SandRidge Energy

WR 45-14 

No. 19a – Frac Service Company

Stages 1, 2 & 3 Superior
SandRidge Energy

WR 45-14 

No. 9 - Pressure Test of Casing

1.30.10 WellView Field Report says: pressure test csg to 4800 psi 20 min. 
February 20, 2010 POST TREATMENT REPORT

 Sand Ridge Energy 

 West Ranch 45-14 stg.3 

 Pecos County, Tx. 

 Treatment Date: February 20, 2010 

Attn: 

Sandridge Energy 

The stimulation of the West Ranch 45-14 stg.3 well consisted of 1923 total foam bbls of 

20# Linear Gel fluid @ 70Q. 195 tons of CO2 was used. This fluid was laden with 71,950 lbs of 

20/40 Ottawa sand in a 1, 1-4 lb hold, and 8,283 lbs 20/40 SLC sand in a 4 lb hold. It was 

pumped at an average rate of 49.8 bpm, and an average surface pressure of 3,676 psi. The ISIP 

was 3,057 psi and the approximate load to recover is 750 bbls. Please find the attached Meyers 

Charts recorded during the job for stg. #3. 

Superior Well Services appreciates the opportunity to perform pumping services for you 

in a cost-effective manner that focuses on quality and safety. 

Please contact the Midland Engineering Department if you have any questions. 

Thank you, 

Ricky Herrera 

Field Engineer

Midland, TX 

(432) 813-6420 

rherrera@swsi.com
Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATESuperior Rep. Customer Rep. Stage #

JOHNNY ANAYA

Co2 Rate CO2 Total Total Rate Gel Foam Prop Total

BPM BBLS BPM Quality Quality LBS/Stg

100

35 42 50 30 70

34 72 50 30 70 11,751

33 95 48 30 70

34 119 50 30 70 7,588

32 137 50 30 70 10,492

32 155 51 30 70 14,17631 168 50 30 70 12,64230 181 50 30 70 15,30130 193 51 30 70 8,283

43

Job Description / Remarks

Proppant Conc / Type

AOL

Rig up risers on 46-8

Stimulation Treatment Report

55-000361 02/20/10

WEST RANCH 45-14 PecosSANDRIDGE ENERGY

TX

George Castillo 3

ANNULUS BPM BBLS BBLS

5:30

Time

Pressures (psi) Rate Stage Total

STP

5:45

45-14 due to sand not being 

delivered.

8:30 

Rig up risers on 45-14

iso tool 

decision was made to pump

Rig down risers and move

10:15 3823 8 53 53 Breakdown

10:14 1700 Open Wellhead

9:45 Safety meeting

10:28 4007 16.4 82 243 1# 20/40 Ottawa10:20 3290 14.8 108 161 Pad

2# 20/40 otttawa

10:44 3621 18.9 58 483 2.5# 20/40 ottawa

10:41 3701 17.8 55 425 

Sweep 

10:37 3741 16.5 65 370 1# 20/40 ottawa10:33 3496 15 62 30510:49 3292 20 49 575 4# 20/40 Ottawa10:47 3483 19 43 526 3# 20/40 Ottawa 

4# 20/40 Ottawa

10:54 3136 42.6 218 836 Flush

10:51 3444 20.6 43 618 

Maximum 4007 Maximum 43 5 Min. 

Treating Presure Injection Rates Shut In Pressures 

Minimum Minimum 8 ISDP 3057 

Operators 

Max Pressure 6200

15 Min. 

Average 3395 Average 19 10 Min.

Final 

Page 1
PROPPANT PLOT

0 10 20 30 

TIME (min)

0123456789

101112131415

BLENDER DENSITY (lb/gal)

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

MView - MVIEW W.R. 45-14 STG.3 - 2/20/2010
BOTTOM HOLE QUALITY

0 10 20 30 40 

TIME (min)

0

102030405060708090

100

Real-Time SLURRY RATE (bpm)Real-Time CO2 RATE (bpm)

Real-Time BLReal-Time BO

MView - MVIEW W.R. 45-14 STG.3 - 2/20/2010
HYDRATION CHEMICALS

0 10 20 30 40 

TIME (min)

02468

101214161820

LSG GPT (gal/1000 gal)

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

MView - MVIEW W.R. 45-14 STG.3 - 2/20/2010
BLENDER CHEMICALS

0 10 20 30 40 

TIME (min)

0.000.000.500.501.001.001.501.502.002.002.502.503.003.003.503.504.004.004.504.505.005.00

Real-Time CLAY TREAT PP GPT (gal/1000 gal)Real-Time OB1/OB2 GPT (lbm/1000 gal)

Real-Time ACT

MView - MVIEW W.R. 45-14 STG.3 - 2/20/2010
MAIN PLOT W.R. 45-14 STG

0 10 20 30 40 

TIME (min)

0

100020003000400050006000700080009000

10000

Real-Time PRESSURE (psi)Real-Time PRESSURE II (psi)Real-Time ANNULUS PRESSURE (psi)

Real-Time FOReal-Time SLReal-Time COReal-Time BLReal-Time INL

MView - MVIEW W.R. 45-14 STG.3 - 2/20/2010
BHP Difference Plot

0.1 1 10 

Time (min)

10

100

1000

10000

Measured Minus MFrac BHP (psi)

BHTP Dif. (Measured - MFrac) (psi) BH Conc. (lbm

MWell - MWELL W.R. 45-14 STG.3 - 2/20/2010
BHTP & SP W.R. 45-14 STG.

0 10 20 30 40 

Time (min)

0

100020003000400050006000700080009000

10000

Pressure (psi)

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

Measured SurfBH Conc. (lbmMeasured Surf

MWell - MWELL W.R. 45-14 STG.3 - 2/20/2010
CUSTOMER WELL NAME DATE FIELD RECIEPT # FLUID TECH

SANDRIDGE ENERGY WEST RANCH 45-14 2/20/10 PADILLA

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

 Water bbls. Per stges.>> 

SYSTEM:

Chemicals BEG. ENDING 

LSG-1 1476 1341 135 

CLAYTREAT P 274 216 58 

SUPERNE-100 315 249 66 

OB-1 613 604 9 OB-2 45 37 8 

ACTIVATOR 81 74 7 

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

0 0 

0 0 

Comments :
DATE:

FIELD RECEIPT #:

FLUID TECH:

Net Usage

135

58

66

9

8

7

0

0

0

0

0

0

0

0

Fluid Tech Signature : 

274

315

216

249

604

37

613

45

81 74

OB-2

ACTIVATOR

CLAYTREAT PP

SUPERNE-100

OB-1

LSG-1

Loaded

1476

Returned

1341

Product Description

2/8/2010 SANDRIDGE ENERGY

STAGE 2

CHEM-ADD OPERATOR:

CUSTOMER:

LEASE NAME & WELL #:

PADILLA

WEST RANCH 22-22

CALVIN/RITO

Load Sheet
Page of

Propant placed in the district proppant silos shall be tested at a minimum interval of every 250,000 pounds.

X

X

CLAYTREAT

SUPERNE-1

Size lb Size lb

No

94.7% 95.0%

Recognized proppant or gravel sizes: 6/12, 8/16, 12/20, 16/20, 16/30, 20/40, 30/50, 40/70, or 50/70 (40/60 for gravel)

*Recombine all proppant samples to represent 100,000 lbs or fraction. Gravel samples should represent 2,000 lbs or fraction.

WEST RANCH 45-14 DISTRICT PROPPANT SILO:

UNIT/COMPARTMENT:

Combine all samples

Nominal size from list below

Is total weight for each size appropriate for job requirements?

Total weight , each size

20/40 SLC

50 grams of sample

4.83 4.2 8.40

Amount Retained

50

50

Weight

Is the content color right Yes/No Yes

Yes

Weight

VENDOR:

ACTIVATOR

FIELD RECEIPT NO:

LEASE NAME & WELL NO:

Other (specify)

Ceramic proppant Curable

Sintered bauxite

Other (specify)

If proppant, select type

Proppant 100 mesh sand

Brady

QUALITY CONTROL OF PROPPANT/GRAVEL/100 MESH SAND

(Attachment to Treatment Report)

CUSTOMER: SANDRIDGE ENERGY

No. No.

Ottawa

Gravel

If gravel, select type

Ottawa

Resieved

Resin coated sand

OB-1

OB-2 No. No.

of the truck proper? low dust Yes/No Yes

No.

oversize <.1%

appearance right Yes/No Yes

insize>90%

no contamination Yes/No Yes

Does the manufacturer's

Yes/No Yes

Yes/No Yes

sieve analysis meet fines<1%

Yes

specifications? Attach all. Yes

Sample taken? Yes/No

Yes/No

If not appropriate, correct problem before sieve analysis. If the manufacturer's sieve analysis does not meet specifications, perform sieve analysis. 

Is the truck content acceptable? Yes/No Yes

Spot check manufacturer's sieve analysis at a minimum of every 250,000 lbs.

Sieve mesh

}

0.00

21.20

54.18

19.30

16

Sieve Analysis

fines

pass

Total wt. Gram

0.00

51.9 103.88

Turbidity

Tested By: PADILLA

9.66

104.94

fail

pass pass fail

52.5

pass

pH

Pan

Total wt. Gram

Turbidity

fail pH

fail

fines

20

30

35

40

Sieve Analysis

20/40 WHITE

Sieve mesh Gram

10.6

27.09

9.65

0.3

0

0.00

%

50

Combine all samples

grams of sample

Amount Retained

0.60

Total 

%

0.00

Gram

0.00 Total 

20 0.24 0.48 In-Size 

20.20 } 35 26.5

0.00

53.00

40 10.9 21.80

16 0

30 10.1

In-Size 
Total Variance: 4.74% 

DATE: FLUID TECHFIELD RECEIPT NO:

2 3 4 5 6 7 8 9 10 

PLANNED FLOW 

PROPOSED START HOSES END TOTAL LOSSES PUMPED VOLUME METER 

VOLUME LOADED USED DOWNHOLE FOR FLUID MEASURED 

PUMPED VOLUME 

1476 1470 1341 135 6 129 127 

274 270 216 58 4 54 53 315 310 249 66 5 61 6613 613 604 9 0 9 9 

45 45 37 8 0 8 8 

81 77 74 7 4 3 4 

13 14 

PROPPANT (lbs)

CLAYTREAT PPSUPERNE-100OB-1

PRODUCT VARIANCE CALCULATIONS

CHEMICALS

CHEM-ADD OPERATOR: 

1

MEASURED VOLUMES

LEASE NAME & WELL NO:

2/20/2010 SANDRIDGE ENERGY CUSTOMER:

WEST RANCH 45-14

PRODUCT

LSG-1OB-2ACTIVATOR

13 14 15 16 17 18 

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

20/40 WHITE 2.65 SUPER LC 20/40 2.65 

CLEAN VOLUME Comments:

FLOW METER SLUR

29 40

PROPPANT VOLUME

SLURRY VOLUME (bbls)

8,283

71,950

LOCATION

CLEAN VOLUME (bbls)

AFTER LOADING

24

BEGINNING VOLUME

28

25

BASE FLUID DESCRIPTION

8,283 0

IN SAND KING (est.)

0

DEN

20# LINEAR 

ENDING VOLUME

21

71,950

T

PUMPED 

DOWNHOLE

0

22

15 16 17 18

TOTAL SLURRY

30

FLOW M

SPILLAGE

DOWNHOLE VOLUME

0

(est.on the ground)

23
DATE:CUSTOMER:Tank/Transport No. 234567Water Quality City Well Clarity, color, odor CLEAR CLEAR CLEAR CLEAR CLEAR CLEARSample Temperature, (F) 62 62 62 62 62 62Specific gravity 1.050 1.027 1.029 1.024 1.030 1.030Initial pH 7.64 7.8 7.8 7.8 7.89 7.86Iron (Fe++/Fe+++) ppm 000000CHLORIDE,PPM 20645 20582 20376 20574 20984 20546 Aerobic: No. per ml/time / / / / / / / / / / /  Anaerobic: No. per ml/time / / / / / / / / / / / 

Base Gel Quality Use additional copies of this form for each series 

Name of product system mixed 20#LSGGellant loading (lbs/1000 gal.) 5Fluid sampling location PILOTSampling time 6:30Sample Temperature, (F) 62pH 8.2

3 min. 19

Fann reading 9 min. 22

@ 300 rpm 30 min. 24

60 min.

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

Tested by:

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

Date water sampled: Source of water:

Biocide added before H2O?

Field Pilot Test Batch Mixed Gel Quality Test

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

Date Biocide Added:

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

WATER BASED FRAC FLUID QUALITY CONTROL

(Attachment to Treatment Report)

2/20/2010 FIELD RECEIPT NO:

LEASE NAME & WELL NO: WEST RANCH 45-14
Pump Schedule

Customer Name: SANDRIDGEWell Name: WEST RANCH 45-14 STG.3Formation: TESNUSFluid Type: 20# LIN/70Q

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

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

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

PAD 17500 0.00 0.00 0.00 0.00 0 0 15.0 15.0 35.0 125.0 125.0 12

1# 20/40 WHITE 10000 1.00 1.00 3.33 3.33 10000 10000 16.5 14.3 33.5 71.4 82.3 2

SWEEP 10000 0.00 0.00 0.00 0.00 0 10000 15.0 15.0 35.0 71.4 71.4 27

1# 20/40 WHITE 8000 1.00 1.00 3.33 3.33 8000 18000 16.5 14.3 33.5 57.1 65.8 34

2# 20/40 WHITE 6000 2.00 2.00 6.67 6.67 12000 30000 17.9 13.7 32.1 42.9 55.9 4

2.5# 20/40 WHITE 6000 2.50 2.50 8.33 8.33 15000 45000 18.6 13.5 31.4 42.9 59.1 4

3# 20/40 WHITE 4000 3.00 3.00 10.00 10.00 12000 57000 19.2 13.2 30.8 28.6 41.6 5

4# 20/40 WHITE 4000 4.00 4.00 13.33 13.33 16000 73000 20.4 12.7 29.6 28.6 45.9 54

4# 20/40 SLC 2000 4.00 4.00 13.33 13.33 8000 81000 20.4 12.7 29.6 14.3 23.1 57

FLUSH 9180 0.00 0.00 0.00 0.00 0 81000 50.0 50.0 0.0 218.6 218.6 7

Design Totals --> 76680 81000 0 700.7 788.8 Actual Totals -->

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

Top Perf 5728 50 Tubing Casing

Bottom Perf 5796 Casing 219.15 Blen

N/A Annulus

Flu

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

Casing 7 0.03826 6.276 Flush (bbls) Hydra

Tubing Top 219.2

Annulus Bottom 221.8

26
Superior Well Services

Additive Schedule

Customer Name: SANDRIDGE 2/20/2010Well Name: WEST RANCH 45-14 STG.3 Formation: TESNUS

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

PPG VOLUME LOAD AMOUNT 11 BPM 13 BPM 15 BPM 17 BPM 19 BPM Actual GONE 11 13 15 1

0.00 5250 5.00 26.25 2.31 2.73 3.15 3.57 3.99 26.25 11.0 13.0 15.0 17

3.33 3000 5.00 15.00 2.00 2.37 2.73 3.11 3.47 41.25 9.5 11.3 13.0 14

0.00 3000 5.00 15.00 2.31 2.73 3.15 3.57 3.99 56.25 11.0 13.0 15.0 17

3.33 2400 5.00 12.00 2.00 2.37 2.73 3.11 3.47 68.25 9.5 11.3 13.0 14

6.67 1800 5.00 9.00 1.76 2.10 2.42 2.73 3.07 77.25 8.4 10.0 11.5 13

8.33 1800 5.00 9.00 1.68 1.97 2.29 2.58 2.90 86.25 8.0 9.4 10.9 12

10.00 1200 5.00 6.00 1.60 1.87 2.16 2.46 2.73 92.25 7.6 8.9 10.3 1113.33 1200 5.00 6.00 1.43 1.70 1.95 2.23 2.48 98.25 6.8 8.1 9.3 1013.33 600 5.00 3.00 1.43 1.70 1.95 2.21 2.48 101.25 6.8 8.1 9.3 10

0.00 9180 0.00 0.00 0.00 0.00 0.00 0.00 0.00 101.25 11.0 13.0 15.0 17

101.25101.25101.25101.25101.25101.25101.25101.25101.25101.25101.25

Additive: CLAYTREAT PP Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 11 BPM 13 BPM 15 BPM 17 BPM 19 BPM Actual GONE 11 13 15 1

0.00 5250 2.00 10.50 0.92 1.09 1.26 1.43 1.60 10.50 11.0 13.0 15.0 17

3.33 3000 2.00 6.00 0.80 0.95 1.09 1.24 1.39 16.50 9.5 11.3 13.0 14

0.00 3000 2.00 6.00 0.92 1.09 1.26 1.43 1.60 22.50 11.0 13.0 15.0 173.33 2400 2.00 4.80 0.80 0.95 1.09 1.24 1.39 27.30 9.5 11.3 13.0 14

6.67 1800 2.00 3.60 0.71 0.84 0.97 1.09 1.23 30.90 8.4 10.0 11.5 13

8.33 1800 2.00 3.60 0.67 0.79 0.92 1.03 1.16 34.50 8.0 9.4 10.9 12

10.00 1200 2.00 2.40 0.64 0.75 0.87 0.98 1.09 36.90 7.6 8.9 10.3 1113.33 1200 2.00 2.40 0.57 0.68 0.78 0.89 0.99 39.30 6.8 8.1 9.3 1013.33 600 2.00 1.20 0.57 0.68 0.78 0.88 0.99 40.50 6.8 8.1 9.3 10

0.00 9180 2.00 18.36 0.92 1.09 1.26 1.43 1.60 58.86 11.0 13.0 15.0 17

58.8658.8658.8658.8658.8658.8658.8658.8658.8658.8658.86

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

PPG VOLUME LOAD AMOUNT 11 BPM 13 BPM 15 BPM 17 BPM 19 BPM Actual GONE 11 13 15 1

0.00 5250 0.50 2.63 0.23 0.27 0.32 0.36 0.40 2.63 11.0 13.0 15.0 17

3.33 3000 0.50 1.50 0.20 0.24 0.27 0.31 0.35 4.13 9.5 11.3 13.0 14

0.00 3000 0.50 1.50 0.23 0.27 0.32 0.36 0.40 5.63 11.0 13.0 15.0 17

3.33 2400 0.50 1.20 0.20 0.24 0.27 0.31 0.35 6.83 9.5 11.3 13.0 14

6.67 1800 0.50 0.90 0.18 0.21 0.24 0.27 0.31 7.73 8.4 10.0 11.5 13

8.33 1800 0.50 0.90 0.17 0.20 0.23 0.26 0.29 8.63 8.0 9.4 10.9 12

10.00 1200 0.50 0.60 0.16 0.19 0.22 0.25 0.27 9.23 7.6 8.9 10.3 1113.33 1200 0.50 0.60 0.14 0.17 0.20 0.22 0.25 9.83 6.8 8.1 9.3 1013.33 600 0.50 0.30 0.14 0.17 0.20 0.22 0.25 10.13 6.8 8.1 9.3 10

0.00 9180 0.50 4.59 0.23 0.27 0.32 0.36 0.40 14.72 11.0 13.0 15.0 17

14.7214.7214.7214.7214.7214.7214.7214.7214.7214.7214.72 #VALUE! #VALUE! #VALUE! #VA
Superior Well Services

Additive Schedule

Fluid Technician: PADILLAField Receipt #: STG.3 Prepared By: RICKY

Customer Name: SANDRIDGE 2/20/2010Well Name: WEST RANCH 45-14 STG.3 Formation: TESNUS

Additive: ACTIVATOR Planned Additive Rates (PPT) VOLUME

PPG VOLUME LOAD AMOUNT 11 BPM 13 BPM 15 BPM 17 BPM 19 BPM Actual GONE 11 13 15 1

0.00 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11.0 13.0 15.0 17

3.33 3000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.5 11.3 13.0 14

0.00 3000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11.0 13.0 15.0 17

3.33 2400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.5 11.3 13.0 14

6.67 1800 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.4 10.0 11.5 13

8.33 1800 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.0 9.4 10.9 12

10.00 1200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 7.6 8.9 10.3 1113.33 1200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.8 8.1 9.3 1013.33 600 5.00 3.00 1.43 1.70 1.95 2.21 2.48 3.00 6.8 8.1 9.3 10

0.00 9180 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 11.0 13.0 15.0 17

Additive: SUPER NE 100 Planned Additive Rates (GPT) VOLUME

PPG VOLUME LOAD AMOUNT 11 BPM 13 BPM 15 BPM 17 BPM 19 BPM Actual GONE 11 13 15 1

0.00 5250 2.00 10.50 0.92 1.09 1.26 1.43 1.60 10.50 11.0 13.0 15.0 17

3.33 3000 2.00 6.00 0.80 0.95 1.09 1.24 1.39 16.50 9.5 11.3 13.0 14

0.00 3000 2.00 6.00 0.92 1.09 1.26 1.43 1.60 22.50 11.0 13.0 15.0 173.33 2400 2.00 4.80 0.80 0.95 1.09 1.24 1.39 27.30 9.5 11.3 13.0 14

6.67 1800 2.00 3.60 0.71 0.84 0.97 1.09 1.23 30.90 8.4 10.0 11.5 13

8.33 1800 2.00 3.60 0.67 0.79 0.92 1.03 1.16 34.50 8.0 9.4 10.9 12

10.00 1200 2.00 2.40 0.64 0.75 0.87 0.98 1.09 36.90 7.6 8.9 10.3 1113.33 1200 2.00 2.40 0.57 0.68 0.78 0.89 0.99 39.30 6.8 8.1 9.3 1013.33 600 2.00 1.20 0.57 0.68 0.78 0.88 0.99 40.50 6.8 8.1 9.3 10

0.00 9180 2.00 18.36 0.92 1.09 1.26 1.43 1.60 58.86 11.0 13.0 15.0 17

Additive: Planned Additive Rates ()

PPG VOLUME LOAD AMOUNT 11 BPM 13 BPM 15 BPM 17 BPM 19 BPM Actual GONE 11 13 15 1
1 of 1

WELL PERMIT NUMBER

TIME 5:30 TIME

DATE

LOC ITEM 

REFERENCE

QTY DISC ACCT UNIT PRICE

55 11-110-0001 8 79.00% 135.00 $ 1,080.00 $ 

55 30-200-0001 680 79.00% 7.60 $ 5,168.00 $ 

55 30-200-0002 160 79.00% 4.30 $ 688.00 $ 

55 30-200-0006 20 79.00% 270.00 $ 5,400.00 $ 

55 30-200-1000 64800 79.00% 0.18 $ 11,664.00 $ 

55 30-260-0004 1 79.00% 3,550.00 $ 3,550.00 $ 

55 30-260-0006 803 79.00% 5.40 $ 4,336.20 $ 

55 30-260-4150 1 79.00% 7,220.00 $ 7,220.00 $ 

55 30-265-0001 19123 79.00% 0.31 $ 5,928.13 $ 

55 30-270-1000 6 79.00% 8,450.00 $ 50,700.00 $ 

55 30-299-1090 1 79.00% 2,080.00 $ 2,080.00 $ 

55 30-299-2010 1 79.00% 795.00 $ 795.00 $ 

55 30-299-2014 1 79.00% 3,680.00 $ 3,680.00 $ 

55 30-299-2103 1 79.00% 3,760.00 $ 3,760.00 $ 

55 35-285-3000 195 79.00% 116.00 $ 22,620.00 $ 

55 35-440-1000 4 79.00% 223.00 $ 892.00 $ 

55 35-445-0011 58 79.00% 104.30 $ 6,049.40 $ 

55 35-475-1102 9 79.00% 25.10 $ 225.90 $ 

55 35-475-1106 8 79.00% 120.00 $ 960.00 $ 

55 35 485 0200 135 79 00% $ 53 90 $ 7 276 50

2/20/2010

WEST-09-SALES & SERVICE FIELD INVOICE

CHARGE TO LEASE NAME OR PROJECT

STATE COUNTY

Sandridge Energy

ADDRESS

West Ranch 45-14

SUPERIOR WELL SERVICES Invoice Number

INVOICE DATE

INVOICE PAGE

Tx Pecos

ADDRESS FIELD

OWNER SERVICE LEADER

George Castillo

PURCHASE ORDER / REFERENCE JOB TYPE ON LOCATION COMPLETED

DESCRIPTION AMOUNT

Field Laboratory Services - per hour

Mileage DOT Units - Stim - per unit, per mile, one way

Mileage non-DOT Units - Stim - per job

Stimulation

12:00

2/20/2010 SIGNATURE NAME (PLEASE PRINT) I have read, understood and agreed to the terms and conditions printed on the reverse side hereof 

which include, but are not limited to, LIMITED WARRANTY, INDEMNITY, RELEASE and PAYMENT X Johnny Anaya and represent that I have full power and authority to execute this agreement.

2/20/2010

CO2 Service Charge - per ton

OB-2 - per pound

LSG 1 ll

Food & Lodging - Stim - per man, per day

Pump Minimum - first 4 hours, per unit

Proppant Storage and Conveyor System

Densiometer - Stim - each, per job

AccuDat Remote Data Transmission - per job

AccuDat Frac Van III - per job

Bulk Proppant Delivery - per sack, per one way mileage

LGC Pre-Blender - first 4 hour, per unit

Proppant Charge > 10cp Fluid – per cwt

Blender 41-50 BPM - first 4 hours, per unit

HHP Standby after 4 hours – per hour per HHP

BioClear 1000 - per pound

55-000361

Clay Treat PP - per gallon

OB Breaker - per pound

55 35-485-0200 135 79.00% 53.90 $ $ 7,276.50

55 35-511-0100 7 79.00% 170.00 $ 1,190.00 $ 

55 35-511-2010 83 79.00% 175.00 $ 14,525.00 $ 

 35-525-0001 0 79.00% 57.50 $ 

55 35-525-0100 66 79.00% 66.80 $ 4,408.80 $ 

55 35-547-2040 720 79.00% 33.34 $ 24,004.80 $ 

Subtotal

Special Discount

Line Item Discounts

Special Allowance $ -

Subtotal

Fuel Surcharges

NM State Tax 0.00%

LSG-1 - per gallon

$ 188,201.73

Continuation Page $ -

Curable Resin Coated Sand LS - per cwt

Super Foam - per gallon

Super 100 NE - per gallon

TX Specific 20/40 mesh Sand - per 100 lbs

ULT Resin Sand Activator - per gallon

AMOUNT DUE ===> $ 39,522.36

X $ -

$ (148,679.37)

$ -

Receipt: The customer or customer’s agent acknowledges 

that the equipment, materials and services were received as 

listed on this field invoice.

Terms: Net 30 days. Finance charge 1-1/2% 

per month on past due accounts. Applicable 

taxes will be added on invoice.

$ 39,522.36

$ -

$ -

CUSTOMER OR AGENT SIGNATURE / COMMENTS
TRUE 1 1.25 Float Shoe Casing shoe 7

TRUE 2 1 38.82 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 3 0.9 Float CollarFloat collar 7 26 P‐110 6.276

TRUE 4 2 39.71 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 5 3 38.58 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 6 4 40.32 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 7 5 37.79 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 8 6 39.6 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 9 7 39.6 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 10 8 39.31 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 11 9 38.83 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 12 10 38.72 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 13 11 38.86 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 14 12 38 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 15 13 41.61 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 16 14 39.85 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 17 15 39.5 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 18 16 38.25 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 19 17 37.6 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 20 18 39 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 21 19 39.16 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 22 20 40.62 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 23 175 37.58 Marker JoinCasing (red 7 26 P‐110 6.276

TRUE 24 21 38.7 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 25 22 39.39 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 26 23 40 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 27 24 39.67 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 28 25 39.65 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 29 26 39.87 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 30 27 37.7 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 31 28 39.65 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 32 176 37.35 Marker JoinCasing (red 7 26 P‐110 6.276

TRUE 33 29 38.24 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 34 30 38.07 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 35 31 37.65 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 36 32 39.16 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 37 33 39.37 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 38 34 39.04 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 39 35 38.61 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 40 36 40.3 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 41 37 38.53 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 42 38 39.8 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 43 39 39.25 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 44 40 39.6 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 45 41 39.12 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 46 42 40.6 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 47 43 39.4 Casing‐JoinCasing (bla 7 26 P‐110 6.276
TRUE 48 44 39.27 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 49 45 39.96 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 50 46 39.19 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 51 47 38.56 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 52 48 40.28 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 53 49 38.88 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 54 50 40.83 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 55 51 39.7 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 56 52 40.35 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 57 53 40.86 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 58 54 38.78 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 59 55 39.12 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 60 56 39.5 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 61 57 40.8 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 62 58 39.46 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 63 59 38.44 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 64 60 40.9 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 65 61 39.33 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 66 62 38.63 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 67 63 38.18 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 68 64 40.19 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 69 65 39.55 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 70 66 38.93 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 71 67 38.73 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 72 68 38.51 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 73 69 39.69 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 74 70 40.11 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 75 71 38.55 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 76 72 39.82 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 77 73 39.13 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 78 74 39.84 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 79 75 39.37 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 80 76 40.1 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 81 77 38.36 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 82 78 39.76 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 83 79 38.98 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 84 80 39.13 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 85 81 38.95 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 86 82 40 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 87 83 39.24 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 88 84 39.42 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 89 85 39.21 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 90 86 38.82 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 91 87 40.77 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 92 88 39.25 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 93 89 39.81 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 94 90 39.63 Casing‐JoinCasing (bla 7 26 P‐110 6.276
TRUE 95 91 39.71 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 96 92 37.28 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 97 93 40.69 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 98 94 39.2 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 99 95 37.87 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 100 96 38.77 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 101 97 39.58 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 102 98 38.91 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 103 99 37.94 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 104 100 39.14 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 105 101 40 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 106 102 38.52 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 107 103 39.83 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 108 104 40.12 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 109 105 38.35 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 110 106 39.66 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 111 107 39.51 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 112 108 38.92 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 113 109 38.4 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 114 110 38.58 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 115 111 37.9 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 116 112 38.86 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 117 113 38.85 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 118 114 39.25 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 119 115 39.18 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 120 116 39.2 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 121 117 39.38 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 122 118 39.14 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 123 119 40.06 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 124 120 40.36 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 125 121 39.2 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 126 122 39.47 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 127 123 38.35 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 128 124 39.05 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 129 125 38.12 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 130 126 39.43 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 131 127 38.06 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 132 128 38.86 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 133 129 38.51 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 134 130 39.05 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 135 131 38.68 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 136 132 39.38 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 137 133 38.5 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 138 134 39.53 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 139 135 38.4 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 140 136 39.48 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 141 137 39.72 Casing‐JoinCasing (bla 7 26 P‐110 6.276
TRUE 142 138 39.2 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 143 139 39.17 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 144 140 38.05 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 145 141 39.12 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 146 142 39 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 147 143 40.38 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 148 144 38.6 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 149 145 39.2 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 150 146 38.23 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 151 147 40.58 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 152 148 39.55 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 153 149 38.91 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 154 150 37.78 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 155 151 37.97 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 156 152 39.62 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 157 153 37.65 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 158 154 39.62 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 159 155 39.74 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 160 156 39.47 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 161 157 39.62 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 162 158 39.35 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 163 159 41.25 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 164 160 39.53 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 165 161 39.4 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 166 162 39.52 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 167 163 38.05 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 168 164 39.67 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 169 165 38.53 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 170 166 39.1 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 171 167 39.43 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 172 168 39.07 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 173 169 40 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 174 170 39.83 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 175 171 38.94 Casing‐JoinCasing (bla 7 26 P‐110 6.276

TRUE 176 172 40.12 Casing‐JoinCasing (bla 7 26 P‐110 6.276

FALSE 173 38.3 Casing‐JoinCasing (bla 7 26 P‐110 6.276

FALSE 174 38.93 Casing‐JoinCasing (bla 7 26 P‐110 6.276

FALSE 175 Casing‐JoinCasing (bla 7 26 P‐110 6.276
Other LTC FALSE 1.25 6,793.80 6,795.00 0.1 0

Casing LTC TRUE 40.07 6,754.90 6,793.80 0.4 1

Other LTC FALSE 40.97 6,754.00 6,754.90 0.4 1

Casing LTC FALSE 80.68 6,714.30 6,754.00 0.8 2.1

Casing LTC FALSE 119.26 6,675.70 6,714.30 1.2 3.1

Casing LTC TRUE 159.58 6,635.40 6,675.70 1.5 4.1

Casing LTC FALSE 197.37 6,597.60 6,635.40 1.9 5.1

Casing LTC FALSE 236.97 6,558.00 6,597.60 2.3 6.1

Casing LTC FALSE 276.57 6,518.40 6,558.00 2.6 7.2

Casing LTC FALSE 315.88 6,479.10 6,518.40 3 8.2

Casing LTC FALSE 354.71 6,440.30 6,479.10 3.4 9.2

Casing LTC FALSE 393.43 6,401.60 6,440.30 3.7 10.2

Casing LTC FALSE 432.29 6,362.70 6,401.60 4.1 11.2

Casing LTC FALSE 470.29 6,324.70 6,362.70 4.4 12.2

Casing LTC FALSE 511.9 6,283.10 6,324.70 4.8 13.3

Casing LTC FALSE 551.75 6,243.30 6,283.10 5.2 14.3

Casing LTC FALSE 591.25 6,203.80 6,243.30 5.6 15.3

Casing LTC FALSE 629.5 6,165.50 6,203.80 5.9 16.3

Casing LTC FALSE 667.1 6,127.90 6,165.50 6.3 17.3

Casing LTC TRUE 706.1 6,088.90 6,127.90 6.6 18.3

Casing LTC FALSE 745.26 6,049.70 6,088.90 7 19.4

Casing LTC FALSE 785.88 6,009.10 6,049.70 7.4 20.4

Other LTC FALSE 823.46 5,971.50 6,009.10 7.7 21.4

Casing LTC FALSE 862.16 5,932.80 5,971.50 8.1 22.4

Casing LTC FALSE 901.55 5,893.50 5,932.80 8.5 23.4

Casing LTC TRUE 941.55 5,853.50 5,893.50 8.8 24.5

Casing LTC FALSE 981.22 5,813.80 5,853.50 9.2 25.5

Casing LTC FALSE 1,020.87 5,774.10 5,813.80 9.6 26.5

Casing LTC FALSE 1,060.74 5,734.30 5,774.10 10 27.6

Casing LTC TRUE 1,098.44 5,696.60 5,734.30 10.3 28.5

Casing LTC FALSE 1,138.09 5,656.90 5,696.60 10.7 29.6

Other LTC FALSE 1,175.44 5,619.60 5,656.90 11 30.5

Casing LTC FALSE 1,213.68 5,581.30 5,619.60 11.4 31.5

Casing LTC FALSE 1,251.75 5,543.30 5,581.30 11.7 32.5

Casing LTC FALSE 1,289.40 5,505.60 5,543.30 12.1 33.5

Casing LTC FALSE 1,328.56 5,466.40 5,505.60 12.5 34.5

Casing LTC FALSE 1,367.93 5,427.10 5,466.40 12.8 35.5

Casing LTC FALSE 1,406.97 5,388.00 5,427.10 13.2 36.6

Casing LTC FALSE 1,445.58 5,349.40 5,388.00 13.5 37.6

Casing LTC FALSE 1,485.88 5,309.10 5,349.40 13.9 38.6

Casing LTC FALSE 1,524.41 5,270.60 5,309.10 14.3 39.6

Casing LTC FALSE 1,564.21 5,230.80 5,270.60 14.7 40.7

Casing LTC FALSE 1,603.46 5,191.50 5,230.80 15 41.7

Casing LTC FALSE 1,643.06 5,151.90 5,191.50 15.4 42.7

Casing LTC FALSE 1,682.18 5,112.80 5,151.90 15.8 43.7

Casing LTC FALSE 1,722.78 5,072.20 5,112.80 16.1 44.8

Casing LTC FALSE 1,762.18 5,032.80 5,072.20 16.5 45.8
Casing LTC FALSE 1,801.45 4,993.60 5,032.80 16.9 46.8

