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199-083
RECEIVED STATE OF ALASKA • r AL. OIL AND GAS CONSERVATION COMMISSION FEB 15 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon [j Repair Well u Plug Perforations ❑ Perforate LJ Other U Install New Tubing Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Ve16 S-frt Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended WeII ❑ a234. 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory ❑ 199 -083 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 • 50- 133 - 10106 -01 - 0) 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028997 J Soldotna Creek Unit (SCU) 22 -04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): • N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,140 feet Plugs measured N/A feet true vertical 10,470 feet Junk measured N/A feet 9,470` 9,494; Effective Depth measured 11,140 feet Packer measured 9,546; 10,276 feet true vertical 10,470 feet true vertical 9,470'; 9,494; feet 9,546; 10,276 Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11 -3/4" 1,413' 1,413' 3,070 psi 1,510 psi Intermediate 10,110' 7 -5/8" 10,100' 10,100' 6,890 psi 4,790 psi Production Liner 407' 5 -1/2" 10,100' 10,100' 9,190 psi 8,830 psi Liner 1,550' 3 -1/2" 11,096' 10,474' 10,160 psi 10,540 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2 -3/8" 4.7# / L -80 9,489' MD 9,489' TVD Tubing (size, grade, measured and true vertical depth) 4 -1/2 ". 12.6# / L -80 9,489' MD 9,489' TVD Tripoint FH Retrievable; 9,470'; 9,47Q ■••••••••••■1101 Packers and SSSV (type, measured and true vertical depth) Baker SC -1; Baker ZXP; 9,494'; 9,546'; 9,494'; 9,546'; N/A DW 1 Pkr; N/A 10,276' MDs 10,276' TVDs 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A SCANNED MAR 1 3 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 440 120 Subsequent to operation: 6 0 10 740 180 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil p El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -474 Contact Chad Helgeson Email chelgeson©hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature (3./74,17g Phone 907 - 777 -8405 Date 2115 Form 10-404 Revised 10/2012 RBDMS FEB 1 9 gIU 4Nr1 ,.z...._./3 Submit Original Only • • Soldotna Creek Unit SCHEMATIC Well SCU 22 -04 Completion Date: 10 -14 -99 Ililcorp Alaska, LLC PTD: 199 -083 API: 50- 133 - 10106 -01 CASING DETAIL Size WT Grade Conn ID Top Btm AFE= -1 _ 22" 28' 11 -3/4" 47 J -55 8rd 11" Surface 1,413' iii 7 -5/8" 39 N -80 Speed Tite 6.625" Surface 131' :I- 7 -I 7 -5/8" 33.7 N -80 X -line 6.765" 131' 3,623' In 7 -5/8" 29.7 N -80 Speed Tite 6.875" 3,623' 5,654' fit= A 7 -5/8" 33.7 N -80 Speed Tite 6.765" 5,654' 6,552' RKB = 18.85' 7 -5/8" 39 N -80 Speed Tite 6.625" 6,552' 10,100' J 1 L 5-1/2" liner 20 N -80 Hydril 4.778" 9,693' 10,100' 3 1/2" liner 9.2 L -80 Hydril 511 2.992" 9,546' 11,096' 3 TUBING DETAIL I 4 -1/2" 12.6 L -80 Buttress 3.958" Surf 2,322' 4 -1/2" 12.6 L -80 TDS 3.958" 2,322' 9,489' 2 -3/8" 4.6 L -80 8rd EUE 1.995" Surf 9,489' JEWELRY DETAIL DVT @ 6,983' N1 . Depth I D OD Tubing Hanger, 7 -1/16" x 4 -1/2" Butt., Type" H" BPV profile. CL prep. II 2,322' 4 -1/2" L-80 12.6 ft/lb Butt. tubing 4 2 9 489 3.958" 4.5° 4 -1/2" L -80 12.6 ft/lb TDS tubing 3 2,217' 3.865" 5.25" Chemical Injection Mandrel Macco Cm -3 2,311' 11 11 1 1 1 1 4,2097' 4 �'S89, 3.833" 5.983" Six 2 4-1/2" 7,589' Pocket Mandrel MACCO SMOR -1A with 1" GLV's and # # 1 8,994' ass , B 9,447 i • C 5 9,489' 4 -1/2" buttress x 3 -1/2" buttress crossover Baker Locator type seal ° — ' D 9,491' assembly (4.0" OD) a; . E 6 9,494' Baker SC-1 7-5/8" 39# ret. pkr with 10' 4" ID seal bore 5 7 9,543' 3 -1/2" buttress X nipple, 2.813" ID 6 t 7a 9,546' 3 -1/2" buttress seal assy, 5.5' long x 4.0" OD 7b 9,575' Baker ZXP liner top packer, failed pressure test Knock -out Isolation valve, 2.700" inner string clearance 3.437" ID when 8 9,589' 3.437" flapper knocked out 7 9 9,627' 2.813" 3 -1/2" Hydrill 511 X nipple, ID = 2.813" 1 ■ 7b 10 10,270' DPM Baker Bottom Trip Whipstock, 5 -1/2" 8 11 10,276' ELM 5 -1/2" DW_1 packer with slot for whipstock orientation S 12 11,108' Bottom of slotted liner 9 MINI INNER STRING JEWELRY DETAIL No. Depth ID OD Item A 19' 1.995" 7.00" Tubing Hanger B 9,417' 1.875" 3.063" 2 -3/8" EUE "X" Landing Nipple 10 G1 C 9,454' 1.995" 3.75" 2 -3/8" EUE GLM T -1 Latch Mandrel D 9,470' 1.995" 3.75" 4 -1/2" 9.5 -13.5# TriPoint FH Hydraulic Retrievable Pkr G2 H4 E 9,482' 1.791" 3.063" 2 -3/8" EUE "XN" Landing Nipple -- H5 G -2 Perfs 1 12 10,272'- 10,367'MD — Top H -4 Target @ 10,272'- 10,365'TVD 10,525'MD/10,469' TVD TD = 11,140' MD /10,470' TVD Total Horizontal Section (H- 4 -H5)= 600' L Window /Kick off Point @ 10,267'- 10,280' MAX HOLE ANGLE = 95.13 deg 35 deg/100' build 3- 1 /2 "perfed liner, 10,235'- 11,033' Updated by DMA 02 -15 -13 • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 22 -04 50- 133 - 10106 -01 199 -083 12/12/12 12/18/13 Daily Operations: 12/12/2012- Wednesday Started RU Williams WOR 405. MIRU SL, RIH w/ 3.80" GR and tag at 9,499' slm. POOH, PU a PX plug and RIH. Set plug in x- nipple (2.83) at 9,543' slm. POOH. PU PX Prong and RIH. Set in plug at 9,542' slm. POOH. SDFN. 12/13/2012 - Thursday Finished Final RU and winterization. 12/14/2012 - Friday Finished RU. Installed BPV, NU new tree adapter and BOP's. Set TBG hanger on 2 -3/8" test joint. 