE2898 9 9C98927218EE4EF996A2BF03DB23FEB9 8 A36F52C4 A EACE2898 9 6C7A0D7388EC4DA6B18E63B33886E6F6 7 A36F52C4 A EACE2898 9 DBD0F09AF97D4C94A7E8F7569510D892 6 A36F52C4 A EACE2898 9 5269E98264A54A85B1472D2A6119E97B 5 A36F52C4 A EACE2898 9 6A23CAB8855E489F860F4C55709C433F 4 A36F52C4 A EACE2898 9 6DFB7F68C3324405970A0F69CCB28E09 3 A36F52C4 A EACE2898 9 D43B1CE421364251BE8AA464B4237C55 2 A36F52C4 A EACE2898 9 EDAC1FAD756B48638E5E399678C21EA3 1 A36F52C4 A 6CB4A0C7 05E954BDA79EE45AB883BFA3F41C6EB49 1 A36F52C4 A F357217C 1 D3A0E34DCFEA49CA9057FFE0C90EF5D2 40 A36F52C4 A F357217C 1 0D97FFA0D3F64A0497FD028FAADE1ADE 39 A36F52C4 A F357217C 1 208F5D0B908744F482BB4AB9C1A89540 38 A36F52C4 A F357217C 1 27E0DF104B0047D2838363026E28C6E8 37 A36F52C4 A F357217C 1 B7C96F0581B048789B708FF857069F20 36 A36F52C4 A F357217C 1 A151EBEBF10D4CEBADAD1816D05F3D1C 35 A36F52C4 A F357217C 1 BF57AB8446F640629F28955D4140197B 34 A36F52C4 A F357217C 1 9BE6D11E997C44D2B191C78CE633D0F0 33 A36F52C4 A F357217C 1 9E10EACEEB4A44AEA04A05E0BE1543BD 32 A36F52C4 A F357217C 1 F01E4870E8C04111A3ED63BE0D0E639C 31 A36F52C4 A F357217C 1 610BC4AA7B154203BF24B5742C78BE43 30 A36F52C4 A F357217C 1 A206184B7FB44AF0AC98AC2B9F0160DE 29 A36F52C4 A F357217C 1 D21C1C3B07FC4CF59C4074F27D4A7515 28 A36F52C4 A F357217C 1 3B92E58CA66C4488A7AADD4EFAF2D43C 27 A36F52C4 A F357217C 1 E45E880291F94FDF8FDAAC30557BA679 26 A36F52C4 A F357217C 1 2C1447EA150640AD8CEE5A8A93F71CA2 25 A36F52C4 A F357217C 1 3A86EDF90FBA4D6A88F8D8835DE9B239 24 A36F52C4 A F357217C 1 4436C73BC3E94F7AB93BD8B1F72D9FAC 23

## A36F52C4 A F357217C 1 5F87574FD734442BBB527D86B44D0CFA 22 A36F52C4 A F357217C 1 CDB79098016543CFA82FA07C0DF5A83C 21 A36F52C4 A F357217C 1 93AACE4194CC46B88257A66DD60F66CB 20 A36F52C4 A F357217C 1 F053117ED54B461BA3FD5B6968AA1CBC 19 A36F52C4 A F357217C 1 0B5933F7DAB14F99A7091B9B87EBFF07 18 A36F52C4 A F357217C 1 436770CCCC7441ABAD7B8601E9602EB5 17 A36F52C4 A F357217C 1 3A4C7FF336E74EE49699FD08BA651729 16 A36F52C4 A F357217C 1 AE6A8E83BA964CD7920C5864E0BCC507 15 A36F52C4 A F357217C 1 73B0166FD374448F8FF5ED4A14AFDDFD 14 A36F52C4 A F357217C 1 C6DDAF412E9241DCA785EEA69D6E4A21 13 A36F52C4 A F357217C 1 633D8E31C7394C68A168238BBA864F3B 12 A36F52C4 A F357217C 1 A10FE155D56F4717A2DCD661280CA693 11 A36F52C4 A F357217C 1 4002B3F05A0247D6B025825EA5A3AC5E 10 A36F52C4 A F357217C 1 8EF11B81EF2546D6B07D12725487FCBC 9 A36F52C4 A F357217C 1 F054B3F5B7E34E8593ED67632F682319 8 A36F52C4 A F357217C 1 079531AF65604AAE97A6F95C7AFEBC6F 7 A36F52C4 A F357217C 1 653753BCAF9D422BBF47FB6A60E602C6 6 A36F52C4 A F357217C 1 CC82051ABB7C4CBC96754514CF2DD1D6 5 A36F52C4 A F357217C 1 0DD65AF6D1F6406BA7AA252CE238EE25 4 A36F52C4 A F357217C 1 ED823FA8BE6141C9A3B9D2B0B078FCA9 3 A36F52C4 A F357217C 1 AC80D587AD5E47579CD306D9ADEC6638 2 A36F52C4 A F357217C 1 D0D042D4BE4945CA9FE32FBCE53FD833 1

## ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig

## ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig

## ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig

## ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig ######## ######## ######## Rig ######## ######## Rig

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

# Casing & Cement

www.SandRidgeEnergy.com Page 1/1 

## WEST RANCH 22-12 For String: Surface Casing Detail: Casing Description Surface Run Date 7/4/2006 00:00 Set Depth (ftKB) 1,500 Wellbore Original Hole Csg Cutoff (ftKB) Casing Cutoff Date Centralizers Scratchers
Casing Components:
Joints 1 Item Description

Casing Joints Icon Casing (black) OD (in) 7 ID (in) 6.366 Wt (lb/ft) 23.00 Grade K-55 Top Connection Thread Length (ft) 1,454.00 Top Depth (ftKB) 0.0 Btm (ftKB) 1,454.0 Joints 1 Item Description

Float Collar Icon Float collar OD (in) 7 ID (in) 6.366 Wt (lb/ft) 23.00 Grade K-55 Top Connection Thread Length (ft) 1.50 Top Depth (ftKB) 1,454.0 Btm (ftKB) 1,455.5 Joints 1 Item Description

Casing Joints Icon Casing (black) OD (in) 7 ID (in) 6.366 Wt (lb/ft) 23.00 Grade K-55 Top Connection Thread Length (ft) 43.00 Top Depth (ftKB) 1,455.5 Btm (ftKB) 1,498.5 Joints 1 Item Description

Guide Shoe Icon Casing shoe OD (in) 7 ID (in) 6.366 Wt (lb/ft) 23.00 Grade K-55 Top Connection Thread Length (ft) 1.50 Top Depth (ftKB) 1,498.5 Btm (ftKB) 1,500.0
Cementing Job Details: Description Surface Casing Cement Type Casing String Surface, 1,500ftKB Wellbore Original Hole Cementing Start Date 7/4/2006 00:00 Cementing End Date 7/4/2006 00:00 Cementing Company Key Comment

Cement Stage#1 Description: Stage Number 1 Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 1,500.0 Cement Volume Return (bbl)

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

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

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

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

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

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

Comment

Additive Details
Add Conc Conc Unit

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

# Casing & Cement

www.SandRidgeEnergy.com Page 1/1 

## WEST RANCH 22-12 For String: Production Casing Detail: Casing Description Production Run Date 7/19/2006 00:00 Set Depth (ftKB) 4,792 Wellbore Original Hole Csg Cutoff (ftKB) Casing Cutoff Date Centralizers Scratchers
Casing Components:
Joints 1 Item Description

Casing Joints Icon Casing (black) OD (in) 4 1/2 ID (in) 4 Wt (lb/ft) 11.60 Grade N-80 Top Connection Thread Length (ft) 4,746.00 Top Depth (ftKB) 0.0 Btm (ftKB) 4,746.0 Joints Item Description Float Collar Icon Float collar OD (in) 4 1/2 ID (in) 4 Wt (lb/ft) 11.60 Grade N-80 Top Connection Thread Length (ft) 1.50 Top Depth (ftKB) 4,746.0 Btm (ftKB) 4,747.5 Joints Item Description Casing Joints Icon Casing (black) OD (in) 4 1/2 ID (in) 4 Wt (lb/ft) 11.60 Grade N-80 Top Connection Thread Length (ft) 43.00 Top Depth (ftKB) 4,747.5 Btm (ftKB) 4,790.5 Joints Item Description Guide Shoe Icon Casing shoe OD (in) 4 1/2 ID (in) 4 Wt (lb/ft) 11.60 Grade N-80 Top Connection Thread Length (ft) 1.50 Top Depth (ftKB) 4,790.5 Btm (ftKB) 4,792.0
Cementing Job Details: Description Production Casing Cement Type Casing String Production, 4,792ftKB Wellbore Original Hole Cementing Start Date 7/19/2006 00:00 Cementing End Date 7/19/2006 00:00 Cementing Company Key Comment

Cement Stage#1 Description: Stage Number 1 Top Depth (ftKB) 540.0 Bottom Depth (ftKB) 4,800.0 Cement Volume Return (bbl)

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

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

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

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

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

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

Comment

Additive Details
Add Conc Conc UnitWELLBORE SCHEMATIC

Dev GL: 4,215' WELL NAME: West Ranch 22-12 SPOT: 330' FSL & 550' FEL ZONE: TESNUS OPERATOR : SANDRIDGE ENERGY KB: 4,232' API NO: 42-371-37664 LOCATION: SEC 22, BLK 2, TCRR SURVEY ELEVATION: 4,215' SPUD DATE: 07/02/06 WI: FIELD: PINON (OVERTHRUST) KB: 4,232' RR DATE: 07/19/06 RI: COUNTY: PECOS TD: 4,800' MICU: 08/01/06 CORP ID: STATE: TEXAS PBTD: 4,748' COMPL DATE: PIPE RECORD CEMENT & HOLE DATA CSG OD GRADE THD WT/FT TOP BTM # JTS BIT SZE DEPTH SXS TOC Cond Surface 7.000'' K-55 LT&C 23.00# 0' 1,500' 8.750'' 1500' 380 Surface Interm. TOC = 540' Prod 4.500'' J-55 LT&C 11.60# 0' 4,792' 6.125'' 4800' 400 540' (CBL) Tbg 2.375'' J-55 8rd EUE 4.70# 0' 2,343'

Well tools:

WELL HISTORY

DATE WORK DETAIL PROD. RESULTS Well History Hole Size = 08/03/06 Run CBL (540' TOC) & Perf Tesnus I - 4079-94', 4143-52', 4209-4213', 4219-24', 4264-73' 42', 84 holes 8-3/4" 08/21/06 Frac'd Tesnus I w/ 18# borate / 60Q N2 - Perf'd Tesnus II - 3782-86', 3792-98', 3804-22', 3830-36' - 34', 68 holes 130 MCFD Frac'd Tesnus II w/ 18# Borate / 70Q N2 09/07/06 MIRU WL - Set SCBP @ 3700'. Perf'd Tesnus III - 3476-92' 10/18/06 Frac'd Tesnus III w/ 18# Borate / 70Q N2 - Perf'd Tesnus IV - 3161-76', 3192-224' (47', 94 holes) - Frac'd Tesnus IV 160 MCFD 11/01/06 MIRU CU - Drill plugs and clean out to PBTD @ 4748' 11/27/06 MIRU WL - set SCBP @ 3050'. Perf'd Tesnus V - 2872-80', 2882-86', 2892-900', 2926-54', 2958-84' (88', 176 holes) 12/01/06 MIRU BJ - Frac'd Tesnus V w/ 20# Gelled Diesel / 40Q CO2 12/05/06 MIRU CU - bailed / clean sand 106 MCFD 01/04/07 MIRU - drilled plug / cleaned out to PBTD 02/20/08 MIRU Lariat P/Unit, unhung well, long-stroked pump, pump was stuck due to paraffin 7" csg @ 1500' TOH w/67 jts, 2 3/8" tbg to the 3/4" rods 02/22/08 Completed Stripping Rods/Tbg Out of hole, pump was stuck above S.N. TIH w/ 1 jt. M.A. (slotted) w/ bull plug, S.N., 44 jts., 4 1/2" TAC, 91 jts. 2 3/8" Tbg EOT @ 4309' S.N. @ 4288' TAC @ 2891' 02/23/08 Set TAC in 10-K tension, RIH w/ Pump. 2"x 1 1/2"x20' BHD Pump, On/Off Tool and 170 -3/4" rods Spaced Pump w/1-8', 1-6'x3/4" sub and 22'x 1 1/4" P/Rod. Hung Well On, and left well pumping. RDMO Lariat P/unit Hole Size = 04/29/08 Put well on line 129 MCFD 6-1/4" 02/01/10 MIRU WSU. Blow down to tank. Unhang well from pumping unit and unseat pump. TOH laying down 132 JTS 2 3/8" j-55 TBG & TAC. RDMO WSU 02/02/10 MIRU WL. Set 4 1/2" CFP @ 2600. Perf St 1 Tesnus 2326'-2383'. 60 deg phas. 78 holes OA. RDMO WL XN @ 2311' 02/13/10 MIRU Stim Crew. Frac Stg 1 Tesnus 2326'-2383'. RDMO Frac Equip. Plunger 02/14/10 MIRU FAU. Snubber. GIH W 2 3/8" NC, 1 JT 2 3/8", XN Nipple 1.875, packing bore W 1.791 no/go, w/ PT plug in place. GIH w/ 78 jts tbg & hit fill @ 2562'. Went thru bridge. LD tbg w/ EOT 2347.89'. RUN SL & Pulled PT plug. RD SL. Tesnus Stg 1 02/15/10 RDMO PIT Pump & Swivel. Hooking up to Sales on 20/64 CK, CO2 39 & TP 400# CSG P 535, LP 204

Perfs 02/24/10 Final Report: MCF=511, HRS=24, Choke=FO, SR=469, BOD=0, BWD=0, tbg=60, csg=130, CO2=5%, LP=60. 2326' 06/17/10 Slickline. Ran 1.916" broach to XN nipple @ 2311'; rec'd broach w/ paraffin on it. Ran full gauge scratcher to XN nipple; cut medium paraffin 0'-1540'. RIH, tagged 2500' & located 2383' EOT @ 2343'. Dropped ball & seat spring w/ 2-pad plngr; chased to nipple. Inst conventional plngr system w/ solid plngr. Cycled to sales. FR.

EOT @ 2343'

CFP @ 2600
Drilling Notations:

Tesnus V 2872-2984'

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

8/21/06 Tensus I 172 1439 18# Borate / 60Q N2 20/40 Brady 32 / 3572 ISIP=2513 08/03/06 4,079' 4,242' Tesnus I 2 (84) / 90 deg Producing
Tesnus IV 8/21/06 Tesnus II 122 1030 18# Borate / 70Q N2 20/40 Brady 36 / 3478 ISIP=2248 08/21/06 3,782' 3,836' Tesnus II 2 (68) / 90 deg Producing
3161-3224' 10/18/06 Tesnus III 447 18# Borate / 70Q N2 16/30 White 35 / 3377 ISIP=2154 09/07/06 3,476' 3,492' Tesnus III 2 (32) / 90 deg Producing 10/18/06 Tesnus IV 508 18# Borate / 70Q N2 16/30 White 35 / 2930 ISIP= ? 10/18/06 3,161' 3,224' Tesnus IV 2 (94) / 90 deg Producing 12/1/06 Tesnus V 95 1129 20# Gelled Diesel / CO2 20/40 White 23 / 2500 ISIP = 1503 11/27/06 2,872' 2,984' Tesnus V 2 (176) / 90 deg Producing 2/13/10 Tesnus stg 1 195 845 20# Linear & 70Q CO2,7%KCL 20/40 OTT 45.6/2764 ISIP = 2000

Frac Job Remarks (Screenouts or problems in Frac job): Tesnus V - chemicals in diesel were not pumped correctly - almost no load recovery 02/02/10 2,380' 2,383' Tesnus stg 1 4(12)/60 Deg 2,374' 2,378' Tesnus stg 1 4(16)/60 Deg
Tesnus III CIBP Record 2,348' 2,358' Tesnus stg 1 3(30)/60 Deg
3476-3492' Date Depth Type 2,326' 2,336' Tesnus stg 1 2(20)/60 Deg

2/2/2010 2,600' CFP

Tesnus II
3782-3836' Remarks:

Downhole Jewelry
Tesnus I Length Depth Description ID Drift Collapse* Burst* Tensile*
4079-4242' Material (Haliburton Handbook) (in) (in) (psi) (psi) (Klbs)
'' # 7'' K-55 LT&C 23# 6.366 6.241 3,270 4,360 366
'' # 4.5'' J-55 LT&C 11.6# 4.052 3.927 4,010 4,790 132 2.375'' J-55 8rd EUE 4.7# 1.995 1.901 8,100 7,700 72
'' # * Safety Factor Not Included REMARKS

ENGINEER: Justin R. Davis GEOLOGIST: Tom Daugherty LANDMAN: James Reynolds PREPARED BY: Justin R. Davis PREPARED DATE: 1/15/2007 UPDATED: PBTD @ 4748' UPDATED: UPDATED: 4-1/2" csg @ UPDATED: 2/16/2010 Luke Wyckoff UPDATED: TD @ 4800' 4792' 12885 75.110000%

KeyLite w/ 2% CaCl

N.Asaad/G.Rowe 12/7/09 8.19.11 MF 99.920000%

TYPE

Class "C" + additives

Date Removed Notes

TUBULAR GOODS PERFORMANCE

Packer Detail: TAC @ 2891'WELLBORE SCHEMATIC

GL: 4150' WELL NAME: WEST RANCH #23- 3 SPOT: 1460' FNL & 1385' FEL ZONE: Caballos OPERATOR: SandRidge Energy, Inc. KB: 4167' API NO: 42-371-37381 LOCATION: Sec 23, Blk 2, TCRR Survey ELEVATION: 4,150' SPUD DATE: 05/17/04 WI: FIELD: Pinon KB: 4,167' RR DATE: RI: 71.26000% COUNTY: PECOS TD: 9,500' MICU: STATE: TEXAS PBTD: 8,575' est COMPL DATE: 08/18/04 PIPE RECORD CEMENT & HOLE DATA CSG OD GRADE THD WT/FT TOP BTM # JTS BIT SZE DEPTH SXS TOC Surface 13-3/8" J-55 ST&C 54.6 & 68# 0' 1,440' 17.500'' 1440' 270 surface Surface 9.625'' K, N & P LT&C 40.00# 0' 5,909' 12.250'' 5909' 44, 1320 4550 TOC = 2450' Interm. 7.000'' N-80 LT&C 26.00# 5771' 7,602' 8.750'' 7602' 974 5771 (O-H log calc) Prod. 4.500'' N-80 LT&C 11.60# 0' 3,601' 6.125'' 8654' 180 7100'

13-3/8" @ 1,440'