Casing LTC FALSE 1,841.41 4,953.60 4,993.60 17.2 47.9

Casing LTC FALSE 1,880.60 4,914.40 4,953.60 17.6 48.9

Casing LTC FALSE 1,919.16 4,875.80 4,914.40 18 49.9

Casing LTC FALSE 1,959.44 4,835.60 4,875.80 18.3 50.9

Casing LTC FALSE 1,998.32 4,796.70 4,835.60 18.7 51.9

Casing LTC FALSE 2,039.15 4,755.90 4,796.70 19.1 53

Casing LTC FALSE 2,078.85 4,716.20 4,755.90 19.5 54

Casing LTC FALSE 2,119.20 4,675.80 4,716.20 19.8 55.1

Casing LTC FALSE 2,160.06 4,634.90 4,675.80 20.2 56.1

Casing LTC FALSE 2,198.84 4,596.20 4,634.90 20.6 57.2

Casing LTC FALSE 2,237.96 4,557.00 4,596.20 20.9 58.2

Casing LTC FALSE 2,277.46 4,517.50 4,557.00 21.3 59.2

Casing LTC FALSE 2,318.26 4,476.70 4,517.50 21.7 60.3

Casing LTC FALSE 2,357.72 4,437.30 4,476.70 22.1 61.3

Casing LTC FALSE 2,396.16 4,398.80 4,437.30 22.4 62.3

Casing LTC FALSE 2,437.06 4,357.90 4,398.80 22.8 63.4

Casing LTC FALSE 2,476.39 4,318.60 4,357.90 23.2 64.4

Casing LTC FALSE 2,515.02 4,280.00 4,318.60 23.5 65.4

Casing LTC FALSE 2,553.20 4,241.80 4,280.00 23.9 66.4

Casing LTC FALSE 2,593.39 4,201.60 4,241.80 24.3 67.4

Casing LTC FALSE 2,632.94 4,162.10 4,201.60 24.6 68.4

Casing LTC FALSE 2,671.87 4,123.10 4,162.10 25 69.5

Casing LTC FALSE 2,710.60 4,084.40 4,123.10 25.4 70.5

Casing LTC FALSE 2,749.11 4,045.90 4,084.40 25.7 71.5

Casing LTC FALSE 2,788.80 4,006.20 4,045.90 26.1 72.5

Casing LTC FALSE 2,828.91 3,966.10 4,006.20 26.5 73.5

Casing LTC FALSE 2,867.46 3,927.50 3,966.10 26.8 74.5

Casing LTC FALSE 2,907.28 3,887.70 3,927.50 27.2 75.6

Casing LTC FALSE 2,946.41 3,848.60 3,887.70 27.6 76.6

Casing LTC FALSE 2,986.25 3,808.80 3,848.60 27.9 77.6

Casing LTC FALSE 3,025.62 3,769.40 3,808.80 28.3 78.7

Casing LTC FALSE 3,065.72 3,729.30 3,769.40 28.7 79.7

Casing LTC FALSE 3,104.08 3,690.90 3,729.30 29 80.7

Casing LTC FALSE 3,143.84 3,651.20 3,690.90 29.4 81.7

Casing LTC FALSE 3,182.82 3,612.20 3,651.20 29.8 82.7

Casing LTC FALSE 3,221.95 3,573.10 3,612.20 30.1 83.8

Casing LTC FALSE 3,260.90 3,534.10 3,573.10 30.5 84.8

Casing LTC FALSE 3,300.90 3,494.10 3,534.10 30.9 85.8

Casing LTC FALSE 3,340.14 3,454.90 3,494.10 31.2 86.8

Casing LTC FALSE 3,379.56 3,415.40 3,454.90 31.6 87.9

Casing LTC FALSE 3,418.77 3,376.20 3,415.40 32 88.9

Casing LTC FALSE 3,457.59 3,337.40 3,376.20 32.3 89.9

Casing LTC FALSE 3,498.36 3,296.60 3,337.40 32.7 91

Casing LTC FALSE 3,537.61 3,257.40 3,296.60 33.1 92

Casing LTC FALSE 3,577.42 3,217.60 3,257.40 33.5 93

Casing LTC FALSE 3,617.05 3,178.00 3,217.60 33.8 94
Casing LTC FALSE 3,656.76 3,138.20 3,178.00 34.2 95.1

Casing LTC FALSE 3,694.04 3,101.00 3,138.20 34.5 96

Casing LTC FALSE 3,734.73 3,060.30 3,101.00 34.9 97.1

Casing LTC FALSE 3,773.93 3,021.10 3,060.30 35.3 98.1

Casing LTC FALSE 3,811.80 2,983.20 3,021.10 35.6 99.1

Casing LTC FALSE 3,850.57 2,944.40 2,983.20 36 100.1

Casing LTC FALSE 3,890.15 2,904.90 2,944.40 36.4 101.1

Casing LTC FALSE 3,929.06 2,865.90 2,904.90 36.7 102.2

Casing LTC FALSE 3,967.00 2,828.00 2,865.90 37.1 103.1

Casing LTC FALSE 4,006.14 2,788.90 2,828.00 37.5 104.2

Casing LTC FALSE 4,046.14 2,748.90 2,788.90 37.8 105.2

Casing LTC FALSE 4,084.66 2,710.30 2,748.90 38.2 106.2

Casing LTC FALSE 4,124.49 2,670.50 2,710.30 38.6 107.2

Casing LTC FALSE 4,164.61 2,630.40 2,670.50 38.9 108.3

Casing LTC FALSE 4,202.96 2,592.00 2,630.40 39.3 109.3

Casing LTC FALSE 4,242.62 2,552.40 2,592.00 39.7 110.3

Casing LTC FALSE 4,282.13 2,512.90 2,552.40 40 111.3

Casing LTC FALSE 4,321.05 2,474.00 2,512.90 40.4 112.4

Casing LTC FALSE 4,359.45 2,435.60 2,474.00 40.8 113.4

Casing LTC FALSE 4,398.03 2,397.00 2,435.60 41.1 114.4

Casing LTC FALSE 4,435.93 2,359.10 2,397.00 41.5 115.3

Casing LTC FALSE 4,474.79 2,320.20 2,359.10 41.8 116.4

Casing LTC FALSE 4,513.64 2,281.40 2,320.20 42.2 117.4

Casing LTC FALSE 4,552.89 2,242.10 2,281.40 42.6 118.4

Casing LTC FALSE 4,592.07 2,202.90 2,242.10 42.9 119.4

Casing LTC FALSE 4,631.27 2,163.70 2,202.90 43.3 120.4

Casing LTC FALSE 4,670.65 2,124.40 2,163.70 43.7 121.4

Casing LTC FALSE 4,709.79 2,085.20 2,124.40 44 122.5

Casing LTC FALSE 4,749.85 2,045.20 2,085.20 44.4 123.5

Casing LTC FALSE 4,790.21 2,004.80 2,045.20 44.8 124.6

Casing LTC FALSE 4,829.41 1,965.60 2,004.80 45.1 125.6

Casing LTC FALSE 4,868.88 1,926.10 1,965.60 45.5 126.6

Casing LTC FALSE 4,907.23 1,887.80 1,926.10 45.9 127.6

Casing LTC FALSE 4,946.28 1,848.70 1,887.80 46.2 128.6

Casing LTC FALSE 4,984.40 1,810.60 1,848.70 46.6 129.6

Casing LTC FALSE 5,023.83 1,771.20 1,810.60 47 130.6

Casing LTC FALSE 5,061.89 1,733.10 1,771.20 47.3 131.6

Casing LTC FALSE 5,100.75 1,694.30 1,733.10 47.7 132.6

Casing LTC FALSE 5,139.26 1,655.70 1,694.30 48 133.6

Casing LTC FALSE 5,178.31 1,616.70 1,655.70 48.4 134.6

Casing LTC FALSE 5,216.99 1,578.00 1,616.70 48.8 135.7

Casing LTC FALSE 5,256.37 1,538.60 1,578.00 49.1 136.7

Casing LTC FALSE 5,294.87 1,500.10 1,538.60 49.5 137.7

Casing LTC FALSE 5,334.40 1,460.60 1,500.10 49.9 138.7

Casing LTC FALSE 5,372.80 1,422.20 1,460.60 50.2 139.7

Casing LTC FALSE 5,412.28 1,382.70 1,422.20 50.6 140.7

Casing LTC FALSE 5,452.00 1,343.00 1,382.70 51 141.8
Casing LTC FALSE 5,491.20 1,303.80 1,343.00 51.3 142.8

Casing LTC FALSE 5,530.37 1,264.60 1,303.80 51.7 143.8

Casing LTC FALSE 5,568.42 1,226.60 1,264.60 52 144.8

Casing LTC FALSE 5,607.54 1,187.50 1,226.60 52.4 145.8

Casing LTC FALSE 5,646.54 1,148.50 1,187.50 52.8 146.8

Casing LTC FALSE 5,686.92 1,108.10 1,148.50 53.1 147.9

Casing LTC FALSE 5,725.52 1,069.50 1,108.10 53.5 148.9

Casing LTC FALSE 5,764.72 1,030.30 1,069.50 53.9 149.9

Casing LTC FALSE 5,802.95 992 1,030.30 54.2 150.9

Casing LTC FALSE 5,843.53 951.5 992 54.6 152

Casing LTC FALSE 5,883.08 911.9 951.5 55 153

Casing LTC FALSE 5,921.99 873 911.9 55.3 154

Casing LTC FALSE 5,959.77 835.2 873 55.7 155

Casing LTC FALSE 5,997.74 797.3 835.2 56 156

Casing LTC FALSE 6,037.36 757.6 797.3 56.4 157

Casing LTC FALSE 6,075.01 720 757.6 56.8 158

Casing LTC FALSE 6,114.63 680.4 720 57.1 159

Casing LTC FALSE 6,154.37 640.6 680.4 57.5 160

Casing LTC FALSE 6,193.84 601.2 640.6 57.9 161.1

Casing LTC FALSE 6,233.46 561.5 601.2 58.3 162.1

Casing LTC FALSE 6,272.81 522.2 561.5 58.6 163.1

Casing LTC FALSE 6,314.06 480.9 522.2 59 164.2

Casing LTC FALSE 6,353.59 441.4 480.9 59.4 165.2

Casing LTC FALSE 6,392.99 402 441.4 59.7 166.2

Casing LTC FALSE 6,432.51 362.5 402 60.1 167.3

Casing LTC FALSE 6,470.56 324.4 362.5 60.5 168.3

Casing LTC FALSE 6,510.23 284.8 324.4 60.8 169.3

Casing LTC FALSE 6,548.76 246.2 284.8 61.2 170.3

Casing LTC FALSE 6,587.86 207.1 246.2 61.6 171.3

Casing LTC FALSE 6,627.29 167.7 207.1 61.9 172.3

Casing LTC FALSE 6,666.36 128.6 167.7 62.3 173.4

Casing LTC FALSE 6,706.36 88.6 128.6 62.7 174.4

Casing LTC FALSE 6,746.19 48.8 88.6 63 175.4

Casing LTC FALSE 6,785.13 9.9 48.8 63.4 176.4

Casing LTC FALSE 6,825.25 ‐30.2 9.9 63.8 177.5

Casing LTC FALSE

Casing LTC FALSE

Casing LTC
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144

144

144

144

144

144

144

144

144

144

144

144
1.25

38.82 9,950 6,230 6.151

0.9 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

744.91 9,950 6,230 6.151

37.58 9,950 6,230 6.151

314.63 9,950 6,230 6.151

314.63 9,950 6,230 6.151

314.63 9,950 6,230 6.151

314.63 9,950 6,230 6.151

314.63 9,950 6,230 6.151

314.63 9,950 6,230 6.151

314.63 9,950 6,230 6.151

314.63 9,950 6,230 6.151

37.35 9,950 6,230 6.151

5,600 9,950 6,230 6.151

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5,600 9,950 6,230 6.151

5,600 9,950 6,230 6.151

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5,600 9,950 6,230 6.151

5,600 9,950 6,230 6.151
8

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7.656

1

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1

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1

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

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######## ######## ######## dtatum ######## ######## Rig

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February 1, 2010 POST TREATMENT REPORT

 Sandridge 

 West Ranch 45-14 STG #1 

 Pecos Co. 

 Treatment Date: February 1, 2010 

Attn: 

Sandridge 

Fluid Efficiency Test for the West Ranch 45-14 Stg #1 was conducted at max rate of 48 

bpm at 4,344 psi. Test was conducted with 15,414 gallons of treated water with an ISIP of 2,666 

psi, 5 min 2,208 psi, 10 min 1954 psi, and 15 min 1,711 psi. Surface closure was at 2,472 psi and 

bottom hole closure was at 4,639 psi. Test showed 32 perforations open and a fluid efficiency of 

9% of treated water. 

The stimulation of the West Ranch 4-4W Stg #1 well consisted of 106,638 gallons of 

25# linear gel, and 32,382 gallons of treated water. This fluid was laden with 9,280 lbs of 100 

Mesh, 38,236 lbs of 30/50 Ottawa, and 5,777 lbs of 20/40 Ottawa. It was pumped at an average 

foam rate of 57 bpm, and an average surface pressure of 4,841 psi. The ISIP was 5,251 psi and 

the approximate load to recover is 3,250 bbls. 

Job Notes: Right after the Fluid Efficiency Test pump #3719 was not working properly 

causing us to keep the pump off line. Pump#3697 on the fluid side was fluctuating on rate and 

had 5 ECM trouble codes which are being looked into and WarrenCat will be here to fix the 

problem before continuing. Lost packing on Pumps#3731, #3765, #3772, #3750 causing us to 

lose rate and leading to Johnny Anaya calling for us to go to flush while pumping 1# 20/40 

Ottawa and called flush at 4,584 bbls which lead to formation being over flushed by 50 bbls. 

Please see all attached Meyers files. 

Superior Well Services appreciates the opportunity to perform pumping services for you 

in a cost-effective manner that focuses on quality and safety. 

Please contact the Midland Engineering Department if you have any questions, 

Thank you, 

Crisoforo Esquivel III 

Field Engineer 

Midland, Tx 

(432) 207-0366 

cesquivel@swsi.com
Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATESuperior Rep. Customer Rep. Stage #

JOHNNY ANAYA

Co2 Rate CO2 Total Total Rate Gel Foam Prop Total

BPM BBLS BPM Quality Quality LBS/Stg

Page 1

finish rigging up back side.

12 10PM P i12:00PM

finish rigging up.

11:15AM Sand trucks finish unloading10:30AM Pre job safety meeting

Arrive at ranch

Spotting trucks

7:20AM Begin off loading sand trucks.7:00AM Sand trucks on location 

Waiting on 30/50 Ottawa to

Rigging up equipment 

5:45AM

Arrive on location 

4:25AM Pre rig up safety meeting4:15AM4:35AM 

ANNULUS BPM BBLS BBLS

12:00AM

Time

Pressures (psi) Rate Stage Total

STP

1:00AM3:30AM

Job Description / Remarks

Proppant Conc / Type

Arrive at yard

Left yard

Stimulation Treatment Report

55000354 02/01/10

WEST RANCH 45-14 PecosSANDRIDGE ENERGY

TX

Benjamin Munoz 1

46 2%KCL

19 27 63 25# 30Q

18 8 60 25# 30Q 3,863

17 14 60 25# 30Q

18 17 59 25# 30Q 8,254

19 19 57 25# 30Q

17 14 55 25# 30Q 8,906

18 16 57 25# 30Q

17,2 10 57 25# 30Q 8,375

17 16 57 25# 30Q

17 11 57 25# 30Q 10,995

18 19 57 25# 30Q

17 12 57 25# 30Q 11,010

17 18 57 25# 30Q

18 18 54 25# 30Q 5,773

Treating Presure Injection Rates Shut In Pressures 

Minimum Minimum ISDP 

A lot off mcm codes on the 

unit.

3697 throttle up and down has 

Lost the packing on pumps 3731, 

fluid side and also pumps 3765,

3772,3750 on CO2 side.

3719 does not go into gear.

2:32PM 5119 36.9 404 3,310 1# 20/40 /Flush2:26PM 4932 39.5 250 2,906 Sweep

Sweep

2:22PM 5083 39.1 149

2:12PM 5164 39.3 145 2,263 1.5# 30/50 Ottawa2:07PM 4992 39.6 202 2,118 Sweep

2,656 1.5# 30/50 Ottawa

2:16PM 4839 39.6 244 2,507

Sweep

2:02PM 5127 39.4 125 1,916 1.25# 30/50 Ottawa1:59PM 4917 38.3 203 1,7911:43PM 5019 42 194 1,197 .75# 100 Mesh

Sweep 

1:55PM 5108 38.1 164 1,588 1# 30/50 Ottawa1:49PM 4760 37.5 227 1,424

Pad

1:36PM 4872 42 118 814 .5# 100 Mesh

1:22PM 4922 42 329 696 

1:39PM 4689 42.1 189 1,003 Sweep

12:45PM 4436 46 367 FET12:10PM Prime up pumps

Testing Lines

Good line Test

12:25PM 

Final 

Operators 

Max Pressure 6200

15 Min. 1711 

Average 4841 Average 57 10 Min. 1954

Maximum 5251 Maximum 61 5 Min. 2208 
WEST RANCH 45-14 STG#1 STEP 

6

8 10 12 14 16 18 

TIME (min)

0

10002000300040005000600070008000

Pressure (psi)

Real-Time Pressure (psi) Real-Tim

Real-TimReal-Tim

MView - WEST RANCH 45-14 - 2/1/2010
Step Down Diagnostic - Surf

0 10 20 30 

Rate (bpm)

0

200400600800

10001200

Pressure Loss (psi)

DP NW Data PointsDP NW: Alpha = 0.5DP Total NW Data PointsDP Total NWDP Perf Ideal

Number of perfs = 32Discharge Coeff. = 0.6Perf diameter = 0.4 (in.)

MinFrac - 2/1/2010
WEST RANCH 45-14 STG#1 Regressio

0 0.3 0.6 0.9 1.2 1.5 1.

Nolte G Time

1600180020002200240026002800

Surface Pressure (psi)

Surface PressureISIP - G dP/dG ISIP

TC

1A

1B2B

Pump Time (tpClosure Time Delta Closure Surface ISIP (Surface ClosurBH ISIP (ISIPBH Closure (PNet Pressure (Stress GradienEfficiency* 

Slope 1 -908.31Slope 2 -428.19Slope 3Slope 4

MinFrac - 2/1/2010
WEST RANCH 45-14 STG#1 BH

0 10 20 30 40 50 60 70 80 

Time (min)

0

100020003000400050006000700080009000

100001100012000

Pressure (psi)

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

Measured BH Conc. Measured 

MWell - WEST RANCH 45-14 STG1 - 2/1/2010
NET PRESSURE

1 10 

Time (min)

100020003000400050006000700080009000

Measured Minus MFrac BHP (psi)

BHTP Dif. (Measured - MFrac) (psi) BH Conc. 

MWell - WEST RANCH 45-14 STG1 - 2/1/2010
WEST RANCH 45-14 STG#1 IS

92.8 93.0 93.2 93.4 93.6 93.8 94.0 94.2 

TIME (min)

360038004000420044004600480050005200

Pressure (psi)

Real-Time Pressure (psi) Real-Time 

Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/1/2010
WEST RANCH 45-14 STG#1 MAIN 

0 20 40 60 80 

TIME (min)

0

100020003000400050006000700080009000

10000

Pressure (psi)

Real-Time Pressure (psi) Real-Time 

Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/1/2010
RATES

0 20 40 60 80 

TIME (min)

0

20406080

100

Real-Time FOAM RATE (bpm)Real-Time RATE (bpm)Real-Time CO2 RATE (bpm)Real-Time HYD SUC RATE (bpm)

Real-Time 

MView - WEST RANCH 45-14 - 2/1/2010
CHEMICAL PLOT

0 20 40 60 80 

TIME (min)

02468

10

Real-Time LSG GPT (gpt)Real-Time ACTIVATOR GPT (gpt)

Real-Time Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/1/2010
DENSITY

0 20 40 60 

TIME (min)

0.01.02.03.04.05.06.07.08.09.0

10.0

Real-Time DENSITY (lb/gal)Real-Time INLINE (lb/gal)

Real-Time 

MView - WEST RANCH 45-14 - 2/1/2010
Total Variance: 2.11% 

DATE: FLUID TECHFIELD RECEIPT NO:

2 3 4 5 6 7 8 9 10 

PLANNED FLOW 

PROPOSED START HOSES END TOTAL LOSSES PUMPED VOLUME METER 

VOLUME LOADED USED DOWNHOLE FOR FLUID MEASURED 

PUMPED VOLUME 

1605 2566 2566 1857 709 0 709 721 

490 1577 1575 1365 212 2 210 220 

69 301 301 301 0 0 0 0 

298 298 298 0 0 0 0 

619 2274 2271 2051 223 3 220 230 

26 298 298 298 0 0 0 0 73 300 300 280 20 0 20 20 73 250 250 230 20 0 20 20 

LEASE NAME & WELL NO:

PRODUCT VARIANCE CALCULATIONS

CHEMICALS

2/1/2010 SANDRIDGE ENERGY CUSTOMER:

WEST RANCH 45-14

LSG-1PELXFOAMCLAYTREAT PPACETPLEX 40

CHEM-ADD OPERATOR:

1

MEASURED VOLUMES

PRODUCT

SUPERNE-100ACTIVATOROB2OB1

13 14 

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

CLEAN VOLUME Comments:

15 16 17 18

FLOW MET

1

DOWNHOLE VOLUME

PUMPED 

DOWNHOLE

3,2

SPILLAGE DENSIO

22 25

28

3,399

25# LINEAR GEL

2

9,849

ENDING VOLUME

21

TOTAL SLURRY

3,399

30

BASE FLUID DESCRIPTION

PROPPANT (lbs)

CLEAN VOLUME (bbls)

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

3,399.0

FLOW METER SLURRY 

6,390

29 40

9,789

PROPPANT VOLUME

SLURRY VOLUME (bbls)

23 24

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

Clarity, color, odor CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR CLEAR Sample Temperature, (F) 63 64 66 68 80 63 74 63 64 67 63 Specific gravity 1.250 1.025 1.030 1.002 1.002 1.002 1.002 1.002 1.002 1.002 1.002 Initial pH 7.4 7.6 7.6 8.1 8.1 8.2 8.1 8.2 8.3 8.3 8.100 Iron (Fe++/Fe+++) ppm 0 0000000003Reducing Agent (Yes or No)Sulfate, ppm 400 400 400 400 400 400 400 400 400 400 400 Chloride, ppm 22641 19602 19602 6153 3921 1666 1666 1666 1666 1666 3193 Calcium, ppmMagnesium, ppmBF-7L Precipitate > > > > > 1 2 3 4 5 6 7 8 8Bacteria  Aerobic: No. per ml/time / / / / / / / / / / /  Anaerobic: No. per ml/time / / / / / / / / / / / 

Base Gel Quality Use additional copies of this form for each series 

Name of product system mixed 25Gellant loading (lbs/1000 gal.) 6.25GPTFluid sampling location PILOTSampling time 4:AMSample Temperature, (F) 65pH 8.2

3 min. 19

Fann reading 9 min. 22

@ 300 rpm 30 min.

60 min.

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

Tested by:

WATER BASED FRAC FLUID QUALITY CONTROL

(Attachment to Treatment Report)

2/1/2010 FIELD RECEIPT NO:SANDRIDGE ENERGY LEASE NAME & WELL NO: WEST RANCH 45-14

Biocide added before H2O?

Field Pilot Test Batch Mixed Gel Quality Test

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

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 or for frac quality assurance. Data recorded electronically with Engineering substituted for applicable portions of this form. This testing data is considered to be the minimum needed for the well file.

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

Date water sampled: Source of water:
DATE:CUSTOMER:Tank/Transport No. 16 17 18 19 20Water Quality Date filled: City Well 

Clarity, color, odor CLEAR CLEAR CLEAR CLEAR CLEARSample Temperature, (F) 63 62 63 63 64Specific gravity 1.002 1.002 1.002 1.002 1.002Initial pH 8.1 8.2 8.5 8.2 8.2Iron (Fe++/Fe+++) ppm 0 0 0 0Reducing Agent (Yes or No)Sulfate, ppm 400 400 400 400 400Chloride, ppm 2075 1596 1598 1796 1796Calcium, ppmMagnesium, ppmBF-7L Precipitate > > > > > 1 2 3 4 5 6 7 8 8Bacteria  Aerobic: No. per ml/time / / / / / / / / / / /  Anaerobic: No. per ml/time / / / / / / / / / / / 

Base Gel Quality Use additional copies of this form for each series 

Name of product system mixed 25Gellant loading (lbs/1000 gal.) 6.25Fluid sampling location PILOTSampling time 4:AMSample Temperature, (F) 65pH 8.2

3 min. 19

Fann reading 9 min. 22

@ 300 rpm 30 min.

60 min.

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

Tested by:

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

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

Field Pilot Test Batch Mixed Gel Quality Test

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

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

Date water sampled: Source of water:

WATER BASED FRAC FLUID QUALITY CONTROL

(Attachment to Treatment Report)

2/1/2010 FIELD RECEIPT NO:SANDRIDGE ENERGY LEASE NAME & WELL NO: WEST RANCH 45-14
Page: 

DATE: FIELD RECEIPT NO:CUSTOMER: LEASE NAME & WELL NO:SYSTEM:

 gpt ppt gpt ppt gpt ppt 

 gpt ppt gpt ppt gpt ppt 

gpt ppt gpt ppt gpt ppt 

Time Bob Size Time Bob Size Reading Time Bob Size Reading Time Bo

INIT B-2 22 INIT B-2 22 INIT B-2 INIT 

5 B-2 20 5 B-2 20 5 B-2 5 

10 B-2 18 150 B-2 16 10 B-2 10 20 B-2 15 15 B-2 12 20 B-2 20 30 B-2 12 20 B-2 7 30 B-2 30 45 B-2 9 45 B-2 2 45 B-2 45 60 B-2 5 60 B-2 60 B-2 60 

75 B-2 2 90 B-2 70 B-2 90 

80 B-2

Remarks:

10

Pre-XL pH:

Sample Temp. Other Loading:

6.25 GPT22OB-2 .5OB-1 .5

Broken pH:

Closure Time:Crown Time: Crown Time:

Closure Time:

Broken pH:

Crown Time:

68 Sample Temp. (F): 688.1OB-1 .25 PPT

Crosslinker:

BREAKER TEST REPORT

(Attachment to Treatment Report)

LOADING 

ADDITIV

FORMATION:

2/1/2010

Closure Time:Crown Time:Broken pH:

Temp.

XL pH:

Buffer Loading:Crosslinker:

Temp.

8.1

Closure Time:

Base Visc. (cp):Gellant Loading:

Base Visc. (cp):

Test No: 

Gellant Loading:

WEST RANCH 45-14

LOADING ADDITIVE

SANDRIDGE ENERGY

LOADING ADDITIVE

Breaker Loadin

T

ADDITIVE

Gellant Loading:

Test No: 1

6.25 GPT

SUPER NE 100Breaker Loading:Base Visc. (cp):Sample Temp. (F):

Breaker Loading:

Buffer Loading:Crosslinker:

OB-2 .25 PPT22

Breaker Loading:

Gellant LoadingBuffer LoadingBase Visc. (cp)Breaker LoadinCrosslinker:

Sample Temp. (F):Buffer Loading:

160160

150150

Breaker Loading:Other Loading:

Broken pH:

Pre-XL pH:XL pH:

Breaker Loading:Other Loading:Pre-XL pH:XL pH:

150

160160

Pre-XL pH:XL pH:

Temp.

Breaker Loading:Other Loading:

Tested BY: R. RUBIO

160160

140140140140

150150

140140140140

150

160160

150
Page of

Propant placed in the district proppant silos shall be tested at a minimum interval of every 250,000 pounds.

X

X

Size lb Size lb

No

96.8% 95.2%

Recognized proppant or gravel sizes: 6/12, 8/16, 12/20, 16/20, 16/30, 20/40, 30/50, 40/70, or 50/70 (40/60 for gravel)

*Recombine all proppant samples to represent 100,000 lbs or fraction. Gravel samples should represent 2,000 lbs or fraction.

35 20.78

0.00

41.56

40 6.34 12.68

16 0

30 20.5

Total 

20 0.78 1.56 In-Size 

41.00 }

In-Size 

Total 

%

0.00

Gram

0.00

0.00

%

50

Combine all samples

grams of sample

Amount Retained

0.68

Gram

6.4

23.2

18.8

0.34

0

20

30

35

40

Sieve Analysis

20/40 OTTOWA

Sieve mesh

Turbidity

Pan

pH

Pan

Total wt. Gram

Turbidity

fail pH

Tested By: R. RUBIO

4.20

101.68

fail

pass pass fail

50.8

pass fail

fines fines

pass

Total wt. Gram

0 0.00

50.0 99.92

Spot check manufacturer's sieve analysis at a minimum of every 250,000 lbs.

Sieve mesh

}

0.00

12.80

46.40

37.60

16

Sieve Analysis

If not appropriate, correct problem before sieve analysis. If the manufacturer's sieve analysis does not meet specifications, perform sieve analysis. 

Is the truck content acceptable? Yes/No Yes

Sample taken? Yes/No

Yes/No

sieve analysis meet fines<1%

Yes

specifications? Attach all. Yes

Yes/No Yes

Yes/No Yes

insize>90%

no contamination Yes/No Yes

Does the manufacturer's oversize <.1%

appearance right Yes/No Yes

of the truck proper? low dust Yes/No Yes

No.

Resin coated sand

Note: Use additional copies of this form for additional trucks,sizes,or vendors

Truck number No. No. No. No.

Ottawa

Gravel

If gravel, select type

Ottawa

Resieved

Proppant 100 mesh sand

Brady

QUALITY CONTROL OF PROPPANT/GRAVEL/100 MESH SAND

(Attachment to Treatment Report)

CUSTOMER: SANDRIDGE ENERGY

FIELD RECEIPT NO:

Weight slip available? Attach all. Yes/N

LEASE NAME & WELL NO:

Other (specify)

Ceramic proppant Curable

Sintered bauxite

Other (specify)

If proppant, select type

VENDOR:

Trucking company

Net weight delivered 

Weight Weight

Is the content Yes color right Yes/No

Yes

20/40 TLC 

50 grams of sample

2.1 1.56 3.12

Amount Retained

50

50

Combine all samples

Nominal size from list below

Is total weight for each size appropriate for job requirements?

Total weight , each size

WEST RANCH 45-14 DISTRICT PROPPANT SILO:

UNIT/COMPARTMENT:
Page of

Propant placed in the district proppant silos shall be tested at a minimum interval of every 250,000 pounds.

X

Size lb Size lb

No

95.3% 0.0%

Recognized proppant or gravel sizes: 6/12, 8/16, 12/20, 16/20, 16/30, 20/40, 30/50, 40/70, or 50/70 (40/60 for gravel)

*Recombine all proppant samples to represent 100,000 lbs or fraction. Gravel samples should represent 2,000 lbs or fraction.

DISTRICT PROPPANT SILO:

UNIT/COMPARTMENT:

Weight

fines

20

Sieve Analysis

Amount Retained

36.74

49.72

Combine all samples

Weight

Nominal size from list below

Total weight , each size

Trucking company

No.

Ceramic proppant

Sintered bauxite

Other (specify)

VENDOR:

LEASE NAME & WELL NO:

Other (specify)

Brady Curable

If proppant, select type

QUALITY CONTROL OF PROPPANT/GRAVEL/100 MESH SAND

(Attachment to Treatment Report)

CUSTOMER: SANDRIDGE ENERGY

FIELD RECEIPT NO:

No.

Ottawa

Gravel

If gravel, select type

Ottawa

Resieved

Proppant 100 mesh sand

Weight slip available? Attach all. Yes/N

Resin coated sand

Note: Use additional copies of this form for additional trucks,sizes,or vendors

Truck number No. No. No.

Is total weight for each size appropriate for job requirements?

Is the content color right Yes/No

Net weight delivered 

Yes

Yes

of the truck proper? low dust Yes/No Yes

appearance right Yes/No Yes

no contamination Yes/No Yes

sieve analysis meet fines<1% Yes/No Yes

specifications? Attach all. insize>90% Yes/No Yes

Does the manufacturer's oversize <.1% Yes/No Yes

Spot check manufacturer's sieve analysis at a minimum of every 250,000 lbs.

If not appropriate, correct problem before sieve analysis. If the manufacturer's sieve analysis does not meet specifications, perform sieve analysis. 