12/15/2012 - Saturday Tested BOPE per AOGCC. Witness waived by Jim Regg (250 low - 3,000 high). MIRU SL. RIH, pulled prong and plug. PU BHA consisting of WL Entry guide, X nipple (1.875) loaded with a RHCP, Hydraulic Packer, gas lift mandrel, x- nipple. RIH w/ 30 jts on 2 -3/8" at report time. (24 hr ops) 12/16/2012 - Sunday RIH w/ BHA and set packer at 9,469'. Dropped rod and tested tbg to 3,000 psi (30 min chart). Tested csg to 1,400 psi (charted to 30 mins). ND BOP's and NU 2- 1/16" PT. Set TWC and tested to 5,000 psi. 12/17/2012 - Monday Pulled TWC. RDMO Williams WOR. RU gaslift line to 4 -1/2 ". 12/18/2012 - Tuesday RU slickline, pull GL dummy, swab fluid from well. Pressure backside with 1,400 psi gas lift gas. Fluid help swab well down. • of 7.4 1 77, At A t THE STATE Alaska Oil and Gas , ®f l L 1 Conservation Commission rh GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0 p. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson Q S 3 Operations Engineer j5 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 " "" Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 22 -04 Sundry Number: 312 -474 SCANNED JAN 2 3 2Q13 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 3 day of December, 2012. Encl. „Al (4 ,,AL., iRECiEIVE�D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 12 2012 APPLICATION FOR SUNDRY APPROVALS ,�OGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wel❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casing Other. Install New Tubing 2. Operator Name: 4. Current Well Cla 1!tt/ 5. Permit to Drif Number. Hilcorp Alaska, LLC � u y `� 199-083 Exploratory Development si 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: • Anchorage, Alaska 99503 50-133-10106-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A Soldotna Creek Unit (SCU) 22-04 • Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028997 - Swanson River Field / Hemlock Oil •• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,140 10,470 - 11,140 10,470 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22” 28' 28' Surface 1,413' 11 -3/4" 1,413' 1,413' 3,070 psi 1,510 psi Intermediate 10,110' 7 -5/8" 10,100' 10,100' 6,890 psi 4,790 psi Production 407' 5 -1/2" 10,100' 10,100' 9,190 psi 8,830 psi Liner 1,550' 3 -1/2" 11,096' 10,474' 10,160 psi 10,540 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4 -1/2" 12.6" / L-80 2,322' Packers and SSSV Type: Baker SC -1 Pkr; Baker ZXP Pkr Packers and SSSV MD (t) and TVD (ft): • 9,494' MD & 'ND; 9,546' MD & TVD DW 1 Pkr; N/A 10,276' MD & TVD; N/A 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n • Exploratory n Stratigraphirn Development n • Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/13/12 Oil Q . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907- 777 -8405 EmaN chelgesoni'd)hilcorp.com Printed Name Chad Helgeson Title Operations Engineer Signature /7,7 � Phone 907 - 777 -8405 Date 12/12/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 - Lr7q Plug Integrity ❑ BOP Test ke Mechanical Integrity Test ❑ Location Clearance ❑ Other: 300(3 p:, a O l � s -c- RBDMS DEC 1 4 2012 Spacing Exception Required? Yes ❑ No i Subsequent Form Required: ` - 1 1 tt al APPROVED BY Approved by: '/ COMMISSIONER THE COMMISSION Date: 121 C51 I ) LiL 2NI Ay Fo 4R. i z • Approved application is v ali d en months from the date of app roval. Attach nts in pupiicate � / 4 • • Well Prognosis Well: SCU 22 -04 Hilcorn Alaska, LLC Date: 12/12/12 Well Name: SCU 22 -04 API Number: 50- 133 - 10106 -01 Current Status: Shut in Oil /Gas Producer _ Leg: N/A Estimated Start Date: December 13th, 2012 Rig: Williams #405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 199 -083 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) (832) 421 -8728 (M) AFE Number: 1222218 Current Bottom Hole Pressure: — 954 psi @ 9,627 TVD (Measured BHP Survey) Maximum Expected BHP: — 954 psi @ 9,627' TVD Max. Allowable Surface Pressure: — 175 psi (Based on a column of fluid in the well from formation.) Brief Well Summary This well was drilled and completed as a gas cap blowdown well in 1999. In 2004 a coiled tubing velocity string was installed to help remove fluid from the well, but the work wasn't successful to obtain sustained flowing pressures. The coiled tubing velocity string was removed in August, the lateral was attempted to be cleaned out, but the coil tubing work was unsuccessful. A new 2 -3/8" completion is planned to be run inside the 4 -1/2" ' tubing with the future ability to install a gas lifted plunger lift system in the future. Notes Regarding Wellbore Condition • Well current well status is a SI production well. Brief Procedure: 1. RU Slickline (PT lubricator to 1,500 psi). 2. RIH with 3.80" gauge ring. 3. RIH with PX plug and prong and set in X Nipple at 9,543ft. (note fluid depth). 4. RD Slickline. 5. Blowdown any gas pressure on the well, (shoot fluid level with an echo meter and record). 6. MIRU Williams #405 pulling unit. (Install winterization package) 7. Install C, ND lower master valve, NU new tree adapter, NU BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high. S 'C"� a. Notify AOGCC 24hrs in advance to witness test. _- /( 8. Pump 30 bbls of PW down tubing. 9. RU Slickline with lubricator, RIH and pull prong and plug. 10. RD slickline. 