Well tools: DV Tool @ 4391' cmt'd w/ 1320 sx "C" 50/50 POZ Hole @ 1,480' (11/23/2009) Sqz'd with 200 sx WELL HISTORY (12/3/2009) DATE WORK DETAIL PROD. RESULTS 10/27/04 AOF=4300 mcfd, SIBHP 1450#, CO2 38.264%. 09/11/04 Swab: SITP/CP=0, BFL 2700', 5 runs, well started flowing. 09/10/04 RIH w/notched collar, SN, 264 jts 2-3/8" tbg, tag sd 8,391 Pkr @ 3,594' 09/01/04 CO2=19.4% XN nipple @ 3601' 08/31/04 Test csg to 5000# for 15 minutes, perf'd well, Break down perfs @ 4100 psi, went to 3200 psi. Pump-in rates 2 bbls/min @ 1700#, 2.5 bbls/min @ 2100#, 4.5 bbls/min @ 2300#. Pumped 30 bbls. ISIP = 900 psi. SWI, Open 22 CK, bled down in less than a minute. Left well open to pit on 22 CK, SDFN. EOT: 3,601' (12/15/200 9 08/27/04 Release drilling rig. 07/10/08 MIRU GREAT WHITE SLICK LINE UNIT. RIH W 1.75 SAMPLE BAILER. LOCATE NIPPLE @ 8284 AND TD @ 8360. POOH RDMO SLU
Tesnus: 07/12/08 MIRU SLB WLU, CRANE & GYRO DATA. RIH WITH GYRO TOOLS. LOG FROM EOT @ 8250' TO SURFACE. RDMO ALL EQUIPMENT. RETURN WELL TO SALES 3722'-3946' 09/27/08 24 HR 250# VENT TEST RESULTS,TP=260,CP=475,LP=249,SR=1552,CUM GAS=1931 MCF,RESULTS ARE AFTER A LONG SHUT IN DUE TO GREY RANCH,STARTED 50# TEST 3982'-4030' 09/30/08 Results of 50 psi test; 947 mcf for 24 hrs, 847 mcf @ end of test, 95 psi ftp, 330 sicp, 75 psi line psi, RDMO test unit leave well SI (12/3/2009) 10/06/09 Tag PBTD @ 8384'. TOH. PU & TIH w/WEG, 1.791 XN Nipple, 6'x2-3/8" pup, 4-1/2 AST 1X pkr w/T-2 on/off tool, 1 jt, 1.875 X nipple & 2-3/8 tbg Set pkr @ 8282' XN @ 8295', T-2 @ 8281', WEG @ 8296' ND BOP, NU Tree 10/08/09 Swab well and turn to sales on 8/64 choke 51% CO2 10/15/09 Slickline. Ran GR & tagged 8353'. Located EOT @ 8340'. Ran BHP survey. SIFBU 10 days. SITP - 135 psi; SICP - 0 psi. 10/29/09 Pulled BHP gauges. Left SI. SITP - 400 psi. 10/30/09 Rtnd to sales. 92 MCF (spot); FTP - 389 psi; SICP - 0 psi; LP - 91 psi. CO2 - 49.5%. 11/16/09 Rel'd pkr @ 8282'. TOH w/ 264 jts tbg & LD pkr. Set 4-1/2" CFP @ 8300'. 11/17/09 Welded 4-1/2" pull nipple to csg & pulled 1400000#. Worked csg; could not move csg to remove slips. 11/18/09 to 11/19/2009. Pulled 124000# on 4-1/2" csg; rmvd slips & wrap around. Ran freepoint: csg free @ 6865'; chem cut @ 6865'. TOH & LD 4-1/2" csg; 154 total jts. DV Tool @ 4391' 11/20/09 Dressed off cut off 4-1/2" csg. 11/21/09 Logged 6800'-950'. TOC @ 1150'. 11/22/09 Set RBP @ 7350'. Pressured csg to 1200 psi & 1.5 bpm. TOC: 4,550' 11/23/09 TIH w/ 9-5/8" test pkr to 5726'. PT 7" liner & csg to 2000 psi. PT 9-5/8" csg to 1200 psi. Rel'd test pkr & pulled abv DV tool @ 4366'. Set pkr & tstd annulus to 1200 psi pmpg @ 2 bpm. Pulled OH tstg to 1480'. Tstd tbg to 2000 psi & annulus to 1200 psi. Tstd annulus abv 1480' to 2000 psi; tbg tstd to 1200. TOH w/ tbg & LD test pkr. SDFN. 11/24/09 MIRU WL. RIH w/ CCL/dump bailer to top of 4-1/2" csg @ 6880'; made several unsuccessful attempts but unable to go thru csg. POH. RD WL. TIH w/ muleshoe, XN nipple & tbg to 7075'; dmpd 23' sd (approx) & pmpd 15 bbls 7% KCL. TOH. TIH w/ sqz pkr, XN nipple & tbg & set @ 1460'. SDFN. 11/25/09 Set sqz pkr @ 1460' & tstd annulus to 1000 psi. Pmpd 200 sx Class C cmt @ 1000 psi & 1 bpm; press dropped to 900 psi & 1 bpm; final pump press 1074 psi. TOL @ 5,771' rel'd pkr. Rev circ clean. TOH w/ 10 jts tbg. Set pkr & pressured to 1050 psi. RD cmtrs. 11/28/09 to 11/30/2009: TP-1050 psi. Bled dn. Rel'd sqz pkr. TOH & LD pkr. TIH w/ rock bit, sub, XO's, DC's, XN nipple & tbg to TOC @ 1424'. Brk circ. Drld cmt to 1569'; 9 5/8" @ 5,909' v hd drlg. Circ clean. Contd DO cmt to 1878'; hd drlg. 12/1-2 TOH. Drld 162' cmt 1878'-2040'. Total 616' cmt drld. Contd TIH w/ tbg to 2123'. Test sqz'd 9-5/8" csg to 1200 psi 30 min. Rev circ clean to 7350' & rel'd RBP . . @ 7350'. Tstd csg to 1200 psi. TOH w/ tbg & LD RBP. SWI & SDFN. 12/03/09 Perf'd Tesnus 3982'-4030'; 126 holes OA. TIH & set pkr @ 2603 psi. BD perfs @ 2500 psi w/ 20 bbls 7% KCL. Rel'd pkr. TOH w/ tbg. Cont'd perf'g 3722'-3946'. 12/04/09 TIH w/ WEG, XN nipple, subs, AS1X pkr, on/off tool, XO & 82 jts 4-1/2" tbg & set pkr @ 3648' w/ 20 pts compression; XN nipple @ 3648', X profile @ 3631'. Pressured csg & tstd pkr to 1000 psi. SWI & SDFN. WOF. 12/14/09 Attempted unsuccessfully to frac Tesnus Sd. SD due to leak betw tbg & csg. 22 TLTR. Rel'd pkr. 12/15/09 TOH & LD tbg & AS1X pkr. TIH w/ WEG, XN nipple, subs, AS1X pkr, T2 on/off tool, XO & tbg; hydro tstd tbg to 7000 psi. Set pkr @ 3594' w/ 20 pts compression; XN @ 3601'. PT csg to 750 psi. Bled off. SWI. WOF. 12/16/09 TOH & LD tbg. 12/17-19 PT 9-5/8" csg to 500 psi. Loaded/pmpd 4-1/2" csg @ 2148 psi & 6 bpm. Frac'd Tesnus. Rtnd to sales; SR - 1538 MCF. 12/20-21 Set plug in XN nipple @ 3601'. Blew dn. Rel'd & latched onto on/off tool. Pulled plug fr/ X nipple. Set plug @ 3580'. TOH & LD tbg. 12/23/09 Landed tbg in hanger w/ 7 pts compression. Pulled plug. Tied into flowlines. Rtnd to sales. SR - 1165 MCF. FINAL REPORT: 1/3/2010 - 853 MCF.

Drilling Notations:

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

9/8/08 3 111 3630 Gelled 20% HCL+slick H2O 30/70 ?/3980 ?/2255 08/31/04 8,352' 8,382' 3rd Caballos 4 spf/90 Inactive
Chemical cut 4 1/2" @ 12/14/09 Tes Sd none 22 n/a n/a 12/03/09 3,722' 3,728' Tesnus Sand 1 SPF/60 Active 6,865' (11/18/2009) 12/18/09 Tes Sd 181 849 20# LG/70Q CO2 20/40 Ott/SLC 55.3/4203 n/a 12/03/09 3,748' 3,756' Tesnus Sand 1 SPF/60 Active 12/03/09 3,772' 3,782' Tesnus Sand 1 SPF/60 Active 12/03/09 3,818' 3,822' Tesnus Sand 2 SPF/60 Active TOC: 6,600' (11/21/2009 Frac Job Remarks (Screenouts or problems in Frac job): 12/03/09 3,902' 3,906' Tesnus Sand 3 SPF/60 Active 12/14/09: frac stopped due to communication betw. 4-1/2" tbg & 9-5/8" csg. 12/03/09 3,940' 3,946' Tesnus Sand 3 SPF/60 Active 7" liner @ 7,602' 12/03/09 3,982' 3,992' Tesnus Sand 4 SPF/60 Active CIBP Record 12/03/09 4,024' 4,030' Tesnus Sand 4 SPF/60 Active
Date Depth Type

Remarks:

Downhole Jewelry Length Depth Description ID Drift Collapse* Burst* Tensile* Material (Haliburton Handbook) (in) (in) (psi) (psi) (Klbs)

9.625'' K, N & P LT&C 40# 8.921 8.765 2,020 3,520 394,000 7'' N-80 LT&C 26# 6.276 6.151 5,410 7,240 519,000 4.5'' N-80 LT&C 11.6# 4.000 3.875 6,350 7,780 223,000
'' #
3rd Caballos '' #
8352-82' * Safety Factor Not Included
REMARKS

Tag SD 8360 7/10/08 ENGINEER: GEOLOGIST:
LANDMAN:
PREPARED BY:
PREPARED DATE: UPDATE D PBTD @ 8575' UPDATED: UPDATE D TD @ 9500' UPDATED: UPDATED: TUBULAR GOODS PERFORMANCE

Packer Detail:

9.2.11 SK 8.23.11 MF 5/20/2008 Greg Carlisle

8/20/2009 FJC "H" 50/50 POZ

Date Removed Notes "H" 50/50 POZ CURRENT

95.01000%

TYPE 250 sx C 50/50 & 150 sx LITE

"C" 50/50, 2 stage cmtSandRidge Energy Daily Completions ReportWR 31-32 - SandRidge EnergyReport Start DateReport End DateDaily SummaryDaily Production Summary10/7/2009 10/8/2009 R&C 5 1/2" 17# N-80 csg @ 6020'. Rig released 10/8/09. Temporarily drop fr/ report.10/10/2009 10/11/2009 WOCU.10/11/2009 10/12/2009 SI; WO frac sch 10/15.10/12/2009 10/13/2009 SI; WO frac sch 10/15.10/13/2009 10/14/2009MIRU WSU. TIH w/ bit, sub, DC's, XO, & 36 jts tbg & tagged cmt @ 1,390'. Brk circ. Washed &DO cmt to DV tool 1,430'; DO DV tool. Circ clean. TOH abv DV tool. SWI & SDFN.10/14/2009 10/15/2009Cont TIH to 5,947'. Dsplc'd csg w/ 190 bbls 2% KCL. TOH & LD tbg & BHA. ND BOP & NU capflange. RDMO WSU. SDFN. Prep f/ WL. Rec'd 0 MCF, 0 BO, 0 BLW (190 LLTR).10/15/2009 10/16/2009MIRU WL. RIH w/ CCL/GR/CBL & logged 5,930'-4,470'. TOC @ 4,670'. POH. Tstd csg to 4800psi. Perf'd 2nd Cab 5,700'-5,702'; 5,756'-5,758' w/ 4 SPF using 3-1/8" csg guns 60 deg phased.BD @ 3000 psi w/ 30 bbls 2% KCL. Cont perf'g 5,406'-5,416'; 5,468'-5,476' w/ 2 SPF; 5,558'-5,560'; 5,575'-5,579'; 5,605'-5,607' w/ 3 SPF; 5,637'-5,640' w/ 4 SPF (88 holes OA). RDMO WL.SDFN.10/16/2009 10/17/2009MIRU WL. RIH w/ CCL/CBL & logged 2,500'-sfc. FL @ 1,400'. RDMO WL. SWI & SDFN. WOfrac sch 10/21.10/17/2009 10/18/2009 SI; WO frac sch 10/21.10/18/2009 10/19/2009 SI; WO frac sch 10/21.10/19/2009 10/20/2009 Inst hydraulic frac valve. SI; WO frac resch 10/22.10/20/2009 10/21/2009 SI; WO frac sch 10/22.10/21/2009 10/22/2009 MIRU frac services. SDFN. Prep to frac.10/22/2009 10/23/2009BD 2nd cab w/ 2% KCL & 6.2 bpm & 2223 psi. Started acid & ball dropper failed; flushed acid tobtm perf. Acidized w/ 7-5% NeFe HCL @ 6.5 bpm & 1720 psi. Dropped 120 balls; good action.1676 psi - ISIP. SI 30 min. Frac'd w/ 25# linear gel, 45Q CO2, 85M lbs 100# Mesh, 30/50 Ottawa& 20/40 TLC, 2035 TLTR, 952 bbls CO2. SI 4 hrs. Opened to tank; flwg back load after frac.Rec'd 0 MCF, 0 BO, 147 BLW (1888 LLTR), 12/64 choke @1320 psi - FCP.10/23/2009 10/24/2009MIRU WSU & snub unit. TIH w/ NC, PO sub, XN nipple & 166 jts tbg & landed tbg @ 5,400'.RDMO snub unit. ND frac valve & BOP. NU tree. PO NC. RDMO WSU. Flwg to tank.Rec'd 0 MCF, 0 BO, 514 BLW (1374 LLTR), 16/64 choke @1040 psi - FTP; 1330 psi - FCP.10/24/2009 10/25/2009 FIRST SALES @ 3:20 p.m. on 10/24/09.1014 MCF (spot), 0 BO, 206 BLW (1168 LLTR), 16/64 choke@ 1000 psi - FTP; 1360 psi - FCP; 58 psi - LP.10/25/2009 10/26/2009 Flwg to sales.390 MCF, 0 BO, 67 BLW (1101 LLTR), 9 hrs on 30/64 choke@ 500 psi - FTP; 600 psi - SICP; 55 psi - LP.10/26/2009 10/27/2009 Flwg to sales.771 MCF, 0 BO, 47 BLW (1054 LLTR), 24 hrs on 1" choke @52 psi - FTP; 230 psi - SICP; 51 psi - LP.10/27/2009 10/28/2009 Flwg to sales.434 MCF, 0 BO, 25 BLW (1029 LLTR), 24 hrs on 1" choke @48 psi - FTP; 120 psi - SICP; 48 psi - LP.10/28/2009 10/29/2009MIRU SLU. RIH & tagged 5,880'; EOT @ 5,386'. POH. RIH w/ broach to 5,352' (SN). POH.RDMO SLU. Inst bypass plngr & cycled to sales.322 MCF, 0 BO, 15 BLW (1014 LLTR), 24 hrs on 1" choke @51 psi - FTP; 140 psi - SICP; 51 psi - LP.10/29/2009 10/30/2009 Flwg to sales on plngr.279 MCF, 0 BO, 7 BLW (1007 LLTR), 18 hrs on 1" choke @100 psi - FTP; 100 psi - SICP; 48 psi - LP.10/30/2009 10/31/2009 Flwg to sales on plngr.254 MCF, 0 BO, 10 BLW (997 LLTR), 20 hrs on 1" choke @55 psi - FTP; 65 psi - SICP; 49 psi - LP.1 of 2SandRidge Energy Daily Completions Report10/31/2009 11/1/2009 Flwg to sales on plngr.231 MCF, 0 BO, 7 BLW (990 LLTR), 22 hrs on 1" choke @ 40psi - FTP; 60 psi - SICP; 49 psi - LP.11/1/2009 11/2/2009 Flwg to sales on plngr.214 MCF, 0 BO, 6 BLW (984 LLTR), 22 hrs on 1" choke @ 49psi - FTP; 63 psi - SICP; 49 psi - LP.11/2/2009 11/3/2009 Flwg to sales on plngr.200 MCF, 0 BO, 7 BLW (977 LLTR), 23 hrs on 1" choke @ 50psi - FTP; 50 psi - SICP; 50 psi - LP.11/3/2009 11/4/2009 Flwg to sales on plngr. FINAL REPORT.191 MCF, 0 BO, 5 BLW (972 LLTR), 23 hrs; 50 psi - FTP; 50psi - SICP; 48 psi - LP.2 of 2

### 10/22/09

WELL NAME: REPORT DATE: 

### 10-22-09 to 10-23-09 ZONE NAME: COUNTY 

### Pecos STAGE NUMBER: FIELD: Pinon 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 07:00 0 0 0 08:00 0 0 0 09:00 0 0 0 10:00 0 0 0 11:00 0 0 0 12:00 0 0 0 13:00 0 0 0 14:00 0 0 0 15:00 0 0 0 16:00 0 0 0 17:00 0 0 0 18:00 0 0 0 19:00 0 0 0 20:00 0 0 0 21:00 0 0 0 22:00 0 0 0 SIP 1850 PSI 23:00 12 1,680 0 0 2,035 Opened up well at 11:00 P.M 24:00 12 1,480 25 25 25 2,010 01:00 12 1,420 24 49 49 1,986 02:00 12 1,400 25 74 74 1,961 03:00 12 1,380 25 99 99 1,936 04:00 12 1,340 25 124 124 1,911 05:00 12 1,320 23 147 147 1,888

TOTAL LOAD TO RECOVER: 2035 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 147 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 147 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 1888 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 7 % Today's Date:

Gary (432) 360-6272 

### FLOWBACK SUMMARY

FLOWBACK HANDS : James C. Ely (432) 360-5346 

# SANDRIDGE ENERGY INC. FLOWBACK REPORT

TL =2035 BBLS. DLR = 147 BBLS. TLR = 147BBLS. LTR = 1888 BBLS. 7% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS. 

### West Ranch 31-32

### 10/23/09

WELL NAME: REPORT DATE: 

### 10-23-09 to 10-24-09 ZONE NAME: COUNTY 

### Pecos STAGE NUMBER: FIELD: Pinon 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 1,300 25 25 172 1,863 07:00 12 1,260 23 48 195 1,840 08:00 12 1,220 25 73 220 1,815 Shut in for wireline @8:20 A.M 09:00 14 1,220 6 79 226 1,809 Opened up @ 9:00 A.M to tank 10:00 14 1,200 25 104 251 1,784 11:00 14 1,140 25 129 276 1,759 12:00 12 1,140 22 151 298 1,737 13:00 12 1,140 23 174 321 1,714 14:00 12 1,160 25 199 346 1,689 Flowing to Tank 15:00 12 1,180 11 210 357 1,678 16:00 16 1,120 23 233 380 1,655 Flowing to Tank 17:00 14 1,120 25 258 405 1,630 18:00 14 1,120 23 281 428 1,607 Flowing to Tank 19:00 14 1,000 1,240 20 301 448 1,587 20:00 14 1,150 1,220 20 321 468 1,567 Flowing to Tank 21:00 14 1,200 1,220 25 346 493 1,542 22:00 14 1,150 1,240 19 365 512 1,523 Flowing to Tank 23:00 14 1,150 1,260 25 390 537 1,498 24:00 14 1,175 1,280 18 408 555 1,480 Flowing to Tank 01:00 14 1,175 1,300 13 421 568 1,467 02:00 16 1,150 1,320 20 441 588 1,447 Flowing to Tank 03:00 16 1,100 1,320 25 466 613 1,422 04:00 16 1,040 1,330 23 489 636 1,399 Flowing to Tank 05:00 16 1,040 1,330 25 514 661 1,374 Flowing to Tank

TOTAL LOAD TO RECOVER: 2035 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 514 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 661 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 1374 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 32 % Today's Date: 

# SANDRIDGE ENERGY INC. FLOWBACK REPORT
West Ranch 31-32

TL =2035 BBLS. DLR = 514 BBLS. TLR = 661 BBLS. LTR = 1374 BBLS. 32% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS :

### 10/24/09

WELL NAME: REPORT DATE: 

### 10-24-09 to 10-25-09 ZONE NAME: COUNTY 

### Pecos STAGE NUMBER: FIELD: Pinon 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 16 1,040 1,320 23 23 684 1,351 Flowing to tank 07:00 16 1,020 1,340 21 44 705 1,330 08:00 16 1,020 1,340 20 64 725 1,310 Flowing to tank 09:00 16 1,020 1,360 25 89 750 1,285 10:00 16 1,020 1,360 18 107 768 1,267 Flowing to tank 11:00 18 1,000 1,360 20 127 788 1,247 12:00 18 1,000 1,360 21 148 809 1,226 Flowing to tank 13:00 18 1,000 1,360 20 168 829 1,206 14:00 18 1,000 1,360 18 186 847 1,188 Flowing to tank 15:00 18 1,000 1,320 20 206 867 1,168 16:00 24 1,000 1,320 937 16 222 883 1,152 Turned to sales @ 3:20 P.M 17:00 24 1,000 1,300 859 12 234 895 1,140 18:00 24 1,000 1,300 801 14 248 909 1,126 19:00 24 900 1,200 1,051 7 255 916 1,119 20:00 28 900 1,200 1,083 7 262 923 1,112 21:00 28 900 1,150 1,101 7 269 930 1,105 22:00 28 900 1,100 1,141 9 278 939 1,096 23:00 28 850 1,100 1,053 9 287 948 1,087 24:00 28 825 1,000 1,212 8 295 956 1,079 01:00 28 800 950 1,297 10 305 966 1,069 02:00 28 750 900 1,167 9 314 975 1,060 03:00 28 700 800 1,284 8 322 983 1,052 04:00 28 700 800 1,164 8 330 991 1,044 05:00 28 650 750 1,235 7 337 998 1,037

TOTAL LOAD TO RECOVER: 2035 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 337 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 998 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 1037 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 49 % TL =2035 BBLS. DLR = 337 BBLS. TLR = 998 BBLS. LTR = 1037 BBLS. 49% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Today's Date: 

# SANDRIDGE ENERGY INC. FLOWBACK REPORT
West Ranch 31-32

### 10/25/09

WELL NAME: REPORT DATE: 

### 10/25/09 ZONE NAME: COUNTY 

### Pecos STAGE NUMBER: FIELD: Pinon 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 28 600 600 955 8 8 1,006 1,029 07:00 28 600 600 929 8 16 1,014 1,021 08:00 28 550 600 839 10 26 1,024 1,011 09:00 28 500 600 813 7 33 1,031 1,004 10:00 28 500 600 785 4 37 1,035 1,000 11:00 37 1,035 1,000 12:00 37 1,035 1,000 13:00 37 1,035 1,000 14:00 37 1,035 1,000 15:00 37 1,035 1,000 16:00 37 1,035 1,000 17:00 37 1,035 1,000 18:00 37 1,035 1,000 19:00 37 1,035 1,000 20:00 37 1,035 1,000 21:00 37 1,035 1,000 22:00 37 1,035 1,000 23:00 37 1,035 1,000 24:00 37 1,035 1,000 01:00 37 1,035 1,000 02:00 37 1,035 1,000 03:00 37 1,035 1,000 04:00 37 1,035 1,000 05:00 37 1,035 1,000

TOTAL LOAD TO RECOVER: 2035 BBLS DAILY SAND RECOVERY: SACKS DAILY LOAD RECOVERY: 37 BBLS TOTAL SAND RECOVERED : SACKS TOTAL LOAD RECOVERED: 1035 BBLS DAILY OIL RECOVERY: BBLS LOAD LEFT TO RECOVER: 1000 BBLS TOTAL OIL RECOVERED: BBLS % OF LOAD RECOVERED: 51 % TL =2035 BBLS. DLR = 37 BBLS. TLR = 1035 BBLS. LTR = 1000 BBLS. 51% OF LOAD RECOVERED. WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.



