Docket No. 2001-022 Cause No. 139-73 February 27, 2002 Road Runner Oil, Inc. and Gavilan Petroleum, Inc

Docket No. 2001-022

Cause No. 139-73

February 27, 2002

Road Runner Oil, Inc. and

Gavilan Petroleum, Inc.

Road Runner Oil, Inc.Docket No. 2001-022Cause No. 139-73

Exhibit “1”

Birch #1-25 Section 25, T1S, R5W

Duchesne County, Utah

The Birch #1-25 was drilled and completed in 1974. Initial production was 1,684 BO and 444 MCF gas with no water. The well was completed with 7-5/8” intermediate casing and a 5½” uncemented liner. The liner is not slotted but was produced open ended with perforations added in the lower Wasatch at a later time. The lower Wasatch was abandon and bridge plugged off in mid 1987. The upper Wasatch was then completed and an ineffective acid stimulation was put on the well following perforating. A casing leak was then repaired immediately following the stimulation with no repeat of the stimulation. The well has not produced since that time. Cumulative production on the well is currently 60.6 MBBLS. The average production on wells for major oil companies surrounding this was is 301 MBBLS. Therefore, the expected addition production from the well is about 240 MBBLS. To accomplish this, it would be necessary to pull the existing liner, run open hole logs if none can be located, and rerun and cement the same or a replacement liner. At this point, it would be possible to perforate and complete the Wasatch in a normal fashion. The expected cost to perform this work is $350,000. This is excluding the cost of artificial lift equipment and surface equipment repairs.


Exhibit “2”

Sec. 25, T1S, R5WDuchesne County, Utah

9-5/8”, 36#, K-55 LT&C set @ 3,012’

7-5/8”, 26.4, 29.7, & 33.7# S-95 set at 12,745'

2/7/8", 6.5#, J-55 set @ 11,106' w/ packer

Top of cement unknown

Perforations 11,883'-12,406'

CIBP set @ 12,482'

7-5/8" casing set at 12,980'

5½”,22.54#, P-110 Hydril set 12,433’-15,825’

Perforations 13,500' - 14,502'

Production liner uncemented

Shoe @ 15,825' w/ perforated nipple above shoeTD at 16,325'

BIRCH #1-25

Sorensen #1-5 Section 5, T2S, R5W

Duchesne County, Utah

The Sorensen #1-5 was drilled and completed in 1974. Initial production is unknown at this time. The well was completed with 7-5/8” intermediate casing and a 5½” uncemented liner. The liner is not slotted but was produced open ended. Cumulative production on the well is currently 6.2 MBBLS. The average production on wells for major oil companies surrounding this was is 234 MBBLS. Therefore, the expected addition production from the well is about 225 MBBLS. To accomplish this, it would be necessary to pull the existing liner, run open hole logs if non can be located, and rerun and cement the same or a replacement liner. At this point, it would be possible to perforate and complete the Wasatch in a normal fashion. The expected cost to perform this work is $350,000. This is excluding the cost of artificial lift equipment and surface equipment repairs.


Exhibit “3”

Sec. 5, T2S, R5W2 Duchesne County, Utah

9-5/8”, 40#, K-55 LT&C set @ 3,412’

7-5/8”, 26.4, 29.7, & 33.7# N-80 & S-95 set at 13,500'

2/7/8", 6.5#, N-80 set @ 12,000' w/ Otis WB packerw/ 12' millout extensionTop of cement unknown

7-5/8" casing set at 12,980'

5½”,22.54#, P-110 Hydril set 12,670’-15,153’