Is the truck content acceptable? Yes/No

Sample taken? Yes/No

Yes

Yes

0.00

Combine all samples

50 grams of sample

Total 

fail

0 fines

1.12 2.24

100.06

0.00

50.0

pass

Total wt. Gram

Turbidity

0.0 0.00

Tested By: R. RUBIO

pH pass fail pH pass

Pan

Total wt. Gram

Turbidity

Pan

2.42

4.43

18.37

24.86

1.21

pass

grams of sample

Amount Retained

50

%

Sieve Analysis

70

30

40

45

50 8.86 }

0.04 0.08 Total 

30/50 OTTOWA

Sieve mesh Gram

0.00

In-Size 

0.00

0.00

Gram %

0.00 In-Size 

0.00

0.00

fail

fail

0.00 } 0.00
Pump Schedule

Customer Name: SandRidge EnergyWell Name: WEST RANCH 45-14Formation: 1ST CABALLOSFluid Type: 25# LINEAR

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

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

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

FET 10000 0.00 0.00 0.00 0.00 0 0 40.0 40.0 0.0 0 238.1 238.1 23

PAD 20000 0.00 0.00 0.00 0.00 0 0 42.0 42.0 18.0 0 333.3 333.3 57

.5# 100 MESH 7500 0.50 0.50 0.71 0.71 3750 3750 42.4 41.1 17.0 0 125.0 129.0 70

SWEEP 12000 0.00 0.00 0.00 0.00 0 3750 42.0 42.0 18.0 0 200.0 200.0 90

.75# 100 MESH 7500 0.75 0.75 1.07 1.07 5625 9375 42.6 40.6 17.0 0 125.0 131.1 10

SWEEP 12000 0.00 0.00 0.00 0.00 0 9375 42.0 42.0 18.0 0 200.0 200.0 12

1# 30/50 7500 1.00 1.00 1.43 1.43 7500 16875 42.8 40.2 17.0 0 125.0 133.1 13

SWEEP 12000 0.00 0.00 0.00 0.00 0 16875 42.0 42.0 18.0 0 200.0 200.0 15

1.25# 30/50 7500 1.25 1.25 1.79 1.79 9375 26250 43.0 39.7 17.0 0 125.0 135.1 16

SWEEP 12000 0.00 0.00 0.00 0.00 0 26250 42.0 42.0 18.0 0 200.0 200.0 18

1.5# 30/50 7500 1.50 1.50 2.14 2.14 11250 37500 43.1 39.3 16.0 0 125.0 137.1 20

SWEEP 12000 0.00 0.00 0.00 0.00 0 37500 42.0 42.0 18.0 0 200.0 200.0 22

1.5# 30/50 7500 1.50 1.50 2.14 2.14 11250 48750 43.1 39.3 16.0 0 125.0 137.1 23

SWEEP 12000 0.00 0.00 0.00 0.00 0 48750 42.0 42.0 18.0 0 200.0 200.0 25

1# 20/40 10000 1.00 1.00 1.43 1.43 10000 58750 42.8 40.2 17.0 0 166.7 177.5 27

2# 20/40 8000 2.00 2.00 2.86 2.86 16000 74750 43.5 38.5 16.0 0 133.3 150.6 29

3# 20/40 6000 3.00 3.00 4.29 4.29 18000 92750 44.2 37.0 15.0 0 100.0 119.4 30

4# 20/40 6000 4.00 4.00 5.71 5.71 24000 116750 44.8 35.6 15.0 0 100.0 125.9 31

4# SLC 3000 4.00 4.00 5.71 5.71 12000 128750 44.8 35.6 15.0 0 50.0 62.9 32

FLUSH 10350 0.00 0.00 0.00 0.00 0 128750 60.0 60.0 0.0 0 246.4 246.4 34

0 

Design Totals --> 190350 128750 0 3317.9 3456.7 

Actual Totals -->

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

Top Perf 6470 90 Tubing Casing

Bottom Perf 6596 Casing 247.54 Ble

0 Annulus

Flu

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

Casing 7 0.03826 6.276 Flush (bbls) Hydra

Tubing Top 247.5

Annulus Bottom 252.4

26
Superior Well Services

Additive Schedule

Customer Name: SandRidge Energy 2/1/2010

Well Name: WEST RANCH 45-14 Formation: 1ST CABALLOS

Additive: LSG-1 Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 6.25 87.50 14.70 15.23 15.75 16.28 16.80 87.50

0.71 5250 6.25 32.81 14.23 14.75 15.25 15.78 16.28 120.31

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 172.81

1.07 5250 6.25 32.81 14.02 14.52 15.02 15.51 16.01 205.63

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 258.13

1.43 5250 6.25 32.81 13.81 14.31 14.81 15.28 15.78 290.94

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 343.44

1.79 5250 6.25 32.81 13.60 14.10 14.57 15.07 15.54 376.25

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 428.75

2.14 5250 6.25 32.81 13.39 13.89 14.36 14.83 15.30 461.56

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 514.06

2.14 5250 6.25 32.81 13.39 13.89 14.36 14.83 15.30 546.88

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 599.38

1.43 7000 6.25 43.75 13.81 14.31 14.81 15.28 15.78 643.13

2.86 5600 6.25 35.00 13.02 13.49 13.94 14.41 14.88 678.13

4.29 4200 6.25 26.25 12.31 12.76 13.18 13.62 14.07 704.38

5.71 4200 6.25 26.25 11.68 12.10 12.52 12.94 13.34 730.63

5.71 2100 6.25 13.13 11.68 12.10 12.52 12.94 13.34 743.75

0.00 10350 0.00 0.00 0.00 0.00 0.00 0.00 0.00 743.75

743.75

Additive: SUPER 1OO N3 Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 2.00 20.00 4.70 4.87 5.04 5.21 5.38 20.00

0.00 14000 2.00 28.00 4.70 4.87 5.04 5.21 5.38 48.00

0.71 5250 2.00 10.50 4.55 4.72 4.88 5.05 5.21 58.50

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 75.30

1.07 5250 2.00 10.50 4.49 4.65 4.80 4.96 5.12 85.80

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 102.60

1.43 5250 2.00 10.50 4.42 4.58 4.74 4.89 5.05 113.10

0.00 8400 2.00 16.80 0.00 0.00 5.04 5.21 5.38 129.90

1.79 5250 2.00 10.50 4.35 4.51 4.66 4.82 4.97 140.40

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 157.20

2.14 5250 2.00 10.50 4.28 4.44 4.59 4.75 4.90 167.70

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 184.50

2.14 5250 2.00 10.50 4.28 4.44 4.59 4.75 4.90 195.00

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 211.80

1.43 7000 2.00 14.00 4.42 4.58 4.74 4.89 5.05 225.80

2.86 5600 2.00 11.20 4.17 4.32 4.46 4.61 4.76 237.00

4.29 4200 2.00 8.40 3.94 4.08 4.22 4.36 4.50 245.40

5.71 4200 2.00 8.40 3.74 3.87 4.01 4.14 4.27 253.80

5.71 2100 2.00 4.20 3.74 3.87 4.01 4.14 4.27 258.00

0.00 10350 2.00 20.70 4.70 4.87 5.04 5.21 5.38 278.70

278.70

Additive: OB1 Planned Additive Rates (PPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.25 2.50 0.59 0.61 0.63 0.65 0.67 2.50

0.00 14000 0.25 3.50 0.59 0.61 0.63 0.65 0.67 6.00

0.71 5250 0.25 1.31 0.57 0.59 0.61 0.63 0.65 7.31

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 9.41

1.07 5250 0.25 1.31 0.56 0.58 0.60 0.62 0.64 10.73

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 12.83

1.43 5250 0.25 1.31 0.55 0.57 0.59 0.61 0.63 14.14

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 16.24

1.79 5250 0.25 1.31 0.54 0.56 0.58 0.60 0.62 17.55

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 19.65

2.14 5250 0.25 1.31 0.54 0.56 0.57 0.59 0.61 20.96

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 23.06

2.14 5250 0.25 1.31 0.54 0.56 0.57 0.59 0.61 24.38

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 26.48

1.43 7000 0.25 1.75 0.55 0.57 0.59 0.61 0.63 28.23

2.86 5600 0.25 1.40 0.52 0.54 0.56 0.58 0.60 29.63

4.29 4200 0.25 1.05 0.49 0.51 0.53 0.54 0.56 30.68

5.71 4200 0.50 2.10 0.93 0.97 1.00 1.04 1.07 32.78

5.71 2100 0.50 1.05 0.93 0.97 1.00 1.04 1.07 33.83

0.00 10350 0.00 0.00 0.00 0.00 0.00 0.00 0.00 33.83

33.83

Fluid Technician: SOTO

Field Receipt #: STG #1 Prepared By: C ESQUIVEL
Superior Well Services

Additive Schedule

Customer Name: SandRidge Energy 2/1/2010

Well Name: WEST RANCH 45-14 Formation: 1ST CABALLOS

Additive: OB2 Planned Additive Rates (PPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.25 2.50 0.59 0.61 0.63 0.65 0.67 2.50

0.00 14000 0.25 3.50 0.59 0.61 0.63 0.65 0.67 6.00

0.71 5250 0.25 1.31 0.57 0.59 0.61 0.63 0.65 7.31

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 9.41

1.07 5250 0.25 1.31 0.56 0.58 0.60 0.62 0.64 10.73

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 12.83

1.43 5250 0.25 1.31 0.55 0.57 0.59 0.61 0.63 14.14

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 16.24

1.79 5250 0.25 1.31 0.54 0.56 0.58 0.60 0.62 17.55

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 19.65

2.14 5250 0.25 1.31 0.54 0.56 0.57 0.59 0.61 20.96

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 23.06

2.14 5250 0.25 1.31 0.54 0.56 0.57 0.59 0.61 24.38

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 26.48

1.43 7000 0.25 1.75 0.55 0.57 0.59 0.61 0.63 28.23

2.86 5600 0.25 1.40 0.52 0.54 0.56 0.58 0.60 29.63

4.29 4200 0.25 1.05 0.49 0.51 0.53 0.54 0.56 30.68

5.71 4200 0.50 2.10 0.93 0.97 1.00 1.04 1.07 32.78

5.71 2100 0.50 1.05 0.93 0.97 1.00 1.04 1.07 33.83

0.00 10350 0.00 0.00 0.00 0.00 0.00 0.00 0.00 33.83

Additive: SUPERFOAM Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 2.00 28.00 4.70 4.87 5.04 5.21 5.38 28.00

0.71 5250 2.00 10.50 4.55 4.72 4.88 5.05 5.21 38.50

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 55.30

1.07 5250 2.00 10.50 4.49 4.65 4.80 4.96 5.12 65.80

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 82.60

1.43 5250 2.00 10.50 4.42 4.58 4.74 4.89 5.05 93.10

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 109.90

1.79 5250 2.00 10.50 4.35 4.51 4.66 4.82 4.97 120.40

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 137.20

2.14 5250 2.00 10.50 4.28 4.44 4.59 4.75 4.90 147.70

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 164.50

2.14 5250 2.00 10.50 4.28 4.44 4.59 4.75 4.90 175.00

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 191.80

1.43 7000 2.00 14.00 4.42 4.58 4.74 4.89 5.05 205.80

2.86 5600 2.00 11.20 4.17 4.32 4.46 4.61 4.76 217.00

4.29 4200 2.00 8.40 3.94 4.08 4.22 4.36 4.50 225.40

5.71 4200 2.00 8.40 3.74 3.87 4.01 4.14 4.27 233.80

5.71 2100 2.00 4.20 3.74 3.87 4.01 4.14 4.27 238.00

0.00 10350 0.00 0.00 0.00 0.00 0.00 0.00 0.00 238.00

238.00

Additive: CLAYTREAT Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.71 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.07 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.43 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.79 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.14 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.14 5250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.43 7000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.86 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

4.29 4200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 4200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 2100 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 10350 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Fluid Technician: SOTO

Field Receipt #: STG #1 Prepared By: C ESQUIVEL
February 2, 2010 POST TREATMENT REPORT

 Sandridge Energy 

 West Ranch 45-14 STG #1A 

 Pecos Co. 

 Treatment Date: February 2, 2010 

Attn: Johnny Anaya 

Sandridge Energy 

The stimulation of the West Ranch 4-4W Stg #1A well consisted of 85,680 gallons of 

25# linear gel, and 10,416 gallons of treated water. This fluid was laden with 80,632 lbs of 20/40 

Ottawa and 14,000 lbs of 20/40 SLC. It was pumped at an average foam rate of 60.2 bpm, and an 

average surface pressure of 5612 psi. The ISIP was 5,502 psi and the approximate load to recover 

is 1,933 bbls. 145 tons of CO2 were used to during the job and 5 tons used to cool down. 

Please see all attached Meyers files. 

Superior Well Services appreciates the opportunity to perform pumping services for you 

in a cost-effective manner that focuses on quality and safety. 

Please contact the Midland Engineering Department if you have any questions, 

Thank you, 

Crisoforo Esquivel III 

Field Engineer 

Midland, Tx 

(432) 207-0366 

cesquivel@swsi.com
Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATESuperior Rep. Customer Rep. Stage #

JOHNNY ANAYA

Co2 Rate CO2 Total Total Rate Gel Foam Prop Total

BPM BBLS BPM Quality Quality LBS/Stg

18 36 60 25# 30Q18 17 60 25# 30Q 4,070

18 19 60 25# 30Q 7,50218 15 60 25# 30Q 8,489

9 05AM 5603 43 2 211 1 239 17 15 60 25# 30Q 12 056 1# 20/40 Ott 

.5# 20/40 Ottawa 

9:00AM 5529 41.9 200 1,028 1.1 20/40 Ottawa 

8:54AM 5398 42.1 241 8288:49AM 5468 42 227 587 .25# 20/40 Ottawa

8:22AM 5560 42 360 Pad 7:35AM Tested lines to 8500 psi 7:20AM Prime trucks up 

Spotting and rigging up trucks. 

7:00AM Rig up complete5:30AM

Arrive at location 

5:15AM Pre rig up safety meeting 5:00AM

Call out time at motel

4:15AM Arrive at ranch

BPM BBLS BBLS

3:00AM

Benjamin Munoz 1a

Time

Pressures (psi) Rate Stage Total Job Description / Remarks

Proppant Conc / Type STP ANNULUS

Page 1 Stimulation Treatment Report

SANDRIDGE ENERGY 55000354 03/11/10

WEST RANCH 45-14 Pecos TX

17 15 60 25# 30Q 12,05616 14 60 25# 30Q 22,150

15 7 61 25# 30Q 18,91514 3 60 25# 30Q 7,450

15 7 61 25# 30Q 14,000

2%KCL

Total 133

Treating Presure Injection Rates Shut In Pressures 

Minimum Minimum ISDP 5502 

Testing plug to 4800 psi 

12:30PM

9:30AM Turn over to wireline

4# SLC 

9:21AM 5632 50 248 2,040 Flush

9:19AM 5932 45.9 135 1,7929:18AM 5991 46 45 1,643 4# 20/40 Ottawa 

9;15AM 5701 45.9 130 1,598 3# 20/40 Ottawa 

1# 20/40 Ottawa 

9:10AM 5709 44.3 229 1,468 2# 20/40 Ottawa9:05AM 5603 43.2 211 1,239

Operators 

Max Pressure 6200

Average 5612 Average 60 10 Min.

Final 

15 Min. 

Maximum 6592 Maximum 62 5 Min. 
WEST RANCH 45-14 STG#1 BH

0 10 20 30 40 50 60 

Time (min)

0

100020003000400050006000700080009000

Pressure (psi)

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

Measured SBH Conc. Measured S

MWell - WEST RANCH 45-14 STG1A - 2/2/2010
NET PRESSURE

1 10 100 

Time (min)

-2000

0

2000400060008000

1000012000

Measured Minus MFrac BHP (psi)

BHTP Dif. (Measured - MFrac) (psi) BH Conc

MWell - WEST RANCH 45-14 STG1A - 2/2/2010
WEST RANCH 45-14 STG#1A I

68.4 68.8 69.2 69.6 70.0 70.4 

TIME (min)

5100520053005400550056005700580059006000

Pressure (psi)

Real-Time Pressure (psi) Real-Time 

Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
WEST RANCH 45-14 STG#1A MAI

0 20 40 60

TIME (min)

0

500

1000150020002500300035004000450050005500600065007000

Pressure (psi)

Real-Time Pressure (psi) Real-Time 

Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
RATES

0 20 40 60

TIME (min)

0

10203040506070

Real-Time FOAM RATE (bpm)Real-Time RATE (bpm)Real-Time CO2 RATE (bpm)Real-Time HYD SUC RATE (bpm)

Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
CHEMICAL PLOT

0 20 40 60

TIME (min)

02468

10

Real-Time LSG GPT (gpt)Real-Time ACTIVATOR GPT (gpt)

Real-Time Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
DENSITY

0 20 40 60

TIME (min)

0.01.02.03.04.05.06.07.08.09.0

10.0

Real-Time DENSITY (lb/gal)Real-Time INLINE (lb/gal)

Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
Pump Schedule

Customer Name: SandRidge EnergyWell Name: WEST RANCH 45-14Formation: 1ST CABALLOSFluid Type: 25# LINEAR

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

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

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

PAD 17500 0.00 0.00 0.00 0.00 0 0 42.0 42.0 18.0 0 291.7 291.7 29

.25# 20/40 12000 0.25 0.25 0.36 0.36 3000 3000 42.2 41.5 17.0 0 200.0 203.2 49

.5# 20/40 12000 0.50 0.50 0.71 0.71 6000 9000 42.4 41.1 17.0 0 200.0 206.5 70

.75# 2040 12000 0.75 0.75 1.07 1.07 9000 18000 42.6 40.6 18.0 0 200.0 209.7 9

1# 20/40 12000 1.00 1.00 1.43 1.43 12000 30000 42.8 40.2 17.0 0 200.0 212.9 112# 20/40 12000 2.00 2.00 2.86 2.86 24000 54000 43.5 38.5 16.0 0 200.0 225.9 133# 20/40 6000 3.00 3.00 4.29 4.29 18000 72000 44.2 37.0 15.0 0 100.0 119.4 14

4# 20/40 4000 4.00 4.00 5.71 5.71 16000 88000 44.8 35.6 15.0 0 66.7 83.9 15

4# SLC 2500 4.00 4.00 5.71 5.71 10000 98000 44.8 35.6 15.0 0 41.7 52.5 16

FLUSH 10340 0.00 0.00 0.00 0.00 0 98000 50.0 50.0 0.0 0 246.2 246.2 18

Design Totals --> 100340 98000 0 1746.2 1851.9 

Actual Totals -->

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

Top Perf 6470 90 Tubing Casing

Bottom Perf 6596 Casing 247.54 Ble

0 Annulus

Flu

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

Casing 7 0.03826 6.276 Flush (bbls) Hydra

Tubing Top 247.5

Annulus Bottom 252.4

26
Superior Well Services

Additive Schedule

Customer Name: SandRidge Energy 2/2/2010

Well Name: WEST RANCH 45-14 Formation: 1ST CABALLOS

Additive: LSG-1 Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 12250 6.25 76.56 14.70 15.23 15.75 16.28 16.80 76.56

0.36 8400 6.25 52.50 14.46 14.99 15.49 16.01 16.54 129.06

0.71 8400 6.25 52.50 14.23 14.75 15.25 15.78 16.28 181.56

1.07 8400 6.25 52.50 14.02 14.52 15.02 15.51 16.01 234.06

1.43 8400 6.25 52.50 13.81 14.31 14.81 15.28 15.78 286.56

2.86 8400 6.25 52.50 13.02 13.49 13.94 14.41 14.88 339.06

4.29 4200 6.25 26.25 12.31 12.76 13.18 13.62 14.07 365.31

5.71 2800 6.25 17.50 11.68 12.10 12.52 12.94 13.34 382.81

5.71 1750 6.25 10.94 11.68 12.10 12.52 12.94 13.34 393.75

0.00 10340 6.25 64.63 14.70 15.23 15.75 16.28 16.80 458.38

.75# 2040 0.75 0.75 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! 459.13

459.13

459.13

459.13

459.13

459.13

459.13

459.13

459.13

459.13

Additive: SUPER 1OO N3 Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 12250 2.00 24.50 4.70 4.87 5.04 5.21 5.38 24.50

0.36 8400 2.00 16.80 4.63 4.80 4.96 5.12 5.29 41.30

0.71 8400 2.00 16.80 4.55 4.72 4.88 5.05 5.21 58.10

1.07 8400 2.00 16.80 4.49 4.65 4.80 4.96 5.12 74.90

1.43 8400 2.00 16.80 4.42 4.58 4.74 4.89 5.05 91.70

2.86 8400 2.00 16.80 4.17 4.32 4.46 4.61 4.76 108.50

4.29 4200 2.00 8.40 0.00 0.00 4.22 4.36 4.50 116.90

5.71 2800 2.00 5.60 3.74 3.87 4.01 4.14 4.27 122.50

5.71 1750 2.00 3.50 3.74 3.87 4.01 4.14 4.27 126.00

0.00 10340 2.00 20.68 4.70 4.87 5.04 5.21 5.38 146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

Additive: OB1 Planned Additive Rates (PPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 0 0.25 0.00 0.59 0.61 0.63 0.65 0.67 0.00

0.00 12250 0.25 3.06 0.59 0.61 0.63 0.65 0.67 3.06

0.36 8400 0.25 2.10 0.58 0.60 0.62 0.64 0.66 5.16

0.71 8400 0.25 2.10 0.57 0.59 0.61 0.63 0.65 7.26

1.07 8400 0.25 2.10 0.56 0.58 0.60 0.62 0.64 9.36

1.43 8400 0.25 2.10 0.55 0.57 0.59 0.61 0.63 11.46

2.86 8400 0.25 2.10 0.52 0.54 0.56 0.58 0.60 13.56

4.29 4200 0.25 1.05 0.49 0.51 0.53 0.54 0.56 14.61

5.71 2800 0.25 0.70 0.47 0.48 0.50 0.52 0.53 15.31

5.71 1750 0.25 0.44 0.47 0.48 0.50 0.52 0.53 15.75

0.00 10340 0.25 2.59 0.59 0.61 0.63 0.65 0.67 18.34

18.34

18.34

18.34

18.34

18.34

18.34

18.34

18.34

18.34

18.34

Fluid Technician SOTO

Field Receipt #: STG #1 Prepared By: C ESQUIVEL
Superior Well Services

Additive Schedule

Customer Name: SandRidge Energy 2/2/2010

Well Name: WEST RANCH 45-14 Formation: 1ST CABALLOS

Additive: OB2 Planned Additive Rates (PPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 0 0.25 0.00 0.59 0.61 0.63 0.65 0.67 0.00

0.00 12250 0.25 3.06 0.59 0.61 0.63 0.65 0.67 3.06

0.36 8400 0.25 2.10 0.58 0.60 0.62 0.64 0.66 5.16

0.71 8400 0.25 2.10 0.57 0.59 0.61 0.63 0.65 7.26

1.07 8400 0.25 2.10 0.56 0.58 0.60 0.62 0.64 9.36

1.43 8400 0.25 2.10 0.55 0.57 0.59 0.61 0.63 11.46

2.86 8400 0.25 2.10 0.52 0.54 0.56 0.58 0.60 13.56

4.29 4200 0.25 1.05 0.49 0.51 0.53 0.54 0.56 14.61

5.71 2800 0.25 0.70 0.47 0.48 0.50 0.52 0.53 15.31

5.71 1750 0.25 0.44 0.47 0.48 0.50 0.52 0.53 15.75

0.00 10340 0.25 2.59 0.59 0.61 0.63 0.65 0.67 18.34

Additive: SUPERFOAM Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 12250 2.00 24.50 4.70 4.87 5.04 5.21 5.38 24.50

0.36 8400 2.00 16.80 4.63 4.80 4.96 5.12 5.29 41.30

0.71 8400 2.00 16.80 4.55 4.72 4.88 5.05 5.21 58.10

1.07 8400 2.00 16.80 4.49 4.65 4.80 4.96 5.12 74.90

1.43 8400 2.00 16.80 4.42 4.58 4.74 4.89 5.05 91.70

2.86 8400 2.00 16.80 4.17 4.32 4.46 4.61 4.76 108.50

4.29 4200 2.00 8.40 3.94 4.08 4.22 4.36 4.50 116.90

5.71 2800 2.00 5.60 3.74 3.87 4.01 4.14 4.27 122.50

5.71 1750 2.00 3.50 3.74 3.87 4.01 4.14 4.27 126.00

0.00 10340 2.00 20.68 4.70 4.87 5.04 5.21 5.38 146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

146.68

Additive: CLAYTREAT Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 12250 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.36 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.71 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.07 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.43 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.86 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

4.29 4200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 2800 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 1750 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 10340 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Fluid Technician SOTO

Field Receipt #: STG #1 Prepared By: C ESQUIVEL
February 2, 2010 POST TREATMENT REPORT

 Sandridge Energy 

 West Ranch 45-14 STG #2 

 Pecos Co. 

 Treatment Date: February 2, 2010 

Attn: Johnny Anaya 

Sandridge Energy 

Fluid Efficiency Test for the West Ranch 45-14 Stg #2 was conducted at max rate of 

40.9bpm at 4,103 psi. Test was conducted with 10,122 gallons of treated water with an ISIP of 

2544 psi, 5 min @ 751 psi, 10 min @ 272 psi, and 15 min @ 125 psi. Surface closure was at 

1,029 psi and bottom hole closure was at 3,196 psi. Test showed 29 perforations open and a fluid 

efficiency of 14% of treated water. 

The stimulation of the West Ranch 4-4W Stg #2 well consisted of 153,804 gallons of 

25# linear gel, and 10,122 gallons of treated water. This fluid was laden with 15,603 lbs of 100 

Mesh, 45,275 lbs of 30/50 Ottawa, 45,624 lbs of 20/40 Ottawa, and 22,959 lbs of 20/40 SBXL. It 

was pumped at an average foam rate of 70.8 bpm, and an average surface pressure of 4,833 psi. 

The ISIP was 4,502 psi and the approximate load to recover is 3,768 bbls. 

Please see all attached Meyers files. 

Superior Well Services appreciates the opportunity to perform pumping services for you 

in a cost-effective manner that focuses on quality and safety. 

Please contact the Midland Engineering Department if you have any questions, 

Thank you, 

Crisoforo Esquivel III 

Field Engineer 

Midland, TX 

(432) 207-0366 

cesquivel@swsi.com
Customer Name TICKET # TICKET DATE

Lease Well Name API # COUNTY STATESuperior Rep. Customer Rep. Stage #

JOHNNY ANAYA

Co2 Rate CO2 Total Total Rate Gel Foam Prop Total

BPM BBLS BPM Quality Quality LBS/Stg

2%KCL

15 22 41 25# 30Q

19 9 66 25# 30Q 6,914

19 14 65 25# 30Q

19 12 69 25# 30Q 8,689

21 15 71 25# 30Q

21 12 70 25# 30Q 8,607

21 14 71 25# 30Q

21 11 70 25# 30Q 11,770

20 14 73 25# 30Q

20 20 72 25# 30Q 12,103

6 26PM 4872 52 5 192 2 438 20 13 72 25# 30Q S 

Sweep 

6:23PM 4946 51.9 144 2,246 1.5# 30/50 Ottawa 6:19PM 4847 52.5 203 2,1026:16PM 4901 49.8 153 1,899 1.25# 30/50 Ottawa6:12PM 4701 50 186 1,746 Sweep 

Sweep 

6:09PM 4842 49.8 164 1,560 1# 30/50 Ottawa6:05PM 4880 50.3 200 1,3966:02PM 4801 50 165 1,196 .75# 100 Mesh 5:59PM 4624 50.3 209 1,031 Sweep 

Pad 

5:55PM 4621 50 149 822 .5# 100 Mesh

5:40PM 4678 48 365 673

Tested lines to 8500 psi 

4:48PM 4261 40.6 308 FET 

Prime up test lines

Small leak on risers

BPM BBLS BBLS

4:15PM

Benjamin Munoz 2

Time

Pressures (psi) Rate Stage Total Job Description / Remarks

Proppant Conc / Type STP ANNULUS

Page 1 Stimulation Treatment Report

SANDRIDGE ENERGY 55000354 03/11/10

WEST RANCH 45-14 Pecos TX

20 13 72 25# 30Q20 13 72 25# 30Q 12,794

20 13 72 25# 30Q

20 17 72 25# 30Q 12,286

20 11 71 25# 30Q 16,07720 11 72 25# 30Q 23,89220 7 72 25# 30Q 13,36920 10 72 25# 30Q 22,959

4%KCL

Treating Presure Injection Rates Shut In Pressures 

Minimum Minimum ISDP 2524 

Flush 

7:20PM Turn over to wireline 6:53PM 4738 52 241 3,9306:50PM 5024 52 154 3,689 4# slc6:48PM 5112 52 99 3,508 4# 20/40 Ottawa 

2# 20/40 Ottawa 

6:45PM 4860 52 159 3,409 3# 20/40 Ottawa

6:42PM 4987 51.8 170 3,2506:37PM 5033 52.1 248 3,080 1# 20/40 Ottawa 

6:33PM 4777 52.1 200 2,832 Sweep 

Sweep 

6:30PM 5014 52 194 2,632 1.5# 30/50 Ottawa6:26PM 4872 52.5 192 2,438

Operators 

Max Pressure 7900

Average 4813 Average 71 10 Min. 272

Final 

15 Min. 125 

Maximum 5217 Maximum 73 5 Min. 751 
WEST RANCH 45-14 STG#2 STEP 

32 33 34 35 36 

TIME (min)

0

500

10001500200025003000350040004500

Pressure (psi)

Real-Time Pressure (psi) Real-Tim

Real-TimReal-Tim

MView - WEST RANCH 45-14 - 2/2/2010
WEST RANCH 45-14 STG#2 Step Do

0

5 10 15 20 25 30 3

Rate (bpm)

0

200400600800

10001200

Pressure Loss (psi)

DP NW Data PointsDP NW: Alpha = 0.5DP Total NW Data PointsDP Total NWDP Perf Ideal

NuDisPer

MinFrac - 2/2/2010
WEST RANCH 45-14 STG#2 Regressio

0 0.2 0.4 0.6 0.8 1.0 1.2 

Nolte G Time

0

200400600800

100012001400160018002000

Surface Pressure (psi)

Surface PressureISIP - G dP/dG ISIP

TC

1A

1B

2A

2B

Pump Time (tp) Closure Time (tc) Delta Closure Time Surface ISIP (ISIPSurface Closure (PBH ISIP (ISIP|bh) BH Closure (Pc) Net Pressure (

∆p) 

Stress Gradient Efficiency* 

Slope 1 -2349Slope 2 -1354.3Slope 3Slope 4

MinFrac - 2/2/2010
WEST RANCH 45-14 STG#2 BH

65 75 85 95 105 115 125 135 

Time (min)

0

100020003000400050006000700080009000

100001100012000

Pressure (psi)

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

Measured SBH Conc. Measured S

MWell - WEST RANCH 45-14 STG2 - 2/2/2010
NET PRESSURE

1 10 100 

Time (min)

100

1000

10000

1e+05

Measured Minus MFrac BHP (psi)

BHTP Dif. (Measured - MFrac) (psi) BH Conc. 

MWell - WEST RANCH 45-14 STG2 - 2/2/2010
WEST RANCH 45-14 STG#2 IS

144 145 146 147 148 14

TIME (min)

38004000420044004600480050005200540056005800

Pressure (psi)

Real-Time Pressure (psi) Real-Time 

Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
WEST RANCH 45-14 STG#2 MAIN 

65 85 105 125 1

TIME (min)

0

100020003000400050006000700080009000

Pressure (psi)

Real-Time Pressure (psi) Real-Time 

Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
CHEMICAL PLOT

65 75 85 95 105 115 125 

TIME (min)

05

101520

Real-Time LSG GPT (gpt)Real-Time ACTIVATOR GPT (gpt)

Real-Time Real-Time Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
RATES

65 85 105 125 1

TIME (min)

0

1020304050607080

Real-Time FOAM RATE (bpm)Real-Time RATE (bpm)Real-Time CO2 RATE (bpm)Real-Time HYD SUC RATE (bpm)

Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
DENSITY

65 85 105 125 1

TIME (min)

0.01.02.03.04.05.06.07.08.09.0

10.0

Real-Time DENSITY (lb/gal)Real-Time INLINE (lb/gal)

Real-Time 

MView - WEST RANCH 45-14 - 2/2/2010
Total Variance: 1.62% 

DATE: FLUID TECHFIELD RECEIPT NO:

2 3 4 5 6 7 8 9 10 

PLANNED FLOW 

PROPOSED START HOSES END TOTAL LOSSES PUMPED VOLUME METER 

VOLUME LOADED USED DOWNHOLE FOR FLUID MEASURED 

PUMPED VOLUME 

1605 1460 1460 751 709 0 709 725 

490 1220 1220 917 303 0 303 290 

69 301 301 283 18 0 18 18 

298 298 298 0 0 0 0 

619 1881 1881 1573 308 0 308 312 

26 260 260 231 29 0 29 30 73 250 250 220 30 0 30 30 73 200 200 170 30 0 30 30 

SUPERNE-100ACTIVATORLSG-1

2/2/2010 SANDRIDGE ENERGY CUSTOMER:

WEST RANCH 45-14

PRODUCT

PRODUCT VARIANCE CALCULATIONS

CHEMICALS

CHEM-ADD OPERATOR: 

1

MEASURED VOLUMES

LEASE NAME & WELL NO:

PELXFOAMCLAYTREAT PPACETPLEX 40OB2OB1

13 14 

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

CLEAN VOLUME Comments:

FLOW MET

3,7

SPILLAGE

DOWNHOLE VOLUME

15 16 17 18

TOTAL SLURRY

3,486

30

1

PUMPED 

DOWNHOLE

DENSIO

25# LINEAR GEL

2

4,363

ENDING VOLUME

21

TO

22

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

23 24

BEGINNING VOLUME

28

25

4,363

PROPPANT VOLUME

SLURRY VOLUME (bbls)

PROPPANT (lbs)

CLEAN VOLUME (bbls)

BASE FLUID DESCRIPTION AFTER LOADING

FLOW METER SLURRY 

877

29 40
Pump Schedule

Customer Name: SandRidge EnergyWell Name: WEST RANCH 45-14Formation: 1ST CABALLOSFluid Type: 25# LINEAR

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

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

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

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

PAD 20000 0.00 0.00 0.00 0.00 0 0 49.0 49.0 20.0 0 333.3 333.3 57

.5# 100 MESH 8000 0.50 0.50 0.71 0.71 4000 4000 49.5 47.9 20.0 0 133.3 137.6 70

SWEEP 12000 0.00 0.00 0.00 0.00 0 4000 49.0 49.0 20.0 0 200.0 200.0 90

.75# 100 MESH 8000 0.75 0.75 1.07 1.07 6000 10000 49.7 47.4 20.0 0 133.3 139.8 10

SWEEP 12000 0.00 0.00 0.00 0.00 0 10000 49.0 49.0 20.0 0 200.0 200.0 12

1# 30/50 8000 1.00 1.00 1.43 1.43 8000 18000 49.9 46.9 19.0 0 133.3 142.0 13

SWEEP 12000 0.00 0.00 0.00 0.00 0 18000 49.0 49.0 20.0 0 200.0 200.0 15

1.25# 30/50 8000 1.25 1.25 1.79 1.79 10000 28000 50.1 46.4 19.0 0 133.3 144.1 17

SWEEP 12000 0.00 0.00 0.00 0.00 0 28000 49.0 49.0 20.0 0 200.0 200.0 19

1.5# 30/50 8000 1.50 1.50 2.14 2.14 12000 40000 50.3 45.9 19.0 0 133.3 146.3 20

SWEEP 12000 0.00 0.00 0.00 0.00 0 40000 49.0 49.0 20.0 0 200.0 200.0 22

1.5# 30/50 8000 1.50 1.50 2.14 2.14 12000 52000 50.3 45.9 19.0 0 133.3 146.3 24

SWEEP 12000 0.00 0.00 0.00 0.00 0 52000 49.0 49.0 20.0 0 200.0 200.0 26

1# 20/40 12000 1.00 1.00 1.43 1.43 12000 64000 49.9 46.9 10.0 0 200.0 212.9 28

2# 20/40 10000 2.00 2.00 2.86 2.86 20000 84000 50.7 44.9 19.0 0 166.7 188.2 303# 20/40 8000 3.00 3.00 4.29 4.29 24000 108000 51.5 43.1 18.0 0 133.3 159.2 31

4# 20/40 6000 4.00 4.00 5.71 5.71 24000 132000 52.2 41.5 17.0 0 100.0 125.9 33

4# SLC 3500 4.00 4.00 5.71 5.71 14000 146000 52.2 41.5 17.0 0 58.3 73.4 33

FLUSH 9900 0.00 0.00 0.00 0.00 0 146000 70.0 70.0 0.0 0 235.7 235.7 36

0 

Design Totals --> 199400 146000 0 3465.5 3622.9 

Actual Totals -->

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

Top Perf 6470 90 Tubing Casing

Bottom Perf 6596 Casing 247.54 Ble

0 Annulus

Flu

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

Casing 7 0.03826 6.276 Flush (bbls) Hydra

Tubing Top 247.5

Annulus Bottom 252.4

26
Superior Well Services

Additive Schedule

Customer Name: SandRidge Energy 2/2/2010

Well Name: WEST RANCH 45-14 Formation: 1ST CABALLOS

Additive: LSG-1 Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 6.25 87.50 14.70 15.23 15.75 16.28 16.80 87.50