### FLOWBACK SUMMARY

FLOWBACK HANDS : Today's Date: 

# SANDRIDGE ENERGY INC. FLOWBACK REPORT
West Ranch 31-32

### Date: 10/22/2009 6200 psig

Formation: Perfs:
SPF: 88 410 psig

Breakdown Acid Job Acid Frac XXX Sand Frac Other:

126 bbl Flush: 124 bbls

2,233 6:41 PM

Total Holes: ISDP: psi/ft Holes Open: Fluid Eff: (%) Max Rate: Calc. Perm: psig Max Pressure: Pc (psig) psig psig

Amount Type

2,000 30/50 Ottawa
2,322 30/50 Ottawa
5,731 30/50 Ottawa
11,047 30/50 Ottawa 21,100 Total

BBLS BLTR: 64218.0 Gals

LBS

45 % tons CO2

0
3,617 psig 3878 psig
79.4 bpm 81 bpm 

## ISIP = 1,925 psig

Yes 2.0

NO 4 Breakdown Pressure: Stimulation Company:

Start Time: psig Liner Depth

2-4spf

Displacement: 45Q CO2 Foam Frac SandRidge Supervisor(s):

1 2nd Caballos 5 1/2" Pipe 2 Size: Johnny Anaya Displ Coef:

End Time: Top Perf Depth

3:29 PM

66 76 Superior

Flush 2% KCL Water *6.5 bpm @ *1666 psi ISIP=1676 (Surge Balls) SD 30min 76 FLUIDS PUMPED Acid Ballout

107 478 Pad 25# Linear Gel/45Q CO2 *79 bpm @ *3535 psi 5 min SIP:

Flush 2% KCL Water *6.9 bpm @ *1802 psi (((SEE REMARKS))) ISIP=1758
112 Acid 7 1/2% NEFE HCL/w 120 1.3 s.g. BS *6.5 bpm @ *1720 psi 126 10 min SIP:

Proppants
Acid 7 1/2% NEFE HCL/w 120 1.3 s.g. BS *6.1 bpm @ *1800 psi Amount Load & Breakdown 2% KCL Water *6.2 bpm @ *2223 psi 26

*21,100# 30/50 Ottawa, *51,080# 20/40 Ottawa, *12,472# 20/40 SLC. Total Load=2035, Total Prop=84,652#. Job Called for 100 Mesh and no 100 Mesh was ordered. The decision was made to go ahead and replace 100 Mesh w/30/50 Ottawa Cutting the Concentrations in Half. While Pumping Ball Job, Superior was about to Make 1st Ball Drop and Ball Gun Quit working. Displaced Acid to Bottom Perf and waited on Replacement. Superior had extra Acid on Location. Started job over. Ran Radioactive Tracer as per Design. Foam Quality:

Was Treatment Underdisplaced? Avg Treating Press= Maximum = Was there ball action seen? How many ball sealers were pumped: 0

Remarks/Notes Avg Treating Rate = Maximum = Amount of Foam Pumped: 170DH/5CD Frac Grad:

Pad 25# Linear Gel/45Q CO2 *80.3 bpm @ *3694 psi
Pad 25# Linear Gel/45Q CO2 *81 bpm @ *3655 psi

1.5ppg 25# Linear Gel/45Q CO2 *79.8 bpm @ *3748 psi

See Remarks 

# SandRidge Energy, inc.

Treatment Type: Well Name:

Total # of Holes: SICP= Max Pressure:

Stage/Zone # : Treatment Report West Ranch 31-32

5406-5758

69 135

.4ppg 25# Linear Gel/45Q CO2 *80 bpm @ *3720 psi 81 (Hit 1 *6.6bpm @ *1676psi) (Hit 2 *6.5bpm @ *1685psi) (Hit 3 *6.5bpm @ *1694psi) (Hit 4 *6.5bpm @ *1722psi) (Hit 5 *6.5bpm @ *1831psi) (Hit 6 *6.5bpm @ *1939psi)

Pad 25# Linear Gel/45Q CO2 *79.9 bpm @ *3714 psi 1ppg 25# Linear Gel/45Q CO2 *79.9 bpm @ *3674 psi Pump-in 2% KCL Water *6.6 bpm @ *1693 psi

.25ppg 25# Linear Gel/45Q CO2 *79.8 bpm @ *3536 psi

1,529

Type of foam: 5406

Was well flowed back immediately? If not, well was shut-in hours before flowing back. If so, by how many bbls/gal? 98 14

65

X-Link Breaker Time: Total Fluid Pumped:
Total Proppant: 21,100 Continued

Type of Proppant: Pipe 1 Size: 0.02324 Displ Coef:

### Date: 10/22/2009 6200 psig

Formation: Perfs:
SPF: 88 psig

Breakdown Acid Job Acid Frac XXX Sand Frac Other:

126 bbl Flush: 124 bbls

Total Holes: ISDP: psi/ft Holes Open: Fluid Eff: (%) Max Rate: Calc. Perm: psig Max Pressure: Pc (psig) psig psig

Amount Type

8,022 20/40 Ottawa 10,443 20/40 Ottawa 16,279 20/40 Ottawa 16,336 20/40 Ottawa 12,472 20/40 SLC

21,100

84,652 Total

BBLS BLTR: 85470.0 Gals

LBS

% tons

0
psig psig
bpm bpm 

## ISIP = psig

YES 2.0

NO N/A Was Treatment Underdisplaced? If so, by how many bbls/gal?
Was well flowed back immediately? If not, well was shut-in hours before flowing back.

Remarks/Notes Avg Treating Press= Maximum =
Avg Treating Rate = Maximum = How many ball sealers were pumped: Was there ball action seen? N/A X-Link Breaker Time: NA Foam Quality: Amount of Foam Pumped: Type of foam: psig Start Time:

Total Fluid Pumped: 2,035 45Q CO2 Foam Frac
Stimulation Company: Superior Displacement:

End Time:

FET ANALYSIS Frac Grad:

2ppg 25# Linear Gel/45Q CO2 *78 bpm @ *3467 psi

Total Proppant: 84,652 Type of Proppant: 63

Continued fro Previous Page 60 4ppg 25# Linear Gel/45Q CO2 *79.4 bpm @ *3593 psi 124 68

Flush 2% KCL Water *50.5 bpm @ *2608 psi 1ppg 25# Linear Gel/45Q CO2 *78.2 bpm @ *3549 psi 2nd Caballos 5406-5758 Liner Depth

1 2-4spf Total # of Holes:

10 min SIP: Breakdown Pressure: 

# SandRidge Energy, inc.

Well Name: Max Pressure: Treatment Report West Ranch 31-32

Amount 5 min SIP:

FLUIDS PUMPED Proppants

3ppg 25# Linear Gel/45Q CO2 *79 bpm @ *3493 psi 50 4ppg 25# Linear Gel/45Q CO2 *79.5 bpm @ *3507 psi 69

1,529 SandRidge Supervisor(s): Pipe 2 Size: Johnny Anaya Pipe 1 Size:
Top Perf Depth Displ Coef:

72 Pad 25# Linear Gel/45Q CO2 *78.3 bpm @ *3596 psi 5 1/2" Displ Coef: 0.02324 5406

SICP=
Treatment Type: Stage/Zone # :

### Date: psig

Formation: Perfs:

SPF: psig

Breakdown Acid Job Acid Frac Sand Frac Other:

0 bbl Flush: -4 bbls

Total Holes: ISDP: psi/ft Holes Open: Fluid Eff: (%) Max Rate: Calc. Perm: psig Max Pressure: Pc (psig) psig psig

Amount Type

0 Total

BBLS BLTR: 0.0 Gals

LBS

% tons

N/A
psig psig
bpm bpm 

## ISIP = psig

YES 4.0

YES Was Treatment Underdisplaced? If so, by how many bbls/gal?
Was well flowed back immediately? If not, well was shut-in hours before flowing back.

Remarks/Notes Avg Treating Press= Maximum =
Avg Treating Rate = Maximum = How many ball sealers were pumped: Was there ball action seen? X-Link Breaker Time: N/A Foam Quality: Amount of Foam Pumped: Type of foam: psig Start Time:

Total Fluid Pumped: 0 Stimulation Company: Displacement:

End Time:

FET ANALYSIS Frac Grad:

Total Proppant: 0 Type of Proppant: Liner Depth

Total # of Holes:

10 min SIP: Breakdown Pressure: 

# SandRidge Energy, inc.

Well Name: Max Pressure: Treatment Report

Amount 5 min SIP:

FLUIDS PUMPED Proppants SandRidge Supervisor(s): Pipe 2 Size: Pipe 1 Size:
Top Perf Depth Displ Coef: Displ Coef:

SICP=
Treatment Type: Stage/Zone # :

### Date: psig

Formation: Perfs:

SPF: psig

Breakdown Acid Job Acid Frac Sand Frac Other:

0 bbl Flush: -4 bbls

Total Holes: ISDP: psi/ft Holes Open: Fluid Eff: (%) Max Rate: Calc. Perm: psig Max Pressure: Pc (psig) psig psig

Amount Type

0 Total

BBLS BLTR: 0.0 Gals

LBS

% tons

psig psig
bpm bpm 

## ISIP = psig

Was Treatment Underdisplaced? If so, by how many bbls/gal?
Was well flowed back immediately? If not, well was shut-in hours before flowing back.

Remarks/Notes Avg Treating Press= Maximum =
Avg Treating Rate = Maximum = How many ball sealers were pumped: Was there ball action seen? X-Link Breaker Time: Foam Quality: Amount of Foam Pumped: Type of foam: psig Start Time:

Total Fluid Pumped: 0 Stimulation Company: Displacement:

End Time:

FET ANALYSIS Frac Grad:

Total Proppant: 0 Type of Proppant: Liner Depth

Total # of Holes:

10 min SIP: Breakdown Pressure: 

# SandRidge Energy, inc.

Well Name: Max Pressure: Treatment Report

Amount 5 min SIP:

FLUIDS PUMPED Proppants SandRidge Supervisor(s): Pipe 2 Size: Pipe 1 Size:
Top Perf Depth Displ Coef: Displ Coef:

SICP=
Treatment Type: Stage/Zone # :

### Date: psig

Formation: Perfs:

SPF: psig

Breakdown Acid Job Acid Frac Sand Frac Other:

0 bbl Flush: -4 bbls

Total Holes: ISDP: psi/ft Holes Open: Fluid Eff: (%) Max Rate: Calc. Perm: psig Max Pressure: Pc (psig) psig psig

Amount Type

0 Total

BBLS BLTR: 0.0 Gals

LBS

% tons

N/A
psig psig
bpm bpm 

## ISIP = psig

Was Treatment Underdisplaced? If so, by how many bbls/gal?
Was well flowed back immediately? If not, well was shut-in hours before flowing back.

Remarks/Notes Avg Treating Press= Maximum =
Avg Treating Rate = Maximum = How many ball sealers were pumped: Was there ball action seen? N/A X-Link Breaker Time: Foam Quality: Amount of Foam Pumped: Type of foam: psig Start Time:

Total Fluid Pumped: 0 Stimulation Company: Displacement:

End Time:

FET ANALYSIS Frac Grad:

Total Proppant: 0 Type of Proppant: Liner Depth

Total # of Holes:

10 min SIP: Breakdown Pressure: 

# SandRidge Energy, inc.

Well Name: Max Pressure: Treatment Report

Amount 5 min SIP:

FLUIDS PUMPED Proppants SandRidge Supervisor(s): Pipe 2 Size: Pipe 1 Size:
Top Perf Depth Displ Coef: Displ Coef:

SICP=
Treatment Type: Stage/Zone # :WELLBORE SCHEMATIC

Dev GL: 4022' WELL NAME: West Ranch 31-3 2 SPOT: 4551’ FSL & 6122’ FWL OPERATOR: SPUD DATE: 09/16/09 KB: 4041' API NO: 42-371-38558 LOCATION: SEC 31, BLK 138, T&STL RR CO ZONE: 2nd Caballos RR DATE: 10/08/09 WI: FIELD: Pinon ELEVATION: 4,022' MICU: RI: 58.4860% COUNTY: PECOS TD: 6,920' COMPL DATE: STATE: TEXAS PBTD: 5,942' (EST) PIPE RECORD CEMENT & HOLE DATA CSG OD GRADE THD WT/FT TOP BTM # JTS BIT SZE DEPTH SXS TOC

Surface 9-5/8" J-55 ST&C 36.00# 0' 1,367' 34 12.250'' 1367' 800 Top out twice Production 5-1/2" N-80 LT&C 17.00# 0' 6,020' 158 8.750'' 6920' 300/209 4670' / Surface

Tbg 2-3/8" 0' 5,400' 9 5/8" @ 1,367' Well tools: DV tool @ 1,427'. Ran DV tool per TRRC due to surface hole problems while drilling. DV tool @ 1427' Marker joint @ 5,022'.
WELL HISTORY

DATE WORK DETAIL PROD. RESULTS 10/13/09 TIH w/ 4-3/4" bit, bit sub, 6 3-1/8" DC, XO, 36 jts 2-3/8" L-80 tbg and tag @ 1390'. WO/DO cement to DV tool @ 1430'. DO DV tool. 10/14/09 RIH to 5947'. Displace csg w/ 190 bbl 2% KCLW. LD tbg. 10/15/09 Run CCL/GR/CBL 5930' to 4470'. TOC @ 4670'. Test csg to 4800 psi. Perf 5700-5756' OA. BD perf 2/ 2% @ 3000 psi. Perf 5406- 5640' OA. 10/16/09 RIH w/ CCL/CBL from 2500'-surface. Tie into original CBL. FL 1400'. 10/22/09

10/23/09 SIH w/ knotched collar, pump off sub, 1 jt, XN, 2-3/8" tbg. Clean out to PBTD. Land tbg @ 5400'. Pump off knotched collar.

10/28/09 MIRU SL. RIH to tag TD @ 5880'. EOT @ 5386'. Broach to SN @ 5353'. Install bypass plunger system. 03/31/10 SL ran 2" RB pulling tool, sat down at 5361', unable to latch plunger, ran 2" JDC, sat down at 5361', did not latch plunger, ran 1-3/4" IB, sat down at 5361', showed pad on side of plunger. Ran split skirt JDC pulling tool, unable to latch plunger. 04/15/10 SL ran 2 leg fishing tool, sat down at 5361', unalbe to latch plunger, ran 1.90" gauge ring to 5361' and beat down to try to move pad down beside plugner. Ran 2 leg tool again with no luck. Ran 1.80" gauge ring to 5361' and beat down. Ran pulling tool and unable to latch. Ran 1.75" IB to 5361', pad leaning more to the center of tbg. Ran 1.75" magnet, no recovery. ran 2" gutted split skirt JDC pulling tool, got good friction bite, beat up several licks, slipped off, ran magnet to 5361', no recovery. RD. 04/22/10 MIRU SL, Set 2" collar stop at 5321', Set 2" pack-off, set latchdown spring at 5318', dropped plngr and returned to sales.

Drilling Notations:

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
10/22/09 2nd Cab 85 1925 25# lin gel/ 45Q CO2 20/40 Ott 79.4 / 3617 1925 10/15/09 5,406' 5,416' 2nd Cab 2 SPF / 60  ̊ Active 10/15/09 5,468' 5,476' 2nd Cab 2 SPF / 60  ̊ Active 10/15/09 5,558' 5,560' 2nd Cab 3 SPF / 60  ̊ Active 10/15/09 5,575' 5,579' 2nd Cab 3 SPF / 60  ̊ Active 10/15/09 5,605' 5,607' 2nd Cab 3 SPF / 60  ̊ Active Frac Job Remarks (Screenouts or problems in Frac job): 10/15/09 5,637' 5,640' 2nd Cab 4 SPF / 60  ̊ Active 10/15/09 5,700' 5,702' 2nd Cab 4 SPF / 60  ̊ Active 10/15/09 5,756' 5,758' 2nd Cab 4 SPF / 60  ̊ Active CIBP Record
Date Depth Type

TOC 4670'
Remarks:

2" Pack Off Tool 5320' 2" Collar stop at 5321' Plunger Downhole Jewelry

Plunger fish Length Depth Description ID Drift Collapse* Burst* Tensile*
@ 5361' Material (Halliburton Handbook) (in) (in) (psi) (psi) (Klbs)
5,321' Collar stop and spring,
EOT 5400' 5,370' XN, plunger fish could not be removed 9-5/8"'' J-55 ST&C 36# 8.921 8.765 2,020 3,520 394,000
5,400' EOT 5-1/2"'' N-80 LT&C 17# 4.892 4.767 6,280 7,740 348,000
5406-5758' OA '' #
2nd Caballos 2-3/8"'' #
'' # * Safety Factor Not Included
REMARKS Temp @ 6848' = 148°F (1.29°F / 100')

ENGINEER: Fred Garbrecht
GEOLOGIST: Michael Rigby
LANDMAN:
PREPARED BY: Fred Garbrecht
PREPARED DATE: 10/8/2009 UPDATED: 5-1/2"=6020' UPDATED: 8.2.11 MF UPDATED:
TD = 6920' UPDATED: UPDATED: 50/50 Class H CURRENT SANDRIDGE ENERGY

73.25000%

TYPE

Class C

Load hole w/ 26 bbl 2% and BD stg 1 @ 6.2 bpm @ 2223. While pumping ball job, ball dropper quit. Displace 7.5% acid (76 bbl) to btm perf w/ 135 bbl 2%. Started job over. Acidize w/ 188 bbl 7.5% NEFE acid carrying 120 1.3 sg ball sealer in 20 ball clusters. Flush w/ 126 bbl 2% KCL. Saw 6 hits w/ ball sealers. ISIP =1676. Frac w/ 25# lin gel/ 45Q CO2 carrying 21100# 30/50 Ott, 51080# 20/40 Ott, 12472# SLC, 170 tons CO2. Pumped radioactive tracer. ATP=3617, ATR=79.4, MTP=3878, MTR=81, ISIP=1925, total prop=84652#. LTR=2035. SIW w/ 1850.

Lost 50% returns @ 709'. Lost 100% returns @ 900'. TOC after initial surface job was 765'. Ran 1" to 300' and topped out twice. RRC required DV tool to cement 5-1/2" X 9-5/8" annulus over surface casing interval.