SORENSEN #1-5

Sorensen #1-6 Section 6, T2S, R5W

The Sorensen #1-6 was drilled and completed in 1974. Initial production was 428 BO and 132 MCF gas with no water following the initial stimulation of 8,000 gallons of 10% HCL. The well was completed with 7-5/8” intermediate casing and a 5½” uncemented liner. The liner is not slotted but was produced open ended with conventional perforations that were added later. The well was restimulated with 6,000 gallons 15% HCL in May 1977. A review of the available files fails to indicate whether there was a production increase. If there was, I suspect it was small due to the inability to accomplish matrix diversion. Cumulative production on the well is currently 38.4 MBBLS. The average production on wells for major oil companies surrounding this was is 234 MBBLS. Therefore, the expected addition production from the well is about 200 MBBLS. To accomplish this, it would be necessary to pull the existing liner, run open hole logs if none can be located, and rerun and cement the same or a replacement liner. At this point, it would be possible to perforate and complete the Wasatch in a normal fashion. The expected cost to perform this work is $350,000. This is excluding the cost of artificial lift equipment and surface equipment repairs.


Exhibit “4”

Sec. 6, T2S, R5WDuchesne County, Utah

9-5/8”, 36#, K-55 LT&C set @ 3,493’

7-5/8”, 26.4, 29.7, & 33.7# N-80 & S-95 set at 12,980'

2/7/8", 6.5#, N-80 set @ 12,644' w/ Baker LokSet Pkr.and 1544' of 2-3/8" tbg. below pkr.

Top of cement unknown

7-5/8" casing set at 12,980'

5½”,22.54#, P-110 Hydril set 12,670’-15,153’




SORENSEN #1-6


Exhibit “1”

Roosevelt Unit #5W Sec. 20 T1S, R1E

Uintah County, Utah

Well Data Depth: 13,171’ TD PBTD: 13,099’ Elevation: 5427’GL KB: 24’ Casing: 9-5/8”, 40#, SOO-95 set at 2,962’

7-5/8”, 33.7#, N-80 set surface to 10,699’ 4½”, 15.1#, NK-T95 set 10,164’ to 13,181’ Tubing: 2-7/8”, 6.5#, L-80 EUE 8RD tubing set at 9,044’ w/ MSOT anchor

catcher. (Seat nipple @ 9006’) Perfs: Wasatch perfs 10,982’ - 13,048’, 245’, & 490 holes Capacity Burst Collapse Description ID (in) Drift (in) B/FT PSI. PSI. 7-5/8”, 33.7#, N-80 6.765 6.640 .0471 7900 6560 4½”, 15.1#, NK-T95 3.826 3.701 .0142 14420 14320 Procedure

1. MIRU service rig. Hot oil rods and tubing. POOH laying down sucker rods on TOOH. Hot oil tubing and run Weatherford 32 arm caliper on tubing. ND tubing flange and NU BOP. Test BOP. Release tubing anchor & POOH laying down reject tubing.

2. PU 4½” bit and casing scraper on 2-3/8” & 2-7/8” tubing and TIH to PBTD.

POOH laying down bit and scraper.

3. Perforate Wasatch 11,976 to 13,092’ with 3 SPF as per attached procedure.

4. PU 4½” treating packer on 100’ of 2-3/8” and 3½” N-80 tubing and TIH

setting packer at +/-10,250’.

5. Stimulate Wasatch perfs 11,976’ to 13,048’ as per enclosed procedure.


Exhibit “5”

6. Swab back acid and clean up well. After ph >5.0, release packer and POOH laying down 3½” N-80 tubing. Run GR log to determine stimulation coverage.

7. PU 7-5/8” tbg anchor with 2-7/8” production tubing and TIH setting anchor

at 10,000’+/-. ND BOP and NU well head. PU pump and inspected rods and TIH. Hang well on and release rig. Return well to production.

Sec. 20, T1S, R1EUintah County, Utah

9-5/8”, 40#, S00-95 ST&C set @ 2,962’

7-5/8”, 33.7# N-80 set at 10,699'

Top of cement @ 5,300'

7-5/8" casing set at 10,699'

4½”,15.1#, NK-T95 LT&C set 10,164’-13,181’

Production liner cement

Perfs @ 10,982'-13,048'

PBTD at 13,099'TD at 13,181'

ROOSEVELT UNIT #5W

Roosevelt Unit #5W Section 20, T1S, R1E Uintah County, Utah

Perforation Schedule

Perforations picked as per Dresser Atlas DIL, Dated 6/23/84 13,092 12,880 12,294 13,089 12,876 12,248 13,062 12,872 12,244 13,060 12,396 12,240 12,996 12,392 12,236 12,992 12,378 11,993 12,896 12,374 11,980 12,892 12,298 11,976 Total of 24 feet, 72 holes. All perforations are to be 3 SPF using 120° phasing.