11. Ensure well is dead, shoot fluid level with echo meter. (If well is not dead, pump more fluid down well until well is dead) 12. PU new 2 -3/8" L -80 8rd EUE tubing and completion which consists of (WI Entry guide, XN nipple, hydraulic packer, gas lift mandrel (dummy), x nipple and new tubing to surface.) Space out and land tubing in new tubing hanger. 13. RU slickline, RIH and set plug in new tubing. • • , II Well Prognosis Well: SCU 22 -04 • Hilcorp Alaska, LLC Date: 12/12/12 14. Fill tubing with PW, pressure tubing to 3,000 psi (the packer should set at 2,500 psi), hold pressure on tubing for 30 min and chart. 15. Fill 4 -1/2" x 2 -3/8" tubing annulus with PW. PT annulus to 1,400 psi. a. If annulus pressure does not hold may be the GL mandrels on 4 -1/2" tubing, and plan to test annulus with gas. (chart for 30 min). 16. ND BOP, NU new tree, set BPV and PT tree to 5,0000 psi 17. RD Williams #405 18. Pull BPV. 19. RU braided line or slickline, RIH and pull GL dummy 20. Swab fluid from well and annulus, swab as deep as possible 21. RIH with new GL orifice and pull prong and plug. 22. Turn over well to production, RU gas lift to new annulus. Attachments: 1. Current Well Schematic 2. Proposed Schematic 3. BOP Schematic 4. New Wellhead Schematic • • Soldotna Creek Unit Well SCU 22 -04 ., 14 SCHEMATIC Completion Date: 10 -14 -99 HiIcoru Alaska, LLC PTD: 199 -083 API: 50- 133 - 10106 -01 Casing Detail _ SIZE WT GRADE CONN ID TOP BTM. J C. � I 22" 28' I. 11 -3/4" 47 J -55 8rd 11 Surface 1,413' ■ 7 -5/8" 39 N -80 Speed Tite 6.625 Surface 131' :I- .I 7 -5/8" 33.7 N -80 X -line 6.765 131' 3,623' 7 -5/8" 29.7 N -80 Speed Tite 6.875 3,623' 5,654' IF .''.'. 7 -5/8" 33.7 N -80 Speed Tite 6.765 5,654' 6,552' RKB = 18.85' 7 -5/8" 39 N -80 Speed Tite 6.625 6,552' 10,100' J 2 '' L 5-1/2" liner 20 N -80 Hydril 4.778 9,693' 10,100' 3 -1/2" liner 9.2 L -80 Hydril 511 2.992 9,546' 11,096' 3 Tubing Detail I I I I 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 2,322' 4 4 -1/2" 12.6 L -80 TDS 3.958 2,322' 9,470' an Jewelry Detail NO. Depth ID OD Item DVT @ 6,983' 1 18' - - Tubing Hanger, 7- 1/16" x 4 -1/2" Butt., Type" H" BPV profile. CL prep. 2,322' 4 -1/2" L -80 12.6 ft /lb Butt. tubing i IIIMIk '; 2 9 489' 3.958 4.5 4 -1/2" L-80 12.6 ft /lb TDS tubing 3 2,217' 3.865 5.25 Chemical Injection Mandrel Macco Cm -3 2,311' 5 4,207' 6 4 5,997' 3.833 5.983 Six 4 -1/2" Side Pocket Mandrel MACCO SMOR -1A with 1" GLV's and 7,589' BK -2 Latches 8,994' 7 9,447' _ �i _ 9,489' 4 -1/2" buttress x 3 -1/2" buttress crossover Baker Locator type seal 7b 5 9,491' assembly (4.0" OD) g 6 9,494' Baker SC-1 7-5/8" 39# ret. pkr with 10' 4" ID seal bore g 7 9,543' 3 -1/2" buttress X nipple, 2.813" ID 7a 9,546' 3 -1/2" buttress seal assy, 5.5' long x 4.0" OD 9 7b 9,575' Baker ZXP liner top packer, failed pressure test MIN 8 9,589' 3.437 Knock -out Isolation valve, 2.700" inner string clearance 3.437" ID when flapper knocked out 9 9,627' 2.813 3 -1/2" Hydril) 511 X nipple, ID = 2.813" 10 10,270' DPM Baker Bottom Trip Whipstock, 5 -1/2" , 10 G1 11 10,276' ELM 5 -1/2" DW_3 packer with slot for whipstock orientation G2 12 11,108' Bottom of slotted liner H4 ---- H5 ------- 11 �� --- - - - - -- G -2 Perfs ..... . _ . _ . _ .......... 1 12 10,272'40,367' MD Top H -4 Target @ 10,272'- 10,365'ND 10,525'MD/10,469' ND TD = 11,140' MD/10,470' ND Total Horizontal Section (H- 4 -H5)= 600' Window /Kick off Point @ 10,267' - 10,280' MAX HOLE ANGLE = 95.13 deg 35 deg /100' build 3- 1 /2 "perfed liner, 10,235'- 11,033' Updated by DMA 12 - 11 - 12 • • Soldotna Creek Unit PROPOSED Well SCU 22 -04 . la Completion Date: 10 -14 -99 Ililcora Alaska, LLC PTD: 199 -083 API: 50- 133 - 10106 -01 Casing Detail ■ SIZE WT GRADE CONN ID TOP BTM. jrr _ l - .I 22" 28' 11 -3/4" 47 1 -55 8rd 11 Surface 1,413' iii 7 -5/8" 39 N -80 Speed Tite 6.625 Surface 131' :I � I 7 -5/8" 33.7 N -80 X -line 6.765 131' 3,623' m 7 -5/8" 29.7 N -80 Speed Tite 6.875 3,623' 5,654' �t 7 -5/8" 33.7 N -80 Speed Tite 6.765 5,654' 6,552' RKB = 18.85' 7 -5/8" 39 N -80 Speed Tite 6.625 6,552' 10,100' - 2 L 5 -1/2" liner 20 N -80 Hydril 4.778 9,693' 10,100' 3 -1/2" liner 9.2 L -80 Hydril 511 2.992 9,546' 11,096' 3 Tubing Detail i 4-1/2" 12.6 L -80 Buttress 3.958 Surf 2,322' 4 4 -1/2" 12.6 L -80 TDS 3.958 2,322' 9,489' ,�■ 2 -3/8" 4.6 L -80 8rd EUE 1.995 Surf 9,488 Jewelry Detail 1 II II DVT @ 6,983' NO. Depth ID OD Item II II 1 18' 3.958 - -. 4,5 Tubing Hanger, 7- 1/16" x 4 -1/2" Butt., Type" H" BPV profile. CL prep. 2 2,322 4 -1/2" L- 8012,6 ft /Ib Butt. tubing imam 9,489' 4 -1/2" L-80 12.6 ft /lb TDS tubing 3 2,217' 3.865 5.25 Chemical Injection Mandrel Macco Cm -3 2,311' 4,207' if I 4 7'589, 3.833 5.983 Six 4 1 /2" Side Pocket Mandrel MACCO SMOR -1A with 1" GLV's and BK-2 91111111111111* . 8,994' 4 9,449' ' A 9 4 -1/2" buttress x 3 -1/2" buttress crossover Baker Locator type seal '= B 5 9,491' assembly (4.0" OD) g: - . 1 " C 6 9,494' Baker SC-1 7-5/8" 39# ret. pkr with 10' 4" ID seal bore 1 1 D 7 9,543' 3 -1/2" buttress X nipple, 2.813" ID 6 5 7a 9,546' 3 -1/2" buttress seal assy, 5.5' long x 4.0" OD ► =: 7b 9,575' Baker ZXP liner top packer, failed pressure test II II 8 9,589' 3.437 Knock -out Isolation valve, 2.700" inner string clearance 3.437" ID when flapper knocked out 7 MN 9 9,627' 2.813 3 -1/2" Hydrill 511 X nipple, ID = 2.813" 1 7b 10 10,270' DPM Baker Bottom Trip Whipstock, 5 -1/2" 11 10,276' ELM 5 -1/2" DW_3 packer with slot for whipstock orientation 8 12 11,108' Bottom of slotted liner Inner String Jewelry Detail 9 IBM NO. Depth ID OD Item , A 9,415' 1.875 3.063 X- Nipple B 9,453' 1.995 3.75 Gas Lift Mandrel T -1 Latch C 9,469' 1.94 3.75 TriPoint FH Hydraulic Retrievable Packer 10 G3 D 9,481' 1.791 3.063 TT d ing Nipple G2 H4 11 ............ .......... H5 G -2 Perfs ....... - - - - - - - _I 12 10,272'- 10,367'MD Top H -4 Target @ 10,272'- 10,365'TVD 10,525'MD/10,469' ND TD = 11,140' MD /10,470' ND Total Horizontal Section (H- 4 -HS)= 600' L Window /Kick off Point @ 10,267'- 10,280' MAX HOLE ANGLE = 95.13 deg 35 deg /100' build 3- 1 /2 "perfed liner, 10,235' - 11,033' Updated by CAH 12 -12 -12 • Swanson River 2012 Williams Rig BOP 07/31/2012 3.07' • Hydril GK 7 1/16 -5000 III III Ill IIIIll Ill Iii lil III Iil I ' CIW U 3.68' -� 1 '` NI L H H �) 7 1/16-5000 riblir - [ti Iii Iii Iii I - Choke - si I11 1I111i III III i ' ' - 11- rkt 2.00' +4,. } 1�� ► 11 {c °� � . lama Jam . INA r li1lI 5000, Kill • • Swanson River SCU 22 -04 Proposed 12/11/2012 11ilr..rp V,1•1,... 1.1 Swanson River SCU 22 -04 Proposed 2 3/8 completion thru 4 %tubing ti` ' . _____ 2 1/16 5M Tree assy Q al s e r o �[o (J -II I c ° = . N c o ..:111W! Po ( p n c O IMO Y v ' ' WIN so9 •• Tbg head, Seaboard -S, _ —� I _ 11 5M X 71/165M �� �' .r w/ 2- 2 1/16 5M SSO, SP- mit I1, 2 bottom prep, bored out for 7 5/8 casing -.,` � .�•'�` - 24" `f ' `f ►i .I Ili Adapter, 11 5M FE X 7 1/16 5M stdd, bored out fill 1 I Iii 7 to seal on 4 %tubing hanger neck .— = - Ground level Tbg head, Seaboard -S, 13 5/8 3M X 7 1/16 5M - Valve, Seaboard, w/ 2- 2 1/16 5M SSO, SP- . 1_ /, `, j„ 2 1/16 5M FE, HWO, Qty 2 2 bottom prep, bored out �'I � ■■ �,[- ° �I � ��' for 75/8 casing -�� ' III 1111 gitium Casing head, Shaffer KD, 1 IMF . 35/83MX11 %SOW, ill' eau w/ 2- 2" LPO, 7 5/8 KD slip and seal unit in head �,. ■U. It 43 t o: Valve, CIW -F, 2" LPO i f 0 Or ■ ' STATE OF ALASKA • ALs OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations ❑ Perforate ❑ Other U Pull Velocity String Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development © Exploratory 0 , 199 -083 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: Alaska 99503 50 -133- 10106 -01 7. Property Designation (Lease Number): .. 8. Well Name and Number: Soldotna Creek Unit (FEDA028997) Soldotna Creek Unit (SCU) 22 -04 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,, N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,140 feet Plugs measured N/A feet true vertical 10,470 feet Junk measured N/A feet 9,494; Effective Depth measured 11,140 feet Packer measured 9,546; 10,276 feet true vertical 10,470 feet true vertical 9,494; 9,546; 10,276 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11 -3/4" 1,413' 1,413' 3,070 psi 1,510 psi Intermediate 10,100' 7 -5/8" 10,100' 10,100' 6,890 psi 4,790 psi Production 407' 5 -1/2" 10,100' 10,100' 9,190 psi 8,830 psi Liner 1,550' 3 -1/2" 11,096' 10,474' 10,160 psi 10,540 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic :r'.,,.d' , j €P°a,; N ;': 2, a r_';in 4 Tubing (size, grade, measured and true vertical depth) 4 -1/2" L -80 9,470' MD 9,470' TVD Baker SC -1 Pkr 9,494' MD & TVD Baker ZXP Pkr 9,546' MD & TVD Packers and SSSV (type, measured and true vertical depth) DW 1 Pkr 10,276' MD & TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A C E f V E D Intervals treated (measured): N/A AUG 2012 Treatment descriptions including volumes used and final pressure: N/A ��°°yy OGCl� 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 700 500 Subsequent to operation: 3 800 80 900 150 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 .. Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ,. s Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sus ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -269 Contact Chad Helgeson Phone: 907 - 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature ` _"_" Phone 907-777-8300 Date 8/30/2012 Hap MS AUG 3 1 201 ` /2 , ��i�� Form 10-404 Revised 11/2011 l ^ Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 22 -04 50- 133 - 10106 -01 199-083 7/25/12 7 30 12 Daily 0 14 4 04. 1 944: , , , . , . , .. ... , 7/25/2012- Wednesday Spot coil equipment and start RU coil. 7/26/2012 - Thursday Continue to spot equipment and RU coil. Jim Regg, AOGCC waived witness of BOP test., Received approval for rain - for -rent tank with portable containment. Spot slickline equiment and RU lubricator. Pressure test to 250 psi low and 2500 psi high. RIH with 1.30" GR to 10,568' RKB SLM. Tubing tally shows XN nipple at 10,529' RKB with a 1.135" ID. POOH. Continue RU coil tubing unit. RIH with XN plug and attempted to set in profile nipple at 10,568' RKB SLM. POOH. Plug was still on tools. Had dry brown like paraffin cake on plug. Tools were dry like there was no fluid in the coil. RIH with braided line brush and brushed nipple at 10,568' RKB SLM. Went thru nipple and set down at 10,588' RKB SLM. POOH. RD slickline lubricator and secure well. 7/27/2012 - Friday Mob to location. RU slickline lubricator, pressure test to 250 low and 2,500 psi high. RIH with XN plug and attempted to set plug at 10,568'. Could not get plug to set. POOH. RD lubricator and move slickline equipment. 