Date Removed Notes

TUBULAR GOODS PERFORMANCE

Packer Detail:

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

# Casing & Cement

www.SandRidgeEnergy.com Page 1/1 

## WEST RANCH 31-32 For String: Conductor Casing Detail: Casing Description Conductor Run Date 9/16/2009 05:00 Set Depth (ftKB) 59 Wellbore Original Hole Csg Cutoff (ftKB) Casing Cutoff Date Centralizers Scratchers
Casing Components:
Joints 1 Item Description

Casing-Joints Icon Casing (black) OD (in) 16 ID (in) 15 1/4 Wt (lb/ft) 65.00 Grade H-40 Top Connection Thread Length (ft) 40.00 Top Depth (ftKB) 19.0 Btm (ftKB) 59.0
Cementing Job Details: Description Conductor Cement Type Casing String Conductor, 59ftKB Wellbore Original Hole Cementing Start Date 9/16/2009 05:00 Cementing End Date 9/16/2009 05:00 Cementing Company

Comment

Cement Stage#1 Description: Stage Number 1 Top Depth (ftKB) 19.0 Bottom Depth (ftKB) 59.0 Cement Volume Return (bbl)

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

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

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

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

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

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

Comment

Additive Details
Add Conc Conc Unit

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

# Casing & Cement

www.SandRidgeEnergy.com Page 1/2 

## WEST RANCH 31-32 For String: Surface Casing Detail: Casing Description Surface Run Date 9/17/2009 05:00 Set Depth (ftKB) 1,367 Wellbore Original Hole Csg Cutoff (ftKB) Casing Cutoff Date Centralizers 7 Scratchers
Casing Components:
Joints

34 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) 1,345.10 Top Depth (ftKB) 18.9 Btm (ftKB) 1,364.0 Joints 1 Item Description

Guide Shoe Icon Casing shoe OD (in) 9 5/8 ID (in) Wt (lb/ft) Grade Top Connection Thread Length (ft) 3.00 Top Depth (ftKB) 1,364.0 Btm (ftKB) 1,367.0
Cementing Job Details: Description Surface Casing Cement Type Casing String Surface, 1,367ftKB Wellbore Original Hole Cementing Start Date 9/17/2009 06:30 Cementing End Date 9/17/2009 23:45 Cementing Company O-Tex Comment Top out w/total of 300 sks. 5 sks to pit.

Cement Stage#1 Description: Stage Number 1 Top Depth (ftKB) 19.0 Bottom Depth (ftKB) 1,367.0 Cement Volume Return (bbl) 0.0 Float Failed? No Plug Failed? No Full Return? No Pipe Reciprocated? No Pressure Held (psi) 630.0 Top Plug? No Bottom Plug? No Initial Pump Rate (gpm) 210 Final Pump Rate (gpm) 126 Avg Pump Rate (bbl/min) 5 Final Pump Pr essure (psi) 50.0 Plug Bump Pressure (psi) 630.0 Pressure Release Date 9/17/2009

Lead Fluid Details for Stage#1 : Fluid Type Lead Fluid Description Class C Cement + 10 lbs/sk XPC-1 + 10 lbs/sk Kolseal + 0.125 lb/sk CF mixed at 14.2 ppg and 1.62 cf/sk. Amount (sacks) 150 Class C Volume Pumped (bbl) 62.0

Estimated Top (ftKB) 760.0 Estimated Bottom Depth (ftKB) 900.0 Yield (ft3/sack) 1.62 Mix H20 Ratio (gal/sack) 7.66 Free Water (%)

Density (lb/gal) 14.20 Plastic Viscosity (cp) Thickening Time (hr) 4.00 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit Cellophane Flakes 0.125 #/sk Gypsum 10.0 #/sk
KolSeal 10.0 #/sk

Lead Fluid Details for Stage#1 : Fluid Type Lead Fluid Description 35/65/4 Class C + 2%CC + 3% Salt + 3 lbs/sack KS + 0.125 lb/sk CF mixed at 2.08 cu ft/sk & 12.9 lbm/gal Amount (sacks) 470 Class C Volume Pumped (bbl) 189.0

Estimated Top (ftKB) 900.0 Estimated Bottom Depth (ftKB) 1,150.0 Yield (ft3/sack) 2.08 Mix H20 Ratio (gal/sack) 10.95 Free Water (%)

Density (lb/gal) 12.90 Plastic Viscosity (cp) Thickening Time (hr) 4.00 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit CaCl2 2.0 % Cellophane Flakes 0.125 #/sk
KolSeal 3.0 #/sk

Pozzolan - Lime 65.0 %
Sodium Chloride 3.0 %

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

# Casing & Cement

www.SandRidgeEnergy.com Page 2/2 

## WEST RANCH 31-32 For String: Surface Tail Fluid Details for Stage#1 : Fluid Type Tail Fluid Description Class C Cement + 4% Gel + 2%CC + 2 lbs/sack KS + 0.125 lb/sk CF mixed at 1.68 cu ft/sk & 13.7 lbm/gal Amount (sacks) 180 Class C Volume Pumped (bbl) 54.0

Estimated Top (ftKB) 1,150.0 Estimated Bottom Depth (ftKB) 1,367.0 Yield (ft3/sack) 1.68 Mix H20 Ratio (gal/sack) 8.57 Free Water (%)

Density (lb/gal) 13.70 Plastic Viscosity (cp) Thickening Time (hr) 4.00 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit Bentonite 4.0 %
CaCl2 2.0 % Cellophane Flakes 0.125 #/sk
KolSeal 2.0 #/sk

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

# Casing & Cement

www.SandRidgeEnergy.com Page 1/3 

## WEST RANCH 31-32 For String: Production Casing Detail: Casing Description Production Run Date 10/7/2009 04:00 Set Depth (ftKB) 6,020 Wellbore Original Hole Csg Cutoff (ftKB) Casing Cutoff Date Centralizers 9 Scratchers 0 Casing Components:
Joints

38 Item Description Casing-Joints Icon Casing (black) OD (in) 5 1/2 ID (in) 4.892 Wt (lb/ft) 17.00 Grade N-80 Top Connection Thread LT&C Length (ft) 1,408.43 Top Depth (ftKB) 19.0 Btm (ftKB) 1,427.4 Joints 1 Item Description

Stage Tool Icon Stage collar OD (in) 5 1/2 ID (in) 4.892 Wt (lb/ft) 17.00 Grade P-110 Top Connection Thread LT&C Length (ft) 2.25 Top Depth (ftKB) 1,427.4 Btm (ftKB) 1,429.7 Joints

94 Item Description Casing-Joints Icon Casing (black) OD (in) 5 1/2 ID (in) 4.892 Wt (lb/ft) 17.00 Grade N-80 Top Connection Thread LT&C Length (ft) 3,592.31 Top Depth (ftKB) 1,429.7 Btm (ftKB) 5,022.0 Joints 1 Item Description

Marker Joint Icon Casing (red) OD (in) 5 1/2 ID (in) 4.892 Wt (lb/ft) 17.00 Grade N-80 Top Connection Thread LT&C Length (ft) 41.81 Top Depth (ftKB) 5,022.0 Btm (ftKB) 5,063.8 Joints

23 Item Description Casing-Joints Icon Casing (black) OD (in) 5 1/2 ID (in) 4.892 Wt (lb/ft) 17.00 Grade N-80 Top Connection Thread LT&C Length (ft) 878.68 Top Depth (ftKB) 5,063.8 Btm (ftKB) 5,942.5 Joints 1 Item Description

Float Collar Icon Float collar OD (in) 5 1/2 ID (in) 4.892 Wt (lb/ft) 17.00 Grade N-80 Top Connection Thread LT&C Length (ft) 1.10 Top Depth (ftKB) 5,942.5 Btm (ftKB) 5,943.6 Joints 2 Item Description

Casing-Joints Icon Casing (black) OD (in) 5 1/2 ID (in) 4.892 Wt (lb/ft) 17.00 Grade N-80 Top Connection Thread LT&C Length (ft) 74.92 Top Depth (ftKB) 5,943.6 Btm (ftKB) 6,018.5 Joints 1 Item Description

Float Shoe Icon Casing shoe OD (in) 5 1/2 ID (in) Wt (lb/ft) Grade Top Connection Thread LT&C Length (ft) 1.50 Top Depth (ftKB) 6,018.5 Btm (ftKB) 6,020.0
Cementing Job Details: Description Production Casing Cement Type Casing String Production, 6,020ftKB Wellbore Original Hole Cementing Start Date 10/7/2009 16:30 Cementing End Date 10/8/2009 00:00 Cementing Company O-Tex Comment 2 stage cement procedure, 5.5" shoe @ 6020', DV tool @ 1425'. 1st stage - 330sks, TOC~4800. 2nd stage - 265sks f/1425' back to surface (25sks circ. back)

Cement Stage#1 Description: Stage Number 1 Top Depth (ftKB) 4,670.0 Bottom Depth (ftKB) 6,020.0 Cement Volume Return (bbl)

Float Failed? No Plug Failed? No Full Return? Yes Pipe Reciprocated? Yes Pressure Held (psi) 1,826.0 Top Plug? No Bottom Plug? Yes Initial Pump Rate (gpm) 252 Final Pump Rate (gpm) 126 Avg Pump Rate (bbl/min) 6 Final Pump Pr essure (psi) 1,226.0 Plug Bump Pressure (psi) 600.0 Pressure Release Date 10/7/2009

Spacer Fluid Details for Stage#1 : Fluid Type Spacer Fluid Description fresh water Amount (sacks) Class Volume Pumped (bbl) 20.0 Estimated Top (ftKB) 4,901.0 Estimated Bottom Depth (ftKB) 4,457.0 Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%) 100.00 Density (lb/gal) 8.34 Plastic Viscosity (cp) 28.0 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 50/50 H Amount (sacks) 300 Class H Volume Pumped (bbl) 71.0 Estimated Top (ftKB) 4,457.0 Estimated Bottom Depth (ftKB) 6,020.0 Yield (ft3/sack) 1.32 Mix H20 Ratio (gal/sack) 5.61 Free Water (%)

Density (lb/gal) 14.20 Plastic Viscosity (cp) Thickening Time (hr) 3.00 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit C-12 0.5 %
C-37 0.4 %
EC-1 1.0 #/sk
Kol-Seal 3.0 #/sk

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

# Casing & Cement

www.SandRidgeEnergy.com Page 2/3 

## WEST RANCH 31-32 For String: Production Additive Details
Add Conc Conc Unit NaCl 5.0 %
Displacement Fluid Details for Stage#1 : Fluid Type Displacement Fluid Description fresh water Amount (sacks) Class Volume Pumped (bbl) 110.0 Estimated Top (ftKB) 1,216.0 Estimated Bottom Depth (ftKB) 5,947.0 Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%) 100.00 Density (lb/gal) 8.34 Plastic Viscosity (cp) 28.0 Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit

Displacement Fluid Details for Stage#1 : Fluid Type Displacement Fluid Description mud Amount (sacks) Class Volume Pumped (bbl) 28.0 Estimated Top (ftKB) 0.0 Estimated Bottom Depth (ftKB) 1,216.0 Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

Density (lb/gal) 11.70 Plastic Viscosity (cp) 47.0 Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit

Cement Stage#2 Description: Stage Number 2 Top Depth (ftKB) 19.0 Bottom Depth (ftKB) 1,425.0 Cement Volume Return (bbl) 20.0 Float Failed? No Plug Failed? No Full Return? Yes Pipe Reciprocated? No Pressure Held (psi) 3,340.0 Top Plug? No Bottom Plug? Yes Initial Pump Rate (gpm) 168 Final Pump Rate (gpm) 168 Avg Pump Rate (bbl/min) 4 Final Pump Pr essure (psi) 440.0 Plug Bump Pressure (psi) 2,900.0 Pressure Release Date 10/8/2009

Spacer Fluid Details for Stage#2 : Fluid Type Spacer Fluid Description fresh water Amount (sacks) Class Volume Pumped (bbl) 20.0 Estimated Top (ftKB) 0.0 Estimated Bottom Depth (ftKB) 0.0 Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%) 100.00 Density (lb/gal) 8.34 Plastic Viscosity (cp) 28.0 Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit

Lead Fluid Details for Stage#2 : Fluid Type Lead Fluid Description 35/65 H Amount (sacks) 265 Class H Volume Pumped (bbl) 94.0 Estimated Top (ftKB) 0.0 Estimated Bottom Depth (ftKB) 1,425.0 Yield (ft3/sack) 1.99 Mix H20 Ratio (gal/sack) 10.99 Free Water (%)

Density (lb/gal) 12.40 Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc Unit Bentonite 6.0 %
C-12 0.4 %

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

# Casing & Cement

www.SandRidgeEnergy.com Page 3/3 

## WEST RANCH 31-32 For String: Production Displacement Fluid Details for Stage#2 : Fluid Type Displacement Fluid Description fresh water Amount (sacks) Class Volume Pumped (bbl) 33.0 Estimated Top (ftKB) 0.0 Estimated Bottom Depth (ftKB) 1,425.0 Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%) 100.00 Density (lb/gal) 8.34 Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details
Add Conc Conc UnitReport Date: 10/10/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,920 Footage (ftKB) 0 Avg ROP (ft/hr) Drill Hrs (hrs) DFS 24 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Planned Operations

Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Richard Riggs

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP



### 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 # 7 RR Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,920 Out (ftKB) 6,920 Drld (ftKB) 0 Drl Hrs (hrs) 0.00 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT TD 

### Bit Run # 7 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,768 Out (ftKB) 6,920 Drld (ftKB) 152 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT LOG 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 Production 5 1/2 17.00 N-80 6,020 

### BHA #8, 8 3/4 Slick BHA No. 8 Drill String Name 8 3/4 Slick Length (ft) 707.37 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 57.00 152.19 1 Jars -

Hydraulic 6 1/2 118.00 30.72

17 DC 6 1/2 57.00 520.46

1 Bit Sub

w/Float 6 1/2 0.00 3.00

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 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total Cum Cost To Date 1,286,379 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

## Drilling ReportReport Date: 10/9/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,920 Footage (ftKB) 0 Avg ROP (ft/hr) Drill Hrs (hrs) DFS 23 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Planned Operations

Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Richard Riggs

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP



### 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 # 7 RR Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,920 Out (ftKB) 6,920 Drld (ftKB) 0 Drl Hrs (hrs) 0.00 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT TD 

### Bit Run # 7 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,768 Out (ftKB) 6,920 Drld (ftKB) 152 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT LOG 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 Production 5 1/2 17.00 N-80 6,020 

### BHA #8, 8 3/4 Slick BHA No. 8 Drill String Name 8 3/4 Slick Length (ft) 707.37 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 57.00 152.19 1 Jars -

Hydraulic 6 1/2 118.00 30.72

17 DC 6 1/2 57.00 520.46

1 Bit Sub

w/Float 6 1/2 0.00 3.00

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 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total Cum Cost To Date 1,286,379 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

## Drilling Report

# Lariat

Report Date: 10/8/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,920 Footage (ftKB) 0 Avg ROP (ft/hr) Drill Hrs (hrs) DFS 22 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rigging Down - RIG RELEASED @ 05:00 Planned Operations Cont' R/D & Move Rig to West State 4-4w Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Richard Riggs

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 Rig Up & Down 6,920 R/U Express to run 5-1/2" csg.

06:30 09:00 2.50 4.00 Prod Csg/Cmt Run 45jts 5-1/2", 17#, N-80 csg.

09:00 10:00 1.00 5.00 Unplanned C/O Express hydraulic unit 10:00 12:30 2.50 7.50 Prod Csg/Cmt Run 113jts 5-1/2", 17#, N-80 csg. t/6020' - 158 TOTAL JTS RUN 12:30 13:00 0.50 8.00 Rig Up & Down R/D Express csg. crew & L/D machine

13:00 15:00 2.00 10.00 C&C Hole/Mud Circ. & Cond.
15:00 16:30 1.50 11.50 Rig Up & Down Circ. & Cond // R/U O-Tex // S/M & test lines t/3000psi 16:30 17:30 1.00 12.50 Prod Csg/Cmt Cement 1st stage: Pump spacer-20bbls H20, pump-71bbls(300sks) class H cmt, displ. w/138bbls (110bbls H2O + 28bbls mud) // Bump plug, drop bomb & open tool @ 17:30
17:30 23:30 6.00 18.50 C&C Hole/Mud Monitor well circ. thru staging tool - 55spm, 80psi, 45% flow 23:30 00:00 0.50 19.00 Prod Csg/Cmt R/U O-Tex, test lines t/3000' // Cement 2nd stage: pump spacer-20bbl H2O, pump lead-94bbls(265sks) class H cmt, displ w/33bbls H2O - circ. 20bbls(56sks) back // Bump Plug & close tool @ 00:05 00:00 00:30 0.50 19.50 Rig Up & Down R/D O-Tex cementers
00:30 02:30 2.00 21.50 Rig Up & Down N/D BOP & Set Slips - 80,000 hang-off wt

02:30 05:00 2.50 24.00 NU & Test Cut off csg. N/U tubing head & test - 4200psi // RIG RELEASED @ 05:00 10/08/09 // Back Haul 600bbls Mud to Mud Plant



### 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 # 7 RR Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,920 Out (ftKB) 6,920 Drld (ftKB) 0 Drl Hrs (hrs) 0.00 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT TD 

### Bit Run # 7 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,768 Out (ftKB) 6,920 Drld (ftKB) 152 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT LOG 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 Production 5 1/2 17.00 N-80 6,020 

### BHA #8, 8 3/4 Slick BHA No. 8 Drill String Name 8 3/4 Slick Length (ft) 707.37 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 57.00 152.19 1 Jars -

Hydraulic 6 1/2 118.00 30.72

17 DC 6 1/2 57.00 520.46

1 Bit Sub

w/Float 6 1/2 0.00 3.00

Drill Pipe in Hole

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



### Diesel Fuel Received Used 428 Cum On Location 5428 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 208,650 Cum Cost To Date 1,286,379 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 10/7/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,920 Footage (ftKB) 0 Avg ROP (ft/hr) Drill Hrs (hrs) DFS 21 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rig Service & R/U Express to run 5-1/2" csg. Planned Operations Run 5-1/2" Casing, Cement w/O-Tex (2 stage), N/D BOP, Set Slips, N/U Tubing Head, R/D Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Richard Riggs

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 - Logs 6,920 Finish TOH for Logs 07:30 08:30 1.00 3.50 Trip - Logs L/D Motor, Pull Wear Bushing, Circ. Thru Choke (100% open) 08:30 09:00 0.50 4.00 Rtn. Maint. Rig Service 09:00 10:00 1.00 5.00 Rig Up & Down S/M & R/U Weatherford Loggers
10:00 16:30 6.50 11.50 Logging Logging 1st Run - Gamma/Nuetron/Density/Dual Lat/Sonic/Caliper - Log down @ 11:30, Logger's TD @ 6890' - called by geologist 16:30 17:00 0.50 12.00 Rig Up & Down R/D Weatherford Loggers

17:00 21:00 4.00 16.00 Trip - LDDP Stage in Hole every 20stds w/BHA #8 21:00 22:00 1.00 17.00 C&C Hole/Mud Circ. Bottoms-up - Down Time Gas from logging - 375u 22:00 22:30 0.50 17.50 Rig Up & Down R/U Express L/D machine

22:30 03:00 4.50 22.00 Trip - LDDP Flow check, pump slug, LDDP 03:00 03:30 0.50 22.50 Trip - LDDP Break Kelly 03:30 04:30 1.00 23.50 Trip - LDDP LDDC's 04:30 05:00 0.50 24.00 Rtn. Maint. Rig Service


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 48 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 14 Gel 30 min 19 Filtrate (mL/30min) 5.2 Cake (/32") 1 pH 8.3 Solids (%) 18 LGS (%) 3 MBT (lb/bbl) Oil (%) 2 H20 (%) 81 Chlor (mg/L)

177,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) LCM

Hole Volume (bbl) 459.2 Pit Volume (bbl) 373.0 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 6920 100 375 Down Time Gas From Logging - 375u


### Bit Run # 7 RR Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,920 Out (ftKB) 6,920 Drld (ftKB) 0 Drl Hrs (hrs) 0.00 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT TD WOB (min) (1000lbf) 0 WOB (max) (1000lbf) 0 BHA ROP (ft/hr) SPP (psi) 0.0 Motor RPM (rpm) 0 RPM (rpm) 0 PU (max) (1000lbf) 180 SO (1000lbf) 150 Off-Btm Str Wt (1000lbf) 165 Drag (1000lbf) 15 Start (ftKB) 6,920 End (ftKB) 6,920 