AUTHORITY FOR EXPENDITURE

Wind River Resources, Inc.

Date: 1/7/2002 AFE# 01-07

Well Name: Roosevelt Unit 5W W. I. Sec. 20-T1S-R1E, Uintah County, Utah

Purpose: Return well to economic production by recompleting in Wasatch formaiton.

Intangible Costs Drilling CompletionRoads & LocationsDrilling ContractorCompletion Rig 42000Trucking and Hauling 2000Fuel and Water 2000Bits, Mud, ChemicalsCoring, Testing, LoggingPerforating, Wireline 20000Stimulation 90000Cement, Surf & Intermed.Rental Equipment 9000Wellsite Supervision 7000Subtotal 0 172000

Tangible CostsSurface CasingIntermediate CasingProduction LinerTubing 2000Sucker Rods 20000Subsurface Equipment 2500Wellhead Equipment 1000Surface EquipmentSubtotal 0 25500Total 0 197500

______Approved ______Non-consent

Signature: Date:_____________

Name:


Uintah County, Utah

Well Data Depth: 13,250’ TD PBTD: 13,197’ Elevation: 5450’ KB: 23’ Casing: 9-5/8”, 36#, J-55 set at 2508’

7”, 26#, N-80 & S-95, & 29.7 # S-95 set surface to 10,685’ 5”, 18#, N-80 & P-110 set 9,972’ to 13,238’ Tubing: 2-7/8”, 6.5#, N-80 TC Nulock tubing set at +/-11,813’ w/ Baker 32

FA30 Packer. Note: Tubing in 18K tension on packer Perfs: Wasatch perfs 11,897’ - 13,170’, 299’, & 897 holes Previous Work: 1) Initial Completion, 1-15-84, 60,000 gal. acid job into 299’

of perf (897 holes) between 11,897-13,170. Result: IP flowing 1,267 bopd / 637 Mcfgpd / 14 bwpd. Well averaged 497 bopd in April ’84.

2) 12-11-84 re-acidized same perfs w/ 50,000 gal. Well making 148 bopd / 0? Bwpd / 100 Mcfgpd before acid job and 28 bopd less after.

3) 1-26-89 re-acidized same perfs with 15,000 gal. Oil production for 1989 was same as 1998 (85 bopd), so acid job had no effect.

Capacity Burst Collapse Description ID (in) Drift (in) B/FT PSI. PSI. 7”, 29.7#, N-80 6.875 6.844 .0471 6890 4790 7”, 29.7#, S-95 6.875 6.844 .0471 8670 6010 5”, 18#, P-110 4.670 4.545 .0211 10560 11160 Problems Only the lower Wasatch has been completed in this well. Although it has been heavily perforated (nearly 900 holes) it has not been effectively stimulated since the original completion, 18 years ago. The well still produces 25-35 bopd, but the rod string is so fragile that it can only be kept on production for a few days between rod partings.


Exhibit “6”

Objectives Increase production from 30 bopd to >100 bopd by concentrating stimulation in a manageable interval, remove production packer to improve oil and gas separation and production, and equip well with serviceable rod string. Procedure

1. MIRU service rig. Heat well with condensate. POOH w/ rods and pump laying down same. Send rods off for inspection. Hot oil tubing while cutting wax and run Weatherford 32 arm caliper on tubing. ND tubing flange and NU BOP. Test BOP. Release seal assembly from pkr & POOH laying down reject tubing and reorganizing tubing string by grade.

2. PU 4-1/8” bit and casing scraper on 2-3/8” & 2-7/8” tubing and TIH to top

of pkr at 11,813’. Drill out packer. POOH laying down bit and scraper.