7/28/2012 - Saturday Mob to location and start equipment. Prep coil tubing for the SLB coil dimple connector. Put connector on and pull tested to 35,000 lbs. SLB coil pumped 220 bbls of produced water to kill well. Pumped 2 bpm at 200 psi. Mobe slickline to location and RU lubricator. Pressure tested 250 psi low and 2500 psi high. RIH with 3 -1/2" GS tool with 2.77" OD collet. Latched coil profile and pulled 1,200 Ibs over tool wt. Sheared GS tool and POOH. RD slickline and secure well. 7/29/2012 - Sunday Mobe to location. Start equipment. Shell test coil to 3,000 psi. Pump 149 bbls of produced water at 4 bpm. Well had 220 psi on it when it was opened up. Pressure dropped to zero psi after pumping 10 bbls and stayed at a zero psi throughout the rest of the pumping operation (143 bbls to fill coil and backside). Monitor well for 1 hour and well stayed at zero psi. Pumped 112 bbls to check for gas bubble and well stayed at zero psi. Put 3 -1/2" GS slickline tool on coil and attempted to latch velocity string profile. Sheared brass pin in GS tool. Pin tool with steel pin and latched profile. Pulled 20k to unseat velocit stY ring hanger and picked_up 8' and wt dropped to 14.5k. Broke lubricator and cut off BHA and velocity coil string hanger. Connected velocity string coil to coil tubing with cold roll. Pulled 10,489' of velocity coil out of well. Pumped diesel with test pump every 15 min to cut the paraffin until 2,500' out of well. Pumped total of approx 20 gals. RD BOP and lubricator off well. 7/30/2012 - Monday Spool off velocity string off spool. Move equipment to SCU 42 -4. . • • Swanson River SCHEMATIC Well SCU 22 -04 Hilcorp Alaska, LLC Velocity String Completion Casing Detail - SIZE WT GRADE CONN ID TOP BTM. ]lEi _ I' 'I 22" 28' in III.: 11 -3/4" 47 J -55 8rd 11 Surface 1,413' 7 -5/8" 39 N -80 Speed Tite 6.625 Surface 131' i L- . l� , -1 7 -5/8" 33.7 N -80 X -line 6.765 131' 3,623' -MP 7 -5/8" 29.7 N -80 Speed Tite 6.875 3,623' 5,654' MP; 7 -5/8" 33.7 N -80 Speed Tite 6.765 5,654' 6,552' RKB = 18.85' 7 -5/8" 39 N -80 Speed Tite 6.625 6,552' 10,100' -j 2 [1- 5 -1/2" liner 20 N -80 Hydril 4.778 9,693' 10,100' 3 -1/2" liner 9.2 L -80 Hydril 511 2.992 9,546' 11,096' 3 Tubing Detail _ 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 2,322' 4 4 -1/2" 12.6 _ L -80 TDS 3.958 2,322' 9,470' Jewelry Detail _ NO. Depth ID OD Item DVT @ 6,983' 1 18' - - Tubing Hanger, 7- 1/16" x 4 -1/2" Butt., Type" H" BPV profile. CL prep. - 2,322' 4 -1/2" L -80 12.6 ft/lb Butt. tubing 2 9 489' 3.958 4.5 4 -1/2" L -80 12.6 ft/lb TDS tubing 3 2,217' 3.865 5.25 Chemical Injection Mandrel Macco Cm -3 2,311' 5 4,207' 6 ► 4 5,997 3.833 5.983 Six 4 -1/2" Side Pocket Mandrel MACCO SMOR -1A with 1" GLV's and 7,589' BK -2 Latches • ill 8,994' 9,447' 7 _ 9,489' 4 -1/2" buttress x 3 -1/2" buttress crossover Baker Locator type seal 7b 5 9,491' assembly (4.0" OD) 6 9,494' Baker SC -1 7 -5/8" 39# ret. pkr with 10' 4" ID seal bore ' 7 9,543' 3 -1/2" buttress X nipple, 2.813" ID 7a 9,546' 3 -1/2" buttress seal assy, 5.5' long x 4.0" OD 9 7b 9,575' Baker ZXP liner top packer, failed pressure test 8 9,589' 3.437 Knock -out Isolation valve, 2.700" inner string clearance 3.437" ID when flapper knocked out 9 9,627' 2.813 3 -1/2" Hydrill 511 X nipple, ID = 2.813" 10 10,270' DPM Baker Bottom Trip Whipstock, 5 -1/2" 10 G1 11 10,276' ELM 5 -1/2" DW_1 packer with slot for whipstock orientation G2 12 11,108' Bottom of slotted liner H4 H5 ------------ 11 ----------- G -2 Perfs ----- 1 _ 12 10,272'- 10,367'MD Top H -4 Target @ 10,272'- 10,365'TVD 10,525'MD/10,469' TVD TD = 11,140' MD /10,470' TVD Total Horizontal Section (H- 4 -H5)= 600' Window /Kick off Point @ 10,267'- 10,280' MAX HOLE ANGLE = 95.13 deg 4 1 35 deg /100' build 3 -1/2 "perfed liner, 10,235'-11,033' Revised by: TDF 8/23/2012 ' • • TJ a SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chad Helgeson +Y , ,�� � �� 8-3 Operations Engineer 0 Hilcorp Alaska, LLC (h 3800 Centerpoint Drive t 1 Anchorage, AK 99524 Re: Swanson River Field, Hemlock Oil Pool, SCU 22 -04 Sundry Number: 312 -269 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / i ____/,4"16,1/4.___, Cathy " . Foerster Chair DATED this L,D day of July, 2012. Encl. • • RECEIVED STATE OF ALASKA JUL 2 3 ZO1 ALASKA OIL AND GAS CONSERVATION COMMISSION QJ per' /2 / APPLICATION FOR SUNDRY APPROVALS AOGCC Z 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Pull Velocity String I0, 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska, LLC Development El - Exploratory ❑ 199 -083 ` 3. Address: Stratigraphic Ill Service ❑ 6. API Number: 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50- 133 - 10106 -01 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ Soldotna Creek Unit (SCU) 22 -04 , 9. Property Designation (Lease Number): 10. Field / Pool(s): Soldotna Creek Unit (FEDA028997) 1 Swanson River Field / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,140 • 10,470 • 11,140 10,470 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11 -3/4" 1,413' 1,413' 3,070 psi 1,510 psi Intermediate 10,100' 7 -5/8" 10,100' 10,100' 9,180 psi 8,820 psi Production 407' 5 -1/2" 10,100' 10,100' 9,190 psi 8,830 psi Liner 1,550' 3 -1/2" 11,096' 11,474' 10,160 psi 10,540 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4 -1/2" L -80 9,470 Packers and SSSV Type: Baker SC -1, 7 -5/8 ", 39# ret. Pkr w/ 10' 4" seal Packers and SSSV MD (ft) and TVD (ft): bore N/A 9,494 (MD); 9,494 (TVD) - N/A 12. Attachments: Description Summary of Proposal © 13. Well Class after proposed work: Detailed Operations Program ID BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for / 15. Well Status after proposed work: 25- Jul -12 Commencing Operations: Oil El • Gas 0 WDSPL ❑ Suspended 0 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777 -8300 Printed Name Chad Helgeson 777 -8300 Title Operations Engineer Signature /J / J ,�� //, Phone Date 1/z 3 /i / //'`/ � G'7^/1 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 2- z (DR Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other stop S k ? U P i/s ( cT1) Subsequent Form Required: / —1 1 0Lf APPROVED BY Approved by: ( COMMISSIONER THE COMMISSION Date: 7— 1Z {� der ��+ , .