### Bit Run # 7 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,768 Out (ftKB) 6,920 Drld (ftKB) 152 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT LOG 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 Production 5 1/2 17.00 N-80 6,020 

### BHA #8, 8 3/4 Slick BHA No. 8 Drill String Name 8 3/4 Slick Length (ft) 707.37 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 57.00 152.19 1 Jars -

Hydraulic 6 1/2 118.00 30.72

17 DC 6 1/2 57.00 520.46

1 Bit Sub

w/Float 6 1/2 0.00 3.00

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 195 4.50 16.60 X-95 4.5 XH 6,194 

### Diesel Fuel Received Used 428 Cum On Location 5428 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,200 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 50,823 Cum Cost To Date 1,077,729 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 10/6/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,920 Footage (ftKB) 125 Avg ROP (ft/hr) 6.4 Drill Hrs (hrs) 19.50 DFS 20 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time TOH for Logs Planned Operations Log w/Weatherford, TIH, L/D Drill String Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Richard Riggs

Time Log

Start Time End Time Dur (hrs) Cum Dur (hrs) Ops Code Dpth Start (ftKB) Dpth End (ftKB) Description ROP 05:00 13:00 8.00 8.00 Drilling 6,795 6,844 Drill 52' 6.1 13:00 13:30 0.50 8.50 Rtn. Maint. 6,844 6,844 Rig Service 13:30 01:00 11.50 20.00 Drilling 6,844 6,920 Drill 76' - TD 6.6 01:00 02:00 1.00 21.00 C&C Hole/Mud 6,920 Circ. Bottoms-up
02:00 02:30 0.50 21.50 Short/Wiper Trip Make 5 std short trip

02:30 04:00 1.50 23.00 C&C Hole/Mud Pump Sweep, Circ. Out, Build Slug
04:00 05:00 1.00 24.00 Trip - Logs Flow Check, Pump Slug, TOH for Logs


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 47 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 6 Gel 10 min 13 Gel 30 min 17 Filtrate (mL/30min) 5.2 Cake (/32") 1 pH 8.5 Solids (%) 18 LGS (%) 3 MBT (lb/bbl) Oil (%) 2 H20 (%) 81 Chlor (mg/L)

178,000 Ca (mg/L) 440 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.4 ECD (lb/gal) 12.12 LCM

Hole Volume (bbl) 452.9 Pit Volume (bbl) 390.0 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 6830 90 10 14 6890 80 10 10 32 43 6900 80 20 28 6910 90 10 27 6920 100 14 

### Bit Run # 7 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,768 Out (ftKB) 6,920 Drld (ftKB) 152 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT LOG WOB (min) (1000lbf) 45 WOB (max) (1000lbf) 45 BHA ROP (ft/hr) 6 SPP (psi) 100.0 Motor RPM (rpm) 53 RPM (rpm) 50 PU (max) (1000lbf) 185 SO (1000lbf) 150 Off-Btm Str Wt (1000lbf) 170 Drag (1000lbf) 15 Start (ftKB) 6,795 End (ftKB) 6,920 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA 

### Bit Run # 5 Size (in)

8 3/4 Model FH30 Make Smith Jets (/32") 16/16/16 In (ftKB) 6,679 Out (ftKB) 6,740 Drld (ftKB) 61 Drl Hrs (hrs) 8.00 Avg ROP (ft/hr) 7.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 0 0 NO CP Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #7, 8 3/4 Slick BHA No. 7 Drill String Name 8 3/4 Slick Length (ft) 728.70 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 57.00 152.19 1 Jars -

Hydraulic 6 1/2 118.00 30.72

17 DC 6 1/2 57.00 520.46

1 Great White 0.00 0.16 6 1/2 32.50 24.33 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 194 4.50 16.60 X-95 XH 6,163 

### Diesel Fuel Received Used 714 Cum On Location 5856 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 95 Q (gpm) 318 Pres (psi) 1,400 Stroke (in) 12.01 Slow ... No No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 55,242 Cum Cost To Date 1,026,906 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 10/5/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,795 Footage (ftKB) 29 Avg ROP (ft/hr) 4.1 Drill Hrs (hrs) 7.00 DFS 19 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Drlg. @ 6795' Planned Operations Drill Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 Drilling 6,766 6,768 Core 1.00 07:00 08:00 1.00 3.00 C&C Hole/Mud 6,768 6,768 Break off core & build slug
08:00 12:00 4.00 7.00 Trip for Bit 6,768 6,768 TOH w/ core barrel 12:00 14:00 2.00 9.00 Trip for Bit 6,768 6,768 L D Core & Core barrel 14:00 15:30 1.50 10.50 Trip for Bit 6,768 6,768 TIH to shoe & break circ. 15:30 17:00 1.50 12.00 Rtn. Maint. 6,768 6,768 Cut drlg. line 17:00 17:30 0.50 12.50 Rtn. Maint. 6,768 6,768 Ser. rig 17:30 19:30 2.00 14.50 Trip for Bit 6,768 6,768 TIH w/ bit # 7 & fill every 20 stds. 19:30 23:30 4.00 18.50 Excess Ream 6,768 6,768 Ream f/ 6637-6768'
23:30 00:00 0.50 19.00 Rtn. Maint. 6,768 6,768 Ser. rig 00:00 05:00 5.00 24.00 Drilling 6,768 6,795 Drlg. 27' 5.4


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 50 PV (cp) 20.0 YP (lbf/100ft2) 26 Gel 10 sec 6 Gel 10 min 14 Gel 30 min 20 Filtrate (mL/30min) 5.1 Cake (/32") 1 pH 8.5 Solids (%) 18 LGS (%) 3 MBT (lb/bbl) Oil (%) 2 H20 (%) 81 Chlor (mg/L)

170,000 Ca (mg/L) 480 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 12.12 LCM

Hole Volume (bbl) 452.9 Pit Volume (bbl) 855.0 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 6750 60 40 17 68 851 6755 70 30 16 6760 70 10 20 17 6765 80 10 10 13 6780 100 13 23 363 851 

### Bit Run # 7 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,768 Out (ftKB) 6,920 Drld (ftKB) 152 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT LOG WOB (min) (1000lbf) 45 WOB (max) (1000lbf) 45 BHA ROP (ft/hr) 6 SPP (psi) 150.0 Motor RPM (rpm) 53 RPM (rpm) 45 PU (max) (1000lbf) 185 SO (1000lbf) 145 Off-Btm Str Wt (1000lbf) 165 Drag (1000lbf) 20 Start (ftKB) 6,768 End (ftKB) 6,795 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA WOB (min) (1000lbf) 12 WOB (max) (1000lbf) 12 BHA ROP (ft/hr) 1 SPP (psi) Motor RPM (rpm) RPM (rpm) 65 PU (max) (1000lbf) 180 SO (1000lbf) 150 Off-Btm Str Wt (1000lbf) 165 Drag (1000lbf) 15 Start (ftKB) 6,766 End (ftKB) 6,768 

### Bit Run # 5 Size (in)

8 3/4 Model FH30 Make Smith Jets (/32") 16/16/16 In (ftKB) 6,679 Out (ftKB) 6,740 Drld (ftKB) 61 Drl Hrs (hrs) 8.00 Avg ROP (ft/hr) 7.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 0 0 NO CP Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #7, 8 3/4 Slick BHA No. 7 Drill String Name 8 3/4 Slick Length (ft) 728.70 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 57.00 152.19 1 Jars -

Hydraulic 6 1/2 118.00 30.72

17 DC 6 1/2 57.00 520.46

1 Great White 0.00 0.16 6 1/2 32.50 24.33 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 189 4.50 16.60 X-95 XH 5,953 

### Diesel Fuel Received Used 2582 Cum On Location 6570 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,400 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 60,834 Cum Cost To Date 971,664 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 10/4/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,766 Footage (ftKB) 26 Avg ROP (ft/hr) 1.2 Drill Hrs (hrs) 22.50 DFS 18 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Core w/ Dowdco @ 6766' Planned Operations Core w/ Dowdco & TOH Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 Trip - Other 6,740 6,740 Ream 3 jts. to btm. 06:00 17:00 11.00 12.00 Drilling 6,740 6,751 Core 11' 1.00 17:00 17:30 0.50 12.50 Rtn. Maint. 6,751 6,751 Ser. rig 17:30 05:00 11.50 24.00 Drilling 6,751 6,766 Core 15' 1.30


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 49 PV (cp) 20.0 YP (lbf/100ft2) 26 Gel 10 sec 6 Gel 10 min 14 Gel 30 min 18 Filtrate (mL/30min) 5.2 Cake (/32") 1 pH 8.6 Solids (%) 18 LGS (%) 3 MBT (lb/bbl) Oil (%) 2 H20 (%) 81 Chlor (mg/L)

175,000 Ca (mg/L) 480 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 12.12 LCM

Hole Volume (bbl) 452.9 Pit Volume (bbl) 855.0 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 6745 60 40 26 68 26 6745 60 40 26 6750 60 40 17 6755 70 30 16 6760 70 10 20 17 

### Bit Run # 7 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,768 Out (ftKB) 6,920 Drld (ftKB) 152 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 6.2

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 1 0 WT LOG 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA WOB (min) (1000lbf) 12 WOB (max) (1000lbf) 12 BHA ROP (ft/hr) 1 SPP (psi) Motor RPM (rpm) RPM (rpm) 65 PU (max) (1000lbf) 180 SO (1000lbf) 150 Off-Btm Str Wt (1000lbf) 165 Drag (1000lbf) 15 Start (ftKB) 6,740 End (ftKB) 6,766 

### Bit Run # 5 Size (in)

8 3/4 Model FH30 Make Smith Jets (/32") 16/16/16 In (ftKB) 6,679 Out (ftKB) 6,740 Drld (ftKB) 61 Drl Hrs (hrs) 8.00 Avg ROP (ft/hr) 7.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 0 0 NO CP Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #7, 8 3/4 Slick BHA No. 7 Drill String Name 8 3/4 Slick Length (ft) 728.70 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 57.00 152.19 1 Jars -

Hydraulic 6 1/2 118.00 30.72

17 DC 6 1/2 57.00 520.46

1 Great White 0.00 0.16 6 1/2 32.50 24.33 Drill Pipe in Hole

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



### Diesel Fuel Received Used 650 Cum On Location 9802 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 76 Q (gpm) 255 Pres (psi) 945 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 22,659 Cum Cost To Date 910,830 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 10/3/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,740 Footage (ftKB) 61 Avg ROP (ft/hr) 7.6 Drill Hrs (hrs) 8.00 DFS 17 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time TIH w/ core barrel Planned Operations TIH & cut 30' core & TOH Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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. 6,679 6,679 Ser. rig 05:30 06:00 0.50 1.00 Trip for Bit 6,679 6,679 TIH w/ bit # 5 06:00 06:30 0.50 1.50 Rtn. Maint. 6,679 6,679 Ser. rig 06:30 09:00 2.50 4.00 Trip for Bit 6,679 6,679 TIH w/ bit # 5 & fill every 20 stds. 09:00 10:00 1.00 5.00 Trip for Bit 6,679 6,679 Wash f/ 6559'-6679' No fill 10:00 18:00 8.00 13.00 Drilling 6,679 6,740 Drlg. 61' 7.6 18:00 20:30 2.50 15.50 C&C Hole/Mud 6,740 6,740 Circ. samples @ 6740 & build slug

20:30 21:00 0.50 16.00 Trip - Other 6,740 6,740 Pump out 4 jts. & pump slug 21:00 00:00 3.00 19.00 Trip - Other 6,740 6,740 TOH to pick up core barrel 00:00 01:00 1.00 20.00 Trip - Other 6,740 6,740 Make up core barrel 01:00 01:30 0.50 20.50 Rtn. Maint. 6,740 6,740 Ser. rig 01:30 05:00 3.50 24.00 Trip - Other 6,740 6,740 TIH w/ core barrel & fill every 20 stds.


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 49 PV (cp) 20.0 YP (lbf/100ft2) 25 Gel 10 sec 7 Gel 10 min 14 Gel 30 min 19 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.5 Solids (%) 18 LGS (%) 3 MBT (lb/bbl) Oil (%) 2 H20 (%) 81 Chlor (mg/L)

179,000 Ca (mg/L) 560 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.0 ECD (lb/gal) 12.19 LCM

Hole Volume (bbl) 446.6 Pit Volume (bbl) 866.0 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 6690 70 20 10 14 6710 80 10 10 40 68 98 6720 60 20 20 45 6730 60 10 30 50 6740 60 10 30 47 

### Bit Run # 6 Size (in)

7.8438 Model IMPREG Make Dowdco Jets (/32") In (ftKB) 6,740 Out (ftKB) 6,768 Drld (ftKB) 28 Drl Hrs (hrs) 24.50 Avg ROP (ft/hr) 1.1

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 0 0 NO A X 0 NO BHA 

### Bit Run # 5 Size (in)

8 3/4 Model FH30 Make Smith Jets (/32") 16/16/16 In (ftKB) 6,679 Out (ftKB) 6,740 Drld (ftKB) 61 Drl Hrs (hrs) 8.00 Avg ROP (ft/hr) 7.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 0 0 NO CP WOB (min) (1000lbf) 45 WOB (max) (1000lbf) 45 BHA ROP (ft/hr) 8 SPP (psi) 240.0 Motor RPM (rpm) 53 RPM (rpm) 40 PU (max) (1000lbf) 185 SO (1000lbf) 150 Off-Btm Str Wt (1000lbf) 165 Drag (1000lbf) 20 Start (ftKB) 6,679 End (ftKB) 6,740 

### Bit Run # 4 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,271 Out (ftKB) 6,679 Drld (ftKB) 408 Drl Hrs (hrs) 48.00 Avg ROP (ft/hr) 8.5

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 ER A 5 2 NO HR-Bit Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #6, 8 3/4 Slick BHA No. 6 Drill String Name 8 3/4 Slick Length (ft) 723.25 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 22 DC 6 1/2 32.50 672.65

1 Jars -

Hydraulic 6 1/2 24.50 15.20

1 Core Barrel 6 1/2 24.50 34.40 Drill Pipe in Hole

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



### Diesel Fuel Received 7,000.0 Used 650 Cum On Location 10452 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,450 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 39,117 Cum Cost To Date 888,171 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 10/2/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,679 Footage (ftKB) 114 Avg ROP (ft/hr) 9.1 Drill Hrs (hrs) 12.50 DFS 16 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time TIH w/ bit # 5 & trip ck. BHA Planned Operations TIH & Drill Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 6,565 6,565 Sur. @ 6513' 2.0 deg. 66.1 az. 05:30 15:00 9.50 10.00 Dir Rotate 6,565 6,652 Rot. 87' 9.1 15:00 15:30 0.50 10.50 Rtn. Maint. 6,652 6,652 Ser. rig 15:30 16:00 0.50 11.00 Srvys 6,652 6,652 Sur. @ 6608' 2.7 deg. 99.5 az. 16:00 19:00 3.00 14.00 Dir Rotate 6,652 6,679 Rot. 27' 9.0 19:00 20:30 1.50 15.50 C&C Hole/Mud 6,679 6,679 Circ. btms. up
20:30 21:00 0.50 16.00 Trip for Bit 6,679 6,679 Pump out 3 jts. & pump slug 21:00 00:00 3.00 19.00 Trip for Bit 6,679 6,679 TOH w/ bit # 4 00:00 01:00 1.00 20.00 Trip for Bit 6,679 6,679 LD Dir. tools & PU .16 St. mtr. & bit # 5 01:00 05:00 4.00 24.00 Trip for Bit 6,679 6,679 TIH w/ bit # 5 & trip ck. BHA


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 50 PV (cp) 20.0 YP (lbf/100ft2) 25 Gel 10 sec 7 Gel 10 min 12 Gel 30 min 18 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.5 Solids (%) 18 LGS (%) 3 MBT (lb/bbl) Oil (%) 2 H20 (%) 81 Chlor (mg/L)

175,000 Ca (mg/L) 680 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.5 ECD (lb/gal) 12.16 LCM

Hole Volume (bbl) 440.3 Pit Volume (bbl) 859.0 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 6620 90 10 30 6640 90 10 50 39 98 6650 80 20 35 6660 80 20 38 6670 70 20 10 44 

### Bit Run # 5 Size (in)

8 3/4 Model FH30 Make Smith Jets (/32") 16/16/16 In (ftKB) 6,679 Out (ftKB) 6,740 Drld (ftKB) 61 Drl Hrs (hrs) 8.00 Avg ROP (ft/hr) 7.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 NO A 0 0 NO CP 

### Bit Run # 4 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,271 Out (ftKB) 6,679 Drld (ftKB) 408 Drl Hrs (hrs) 48.00 Avg ROP (ft/hr) 8.5

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 ER A 5 2 NO HR-Bit WOB (min) (1000lbf) 42 WOB (max) (1000lbf) 42 BHA ROP (ft/hr) 9 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 45 PU (max) (1000lbf) 167 SO (1000lbf) 147 Off-Btm Str Wt (1000lbf) 155 Drag (1000lbf) 12 Start (ftKB) 6,565 End (ftKB) 6,679 

### Bit Run # 3 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/10/12/10 In (ftKB) 4,971 Out (ftKB) 6,271 Drld (ftKB) 1,300 Drl Hrs (hrs) 45.50 Avg ROP (ft/hr) 28.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 2 CT M X 0 ER FM Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 6,576 2.70 99.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #5, 8 3/4 Slick BHA No. 5 Drill String Name 8 3/4 Slick Length (ft) 728.70 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 8.00 152.19 1 Jars -

Hydraulic 6 1/2 101.50 30.72

17 DC 6 1/2 8.00 520.46

1 Great White 0.00 0.16 6 1/2 8.00 24.33 Drill Pipe in Hole

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



### Diesel Fuel Received Used 650 Cum On Location 4102 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,800 Stroke (in) 12.01 Slow ... No No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 28,214 Cum Cost To Date 849,054 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 10/1/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,565 Footage (ftKB) 199 Avg ROP (ft/hr) 9.0 Drill Hrs (hrs) 22.00 DFS 15 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Dir. drlg. @ 6565' Planned Operations Dir. drill & surveys Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 6,366 6,366 Sur. @ 6322' 1.9 deg. 78.8 az. 05:30 12:00 6.50 7.00 Dir Rotate 6,366 6,430 Rot. 64' 9.8 12:00 12:30 0.50 7.50 Rtn. Maint. 6,430 6,430 Ser. rig 12:30 15:30 3.00 10.50 Dir Rotate 6,430 6,461 Rot. 31' 10.0 15:30 16:00 0.50 11.00 Srvys 6,461 6,461 Sur. @ 6417' 1.7 deg. 79.0 az. 16:00 20:00 4.00 15.00 Dir Rotate 6,461 6,493 Rot. 32' 8.0 20:00 20:30 0.50 15.50 Rtn. Maint. 6,493 6,493 Ser. rig 20:30 00:00 3.50 19.00 Dir Rotate 6,493 6,525 Rot. 32' 9.1 00:00 03:00 3.00 22.00 Dir Sliding 6,525 6,545 Slide 20' MTF-150 6.6 03:00 05:00 2.00 24.00 Dir Rotate 6,545 6,565 Rot. 20' 10.0


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 52 PV (cp) 20.0 YP (lbf/100ft2) 26 Gel 10 sec 6 Gel 10 min 14 Gel 30 min 19 Filtrate (mL/30min) 5.0 Cake (/32") 1 pH 8.0 Solids (%) 17 LGS (%) 2 MBT (lb/bbl) Oil (%) 2 H20 (%) 81 Chlor (mg/L)

177,000 Ca (mg/L) 960 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 12.70 LCM

Hole Volume (bbl) 427.7 Pit Volume (bbl) 851.0 Storage Volume (bbl) 150.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment 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 6430 90 10 31 6510 90 10 32 93 309 6520 90 10 37 6530 80 20 32 6540 90 10 27 

### Bit Run # 4 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,271 Out (ftKB) 6,679 Drld (ftKB) 408 Drl Hrs (hrs) 48.00 Avg ROP (ft/hr) 8.5