3. PU pkr. plucker on 2-3/8” & 2-7/8” tubing and TIH to top of pkr at 11,813’. Pluck pkr and POOH laying down pkr.

4. PU cast iron bridge plug on 2-3/8” & 2-7/8” tubing and TIH setting CIBP at

12,136’. POOH.

5. PU 5” treating packer on 2-7/8”, 8.7#, P-105 tubing and TIH setting packer at +/-11,850.

6. Stimulate Wasatch perfs 11,897’ to 12,112’ (204 holes) w/ 7,000 gal 15%

HCl diverted with 250 1.1 SG ball sealers. Target rate = 10 bpm. Max. pressure = 9,000 psi. Tag acid w/ radioactive tracer.

7. Swab back acid and clean up well. After ph >5.0, release packer and

POOH laying down P-105 tubing. Run GR log to determine stimulation coverage.

8. PU 7” tbg anchor and gas anchor with 2-7/8” production tubing and TIH

setting anchor at 11,000’+/-. ND BOP and NU well head. Rerun inspected/new rods and pump. Hang well on and release rig. Return well to production.


9-5/8”, 36#, J-55 ST&C set @ 2,508’

7”, 26# N-80 & S-95, 29# S-95 set at 10,300' 7”, 26# N-80 surf- 2708'7”, 26# S-95 2708'-6274'7”, 29# S-95 set at 6274'-10,300'


7-5/8" casing set at 10,685'

5”,18#, N-80 & P-110 set 9,972’-13,238’5”,18#, N-80 set 9,972’-11,871’5”,18#, P-110 set 11,871’-13,238’


Perfs @ 11,897'-13,170'

PBTD at 13,201TD at 13,238'

ROOSEVELT UNIT #6W



Perforations picked as per Dresser Atlas DIL, Dated 11/4/83 13,190 12,960 12,358 13,186 12,758 12,342 13,180 12,754 12,33413,136 12,748 12,326 13,132 12,736 12,296 13,060 12,732 12,134 13,056 12,584 12,130 13,046 12,580 12,124 12,964 12,520 12,118 Total of 27 feet. All perforations are to be 3 SPF using 120° phasing.



Date: 1/7/2002 AFE# 01-05

Well Name: Roosevelt Unit 6W W. I. SW NE Sec. 20-T1S-R1E, Uintah County, Utah






Name:


Uintah County, Utah

Well Data Depth: 13,796’ TD PBTD: 13,524’ Elevation: 5486’GL KB: 23’ Casing: 10-3/4”, 51#, K-55 set at 2540’

7-5/8”, 29.7#, N-80 & S-95 set surface to 10,685’ 5½”, 23#, N-80 set 10,398’ to 13,791’ Tubing: 2-7/8”, 6.5#, N-80 EUE 8RD tubing set at +/-11,784’ stung into w/

Baker FB-1 Packer. (Note: Tubing in 18K tension on packer?) Perfs: Wasatch perfs 11,934’ - 13,370’, 145’, & 329 holes Capacity Burst Collapse Description ID (in) Drift (in) B/FT PSI. PSI. 7-5/8”, 29.7#, N-80 6.875 6.844 .0471 6890 4790 7-5/8”, 29.7#, S-95 6.875 6.844 .0471 8670 6010 5½”, 23#, N-80 4.670 4.545 .0211 10560 11160 Procedure

1. MIRU service rig. POOH w/ rods and pump inspecting rods on TOOH. Hot oil tubing and run Weatherford 32 arm caliper on tubing. ND tubing flange and NU BOP. Test BOP. Release seal assembly from pkr & POOH laying down reject tubing and all tubing in excess of 10,000’.

2. PU 4½” bit and casing scraper on 2-3/8” & 2-7/8” tubing and TIH to top of

pkr at 11,784’. POOH laying down bit and scraper.

3. PU pkr. plucker on 2-3/8” & 2-7/8” tubing and TIH to top of pkr at 11,784’. Pluck pkr and POOH laying down pkr.

4. PU 4½” bit and casing scraper on 2-3/8” & 2-7/8” tubing and TIH to PBTD.

Drill out cement to float collar at 13,748. POOH laying down bit and scraper.