0.71 5600 6.25 35.00 14.23 14.75 15.25 15.78 16.28 122.50

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 175.00

1.07 5600 6.25 35.00 14.02 14.52 15.02 15.51 16.01 210.00

0.00 8400 6.25 52.50 14.70 15.23 15.75 16.28 16.80 262.50

1.43 5600 6.25 35.00 13.81 14.31 14.81 15.28 15.78 297.50

0.00 8400 6.25 52.50 14.70 15.23 15.75 0.00 16.80 350.00

1.79 5600 6.25 35.00 13.60 14.10 14.57 6.30 15.54 20.00

0.00 8000 6.25 50.00 14.70 15.23 15.75 2.36 16.80 20.00

2.14 5600 6.25 35.00 13.39 13.89 14.36 3.68 15.30 20.00

0.00 8000 6.25 50.00 14.70 15.23 15.75 2.36 16.80 20.00

2.14 5600 6.25 35.00 13.39 13.89 14.36 3.68 15.30 20.00

0.00 8000 6.25 50.00 14.70 15.23 15.75 2.36 16.80 19.00

1.43 8400 6.25 52.50 13.81 14.31 14.81 3.68 15.78 20.00

2.86 8000 6.25 50.00 13.02 13.49 13.94 2.36 14.88 19.00

4.29 5600 6.25 35.00 12.31 12.76 13.18 3.68 14.07 20.00

5.71 8000 6.25 50.00 11.68 12.10 12.52 2.36 13.34 19.00

5.71 2450 6.25 15.31 11.68 12.10 12.52 3.68 13.34 20.00

0.00 8000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 19.00

20.00

12000 10

 SUPE 10000 Planned Additive Rates (GPM) 19

PPG 8000 LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual 18

0.00 10000 2.00 20.00 4.70 4.87 5.04 0.59 5.38 17.00

0.00 3500 2.00 7.00 4.70 4.87 5.04 0.34 5.38 17.00

0.71 9900 2.00 19.80 4.55 4.72 4.88 5.05 5.21 46.80

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 63.60

1.07 5600 2.00 11.20 4.49 4.65 4.80 4.96 5.12 74.80

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 91.60

1.43 5600 2.00 11.20 4.42 4.58 4.74 4.89 5.05 102.80

0.00 8400 2.00 16.80 0.00 0.00 5.04 5.21 5.38 119.60

1.79 5600 2.00 11.20 4.35 4.51 4.66 4.82 4.97 130.80

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 147.60

2.14 5600 2.00 11.20 4.28 4.44 4.59 4.75 4.90 158.80

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 175.60

2.14 5600 2.00 11.20 4.28 4.44 4.59 4.75 4.90 186.80

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 203.60

1.43 8400 2.00 16.80 4.42 4.58 4.74 4.89 5.05 220.40

2.86 7000 2.00 14.00 4.17 4.32 4.46 4.61 4.76 234.40

4.29 5600 2.00 11.20 3.94 4.08 4.22 4.36 4.50 245.60

5.71 4200 2.00 8.40 3.74 3.87 4.01 4.14 4.27 254.00

5.71 2450 2.00 4.90 3.74 3.87 4.01 4.14 4.27 258.90

0.00 9900 2.00 19.80 4.70 4.87 5.04 5.21 5.38 278.70

278.70

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

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.25 2.50 0.59 0.61 0.63 0.65 0.67 2.50

0.00 14000 0.25 3.50 0.59 0.61 0.63 0.65 0.67 6.00

0.71 5600 0.25 1.40 0.57 0.59 0.61 0.63 0.65 7.40

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 9.50

1.07 5600 0.25 1.40 0.56 0.58 0.60 0.62 0.64 10.90

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 13.00

1.43 5600 0.25 1.40 0.55 0.57 0.59 0.61 0.63 14.40

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 16.50

1.79 5600 0.25 1.40 0.54 0.56 0.58 0.60 0.62 17.90

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 20.00

2.14 5600 0.25 1.40 0.54 0.56 0.57 0.59 0.61 21.40

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 23.50

2.14 5600 0.25 1.40 0.54 0.56 0.57 0.59 0.61 24.90

0.00 8400 0.25 2.10 0.59 0.61 0.63 0.65 0.67 27.00

1.43 8400 0.25 2.10 0.55 0.57 0.59 0.61 0.63 29.10

2.86 7000 0.25 1.75 0.52 0.54 0.56 0.58 0.60 30.85

4.29 5600 0.25 1.40 0.49 0.51 0.53 0.54 0.56 32.25

5.71 4200 0.50 2.10 0.93 0.97 1.00 1.04 1.07 34.35

5.71 2450 0.50 1.23 0.93 0.97 1.00 1.04 1.07 35.58

0.00 9900 0.00 0.00 0.00 0.00 0.00 0.00 0.00 35.58

35.58

Fluid Technician SOTO

Field Receipt #: STG #1 Prepared By: C ESQUIVEL
Superior Well Services

Additive Schedule

Customer Name: SandRidge Energy 2/2/2010

Well Name: WEST RANCH 45-14 Formation: 1ST CABALLOS

Additive: ACTIVATOR Planned Additive Rates (PPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.71 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.07 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.43 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.79 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.43 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.86 7000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

4.29 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 4200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 2450 5.00 12.25 9.35 9.68 10.02 10.35 10.67 12.25

0.00 9900 0.00 0.00 0.00 0.00 0.00 0.00 0.00 12.25

Additive: SUPERFOAM Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 2.00 28.00 4.70 4.87 5.04 5.21 5.38 28.00

0.71 5600 2.00 11.20 4.55 4.72 4.88 5.05 5.21 39.20

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 56.00

1.07 5600 2.00 11.20 4.49 4.65 4.80 4.96 5.12 67.20

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 84.00

1.43 5600 2.00 11.20 4.42 4.58 4.74 4.89 5.05 95.20

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 112.00

1.79 5600 2.00 11.20 4.35 4.51 4.66 4.82 4.97 123.20

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 140.00

2.14 5600 2.00 11.20 4.28 4.44 4.59 4.75 4.90 151.20

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 168.00

2.14 5600 2.00 11.20 4.28 4.44 4.59 4.75 4.90 179.20

0.00 8400 2.00 16.80 4.70 4.87 5.04 5.21 5.38 196.00

1.43 8400 2.00 16.80 4.42 4.58 4.74 4.89 5.05 212.80

2.86 7000 2.00 14.00 4.17 4.32 4.46 4.61 4.76 226.80

4.29 5600 2.00 11.20 3.94 4.08 4.22 4.36 4.50 238.00

5.71 4200 2.00 8.40 3.74 3.87 4.01 4.14 4.27 246.40

5.71 2450 2.00 4.90 3.74 3.87 4.01 4.14 4.27 251.30

0.00 9900 0.00 0.00 0.00 0.00 0.00 0.00 0.00 251.30

251.30

Additive: CLAYTREAT Planned Additive Rates (GPM) VOLUME

PPG VOLUME LOAD AMOUNT 56 BPM 58 BPM 60 BPM 62 BPM 64 BPM Actual GONE

0.00 10000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 14000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.71 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.07 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.43 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.79 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.14 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1.43 8400 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2.86 7000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

4.29 5600 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 4200 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

5.71 2450 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 9900 2.00 19.80 4.70 4.87 5.04 5.21 5.38 19.80

Fluid Technician SOTO

Field Receipt #: STG #1 Prepared By: C ESQUIVEL




























Report Printed 8/19/2011

123 Robert S. Kerr Ave.

Oklahoma City, OK 73102

Casing & Cement

www.SandRidgeEnergy.com Page 1/1

WEST RANCH 45-14

For String: Conductor

Casing Detail:

Casing Description

Conductor

Run Date

12/3/2009 00:00

Set Depth (ftKB)

60

Wellbore

Original Hole

Csg Cutoff (ftKB)

20.0

Casing Cutoff Date

12/3/2009 09:00

Centralizers Scratchers

Casing Components:

Joints

1

Item Description

Casing-Joints

Icon

Casing (black)

OD (in)

13 3/8

ID (in)

12.715

Wt (lb/ft)

48.00

Grade

H-40

Top Connection Thread Length (ft)

40.00

Top Depth (ftKB)

19.6

Btm (ftKB)

59.6

Cementing Job Details:

Description

Conductor Cement

Type

Casing

String

Conductor, 60ftKB

Wellbore

Original Hole

Cementing Start Date

12/27/2009 18:30

Cementing End Date

12/27/2009 19:30

Cementing Company

Halliburton Energy Services

Comment

Cement Stage#1 Description:

Stage Number

1

Top Depth (ftKB)

19.6

Bottom Depth (ftKB)

59.6

Cement Volume Return (bbl)

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

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

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

Tail Fluid Details for Stage#1 :

Fluid Type

Tail

Fluid Description Amount (sacks) Class Volume Pumped (bbl)

Estimated Top (ftKB)

0.0

Estimated Bottom Depth (ftKB)

40.0

Yield (ft3/sack) Mix H20 Ratio (gal/sack) Free Water (%)

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

Comment

Additive Details

Add Conc Conc Unit
Report Printed 8/19/2011

123 Robert S. Kerr Ave.

Oklahoma City, OK 73102

Casing & Cement

www.SandRidgeEnergy.com Page 1/1

WEST RANCH 45-14

For String: Surface

Casing Detail:

Casing Description

Surface

Run Date

12/8/2009 08:30

Set Depth (ftKB)

1,270

Wellbore

Original Hole

Csg Cutoff (ftKB)

20.0

Casing Cutoff Date

12/8/2009 10:15

Centralizers

6

Scratchers

0

Casing Components:

Joints

33

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

LTC

Length (ft)

1,321.03

Top Depth (ftKB)

-52.0

Btm (ftKB)

1,269.1

Joints

1

Item Description

Guide Shoe

Icon

Casing shoe

OD (in)

9 5/8

ID (in)

8.921

Wt (lb/ft)

36.00

Grade

J-55

Top Connection Thread

LTC

Length (ft)

0.92

Top Depth (ftKB)

1,269.1

Btm (ftKB)

1,270.0

Cementing Job Details:

Description

Surface Casing Cement

Type

Casing

String

Surface, 1,270ftKB

Wellbore

Original Hole

Cementing Start Date

12/8/2009 13:30

Cementing End Date

12/8/2009 16:00

Cementing Company

Halliburton Energy Services

Comment

Cement Stage#1 Description:

Stage Number

1

Top Depth (ftKB)

19.6

Bottom Depth (ftKB)

1,270.0

Cement Volume Return (bbl)

109.0

Float Failed?

No

Plug Failed?

No

Full Return?

No

Pipe Reciprocated?

No

Pressure Held (psi)

297.0

Top Plug?

No

Bottom Plug?

No

Initial Pump Rate (gpm)

231

Final Pump Rate (gpm)

84

Avg Pump Rate (bbl/min)

231

Final Pump Pressure (psi)

351.0

Plug Bump Pressure (psi) Pressure Release Date

Lead Fluid Details for Stage#1 :

Fluid Type

Lead

Fluid Description

Swiftcem

Amount (sacks)

150

Class

C

Volume Pumped (bbl)

43.0

Estimated Top (ftKB)

0.0

Estimated Bottom Depth (ftKB)

0.0

Yield (ft3/sack)

1.62

Mix H20 Ratio (gal/sack)

7.91

Free Water (%)

Density (lb/gal)

14.20

Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

2 lbm Pheno-seal, 10 lbm Cal-seal

Additive Details

Add Conc Conc Unit

Lead Fluid Details for Stage#1 :

Fluid Type

Lead

Fluid Description

Econocem

Amount (sacks)

550

Class

C

Volume Pumped (bbl)

181.0

Estimated Top (ftKB)

0.0

Estimated Bottom Depth (ftKB)

329.0

Yield (ft3/sack)

1.85

Mix H20 Ratio (gal/sack)

9.77

Free Water (%)

Density (lb/gal)

12.90

Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

3% Salt, 2 lbm Pheno-Seal

Additive Details

Add Conc Conc Unit

Tail Fluid Details for Stage#1 :

Fluid Type

Tail

Fluid Description

Halcem

Amount (sacks)

180

Class

C

Volume Pumped (bbl)

54.0

Estimated Top (ftKB)

329.0

Estimated Bottom Depth (ftKB)

1,272.0

Yield (ft3/sack)

1.69

Mix H20 Ratio (gal/sack)

8.64

Free Water (%)

Density (lb/gal)

13.70

Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

4% Bentonite, 1.6 Calcium Chloride, 2.1 lbm Pheno-seal

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 45-14

For String: Production

Casing Detail:

Casing Description

Production

Run Date

12/27/2009 18:30

Set Depth (ftKB)

6,795

Wellbore

Original Hole

Csg Cutoff (ftKB) Casing Cutoff Date Centralizers

5

Scratchers

Casing Components:

Joints

144

Item Description

Casing-Joints

Icon

Casing (black)

OD (in)

7

ID (in)

6.276

Wt (lb/ft)

26.00

Grade

P-110

Top Connection Thread

LTC

Length (ft)

5,600.00

Top Depth (ftKB)

19.6

Btm (ftKB)

5,619.6

Joints

1

Item Description

Marker Joint

Icon

Casing (red)

OD (in)

7

ID (in)

6.276

Wt (lb/ft)

26.00

Grade

P-110

Top Connection Thread

LTC

Length (ft)

37.35

Top Depth (ftKB)

5,619.6

Btm (ftKB)

5,656.9

Joints

8

Item Description

Casing-Joints

Icon

Casing (black)

OD (in)

7

ID (in)

6.276

Wt (lb/ft)

26.00

Grade

P-110

Top Connection Thread

LTC

Length (ft)

314.63

Top Depth (ftKB)

5,656.9

Btm (ftKB)

5,971.5

Joints

1

Item Description

Marker Joint

Icon

Casing (red)

OD (in)

7

ID (in)

6.276

Wt (lb/ft)

26.00

Grade

P-110

Top Connection Thread

LTC

Length (ft)

37.58

Top Depth (ftKB)

5,971.5

Btm (ftKB)

6,009.1

Joints

19

Item Description

Casing-Joints

Icon

Casing (black)

OD (in)

7

ID (in)

6.276

Wt (lb/ft)

26.00

Grade

P-110

Top Connection Thread

LTC

Length (ft)

744.91

Top Depth (ftKB)

6,009.1

Btm (ftKB)

6,754.0

Joints

1

Item Description

Float Collar

Icon

Float collar

OD (in)

7

ID (in)

6.276

Wt (lb/ft)

26.00

Grade

P-110

Top Connection Thread

LTC

Length (ft)

0.90

Top Depth (ftKB)

6,754.0

Btm (ftKB)

6,754.9

Joints

1

Item Description

Casing-Joints

Icon

Casing (black)

OD (in)

7

ID (in)

6.276

Wt (lb/ft)

26.00

Grade

P-110

Top Connection Thread

LTC

Length (ft)

38.82

Top Depth (ftKB)

6,754.9

Btm (ftKB)

6,793.7

Joints

1

Item Description

Float Shoe

Icon

Casing shoe

OD (in)

7

ID (in) Wt (lb/ft) Grade Top Connection Thread

LTC

Length (ft)

1.25

Top Depth (ftKB)

6,793.7

Btm (ftKB)

6,795.0

Cementing Job Details:

Description

Production Casing Cement

Type

Casing

String

Production, 6,795ftKB

Wellbore

Original Hole

Cementing Start Date

12/27/2009 19:30

Cementing End Date

12/27/2009 21:30

Cementing Company

Halliburton Energy Services

Comment

Cement Stage#1 Description:

Stage Number

1

Top Depth (ftKB)

2,550.0

Bottom Depth (ftKB)

6,795.0

Cement Volume Return (bbl)

Float Failed?

No

Plug Failed?

No

Full Return?

No

Pipe Reciprocated?

No

Pressure Held (psi)

1,800.0

Top Plug?

Yes

Bottom Plug?

No

Initial Pump Rate (gpm)

6

Final Pump Rate (gpm)

6

Avg Pump Rate (bbl/min)

6

Final Pump Pressure (psi)

1,300.0

Plug Bump Pressure (psi)

1,800.0

Pressure Release Date

12/27/2009

Lead Fluid Details for Stage#1 :

Fluid Type

Lead

Fluid Description Amount (sacks)

270

Class

H

Volume Pumped (bbl)

63.0

Estimated Top (ftKB)

5,200.0

Estimated Bottom Depth (ftKB)

6,795.0

Yield (ft3/sack)

1.32

Mix H20 Ratio (gal/sack)

6.06

Free Water (%)

Density (lb/gal)

14.20

Plastic Viscosity (cp) Thickening Time (hr) 1st Compressive Strength (psi)

Comment

Additive Details

Add Conc Conc Unit

Econo-lite 0.3 %

Halad - 9 0.7 %

HR 800 0.1 %

Pheno-seal 2.0 lmb

Salt 0.1 %

Description

Cement Plug

Type

Plug

String

Production, 6,795ftKB

Wellbore

Original Hole

Cementing Start Date

12/28/2009 00:00

Cementing End Date

12/28/2009 00:00

Cementing Company

Halliburton Energy Services

Comment
Report Printed 8/19/2011

123 Robert S. Kerr Ave.

Oklahoma City, OK 73102

Casing & Cement

www.SandRidgeEnergy.com Page 2/2

WEST RANCH 45-14

For String: Production

Cement Stage#<Stage Number?> Description:

Stage Number Top Depth (ftKB)

6,754.0

Bottom Depth (ftKB)

6,795.0

Cement Volume Return (bbl)

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

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

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

<Fluid Type?> Fluid Details for Stage#<Stage Number?>:

Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl)

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

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

Comment

Additive Details

Add Conc Conc Unit











SandRidge Energy Daily Completions Report

WR 45-14 - SandRidge Energy

Report Start Date Report End Date Daily Summary 12/27/2009 12/28/2009 Finish logging well. Rig Released 12/28/09.12/28/2009 12/29/2009 WOCU. Temporarily drop fr/ report pending further activity.1/30/2010 1/31/2010

MIRU WL. RIH w/ GR/CCL/CBL & logged 6,754'-2,280'. TOC @ 2,550'. Tstd csBled off. Perf'd 1st Cab 6,470'-6,480'; 6,500'-6,520' w/ 1 SPF; 6,566'-6,596' w/ 2 using 4" csg guns 60 deg phased. SWI & SDFN. WO frac sch 2/1-2.

1/31/2010 2/1/2010 MIRU frac svcs. SDFN. WO frac sch 2/1-2.2/1/2010 2/2/2010

Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 57M lbs 100 Mesh, 20/40 Ottawa & 33250 TLTR, 1288 bbls CO2. FET results: 0.84 psi/ft f.g., 35% FE. SDFN. WO p

2/2/2010 2/3/2010

Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 95M lbs 20/40 Ottawa & CRC sd, 193bbls CO2. RU WL. RIH & set 7" CBP @ 6,420'. POH. Tstd plug to 4800 psi. P6,204'-6,214'; 6,240'-6,260' w/ 1 SPF; 6,360'-6,390' w/ 2 SPF (90 holes) using 4" phased. RD WL. Frac'd 1st Cab w/ 25# linear gel, 30Q CO2, 149M lbs 100 Mes& SB Excel & 30/50 Ottawa sd, 3760 TLTR, 1232 bbls CO2. FET results: 0.84 pFE. RU WL. RIH w/ 7" CBP & tagged 4,680'; made several unsuccessful attempunable to surge up or pump dn. Set CBP @ 3,642'. POH. RDMO WL. SWI & S

2/3/2010 2/4/2010 RDMO frac svcs. MIRU WSU. SDFN. Prep f/ DO. 2/4/2010 2/5/2010

RU WSU & snub unit. NU BOP. Snubbed IH w/ bit, PO sub, XN nipple & 115 jts DO 1st CBP @ 3,642'. Cont snubbing IH w/ 25 jts tbg to 4,440'. Total 73 BF pm

to tank.

2/5/2010 2/6/2010

FCP - 375 psi. Cont snubbing IH w/ 61 jts tbg & tagged 6,376'. Est circ. Drld & wCBP @ 6,420' & DO. Cont snubbing IH w/ 10 jts tbg & tagged 6,694'. CO to 6,74Pulled up & landed tbg @ 6,493'; 204 jts IH; XN nipple @ 6,461'. RDMO snub unND manual frac valve . NU tree. Pump off bit. Total 135 BF pmpd. RDMO WSU

2/6/2010 2/7/2010 Flwg to tank.2/7/2010 2/8/2010 FIRST SALES @ 9:50 a.m. on 2/7/2010.2/8/2010 2/9/2010 Flwg to sales.2/9/2010 2/10/2010 Flwg to sales. Frac sch 2/18.

2/10/2010 2/11/2010 Flwg to sales. Frac sch 2/18.2/11/2010 2/12/2010 Flwg to sales. Frac sch 2/18.2/12/2010 2/13/2010 Flwg to sales. Frac sch 2/18.2/13/2010 2/14/2010

MIRU SLU. RIH & set plug in XN nipple @ 6,461'. Blew dn tbg. MIRU WSU. NBOP. RU snub unit. Snubbed OH & LD 204 jts tbg. RD snub unit. ND BOP. RSDFN. Prep f/ frac.
SandRidge Energy Daily Completions Report

2/14/2010 2/15/2010 SI; WO frac.2/15/2010 2/16/2010 SI; WO frac.2/16/2010 2/17/2010 SI; WO frac.2/17/2010 2/18/2010 SI; WO frac.2/18/2010 2/19/2010

MIRU WL. RIH w/ GR to 5,850'. POH. RIH & set 7" CBP @ 5,830'. Loaded holtstd plug to 4800 psi. Bled dn to 900 psi. Perf'd Tesnus 5,728'-5,758' w/ 1 SPF; 2 SPF (50 holes) using 4" csg guns 60 deg phased. SWI & SDFN. WO frac.

2/19/2010 2/20/2010 SI; WO frac.2/20/2010 2/21/2010 TLTR 2/21/2010 2/22/2010

MIRU WSU. ND hydraulic frac valve. RU snub unit. TIH w/ bit, sub, XN nipple & SDFN. Prep f/ DO.

2/22/2010 2/23/2010

Cont TIH & tagged CBP @ 5,823' & DO. Washed to 6,687'. Circ clean. TOH & snub unit. Total 105 BF pmpd. Flwg to tank. Prep f/ WL & to set pkr.

2/23/2010 2/24/2010 SD due to weather. Prep f/ WL to set pkr. 2/24/2010 2/25/2010

MIRU WL. RIH w/ GR & JB to 6,200'. POH. RIH & set AS1X pkr @ 6,180'. POSWI & SDFN. 

2/25/2010 2/26/2010 SI; no activity.2/26/2010 2/27/2010 SI; no activity.2/27/2010 2/28/2010 SI; no activity.2/28/2010 3/1/2010 Lower: TIH w/ pkr & tbg. SDFN. Prep to run Upper tbg.3/1/2010 3/2/2010

Lower: Equalized. TIH w/ tbg & landed @ 5,756'. RD snub unit. ND BOP's & mNU tree. RD WSU. RU SL. Lower & Upper; Pulled PT plugs. Opened to tanks

3/2/2010 3/3/2010 Lower & Upper: Turned to sales @ 6:00 a.m.3/3/2010 3/4/2010 Lower & Upper: Flwg to sales.3/4/2010 3/5/2010 Lower & Upper: Flwg to sales.
SandRidge Energy Daily Completions Report

3/5/2010 3/6/2010 Lower & Upper: Flwg to sales.3/6/2010 3/7/2010 Lower & Upper: Flwg to sales.3/7/2010 3/8/2010 Lower & Upper: Flwg to sales.3/8/2010 3/9/2010 Lower & Upper: Flwg to sales.3/9/2010 3/10/2010 Lower & Upper: Flwg to sales.3/10/2010 3/11/2010 Lower & Upper: Flwg to sales.3/11/2010 3/12/2010 Lower & Upper: Flwg to sales.3/12/2010 3/13/2010 Lower & Upper: Flwg to sales.3/13/2010 3/14/2010 Lower & Upper: Flwg to sales.3/14/2010 3/15/2010 Lower & Upper: Flwg to sales. FINAL REPORT.
03/02/10

WELL NAME: REPORT DATE: 3/1/10-3/2/10

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 0 180

15:00 0 0 180

16:00 0 0 180

17:00 0 0 180

18:00 0 0 180

19:00 0 0 180

20:00 0 0 180 8:15 opened well

21:00 18 900 1,200 0 0 180 By passed to tank

22:00 18 900 1,000 0 0 180 By passed to tank

23:00 18 900 900 0 0 180 By passed to tank

24:00 18 900 850 0 0 180 By passed to tank/ 55% CO2

01:00 18 900 900 0 0 180 By passed to tank

02:00 18 900 900 0 0 180 By passed to tank

03:00 18 900 900 0 0 180 By passed to tank

04:00 18 900 900 0 0 180 By passed to tank

05:00 18 900 900 0 0 180 By passed to tank

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 180 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

Harrison Harl (432) 360-5566

 Today's Date:

SANDRIDGE ENERGY

FLOWBACK REPORT

West Ranch 45-14

TL =180 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

FLOWBACK SUMMARY

FLOWBACK HANDS:
03/02/10

WELL NAME: REPORT DATE: 3/2/10-3/3/10

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 18 900 0 Flowing to tank

07:00 20 875 1,897 0 0 0 Turned to sales 

08:00 26 750 1,970 0 0 0 Flowing to sales

09:00 26 600 1,851 5 5 5 -5 Flowing to sales

10:00 30 550 1,926 3 8 8 -8 Flowing to sales

11:00 34 550 1,965 2 10 10 -10 Flowing to sales

12:00 34 550 2,032 3 13 13 -13

Flowing to sales/ Personal 

released

13:00 13 13 -13

14:00 13 13 -13

15:00 13 13 -13

16:00 13 13 -13

17:00 13 13 -13

18:00 13 13 -13

19:00 13 13 -13

20:00 13 13 -13

21:00 13 13 -13

22:00 13 13 -13

23:00 13 13 -13

24:00 13 13 -13

01:00 13 13 -13

02:00 13 13 -13

03:00 13 13 -13

04:00 13 13 -13

05:00 13 13 -13

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 13 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 13 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: (13) BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

FLOWBACK SUMMARY

FLOWBACK HANDS:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

West Ranch 45-14
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

FLOWBACK SUMMARY

FLOWBACK HANDS:
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

FLOWBACK SUMMARY

FLOWBACK HANDS:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

FLOWBACK SUMMARY

FLOWBACK HANDS:
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

FLOWBACK SUMMARY

FLOWBACK HANDS:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.
WELL NAME: REPORT DATE: 3/1/10-3/2/10

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 0 180

15:00 0 0 180

16:00 0 0 180

17:00 0 0 180

18:00 0 0 180

19:00 0 0 180

20:00 0 0 180 8:15 opened well

21:00 16 110 1,200 9 9 9 171 By passed to tank

22:00 16 900 1,000 13 22 22 158 By passed to tank

23:00 16 600 900 11 33 33 147 By passed to tank

24:00 16 650 850 3 36 36 144 By passed to tank/ 12% Co2

01:00 16 650 900 36 36 144 By passed to tank

02:00 16 650 900 36 36 144 By Passed to tank

03:00 16 750 900 36 36 144 By passed to tank

04:00 16 750 900 36 36 144 By passed to tank

05:00 16 750 900 36 36 144 By passed to tank

TOTAL LOAD TO RECOVER: 180 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 36 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 36 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 144 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: 20 %

Harrison Harl (432) 360-5566

 Today's Date:

SANDRIDGE ENERGY

FLOWBACK REPORT

West Ranch 45-14

TL =180 BBLS. DLR = 36 BBLS. TLR = 36BBLS. LTR = 144 BBLS. 20% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

FLOWBACK SUMMARY

FLOWBACK HANDS:
03/02/10

WELL NAME: REPORT DATE: 3/2/10-3/3/10

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 16 850 900 0

Flowing to tank/ 6:30 turned to 

sales

07:00 18 850 900 1,495 0 0 0 Flowing to sales

08:00 22 550 800 1,502 0 0 0 Flowing to sales

09:00 28 350 650 1,307 4 4 4 -4 Flowing to sales

10:00 32 300 600 1,246 2 6 6 -6 Flowing to sales

11:00 32 300 550 1,185 3 9 9 -9 Flowing to sales

12:00 32 300 550 1,179 2 11 11 -11

Flowing to sales/ Personal 

Released

13:00 11 11 -11

14:00 11 11 -11

15:00 11 11 -11

16:00 11 11 -11

17:00 11 11 -11

18:00 11 11 -11

19:00 11 11 -11

20:00 11 11 -11

21:00 11 11 -11

22:00 11 11 -11

23:00 11 11 -11

24:00 11 11 -11

01:00 11 11 -11

02:00 11 11 -11

03:00 11 11 -11

04:00 11 11 -11

05:00 11 11 -11

TOTAL LOAD TO RECOVER: 180 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 11 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 11 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: (11) BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: 6 %

Harrison Harl (281) 436-6487

 Today's Date:

FLOWBACK SUMMARY

FLOWBACK HANDS:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL = 180 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

West Ranch 45-14
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

FLOWBACK SUMMARY

FLOWBACK HANDS:
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

FLOWBACK SUMMARY

FLOWBACK HANDS:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.

FLOWBACK SUMMARY

FLOWBACK HANDS:
WELL NAME: REPORT DATE:

ZONE NAME: COUNTY

STAGE NUMBER: FIELD:

PERFS INTERVALS STATE:

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

23:00 0 0 0

24:00 0 0 0

01:00 0 0 0

02:00 0 0 0

03:00 0 0 0

04:00 0 0 0

05:00 0 0 0

TOTAL LOAD TO RECOVER: 0 BBLS DAILY SAND RECOVERY: SACKS

DAILY LOAD RECOVERY: 0 BBLS TOTAL SAND RECOVERED: SACKS

TOTAL LOAD RECOVERED: 0 BBLS DAILY OIL RECOVERY: BBLS

LOAD LEFT TO RECOVER: 0 BBLS TOTAL OIL RECOVERED: BBLS

% OF LOAD RECOVERED: #DIV/0! %

 Today's Date:

FLOWBACK SUMMARY

FLOWBACK HANDS:

SANDRIDGE ENERGY

FLOWBACK REPORT

TL =0000 BBLS. DLR = 0000 BBLS. TLR = 0000BBLS. LTR = 0000 BBLS. 00% OF LOAD RECOVERED. 

WTR WT = 8.6 PPG. SOLD 0000 MCF IN 00 HOURS DOR = 000 BBLS. TOR = 000 BBLS.
Stage #: 1 1st Attempt Formation: 1st Caballos

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 6,470' Bottom Perf: 6,596'

Displ Coef: 

SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: 0.84 psi/ft ISDP: 2,672 psi

Holes Open: Fluid Eff: (%) 35 5 min SIP: 2,208 psi

Max Rate: Calc. Perm: mD 10 min SIP: 1,954 psi

Max Pressure: Pc (psig) 4991 psi 15 min SIP: 1,711 psi

Conc. (ppg) Weight (lbs) Type

0.50 3,863 100 Mesh

0.75 8,254 100 Mesh

1.00 8,906 30/50 Ottawa

1.25 8,375 30/50 Ottawa

1.50 10,995 30/50 Ottawa

1.50 11,010 30/50 Ottawa

1.00 5,773 20/40 Ottawa

BBLS Gal LTR: 136500.0 Gals

LBS 

30 % tons CO2

4,862 psig 5251 psig

56.7 bpm 62.8 bpm

ISIP = 3,946 psig

NO

NO

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

Avg Treating Press= Maximum = 

Avg Treating Rate = Maximum = 

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

hours before flowing back.

Remarks/Notes

*12,117# 100 Mesh, *39,286# 30/50 Ottawa, *5773# 20/40 Ottawa, *0# 20/40 SLC. Had to Call Flush early due to not being able to keep Fluid rate where 

needed be. Lost 3 Fluid Pumps (2 pumps w/ECM Failure & Lost Packing in Another). Also lost Packing in 3 CO2 Pumps. 6 Pumps Total. The decision was 

made to SDFD to Repair Pumps. Will begin in the a.m. NOTE - Corrections were made to report on 2/3/10 by Janet Henderson: Actual Displacement 

was changed from 248.0 to 280.0 bbls; ISIP was changed from 4,862 to 3,946 psig. (Per Jason Stewart). 

Was well flowed back immediately? If not, well was shut-in

Total Fluid Pumped: 3,250

Total Proppant: 57,176

Continue on next page if necessary

See Remarks

Foam Quality: Amount of Foam Pumped: 230DH/10CD Type of foam:

Type of Proppant:

X-Link Breaker Time:

139.0 1.5ppg 25# Linear Gel/30Q CO2 57 5090.0

244.0 Pad 25# Linear Gel/30Q CO2 57 4841.0

117.0 1ppg 25# Linear Gel/30Q CO2 54 5081.0

239.0 Pad 25# Linear Gel/30Q CO2 58 4952.0

117.0 1.25ppg 25# Linear Gel/30Q CO2 57 4731.0

204.0 Pad 25# Linear Gel/30Q CO2 55 4703.0

134.0 1.5ppg 25# Linear Gel/30Q CO2 57 4992.0

202.0 Pad 25# Linear Gel/30Q CO2 58 4789.0

187.0 .75ppg 25# Linear Gel/30Q CO2 60 4855.0

189.0 Pad 25# Linear Gel/30Q CO2 59 4591.0

156.0 1ppg 25# Linear Gel/30Q CO2 59 4911.0

228.0 Pad 25# Linear Gel/30Q CO2 56 4684.0

284.0 FET 2% KCL Sub. Water 47 4325.0

10.0 Load & BD 2% KCL Sub. Water 5 3581.0

118.0 .5ppg 25# Linear Gel/30Q CO2 60 4636.0

402.0 Pad 25# Linear Gel/30Q CO2 60 4809.0

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

190 3,581

FET ANALYSIS

90 Frac Grad:

Fluid Type

48

4,344

FLUIDS PUMPED PROPPANT PUMPED

Liner Top Depth 6,470'

28

247.5 280.0 MAXIMUM PRESSURE

1-2spf

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

2/1/2010 12:45:00 PM 2:51:00 PM

7"
Stage #: 1 1st Attempt Formation: 1st Caballos

Stimulation Company:

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

Pipe 1 Size: Pipe 2 Size: Top Perf: 6,470' Bottom Perf: 6,596'

Displ Coef: 

SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

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

Remarks/Notes

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

280.0 Flush 2% KCL Sub Water 23 4456.0

1-2spf

247.5 280.0 MAXIMUM PRESSURE

PROPPANT PUMPED

190 3,581

FLUIDS PUMPED (CONTINUED FROM PAGE 1)

Liner Depth 6,470'

2/1/2010 12:45:00 PM

7"

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

2:51:00 PM

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14
Stage #: 1 Formation: Tesnus

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250'

Displ Coef: 

SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls

5,700 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi

Holes Open: Fluid Eff: (%) 5 min SIP: psi

Max Rate: Calc. Perm: mD 10 min SIP: psi

Max Pressure: Pc (psig) psi 15 min SIP: psi

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

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa

2.0 14,795 20/40 Ottawa

2.5 20,083 20/40 Ottawa

3.0 18,988 20/40 Ottawa

4.0 21,642 20/40 Ottawa

4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS 

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm

ISIP = 3,400 psig

Yes 2.0

No 4

250

FET ANALYSIS

Frac Grad:

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

Avg Treating Press= Maximum = 

X-Link Breaker Time: n/a

FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum = 

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes

If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in

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

Foam Quality: Amount of Foam Pumped: 400 Type of foam:

Type of Proppant: 20/40 Ottawa, 20/40 SLC

Total Fluid Pumped: 441

Total Proppant: 97,100

57.0 4% Crystalline KCl 3,726 30.0

53.0 3,541 38.1

43.0 3,544 38.2

42.0 3,896 38.4

32.0 3,873 37.1

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

16.0 2,560 2.0

40.0 3,882 38.0

56.0 3,292 38.0

22.0 3,485 38.8

35.0 3,507 37.0

20# Linear gel, 80Q CO2

12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7

4% Crystalline KCl

20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2

3,125

Displ Coef: 0.0383

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report

1 sec (or 2 sec) data in .csv of .txt form

Service Company Treatment Report

Service Company Field Ticket

areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com;

mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com;

tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com;

scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com
Stage #: 1 2nd Attempt Formation: 1st Caballos

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 6,470' Bottom Perf: 6,596'

Displ Coef: 

SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi

Holes Open: Fluid Eff: (%) 5 min SIP: psi

Max Rate: Calc. Perm: mD 10 min SIP: psi

Max Pressure: Pc (psig) psi 15 min SIP: psi

Conc. (ppg) Weight (lbs) Type

0.25 4,070 20/40 Ottawa

0.50 7,502 20/40 Ottawa

0.75 8,489 20/40 Ottawa

1.00 12,056 20/40 Ottawa

2.00 22,150 20/40 Ottawa

3.00 18,915 20/40 Ottawa

4.00 7,450 20/40 Ottawa

4.00 14,000 20/40 CRC

BBLS Gal LTR: 81186.0 Gals

LBS 

30 % tons CO2

5,612 psig 6592 psig

60.2 bpm 62 bpm

ISIP = 5,502 psig

NO

NO

248.0 MAXIMUM PRESSURE

Liner Top Depth 1-2spf

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

2/1/2010 8:24:00 AM 9:28:00 AM

7"

1,247

FET ANALYSIS

Frac Grad:

FLUIDS PUMPED PROPPANT PUMPED

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

6,470'

960

247.5

343.0 Pad 25# Linear Gel/30Q CO2 61 5556.0

17.0 Load & PI 2% KCL Sub Water 3 1247.0

235.0 .5ppg 25# Linear Gel/30Q CO2 61 5389.0

232.0 .25ppg 25# Linear Gel/30Q CO2 61 5423.0

198.0 1ppg 25# Linear Gel/30Q CO2 60 5624.0

191.0 .75 25# Linear Gel/30Q CO2 60 5533.0

111.0 3ppg 25# Linear Gel/30Q CO2 60 5718.0

205.0 2ppg 25# Linear Gel/30Q CO2 60 5687.0

115.0 4ppg 25# Linear Gel/30Q CO2 61 5780.0

38.0 4ppg 25# Linear Gel/30Q CO2 61 5759.0

248.0 Flush 2% KCL Sub Water 51 5744.0

1,933

Total Proppant: 94,632 Type of Proppant: *80,632# 20/40 Ottawa, *14,000# 20/40 CRC

Foam Quality: Amount of Foam Pumped: 145DH/5CD Type of foam:

X-Link Breaker Time:

Avg Treating Press= Maximum = 

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

Was well flowed back immediately? If not, well was shut-in

Fluid Type

Continue on next page if necessary

Avg Treating Rate = Maximum = 

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

Total Fluid Pumped:

hours before flowing back.