` / i Dry1VL303 is�d�l/ 7 H� y rZ ORIGIN A L X 7 77 /Yu bmit in Duplicate Av ✓ X • • Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524 -4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907 /777 -8405 July 23, 2012 Fax: 907/777-8510 Mr. Guy Schwartz RECEIVED Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission JUL 2 3 2012 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 AOGCC Re: Swanson River Coiled Tubing Work Summer 2012 Dear Mr. Schwartz: Please find enclosed a 10 -403 request to remove a coiled tubing velocity string from the Soldotna Creek 22 -04 well. This is the first of several coiled tubing projects we plan to complete this summer. As per my phone discussion with you on July 17 this letter describes the work currently planned for the Schlumberger Coiled Tubing Unit (CTU) in Swanson River. The work planned for each well does not specifically require a 10 -403, but per our requirement to notify you of starting coiled tubing work in the field we are requesting approval to commence the work described below. The following gives a brief summary of the work planned for the coiled tubing rig. () SCU 22 -4, (PTD# 199 -083) will be the first project completed in Swanson River in the summer of 2012 with the Schlumberger CTU. The well currently has a 1.75" coiled tubing velocity string installed that will be removed and then the well will be cleaned out to TD in the horizontal. SCU 42 -4 (PTD# 200 -087) will be the second well the Schlumberger CTU will be used on. This well has the same completion as 22 -4, where the velocity string will be removed and the well will be cleaned out to TD in the horizontal. 3 \ SCU 23A -9 (PTD# 200 -073) will be the third well the Schlumberger CTU will be used on. This well is a deviated well with fill tagged with slickline, but cannot be cleaned out due to the horizontal nature of the wellbore. The well will be cleaned out with N2 and returned to production. SCU 43B -8 (PTD# 190 -152) is the fourth well that might be worked on with coiled tubing. This well is a gas producer that has a through- tubing gravel pack that was installed in 2008. The well has a history of gas production that is difficult to maintain because of the well completion. After slickline work is performed, coiled tubing may be needed to cleanout and possibly remove the gravel pack and replaced. • • Mr. Guy Schwartz July 23, 2012 Page 2 of 2 The SCU wells 22 -4, 42 -4 and 23A -9 will be brought back onto production after the coil work; however, if it is unsuccessful, a rig work over may be required where additional 10 -403's will be completed for that work. Hilcorp requests the approval to move the Schlumberger CTU to Swanson River and complete this work, 24hr notice will be provided for BOP testing. Equipment will be mobilized this week to Swanson River, so an expeditious review of this project would be greatly appreciated. If you have any questions regarding this work, please contact me via email (chelgeson @hilcorp.com) or via phone (777 -8405 office, 229 -4824 cell). Sincerely, HILCORP ALASKA, LLC Chad A. Helgeson Operations Engineer CAH:dma 10 -403 for SCU 22 -04 Procedure for work on SCU 22 -04 Well diagrams, SCU 22 -04, SCU 42 -04, SCU 23A -09, and SCU 43B -08 cc: Well File Y y • • Well Prognosis • Well: SCU 22 -04 Hilcorn Alaska, LLC Date: 7/23/2012 Well Name: SCU 22 -04 API Number: 50- 133 - 10106 -01 Current Status: Shut in Gas Producer Leg: N/A Estimated Start Date: July 25th, 2012 Rig: SLB Coiled Tubing Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 199 -083 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) (832) 421 -8728 (M) AFE Number: 1222218 Current Bottom Hole Pressure: — 1,000 psi @ 9,627 TVD (Calc. from surface pressure and Historic Reservoir data) Maximum Expected BHP: — 1,000 psi @ 9,627' TVD Max. Allowable Surface Pressure: — 1,000 psi Brief Well Summary This well was drilled and completed as a gas cap blowdown well in 1999. In 2004 a coiled tubing velocity string was installed to help remove fluid from the well, but the work wasn't successful to obtain sustained flowing pressures. The plan is to pull the coiled tubing completion, cleanout lateral, prep well for a rig workover. Notes Regarding Wellbore Condition • Well current well status is a SI production well. Brief Procedure: 1. Nipple down swab valve and install new flow cross and swab valve. 2. RU slickline. Pressure test lubricator 250psi low /2500psi high. 3. RIH w/ GS tool and pull CT hanger. LD Slickline. 4. RU 1.75" coiled tubing equipment. 5. Test coiled tubing BOP's to 3000 psi. (notify state 24hrs in advance) 6. RU fishing tools on bottom of coil, RIH and latch coil seal assembly. 