Exhibit “7”


6. PU 5½” treating packer on 100’ of 2-7/8” and 3½” N-80 tubing and TIH




9. PU 7-5/8” tbg anchor with 2-7/8” production tubing and TIH setting anchor

at 10,500’+/-. ND BOP and NU well head. Rerun rods and pump with a 86 rods design of 30%, 30%, 60%. Hang well on and release rig. Return well to production.


10-3/4”, 51#, K-55 ST&C set @ 2,540’

7-5/8”, 29# N-80 & S-95 set at 10,685'


7-5/8" casing set at 10,685'

5½”,23#, N-80 LT&C set 10,398’-13,791’


Perfs @ 11,934'-13,370'

PBTD at 13,524'TD at 13,796'

ROOSEVELT UNIT #7W



Perforations picked as per Schlumberger DIL, Dated 1/12/84 13,738 13,552 12,958 12,314 13,716 13,536 12,954 12,310 13,712 13,532 12,946 12,27413,702 13,526 12,942 12,268 13,698 13,522 12,938 12,262 13,690 13,497 12,916 12,244 13,686 13,470 12,910 12,204 13,682 13,457 12,898 12,194 13,678 13,448 12,894 12,154 13,648 13,410 12,752 12,150 13,644 13,396 12,748 12,146 13,632 13,332 12,654 12,138 13,628 13,314 12,650 12,122 13,624 13,224 12,646 12,118 13,620 13,172 12,642 12,092 13,616 13,150 12,554 12,088 13,608 13,146 12,550 12,084 13,604 13,128 12,546 12,036 13,600 13,066 12,412 12,032 13,596 13,016 12,408 12,000 13,582 12,986 12,404 11,996 13,578 12,982 12,394 11,930 13,574 12,974 12,390 11,926 13,570 12,970 Total of 94 feet, total 282 holes. All perforations are to be 3 SPF using 120° phasing.



Date: 10/5/2001 AFE# 01-06

Well Name: Roosevelt Unit 7W W. I. SW NW Sec. 19-T1S-R1E, Uintah County, Utah






Name:

Roosevelt Unit #9W Sec. 28, T1S, R1E

Uintah County, Utah

Well Data Depth: 13,500’ TD PBTD: 13,450’ Casing: 9-5/8”, 36#, K-55 set at 2515’

7”, 23, 26, & 29#, N-80 & 29, &32# S-95 & P-110 set surface to 11,079’

5”, 18#, S-95 set 10,396’ to 13,495’ Tubing: 2-7/8”, 6.5#, N-80 tubing set at +/-9425’ w/ B-2 anchor catcher. Packer: Arrow Set II or equivalent Perfs: Wasatch perfs 12,340’ - 13,378’ 11,700’ - 12,191’ Green River perfs 8,344’ – 9,616’ Procedure

1. MIRU service rig. POOH w/ rods and pump inspecting rods on TOOH. Hot oil tubing and run Dialog 32 arm caliper on tubing. ND tubing flange and NU BOP. Test BOP. POOH laying down reject tubing.

2. PU 6” bit and casing scraper on 2-7/8” tubing and TIH to top of 5” liner.

POOH laying down bit and scraper.

3. PU 4-1/8” bit and casing scraper on 2-3/8” tubing and TIH to PBTD. POOH laying down bit and scraper.

4. Perforate Wasatch 12,366 to 13,394’ with 3 SPF as per attached

procedure.

5. PU 5” treating packer on 1900’ of 2-7/8” P-105 and 3½” N-80 tubing and TIH setting packer at 12,250’+/-.



Exhibit “8”

7. Swab back acid and clean up well. After ph >5.0, release packer and POOH laying down 3½” & 2-7/8” P-105 tubing. Run GR log to determine stimulation coverage.

8. PU 7” tbg anchor with on/off tool and TIH setting anchor at 10,250’.

Release on/off tool and POOH. PU 7” XXX pkr., 1400’ of 5½”, 17#, N-80 casing, and 7” XXX packer on 2-7/8” tubing and TIH setting bottom pkr at 9,675’. Sting out of packer and POOH.