Remarks/Notes

NOTE: Corrections were made to this report on 2/3/10 by Janet Henderson: Maximum Treating Press was changed from 6256 to 6592 psig (per Jason 

Stewart). 
Stage #: 1 2nd Attempt Formation: 1st Caballos

Stimulation Company:

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

Pipe 1 Size: Pipe 2 Size: Top Perf: 6,470' Bottom Perf: 6,596'

Displ Coef: 

SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

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

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14

9:28:00 AM

7"

PROPPANT PUMPED

Liner Depth 6,470'

2/1/2010 8:24:00 AM

960 1,247

1-2spf

247.5 248.0 MAXIMUM PRESSURE

FLUIDS PUMPED (CONTINUED FROM PAGE 1)

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

Remarks/Notes
Stage #: 1 Formation: Tesnus

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250'

Displ Coef: 

SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls

5,700 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi

Holes Open: Fluid Eff: (%) 5 min SIP: psi

Max Rate: Calc. Perm: mD 10 min SIP: psi

Max Pressure: Pc (psig) psi 15 min SIP: psi

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

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa

2.0 14,795 20/40 Ottawa

2.5 20,083 20/40 Ottawa

3.0 18,988 20/40 Ottawa

4.0 21,642 20/40 Ottawa

4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS 

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm

ISIP = 3,400 psig

Yes 2.0

No 4

12/22/2009 10:10:00 AM

Displ Coef: 0.0383

Liner Top Depth 0.5 - 2 SPF

7.000

MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services

56.0 3,292 38.0

22.0 3,485 38.8

35.0 3,507 37.0

20# Linear gel, 80Q CO2

12:36:00 PM

45.0 3,439 39.7

4% Crystalline KCl

20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2

3,125

199.2 198.0

53.0 3,541 38.1

43.0 3,544 38.2

42.0 3,896 38.4

32.0 3,873 37.1

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

57.0 3,726 30.0 4% Crystalline KCl

Total Fluid Pumped: 441

Total Proppant: 97,100 Type of Proppant: 20/40 Ottawa, 20/40 SLC

Foam Quality: Amount of Foam Pumped: 400 Type of foam:

X-Link Breaker Time: n/a

n/a

Avg Treating Press= Maximum = 

FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum = 

hours before flowing back.

Remarks/Notes

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

Was well flowed back immediately? If not, well was shut-in

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

250

FET ANALYSIS

Frac Grad:

3,882 38.0

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

16.0 2,560 2.0

40.0
Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report

1 sec (or 2 sec) data in .csv of .txt form

Service Company Treatment Report

Service Company Field Ticket

areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com;

mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com;

tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com;

scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com
Stage #: 2 Formation: 1st Caballos

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 6,204' Bottom Perf: 6,390'

Displ Coef: 

SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: 0.84 psi/ft ISDP: 2,558 psi

Holes Open: Fluid Eff: (%) 30 5 min SIP: 751 psi

Max Rate: Calc. Perm: mD 10 min SIP: 270 psi

Max Pressure: Pc (psig) 3233 psi 15 min SIP: 140 psi

Conc. (ppg) Weight (lbs) Type

0.50 6,914 100 Mesh

0.75 8,689 100 Mesh

1.00 8,607 30/50 Ottawa

1.25 11,770 30/50 Ottawa

1.50 12,103 30/50 Ottawa

1.50 12,794 30/50 Ottawa

1.00 12,286 20/40 Ottawa

73,163

BBLS Gal LTR: 157920.0 Gals

LBS 

30 % tons CO2

4,833 psig 5217 psig

70.8 bpm 72.5 bpm

ISIP = 4,520 psig

NO

NO

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

Avg Treating Press= Maximum = 

Avg Treating Rate = Maximum = 

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

hours before flowing back.

Remarks/Notes

*15,603# 100 Mesh, *45,274# 30/50 Ottawa, *65,624# 20/40 Ottawa, *22,959# 20/40 SLC.

Was well flowed back immediately? If not, well was shut-in

3,019

Total Fluid Pumped: 3,760

Total Proppant: 149,460

Continue on next page if necessary

See Remarks

Foam Quality: Amount of Foam Pumped: 220DH/15CD Type of foam:

Type of Proppant:

X-Link Breaker Time:

178.0 1.5ppg 25# Linear Gel/30Q CO2 72 5020.0

192.0 Pad 25# Linear Gel/30Q CO2 72 4826.0

236.0 1ppg 25# Linear Gel/30Q CO2 72 5017.0

207.0 Pad 25# Linear Gel/30Q CO2 72 4775.0

142.0 1.25ppg 25# Linear Gel/30Q CO2 70 4903.0

185.0 Pad 25# Linear Gel/30Q CO2 70 4849.0

133.0 1.5ppg 25# Linear Gel/30Q CO2 72 5061.0

203.0 Pad 25# Linear Gel/30Q CO2 72 4781.0

160.0 .75ppg 25# Linear Gel/30Q CO2 69 4793.0

209.0 Pad 25# Linear Gel/30Q CO2 69 4596.0

156.0 1ppg 25# Linear Gel/30Q CO2 70 4838.0

199.0 Pad 25# Linear Gel/30Q CO2 71 4723.0

298.0 FET 2% KCL Sub. Water 41 4109.0

10.0 Load & BD 2% KCL Sub. Water 2 1393.0

146.0 .5ppg 25# Linear Gel/30Q CO2 65 4595.0

365.0 Pad 25# Linear Gel/30Q CO2 66 4632.0

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

260 1,393

FET ANALYSIS

90 Frac Grad:

Fluid Type

41

4,146

FLUIDS PUMPED PROPPANT PUMPED

Liner Top Depth 6,204'

28

237.4 238.0 MAXIMUM PRESSURE

1-2spf

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

2/2/2010 4:58:00 PM 6:59:00 PM

7"
Stage #: 2 Formation: 1st Caballos

Stimulation Company:

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

Pipe 1 Size: Pipe 2 Size: Top Perf: 6,204' Bottom Perf: 6,390'

Displ Coef: 

SPF: Total # of Holes: 90

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

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

2.00 16,077 20/40 Ottawa

3.00 23,892 20/40 Ottawa

4.00 13,369 20/40 Ottawa

4.00 22,959 20/40 SBXL

76,297

Remarks/Notes

741.0

4834.0

130.0 4ppg 25# Linear Gel/30Q CO2 71 5083.0

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

238.0 Flush 4% Cryst. KCL Water

86.0 4ppg 25# Linear Gel/30Q CO2 72

133.0 3ppg 25# Linear Gel/30Q CO2 72 4886.0

154.0 2ppg 25# Linear Gel/30Q CO2 71 4878.0

1-2spf

237.4 238.0 MAXIMUM PRESSURE

PROPPANT PUMPED

0 0

FLUIDS PUMPED (CONTINUED FROM PAGE 1)

Liner Depth 6,204'

2/2/2010 4:58:00 PM

7"

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

6:59:00 PM

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14
Stage #: 1 Formation: Tesnus

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250'

Displ Coef: 

SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls

5,700 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi

Holes Open: Fluid Eff: (%) 5 min SIP: psi

Max Rate: Calc. Perm: mD 10 min SIP: psi

Max Pressure: Pc (psig) psi 15 min SIP: psi

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

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa

2.0 14,795 20/40 Ottawa

2.5 20,083 20/40 Ottawa

3.0 18,988 20/40 Ottawa

4.0 21,642 20/40 Ottawa

4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS 

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm

ISIP = 3,400 psig

Yes 2.0

No 4

250

FET ANALYSIS

Frac Grad:

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

Avg Treating Press= Maximum = 

X-Link Breaker Time: n/a

FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum = 

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes

If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in

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

Foam Quality: Amount of Foam Pumped: 400 Type of foam:

Type of Proppant: 20/40 Ottawa, 20/40 SLC

Total Fluid Pumped: 441

Total Proppant: 97,100

57.0 4% Crystalline KCl 3,726 30.0

53.0 3,541 38.1

43.0 3,544 38.2

42.0 3,896 38.4

32.0 3,873 37.1

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

16.0 2,560 2.0

40.0 3,882 38.0

56.0 3,292 38.0

22.0 3,485 38.8

35.0 3,507 37.0

20# Linear gel, 80Q CO2

12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7

4% Crystalline KCl

20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2

3,125

Displ Coef: 0.0383

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report

1 sec (or 2 sec) data in .csv of .txt form

Service Company Treatment Report

Service Company Field Ticket

areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com;

mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com;

tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com;

scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com
Stage #: 3 Formation: Tesnus

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 5,728' Bottom Perf: 5,796'

Displ Coef: 

SPF: Total # of Holes: 50

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi

Holes Open: Fluid Eff: (%) 5 min SIP: psi

Max Rate: Calc. Perm: mD 10 min SIP: psi

Max Pressure: Pc (psig) psi 15 min SIP: psi

Conc. (ppg) Weight (lbs) Type

1.00 11,751 20/40 Ottawa

1.00 7,588 20/40 Ottawa

2.00 10,492 20/40 Ottawa

2.50 14,176 20/40 Ottawa

3.00 12,642 20/40 Ottawa

4.00 15,301 20/40 Ottawa

4.00 8,283 20/40 SLC

BBLS Gal LTR: 31500.0 Gals

LBS 

30 % tons CO2

3,676 psig 4153 psig

49.8 bpm 53.9 bpm

ISIP = 3,057 psig

No

No

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

Avg Treating Press= Maximum = 

Avg Treating Rate = Maximum = 

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

hours before flowing back.

Remarks/Notes

Was well flowed back immediately? If not, well was shut-in

Total Fluid Pumped: 750

Total Proppant: 80,233

Continue on next page if necessary

*71,950# 20/40 Ottawa, *8283# 20/40 SLC

Foam Quality: Amount of Foam Pumped: 185DH/10CD Type of foam:

Type of Proppant:

X-Link Breaker Time:

34.0 4ppg 20# Linear Gel/70Q CO2 52 3545.0

32.0 4ppg 20# Linear Gel/70Q CO2 52 3489.0

219.0 Flush 4% Cryst. KCL Water 43 3447.0

44.0 2ppg 20# Linear Gel/70Q CO2 52 3692.0

57.0 1ppg 20# Linear Gel/75Q CO2 51 3753.0

29.0 3ppg 20# Linear Gel/70Q CO2 52 3483.0

43.0 2.5ppg 20# Linear Gel/70Q CO2 52 3602.0

109.0 Pad 20# Linear Gel/85Q CO2 49 3956.0

51.0 Load & BD 20# Linear Gel 15 3845.0

61.0 Pad 20# Linear Gel/80Q CO2 47 3622.0

71.0 1ppg 20# Linear Gel/80Q CO2 50 4167.0

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

1,747 3,845

FET ANALYSIS

Frac Grad:

Fluid Type

FLUIDS PUMPED PROPPANT PUMPED

Liner Top Depth 5,728'

219.2 219.0 MAXIMUM PRESSURE

1-2spf

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

2/20/2010 10:15:00 AM 10:15:00 AM

7"
Stage #: 3 Formation: Tesnus

Stimulation Company:

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

Pipe 1 Size: Pipe 2 Size: Top Perf: 5,728' Bottom Perf: 5,796'

Displ Coef: 

SPF: Total # of Holes: 50

Displacement to top perf: bbls Actual Displacement: bbls

7,900 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

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

Remarks/Notes

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

1-2spf

219.2 219.0 MAXIMUM PRESSURE

PROPPANT PUMPED

1,747 3,845

FLUIDS PUMPED (CONTINUED FROM PAGE 1)

Liner Depth 5,728'

2/20/2010 10:15:00 AM

7"

SandRidge Supervisor(s): Johnny Anaya Superior

Displ Coef: 0.0383

10:15:00 AM

SandRidge Energy, inc.

Treatment Report

Well Name: West Ranch 45-14
Stage #: 1 Formation: Tesnus

Stimulation Company:

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

Casing Size: Liner Size: Top Perf: 5,200' Bottom Perf: 5,250'

Displ Coef: 

SPF: Total # of Holes: 100

Displacement to top perf: bbls Actual Displacement: bbls

5,700 psi

Initial Casing Pressure: psi Breakdown Pressure: psi

Total Holes: psi/ft ISDP: psi

Holes Open: Fluid Eff: (%) 5 min SIP: psi

Max Rate: Calc. Perm: mD 10 min SIP: psi

Max Pressure: Pc (psig) psi 15 min SIP: psi

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

1.0 3,900 20/40 Ottawa

1.0 9,592 20/40 Ottawa

2.0 14,795 20/40 Ottawa

2.5 20,083 20/40 Ottawa

3.0 18,988 20/40 Ottawa

4.0 21,642 20/40 Ottawa

4.0 8,100 20/40 SLC

Continue on next page if necessary

BBLS BLTR: 18522.0 Gals

LBS 

70 - 85 % tons CO2

n/a

3,450 psig 3950 psig

38.0 bpm 42 bpm

ISIP = 3,400 psig

Yes 2.0

No 4

250

FET ANALYSIS

Frac Grad:

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

Avg Treating Press= Maximum = 

X-Link Breaker Time: n/a

FLUIDS PUMPED PROPPANT PUMPED

20# Linear gel, 75Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

Avg Treating Rate = Maximum = 

Was Treatment Underdisplaced?

hours before flowing back.

Remarks/Notes

If so, by how many bbls/gal?

Was well flowed back immediately? If not, well was shut-in

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

Foam Quality: Amount of Foam Pumped: 400 Type of foam:

Type of Proppant: 20/40 Ottawa, 20/40 SLC

Total Fluid Pumped: 441

Total Proppant: 97,100

57.0 4% Crystalline KCl 3,726 30.0

53.0 3,541 38.1

43.0 3,544 38.2

42.0 3,896 38.4

32.0 3,873 37.1

20# Linear gel, 70Q CO2

20# Linear gel, 70Q CO2

16.0 2,560 2.0

40.0 3,882 38.0

56.0 3,292 38.0

22.0 3,485 38.8

35.0 3,507 37.0

20# Linear gel, 80Q CO2

12/22/2009 10:10:00 AM 12:36:00 PM

45.0 3,439 39.7

4% Crystalline KCl

20# Linear gel, 85Q CO2

20# Linear gel, 80Q CO2

3,125

Displ Coef: 0.0383

Liner Top Depth 0.5 - 2 SPF

7.000

199.2 198.0 MAXIMUM PRESSURE

SandRidge Energy, inc.

Well Name: Anywell 1-23

SandRidge Supervisor(s):

Treatment Report

Jason Stewart Superior Well Services
Distribution list for Frac Reports

Items to be sent

SandRidge Treatment Report

1 sec (or 2 sec) data in .csv of .txt form

Service Company Treatment Report

Service Company Field Ticket

areyna@sdrge.com; sfrazier@sdrge.com; rhughes@sdrge.com; jstewart@sdrge.com; sthompson@sdrge.com;

mfilippo@sdrge.com; rwilliams@sdrge.com; nasaad@sdrge.com; fgarbrecht@sdrge.com; fclausen@sdrge.com;

tbillingsley@sdrge.com; jchrisman@sdrge.com; bherrera@sdrge.com; cwatts@sdrge.com;

scoshow@sdrge.com; szielny@sdrge.com; wmcalister@sdrge.com
WELLBORE SCHEMATIC

GL: 4176 WELL NAME: WEST RANCH 45-14 SPOT: 1,821' FSL & 999' FWL ZONE: OPERATOR: SandRidge Energy

KB: 4196 CORPORATE ID: LOCATION: Sec 46, Blk 2, TC RR CO Survey, A-5222 GL: 4,176' SPUD DATE: 12/07/09

API NO: FIELD: Piňon KB: 4,196' RR DATE: 12/28/09

WI: COUNTY: Pecos TD: 6,810' MICU:

RI: STATE: Texas PBTD: 6,754' COMPL DATE:

PIPE RECORD CEMENT & HOLE DATA

CSG OD GRADE THD WT/FT TOP BTM # JTS BIT SZE DEPTH SXS TOC

Surf. 9.625'' J-55 LT&C 36.00# 0' 1,270' 33 12.250'' 1,270' 880 0'

Prod. 7.000'' P-110 LT&C 26.00# 0' 6,795' 174 8.750'' 6,810' 270 2,550' - CBL

Well tools: 

WELL HISTORY

DATE WORK DETAIL PROD. RESULTS

9-5/8" @ 1,270'

TOC @ 2,550'

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

Frac Job Remarks (Screenouts or problems in Frac job):

CIBP Record

Date Depth Type

Remarks:

Downhole Jewelry (Bottom to top)

Length Depth Description ID Drift Collapse* Burst* Tensile*

Material (Lone Star Steel Handbook) (in) (in) (psi) (psi) (Klbs)

'' #

'' #

9.625'' J-55 LT&C 36# 8.921 8.765 2,020 3,520 453

7'' P-110 LT&C 26# 6.276 6.151 6,230 9,950 693

'' #

* Safety Factor Not Included

REMARKS

ENGINEER: J. Stewart

GEOLOGIST: J. Lynch

LANDMAN:

PREPARED BY: J. Stewart

PBTD @ 6,754' PREPARED DATE: 12/29/2009 UPDATED:

7" @ 6,795' UPDATED: J. Henderson UPDATED:

TD @ 6,810' UPDATED: 2/1/2010 UPDATED:

Packer Detail:

Temperature: 145° F at 6,780' - OH Logs

Marker joints at 5,620' and 5,972'

 TUBULAR GOODS PERFORMANCE

Date Removed Notes

Prem. Plus "C", Halliburton Prem. Lite

50:50 Poz:Prem. H

CURRENT

1st Caballos, Tesnus

102924

42-371-38606

95.01%

71.78%

TYPE
WELLBORE SCHEMATIC

GL: 4176 WELL NAME: WEST RANCH 45-14 SPOT: 1,821' FSL & 999' FWL ZONE: OPERATOR: SandRidge Energy

KB: 4196 CORPORATE ID: LOCATION: Sec 46, Blk 2, TC RR CO Survey, A-5222 GL: 4,176' SPUD DATE: 12/07/09

API NO: FIELD: Piňon KB: 4,196' RR DATE: 12/28/09

WI: COUNTY: Pecos TD: 6,810' MICU:

RI: STATE: Texas PBTD: 6,754' COMPL DATE:

PIPE RECORD CEMENT & HOLE DATA

CSG OD GRADE THD WT/FT TOP BTM # JTS BIT SZE DEPTH SXS TOC

Surf. 9.625'' J-55 LT&C 36.00# 0' 1,270' 33 12.250'' 1,270' 880 0'

Prod. 7.000'' P-110 LT&C 26.00# 0' 6,795' 174 8.750'' 6,810' 270 2,550' - CBL

Well tools: 

WELL HISTORY

DATE WORK DETAIL PROD. RESULTS

9-5/8" @ 1,270' 01/30/10 Perforate 1st Caballos 6470 - 6596.

02/01/10

02/02/10 Re-frac 1st Caballos 6470 - 6596 with 95M lbs 20/40 Ottawa and CRC in 25# linear gel, 30Q CO2. 

02/04/10

02/05/10

02/13/10

02/18/10

02/20/10

02/22/10

02/28/10

03/01/10

05/28/10

09/21/10

08/04/11

TOC @ 2,550'

Long String Short String

Depth Depth

Wireline Entry Guide 5,756' Wireline Entry Guide

1.791" ID XN-nipple (trimmed for CO2 service) 1 jt 2-3/8" 4.7# L-80 tbg (with TDC)

4' x 2-3/8" 4.7# L-80 sub 1.791" ID XN-nipple

6,177' Arrowset 1-X packer (trimmed for CO2 service) 172 jts 2-3/8" 4.7# L-80 tbg (with TDC)

T-2 on/off tool with 1.875" ID X-profile

1 jt 2-3/8" 4.7# L-80 tbg

1.875" ID X-nipple (trimmed for CO2 service)

193 jts 2-3/8" 4.7# L-80 tbg

3' x 2-3/8" 4.7# L-80 sub

1 jt 2-3/8" 4.7# L-80 tbg

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

2/1/10 1st Cab 57 3250 25# linear, 30Q CO2 30/50 Ottawa 57 / 4862 0.84 / 3946 01/30/10 6,470' 6,480' 1st Caballos 1 SPF / 60° Active

2/2/10 1st Cab 65 1933 25# linear, 30Q CO2 20/40 Ottawa 60 / 5612 / 5502 01/30/10 6,500' 6,520' 1st Caballos 1 SPF / 60° Active

2/2/10 1st Cab 149 3760 25# linear, 30Q CO2 20/40 Ottawa 70 / 4833 0.84 / 4520 01/30/10 6,566' 6,596' 1st Caballos 2 SPF / 60° Active

2/20/10 Tesnus 80 750 20# linear, 70Q CO2 20/40 Ottawa 50 / 3676 / 3057

02/02/10 6,204' 6,214' 1st Caballos 1 SPF / 60° Active

Frac Job Remarks (Screenouts or problems in Frac job): 02/02/10 6,240' 6,260' 1st Caballos 1 SPF / 60° Active

Stage 1 (6470 - 6596) - lost frac pumps & went to flush early 02/02/10 6,360' 6,390' 1st Caballos 2 SPF / 60° Active

Plug Record 02/18/10 5,728' 5,758' 1st Caballos 1 SPF / 60° Active

Date Depth Type 02/18/10 5,786' 5,796' 1st Caballos 2 SPF / 60° Active

2/2/10 6,420' CBP

2/2/10 3,642' CBP

2/20/10 5,830' CBP

Remarks:

CBP set @ 3,642' - hung up at 4,680', pulled up and stuck, had to set high .

Downhole Jewelry (Bottom to top)

Length Depth Description ID Drift Collapse* Burst* Tensile*

Material (Lone Star Steel Handbook) (in) (in) (psi) (psi) (Klbs)

'' #

5,728' '' #

5,796' 9.625'' J-55 LT&C 36# 8.921 8.765 2,020 3,520 453

SS EOT @ 5756' 7'' P-110 LT&C 26# 6.276 6.151 6,230 9,950 693

LS EOT @ 6191' '' #

Pkr @ 6,177' * Safety Factor Not Included

6,204' REMARKS

6,390'

ENGINEER: J. Stewart

6,470' GEOLOGIST: J. Lynch

6,596' LANDMAN:

PREPARED BY: J. Stewart

PBTD @ 6625' PREPARED DATE: 12/29/2009 UPDATED:

7" @ 6,795' UPDATED: J. Henderson 3/17/2010 UPDATED:

TD @ 6,810' UPDATED: UPDATED:

Temperature: 145° F at 6,780' - OH Logs

Marker joints at 5,620' and 5,972'

Packer Detail:

 TUBULAR GOODS PERFORMANCE

2/22/2010 isolate lower intervals during uphole frac

2/5/2010 isolate lower intervals during uphole frac

2/4/2010 isolate lower intervals during uphole frac

Date Removed Notes

Tubing Configuration

Description Description

Set CBP @ 5830 and perforate Tesnus 5728 - 5758. 

Frac Tesnus 5728 - 5758 with 80M lbs 20/40 Ottawa and 20/40 SLC in 20# linear gel, 70Q CO2. 

Land long string @ 6191.

Land short string @ 5756.

Lower: Slickline. Ran 1.5" bailer & tagged TD @ 6625'. Left flwg to sales. 1210 MCF; FTP - 400 psi; SICP - N/A. 

Upper: Lowered dual WH. Inst conventional plngr system. Slickline. Ran broach to nipple @ 5710'. Dropped ball/seat spring & 

2-pad plngr; chased to btm. Cycled to sales. 

Lower: Inst intermitter. 

Drill out CBP at 6420. Clean out to 6744. PU to 6493 and land tubing, pump off bit.

Pulled tubing. 

CURRENT

1st Caballos, Tesnus

102924

42-371-38606

95.01%

Set CBP at 6420 and perforate 1st Caballos 6204 - 6390. 

Frac 1st Caballos 6204 - 6390 with 149M lbs 100 Mesh, 30/50 Ottawa, 20/40 Ottawa and 20/40 SB Excel in 25# linear gel, 30Q CO2. 

Set CBP at 3642 (hung up at 4680, pulled up and stuck, had to set high). 

Drill out CBP at 3642.

8.22.11 MF

50:50 Poz:Prem. H

71.78%

TYPE

Prem. Plus "C", Halliburton Prem. Lite

Drill out CBP at 5830.

Frac 1st Caballos 6470 - 6596 with 57M lbs 100 Mesh, 30/50 Ottawa and 20/40 Ottawa in 25# linear gel, 30Q CO2. 

Lost frac pumps and went to flush early.
Lariat

Report Date: 1/4/2010

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

28

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time Operations Next 24 Hours

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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-In (lb/gal) MW-Out (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. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used Total on Location

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 1/3/2010

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

27

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time Operations Next 24 Hours

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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-In (lb/gal) MW-Out (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. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used Total on Location

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 1/2/2010

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

26

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time Operations Next 24 Hours

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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-In (lb/gal) MW-Out (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. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used Total on Location

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 1/1/2010

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

25

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time Operations Next 24 Hours

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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-In (lb/gal) MW-Out (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. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used Total on Location

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/31/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

24

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time Operations Next 24 Hours

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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-In (lb/gal) MW-Out (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. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used Total on Location

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/30/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

23

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time Operations Next 24 Hours

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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-In (lb/gal) MW-Out (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. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used Total on Location

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/29/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

22

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time Operations Next 24 Hours

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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-In (lb/gal) MW-Out (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. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used Total on Location

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/28/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

21

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Rig Released

Operations Next 24 Hours

Rig Released

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 09:30 4.50 4.50 Trip - LDDP 6,810 6,810 TOH laying down pipe & BHA, Service 

Break Kelly

09:30 18:00 8.50 13.00 Prod 

Csg/Cmt

6,810 6,810 M/U Csg Shoe & Float Collar, Check 

Floats, Run 174 joints of 7", P-110, 26 lb, 

LTC casing, Shoe @ 6795'.

18:00 18:30 0.50 13.50 Prod 

Csg/Cmt

6,810 6,810 Rig Down Csg Crew & L/D Truck, R/U Cmt 

Head & Steel lines

18:30 19:30 1.00 14.50 C&C 

Hole/Mud

6,810 6,810 Circ hole with rig pumps

19:30 22:00 2.50 17.00 Prod 

Csg/Cmt

6,810 Mix & Pump 270 sks of Premium 50/50 Poz 

(H) with .7% Halad-9, 1% Salt, .3% 

Econolite, 2lbm Pheno-seal, .1% HR-800, 

Density 14.2 ppg, Yield 1.32 cf/sk, Mix H20 

Ratio 6.06 gal/sk, Volumn 336 cu/ft. 

Displace Cmt with 259 bbls of 2% KCI 

water. Bump plug with 500 psi over final 

circ pressure of 1300 psi

22:00 00:00 2.00 19.00 Prod 

Csg/Cmt

Nipple Down Set full string weight, 177,000 

lbs, on C-22 slips, Cut off casing

00:00 02:30 2.50 21.50 Prod 

Csg/Cmt

Install "B" section & test

02:30 05:00 2.50 24.00 Rig Up & 

Down

Clean Pits, Rig released @ 05:00

Air/Mud Data

MW-In (lb/gal)

11.30

MW-Out (lb/gal) 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)

5.2

Cake (/32")

1

pH

8.5

Solids (%)

17

LGS (%)

6

MBT (lb/bbl) Oil (%)

3

H20 (%)

80

Chlor (mg/L)

170,000

Ca (mg/L)

380

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.3

ECD (lb/gal)

11.66

LCM

Hole Volume (bbl)

522.1

Pit Volume (bbl)

253.0

Storage Volume (bbl)

0.0

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

Production 7 26.00 P-110 6,795

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

Diesel Fuel

Received Used

435

Total on Location

4205

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total

350,640

Field Est To Date

1,411,690

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/27/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

20

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

L/D Drill Pipe

Operations Next 24 Hours

L/D Drill Pipe, Run & Cmt Casing

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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 Trip - Logs 6,810 6,810 Pull Wear Bushing

05:30 12:00 6.50 7.00 Logging 6,810 6,810 R/U & Run Open Hole Logs, Run #1; 

Spectra Gamma Ray, Neutron, Density, 

Dual Laterolog, Micro Laterolog, 

Compensated Sonic, Log up f/6780'

12:00 12:30 0.50 7.50 Rtn. Maint. 6,810 6,810 Service Rig

12:30 19:00 6.50 14.00 Logging 6,810 6,810 Run Log #2; Compact Imager

19:00 19:30 0.50 14.50 Logging 6,810 6,810 R/D Loggers (Notify TRRC @ 19:30 of 

intent to run 7" csg and cmt. Spoke to 

Sara, Operator #3)

19:30 00:00 4.50 19.00 Trip - LDDP 6,810 6,810 TIH with Bit # 10 RR 6 on slick assembly

00:00 01:00 1.00 20.00 C&C 

Hole/Mud

6,810 6,810 Circ Btm up

01:00 05:00 4.00 24.00 Trip - LDDP 6,810 6,810 L/D 6 sgls, pump slug, TOH laying down 

pipe

Air/Mud Data

MW-In (lb/gal)

11.10

MW-Out (lb/gal) Vis (s/qt)

47

PV (cp)

20.0

YP (lbf/100ft2)

25

Gel 10 sec

9

Gel 10 min

14

Gel 30 min

18

Filtrate (mL/30min)

5.0

Cake (/32")

1

pH

8.4

Solids (%)

16

LGS (%)

6

MBT (lb/bbl) Oil (%)

3

H20 (%)

81

Chlor (mg/L)

170,000

Ca (mg/L)

380

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.3

ECD (lb/gal)

11.47

LCM

Hole Volume (bbl)

522.1

Pit Volume (bbl)

400.0

Storage Volume (bbl)

187.0

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) 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 # 10 RR 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,810

Out (ftKB)

6,810

Drld (ftKB)

0

Drl Hrs (hrs)

0.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A E 0 NO TD

WOB (min) (1000lbf) WOB (max) (1000lbf) BHA ROP (ft/hr) SPP (psi) Motor RPM (rpm) RPM (rpm)

PU (max) (1000lbf)

265

SO (1000lbf)

135

Off-Btm Str Wt (1000lbf)

175

Drag (1000lbf)

90

Start (ftKB)

6,810

End (ftKB)

6,810

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

WOB (min) (1000lbf)

50

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

8

SPP (psi)

125.0

Motor RPM (rpm) RPM (rpm)

45

PU (max) (1000lbf)

265

SO (1000lbf)

135

Off-Btm Str Wt (1000lbf)

175

Drag (1000lbf)

90

Start (ftKB)

6,810

End (ftKB)

6,810

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #10, 8 3/4 Slick

BHA No.

10

Drill String Name

8 3/4 Slick

Length (ft)

1,325.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.32

21 HWDP 5 271.50 643.65

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.00

1 DC 6 1/2 271.50 2.85

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

171 4.50 16.60 X-95 4.5 XO

Diesel Fuel

Received Used

435

Total on Location

4640

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total

46,021

Field Est To Date

1,061,050

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/26/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,810

Footage (ftKB)

113

Drill Hrs (hrs)

16.50

Avg ROP (ft/hr)

6.8

DFS

19

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

R/U Wireline

Operations Next 24 Hours

Wireline Logs, Wiper trip

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 10:30 5.50 5.50 Dir Rotate 6,697 6,729 Rot 32 ft, 50 wob, 45 rpm, 314 gpm 5.8

10:30 11:00 0.50 6.00 Srvys 6,729 6,729 Devation Survey @ 6684' 17.6 Inc, 301.9 Azi

11:00 15:30 4.50 10.50 Dir Rotate 6,729 6,761 Rot 32 ft, 50 wob, 45 rpm, 314 gpm 7.11

15:30 16:00 0.50 11.00 Rtn. Maint. 6,761 6,761 Service Rig

16:00 22:30 6.50 17.50 Dir Rotate 6,761 6,810 Rot 49 ft, 50 wob, 45 rpm, 314 gpm 7.5

22:30 23:30 1.00 18.50 C&C 

Hole/Mud

6,810 6,810 Circ Btm Up

23:30 04:00 4.50 23.00 Trip - Logs 6,810 6,810 Pump out 6 sgls, Pump Slug, Trip out for 

Logs

04:00 04:30 0.50 23.50 Trip - Logs 6,810 6,810 Brk Bit, L/D Monel & Motor

04:30 05:00 0.50 24.00 Rtn. Maint. 6,810 6,810 Service Rig

Air/Mud Data

MW-In (lb/gal)

11.00

MW-Out (lb/gal) Vis (s/qt)

43

PV (cp)

19.0

YP (lbf/100ft2)

23

Gel 10 sec

8

Gel 10 min

12

Gel 30 min

15

Filtrate (mL/30min)

4.8

Cake (/32")

1

pH

8.4

Solids (%)

16

LGS (%)

6

MBT (lb/bbl) Oil (%)

3

H20 (%)

81

Chlor (mg/L)

170,000

Ca (mg/L)

380

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.4

ECD (lb/gal)

11.33

LCM

Hole Volume (bbl)

509.5

Pit Volume (bbl)

400.0

Storage Volume (bbl)

250.0

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

6740 100 13 15 Max Gas @ 6710'

6780 90 10 10 15

6790 90 10 9

6800 70 30 7

6810 70 30 6

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

WOB (min) (1000lbf)

50

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

8

SPP (psi)

125.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

265

SO (1000lbf)

135

Off-Btm Str Wt (1000lbf)

175

Drag (1000lbf)

90

Start (ftKB)

6,697

End (ftKB)

6,810

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Bit Run # 7

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5164450

Jets (/32")

16/16/16

In (ftKB)

6,123

Out (ftKB)

6,327

Drld (ftKB)

204

Drl Hrs (hrs)

31.00

ROP (ft/hr)

6.6

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A 2 0 SD PP

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

6,716 19.20 308.40

6,747 20.80 313.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #9, 8 3/4 Steerable

BHA No.