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 ER A 5 2 NO HR-Bit WOB (min) (1000lbf) 42 WOB (max) (1000lbf) 42 BHA ROP (ft/hr) 9 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 45 PU (max) (1000lbf) 167 SO (1000lbf) 147 Off-Btm Str Wt (1000lbf) 155 Drag (1000lbf) 12 Start (ftKB) 6,366 End (ftKB) 6,565 

### Bit Run # 3 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/10/12/10 In (ftKB) 4,971 Out (ftKB) 6,271 Drld (ftKB) 1,300 Drl Hrs (hrs) 45.50 Avg ROP (ft/hr) 28.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 2 CT M X 0 ER FM 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,750 1.20 102.50 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 6,417 1.70 79.00 6,513 2.00 66.10 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #4, 8 3/4 Steerable BHA No. 4 Drill String Name 8 3/4 Steerable Length (ft) 760.96 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 264.00 152.19 1 Jars -

Hydraulic 6 1/2 93.50 30.72

17 DC 6 1/2 264.00 520.46

1 MWD/NMDC 6 1/2 264.00 31.05 1 UBHO 6 1/2 264.00 2.42 1 Great White 1.83 0.30 6 1/2 93.50 23.12 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 182 4.50 16.60 X-95 XH 5,733 

### Diesel Fuel Received Used 650 Cum On Location 4752 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,800 Stroke (in) 12.01 Slow ... No No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 30,291 Cum Cost To Date 820,840 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/30/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,366 Footage (ftKB) 95 Avg ROP (ft/hr) 7.0 Drill Hrs (hrs) 13.50 DFS 14 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Dir. drlg. @ 6366 Planned Operations Dir. drill & surveys Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 C&C Hole/Mud 6,271 6,271 Circ. f/ bit trip
06:30 07:30 1.00 2.50 Trip for Bit 6,271 6,271 Pump out 2 jts. & pump slug 07:30 10:30 3.00 5.50 Trip for Bit 6,271 6,271 TOH w/ bit # 3 10:30 11:00 0.50 6.00 Trip for Bit 6,271 6,271 Make up bit # 4 11:00 14:00 3.00 9.00 Trip for Bit 6,271 6,271 TIH w/ bit # 4 & fill every 20 stds. 14:00 14:30 0.50 9.50 Rtn. Maint. 6,271 6,271 Ser. rig 14:30 15:00 0.50 10.00 Trip for Bit 6,271 6,271 Wash f/ 6190-6271' No fill 15:00 18:30 3.50 13.50 Dir Rotate 6,271 6,303 Rot. 32' 9.1 18:30 19:00 0.50 14.00 Rtn. Maint. 6,303 6,303 Ser. rig 19:00 21:30 2.50 16.50 Dir Sliding 6,303 6,315 Slide 12' MTF-135 4.8 21:30 05:00 7.50 24.00 Dir Rotate 6,315 6,366 Rot. 51' 6.8


### Air/Mud Data MW (lb/gal) 11.70 Vis (s/qt) 60 PV (cp) 22.0 YP (lbf/100ft2) 28 Gel 10 sec 10 Gel 10 min 16 Gel 30 min 24 Filtrate (mL/30min) 5.8 Cake (/32") 1 pH 8.7 Solids (%) 19 LGS (%) 5 MBT (lb/bbl) Oil (%) 2 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 340 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.2 ECD (lb/gal) 12.00 LCM

Hole Volume (bbl) 490.6 Pit Volume (bbl) 943.0 Storage Volume (bbl) 150.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment Dump sd. trap Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 6270 90 10 32 6320 70 20 10 20 23 1698 51 6330 90 10 17 6340 90 10 16 6350 80 20 19 

### Bit Run # 4 Size (in)

8 3/4 Model GXE38CH Make Hughes Jets (/32") 16/16/16 In (ftKB) 6,271 Out (ftKB) 6,679 Drld (ftKB) 408 Drl Hrs (hrs) 48.00 Avg ROP (ft/hr) 8.5

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 3 ER A 5 2 NO HR-Bit WOB (min) (1000lbf) 42 WOB (max) (1000lbf) 42 BHA ROP (ft/hr) 9 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 45 PU (max) (1000lbf) 167 SO (1000lbf) 147 Off-Btm Str Wt (1000lbf) 155 Drag (1000lbf) 12 Start (ftKB) 6,271 End (ftKB) 6,366 

### Bit Run # 3 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/10/12/10 In (ftKB) 4,971 Out (ftKB) 6,271 Drld (ftKB) 1,300 Drl Hrs (hrs) 45.50 Avg ROP (ft/hr) 28.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 2 CT M X 0 ER FM 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,559 0.90 116.30 5,655 0.80 85.30 5,750 1.20 102.50 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 6,322 1.90 78.80 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #4, 8 3/4 Steerable BHA No. 4 Drill String Name 8 3/4 Steerable Length (ft) 760.96 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 264.00 152.19 1 Jars -

Hydraulic 6 1/2 93.50 30.72

17 DC 6 1/2 264.00 520.46

1 MWD/NMDC 6 1/2 264.00 31.05 1 UBHO 6 1/2 264.00 2.42 1 Great White 1.83 0.30 6 1/2 93.50 23.12 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 175 4.50 16.60 X-95 XH 5,512 

### Diesel Fuel Received Used 650 Cum On Location 5402 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,800 Stroke (in) 12.01 Slow ... No No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 28,180 Cum Cost To Date 790,549 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/29/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 6,271 Footage (ftKB) 540 Avg ROP (ft/hr) 27.0 Drill Hrs (hrs) 20.00 DFS 13 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Survey @ 6227' Planned Operations Dir. drill & surveys & trip Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 Rotate 5,731 5,794 Rot. 63' 25.2 07:30 08:00 0.50 3.00 Srvys 5,794 5,794 Sur. @ 5750' 1.2 deg. 102.5 az. 08:00 11:00 3.00 6.00 Dir Rotate 5,794 5,889 Rot. 95' 31.6 11:00 11:30 0.50 6.50 Srvys 5,889 5,889 Sur. @ 5845' 0.9 deg.86.5 az. 11:30 12:30 1.00 7.50 Dir Sliding 5,889 5,901 Slide 12' 12.0 12:30 14:00 1.50 9.00 Dir Rotate 5,901 5,953 Rot. 52' 34.6 14:00 14:30 0.50 9.50 Rtn. Maint. 5,953 5,953 Ser. rig 14:30 15:30 1.00 10.50 Dir Rotate 5,953 5,985 Rot. 32' 32.0 15:30 16:00 0.50 11.00 Srvys 5,985 5,985 Sur. @ 5941' 2.8 deg. 86.5 az. 16:00 17:00 1.00 12.00 Dir Rotate 5,985 6,017 Rot. 32' 32.0 17:00 18:00 1.00 13.00 Dir Sliding 6,017 6,027 Slide 10' MTF-240 10.0 18:00 20:00 2.00 15.00 Dir Rotate 6,027 6,080 Rot. 53' 26.5 20:00 20:30 0.50 15.50 Srvys 6,080 6,080 Sur. @ 6036' 2.2 deg. 82.8 az. 20:30 00:00 3.50 19.00 Dir Rotate 6,080 6,175 Rot. 95' 27.1 00:00 00:30 0.50 19.50 Srvys 6,175 6,175 Sur. @ 6131' 1.9 deg. 75.5 az. 00:30 02:30 2.00 21.50 Dir Rotate 6,175 6,239 Rot. 64' 32.0 02:30 03:00 0.50 22.00 Rtn. Maint. 6,239 6,239 Ser. rig 03:00 04:30 1.50 23.50 Dir Rotate 6,239 6,271 Rot. 32' 21.3 04:30 05:00 0.50 24.00 Srvys 6,271 6,271 Sur. @ 6227' 1.7 deg. 60.7 az.


### Air/Mud Data MW (lb/gal) 11.60 Vis (s/qt) 55 PV (cp) 23.0 YP (lbf/100ft2) 28 Gel 10 sec 10 Gel 10 min 16 Gel 30 min 24 Filtrate (mL/30min) 4.2 Cake (/32") 1 pH 8.5 Solids (%) 18 LGS (%) 5 MBT (lb/bbl) Oil (%) 2 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 340 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.1 ECD (lb/gal) 11.99 LCM

Hole Volume (bbl) 452.9 Pit Volume (bbl) 350.0 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 5990 90 10 141 6200 80 20 35 68 580 6210 80 20 40 6220 80 20 6230 90 10 

### Bit Run # 3 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/10/12/10 In (ftKB) 4,971 Out (ftKB) 6,271 Drld (ftKB) 1,300 Drl Hrs (hrs) 45.50 Avg ROP (ft/hr) 28.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 2 CT M X 0 ER FM WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 29 SPP (psi) 350.0 Motor RPM (rpm) 95 RPM (rpm) 48 PU (max) (1000lbf) 164 SO (1000lbf) 144 Off-Btm Str Wt (1000lbf) 150 Drag (1000lbf) 14 Start (ftKB) 5,731 End (ftKB) 6,271 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 5,464 0.80 115.50 5,559 0.90 116.30 5,655 0.80 85.30 5,750 1.20 102.50 5,845 0.90 86.50 5,941 2.80 86.50 6,036 2.20 82.80 6,131 1.90 75.50 6,227 1.70 60.70 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 760.96 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 216.00 152.19 1 Jars -

Hydraulic 6 1/2 45.50 30.72

17 DC 6 1/2 216.00 520.46

1 NMDC 6 1/2 216.00 31.05 1 UBHO 6 1/2 216.00 2.42 1 Great White 1.83 0.30 6 1/2 45.50 23.12 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 172 4.50 16.60 X-95 XH 5,418 

### Diesel Fuel Received Used 650 Cum On Location 6052 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,800 Stroke (in) 12.01 Slow ... No No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 29,509 Cum Cost To Date 762,369 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/28/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 5,731 Footage (ftKB) 604 Avg ROP (ft/hr) 30.2 Drill Hrs (hrs) 20.00 DFS 12 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Dir. drlg. @ 5731' Planned Operations Dir. drill & surveys Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 5,127 5,222 Rot. 95' 31.6 08:00 08:30 0.50 3.50 Srvys 5,222 5,222 Sur. @ 5178' 1.7 deg. 55.0 az. 08:30 10:30 2.00 5.50 Dir Rotate 5,222 5,286 Rot. 64' 32.0 10:30 11:00 0.50 6.00 Rtn. Maint. 5,286 5,286 Ser. rig 11:00 11:30 0.50 6.50 Dir Rotate 5,286 5,317 Rot. 31' 64.0 11:30 12:00 0.50 7.00 Srvys 5,317 5,317 Sur. @ 5273' 1.8 deg. 46.9 az. 12:00 13:00 1.00 8.00 Dir Rotate 5,317 5,349 Rot. 32' 32.0 13:00 14:00 1.00 9.00 Dir Sliding 5,349 5,360 Slide 11' MTF-200 11.0 14:00 15:30 1.50 10.50 Dir Rotate 5,360 5,413 Rot. 53' 35.3 15:30 16:00 0.50 11.00 Srvys 5,413 5,413 Sur. @ 5369' 0.8 deg. 102.8 az. 16:00 19:00 3.00 14.00 Dir Rotate 5,413 5,508 Rot. 95' 31.5 19:00 19:30 0.50 14.50 Srvys 5,508 5,508 Sur. @ 5464' 0.8 deg. 115.5 az. 19:30 22:30 3.00 17.50 Dir Rotate 5,508 5,603 Rot. 95' 31.6 22:30 23:00 0.50 18.00 Srvys 5,603 5,603 Sur. @ 5559' 0.9 deg. 116.3 az. 23:00 00:00 1.00 19.00 Dir Rotate 5,603 5,635 Rot. 32' 32.0 00:00 00:30 0.50 19.50 Rtn. Maint. 5,635 5,635 Ser. rig 00:30 02:30 2.00 21.50 Dir Rotate 5,635 5,699 Rot. 64' 32.0 02:30 03:00 0.50 22.00 Srvys 5,699 5,699 Sur. @ 5655' 0.8 deg. 85.3 az. 03:00 03:30 0.50 22.50 Dir Sliding 5,699 5,705 Slide 6' MTF-100 12.0 03:30 05:00 1.50 24.00 Dir Rotate 5,705 5,731 Rot. 26' 17.3


### Air/Mud Data MW (lb/gal) 11.50 Vis (s/qt) 49 PV (cp) 21.0 YP (lbf/100ft2) 26 Gel 10 sec 10 Gel 10 min 15 Gel 30 min 18 Filtrate (mL/30min) 5.6 Cake (/32") 1 pH 8.4 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) 2 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 360 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.0 Mf (mL/mL) 0.1 ECD (lb/gal) 11.76 LCM

Hole Volume (bbl) 402.5 Pit Volume (bbl) 424.0 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 5320 30 70 119 98 184 5640 60 20 20 177 293 1215 5660 50 20 30 216 293 1215 5680 20 50 30 81 293 1215 5700 20 50 30 98 293 1215 

### Bit Run # 3 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/10/12/10 In (ftKB) 4,971 Out (ftKB) 6,271 Drld (ftKB) 1,300 Drl Hrs (hrs) 45.50 Avg ROP (ft/hr) 28.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 2 CT M X 0 ER FM WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 29 SPP (psi) 350.0 Motor RPM (rpm) 95 RPM (rpm) 48 PU (max) (1000lbf) 164 SO (1000lbf) 135 Off-Btm Str Wt (1000lbf) 145 Drag (1000lbf) 13 Start (ftKB) 5,127 End (ftKB) 5,731 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 4,892 1.90 104.20 4,987 1.50 118.10 5,083 1.80 52.30 5,178 1.70 55.00 5,273 1.80 46.90 5,369 0.08 102.80 5,464 0.80 115.50 5,559 0.90 116.30 5,655 0.80 85.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 760.96 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 216.00 152.19 1 Jars -

Hydraulic 6 1/2 45.50 30.72

17 DC 6 1/2 216.00 520.46

1 NMDC 6 1/2 216.00 31.05 1 UBHO 6 1/2 216.00 2.42 1 Great White 1.83 0.30 6 1/2 45.50 23.12 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 155 4.50 16.60 X-95 XH 4,882 

### Diesel Fuel Received Used 650 Cum On Location 6702 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,640 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 29,194 Cum Cost To Date 732,860 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/27/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 5,127 Footage (ftKB) 254 Avg ROP (ft/hr) 18.8 Drill Hrs (hrs) 13.50 DFS 11 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Survey @ 5083' Planned Operations Dir. drill & surveys Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 4,873 4,904 Slide 31' MTF-30 15.5 07:00 09:00 2.00 4.00 Dir Rotate 4,904 4,936 Rot. 32' 16.0 09:00 09:30 0.50 4.50 Srvys 4,936 4,936 Sur. @ 4892' 1.9 deg. 104.2 az. 09:30 13:00 3.50 8.00 Dir Sliding 4,936 4,968 Slide 32' MTF-300 9.1 13:00 13:30 0.50 8.50 Dir Rotate 4,968 4,971 Rot. 3' 6.0 13:30 14:30 1.00 9.50 C&C Hole/Mud 4,971 4,971 Circ. btms. up
14:30 15:00 0.50 10.00 Trip for Bit 4,971 4,971 Pump out 2 jts. & pump slug 15:00 16:30 1.50 11.50 Trip for Bit 4,971 4,971 TOH w/ bit # 2 16:30 17:00 0.50 12.00 Rtn. Maint. 4,971 4,971 Ser. rig 17:00 17:30 0.50 12.50 Trip for Bit 4,971 4,971 TOH w/ bit # 2 & ch. out jars 17:30 19:30 2.00 14.50 Trip for Bit 4,971 4,971 Change out mtr. & bit - scribe - test - & make up bit # 3 19:30 22:00 2.50 17.00 Trip for Bit 4,971 4,971 TIH w/ bit # 3 & fill every 20 stds. 22:00 22:30 0.50 17.50 Rtn. Maint. 4,971 4,971 Ser. rig 22:30 00:30 2.00 19.50 Dir Rotate 4,971 5,031 Rot. 60' 30.0 00:30 01:00 0.50 20.00 Srvys 5,031 5,031 Survey @ 4987' 1.5 deg. 118.1 az. 01:00 02:00 1.00 21.00 Dir Sliding 5,031 5,051 Slide 20' MTF-0 20.0 02:00 04:30 2.50 23.50 Dir Rotate 5,051 5,127 Rot. 76' 30.4 04:30 05:00 0.50 24.00 Srvys 5,127 5,127 Survey @ 5083' 1.8 deg. 52.3 az.


### Air/Mud Data MW (lb/gal) 11.40 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 16 Filtrate (mL/30min) 4.4 Cake (/32") 1 pH 8.4 Solids (%) 18 LGS (%) 7 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 340 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.0 Mf (mL/mL) 0.1 ECD (lb/gal) 11.76 LCM

Hole Volume (bbl) 377.4 Pit Volume (bbl) 420.0 Storage Volume (bbl) 200.0 Compressors Boosters Nitrogen Units Air/Gas Vol. (mcf) Pressure (psi)

Comment Dump sd. trap & jet sh. pit Mud Logging Data

MD (ftKB) Shale (%) SS (%) LS (%) Chert (%) BG Gas (%) C/Gas (%) T/Gas (%) Max Gas (%) Gas Show Comment 4960 100 11 21 22 5050 100 24 53 52 5060 100 16 53 5070 80 20 50 5080 80 20 46 53 52 602 

### Bit Run # 3 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/10/12/10 In (ftKB) 4,971 Out (ftKB) 6,271 Drld (ftKB) 1,300 Drl Hrs (hrs) 45.50 Avg ROP (ft/hr) 28.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 3 2 CT M X 0 ER FM WOB (min) (1000lbf) 10 WOB (max) (1000lbf) 10 BHA ROP (ft/hr) 29 SPP (psi) 350.0 Motor RPM (rpm) 95 RPM (rpm) 48 PU (max) (1000lbf) 164 SO (1000lbf) 133 Off-Btm Str Wt (1000lbf) 136 Drag (1000lbf) 9 Start (ftKB) 4,971 End (ftKB) 5,127 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 240.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 138 SO (1000lbf) 128 Off-Btm Str Wt (1000lbf) 134 Drag (1000lbf) 4 Start (ftKB) 4,873 End (ftKB) 4,971 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 4,321 1.40 141.70 4,416 2.00 149.50 4,511 2.40 144.50 4,606 2.30 135.00 4,702 1.60 153.00 4,797 1.40 146.40 4,892 1.90 104.20 4,987 1.50 118.10 5,083 1.80 52.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #3, 8 3/4 Steerable BHA No. 3 Drill String Name 8 3/4 Steerable Length (ft) 760.96 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 216.00 152.19 1 Jars -

Hydraulic 6 1/2 45.50 30.72

17 DC 6 1/2 216.00 520.46

1 NMDC 6 1/2 216.00 31.05 1 UBHO 6 1/2 216.00 2.42 1 Great White 1.83 0.30 6 1/2 45.50 23.12 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 136 4.50 16.60 X-95 XH 4,284 

### Diesel Fuel Received Used 650 Cum On Location 7352 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,640 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 27,903 Cum Cost To Date 703,666 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/26/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 4,873 Footage (ftKB) 305 Avg ROP (ft/hr) 13.9 Drill Hrs (hrs) 22.00 DFS 10 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Dir. drlg. @ 4873' Planned Operations Dir. drill & surveys Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Steve McComb

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 Sliding 4,568 4,577 Slide 9' MTF-10 6.0 06:30 10:00 3.50 5.00 Dir Rotate 4,577 4,650 Rot. 73' 20.8 10:00 10:30 0.50 5.50 Srvys 4,650 4,650 Sur. @ 4606' 2.3 deg. 134.0 az. 10:30 13:30 3.00 8.50 Dir Sliding 4,650 4,675 Slide 25' MTF-330 8.3 13:30 15:00 1.50 10.00 Dir Rotate 4,675 4,693 Rot. 18' 12.0 15:00 17:00 2.00 12.00 Dir Sliding 4,693 4,714 Slide 21' MTF-340 10.5 17:00 17:30 0.50 12.50 Rtn. Maint. 4,714 4,714 Ser. rig 17:30 18:30 1.00 13.50 Dir Rotate 4,714 4,746 Rot. 32' 32.0 18:30 19:00 0.50 14.00 Srvys 4,746 4,746 Sur. @ 4702' 1.6 deg. 153.0 az. 19:00 21:00 2.00 16.00 Dir Rotate 4,746 4,777 Rot. 31' 15.5 21:00 00:00 3.00 19.00 Dir Sliding 4,777 4,809 Slide 32' MTF-45 10.6 00:00 02:00 2.00 21.00 Dir Rotate 4,809 4,841 Rot. 32' 16.0 02:00 02:30 0.50 21.50 Srvys 4,841 4,841 Sur. @ 4797' 1.4 deg. 146.4 az. 02:30 05:00 2.50 24.00 Dir Rotate 4,841 4,873 Rot. 32' 12.8