9. Rerun production tubing and latch onto on/off tool. ND BOP and NU well

head. Rerun rods and pump. Hang well on and release rig. Return well to production.

ROOSEVELT UNIT #9WSec. 28, T1S, R1EUintah County, Utah

9-5/8”, 36#, K-55 set @ 2,515’

Bowen OS @ 2049'

7”, 23#, N-80, 23, 26, 29#, S-95, & 32#S-95 & P-110 set @ 10,704’

7”, 23#, N-80, Surf-847'7”, 23#, S-95, 847'-3652'7”, 26#, S-95, 3652'-6055’7”, 29#, S-95, 6055-9746’7”, 32#, S-95 & P-110, 9746-10,704’

Top of cement @ 5620'

Perfs @ 8,344'-9,616'

CIBP set at 11,515' & 10,520'

7" casing set at 10,704'

5”,18#, P-110 set 10,396’-13,495’

Perfs @ 11,700'-12,191'


Perfs @ 12,377'-13,400'

PBTD at 13,450'TD at 13,500'



Perforations picked as per Schlumberger DIL, Dated 4/8/85 13,288 12,962 12,866 13,282 12,958 12,862 13,220 12,954 12,856 13,092 12,946 12,852 13,086 12,940 12,966 12,936 Total of 16 feet. All perforations are to be 3 SPF using 120° phasing.



Date: 7-12-01 AFE# 01-03

Well Name: Roosevelt Unit 9W W. I. nenw Sec. 28-T1S-R1E, Uintah County, Utah



Tangible CostsSurface CasingIntermediate CasingProduction Liner 18400TubingSubsurface Equipment 7400Wellhead EquipmentSurface EquipmentSubtotal 0 25800Total 0 171800



Name:


Uintah County, Utah

Well Data Depth: 13,074’ TD PBTD: 13,052’ Casing: 9-5/8”, 36#, K-55 set at 2476’

7”, 23#, S-95, 26#, N-80 & S-95, &29# S-95 & P-110 set surface to 10,979’

5”, 18#, N-80 & P-110 set 10,680’ to 13,074’ Tubing: 2-7/8”, 6.5#, N-80 tubing set at +/-12,800’ w/ B-2 anchor catcher. Perfs: Wasatch perfs 11,946’ - 12,957’ Procedure

1. MIRU service rig. POOH w/ rods and pump inspecting rods on TOOH. Hot oil tubing and run Weatherford 32 arm caliper on tubing. ND tubing flange and NU BOP. Test BOP. POOH laying down reject tubing.

2. PU 4-1/8” bit and casing scraper on 2-3/8” & 2-7/8” tubing and TIH to

PBTD. POOH laying down bit and scraper.


4. PU 5” treating packer on 100’ of 2-7/8” and 3½” N-80 tubing and TIH




7. PU 7” tbg anchor with 2-7/8” production tubing and TIH setting anchor at

10,550’. ND BOP and NU well head. Rerun rods and pump. Hang well on and release rig. Return well to production.


Exhibit “9”

ROOSEVELT UNIT #10WSec. 21, T1S, R1EUintah County, Utah

9-5/8”, 36#, J-55 set @ 2,476’

7”, 23#, S-95, 26# N-80 & S-95, & 29# S-95 & P-110 set @ 10,979’

7”, 26#, N-80, Surf-481'7”, 23#, S-95, 481'-2886'7”, 26#, S-95, 2886'-3846’7”, 29#, S-95, 3846-10,168'7”, 29#, P-110, 10,168'-10,979’

Top of cement @ 5600'


5”,18#, N-80 & P-110 set 10,680’-13,074’


Perfs @ 11,946'-12,957'

PBTD at 13,052'TD at 13,074'



Perforations picked as per Dresser Atlas DIL, Dated 4/26/84 12,982 12,600 12,492 12,978 12,540 12,488 12,874 12,536 12,484 12,870 12,532 12,480 12,708 12,528 12,250 12,626 12,524 12,246 12,622 12,496 12,242 12,604 Total of 22 feet. All perforations are to be 3 SPF using 120° phasing.