9

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.08

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.31

21 HWDP 5 271.50 643.60

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.01

1 MWD/NMDC 6 1/2 271.50 29.85

1 UBHO 6 1/2 271.50 2.58

1 Great White 1.83 0.16 6 1/2 31.00 22.28

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

170 4.50 16.60 X-95 4.5 XO 5,401

Diesel Fuel

Received Used

1015

Total on Location

5075

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,500

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

26,892

Field Est To Date

1,015,029

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/25/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,697

Footage (ftKB)

121

Drill Hrs (hrs)

14.50

Avg ROP (ft/hr)

8.3

DFS

18

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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 Trip for Bit 6,576 6,576 Trip for bit, Brk Bit, Lay down motor

08:00 09:00 1.00 4.00 Trip for Bit 6,576 6,576 Pick up & test new motor, M/U bit #9,

09:00 12:00 3.00 7.00 Trip for Bit 6,576 6,576 Trip in hole w/bit #9

12:00 13:30 1.50 8.50 Excess 

Ream

6,576 6,576 Ream f/ 6475 to 6576'

13:30 19:30 6.00 14.50 Dir Rotate 6,576 6,634 Brk in Bit, Rot 58 ft, 60 wob, 45 rpm, 314 

gpm

10

19:30 20:00 0.50 15.00 Srvys 6,634 6,634 Deviation Survey @ 6589, 15.2 Inc, 287.0 

Azi

20:00 00:30 4.50 19.50 Dir Rotate 6,634 6,666 Rot 32 ft, 60 wob, 45 rpm, 314 gpm 7.1

00:30 01:00 0.50 20.00 Rtn. Maint. 6,666 6,666 Service Rig

01:00 05:00 4.00 24.00 Dir Rotate 6,666 6,697 Rot 31 ft, 60 wob, 45 rpm, 314 gpm 7.75

Air/Mud Data

MW-In (lb/gal)

11.10

MW-Out (lb/gal) Vis (s/qt)

44

PV (cp)

20.0

YP (lbf/100ft2)

24

Gel 10 sec

8

Gel 10 min

13

Gel 30 min

18

Filtrate (mL/30min)

5.0

Cake (/32")

1

pH

8.6

Solids (%)

16

LGS (%)

6

MBT (lb/bbl) Oil (%)

4

H20 (%)

80

Chlor (mg/L)

170,000

Ca (mg/L)

380

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.4

ECD (lb/gal)

11.62

LCM

Hole Volume (bbl)

415.1

Pit Volume (bbl)

400.0

Storage Volume (bbl)

250.0

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

6660 20 10 70 15 57 Trip gas from 6576'

6670 20 10 70 16 15

6680 20 10 70 14

6690 20 10 70 14

Bit Run # 9

Size (in)

8 3/4

Model

GX-E44C

Make

Hughes

SN

6075378

Jets (/32")

16/16/16

In (ftKB)

6,576

Out (ftKB)

6,810

Drld (ftKB)

234

Drl Hrs (hrs)

31.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

3 3 WT A E 1 NO TD

WOB (min) (1000lbf)

50

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

8

SPP (psi)

125.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

265

SO (1000lbf)

135

Off-Btm Str Wt (1000lbf)

175

Drag (1000lbf)

85

Start (ftKB)

6,576

End (ftKB)

6,697

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

Bit Run # 7

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5164450

Jets (/32")

16/16/16

In (ftKB)

6,123

Out (ftKB)

6,327

Drld (ftKB)

204

Drl Hrs (hrs)

31.00

ROP (ft/hr)

6.6

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A 2 0 SD PP

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,398 19.60 290.40

6,461 18.90 291.20

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

6,589 15.20 287.00

6,621 15.40 291.80

6,652 16.60 296.80

6,684 17.60 301.90

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #9, 8 3/4 Steerable

BHA No.

9

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.08

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 271.50 1.48

9 DP 5 271.50 274.31

21 HWDP 5 271.50 643.60

1 XO Sub 6 1/2 271.50 1.56

1 Jars - 

Hydraulic

6 1/2 271.50 31.66

12 DC 6 1/2 295.50 369.01

1 MWD/NMDC 6 1/2 271.50 29.85

1 UBHO 6 1/2 271.50 2.58

1 Great White 1.83 0.16 6 1/2 31.00 22.28

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

166 4.50 16.60 X-95 4.5 XO 5,275

Diesel Fuel

Received Used

1015

Total on Location

6090

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,500

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

42,612

Field Est To Date

988,136

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/24/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,576

Footage (ftKB)

153

Drill Hrs (hrs)

20.50

Avg ROP (ft/hr)

7.5

DFS

17

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Trip for Bit

Operations Next 24 Hours

TFB, Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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 6,423 6,443 Rot 20 ft, 60 wob, 45 rpm, 314 gpm 6.6

08:00 08:30 0.50 3.50 Srvys 6,443 6,443 Deviation Survey @ 6398'

08:30 11:30 3.00 6.50 Dir Sliding 6,443 6,463 Slide 20 ft, 65 wob, 330 gpm, GTF 180 6.6

11:30 12:30 1.00 7.50 Dir Rotate 6,463 6,475 Rot 12 ft, 60 wob, 45 rpm, 314 gpm 12

12:30 13:00 0.50 8.00 Rtn. Maint. 6,475 6,475 Service Rig

13:00 15:30 2.50 10.50 Dir Sliding 6,475 6,490 Slide 15 ft, 65 wob, 330 gpm, GTF 180 6

15:30 21:00 5.50 16.00 Dir Rotate 6,490 6,538 Rot 56 ft, 60 wob, 45 rpm, 314 gpm 8.7

21:00 21:30 0.50 16.50 Srvys 6,538 6,538 Deviation Survey @ 6493'

21:30 03:00 5.50 22.00 Dir Rotate 6,538 6,576 Rot 38 ft, 60 wob, 45 rpm, 314 gpm 7

03:00 04:00 1.00 23.00 C&C 

Hole/Mud

6,576 6,576 Circ Btm Up prior to TFB

04:00 04:30 0.50 23.50 Trip for Bit 6,576 6,576 Pump out 5 Sgls, Pump Slug

04:30 05:00 0.50 24.00 Trip for Bit 6,576 6,576 Trip out for bit

Air/Mud Data

MW-In (lb/gal)

11.00

MW-Out (lb/gal) Vis (s/qt)

43

PV (cp)

19.0

YP (lbf/100ft2)

23

Gel 10 sec

8

Gel 10 min

12

Gel 30 min

15

Filtrate (mL/30min)

4.8

Cake (/32")

1

pH

8.8

Solids (%)

16

LGS (%)

6

MBT (lb/bbl) Oil (%)

4

H20 (%)

80

Chlor (mg/L)

170,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.5

ECD (lb/gal)

11.51

LCM

Hole Volume (bbl)

408.8

Pit Volume (bbl)

400.0

Storage Volume (bbl)

250.0

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

6470 100 12

6540 100 10 13 Max Gas @ 6526

6550 100 9

6560 100 7

6570 100 7

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

WOB (min) (1000lbf)

60

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

8

SPP (psi)

125.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

245

SO (1000lbf)

130

Off-Btm Str Wt (1000lbf)

171

Drag (1000lbf)

74

Start (ftKB)

6,423

End (ftKB)

6,576

Bit Run # 7

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5164450

Jets (/32")

16/16/16

In (ftKB)

6,123

Out (ftKB)

6,327

Drld (ftKB)

204

Drl Hrs (hrs)

31.00

ROP (ft/hr)

6.6

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A 2 0 SD PP

Bit Run # 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,049

Out (ftKB)

6,123

Drld (ftKB)

74

Drl Hrs (hrs)

15.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A 1 0 NO PP

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,271 19.90 287.00

6,303 20.20 288.50

6,334 20.30 290.00

6,366 19.90 291.60

6,398 19.60 290.40

6,461 18.90 291.20

6,493 16.80 288.60

6,525 16.20 287.00

6,557 15.30 285.90

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #8, 8 3/4 Steerable

BHA No.

8

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.12

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 240.50 1.48

9 DP 5 240.50 274.31

21 HWDP 5 240.50 643.60

1 XO Sub 6 1/2 240.50 1.56

1 Jars - 

Hydraulic

6 1/2 240.50 31.66

12 DC 6 1/2 261.50 369.01

1 MWD/NMDC 6 1/2 240.50 29.85

1 UBHO 6 1/2 240.50 2.58

1 Great White 1.83 0.16 6 1/2 33.00 22.32

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

163 4.50 16.60 X-95 XH 5,179

Diesel Fuel

Received Used

1015

Total on Location

7105

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,350

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

28,182

Field Est To Date

945,525

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/23/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,423

Footage (ftKB)

100

Drill Hrs (hrs)

13.50

Avg ROP (ft/hr)

7.4

DFS

16

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

TIH W/ Bit # 8

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 06:00 1.00 1.00 Dir Sliding 6,323 6,327 Slide 4 ft, 65 wob, 320 gpm, GTF 180 4

06:00 06:30 0.50 1.50 C&C 

Hole/Mud

6,327 6,327 Circ Btm Up, Build Slug

06:30 10:00 3.50 5.00 Trip for Bit 6,327 LD 6 Jts, TOH W/ Bit # 7

10:00 11:00 1.00 6.00 Trip for Bit Change out Mtr and UBHO,Test Mtr

11:00 14:00 3.00 9.00 Trip for Bit TIH W/ Bit # 8

14:00 16:00 2.00 11.00 Trip for Bit Wash and ream F/ 6140 to 6327

16:00 18:00 2.00 13.00 Dir Sliding 6,327 6,337 Slide 10 ft, 65 wob, 330 gpm, GTF 180 5

18:00 19:00 1.00 14.00 Dir Rotate 6,337 6,348 Rot 11 ft, 60 wob, 45 rpm, 314 gpm 11

19:00 19:30 0.50 14.50 Srvys 6,348 6,348 Survey @ 6303, 20.2 inc, 288.5 azi

19:30 23:00 3.50 18.00 Dir Rotate 6,348 2,379 Rot 31 ft, 60 wob, 45 rpm, 314 gpm 8.8

23:00 02:00 3.00 21.00 Dir Sliding 2,379 6,399 Slide 20 ft, 65 wob, 330 gpm, GTF 180 6.6

02:00 05:00 3.00 24.00 Dir Rotate 6,399 6,423 Rot 24 ft, 60 wob, 45 rpm, 314 gpm 8

Air/Mud Data

MW-In (lb/gal)

11.10

MW-Out (lb/gal)

11.10

Vis (s/qt)

43

PV (cp)

20.0

YP (lbf/100ft2)

23

Gel 10 sec

8

Gel 10 min

12

Gel 30 min

16

Filtrate (mL/30min)

4.8

Cake (/32")

1

pH

8.4

Solids (%)

17

LGS (%)

6

MBT (lb/bbl) Oil (%)

4

H20 (%)

80

Chlor (mg/L)

170,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.0

Mf (mL/mL)

0.4

ECD (lb/gal)

11.61

LCM

Hole Volume (bbl)

402.5

Pit Volume (bbl)

400.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

6327 10 10 80 13

6420 100 14 38

Bit Run # 8

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5163415

Jets (/32")

16/16/16

In (ftKB)

6,327

Out (ftKB)

6,576

Drld (ftKB)

249

Drl Hrs (hrs)

33.00

ROP (ft/hr)

7.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A E 2 CT TQ 2 chipped teeth on outer row #1 cone, 

Shirt tail wear

WOB (min) (1000lbf)

60

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

8

SPP (psi)

125.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

245

SO (1000lbf)

130

Off-Btm Str Wt (1000lbf)

171

Drag (1000lbf)

74

Start (ftKB)

6,327

End (ftKB)

6,423

Bit Run # 7

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5164450

Jets (/32")

16/16/16

In (ftKB)

6,123

Out (ftKB)

6,327

Drld (ftKB)

204

Drl Hrs (hrs)

31.00

ROP (ft/hr)

6.6

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A 2 0 SD PP

WOB (min) (1000lbf)

60

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

7

SPP (psi)

125.0

Motor RPM (rpm) RPM (rpm)

45

PU (max) (1000lbf)

245

SO (1000lbf)

125

Off-Btm Str Wt (1000lbf)

170

Drag (1000lbf)

75

Start (ftKB)

6,323

End (ftKB)

6,327

Bit Run # 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,049

Out (ftKB)

6,123

Drld (ftKB)

74

Drl Hrs (hrs)

15.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A 1 0 NO PP

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,144 18.10 292.00

6,176 18.60 292.40

6,208 19.60 291.30

6,239 20.00 290.20

6,271 19.90 287.00

6,303 20.20 288.50

6,334 20.30 290.00

6,366 19.90 291.60

6,398 19.60 290.40

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #8, 8 3/4 Steerable

BHA No.

8

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.12

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 240.50 1.48

9 DP 5 240.50 274.31

21 HWDP 5 240.50 643.60

1 XO Sub 6 1/2 240.50 1.56

1 Jars - 

Hydraulic

6 1/2 240.50 31.66

12 DC 6 1/2 261.50 369.01

1 MWD/NMDC 6 1/2 240.50 29.85

1 UBHO 6 1/2 240.50 2.58

1 Great White 1.83 0.16 6 1/2 33.00 22.32

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

158 4.50 16.60 X-95 XH 5,020

Diesel Fuel

Received Used

1015

Total on Location

8120

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,350

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

36,953

Field Est To Date

917,342

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/22/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,323

Footage (ftKB)

147

Drill Hrs (hrs)

22.50

Avg ROP (ft/hr)

6.5

DFS

15

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 05:30 0.50 0.50 Dir Rotate 6,176 6,189 Rot 13 ft, 60 wob, 45 rpm, 314 gpm, 26

05:30 06:00 0.50 1.00 Rtn. Maint. 6,189 6,189 Service Rig

06:00 15:00 9.00 10.00 Dir Rotate 6,189 6,253 Rot 64 ft, 60 wob, 45 rpm, 314 gpm 7.1

15:00 15:30 0.50 10.50 Rtn. Maint. 6,253 6,253 Service Rig

15:30 19:30 4.00 14.50 Dir Sliding 6,253 6,273 Slide 20 ft, 65 wob, 230 gpm, GTF 135 L 5

19:30 02:30 7.00 21.50 Dir Rotate 6,273 6,316 Rot 43 ft, 60 wob, 45 rpm, 314 gpm 6

02:30 03:00 0.50 22.00 Rtn. Maint. 6,316 6,316 Service Rig

03:00 05:00 2.00 24.00 Dir Sliding 6,316 6,323 Slide 7 ft, 65 wob, 230 gpm, GTF 180 3.5

Air/Mud Data

MW-In (lb/gal)

11.10

MW-Out (lb/gal)

11.40

Vis (s/qt)

45

PV (cp)

20.0

YP (lbf/100ft2)

24

Gel 10 sec

8

Gel 10 min

14

Gel 30 min

16

Filtrate (mL/30min)

4.6

Cake (/32")

1

pH

8.4

Solids (%)

17

LGS (%)

5

MBT (lb/bbl) Oil (%)

2

H20 (%)

81

Chlor (mg/L)

170,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.0

Mf (mL/mL)

0.4

ECD (lb/gal)

11.95

LCM

Hole Volume (bbl)

390.0

Pit Volume (bbl)

420.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

6190 10 90 14

6233 100 13

6310 10 10 80 15 19

Bit Run # 7

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5164450

Jets (/32")

16/16/16

In (ftKB)

6,123

Out (ftKB)

6,327

Drld (ftKB)

204

Drl Hrs (hrs)

31.00

ROP (ft/hr)

6.6

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A 2 0 SD PP

WOB (min) (1000lbf)

60

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

7

SPP (psi)

125.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

245

SO (1000lbf)

125

Off-Btm Str Wt (1000lbf)

170

Drag (1000lbf)

75

Start (ftKB)

6,176

End (ftKB)

6,323

Bit Run # 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,049

Out (ftKB)

6,123

Drld (ftKB)

74

Drl Hrs (hrs)

15.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A 1 0 NO PP

Bit Run # 5

Size (in)

8 3/4

Model

EQH 22 R

Make

Security DBS

SN

11151622

Jets (/32")

16/16/16

In (ftKB)

5,433

Out (ftKB)

6,049

Drld (ftKB)

616

Drl Hrs (hrs)

46.50

ROP (ft/hr)

13.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

8 8 BT A 4 0 LT PR

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

6,048 17.80 285.30

6,080 18.20 287.50

6,112 18.40 289.70

6,144 18.10 292.00

6,176 18.60 292.40

6,208 19.60 291.30

6,239 20.00 290.20

6,271 19.90 287.00

6,303 20.20 288.50

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #7, 8 3/4 Steerable

BHA No.

7

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.54

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 207.50 1.48

9 DP 5 207.50 274.31

21 HWDP 5 207.50 643.60

1 XO Sub 6 1/2 207.50 1.56

1 Jars - 

Hydraulic

6 1/2 207.50 31.66

12 DC 6 1/2 228.50 369.01

1 MWD/NMDC 6 1/2 207.50 29.85

1 UBHO 6 1/2 207.50 2.52

1 Great White 1.83 0.16 6 1/2 46.00 22.55

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

155 4.50 16.60 X-95 XH 4,925

Diesel Fuel

Received Used

870

Total on Location

9135

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,350

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

37,918

Field Est To Date

880,389

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/21/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,176

Footage (ftKB)

84

Drill Hrs (hrs)

14.00

Avg ROP (ft/hr)

6.0

DFS

14

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

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. 6,092 6,092 Service Rig

05:30 06:00 0.50 1.00 Dir Rotate 6,092 6,094 Rot 2 ft, 60 wob, 45 rpm, 314 gpm 2

06:00 07:00 1.00 2.00 Dir Sliding 6,094 6,096 Slide 2 ft, 65 wob, 320 gpm, GTF 180 2

07:00 12:00 5.00 7.00 Dir Rotate 6,096 6,123 Rot 27 ft, 60 wob, 45 rpm, 314 gpm, 5.4

12:00 13:00 1.00 8.00 C&C 

Hole/Mud

6,123 Circ, Btm up Build Slug

13:00 16:30 3.50 11.50 Trip for Bit LD 5 Jts, TOH W/ Bit # 6

16:30 17:00 0.50 12.00 Trip for Bit Break bit test mtr, MU bit # 7

17:00 17:30 0.50 12.50 Rtn. Maint. Service rig

17:30 20:00 2.50 15.00 Trip for Bit TIH W/ Bit # 7

20:00 21:00 1.00 16.00 Trip for Bit Wash and Ream F/ 6017 to 6123

21:00 02:30 5.50 21.50 Dir Rotate 6,123 6,157 Rot 34 ft, 60 wob, 45 rpm, 314 gpm 6

02:30 03:00 0.50 22.00 Srvys 6,157 6,157 Survey @ 6112 18.4 inc, 289.7 azi

03:00 05:00 2.00 24.00 Dir Rotate 6,157 6,176 Rot 19 ft, 60 wob, 45 rpm, 314 gpm 9.5

Air/Mud Data

MW-In (lb/gal)

11.30

MW-Out (lb/gal)

11.40

Vis (s/qt)

50

PV (cp)

22.0

YP (lbf/100ft2)

26

Gel 10 sec

8

Gel 10 min

18

Gel 30 min

26

Filtrate (mL/30min)

5.0

Cake (/32")

1

pH

8.3

Solids (%)

17

LGS (%)

5

MBT (lb/bbl) Oil (%)

2

H20 (%)

81

Chlor (mg/L)

171,000

Ca (mg/L)

360

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.0

Mf (mL/mL)

0.3

ECD (lb/gal)

11.92

LCM

Hole Volume (bbl)

383.7

Pit Volume (bbl)

420.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

6100 100 11

6123 100 14

6170 10 90 12

Bit Run # 7

Size (in)

8 3/4

Model

HR---S 55 RG

Make

Hughes

SN

5164450

Jets (/32")

16/16/16

In (ftKB)

6,123

Out (ftKB)

6,327

Drld (ftKB)

204

Drl Hrs (hrs)

31.00

ROP (ft/hr)

6.6

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

5 5 WT A 2 0 SD PP

WOB (min) (1000lbf)

60

WOB (max) (1000lbf)

60

BHA ROP (ft/hr)

7

SPP (psi)

125.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

245

SO (1000lbf)

125

Off-Btm Str Wt (1000lbf)

165

Drag (1000lbf)

75

Start (ftKB)

6,123

End (ftKB)

6,176

Bit Run # 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,049

Out (ftKB)

6,123

Drld (ftKB)

74

Drl Hrs (hrs)

15.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A 1 0 NO PP

WOB (min) (1000lbf)

55

WOB (max) (1000lbf)

55

BHA ROP (ft/hr)

5

SPP (psi)

100.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

240

SO (1000lbf)

120

Off-Btm Str Wt (1000lbf)

165

Drag (1000lbf)

75

Start (ftKB)

6,092

End (ftKB)

6,123

Bit Run # 5

Size (in)

8 3/4

Model

EQH 22 R

Make

Security DBS

SN

11151622

Jets (/32")

16/16/16

In (ftKB)

5,433

Out (ftKB)

6,049

Drld (ftKB)

616

Drl Hrs (hrs)

46.50

ROP (ft/hr)

13.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

8 8 BT A 4 0 LT PR

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

5,920 17.20 280.80

5,952 18.00 281.60

5,983 18.70 283.50

6,017 18.10 284.00

6,048 17.80 285.30

6,080 18.20 287.50

6,112 18.40 289.70

6,144 18.10 292.00

6,176 18.60 292.40

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #7, 8 3/4 Steerable

BHA No.

7

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.54

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 207.50 1.48

9 DP 5 207.50 274.31

21 HWDP 5 207.50 643.60

1 XO Sub 6 1/2 207.50 1.56

1 Jars - 

Hydraulic

6 1/2 207.50 31.66

12 DC 6 1/2 228.50 369.01

1 MWD/NMDC 6 1/2 207.50 29.85

1 UBHO 6 1/2 207.50 2.52

1 Great White 1.83 0.16 6 1/2 46.00 22.55

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

150 4.50 16.60 X-95 XH 4,766

Diesel Fuel

Received Used

870

Total on Location

10005

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,350

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

37,345

Field Est To Date

842,471

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/20/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,092

Footage (ftKB)

66

Drill Hrs (hrs)

11.00

Avg ROP (ft/hr)

6.0

DFS

13

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 05:30 0.50 0.50 Dir Sliding 6,026 6,030 Slide 4 ft, 65 wob, 320 gpm, GTF 180 8

05:30 07:30 2.00 2.50 Dir Rotate 6,030 6,049 Rot, 19 ft, 55 wob, 45 rpm, 314 gpm 9.5

07:30 08:30 1.00 3.50 C&C 

Hole/Mud

6,049 Circ, Btm Up Sample, Build Slug

08:30 12:30 4.00 7.50 Trip for Bit LD 6 Jts, TOH W/ Bit # 5

12:30 14:00 1.50 9.00 Trip for Bit LD Mtr, PU Mtr, Test Mtr & MWD,PU Bit # 6

14:00 17:30 3.50 12.50 Trip for Bit TIH W/ Bit # 6, Tagged @ 5700

17:30 19:30 2.00 14.50 Trip for Bit Wash and Ream F/ 5700 to 6049

19:30 20:00 0.50 15.00 Trip for Bit 6,049 6,049 Fan Btm, Start Pattern

20:00 22:00 2.00 17.00 Dir Rotate 6,049 6,062 Rot 13 ft, 55 wob, 45 rpm, 314 gpm, 6.5

22:00 22:30 0.50 17.50 Srvys 6,062 6,062 survey @ 6017, 18.1 inc, 284 azi

22:30 23:30 1.00 18.50 Dir Sliding 6,062 6,065 Slide 3 ft,65 wob, 320 gpm, GTF 150 L 3

23:30 05:00 5.50 24.00 Dir Rotate 6,065 6,092 Rot 27 ft, 60 wob, 45 rpm, 314 gpm 4.9

Air/Mud Data

MW-In (lb/gal)

11.70

MW-Out (lb/gal) Vis (s/qt)

47

PV (cp)

20.0

YP (lbf/100ft2)

24

Gel 10 sec

8

Gel 10 min

14

Gel 30 min

18

Filtrate (mL/30min)

4.9

Cake (/32")

1

pH

8.4

Solids (%)

18

LGS (%)

5

MBT (lb/bbl) Oil (%)

1

H20 (%)

81

Chlor (mg/L)

172,000

Ca (mg/L)

360

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.0

Mf (mL/mL)

0.5

ECD (lb/gal)

12.29

LCM

Hole Volume (bbl)

377.4

Pit Volume (bbl)

420.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

6049 70 30 12

6060 50 50 12

6080 100 11

6090 100 11

Bit Run # 6

Size (in)

8 3/4

Model

GX E44C

Make

Hughes

SN

5164768

Jets (/32")

16/16/16

In (ftKB)

6,049

Out (ftKB)

6,123

Drld (ftKB)

74

Drl Hrs (hrs)

15.00

ROP (ft/hr)

4.9

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A 1 0 NO PP

WOB (min) (1000lbf)

55

WOB (max) (1000lbf)

55

BHA ROP (ft/hr)

5

SPP (psi)

100.0

Motor RPM (rpm)

50

RPM (rpm)

45

PU (max) (1000lbf)

240

SO (1000lbf)

120

Off-Btm Str Wt (1000lbf)

165

Drag (1000lbf)

75

Start (ftKB)

6,049

End (ftKB)

6,092

Bit Run # 5

Size (in)

8 3/4

Model

EQH 22 R

Make

Security DBS

SN

11151622

Jets (/32")

16/16/16

In (ftKB)

5,433

Out (ftKB)

6,049

Drld (ftKB)

616

Drl Hrs (hrs)

46.50

ROP (ft/hr)

13.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

8 8 BT A 4 0 LT PR

WOB (min) (1000lbf)

50

WOB (max) (1000lbf)

50

BHA ROP (ft/hr)

13

SPP (psi)

150.0

Motor RPM (rpm) RPM (rpm)

40

PU (max) (1000lbf)

240

SO (1000lbf)

125

Off-Btm Str Wt (1000lbf)

165

Drag (1000lbf)

75

Start (ftKB)

6,026

End (ftKB)

6,049

Bit Run # 4

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126189

Jets (/32")

12/12/11/11/12/11/11

In (ftKB)

4,828

Out (ftKB)

5,433

Drld (ftKB)

604

Drl Hrs (hrs)

23.50

ROP (ft/hr)

25.7

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A X 0 NO PR

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

5,824 18.10 287.40

5,856 17.70 284.00

5,888 17.80 282.90

5,920 17.20 280.80

5,952 18.00 281.60

5,983 18.70 283.50

6,017 18.10 284.00

6,048 17.80 285.30

6,080 18.20 287.50

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #6, 8 3/4 Steerable

BHA No.

6

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.29

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 176.50 1.48

9 DP 5 176.50 274.31

21 HWDP 5 176.50 643.60

1 XO Sub 6 1/2 176.50 1.56

1 Jars - 

Hydraulic

6 1/2 176.50 31.66

12 DC 6 1/2 197.50 369.01

1 MWD/NMDC 6 1/2 176.50 29.85

1 UBHO 6 1/2 176.50 2.52

1 Great White 1.83 0.16 6 1/2 15.00 22.55

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

147 4.50 16.60 X-95 XH 4,670

Diesel Fuel

Received Used

763

Total on Location

10875

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,350

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

54,292

Field Est To Date

805,126

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/19/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

6,026

Footage (ftKB)

281

Drill Hrs (hrs)

21.50

Avg ROP (ft/hr)

13.1

DFS

12

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 05:30 0.50 0.50 Dir Rotate 5,745 5,750 Rot 5 ft, 55 wob, 45 rpm, 314 gpm 10

05:30 06:30 1.00 1.50 Dir Sliding 5,750 5,765 Slide 15 ft, 65 wob, 320 gpm, GTF 60 L 15

06:30 07:30 1.00 2.50 Dir Rotate 5,765 5,782 Rot 17 ft, 55 wob, 45 rpm, 314 gpm 17

07:30 08:00 0.50 3.00 Srvys 5,782 5,782 Survey @ 5729, 16* inc, 287.7 azi

08:00 12:30 4.50 7.50 Dir Rotate 5,782 5,846 Rot 64 ft, 55 wob, 45 rpm, 314 gpm 14.2

12:30 14:30 2.00 9.50 Dir Sliding 5,846 5,866 Slide 20 ft, 65 wob, 320 gpm, GTF 135 L 10

14:30 15:30 1.00 10.50 Dir Rotate 5,866 5,878 Rot 12 ft, 55 wob, 45 rpm, 314 gpm 12

15:30 16:00 0.50 11.00 Srvys 5,878 5,878 Survey @ 5824, 18.1* inc 287.4 azi

16:00 17:30 1.50 12.50 Dir Rotate 5,878 5,909 Rot, 31 ft, 55 wob, 45 rpm, 314 gpm 20

17:30 18:00 0.50 13.00 Rtn. Maint. 5,909 5,909 Service Rig

18:00 18:30 0.50 13.50 Rtn. Maint. 5,909 5,909 Service Rig

18:30 20:30 2.00 15.50 Dir Sliding 5,909 5,929 Slide 20 ft, 65 wob, 320 gpm, GTF 150 L 10

20:30 00:00 3.50 19.00 Dir Rotate 5,929 5,973 Rot 44 ft, 55 wob, 45 rpm, 314 gpm 12.6

00:00 00:30 0.50 19.50 Srvys 5,973 5,973 Syrvey @ 5920 17.2 inc, 280.8 azi

00:30 02:30 2.00 21.50 Dir Rotate 5,973 6,005 Rot 32 ft, 55 wob, 45 rpm, 314 gpm 16

02:30 05:00 2.50 24.00 Dir Sliding 6,005 6,026 Slide 16 ft, 65 wob, 320 gpm, GTF 180 6.4

Air/Mud Data

MW-In (lb/gal)

11.70

MW-Out (lb/gal)

11.70

Vis (s/qt)

50

PV (cp)

21.0

YP (lbf/100ft2)

26

Gel 10 sec

8

Gel 10 min

16

Gel 30 min

20

Filtrate (mL/30min)

4.8

Cake (/32")

1

pH

8.7

Solids (%)

18

LGS (%)

5

MBT (lb/bbl) Oil (%)

1

H20 (%)

81

Chlor (mg/L)

172,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.4

ECD (lb/gal)

12.32

LCM

Hole Volume (bbl)

358.5

Pit Volume (bbl)

400.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

SPR #2 49 stks. 500 psi

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

5720 10 90 201 201

5840 40 60 21 432

5910 100 22

6010 100 10

Bit Run # 5

Size (in)

8 3/4

Model

EQH 22 R

Make

Security DBS

SN

11151622

Jets (/32")

16/16/16

In (ftKB)

5,433

Out (ftKB)

6,049

Drld (ftKB)

616

Drl Hrs (hrs)

46.50

ROP (ft/hr)

13.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

8 8 BT A 4 0 LT PR

WOB (min) (1000lbf)

50

WOB (max) (1000lbf)

50

BHA ROP (ft/hr)

13

SPP (psi)

150.0

Motor RPM (rpm)

77

RPM (rpm)

40

PU (max) (1000lbf)

240

SO (1000lbf)

125

Off-Btm Str Wt (1000lbf)

165

Drag (1000lbf)

75

Start (ftKB)

5,745

End (ftKB)

6,026

Bit Run # 4

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126189

Jets (/32")

12/12/11/11/12/11/11

In (ftKB)

4,828

Out (ftKB)

5,433

Drld (ftKB)

604

Drl Hrs (hrs)

23.50

ROP (ft/hr)

25.7

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A X 0 NO PR

Bit Run # 3

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126418

Jets (/32")

11/11/11/11/11/11/11

In (ftKB)

3,427

Out (ftKB)

4,829

Drld (ftKB)

1,402

Drl Hrs (hrs)

34.00

ROP (ft/hr)

41.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 2 CT A X 0 WT TQ 5 Chipped Inserts

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

5,761 17.10 287.30

5,793 17.80 287.20

5,824 18.10 287.40

5,856 17.70 284.00

5,888 17.80 282.90

5,920 17.20 280.80

5,952 18.00 281.60

5,983 18.70 283.50

6,017 18.10 284.00

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #5, 8 3/4 Steerable

BHA No.

5

Drill String Name

8 3/4 Steerable

Length (ft)

1,383.87

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 161.50 1.48

9 DP 5 161.50 274.31

21 HWDP 5 161.50 643.60

1 XO Sub 6 1/2 161.50 1.56

1 Jars - 

Hydraulic

6 1/2 161.50 31.66

12 DC 6 1/2 182.50 369.01

1 MWD/NMDC 6 3/4 161.50 29.85

1 UBHO 6 1/2 161.50 2.52

1 Great White 1.83 0.24 6 1/2 70.50 29.13

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

145 4.50 16.60 X-95 XH 4,607

Diesel Fuel

Received Used

1015

Total on Location

5800

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

49

Q (gpm)

171

Pres (psi)

500

Stroke (in)

10.00

Slow ...