### Air/Mud Data MW (lb/gal) 11.40 Vis (s/qt) 48 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 10 Gel 10 min 15 Gel 30 min 22 Filtrate (mL/30min) 5.8 Cake (/32") 1 pH 8.6 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 340 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.2 ECD (lb/gal) 11.78 LCM

Hole Volume (bbl) 352.2 Pit Volume (bbl) 390.0 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 4660 100 15 18 22 4840 100 12 14 22 4850 100 14 14 22 4860 100 13 14 22 4870 100 15 14 22 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 240.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 138 SO (1000lbf) 128 Off-Btm Str Wt (1000lbf) 134 Drag (1000lbf) 4 Start (ftKB) 4,568 End (ftKB) 4,873 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 4,035 1.20 90.70 4,130 1.40 129.30 4,225 0.90 131.80 4,321 1.40 141.70 4,416 2.00 149.50 4,511 2.40 144.50 4,606 2.30 135.00 4,702 1.60 153.00 4,797 1.40 146.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 128 4.50 16.60 x-95 4.5 xh 4,032 

### Diesel Fuel Received 6,995.0 Used 650 Cum On Location 8002 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 47,942 Cum Cost To Date 675,763 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/25/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 4,568 Footage (ftKB) 362 Avg ROP (ft/hr) 17.2 Drill Hrs (hrs) 21.00 DFS 9 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rot Drlg @ 4568' Planned Operations Drill ahead Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 Sliding 4,206 4,228 Slide drlg 90 spm, 15k wob 14.6 06:30 07:30 1.00 2.50 Dir Rotate 4,228 4,269 Rot drlg 90 spm, 302 gpm, 45 rpm, pumping 20bbls/6ppb nut shell for bit balling 41

07:30 08:00 0.50 3.00 Srvys 4,269 4,269 Survey @ 4225' .9 deg 131.8 azi 08:00 09:00 1.00 4.00 Dir Rotate 4,269 4,301 Rot drlg 90 spm, 302 gpm, 45 rpm, 15k wob 32 09:00 11:00 2.00 6.00 Dir Sliding 4,301 4,309 Slide drlg 90 spm, 302 gpm, 16k wob 4 11:00 13:00 2.00 8.00 Dir Rotate 4,309 4,365 Rot drlg 90 spm, 302 gpm, 45 rpm, 15k wob 28 13:00 13:30 0.50 8.50 Srvys 4,365 4,365 Survey @ 4321' 1.4 deg 141.7 azi 13:30 15:00 1.50 10.00 Dir Rotate 4,365 4,396 Rot drlg 90 spm, 302 gpm, 50 rpm, 15k wob, pumping 6ppb/20bbls sweeps for bit balling every hour 32

15:00 15:30 0.50 10.50 Rtn. Maint. 4,396 4,396 Service rig 15:30 17:00 1.50 12.00 Dir Rotate 4,396 4,428 Rot drlg 90 spm, 302 gpm, 45 rpm, 16k wob, pumping 6ppb/20bbl sweeps every hour 17:00 19:00 2.00 14.00 Dir Sliding 4,428 4,437 Slide drlg 90 spm, 16k wob, 302 gpm (mtf 55) 4.5
19:00 20:00 1.00 15.00 Dir Rotate 4,437 4,460 Rot drlg 90 spm, 302 gpm, 53 rpm, 16k wob 23 20:00 20:30 0.50 15.50 Srvys 4,460 4,460 Survey @ 4416' 2 deg 149.5 azi 20:30 22:00 1.50 17.00 Dir Sliding 4,460 4,467 Slide drlg 90 spm, 302 gpm, 25k wob 4.6 22:00 00:30 2.50 19.50 Dir Rotate 4,467 4,523 Rot drlg 90 spm, 302 gpm, 55 rpm, 16k wob, pumping sweeps 6ppb/20bbl every hour 22.4

00:30 01:00 0.50 20.00 Rtn. Maint. 4,523 4,523 Service rig 01:00 02:00 1.00 21.00 Dir Rotate 4,523 4,555 Rot drlg 90 spm, 302 gpm, 45 rpm 16k wob, pumping sweeps 6ppb/20bbl nutshell 32
02:00 02:30 0.50 21.50 Srvys 4,555 4,555 Survey @ 4511' 2.4 deg 144.5 deg 02:30 05:00 2.50 24.00 Dir Sliding 4,555 4,568 Slide drlg 90 spm 24k wob (MTF-30) 5.2


### Air/Mud Data MW (lb/gal) 11.40 Vis (s/qt) 48 PV (cp) 21.0 YP (lbf/100ft2) 26 Gel 10 sec 10 Gel 10 min 15 Gel 30 min 22 Filtrate (mL/30min) 6.0 Cake (/32") 1 pH 8.9 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 360 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.2 Mf (mL/mL) 0.3 ECD (lb/gal) 11.79 LCM 0 Hole Volume (bbl) 327.1 Pit Volume (bbl) 375.0 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 4320 40 60 21 37 4500 100 17 41 4364 4520 100 19 41 4364 4540 100 15 41 4364 4555 100 17 41 4364 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 240.0 Motor RPM (rpm) 95 RPM (rpm) 55 PU (max) (1000lbf) 138 SO (1000lbf) 124 Off-Btm Str Wt (1000lbf) 128 Drag (1000lbf) 10 Start (ftKB) 4,206 End (ftKB) 4,568 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 3,749 1.50 139.80 3,844 1.40 153.70 3,939 1.70 141.40 4,035 1.20 90.70 4,130 1.40 129.30 4,225 0.90 131.80 4,321 1.40 141.70 4,416 2.00 149.50 4,511 2.40 144.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 119 4.50 16.60 x-95 4.5 xh 3,780 

### Diesel Fuel Received Used 650 Cum On Location 1657 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 Costs Daily Cost Total 35,931 Cum Cost To Date 627,821 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/24/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 4,206 Footage (ftKB) 652 Avg ROP (ft/hr) 32.6 Drill Hrs (hrs) 20.00 DFS 8 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rot Drlg @ 4206' Planned Operations Drill ahead Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 3,554 3,570 90 spm, 302 gpm, 15k wob, 45 rpm 16 06:00 07:00 1.00 2.00 Dir Sliding 3,570 3,585 90 spm, 302 gpm 15 07:00 07:30 0.50 2.50 Dir Rotate 3,585 3,602 90 spm, 302 gpm, 15k wob, 45 rpm 34 07:30 08:00 0.50 3.00 Srvys 3,602 3,602 Survey @ 3558' 08:00 10:00 2.00 5.00 Dir Rotate 3,602 3,697 90 spm, 302 gpm, 15k wob, 45 rpm, 47.5 10:00 10:30 0.50 5.50 Srvys 3,697 3,697 Survey @ 3653' 10:30 11:30 1.00 6.50 Dir Rotate 3,697 3,761 90 spm, 302 gpm, 15k wob, 45 rpm 64 11:30 12:30 1.00 7.50 Dir Sliding 3,761 3,780 90 spm, 302 gpm, 16k wob 19 12:30 13:00 0.50 8.00 Dir Rotate 3,780 3,793 90 spm, 302 gpm, 15k wob, 45 rpm 26 13:00 13:30 0.50 8.50 Srvys 3,793 3,793 Survey @ 3749' 13:30 15:00 1.50 10.00 Dir Rotate 3,793 3,888 90 spm, 302 gpm, 15k wob, 45 rpm 54 15:00 15:30 0.50 10.50 Srvys 3,888 3,888 Survey @ 3844' 15:30 16:00 0.50 11.00 Dir Rotate 3,888 3,920 90 spm, 302 gpm, 45 rpm 64 16:00 17:00 1.00 12.00 Dir Sliding 3,920 3,942 90 spm, 302 gpm, 22 17:00 17:30 0.50 12.50 Dir Rotate 3,942 3,951 90 spm, 302 gpm, 45 rpm, 15k wob 18 17:30 18:00 0.50 13.00 Rtn. Maint. 3,951 3,951 Service rig 18:00 18:30 0.50 13.50 Srvys 3,951 3,951 Survey @ 3939' 18:30 19:00 0.50 14.00 Dir Rotate 3,951 3,983 90 spm, 302 gpm, 45 rpm, 15k wob 54 19:00 21:00 2.00 16.00 Dir Sliding 3,983 4,009 90 spm, 302 gpm, 15k wob 13 21:00 23:00 2.00 18.00 Dir Rotate 4,009 4,079 90 spm, 302 gpm, 45 rpm, 15k wob 39.5 23:00 23:30 0.50 18.50 Srvys 4,079 4,079 Survey @ 4035' 23:30 02:30 3.00 21.50 Dir Rotate 4,079 4,174 90 spm, 302 gpm, 15k wob, 45 rpm 31.6 02:30 03:00 0.50 22.00 Srvys 4,174 4,174 Survey @ 4130' 03:00 05:00 2.00 24.00 Dir Rotate 4,174 4,206 90 spm, 302 gpm, 15k wob, 45 rpm 16


### Air/Mud Data MW (lb/gal) 11.40 Vis (s/qt) 47 PV (cp) 19.0 YP (lbf/100ft2) 26 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 16 Filtrate (mL/30min) 4.4 Cake (/32") 1 pH 8.9 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 340 ES (V) HTHP Filt (mL/30min) 250.0 Pf (mL/mL) 0.2 Mf (mL/mL) 0.3 ECD (lb/gal) 11.84 LCM 0 Hole Volume (bbl) 264.2 Pit Volume (bbl) 355.0 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 3780 100 3780 4150 90 10 22 70 4160 90 10 20 70 4180 100 14 70 4200 100 13 70 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 45 PU (max) (1000lbf) 138 SO (1000lbf) 115 Off-Btm Str Wt (1000lbf) 123 Drag (1000lbf) 3 Start (ftKB) 3,554 End (ftKB) 4,206 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 3,367 1.80 84.20 3,463 1.70 102.50 3,588 1.80 114.10 3,653 1.30 110.90 3,749 1.50 139.80 3,844 1.40 153.70 3,939 1.70 141.40 4,035 1.20 90.70 4,130 1.40 129.30 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 107 4.50 16.60 x-95 4.5 xh 3,399 

### Diesel Fuel Received Used 650 Cum On Location 1657 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 54 Q (gpm) 181 Pres (psi) 600 Stroke (in) 12.01 Slow ... Yes No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,640 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 51,702 Cum Cost To Date 591,890 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/23/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 3,554 Footage (ftKB) 537 Avg ROP (ft/hr) 26.8 Drill Hrs (hrs) 20.00 DFS 7 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rot Drlg @ 3554' Planned Operations Drill ahead Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 3,017 3,030 Rot drlg 89 spm, 300 gpm, 14k wob 13 06:30 07:00 0.50 2.00 Srvys 3,030 3,030 Survey @ 2986' 1.2 deg 107.1 07:00 09:30 2.50 4.50 Dir Rotate 3,030 3,126 Rot drlg 89 spm, 300 gpm, 14k wob, 45 rpm, 38.4
09:30 10:00 0.50 5.00 Srvys 3,126 3,126 Survey @ 3082' 1.4 deg 122.3 10:00 13:00 3.00 8.00 Dir Rotate 3,126 3,221 Rot drlg 89 spm, 300 gpm, 14k wob, 45 rpm 31.6 13:00 13:30 0.50 8.50 Srvys 3,221 3,221 Survey @ 3177' 1.6 deg 126.5 azi 13:30 14:30 1.00 9.50 Dir Rotate 3,221 3,254 Rot drlg 89 spm, 300 gpm, 14k wob, 45 rpm 33 14:30 15:30 1.00 10.50 Dir Sliding 3,254 3,265 Slide drlg 90 spm, 302 gpm, 13k wob 11 15:30 16:00 0.50 11.00 Dir Rotate 3,265 3,284 Rot drlg 90 spm, 302 gpm, 14k wob, 45 rpm 38 16:00 16:30 0.50 11.50 Rtn. Maint. 3,284 3,284 Service rig 16:30 17:30 1.00 12.50 Dir Rotate 3,284 3,316 Rot drlg 90 spm, 302 gpm, 14k wob, 48 rpm 32 17:30 18:00 0.50 13.00 Srvys 3,316 3,316 zi 18:00 19:30 1.50 14.50 Dir Sliding 3,316 3,336 Slide drlg 90 spm, 302 gpm 13 19:30 20:30 1.00 15.50 Dir Rotate 3,336 3,348 Rot drlg pumping sweeps of 6 ppb, fiber seal for bit balling 20 bbls/hr 12
20:30 21:30 1.00 16.50 Dir Sliding 3,348 3,354 Slide drlg 91 spm, 305 gpm, 6 21:30 00:00 2.50 19.00 Dir Rotate 3,354 3,411 Rot drlg started pumping sweeps of 6ppb of nut shell for bit balling 20 bbls/hr 22.8
00:00 00:30 0.50 19.50 Srvys 3,411 3,411 Survey @ 3367 1.8 deg 84.20 azi 00:30 01:30 1.00 20.50 Dir Rotate 3,411 3,443 Rot drlg 90 spm, 302 gpm, 16k wob, 35 rpm 32 01:30 02:00 0.50 21.00 Rtn. Maint. 3,443 3,443 Service rig 02:00 03:30 1.50 22.50 Dir Rotate 3,443 3,507 Rot drlg 90 spm, 302 gpm, 16k wob, 35 rpm, stopped pumping sweeps 42.6
03:30 04:00 0.50 23.00 Srvys 3,507 3,507 Survey @ 3463' 1.7 deg 102.5 azi 04:00 05:00 1.00 24.00 Dir Rotate 3,507 3,554 Rot drlg 90 spm, 302 gpm, 14k wob, 47


### Air/Mud Data MW (lb/gal) 11.30 Vis (s/qt) 43 PV (cp) 18.0 YP (lbf/100ft2) 25 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 18 Filtrate (mL/30min) 5.6 Cake (/32") 1 pH 8.8 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 360 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.84 LCM 0 Hole Volume (bbl) 226.4 Pit Volume (bbl) 360.0 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 3220 100 15 22 3450 10 80 10 49 49 3460 80 20 26 49 3480 80 20 35 49 3520 80 20 31 49 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 240.0 Motor RPM (rpm) 90 RPM (rpm) 45 PU (max) (1000lbf) 138 SO (1000lbf) 100 Off-Btm Str Wt (1000lbf) 105 Drag (1000lbf) 5 Start (ftKB) 3,017 End (ftKB) 3,554 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 2,697 1.10 115.30 2,796 1.60 124.70 2,891 1.30 108.20 2,986 1.20 107.10 3,082 1.40 122.30 3,177 1.60 126.50 3,272 2.00 122.30 3,367 1.80 84.20 3,463 1.70 102.50 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 87 4.50 16.60 x-95 4.5 xh 2,763 

### Diesel Fuel Received Used 650 Cum On Location 2307 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 54 Q (gpm) 181 Pres (psi) 600 Stroke (in) 12.01 Slow ... Yes SPM (spm) 54 Q (gpm) 181 Pres (psi) 600 Stroke (in) 12.01 Slow ... Yes No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,640 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 28,615 Cum Cost To Date 540,188 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/22/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 3,017 Footage (ftKB) 677 Avg ROP (ft/hr) 34.7 Drill Hrs (hrs) 19.50 DFS 6 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rot Drlg @ 3017' Planned Operations Drill ahead Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 2,331 2,363 Rot drlg 90 spm, 302 gpm, 13k wob 32 06:00 06:30 0.50 1.50 Srvys 2,363 2,363 Survey @ 2319' 1.6 deg 129.9 azi 06:30 08:30 2.00 3.50 Dir Rotate 2,363 2,458 Rot drlg 90 spm, 302 gpm, 14k wob 47.5 08:30 09:00 0.50 4.00 Srvys 2,458 2,458 Survey @ 2414' 1.9 deg 140.6 azi 09:00 10:30 1.50 5.50 Dir Rotate 2,458 2,522 Rot drlg 90 spm, 302 gpm, 14k wob 42.6 10:30 11:00 0.50 6.00 Rtn. Maint. 2,522 2,522 Service rig 11:00 12:30 1.50 7.50 Dir Sliding 2,522 2,536 Slide drlg 90 spm, 302 gpm, (MTF 350) 12:30 13:00 0.50 8.00 Dir Rotate 2,536 2,554 Rot drlg 90 spm, 302 gpm, 14k wob 36 13:00 13:30 0.50 8.50 Srvys 2,554 2,554 Survey @ 2510' 2.1 deg 148.9 azi 13:30 15:30 2.00 10.50 Dir Rotate 2,554 2,617 Rot dlrg 90 spm, 302 gpm, 14k wob 31.5 15:30 16:30 1.00 11.50 Dir Sliding 2,617 2,637 Slide drlg 90 spm, 302 gpm, 20 16:30 17:00 0.50 12.00 Dir Rotate 2,637 2,649 Rot drlg 90 spm, 302 gpm, 13k wob, 24 17:00 17:30 0.50 12.50 Srvys 2,649 2,649 Survey @ 2605' 1.4 deg 151.6 azi 17:30 19:00 1.50 14.00 Dir Rotate 2,649 2,744 Rot drlg 89 spm, 300 gpm, 13k wob 63 19:00 19:30 0.50 14.50 Srvys 2,744 2,744 Survey @ 2697' 1.1 deg 115.3 azi 19:30 21:00 1.50 16.00 Dir Rotate 2,744 2,808 Rot drlg 89 spm, 300 gpm, 13k wob 42.6 21:00 22:00 1.00 17.00 Dir Sliding 2,808 2,821 Slide drlg 89 spm, 300 gpm, 10k wob 13 22:00 22:30 0.50 17.50 Dir Rotate 2,821 2,840 Rot drlg 89 spm, 300 gpm, 13k wob 38 22:30 23:00 0.50 18.00 Srvys 2,840 2,840 Survey @ 2796' 1.6 deg 124.7 azi 23:00 00:00 1.00 19.00 Dir Rotate 2,840 2,871 Rot drlg 89 spm, 300 gpm, 14k wob 31 00:00 00:30 0.50 19.50 Rtn. Maint. 2,871 2,871 Service rig 00:30 01:00 0.50 20.00 Dir Sliding 2,871 2,881 Slide drlg 89 spm, 300 gpm, 20 01:00 02:30 1.50 21.50 Dir Rotate 2,881 2,935 Rot drlg 89 spm, 300 gpm, 13k wob 36 02:30 03:00 0.50 22.00 Srvys 2,935 2,935 Survey @ 2891' 1.3 deg 108.2 azi 03:00 05:00 2.00 24.00 Dir Rotate 2,935 3,017 Rot drlg 89 spm, 300 gpm, 13k wob


### Air/Mud Data MW (lb/gal) 11.40 Vis (s/qt) 45 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 15 Filtrate (mL/30min) 4.6 Cake (/32") 1 pH 8.5 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 340 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.2 ECD (lb/gal) 11.88 LCM 0 Hole Volume (bbl) 169.8 Pit Volume (bbl) 360.0 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 2540 30 70 24 52 2900 20 80 17 27 2920 20 80 16 27 2940 80 20 16 27 2960 80 20 17 27 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 190.0 Motor RPM (rpm) 91 RPM (rpm) 45 PU (max) (1000lbf) 138 SO (1000lbf) 95 Off-Btm Str Wt (1000lbf) 100 Drag (1000lbf) 5 Start (ftKB) 2,340 End (ftKB) 3,017 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 2,224 1.90 130.70 2,319 1.60 129.90 2,414 1.90 140.60 2,510 2.10 148.90 2,605 1.40 151.60 2,697 1.10 115.30 2,796 1.60 124.70 2,891 1.30 108.20 2,986 1.20 107.10 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 70 4.50 16.60 x-95 4.5 xh 2,223 