Date: 1/7/2002 AFE# 01-04

Well Name: Roosevelt Unit 10W W. I. SW NE Sec. 21-T1S-R1E, Uintah County, Utah



Tangible CostsSurface CasingIntermediate CasingProduction LinerTubingSubsurface EquipmentWellhead EquipmentSurface EquipmentSubtotal 0 0Total 0 195500



Name:

7-10-01

WORKOVER PROCEDURE Roosevelt Unit #C-11

Sec. 18, T1S, R1E Uintah County, Utah

Purpose To restore well to economic production from the Wasatch formation by adding perforations and stimulating old and new perforated intervals with and acid job.

Well Data Depth: 13,490’ TD Casing: 9-5/8”, 36#, K-55 set at 2515’ 7”, 23, 26, & 29#, N-80 & 29# SOO-95 set surface to 11,079’ 5”, 18#, S-95 set 10,786’ to 13,490’ Tubing: 2-7/8”, 6.5#, N-80 tubing set at +/-9425’ w/ B-2 anchor catcher. Packer: Arrow Set II or equivalent Perfs: Wasatch perfs 12,340’ to 13,378 Procedure

1. MIRU service rig. POOH w/ rods and pump. ND tubing flange and NU BOPE. Test BOP. POOH with tubing.

2. PU 4-1/8” bit and casing scraper on 2-7/8” & 2-3/8” tubing and TIH to

PBTD. POOH & LD down bit and scraper.

3. Perforate Wasatch 12,366 to 13,394’ with 3 SPF, per attached schedule.

4. PU 5” treating packer on 3 joints 2-3/8” N-80 and 3½” N-80 tubing, TIH and set packer at 10,835’

5. Stimulate Wasatch perfs 12,340’ to 13,394’, per enclosed procedure.

6. Swab back acid and clean up well. After ph >5.0, release packer and

POOH laying down 3½” tubing. Run after-frac GR log to determine stimulation coverage.

7. Rerun tubing. ND BOP and NU well head. Rerun rods and pump. Hang

well on and release rig. Put well on production.


Exhibit “10”

ROOSEVELT UNIT #C-11Sec. 18, T1S, R1E 7/10/2001Uintah County, Utah

9-5/8”, 36#, K-55 set @ 2,515’

7”, 23, 26, 29#, fN-80 & SOO-95 set @ 11,079’

7”, 23#, N-80, Surf-3450'7”, 26#, N-80, 3450'-6235’7”, 29#, N-80, 6235-9557’7”, 29#, SOO-95, 9557-11,079’

CIBP at 9,250' w/ 10' cement on top


5”,18#, S-95 set 10,786’-13,490’


Perfs @ 12,340'-13,378'

PBTD at 13,408'TD at 13,490'

7-10-01 Vince Guinn

Roosevelt Unit #C-11 Section 18, T1S, R1E Uintah County, Utah


Perforations picked as per Schlumberger DIL, Dated 4/8/85 13,394 12,874 12,416 13,386 12,864 12,394 13,302 12,778 12,390 13,072 12,768 12,376 13,068 12,746 12,366 13,042 12,742 13,036 12,686 13,016 12,682 13,006 12,576 13,002 12,554 12,986 12,550 12,982 12,420 Total of 29 feet. All perforations are to be 3 SPF using 120° phasing.



Date: 7-10-01 AFE# 01-02

Well Name: Roosevelt Unit C-11 W. I. nesw Sec. 18-T1S-R1E, Uintah County, Utah 62%??



Tangible CostsSurface CasingIntermediate CasingProduction LinerTubingSubsurface EquipmentWellhead EquipmentSurface EquipmentSubtotal 0 0Total 0 197900



Name:

Documents

Docket No. 2001-022 Cause No. 139-73 February 27, 2002 Road Runner Oil, Inc. and Gavilan Petroleum, Inc