Yes

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,350

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

31,442

Field Est To Date

750,834

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/18/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

5,745

Footage (ftKB)

300

Drill Hrs (hrs)

21.50

Avg ROP (ft/hr)

14.0

DFS

11

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 09:00 4.00 4.00 Dir Rotate 5,445 5,496 Rot 51 ft, 55 wob, 45 rpm 314 gpm, 12.8

09:00 09:30 0.50 4.50 Srvys 5,496 5,496 Survey @ 5443, 14.9* inc, 282.8 azi

09:30 11:30 2.00 6.50 Dir Rotate 5,496 5,528 Rot 32 ft, 55 wob, 45 rpm, 314 gpm 16

11:30 12:00 0.50 7.00 Rtn. Maint. 5,528 5,528 Service Rig

12:00 17:00 5.00 12.00 Dir Rotate 5,528 5,591 Rot 63 ft, 55 wob, 45 rpm, 314 gpm 12.6

17:00 17:30 0.50 12.50 Srvys 5,591 5,591 Survey @ 5538, 14.5* inc, 282.3 azi

17:30 20:30 3.00 15.50 Dir Rotate 5,591 5,623 Rot ft, 55 wob, 45 rpm, 314 gpm 10.6

20:30 22:00 1.50 17.00 Dir Sliding 5,623 5,635 Slide, 12 ft, 55 wob, 320 gpm, GTF 30 R 8

22:00 02:00 4.00 21.00 Dir Rotate 5,635 5,687 Rot 52 ft, 55 wob, 45 rpm, 314 gpm 13

02:00 02:30 0.50 21.50 Srvys 5,687 5,687 Survey @ 5634, 15.3* inc, 283.6 azi

02:30 04:00 1.50 23.00 Dir Rotate 5,687 5,719 Rot 32 ft, 55 wob, 45 rpm, 314 gpm 21

04:00 04:30 0.50 23.50 Rtn. Maint. 5,719 5,719 Service Rig

04:30 05:00 0.50 24.00 Dir Rotate 5,719 5,745 Rot 26 ft, 55 wob, 45 rpm, 314 gpm 52

Air/Mud Data

MW-In (lb/gal)

11.70

MW-Out (lb/gal)

11.70

Vis (s/qt)

47

PV (cp)

22.0

YP (lbf/100ft2)

24

Gel 10 sec

8

Gel 10 min

14

Gel 30 min

18

Filtrate (mL/30min)

5.4

Cake (/32")

1

pH

8.3

Solids (%)

18

LGS (%)

5

MBT (lb/bbl) Oil (%)

1

H20 (%)

82

Chlor (mg/L)

171,000

Ca (mg/L)

440

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.0

Mf (mL/mL)

0.4

ECD (lb/gal)

12.32

LCM

Hole Volume (bbl)

339.6

Pit Volume (bbl)

410.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

5530 100 20

5700 100 16

Bit Run # 5

Size (in)

8 3/4

Model

EQH 22 R

Make

Security DBS

SN

11151622

Jets (/32")

16/16/16

In (ftKB)

5,433

Out (ftKB)

6,049

Drld (ftKB)

616

Drl Hrs (hrs)

46.50

ROP (ft/hr)

13.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

8 8 BT A 4 0 LT PR

WOB (min) (1000lbf)

50

WOB (max) (1000lbf)

50

BHA ROP (ft/hr)

13

SPP (psi)

150.0

Motor RPM (rpm)

77

RPM (rpm)

40

PU (max) (1000lbf)

240

SO (1000lbf)

125

Off-Btm Str Wt (1000lbf)

160

Drag (1000lbf)

80

Start (ftKB)

5,445

End (ftKB)

5,745

Bit Run # 4

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126189

Jets (/32")

12/12/11/11/12/11/11

In (ftKB)

4,828

Out (ftKB)

5,433

Drld (ftKB)

604

Drl Hrs (hrs)

23.50

ROP (ft/hr)

25.7

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A X 0 NO PR

Bit Run # 3

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126418

Jets (/32")

11/11/11/11/11/11/11

In (ftKB)

3,427

Out (ftKB)

4,829

Drld (ftKB)

1,402

Drl Hrs (hrs)

34.00

ROP (ft/hr)

41.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 2 CT A X 0 WT TQ 5 Chipped Inserts

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

12 5.00 43 4.5 IF 372 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

5,475 15.00 282.20

5,507 14.70 283.70

5,538 14.50 282.30

5,570 14.50 280.80

5,602 14.90 281.40

5,634 15.30 283.60

5,665 15.60 285.40

5,697 15.60 287.70

5,729 16.00 287.70

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #5, 8 3/4 Steerable

BHA No.

5

Drill String Name

8 3/4 Steerable

Length (ft)

1,383.87

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 161.50 1.48

9 DP 5 161.50 274.31

21 HWDP 5 161.50 643.60

1 XO Sub 6 1/2 161.50 1.56

1 Jars - 

Hydraulic

6 1/2 161.50 31.66

12 DC 6 1/2 182.50 369.01

1 MWD/NMDC 6 3/4 161.50 29.85

1 UBHO 6 1/2 161.50 2.52

1 Great White 1.83 0.24 6 1/2 70.50 29.13

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

136 4.50 16.60 X-95 XH 4,321

Diesel Fuel

Received Used

870

Total on Location

6815

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,450

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

36,779

Field Est To Date

719,392

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/17/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

5,445

Footage (ftKB)

124

Drill Hrs (hrs)

7.00

Avg ROP (ft/hr)

17.7

DFS

10

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

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 5,321 5,337 Rot 16 ft, 22 wob, 45 rpm, 314 gpm, 16

06:00 08:30 2.50 3.50 Dir Sliding 5,337 5,352 Slide 15 ft, 35 wob, 330 gpm, GTF 90 L 6

08:30 10:00 1.50 5.00 Dir Rotate 5,352 5,401 Rot, 49 ft, 22 wob, 45 rpm, 314 gpm 32

10:00 10:30 0.50 5.50 Srvys 5,401 5,401 Survey @ 5348, 16.3, 284.2 azi

10:30 11:30 1.00 6.50 Unplanned 5,401 5,401 Pump LCM Sweep, Plugged off Screens, 

Clean Screens

11:30 12:30 1.00 7.50 Dir Rotate 5,401 5,433 Rot, 32 ft, 22 wob, 45 rpm, 314 gpm 32

12:30 13:30 1.00 8.50 C&C 

Hole/Mud

5,433 Circ Btm Up Sample, Build Slug

13:30 14:00 0.50 9.00 Rtn. Maint. Service Rig

14:00 18:00 4.00 13.00 Trip for Bit LD 11 Jts, TOH W/ Bit # 4

18:00 19:00 1.00 14.00 Trip for Bit Break Bit, Test Mtr & MWD, MU Bit

19:00 21:00 2.00 16.00 Trip for Bit TIH W/ Bit # 5, Tag @ 3000

21:00 00:30 3.50 19.50 Excess 

Ream

Ream F/3000 to 3127

00:30 01:30 1.00 20.50 Trip for Bit TIH W/ Bit # 5, Tag @ 5197

01:30 03:30 2.00 22.50 Excess 

Ream

Wash and Ream F/ 5197 to 5433

03:30 04:00 0.50 23.00 Rtn. Maint. 5,433 5,433 Service Rig

04:00 05:00 1.00 24.00 Dir Sliding 5,433 5,445 Slide 12 ft, 50 wob, 320 gpm, GTF 135 L 12

Air/Mud Data

MW-In (lb/gal)

11.70

MW-Out (lb/gal)

11.70

Vis (s/qt)

47

PV (cp)

22.0

YP (lbf/100ft2)

26

Gel 10 sec

8

Gel 10 min

16

Gel 30 min

20

Filtrate (mL/30min)

5.0

Cake (/32")

1

pH

8.4

Solids (%)

18

LGS (%)

5

MBT (lb/bbl) Oil (%)

2

H20 (%)

82

Chlor (mg/L)

170,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.0

Mf (mL/mL)

0.4

ECD (lb/gal)

12.36

LCM

Hole Volume (bbl)

333.4

Pit Volume (bbl)

410.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

5433 70 30 18 40

Bit Run # 5

Size (in)

8 3/4

Model

EQH 22 R

Make

Security DBS

SN

11151622

Jets (/32")

16/16/16

In (ftKB)

5,433

Out (ftKB)

6,049

Drld (ftKB)

616

Drl Hrs (hrs)

46.50

ROP (ft/hr)

13.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

8 8 BT A 4 0 LT PR

WOB (min) (1000lbf)

50

WOB (max) (1000lbf)

50

BHA ROP (ft/hr)

13

SPP (psi)

150.0

Motor RPM (rpm)

77

RPM (rpm)

40

PU (max) (1000lbf)

240

SO (1000lbf)

125

Off-Btm Str Wt (1000lbf)

150

Drag (1000lbf)

75

Start (ftKB)

5,433

End (ftKB)

5,445

Bit Run # 4

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126189

Jets (/32")

12/12/11/11/12/11/11

In (ftKB)

4,828

Out (ftKB)

5,433

Drld (ftKB)

604

Drl Hrs (hrs)

23.50

ROP (ft/hr)

25.7

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A X 0 NO PR

WOB (min) (1000lbf)

35

WOB (max) (1000lbf)

35

BHA ROP (ft/hr)

26

SPP (psi)

175.0

Motor RPM (rpm)

72

RPM (rpm)

45

PU (max) (1000lbf)

220

SO (1000lbf)

120

Off-Btm Str Wt (1000lbf)

145

Drag (1000lbf)

75

Start (ftKB)

5,321

End (ftKB)

5,433

Bit Run # 3

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126418

Jets (/32")

11/11/11/11/11/11/11

In (ftKB)

3,427

Out (ftKB)

4,829

Drld (ftKB)

1,402

Drl Hrs (hrs)

34.00

ROP (ft/hr)

41.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 2 CT A X 0 WT TQ 5 Chipped Inserts

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

5,189 19.00 286.00

5,221 18.80 284.30

5,253 19.00 285.80

5,284 18.10 286.40

5,316 17.00 286.00

5,348 16.30 284.20

5,380 15.70 284.50

5,411 15.40 285.60

5,443 14.90 282.80

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #5, 8 3/4 Steerable

BHA No.

5

Drill String Name

8 3/4 Steerable

Length (ft)

1,383.87

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 161.50 1.48

9 DP 5 161.50 274.31

21 HWDP 5 161.50 643.60

1 XO Sub 6 1/2 161.50 1.56

1 Jars - 

Hydraulic

6 1/2 161.50 31.66

12 DC 6 1/2 182.50 369.01

1 MWD/NMDC 6 3/4 161.50 29.85

1 UBHO 6 1/2 161.50 2.52

1 Great White 1.83 0.24 6 1/2 70.50 29.13

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

127 4.50 16.60 X-95 XH 4,035

Diesel Fuel

Received Used

870

Total on Location

6815

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

89

Q (gpm)

310

Pres (psi)

1,450

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

39,769

Field Est To Date

682,613

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/16/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

5,321

Footage (ftKB)

493

Drill Hrs (hrs)

17.50

Avg ROP (ft/hr)

28.2

DFS

9

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

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 Excess 

Ream

4,829 4,829 Wash and Ream F/4734 to 4829

06:00 07:00 1.00 2.00 Dir Sliding 4,829 4,844 Slide 15 ft, 30 wob, 330 gpm, GTF 60 L 15

07:00 08:30 1.50 3.50 Dir Rotate 4,844 4,893 Rot 49 ft, 22 wob, 60 rpm, 320 gpm 33

08:30 10:30 2.00 5.50 Unplanned 4,893 4,893 Work tight hole

10:30 11:00 0.50 6.00 C&C 

Hole/Mud

4,893 4,893 Circ Btm Up, with some increase in 

returns,Gummy Shale

11:00 11:30 0.50 6.50 Dir Rotate 4,893 4,924 Rot 31, 22 wob, 60 rpm, 300 gpm 62

11:30 12:00 0.50 7.00 Srvys 4,924 4,924 Survey @ 4871, 16.4* inc, 285.4 azi

12:00 15:00 3.00 10.00 Dir Rotate 4,924 5,020 Rot 96 ft, 22 wob, 60 rpm, 300 gpm, Pump 

40 Brl LCM Sweep with some increase in 

cuttings return

32

15:00 15:30 0.50 10.50 Unplanned 5,020 5,020 Work tight hole

15:30 16:00 0.50 11.00 Srvys 5,020 5,020 Survey @ 4967, 15.8* inc, 282.2 azi

16:00 19:30 3.50 14.50 Dir Rotate 5,020 5,115 Rot 95 ft, 20 wob, 45 rpm, 300 gpm, 27

19:30 20:00 0.50 15.00 Srvys 5,115 5,115 Survey @ 5062, 16* inc, 283.5 azi

20:00 22:00 2.00 17.00 Dir Rotate 5,115 5,210 Rot, 95 ft, 20 wob, 45 rpm, 300 gpm 47

22:00 22:30 0.50 17.50 Srvys 5,210 5,210 Survey @ 5157, 17.3* inc, 287.3 azi

22:30 23:30 1.00 18.50 Dir Sliding 5,210 5,225 Slide 15 ft, 30 wob, 300 gpm, GTF 135 L 15

23:30 01:30 2.00 20.50 Dir Rotate 5,225 5,274 Rot 49 ft, 20 wob, 45 rpm, 300 gpm, 24

01:30 03:00 1.50 22.00 Dir Sliding 5,274 5,284 Slide 10 ft, 30 wob, 320 gpm, GTF 150 L 6.6

03:00 03:30 0.50 22.50 Dir Rotate 5,284 5,306 Rot 22 ft, 20 wob, 45 rpm, 300 gpm 44

03:30 04:00 0.50 23.00 Srvys 5,306 5,306 Survey @ 5253, 19* inc, 285.8 azi

04:00 05:00 1.00 24.00 Dir Sliding 5,306 5,321 Slide 15 ft, 40 wob, 330 gpm, GTF 150 L 15

Air/Mud Data

MW-In (lb/gal)

11.80

MW-Out (lb/gal)

11.90

Vis (s/qt)

52

PV (cp)

22.0

YP (lbf/100ft2)

30

Gel 10 sec

8

Gel 10 min

16

Gel 30 min

20

Filtrate (mL/30min) Cake (/32")

1

pH

8.3

Solids (%)

19

LGS (%) MBT (lb/bbl) Oil (%) H20 (%)

Chlor (mg/L) Ca (mg/L)

400

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. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

4950 100 11

5230 80 10 10

5270 80 10 10 15 21

5308 80 10 10 10

Bit Run # 4

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126189

Jets (/32")

12/12/11/11/12/11/11

In (ftKB)

4,828

Out (ftKB)

5,433

Drld (ftKB)

604

Drl Hrs (hrs)

23.50

ROP (ft/hr)

25.7

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A X 0 NO PR

WOB (min) (1000lbf)

35

WOB (max) (1000lbf)

35

BHA ROP (ft/hr)

26

SPP (psi)

175.0

Motor RPM (rpm)

72

RPM (rpm)

45

PU (max) (1000lbf)

220

SO (1000lbf)

120

Off-Btm Str Wt (1000lbf)

145

Drag (1000lbf)

75

Start (ftKB)

4,828

End (ftKB)

5,321

Bit Run # 3

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126418

Jets (/32")

11/11/11/11/11/11/11

In (ftKB)

3,427

Out (ftKB)

4,829

Drld (ftKB)

1,402

Drl Hrs (hrs)

34.00

ROP (ft/hr)

41.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 2 CT A X 0 WT TQ 5 Chipped Inserts

Bit Run # 2

Size (in)

8 3/4

Model

FX 55

Make

Security DBS

SN

11230914

Jets (/32")

12/12/12/12/12

In (ftKB)

1,300

Out (ftKB)

3,427

Drld (ftKB)

2,127

Drl Hrs (hrs)

57.50

ROP (ft/hr)

37.0

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

2 4 BT A X 0 WT TQ 8 Insert broken

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

5,062 16.00 283.50

5,094 16.40 285.50

5,126 16.50 286.40

5,157 18.00 287.20

5,189 19.00 286.00

5,221 18.80 284.30

5,253 19.00 285.80

5,284 18.10 286.40

5,316 17.00 286.00

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #4, 8 3/4 Steerable

BHA No.

4

Drill String Name

8 3/4 Steerable

Length (ft)

1,384.12

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 114.50 1.48

9 DP 5 114.50 274.31

21 HWDP 5 114.50 643.60

1 XO Sub 6 1/2 114.50 1.56

1 Jars - 

Hydraulic

6 1/2 114.50 31.66

12 DC 6 1/2 135.50 369.01

1 MWD/NMDC 6 3/4 114.50 29.85

1 UBHO 6 1/2 114.50 2.52

1 Great White 1.83 0.24 6 1/2 23.50 29.13

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

123 4.50 16.60 X-95 XH 5,908

Diesel Fuel

Received Used

870

Total on Location

7685

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

90

Q (gpm)

314

Pres (psi)

1,600

Stroke (in)

10.00

Slow ...

No

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total

30,535

Field Est To Date

642,844

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/15/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

4,828

Footage (ftKB)

545

Drill Hrs (hrs)

11.00

Avg ROP (ft/hr)

49.5

DFS

8

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

TIH With Bit # 4

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 05:30 0.50 0.50 Dir Sliding 4,283 4,293 Slide 10 ft, 25 wob, 330 gpm, GTF 180 20

05:30 06:30 1.00 1.50 Dir Rotate 4,293 4,347 Rot 54 ft, 20 wob, 60 rpm, 330 gpm 54

06:30 07:00 0.50 2.00 Srvys 4,347 4,347 Survey @ 4301, 13.4* inc, 281.7 azi

07:00 07:30 0.50 2.50 Dir Rotate 4,347 4,411 Rot 64 ft, 20 wob, 60 rpm, 330 gpm 64

07:30 08:00 0.50 3.00 Dir Sliding 4,411 4,426 Slide 15 ft, 25 wob, 330 gpm, GTF 90 L 30

08:00 08:30 0.50 3.50 Dir Rotate 4,426 4,442 Rot 16 ft, 20 wob, 60 rpm, 330 gpm 32

08:30 09:00 0.50 4.00 Srvys 4,442 4,442 Survey @ 4396, 14.4* inc, 283.3 azi

09:00 09:30 0.50 4.50 Dir Rotate 4,442 4,506 Rot 64 ft , 20 wob, 60 rpm, 330 gpm 64

09:30 10:00 0.50 5.00 Dir Sliding 4,506 4,521 Slide 15 ft, 25 wob, 330 gpm, GTF 90 L 30

10:00 10:30 0.50 5.50 Dir Rotate 4,521 4,537 Rot 16 ft, 20 wob, 60 rpm, 320 gpm 32

10:30 11:00 0.50 6.00 Srvys 4,537 4,537 Survey @ 4491, 16.2* inc, 280.8 azi

11:00 12:00 1.00 7.00 Dir Rotate 4,537 4,633 Rot 96 ft, 20 wob, 60 rpm, 320 gpm 96

12:00 12:30 0.50 7.50 Srvys 4,633 4,633 Survey @ 4587, 16.3* inc, 278.6 azi

12:30 14:30 2.00 9.50 Dir Rotate 4,633 4,728 Rot 95 ft, 23 wob, 60 rpm, 320 gpm 38

14:30 15:00 0.50 10.00 Srvys 4,728 4,728 Survey @ 4682, 16.1* inc, 281.8 azi

15:00 15:30 0.50 10.50 Dir Rotate 4,728 4,760 Rot 32 ft, 23 wob, 60 rpm, 320 gpm 64

15:30 16:00 0.50 11.00 Rtn. Maint. 4,760 4,760 Service Rig

16:00 18:30 2.50 13.50 Dir Rotate 4,760 4,823 Rot 63 ft, 23 wob, 60 rpm, 320 gpm 25

18:30 19:00 0.50 14.00 Srvys 4,823 4,823 Survey @ 4777, 15.5* inc, 287.7 azi

19:00 19:30 0.50 14.50 Dir Sliding 4,823 4,829 Slide 6 ft, 30 wob, 320 gpm, GTF 60 L 12

19:30 20:00 0.50 15.00 C&C 

Hole/Mud

4,829 Circ for sample and build slug

20:00 00:00 4.00 19.00 Trip - Mtr 

Failure

LD 4 Jts, TOH W/ Bit # 3, Tight F/ 3350 to 

3030

00:00 01:00 1.00 20.00 Trip - Mtr 

Failure

LD Mtr, PU new Mtr, Test Mtr & MWD, PU 

bit

01:00 02:00 1.00 21.00 Trip - Mtr 

Failure

TIH to Shoe

02:00 03:30 1.50 22.50 Rtn. Maint. Cut 120 ft drlg line, Service rig

03:30 05:00 1.50 24.00 Trip - Mtr 

Failure

TIH With Bit # 4

Air/Mud Data

MW-In (lb/gal)

11.60

MW-Out (lb/gal) Vis (s/qt)

48

PV (cp)

22.0

YP (lbf/100ft2)

26

Gel 10 sec

8

Gel 10 min

15

Gel 30 min

18

Filtrate (mL/30min)

4.8

Cake (/32")

1

pH

8.3

Solids (%)

18

LGS (%)

5

MBT (lb/bbl) Oil (%)

2

H20 (%)

80

Chlor (mg/L)

170,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.4

ECD (lb/gal)

12.42

LCM

Hole Volume (bbl)

295.6

Pit Volume (bbl)

415.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

4350 80 20 8

4825 40 60 8

Bit Run # 4

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126189

Jets (/32")

12/12/11/11/12/11/11

In (ftKB)

4,828

Out (ftKB)

5,433

Drld (ftKB)

604

Drl Hrs (hrs)

23.50

ROP (ft/hr)

25.7

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 1 WT A X 0 NO PR

WOB (min) (1000lbf)

35

WOB (max) (1000lbf)

35

BHA ROP (ft/hr)

26

SPP (psi) Motor RPM (rpm) RPM (rpm)

PU (max) (1000lbf)

220

SO (1000lbf)

120

Off-Btm Str Wt (1000lbf)

140

Drag (1000lbf)

55

Start (ftKB)

4,829

End (ftKB)

4,828

Bit Run # 3

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126418

Jets (/32")

11/11/11/11/11/11/11

In (ftKB)

3,427

Out (ftKB)

4,829

Drld (ftKB)

1,402

Drl Hrs (hrs)

34.00

ROP (ft/hr)

41.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 2 CT A X 0 WT TQ 5 Chipped Inserts

WOB (min) (1000lbf)

10

WOB (max) (1000lbf)

25

BHA ROP (ft/hr)

41

SPP (psi)

250.0

Motor RPM (rpm)

80

RPM (rpm)

60

PU (max) (1000lbf)

174

SO (1000lbf)

110

Off-Btm Str Wt (1000lbf)

130

Drag (1000lbf)

44

Start (ftKB)

4,283

End (ftKB)

4,829

Bit Run # 2

Size (in)

8 3/4

Model

FX 55

Make

Security DBS

SN

11230914

Jets (/32")

12/12/12/12/12

In (ftKB)

1,300

Out (ftKB)

3,427

Drld (ftKB)

2,127

Drl Hrs (hrs)

57.50

ROP (ft/hr)

37.0

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

2 4 BT A X 0 WT TQ 8 Insert broken

Survey Data

MD (ftKB) Incl (°) Azm (°)

4,555 16.70 277.10

4,587 16.30 278.60

4,618 16.10 278.90

4,650 16.00 279.80

4,682 16.10 281.80

4,714 15.90 282.10

4,746 15.80 285.50

4,777 15.50 287.70

4,808 15.60 286.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #4, 8 3/4 Steerable

BHA No.

4

Drill String Name

8 3/4 Steerable

Length (ft)

1,384.12

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 114.50 1.48

9 DP 5 114.50 274.31

21 HWDP 5 114.50 643.60

1 XO Sub 6 1/2 114.50 1.56

1 Jars - 

Hydraulic

6 1/2 114.50 31.66

12 DC 6 1/2 135.50 369.01

1 MWD/NMDC 6 3/4 114.50 29.85

1 UBHO 6 1/2 114.50 2.52

1 Great White 1.83 0.24 6 1/2 23.50 29.13

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

108 4.50 16.60 X-95 XH 3,431

Diesel Fuel

Received Used

1015

Total on Location

8555

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,400

Stroke (in)

10.00

Slow ...

No

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

88

Q (gpm)

307

Pres (psi)

1,450

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

51,004

Field Est To Date

612,310

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/15/2009

Spud Date: 12/7/2009

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/14/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

4,283

Footage (ftKB)

762

Drill Hrs (hrs)

20.00

Avg ROP (ft/hr)

38.1

DFS

7

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

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 3,521 3,553 Rot, 32 ft, 12 wob, 60 rpm, 330 gpm 21

06:30 07:00 0.50 2.00 Dir Sliding 3,553 3,573 Slide, 20 ft, 25 wob, 340 gpm, GTF 90 L 40

07:00 07:30 0.50 2.50 Dir Rotate 3,573 3,584 Rot, 11 ft, 12 wob, 60 rpm, 330 gpm 22

07:30 08:00 0.50 3.00 Srvys 3,584 3,584 Survey @ 3538, 16.4*inc 286.6 azi

08:00 09:30 1.50 4.50 Dir Rotate 3,584 3,648 Rot, 64 ft, 20 wob, 60 rpm, 330 gpm 32

09:30 10:00 0.50 5.00 Dir Sliding 3,648 3,668 Slide, 20 ft, 25 wob, 340 gpm, GTF 180 40

10:00 10:30 0.50 5.50 Dir Rotate 3,668 3,680 Rot, 12 ft, 20 wob, 60 rpm, 330 gpm 24

10:30 11:00 0.50 6.00 Srvys 3,680 3,680 Survey @ 3634, 17.3* inc, 282.7 azi

11:00 12:30 1.50 7.50 Dir Rotate 3,680 3,775 Rot, 95 ft, 20 wob, 60 rpm, 330 gpm 45

12:30 13:00 0.50 8.00 Srvys 3,775 3,775 Survey @ 3729, 14.6* inc, 283.5

13:00 13:30 0.50 8.50 Dir Rotate 3,775 3,807 Rot, 32 ft, 20 wob, 60 rpm, 330 gpm 64

13:30 14:00 0.50 9.00 Dir Sliding 3,807 3,822 Slide, 15 ft, 25 wob, 340 gpm, GTF 90 L 30

14:00 14:30 0.50 9.50 Dir Rotate 3,822 3,839 Rot, 17 ft, 20 wob, 60 rpm, 330 gpm 34

14:30 15:00 0.50 10.00 Rtn. Maint. 3,839 3,839 Service Rig

15:00 15:30 0.50 10.50 Dir Sliding 3,839 3,854 Slide, 15 ft, 25 wob, 340 gpm, GTF 180 up 30

15:30 16:00 0.50 11.00 Dir Rotate 3,854 3,870 Rot, 16 ft, 20 wob, 60 rpm, 330 gpm 32

16:00 16:30 0.50 11.50 Srvys 3,870 3,870 Survey @ 3824, 15.4* inc, 285.9 azi

16:30 17:00 0.50 12.00 Dir Sliding 3,870 3,885 Slide, 15 ft, 25 wob, 340 gpm, GTF 90 L 30

17:00 17:30 0.50 12.50 Dir Rotate 3,885 3,902 Rot, 17 ft, 20 wob, 60 rpm, 330 gpm 34

17:30 18:00 0.50 13.00 Dir Sliding 3,902 3,917 Slide, 15 ft, 25 wob, 340 gpm, GTF 90 L 38

18:00 19:00 1.00 14.00 Dir Rotate 3,917 3,966 Rot, 49 ft, 20 wob, 60 rpm, 330 gpm 49

19:00 19:30 0.50 14.50 Srvys 3,966 3,966 Survey @ 3920, 17.8* inc, 279.7 azi

19:30 20:00 0.50 15.00 Dir Sliding 3,966 3,981 Slide, 15 ft, 25 wob, 340 gpm, GTF 135 L 30

20:00 20:30 0.50 15.50 Dir Rotate 3,981 3,998 Rot, 17 ft 20 wob, 60 rpm, 330 gpm 34

20:30 21:00 0.50 16.00 Dir Sliding 3,998 4,013 Slide, 15 ft, 25 wob, 340 gpm, GTF 135 L 30

21:00 21:30 0.50 16.50 Dir Rotate 4,013 4,029 Rot,16 ft, 20 wob, 60 rpm, 330 gpm 32

21:30 22:00 0.50 17.00 Dir Sliding 4,029 4,039 Slide,10 ft, 25 wob, 340 gpm, GTF 180 20

22:00 23:30 1.50 18.50 Dir Rotate 4,039 4,125 Rot, 86 ft, 20 wob, 60 rpm, 330 gpm 57

23:30 00:00 0.50 19.00 Dir Sliding 4,125 4,140 Slide, 15 ft, 25 wob, 340 gpm, GTF 135 R 30

00:00 00:30 0.50 19.50 Dir Rotate 4,140 4,156 Rot, 16 ft, 20 wob, 60 rpm, 330 gpm 32

00:30 01:00 0.50 20.00 Srvys 4,156 4,156 Survey @ 4111, 17.5* inc, 265.6 azi

01:00 01:30 0.50 20.50 Dir Sliding 4,156 4,171 Slide, 15 ft, 25 wob, 340 gpm, GTF 90 R 30

01:30 03:30 2.00 22.50 Dir Rotate 4,171 4,252 Rot, 81 ft, 20 wob, 60 rpm, 330 gpm 40

03:30 04:00 0.50 23.00 Srvys 4,252 4,252 Survey @ 4207, 16* inc, 274.5 azi

04:00 04:30 0.50 23.50 Dir Sliding 4,252 4,267 Slide, 15 ft, 25 wob, 330 gpm, GTF 135 R 30

04:30 05:00 0.50 24.00 Dir Rotate 4,267 4,283 Rot, 16 ft, 20 wob, 60 rpm, 330 gpm 32

Air/Mud Data

MW-In (lb/gal)

11.65

MW-Out (lb/gal) Vis (s/qt)

47

PV (cp)

22.0

YP (lbf/100ft2)

25

Gel 10 sec

8

Gel 10 min

16

Gel 30 min

22

Filtrate (mL/30min)

5.0

Cake (/32")

1

pH

8.6

Solids (%)

18

LGS (%)

5

MBT (lb/bbl) Oil (%)

2

H20 (%)

80

Chlor (mg/L)

173,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.4

ECD (lb/gal)

12.35

LCM

Hole Volume (bbl)

232.7

Pit Volume (bbl)

390.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

3600 90 10 7

3780 100 13

4250 80 20 5

4275 70 30 8

Bit Run # 3

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126418

Jets (/32")

11/11/11/11/11/11/11

In (ftKB)

3,427

Out (ftKB)

4,829

Drld (ftKB)

1,402

Drl Hrs (hrs)

34.00

ROP (ft/hr)

41.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 2 CT A X 0 WT TQ 5 Chipped Inserts

WOB (min) (1000lbf)

10

WOB (max) (1000lbf)

25

BHA ROP (ft/hr)

41

SPP (psi)

250.0

Motor RPM (rpm)

80

RPM (rpm)

60

PU (max) (1000lbf)

174

SO (1000lbf)

110

Off-Btm Str Wt (1000lbf)

130

Drag (1000lbf)

44

Start (ftKB)

3,521

End (ftKB)

4,283

Bit Run # 2

Size (in)

8 3/4

Model

FX 55

Make

Security DBS

SN

11230914

Jets (/32")

12/12/12/12/12

In (ftKB)

1,300

Out (ftKB)

3,427

Drld (ftKB)

2,127

Drl Hrs (hrs)

57.50

ROP (ft/hr)

37.0

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

2 4 BT A X 0 WT TQ 8 Insert broken

Bit Run # 1

Size (in)

12 1/4

Model

C623G Hammer

Make SN

SN AC-123153

Jets (/32") In (ftKB)

59

Out (ftKB)

1,300

Drld (ftKB)

1,241

Drl Hrs (hrs)

20.50

ROP (ft/hr)

60.5

Survey Data

MD (ftKB) Incl (°) Azm (°)

4,015 17.30 268.50

4,047 16.70 266.00

4,079 17.00 265.90

4,110 17.50 265.60

4,142 16.20 267.00

4,174 15.30 272.10

4,206 16.00 274.50

4,237 16.30 274.80

4,269 14.80 278.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #3, 8 3/4 Steerable

BHA No.

3

Drill String Name

8 3/4 Steerable

Length (ft)

1,378.45

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 91.50 1.48

9 DP 5 91.50 274.31

21 HWDP 5 91.50 643.60

1 XO Sub 6 1/2 91.50 1.56

1 Jars - 

Hydraulic

6 1/2 91.50 31.66

12 DC 6 1/2 112.00 369.01

1 MWD/NMDC 6 1/2 91.50 29.85

1 UBHO 6 1/2 91.50 2.52

1 Great White 1.83 0.24 6 1/2 34.00 23.46

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

90 4.50 16.60 X-95 XH 2,859

Diesel Fuel

Received Used

870

Total on Location

9570

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,275

Stroke (in)

10.00

Slow ...

No

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,450

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

29,658

Field Est To Date

561,306

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/14/2009

Spud Date: 12/7/2009

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

0 0 WT A X 0 WT TD

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/13/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

3,521

Footage (ftKB)

383

Drill Hrs (hrs)

12.50

Avg ROP (ft/hr)

30.6

DFS

6

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 05:30 0.50 0.50 Dir Rotate 3,138 3,170 Rot, 14 wob, 45 rpm, 330 gpm 64

05:30 06:30 1.00 1.50 Unplanned 3,170 3,170 Work Tight Hole

06:30 07:00 0.50 2.00 Dir Rotate 3,170 3,202 Rot, 14 wob, 45 rpm, 320 gpm 64

07:00 07:30 0.50 2.50 Srvys 3,202 3,202 Survey @ 3157, 16.6* inc, 271.4 azi

07:30 08:30 1.00 3.50 Dir Rotate 3,202 3,234 Rot, 14 wob, 45 rpm, 320 gpm, 32

08:30 10:00 1.50 5.00 Dir Sliding 3,234 3,249 Slide, 26 wob, 340 gpm, GTF 90 R 7

10:00 11:00 1.00 6.00 Dir Rotate 3,249 3,297 Rot, 12 wob, 45 rpm, 330 gpm 48

11:00 11:30 0.50 6.50 Srvys 3,297 3,297 Survey @ 3252, 16* inc, 274.9 azi

11:30 13:00 1.50 8.00 Dir Rotate 3,297 3,361 Rot, 12 wob, 45 rpm, 330 gpm 42

13:00 14:30 1.50 9.50 Dir Sliding 3,361 3,376 Slide, 20 wob, 330 gpm, GTF 90 R 10

14:30 15:00 0.50 10.00 Dir Rotate 3,376 3,393 Rot, 12 wob, 45 rpm, 330 gpm 34

15:00 15:30 0.50 10.50 Srvys 3,393 3,393 Survey @ 3348, 15.8* inc, 277 azi

15:30 16:30 1.00 11.50 Dir Rotate 3,393 3,424 Rot, 12 wob, 45 rpm, 330 gpm 31

16:30 17:00 0.50 12.00 Dir Sliding 3,424 3,427 Slide, 20 wob, 340 gpm, GTF 70 R 6

17:00 17:30 0.50 12.50 Rtn. Maint. 3,427 Service Rig

17:30 18:00 0.50 13.00 C&C 

Hole/Mud

Circ Btm Up, Build Slug

18:00 20:30 2.50 15.50 Trip for Bit LD 5 Jts, TOH with Bit # 2

20:30 21:30 1.00 16.50 Trip for Bit LD mtr, PU new Mtr, test Mtr & MWD

21:30 00:00 2.50 19.00 Trip for Bit TIH W/ Bit # 3,

00:00 01:00 1.00 20.00 Trip for Bit Wash and Ream F/ 3284 to 3427

01:00 01:30 0.50 20.50 Dir Sliding 3,427 3,432 Slide, 20 wob, 340 gpm, GTF 45 R 10

01:30 02:30 1.00 21.50 Dir Rotate 3,432 3,457 Rot, 10 wob, 60 rpm, 330 gpm, 25

02:30 03:00 0.50 22.00 Rtn. Maint. 3,457 3,457 Service Rig

03:00 03:30 0.50 22.50 Dir Sliding 3,457 3,472 Slide, 25 wob, 340 gpm, TF Highside 30

03:30 04:00 0.50 23.00 Dir Rotate 3,472 3,489 Rot, 10 wob, 60 rpm, 330 gpm 34

04:00 04:30 0.50 23.50 Srvys 3,489 3,489 Survey @ 3443, 14.4* inc, 281.1 azi

04:30 05:00 0.50 24.00 Dir Rotate 3,489 3,521 Rot, 12 wob, 60 rpm, 330 gpm 63

Air/Mud Data

MW-In (lb/gal)

11.60

MW-Out (lb/gal) Vis (s/qt)

45

PV (cp)

22.0

YP (lbf/100ft2)

24

Gel 10 sec

8

Gel 10 min

14

Gel 30 min

16

Filtrate (mL/30min)

4.8

Cake (/32")

1

pH

8.8

Solids (%)

18

LGS (%)

5

MBT (lb/bbl) Oil (%)

2

H20 (%)

80

Chlor (mg/L)

172,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.4

ECD (lb/gal)

12.34

LCM

Hole Volume (bbl)

188.7

Pit Volume (bbl)

400.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

3210 80 10 10 15

3340 20 80 0 17

3440 50 50 8

3470 50 50 8 55

Bit Run # 3

Size (in)

8 3/4

Model

QD 505 F

Make

Hughes

SN

7126418

Jets (/32")

11/11/11/11/11/11/11

In (ftKB)

3,427

Out (ftKB)

4,829

Drld (ftKB)

1,402

Drl Hrs (hrs)

34.00

ROP (ft/hr)

41.2

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

1 2 CT A X 0 WT TQ 5 Chipped Inserts

WOB (min) (1000lbf)

10

WOB (max) (1000lbf)

25

BHA ROP (ft/hr)

41

SPP (psi)

175.0

Motor RPM (rpm)

80

RPM (rpm)

60

PU (max) (1000lbf)

174

SO (1000lbf)

110

Off-Btm Str Wt (1000lbf)

120

Drag (1000lbf)

10

Start (ftKB)

3,427

End (ftKB)

3,521

Bit Run # 2

Size (in)

8 3/4

Model

FX 55

Make

Security DBS

SN

11230914

Jets (/32")

12/12/12/12/12

In (ftKB)

1,300

Out (ftKB)

3,427

Drld (ftKB)

2,127

Drl Hrs (hrs)

57.50

ROP (ft/hr)

37.0

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

2 4 BT A X 0 WT TQ 8 Insert broken

WOB (min) (1000lbf)

8

WOB (max) (1000lbf)

20

BHA ROP (ft/hr)

37

SPP (psi)

200.0

Motor RPM (rpm)

96

RPM (rpm)

45

PU (max) (1000lbf)

130

SO (1000lbf)

105

Off-Btm Str Wt (1000lbf)

115

Drag (1000lbf)

15

Start (ftKB)

3,138

End (ftKB)

3,427

Bit Run # 1

Size (in)

12 1/4

Model

C623G Hammer

Make SN

SN AC-123153

Jets (/32") In (ftKB)

59

Out (ftKB)

1,300

Drld (ftKB)

1,241

Drl Hrs (hrs)

20.50

ROP (ft/hr)

60.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

0 0 WT A X 0 WT TD

Survey Data

MD (ftKB) Incl (°) Azm (°)

3,252 16.00 274.90

3,284 16.00 276.40

3,316 16.10 276.00

3,348 15.80 277.00

3,379 14.70 277.10

3,411 14.40 279.30

3,443 14.40 281.10

3,475 15.60 284.40

3,507 16.10 287.00

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #3, 8 3/4 Steerable

BHA No.