### Diesel Fuel Received Used 650 Cum On Location 3557 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 90 Q (gpm) 302 Pres (psi) 1,550 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 29,467 Cum Cost To Date 511,573 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/21/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 2,340 Footage (ftKB) 580 Avg ROP (ft/hr) 29.0 Drill Hrs (hrs) 20.00 DFS 5 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rot drlg @ 2340' Planned Operations Drill ahead Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 1,760 1,855 Rot drlg 89 spm 300 gpm, 10k wob 31 08:00 08:30 0.50 3.50 Srvys 1,855 1,855 Survey @ 1843' 1.8 deg 113.1azi 08:30 11:30 3.00 6.50 Dir Rotate 1,855 1,950 Rot drlg 89 spm, 300 gpm, 10k wob 31 11:30 12:00 0.50 7.00 Srvys 1,950 1,950 Survey @ 1938' 2 deg 128.5azi 12:00 12:30 0.50 7.50 Dir Rotate 1,950 1,982 Rot drlg 89 spm, 300 gpm, 10k wob 32 12:30 13:30 1.00 8.50 Dir Sliding 1,982 1,992 Slide drlg 89 spm, 10k wob 10 13:30 15:00 1.50 10.00 Dir Rotate 1,992 2,045 Rot drlg 89 spm, 300 gpm, 11k wob 35 15:00 15:30 0.50 10.50 Srvys 2,045 2,045 Survey @ 2033' 1.1 deg 151.8 azi 15:30 16:00 0.50 11.00 Dir Rotate 2,045 2,077 Rot drlg 89 spm, 300 gpm, 11k wob 32 16:00 16:30 0.50 11.50 Rtn. Maint. 2,077 2,077 Service rig 16:30 18:00 1.50 13.00 Dir Rotate 2,077 2,109 Rot drlg 89 spm, 300 gpm, 11k wob 32 18:00 18:30 0.50 13.50 Dir Sliding 2,109 2,121 Slide drlg 89 spm, 300 gpm, 113k wob 12 18:30 19:00 0.50 14.00 Dir Rotate 2,121 2,141 Rot dlrg 89 spm, 300 gpm, 11k wob 40 19:00 19:30 0.50 14.50 Srvys 2,141 2,141 Survey @ 2128' 1.7 deg 123.2 19:30 21:30 2.00 16.50 Dir Rotate 2,141 2,204 Rot dlrg 89 spm, 300 gpm, 11k wob 31 21:30 22:00 0.50 17.00 Rtn. Maint. 2,204 2,204 Service rig 22:00 22:30 0.50 17.50 Dir Sliding 2,204 2,209 Slide drlg 89 spm, 300 gpm, 13k wob 10 22:30 23:30 1.00 18.50 Dir Rotate 2,209 2,236 Rot drlg 89 spm, 300 gpm,, 12k wob 27 23:30 00:00 0.50 19.00 Srvys 2,236 2,236 Survey @ 2224' 1.9 deg 130.7 00:00 02:30 2.50 21.50 Dir Rotate 2,236 2,300 Rot drlg 89 spm, 300 gpm, 13kwob 26 02:30 03:30 1.00 22.50 Dir Sliding 2,300 2,310 Slide drlg 89 spm, 300 gpm, 13k wob 10 03:30 04:30 1.00 23.50 Dir Rotate 2,310 2,331 Rot drlg 89 spm, 300 gpm, 13k wob 23 04:30 05:00 0.50 24.00 Srvys 2,331 2,331 Survey @ 2287' 1.8 deg 134.9 azi


### Air/Mud Data MW (lb/gal) 11.30 Vis (s/qt) 43 PV (cp) 17.0 YP (lbf/100ft2) 25 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 15 Filtrate (mL/30min) 4.8 Cake (/32") 1 pH 8.8 Solids (%) 17 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 560 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.1 Mf (mL/mL) 0.3 ECD (lb/gal) 11.84 LCM 0 Hole Volume (bbl) 119.5 Pit Volume (bbl) 350.0 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 1980 50 50 14 48 2290 40 60 17 48 2300 40 60 16 48 2310 40 60 15 48 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 200.0 Motor RPM (rpm) 90 RPM (rpm) 45 PU (max) (1000lbf) 138 SO (1000lbf) 92 Off-Btm Str Wt (1000lbf) 95 Drag (1000lbf) 1 Start (ftKB) 1,760 End (ftKB) 2,340 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 1,559 1.60 103.70 1,652 1.50 55.20 1,747 1.60 89.40 1,843 1.80 113.10 1,938 2.00 128.50 2,033 1.10 151.80 2,128 1.70 123.20 2,224 1.90 130.70 2,319 1.60 129.90 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 49 4.50 16.60 x-95 4.5 xh 1,556 

### Diesel Fuel Received Used 650 Cum On Location 3557 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 54 Q (gpm) 181 Pres (psi) 600 Stroke (in) 12.01 Slow ... Yes No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 89 Q (gpm) 298 Pres (psi) 1,425 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 34,085 Cum Cost To Date 482,106 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/20/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 1,760 Footage (ftKB) 370 Avg ROP (ft/hr) 17.6 Drill Hrs (hrs) 21.00 DFS 4 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Running MWD survey Planned Operations Drill ahead Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 Rotate 1,390 1,412 Rot drlg @ 1412' 8.8 07:30 08:00 0.50 3.00 Rtn. Maint. 1,412 1,412 Service rig 08:00 09:30 1.50 4.50 Dir Sliding 1,412 1,422 Slide drlg @ 1422' 88 spm, 295 gpm, 09:30 12:30 3.00 7.50 Dir Rotate 1,422 1,476 Rot dlrg @ 1476' 18 12:30 13:00 0.50 8.00 Srvys 1,476 1,476 Dev survey @ 1432' 1.9 deg 153.7 azi 13:00 14:30 1.50 9.50 Dir Rotate 1,476 1,507 Rot drlg @ 1490' 89 spm 300 gpm, 20.6 14:30 15:30 1.00 10.50 Dir Sliding 1,507 1,514 Slide drlg @ 1514, 89 spm, 300 gpm 7 15:30 17:30 2.00 12.50 Dir Rotate 1,514 1,539 Rot drlg @ 1539, 89 spm, 300 gpm, 118 rpm 25 17:30 18:30 1.00 13.50 Dir Sliding 1,539 1,549 Slide drlg @ 1549 89 spm, 300 gpm, 10 18:30 19:00 0.50 14.00 Dir Rotate 1,549 1,571 Rot drlg 89 spm, 300 gpm, 118 ttl rpm, rot 45 44
19:00 19:30 0.50 14.50 Srvys 1,571 1,571 Survey @ 1559' 1.6 deg 103.7 azi 19:30 21:00 1.50 16.00 Dir Sliding 1,571 1,588 Slide drlg @ 1588' 89 spm, 300 gpm, 11.3 21:00 00:00 3.00 19.00 Dir Rotate 1,588 1,666 Rot drlg 89 spm, 300 gpm, 118 rpm 26 00:00 00:30 0.50 19.50 Srvys 1,666 1,666 Survey @ 1652' 1.5 deg 55.2 azi 00:30 01:30 1.00 20.50 Dir Rotate 1,666 1,696 Rot drlg 89 spm, 300 gpm, 118 rpm 30 01:30 02:00 0.50 21.00 Rtn. Maint. 1,696 1,696 Service rig 02:00 03:00 1.00 22.00 Dir Rotate 1,696 1,728 Rot drlg 89 spm, 300 gpm 32 03:00 03:30 0.50 22.50 Dir Sliding 1,728 1,735 Slide drlg 89 spm, 300 gpm 14 03:30 04:30 1.00 23.50 Dir Rotate 1,735 1,760 Rot dlrg 89 spm, 300 gpm, 118 rpm 25 04:30 05:00 0.50 24.00 Srvys 1,760 1,760 Survey @ 1720' 1.4 deg 69.8 azi


### Air/Mud Data MW (lb/gal) 11.10 Vis (s/qt) 46 PV (cp) 19.0 YP (lbf/100ft2) 25 Gel 10 sec 8 Gel 10 min 12 Gel 30 min 16 Filtrate (mL/30min) 6.0 Cake (/32") 1 pH 9.0 Solids (%) 16 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 80 Chlor (mg/L)

178,000 Ca (mg/L) 460 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.3 Mf (mL/mL) 0.5 ECD (lb/gal) 11.58 LCM 0 Hole Volume (bbl) 81.8 Pit Volume (bbl) 320.0 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 1470 70 30 11 11 1730 80 20 11 11 1740 80 20 10 11 1750 80 20 11 11 1760 80 20 11 11 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 200.0 Motor RPM (rpm) 90 RPM (rpm) 45 PU (max) (1000lbf) 138 SO (1000lbf) 85 Off-Btm Str Wt (1000lbf) 85 Drag (1000lbf) 0 Start (ftKB) 1,390 End (ftKB) 1,760 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 141 0.40 147.80 249 1.00 147.80 600 1.00 147.80 1,000 1.50 147.80 1,463 2.10 147.80 1,559 1.60 103.70 1,652 1.50 55.20 1,747 1.60 89.40 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 30 4.50 16.60 x-95 4.5 xh 949 

### Diesel Fuel Received Used 650 Cum On Location 4207 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 54 Q (gpm) 181 Pres (psi) 300 Stroke (in) 12.01 Slow ... Yes SPM (spm) 89 Q (gpm) 298 Pres (psi) 1,425 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 50,271 Cum Cost To Date 448,021 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/19/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 1,390 Footage (ftKB) 23 Avg ROP (ft/hr) 23.0 Drill Hrs (hrs) 1.00 DFS 3 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Drlg @ 1390' Planned Operations Drill ahead Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 NU & Test 1,367 1,367 Test well head 06:30 07:00 0.50 2.00 Rtn. Maint. 1,367 1,367 Service rig 07:00 13:30 6.50 8.50 NU & Test 1,367 1,367 Nipple up BOPE and start working on flow line 13:30 17:00 3.50 12.00 NU & Test 1,367 1,367 Test BOPE 17:00 21:30 4.50 16.50 Rig Up & Down 1,367 1,367 Rig up flow line and hopper line in active pits 21:30 22:30 1.00 17.50 Trip - Other 1,367 1,367 Pick up dir tools and test 22:30 23:00 0.50 18.00 Rtn. Maint. 1,367 1,367 Service rig 23:00 01:00 2.00 20.00 Trip - Other 1,367 1,367 TIH with bit #2 and tag up @ 1270' 01:00 03:30 2.50 22.50 Drilling Cement 1,367 1,367 Drill cement f/1270'-1367'

03:30 04:00 0.50 23.00 C&C Hole/Mud 1,367 1,367 Displace f/w with 10.8 ppb mud
04:00 05:00 1.00 24.00 Drilling 1,367 1,390 Drilling @ 1390' 88 spm, 295 gpm


### Air/Mud Data MW (lb/gal) 10.80 Vis (s/qt) 54 PV (cp) 21.0 YP (lbf/100ft2) 26 Gel 10 sec 10 Gel 10 min 15 Gel 30 min 22 Filtrate (mL/30min) 5.2 Cake (/32") 1 pH 9.0 Solids (%) 15 LGS (%) 5 MBT (lb/bbl) Oil (%) 3 H20 (%) 82 Chlor (mg/L)

178,000 Ca (mg/L) 460 ES (V) HTHP Filt (mL/30min) Pf (mL/mL) 0.2 Mf (mL/mL) 0.4 ECD (lb/gal) 10.80 LCM 0 Hole Volume (bbl) 125.8 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 1390 90 10 10 10 

### Bit Run # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit WOB (min) (1000lbf) 5 WOB (max) (1000lbf) 16 BHA ROP (ft/hr) 24 SPP (psi) 200.0 Motor RPM (rpm) 95 RPM (rpm) 45 PU (max) (1000lbf) 138 SO (1000lbf) 80 Off-Btm Str Wt (1000lbf) 80 Drag (1000lbf) 0 Start (ftKB) 1,367 End (ftKB) 1,390 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 141 0.40 147.80 249 1.00 147.80 600 1.00 147.80 1,000 1.50 147.80 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 17 4.50 16.60 x-95 4.5 xh 571 

### Diesel Fuel Received Used 550 Cum On Location 4857 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 54 Q (gpm) 181 Pres (psi) 500 Stroke (in) 12.01 Slow ... Yes No. 2 Make Continental-Emsco Model FA-1300 Liner Size (in) 5 1/2 Rod Dia (in) 2 1/2 Stroke (in) 12.01 SPM (spm) 88 Q (gpm) 295 Pres (psi) 1,115 Stroke (in) 12.01 Slow ... No Costs Daily Cost Total 27,597 Cum Cost To Date 397,750 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/18/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 1,367 Footage (ftKB) 0 Avg ROP (ft/hr) Drill Hrs (hrs) DFS 2 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Weld on well head Planned Operations Nipple up BOPE Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 Surf Csg/Cmt 1,367 1,367 Ran 34jts 9 5/8" 36# J-55 lt&c csg set @ 1367' 06:30 07:30 1.00 2.50 C&C Hole/Mud 1,367 1,367 pumped 250 bbls f/w gel with 20ppb LCM

07:30 09:30 2.00 4.50 Surf Csg/Cmt 1,367 1,367 Pumped ttl 800 sks class c cement, no returns during job, landed plug with 500 psi, final lift 50 psi 09:30 13:30 4.00 8.50 WOC 1,367 1,367 hold pressure on cement head, let cement set to run temp survey 13:30 14:00 0.50 9.00 WOC 1,367 1,367 Running cement temp log, est. top of cement 765' 14:00 16:00 2.00 11.00 WOC 1,367 1,367 WOC 16:00 17:00 1.00 12.00 WOC 1,367 1,367 #2 temp log run, est top of cement @ 765' 17:00 17:30 0.50 12.50 Rtn. Maint. 1,367 1,367 Service rig 17:30 19:00 1.50 14.00 Rig Up & Down 1,367 1,367 rig up and run 15 jts 1" pipe to 300'

19:00 20:00 1.00 15.00 Surf Csg/Cmt 1,367 1,367 pumped 200sks class C top out cement did not circ. cement to surface 20:00 22:00 2.00 17.00 WOC 1,367 1,367 R/R comm on loc wait for cement to set 22:00 23:30 1.50 18.50 Surf Csg/Cmt 1,367 1,367 Ran 4 jts 1" pipe pumped 100 sks class c cement and circ 5 sks to surface 23:30 01:30 2.00 20.50 WOC 1,367 1,367 Cut conductor make final cut on 9 5/8" 01:30 05:00 3.50 24.00 Rig Up & Down 1,367 1,367 Weld on weld head



### 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 # 2 Size (in)

8 3/4 Model MDi513 Make Smith Jets (/32")

10/10/10/10/12/10/10 In (ftKB) 1,367 Out (ftKB) 4,971 Drld (ftKB) 3,604 Drl Hrs (hrs) 152.50 Avg ROP (ft/hr) 23.6

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 2 4 CT S X 0 ER HR-Bit 

### Bit Run # 1 Size (in)

12 1/4 Model N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 141 0.40 147.80 249 1.00 147.80 600 1.00 147.80 1,000 1.50 147.80 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #2, 8 3/4 Steerable BHA No. 2 Drill String Name 8 3/4 Steerable Length (ft) 760.10 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/2 170.50 152.19 1 Jars -

Hydraulic 6 1/2 152.50 30.72

17 DC 6 1/2 170.50 520.46

1 MWD/NMDC 6 1/2 152.50 31.05 1 UBHO 6 1/2 152.50 2.42 1 Great White 1.83 0.30 6 1/2 152.50 22.26 Drill Pipe in Hole

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



### Diesel Fuel Received Used 500 Cum On Location 5407 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 No. 2 Make Continental-Emsco Model FA-1300 Costs Daily Cost Total 78,263 Cum Cost To Date 370,153 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report

# Lariat

Report Date: 9/17/2009 Spud Date: 9/16/2009 Well Name WEST RANCH 31-32 Proposed TD (ftKB) 7,300 MD (ftKB) 1,367 Footage (ftKB) 1,327 Avg ROP (ft/hr) 73.7 Drill Hrs (hrs) 18.00 DFS 1 Field Name PINON (OVERTHRUST) Corp ID 102814 County/Parish PECOS ST TX Section 31 Blk/Twn 138 Survey/Range T&STL Operations at Report Time Rigging up csg crew Planned Operations Run 9 5/8" surface csg and cement Drilling Manager Roger Wilson Drilling Engineer Marc Harvey Geology Contact Michael Rigby Field Geologist Will Murley Drilling Supt. Lawrence Rogers Company Man Jason Harrison

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 Rig Up & Down 40 40 Picking up 12.25 Hammer and testing
06:00 08:30 2.50 3.50 Drilling 40 200 Mist drilling rpm 25, 2k wob, 64 08:30 09:00 0.50 4.00 Srvys 200 200 Dev survey @ 141' .4 deg 09:00 13:30 4.50 8.50 Drilling 200 614 Mist drlg, rpm 25, 2k wob, 92 13:30 14:00 0.50 9.00 Srvys 614 614 Survey @ 600' 1 deg 14:00 19:00 5.00 14.00 Drilling 614 1,041 @ 709' lost 50% returns @ 900' lost all returns 19:00 19:30 0.50 14.50 Srvys 1,041 1,041 Survey @ 1000' 1.5 deg 19:30 23:30 4.00 18.50 Drilling 1,041 1,367 mist drlg 25 rpm, 3kwob, no circ returns 23:30 00:00 0.50 19.00 Rtn. Maint. 1,367 1,367 service rig and circ hole clean 00:00 00:30 0.50 19.50 Trip - Other 1,367 1,367 pump out and laydown 6 jts 00:30 02:00 1.50 21.00 Trip - Other 1,367 1,367 TOOH with hammer 02:00 04:00 2.00 23.00 Rig Up & Down 1,367 1,367 Rig up laydown machine and lay down 8" collars 04:00 05:00 1.00 24.00 Rig Up & Down 1,367 1,367 Rig up csg crew and hold saftey meeting R/R contacted Job # 10069



### 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 4 Boosters 2 Nitrogen Units 0 Air/Gas Vol. (mcf) 4,100.000 Pressure (psi) 605.00 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 N-125 Make Numa Jets (/32") In (ftKB) 40 Out (ftKB) 1,367 Drld (ftKB) 1,327 Drl Hrs (hrs) 18.00 Avg ROP (ft/hr) 73.7

Inner Outer Dull Loc Bearing Gauge Other Reason LD Comment 1 1 FC A E 0 No TD WOB (min) (1000lbf) 3 WOB (max) (1000lbf) 3 BHA ROP (ft/hr) 74 SPP (psi) Motor RPM (rpm) RPM (rpm) 25 PU (max) (1000lbf) 105 SO (1000lbf) 95 Off-Btm Str Wt (1000lbf) 100 Drag (1000lbf) 5 Start (ftKB) 40 End (ftKB) 1,367 Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn Length (ftKB) Comment 319 4.50 16.6 X-95 4.5 xh 10,250 Survey Data MD (ftKB) Incl (°) Azm (°) 141 0.40 147.80 249 1.00 147.80 600 1.00 147.80 1,000 1.50 147.80 Casing Strings

Csg Desc String OD (in) String Wt (lbs/ft) String Grade Set Depth (ftKB) Conductor 16 65.00 H-40 40 Surface 9 5/8 36.00 J-55 1,367 

### BHA #1, 12 1/4 Slick BHA No. 1 Drill String Name 12 1/4 Slick Length (ft) 813.28 BHA Components

Jts Item Description Bend (°) Rpg OD (in) Run (hrs) Len (ft) 5 DC 6 1/4 18.00 152.19 1 Jars -

Hydraulic 6 1/4 18.00 30.72

17 DC 6 1/4 18.00 520.46

1 XO Sub 8 18.00 3.10 3 DC 8 18.00 93.04 1 Bit Sub

w/Float 8 18.00 3.00

1 Hammer 10 3/4 18.00 7.77

Drill Pipe in Hole

# of Jts Size (in) Wt Grade Conn Length (ftKB) 16 4.50 16.60 x-95 4.5 xh 508 

### Diesel Fuel Received Used 500 Cum On Location 5907 Last BOP Test End Date 9/18/2009
Mud Pumps No. 1 Make Continental-Emsco Model FA-1300 No. 2 Make Continental-Emsco Model FA-1300 Costs Daily Cost Total 291,890 Cum Cost To Date 291,890 AFE Rig Release Cost Cost 1,609,075 A FE: 091093 

# 41 Drilling Report