3

Drill String Name

8 3/4 Steerable

Length (ft)

1,378.45

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 91.50 1.48

9 DP 5 91.50 274.31

21 HWDP 5 91.50 643.60

1 XO Sub 6 1/2 91.50 1.56

1 Jars - 

Hydraulic

6 1/2 91.50 31.66

12 DC 6 1/2 112.00 369.01

1 MWD/NMDC 6 1/2 91.50 29.85

1 UBHO 6 1/2 91.50 2.52

1 Great White 1.83 0.24 6 1/2 34.00 23.46

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

66 4.50 16.60 X-95 XH 2,097

Diesel Fuel

Received Used

767

Total on Location

10440

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,450

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

59,473

Field Est To Date

531,648

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/13/2009

Spud Date: 12/7/2009

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/12/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

3,138

Footage (ftKB)

667

Drill Hrs (hrs)

19.50

Avg ROP (ft/hr)

34.2

DFS

5

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 06:00 1.00 1.00 Dir Sliding 2,471 2,491 Slide, 20 wob, 330 gpm, GTF 90 L 20

06:00 07:30 1.50 2.50 Dir Rotate 2,491 2,535 Rot, 16 wob, 45 rpm, 330 gpm 29.3

07:30 08:00 0.50 3.00 Srvys 2,535 2,535 Survey @ 2490, 8.5* inc, 315.6 azi

08:00 09:00 1.00 4.00 Dir Sliding 2,535 2,555 Slide, 20 wob, 330 gpm, GTF 90 L 20

09:00 10:30 1.50 5.50 Dir Rotate 2,555 2,598 Rot, 16 wob, 45 rpm, 330 gpm 28.6

10:30 11:00 0.50 6.00 Dir Sliding 2,598 2,618 Slide, 20 wob, 340 gpm, GTF 90 L 40

11:00 11:30 0.50 6.50 Dir Rotate 2,618 2,630 Rot, 14 wob, 45 rpm, 330 gpm 24

11:30 12:00 0.50 7.00 Srvys 2,630 2,630 Survey @ 2585, 10.8* inc, 304.1 azi

12:00 13:00 1.00 8.00 Dir Rotate 2,630 2,662 Rot, 14 wob, 45 rpm, 330 gpm 32

13:00 14:00 1.00 9.00 Dir Sliding 2,662 2,682 Slide, 20 wob, 340 gpm, GTF 130 L 20

14:00 14:30 0.50 9.50 Dir Rotate 2,682 2,694 Rot, 14 wob, 45 rpm, 330 gpm 24

14:30 15:00 0.50 10.00 Rtn. Maint. 2,694 2,694 Service Rig, Calibrate Block Height

15:00 15:30 0.50 10.50 Dir Rotate 2,694 2,725 Rot, 14 wob, 45 rpm, 330 gpm 62

15:30 16:00 0.50 11.00 Srvys 2,725 2,725 Survey @ 2680, 11.5* inc, 298.6 azi

16:00 17:00 1.00 12.00 Dir Rotate 2,725 2,757 Rot, 14 wob, 45 rpm, 330 gpm 64

17:00 17:30 0.50 12.50 Dir Sliding 2,757 2,772 Slide, 20 wob, 340 gpm, GTF 60 L 30

17:30 18:00 0.50 13.00 Dir Rotate 2,772 2,789 Rot, 14 wob, 45 rpm, 330 gpm 34

18:00 19:00 1.00 14.00 Dir Sliding 2,789 2,804 Slide, 20 wob, 340 gpm, GTF 90 L 15

19:00 19:30 0.50 14.50 Dir Rotate 2,804 2,821 Rot, 14 wob, 45 rpm, 330 gpm 34

19:30 20:00 0.50 15.00 Srvys 2,821 2,821 Survey @ 2776, 13.5* inc, 297.6 azi

20:00 20:30 0.50 15.50 Dir Sliding 2,821 2,836 Slide, 20 wob, 340 gpm, GTF 90 L 30

20:30 21:00 0.50 16.00 Dir Rotate 2,836 2,852 Rot, 14 wob, 45 rpm, 340 gpm 32

21:00 21:30 0.50 16.50 Dir Sliding 2,852 2,867 Slide, 22 wob, 340 gpm, GTF 90 L 30

21:30 22:00 0.50 17.00 Dir Rotate 2,867 2,884 Rot, 14 wob, 45 rpm, 330 gpm 34

22:00 22:30 0.50 17.50 Rtn. Maint. 2,884 2,884 Service Rig,

22:30 23:00 0.50 18.00 Dir Sliding 2,884 2,899 Slide, 22 wob, 340 gpm, GTF 110 L 30

23:00 23:30 0.50 18.50 Dir Rotate 2,899 2,916 Rot, 14 wob, 45 rpm, 330 gpm 34

23:30 00:00 0.50 19.00 Srvys 2,916 2,916 Syrvey @ 2871, 16.3* inc, 283.7 azi

00:00 00:30 0.50 19.50 Dir Sliding 2,916 2,931 Slide, 22 wob, 340 gpm, GTF 90 L 30

00:30 01:30 1.00 20.50 Dir Rotate 2,931 3,011 Rot, 14 wob, 45 rpm, 330 gpm 80

01:30 02:00 0.50 21.00 Srvys 3,011 3,011 Survey @ 2966, 16.8* inc, 274.5 azi

02:00 02:30 0.50 21.50 Dir Rotate 3,011 3,043 Rot, 15 wob, 45 rpm, 330 gpm 64

02:30 03:30 1.00 22.50 Dir Sliding 3,043 3,063 Slide, 22 wob, 340 gpm, GTF 120 L 20

03:30 04:00 0.50 23.00 Dir Rotate 3,063 3,107 Rot, 15 wob, 45 rpm, 330 gpm 88

04:00 04:30 0.50 23.50 Srvys 3,107 3,107 Survey @ 3062, 16.5* inc, 271.4 azi

04:30 05:00 0.50 24.00 Dir Rotate 3,107 3,138 Rot, 16 wob, 45 rpm, 330 gpm 62

Air/Mud Data

MW-In (lb/gal)

11.20

MW-Out (lb/gal) Vis (s/qt)

49

PV (cp)

20.0

YP (lbf/100ft2)

26

Gel 10 sec

8

Gel 10 min

14

Gel 30 min

18

Filtrate (mL/30min)

4.9

Cake (/32")

1

pH

8.8

Solids (%)

16

LGS (%)

5

MBT (lb/bbl) Oil (%)

1

H20 (%)

83

Chlor (mg/L)

172,000

Ca (mg/L)

400

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.4

ECD (lb/gal)

11.90

LCM

Hole Volume (bbl)

163.5

Pit Volume (bbl)

400.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

2500 10 90 11

2670 70 30 18

2990 80 20 20 55

3125 80 20 17

Bit Run # 2

Size (in)

8 3/4

Model

FX 55

Make

Security DBS

SN

11230914

Jets (/32")

12/12/12/12/12

In (ftKB)

1,300

Out (ftKB)

3,427

Drld (ftKB)

2,127

Drl Hrs (hrs)

57.50

ROP (ft/hr)

37.0

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

2 4 BT A X 0 WT TQ 8 Insert broken

WOB (min) (1000lbf)

8

WOB (max) (1000lbf)

20

BHA ROP (ft/hr)

37

SPP (psi)

200.0

Motor RPM (rpm)

98

RPM (rpm)

45

PU (max) (1000lbf)

130

SO (1000lbf)

105

Off-Btm Str Wt (1000lbf)

115

Drag (1000lbf)

15

Start (ftKB)

2,471

End (ftKB)

3,138

Bit Run # 1

Size (in)

12 1/4

Model

C623G Hammer

Make SN

SN AC-123153

Jets (/32") In (ftKB)

59

Out (ftKB)

1,300

Drld (ftKB)

1,241

Drl Hrs (hrs)

20.50

ROP (ft/hr)

60.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

0 0 WT A X 0 WT TD

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

Survey Data

MD (ftKB) Incl (°) Azm (°)

2,871 16.30 283.70

2,903 16.40 277.90

2,935 16.70 274.00

2,966 16.80 274.50

2,998 16.90 276.10

3,030 17.00 277.00

3,062 16.50 271.40

3,093 16.80 269.80

3,125 16.70 269.70

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #2, 8 3/4 Steerable

BHA No.

2

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.29

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 57.50 1.48

9 DP 5 57.50 274.31

21 HWDP 5 57.50 643.60

1 XO Sub 6 1/2 57.50 1.56

1 Jars - 

Hydraulic

6 1/2 57.50 31.66

12 DC 6 1/2 78.00 369.01

1 MWD/NMDC 6 1/2 57.50 29.85

1 UBHO 6 1/2 57.50 2.52

1 Great White 1.83 0.30 6 1/2 57.50 22.30

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

54 4.50 16.60 X-95 4 1/2 

XH

1,716

Diesel Fuel

Received

7,002.0

Used

1015

Total on Location

11207

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,275

Stroke (in)

10.00

Slow ...

No

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,200

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

31,062

Field Est To Date

472,175

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/12/2009

Spud Date: 12/7/2009

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/11/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

2,471

Footage (ftKB)

762

Drill Hrs (hrs)

19.00

Avg ROP (ft/hr)

40.1

DFS

4

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

Time Log

Start

Time

End

Time

Dur

(hrs)

Cum

Dur

(hrs) Ops Code

Dpth

Start

(ftKB)

Dpth

End

(ftKB) Description ROP

05:00 06:00 1.00 1.00 Dir Sliding 1,709 1,729 slide, 12 wob, 330 gpm, GTF 120 R. 20

06:00 07:00 1.00 2.00 Dir Rotate 1,729 1,772 Rot, 8 wob, 45 rpm, 330 gpm, 43

07:00 07:30 0.50 2.50 Srvys 1,772 1,772 Survey @ 1727, 3.1* inc, 16.2 azi

07:30 09:00 1.50 4.00 Dir Rotate 1,772 1,867 Rot, 8 wob, 45 rpm, 330 gpm 63

09:00 09:30 0.50 4.50 Srvys 1,867 1,867 Survey @ 1822, 4.7* inc, 10.8 azi

09:30 10:00 0.50 5.00 Dir Sliding 1,867 1,887 Slide, 12 wob, 330 gpm, GTF 120 R 40

10:00 11:30 1.50 6.50 Dir Rotate 1,887 1,931 Rot, 8 wob, 45 rpm, 330 gpm, 29.3

11:30 12:00 0.50 7.00 Dir Sliding 1,931 1,951 Slide, 12 wob, 330 gpm, GTF 180 40

12:00 12:30 0.50 7.50 Dir Rotate 1,951 1,963 Rot, 8 wob, 45 rpm, 330 gpm 24

12:30 13:00 0.50 8.00 Srvys 1,963 1,963 Survey @ 1918, 5.0* inc, 15.3 azi

13:00 13:30 0.50 8.50 Dir Rotate 1,963 1,995 Rot, 8 wob, 45 rpm, 330 gpm, 64

13:30 14:00 0.50 9.00 Dir Sliding 1,995 2,015 Slide, 12 wob, 330 gpm, GTF 120 R 40

14:00 14:30 0.50 9.50 Dir Rotate 2,015 2,058 Rot, 8 wob, 45 rpm, 330 gpm 43

14:30 15:00 0.50 10.00 Srvys 2,058 2,058 Survey @ 2013, 4.0* inc, 13.3 azi

15:00 17:30 2.50 12.50 Dir Rotate 2,058 2,153 Rot, 8 wob, 45 rpm, 330 gpm 38

17:30 18:00 0.50 13.00 Rtn. Maint. 2,153 2,153 Service Rig

18:00 18:30 0.50 13.50 Srvys 2,153 2,153 Survey @ 2108, 4.1* inc, 11.3 azi

18:30 19:00 0.50 14.00 Dir Sliding 2,153 2,173 Slide, 14 wob, 330 gpm, GTF 120 L 40

19:00 19:30 0.50 14.50 Dir Rotate 2,173 2,185 Rot 15 wob, 45 rpm, 330 gpm 24

19:30 20:00 0.50 15.00 Dir Sliding 2,185 2,205 Slide, 20 wob, 330 gpm, GTF 180 40

20:00 21:30 1.50 16.50 Dir Rotate 2,205 2,249 Rot, 12 wob, 45 rpm, 330 gpm 29

21:30 22:00 0.50 17.00 Srvys 2,249 2,249 Survey @ 2204, 5.3* inc, 337.5 azi

22:00 22:30 0.50 17.50 Dir Sliding 2,249 2,269 Slide, 20 wob, 330 gpm, GTF 180 40

22:30 23:00 0.50 18.00 Dir Rotate 2,269 2,281 Rot, 12 wob, 45 rpm, 330 gpm 26

23:00 23:30 0.50 18.50 Dir Sliding 2,281 2,301 Slide, 20 wob, 330 gpm, GTF 120 L 40

23:30 00:00 0.50 19.00 Dir Rotate 2,301 2,312 Rot, 12 wob, 45 rpm, 330 gpm 22

00:00 00:30 0.50 19.50 Rtn. Maint. 2,312 2,312 Service Rig

00:30 01:00 0.50 20.00 Dir Rotate 2,312 2,344 Rot, 12 wob, 45 rpm, 330 gpm 44

01:00 01:30 0.50 20.50 Srvys 2,344 2,344 Survey @ 2299, 4.9* inc, 315.3 azi

01:30 02:00 0.50 21.00 Dir Rotate 2,344 2,376 Rot, 12 wob, 45 rpm, 330 gpm 64

02:00 03:00 1.00 22.00 Dir Sliding 2,376 2,396 Slide, 20 wob, 330 gpm, GTF 130 L 20

03:00 04:00 1.00 23.00 Dir Rotate 2,396 2,439 Rot, 12 wob, 45 rpm, 330 gpm 43

04:00 04:30 0.50 23.50 Srvys 2,439 2,439 Survey @ 2394, 6.2* inc, 315.6 azi

04:30 05:00 0.50 24.00 Dir Rotate 2,439 2,471 Rot, 12 wob, 45 rpm, 330 gpm 62

Air/Mud Data

MW-In (lb/gal)

11.00

MW-Out (lb/gal)

11.00

Vis (s/qt)

46

PV (cp)

18.0

YP (lbf/100ft2)

24

Gel 10 sec

8

Gel 10 min

12

Gel 30 min

16

Filtrate (mL/30min)

5.0

Cake (/32")

1

pH

8.9

Solids (%)

15

LGS (%)

5

MBT (lb/bbl) Oil (%)

1

H20 (%)

84

Chlor (mg/L)

170,000

Ca (mg/L)

440

ES (V) HTHP Filt (mL/30min) Pf (mL/mL)

0.1

Mf (mL/mL)

0.5

ECD (lb/gal)

11.68

LCM

Hole Volume (bbl)

88.1

Pit Volume (bbl)

400.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

1710 60 40 13

1980 80 20 16

2170 80 20

2420 30 70 12 12

Bit Run # 2

Size (in)

8 3/4

Model

FX 55

Make

Security DBS

SN

11230914

Jets (/32")

12/12/12/12/12

In (ftKB)

1,300

Out (ftKB)

3,427

Drld (ftKB)

2,127

Drl Hrs (hrs)

57.50

ROP (ft/hr)

37.0

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

2 4 BT A X 0 WT TQ 8 Insert broken

WOB (min) (1000lbf)

8

WOB (max) (1000lbf)

20

BHA ROP (ft/hr)

37

SPP (psi)

175.0

Motor RPM (rpm)

98

RPM (rpm)

45

PU (max) (1000lbf)

130

SO (1000lbf)

100

Off-Btm Str Wt (1000lbf)

106

Drag (1000lbf)

2

Start (ftKB)

1,709

End (ftKB)

2,471

Bit Run # 1

Size (in)

12 1/4

Model

C623G Hammer

Make SN

SN AC-123153

Jets (/32") In (ftKB)

59

Out (ftKB)

1,300

Drld (ftKB)

1,241

Drl Hrs (hrs)

20.50

ROP (ft/hr)

60.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

0 0 WT A X 0 WT TD

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

2,204 5.30 337.50

2,236 5.20 340.70

2,267 4.40 324.90

2,299 4.90 315.30

2,331 5.60 314.50

2,363 5.70 319.50

2,394 6.20 315.60

2,426 6.50 319.40

2,458 7.20 320.60

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #2, 8 3/4 Steerable

BHA No.

2

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.29

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 57.50 1.48

9 DP 5 57.50 274.31

21 HWDP 5 57.50 643.60

1 XO Sub 6 1/2 57.50 1.56

1 Jars - 

Hydraulic

6 1/2 57.50 31.66

12 DC 6 1/2 78.00 369.01

1 MWD/NMDC 6 1/2 57.50 29.85

1 UBHO 6 1/2 57.50 2.52

1 Great White 1.83 0.30 6 1/2 57.50 22.30

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

33 4.50 16.60 X-95 4 1/2 

XH

1,048

Diesel Fuel

Received Used

870

Total on Location

5220

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,200

Stroke (in)

10.00

Slow ...

No

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

95

Q (gpm)

331

Pres (psi)

1,200

Stroke (in)

10.00

Slow ...

No

SPM (spm)

97

Q (gpm)

338

Pres (psi)

1,200

Stroke (in)

10.00

Slow ...

No

Costs

Daily Cost Total

26,708

Field Est To Date

441,113

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/10/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

1,709

Footage (ftKB)

409

Drill Hrs (hrs)

9.50

Avg ROP (ft/hr)

43.1

DFS

3

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Dir Drlg

Operations Next 24 Hours

Dir Drlg

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

G. Fleming

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 NU & Test 1,300 1,300 Install Wear Bushing

05:30 06:00 0.50 1.00 Rtn. Maint. 1,300 1,300 Rig Service

06:00 12:00 6.00 7.00 Trip - Other 1,300 1,300 Pick up BHA, Tag Cement @ 1166

12:00 15:30 3.50 10.50 Drilling 

Cement

1,300 Drlg Cement 1166 to 1300

15:30 17:30 2.00 12.50 Dir Rotate 1,300 1,359 Rot, 8 wob, 45 rpm, 325 gpm, 29.5

17:30 18:00 0.50 13.00 Rtn. Maint. 1,359 1,359 Service Rig

18:00 18:30 0.50 13.50 Dir Rotate 1,359 1,390 Rot, 8 wob, 45 rpm, 3325 gpm 62

18:30 20:00 1.50 15.00 Srvys 1,390 1,390 Run Gyro, and MWD Survey @ 1345,

20:00 21:00 1.00 16.00 Dir Sliding 1,390 1,410 Slide,12 wob, 330 gpm, GTF 180 20

21:00 22:00 1.00 17.00 Dir Rotate 1,410 1,454 Rot, 8 wob, 45 rpm, 330 gpm, 44

22:00 22:30 0.50 17.50 Dir Sliding 1,454 1,474 Slide, 12 wob, 330 gpm, GTF 160 R 40

22:30 23:00 0.50 18.00 Dir Rotate 1,474 1,486 Rot, 8 wob, 45 rpm, 330 gpm 24

23:00 23:30 0.50 18.50 Srvys 1,486 1,486 Survey @ 1441, 3.8* inc, 20.4 azi

23:30 00:00 0.50 19.00 Dir Rotate 1,486 1,518 Rot, 8 wob, 45 rpm, 330 gpm 64

00:00 00:30 0.50 19.50 Dir Sliding 1,518 1,538 Slide, 12 wob, 330 gpm, GTF 130 R 40

00:30 01:00 0.50 20.00 Dir Rotate 1,538 1,582 Rot, 8 wob, 45 rpm, 330 gpm 44

01:00 01:30 0.50 20.50 Srvys 1,582 1,582 Survey @ 1537, 3.2* inc, 28.9 azi

01:30 02:00 0.50 21.00 Dir Rotate 1,582 1,613 Rot, 8 wob, 45 rpm, 330 gpm 62

02:00 02:30 0.50 21.50 Rtn. Maint. 1,613 1,613 Service Rig

02:30 03:00 0.50 22.00 Dir Rotate 1,613 1,645 Rot, 8 wob, 45 rpm, 330 gpm 64

03:00 03:30 0.50 22.50 Dir Sliding 1,645 1,665 Slide, 12 wob, 330 gpm, GTF 150 R 40

03:30 04:00 0.50 23.00 Dir Rotate 1,665 1,677 Rot, 8 wob, 45 rpm, 330 gpm 24

04:00 04:30 0.50 23.50 Srvys 1,677 1,677 Survey @ 1632, 4* inc, 22.2 azi

04:30 05:00 0.50 24.00 Dir Rotate 1,677 1,709 Rot, 8 wob, 45 rpm, 330 gpm 64

Air/Mud Data

MW-In (lb/gal)

10.80

MW-Out (lb/gal) Vis (s/qt)

50

PV (cp)

20.0

YP (lbf/100ft2)

26

Gel 10 sec

8

Gel 10 min

16

Gel 30 min

20

Filtrate (mL/30min)

5.1

Cake (/32")

1

pH

9.0

Solids (%)

15

LGS (%)

5

MBT (lb/bbl) Oil (%)

1

H20 (%)

84

Chlor (mg/L)

170,000

Ca (mg/L)

480

ES (V) HTHP Filt (mL/30min) Pf (mL/mL) Mf (mL/mL)

4.5

ECD (lb/gal)

11.63

LCM

Hole Volume (bbl)

81.8

Pit Volume (bbl)

410.0

Storage Volume (bbl)

Compressors Boosters Nitrogen Units Air/Gas Vol. (ft3/min) Pressure (psi)

Comment

Mud Logging Data

MD

(ftKB)

Shale

(%) SS (%) LS (%)

Chert

(%)

BG Gas

(%)

C/Gas

(%)

T/Gas

(%)

Max

Gas (%)

Gas

Show Comment

1360 70 30 10

1640 60 40 12

1677 60 40 13 15

Bit Run # 2

Size (in)

8 3/4

Model

FX 55

Make

Security DBS

SN

11230914

Jets (/32")

12/12/12/12/12

In (ftKB)

1,300

Out (ftKB)

3,427

Drld (ftKB)

2,127

Drl Hrs (hrs)

57.50

ROP (ft/hr)

37.0

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

2 4 BT A X 0 WT TQ 8 Insert broken

WOB (min) (1000lbf)

8

WOB (max) (1000lbf)

20

BHA ROP (ft/hr)

37

SPP (psi)

150.0

Motor RPM (rpm)

98

RPM (rpm)

45

PU (max) (1000lbf)

130

SO (1000lbf)

92

Off-Btm Str Wt (1000lbf)

94

Drag (1000lbf)

2

Start (ftKB)

1,300

End (ftKB)

1,709

Bit Run # 1

Size (in)

12 1/4

Model

C623G Hammer

Make SN

SN AC-123153

Jets (/32") In (ftKB)

59

Out (ftKB)

1,300

Drld (ftKB)

1,241

Drl Hrs (hrs)

20.50

ROP (ft/hr)

60.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

0 0 WT A X 0 WT TD

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

1,441 3.80 20.40

1,473 3.50 14.50

1,505 3.50 18.10

1,537 3.20 28.90

1,568 3.50 30.00

1,600 3.90 26.10

1,632 4.00 22.20

1,664 3.50 15.10

1,695 3.90 6.80

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #2, 8 3/4 Steerable

BHA No.

2

Drill String Name

8 3/4 Steerable

Length (ft)

1,377.29

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 XO Sub 6 1/2 57.50 1.48

9 DP 5 57.50 274.31

21 HWDP 5 57.50 643.60

1 XO Sub 6 1/2 57.50 1.56

1 Jars - 

Hydraulic

6 1/2 57.50 31.66

12 DC 6 1/2 78.00 369.01

1 MWD/NMDC 6 1/2 57.50 29.85

1 UBHO 6 1/2 57.50 2.52

1 Great White 1.83 0.30 6 1/2 57.50 22.30

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

9 4.50 16.60 X-95 4 1/2 

XH

286

Diesel Fuel

Received Used

580

Total on Location

6090

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

SPM (spm)

94

Q (gpm)

328

Pres (psi)

1,100

Stroke (in)

10.00

Slow ...

No

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total

49,964

Field Est To Date

414,405

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/9/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

1,300

Footage (ftKB)

0

Drill Hrs (hrs) Avg ROP (ft/hr) DFS

2

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Set Wear bushing, M/U Directional BHA

Operations Next 24 Hours

TIH, Directional Drilling

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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 C&C 

Hole/Mud

1,300 1,300 Pump two 5 gal sweeps, Blow hole clean

05:30 07:00 1.50 2.00 Trip - Other 1,300 1,300 Trip out of hole for csg

07:00 07:30 0.50 2.50 Rtn. Maint. 1,300 1,300 Service Rig

07:30 08:30 1.00 3.50 Trip - Other 1,300 1,300 R/U Lay Down Truck/ L/D 8" DC's

08:30 12:30 4.00 7.50 Surf 

Csg/Cmt

1,300 1,300 Rig Up and Run 33 joints of 9 5/8", 36 lb/ft, 

J-55 Csg, Guide Shoe depth @ 1272'

12:30 13:30 1.00 8.50 Surf 

Csg/Cmt

1,300 1,300 Unable to pass 1272' Attempt to circ w/air, 

Pump 80 bbl sweep with rig pump

13:30 16:00 2.50 11.00 Surf 

Csg/Cmt

1,300 1,300 Rig up cementers and cmt csg @ 1272', 

Pump 50 bbls fresh water w/5 gallons of 

MF-55 followed by; Scavenger: 150 sks 

Premium Plus C Cmt + 10lbs/sk Cal-Seal 

60 + 0.125 lb/sk Poly-E-Flake. Lead: 550 

Sks (250% excess) Haliburton Lite 

Premium Plus + 3% salt + 2.0lbs/sk 

Pheno-Seal mixed @ 1.85 cu ft/sk & 12.9 

lbm/gal, Tail: 180 sks Premium Plus C 

Cement + 2% bwoc Calcium Chloride + 4% 

bwoc Bentonite + 2.0 lbs/sk Pheno-Seal 

mixed @ 1.69 cu ft/sk & 13.7 lbm/gal. 

Displacement cut short by 7 bbls. 350 sks 

cmt returns to surface. Cmt job witnessed 

by Graham of TRRC.

16:00 20:00 4.00 15.00 WOC 1,300 1,300 WOC

20:00 01:00 5.00 20.00 NU & Test 1,300 1,300 Cut off conductor & 9 5/8" csg, Weld & test 

head

01:00 04:30 3.50 23.50 NU & Test 1,300 1,300 Nipple up BOP

04:30 05:00 0.50 24.00 NU & Test 1,300 1,300 Test BOP to 1500 psi, Set Wear Bushing

Air/Mud Data

MW-In (lb/gal) MW-Out (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

1

Nitrogen Units Air/Gas Vol. (ft3/min)

4,400.00

Pressure (psi)

380.0

Comment

Water - 18 bbl/hr, Soap - 3 gal/hr, CL - 9390 - 2 gal/hr

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

C623G Hammer

Make SN

SN AC-123153

Jets (/32") In (ftKB)

59

Out (ftKB)

1,300

Drld (ftKB)

1,241

Drl Hrs (hrs)

20.50

ROP (ft/hr)

60.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

0 0 WT A X 0 WT TD

WOB (min) (1000lbf)

7

WOB (max) (1000lbf)

7

BHA ROP (ft/hr)

61

SPP (psi) Motor RPM (rpm) RPM (rpm)

40

PU (max) (1000lbf)

72

SO (1000lbf)

69

Off-Btm Str Wt (1000lbf)

70

Drag (1000lbf)

2

Start (ftKB)

1,300

End (ftKB)

1,300

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

470 1.30

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

Surface 9 5/8 36.00 J-55 1,270

BHA #1, 12 1/4 Slick

BHA No.

1

Drill String Name

12 1/4 Slick

Length (ft)

259.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 DC 6 1/2 20.50 31.02

1 DC 6 1/2 20.50 31.03

1 DC 6 1/2 20.50 30.93

1 DC 6 1/2 20.50 30.79

1 DC 6 1/2 20.50 31.01

1 DC 6 1/2 20.50 30.62

1 XO Sub 8 20.50 2.95

1 DC 8 20.50 31.03

1 DC 8 20.50 31.02

1 DC 8 20.50 2.60

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

30 4.50 16.60 X-95 4 1/2 XO 953

Diesel Fuel

Received Used

725

Total on Location

6670

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total

149,760

Field Est To Date

364,441

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report
Lariat

Report Date: 12/8/2009

Spud Date: 12/7/2009

Well Name

WEST RANCH 45-14

Proposed TD (ftKB)

7,000

MD (ftKB)

1,300

Footage (ftKB)

1,241

Drill Hrs (hrs)

20.50

Avg ROP (ft/hr)

60.5

DFS

1

Field Name

PINON

Corp ID

102924

County/Parish

PECOS

ST

TX

Section

45

Blk/Twn

2

Survey/Range

TC RR CO

Operations at Report Time

Blowing Hole Clean

Operations Next 24 Hours

Trip/pump out of hole to run csg & cmt

Drilling Manager

Nick Newland

Drilling Engineer

Ryan Robinson

Geology Contact

Justin Lynch

Field Geologist

Will Murley

Drilling Supt.

Johnny Green

Company Man

James McLeroy

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 Rig Up & 

Down

Rig Up to Spud Well, Called TRRC @ 21:30 

hrs on 06-Dec-09 with notification of spud 

time. Spoke with Andrea, Operator # 24

07:30 17:30 10.00 12.50 Drilling 59 529 Spudded at 7:30 12-7-09. Drill 12-1/4" 

Surface Hole to 529'

47

17:30 18:00 0.50 13.00 Rtn. Maint. 529 529 Service rig

18:00 18:30 0.50 13.50 Srvys 529 529 Deviation Survey @ 470'

18:30 05:00 10.50 24.00 Drilling 529 1,300 Drill 12-1/4" Surface Hole to 1,300' Called 

TRRC @ 12:01 AM with notification of 

intent to run casing & cmt. Spoke to 

Audrey, Operator #2

73

Air/Mud Data

MW-In (lb/gal) MW-Out (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

1

Nitrogen Units Air/Gas Vol. (ft3/min)

4,400.00

Pressure (psi)

380.0

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

C623G Hammer

Make SN

SN AC-123153

Jets (/32") In (ftKB)

59

Out (ftKB)

1,300

Drld (ftKB)

1,241

Drl Hrs (hrs)

20.50

ROP (ft/hr)

60.5

Inner Outer Dull Loc Bearing Gauge Other

Reason

LD Comment

0 0 WT A X 0 WT TD

WOB (min) (1000lbf)

7

WOB (max) (1000lbf)

7

BHA ROP (ft/hr)

61

SPP (psi) Motor RPM (rpm) RPM (rpm)

40

PU (max) (1000lbf)

72

SO (1000lbf)

69

Off-Btm Str Wt (1000lbf)

70

Drag (1000lbf)

2

Start (ftKB)

59

End (ftKB)

1,300

Drill Pipe on Location

# of Jts Size (in) Wt Grade Conn

Length

(ftKB) Comment

9 5.00 19.5 G-105 4.5 IF 274

318 4.50 16.6 X-95 4.5 XH 10,297 318 Useable

24 5.00 43 4.5 IF 744 HWDP

Survey Data

MD (ftKB) Incl (°) Azm (°)

470 1.30

Casing Strings

Csg Desc

String

OD (in)

String

Wt

(lbs/ft)

String

Grade

Set Depth

(ftKB)

Conductor 13 3/8 48.00 H-40 60

BHA #1, 12 1/4 Slick

BHA No.

1

Drill String Name

12 1/4 Slick

Length (ft)

259.27

BHA Components

Jts

Item

Description

Bend

(°) Rpg

OD

(in)

Run

(hrs) Len (ft)

1 DC 6 1/2 20.50 31.02

1 DC 6 1/2 20.50 31.03

1 DC 6 1/2 20.50 30.93

1 DC 6 1/2 20.50 30.79

1 DC 6 1/2 20.50 31.01

1 DC 6 1/2 20.50 30.62

1 XO Sub 8 20.50 2.95

1 DC 8 20.50 31.03

1 DC 8 20.50 31.02

1 DC 8 20.50 2.60

Drill Pipe in Hole

# of

Jts

Size

(in) Wt Grade Conn

Length

(ftKB)

30 4.50 16.60 X-95 4 1/2 XO 953

Diesel Fuel

Received

9,570.0

Used

2175

Total on Location

7395

Last BOP Test

End Date

12/9/2009

Mud Pumps

No.

1

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

No.

2

Make

Rhongshang

Model

RSF-1000

Liner Size (in)

6

Rod Dia (in) Stroke (in)

10.00

Costs

Daily Cost Total

214,681

Field Est To Date

214,681

AFE Rig Release Estimate

Estimate

1,692,101

AFE: D101015

42

Drilling Report