7. POH with coil velocity string. Reel up on temp coil reel. LD BHA. 8. RU CT workstring on well, RIH to bottom, tag up and circulate N2 through choke to blow down tank. 4 FC 9. RD CT and turn well over to production. Attachments: 1. As -built Schematic , ., • Swanson River SCHEMATIC Well SCU 22 -04 Hilcorp Alaska, LLC Velocity String Completion mx CASING AND TUBING DETAIL • ; ■ , r _ 22 SIZE WT GRADE CONN ID TOP BTM. I • I " - - - 28' 11 -3/4" 47 J -55 8rd 11.000 Surface 1413' I. (t- - 7 -5/8" 39 N -80 Speed Tite 6.625 Surface 131' t. 7 -5/8" 33.7 N -80 X -line 6.765 131' 3623' ._� T� — 7 -5/8" 29.7 N -80 Speed Tite 6.875 3623' 5654' I r -1 . - 7 -5/8" 33.7 N -80 Speed Tite 6.765 5654' 6552' A 1 I 7 -5/8" 39 N -80 Speed Tite 6.625 6552' 10,100' Iv: - 5 -1/2" liner 20 N -80 Hydril 4.778 9693' 10,100' RKB = 18.85' ! L 3 -1/2" liner 9.2 L -80 Hydril 511 2.992 9546' 11,096' J L J L Tubing 1. . 1111 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 2322' 3 CC 4 -1/2" 12.6 L -80 TDS 3.958 2322' 9470' 1 -3/4" Coil HS -80 NA Surf 10,489' 4 JEWELRY DETAIL NO. Depth ID OD Item A i 1 18' Tubing Hanger, 7- 1/16" x 4 -1/2" Butt., Type" H" BPV profile. CL 6983' prep. L 11. a ' DVT @ 2 2322' 3.958 4.500 4 -1/2" L -80 12.6 ft/lb Butt. tubing IN I` 9489' 4 -1/2" L -80 12.6 ft/lb TDS tubing ■ 3 2217 3.865 5.25 Chemical Injection Mandrel Macco Cm -3 I= 4 2311' 3.833 5.983 Six 4 -1/2" Side Pocket Mandrel MACCO SMOR -1A 4207' with 1" GLVs and BK -2 latches 5 5997' 6 7589' 10.1741 8994' 9447' • ill 5 9489' 4 -1/2" buttress x 3 -1/2" buttress crossover 9491' Baker Locator type seal assembly (4.0" OD) • • 6 9494' Baker SC -1 7 -5/8" 39# ret. pkr with 10' 4" ID seal bore 4 L , 7b 7 9543' 3 -1/2" buttress X nipple, 2.813" ID 7a 9575' 3 -1/2" buttress seal assy, 5.5' long x 4.0" OD jjSS, 9 ■ ■ 7b 9546' Baker ZXP liner top packer, failed pressure test 8 9589' 3.437 Knock -out Isolation valve, 2.700" inner string clearance 3.437" ID when flapper knocked out 9 9627' 2.813 3 -1/2" Hydrill 511 X nipple, ID = 2.813" 10 10,270' DPM Baker Bottom Trip Whipstock, 5-1/2" 11 10,276' ELM 5 -1/2" DW 1 packer with slot for whipstock orientation 12 11108' Bottom of slotted liner A Surface Tie -Back stem B —1' TIW CT Auto "J" Hngr w/ Tie -Back reciprocal w/ CTC ✓ 10 G1 C 10,489' CTC, Pup joint, Profile Nipple & Shear Sub G2 H4 at — H5 ---- � ............... _1 G -2 Perfs Top H -4 Target @ 10272'- 10367' 10525'MD/10,469' T' ) TD = 11140' MD/10,469' TVD Total Horizontal Section (H- 4 -H5)= 600' indow/Kick off Point @ 10,267' - 10280' MAX HOLE ANGLE = 95.13 dee L 35 deg/100' build 3 -1/2 "perfed liner, 10235'- 11033' SCU 22 -04 Schematic 7 -23 -2012 Drawn by: TAB (updated CRW) 2/9/2005 ." ( (" RECEIVED APR 2. n 2005 UNOCAL@) "-Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com I\la$ka Oil <?i Gas Cons. Commissíùik Anchorage April 29, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 Re: Request for Variance-Swanson River Mr. Aubert, We are requesting a variance of 20 MC 25.285 (c) (9) and (10). We are preparing to perform well intervention work with a "well servicing unit" provided by Nabors Alaska Drilling, currently stacked at Swanson River. We augmented the BOP equipment on the unit to satisfy our internal standards. Last year we worked with you to obtain a variance to work over several wells in the Swanson River field. We continue to believe the proposed system is superior in well control capabilities to BOPE configurations that are presently in use in the United States and Canada for wells with equivalent pressure and flow regimes. tCÛ'~(fð3 We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the wells to be worked on; the highest maximum anticipated surface pressure (MASP) and the proposed BOP configuration. Additionally you wíll find a schematic of the proposed BOPE layout. Sincerely, '?: ~C<b Timothy C:~ndenbUrg Drilling Manager $CANNED NO\f 1 7 2005 Attachments Union on Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com ( (' Well Descriptions Well Work Inventory SCU 32-08 SRU 23-15 SCU 22-04 lqq-D<¿~ SCU 314-04 S RU 14-15 SRU 12-15 Reservoir The highest BHP of any well to be worked on at this time is 3000 psi @ 10,900' TVD (Hemlock) which is equivalent to a .275 psi/ft gradient or a 5.29 ppg EMW. Fully evacuated, the MASP would be as follows: 3000 psi BHP - (10,900' TVD x .1 psi/ft Gas Gradient) = 1,91 Opsi MASP. Proposed Confi~uration BOP's Annular,5K 7-1/16" or 11" Double gate, 5K, 7-1/16" or 11" Mud Cross, 7 -1/16" and 11 " (optional based on BOP height) Accumulator 1 - 90 gallon Bounty Accumulator System 9-10 gallon Barksdale Control Valves Marsh Gauges 1 - Pump, Union Pump Comp., Model #BIT-532-55 1 - Newman Electric Motor 4 - 11 Gallon Nitrogen Bottles Pits The pit consists of a 150 bbl tank partitioned into 50 bbl compartments. Pump The pump is an Western Roughrider 1000 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 3000 psi Iron or 2", 5000 psi hoses with integral Fig 1502 hammer Unions. Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16",5K valves attached to either the mud cross or the tubing spool annulus valve. (' ( Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke line The choke line will consist of 2",5,000 psi hoses with 2-1/16" 5m API Flange. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and four valves. Choke Return line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the three 50 bbl compartments of the pits. It is constructed with an open bottom that utilizes the hydrostatic level in the tank for the water leg. The gas buster vents vertically. Gas Detection We are proposing that a single gas LEL monitor be placed at the work platform. PVT We are proposing to work with out a PVT system as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. UNOCAL SWANSON ~ ............... ----- I ~ ~ ~ I I I II Pipe Ram II I I II Blinds II I I I ~ PSA ~ 2" 5M MGV 2" 5M MGV I [II rn OJ 11" or 7-1/16" 5M Annular 5M Studded Top and Flanged Bottom ~11"or7-1/16"5M DBL ~ ~ Optional 3111" or 7-1/16" 5M Drilling Spool w/ 2 ea 4" 5M OTL 12", 5m Hose wI flange connections. 1 11" or 7-1/16" 5M Hydril Annular BOP 2 11" or 7-1/16" 5M Shaffer LWS Double BOP 3 11" or 7-1/16" 5M Drilling Spool w/2 ea 4" 5M OTL (Optional) 4 2 1/16 5M Manual Gate Valve 521/16 5M Manual Gate Valve 6 2 1/16 5M Manual Gate Valve 7 2 1/16 5M Manual Gate Valve ~, 2" 5m High Pressure hose. To Flow Back Tank '~ .~ . , STATE OF ALASKA ) AlA~1. Oil AND GAS CONSERVATION COMI\.. :SION REPORT OF SUNDRY WELL OPERATIONS I 8 Z005 PO Box 196247, Anchorage, AK 99519 Oil Stimulate U Other lJ. . Jn~t~I,I.\{~!OClty Stnng Waiver D Time Extension D'; Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 99-83 Service D 6. API Number: 50-133-10106-01 9. Well Name and Number: SCU 22-04 10. Field/Pool(s): Swanson River Field/Hemlock 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D 3. Address: ". 7. KB Elevation (ft): 170.92' RKB MSL 8. Property Designation: Soldatna Creek Unit 11. Present Well Condition Summary: Tubing: (size, grade, and measured depth) Velocity string (1-3/4") Surface -10489' Packers and SSSV (type and measured depth) Total Depth Effective Depth Casing Structural Conductor Surface Production Liner Liner Perforation depth: measured 11 ,140' feet true vertical 10,443' feet measured 11 ,140' feet true vertical 10,443" feet Length Size MD 28' 22" 28' 1,413' 11-3/4" 1,413' 10,100 7-5/8" 10,100' 407' 5-1/2" 10,100' 1,550' 3-1/2" 11,096' Plugs (measured) Junk (measured) TVD Burst Collapse 28' 1 ,409' 737 (1 OOOlb) 3,070 psi 10,074' 683 (1 OOOlb) 4,790 psi 10,074' 466 (1000lb) 8,830 psi 10,477' Measured depth: 10,235' to 11,033' SCANNED FEB 2 :3 2005 True Vertical depth: 10,208' to 10,452' 4-1/2" L-80 9,470 Baker SC-1, 7-5/8", 39# ret. Pkr w/1 0' 4" ID seal bore 9,494' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 15. Well Class after proposed work: ExploratoryD Development 0 16. Well Status after proposed work: Oil 0 Gas D WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service D attached GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 304-132 Contact Steve Tyler 907-263-7649 RBDMS BFL FEB 2 2 2005 Printed Name?TimothY ~denbU/ ~ Signature -y ~ p Form 10-404 Revised 04/2004 Title Drilling Manager Date ?-- (1 -0 S- 0 ~\ G \\'fK: Submit Original Only . . , gli • M Swanson River Well SCU 22 -04 UNOCAL 76 Velocity String Completion ' CASING AND TUBING DETAIL • SIZE WT GRADE CONN ID TOP BTM. im r - - — — _ 22" - - - 28' j 1 irZei 11-3/4" 47 J -55 8rd 11.000 Surface 1413' Oa S 7 -5 /8" 39 N -80 Speed Tite 6.625 Surface 131' • 7 -5/8" 33.7 N -80 X -line 6.765 131' 3623' _ 7 -5/8" 29.7 N -80 Speed Tite 6.875 3623' 5654' .i IL -. l _ — 7 -5/8" 33.7 N -80 Speed Tite 6.765 5654' 6552' A 1 I 7 -5/8" 39 N -80 Speed Tite 6.625 6552' 10,100' OB- • - 5 -1/2" liner 20 N -80 Hydril 4.778 9693' 10,100' RKB = 18.85' II 3 -1/2" liner 9.2 L -80 Hydril 511 2.992 9546' 11,096' 1 C. J L L Tubing 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 2322' rir 4 -1/2" 12.6 L -80 TDS 3.958 2322' 9470' 3 1-3/4" Coil HS -80 NA Surf 10,489' 4 i 1 JEWELRY DETAIL NO. Depth ID OD Item 1 1 18' - - Tubing Hanger, 7- 1/16" x 4 -1/2" Butt., Type" H" BPV profile. CL prep. L 1 1 ' D VT @ 6983' 2 2322' 3.958 4.500 4 -1/2" L-80 12.6 ft/lb Butt. tubing 1 I 9489' 4 -1/2" L -80 12.6 ft/lb TDS tubing I I 3 2217' 3.865 5.25 Chemical Injection Mandrel Macco Cm -3 4 2311' 3.833 5.983 Six 4 -1/2" Side Pocket Mandrel MACCO SMOR -1A A la 4207' with 1" GLVs and BK -2 latches 5 5997' 6 7589' 2 I F. . 8994' F 9447' 5 9489' 4 -1/2" buttress x 3 -1/2" buttress crossover 9491' Baker Locator type seal assembly (4.0" OD) 7 • • 6 9494' Baker SC -1 7 -5/8" 39# ret. pkr with 10' 4" ID seal bore 1.4 J L .-,... 7b 7 9543' 3 -1/2" buttress X nipple, 2.813" ID 7 a 9575' 3 -1/2" buttress seal assy, 5.5' long x 4.0" OD k r 7b 9546' Baker ZXP liner top packer, failed pressure test 1 8 9589' 3.437 Knock -out Isolation valve, 2.700" inner string clearance 3.437" ID when flapper knocked out 9 • • 9 9627' 2.813 3 -1/2" Hydrill 511 X nipple, ID = 2.813" 10 10,270' DPM Baker Bottom Trip Whipstock, 5 -1/2" 11 10,276' ELM 5 -1/2" DW 1 packer with slot for whipstock orientation 12 11108' Bottom of slotted liner A Surface Tie -Back stem B -1' TIW CT Auto "J" Hngr wl Tie -Back reciprocal wl CTC 10 G1 C 10,489' CTC, Pup joint, Profile Nipple & Shear Sub G2 H4 ------------ - - - - -- —_ 112 G -2 Perfs Top H-4 Target @ 10272'- 10367' 10525'MD/10,469' T' ) TD= 11140' MD /10,469' TVD Total Horizontal Section (H- 4 -H5)= 600' indow /Kick off Point @ 10,267' - 10280' MAX HOLE ANGLE = 95.13 dee L 35 deg/100' build 3 -1/2 "perfed liner, 10235' - 11033' SCU 22 -04 Schematic 02 -09 -05 Drawn by: TAB (updated CRW) 2/9/2005 ... IÌI ,I :f ) ) .. . 07/19/2004 No activity SIMOP's with Production & Construction. Pollard spot equipment on location and rig up after Peak changes out well head cap. Hydro test to 1500#. Tool string consist of2.80" OR, tungsten carbide stem, roller stem and anti blowup tool. Running in hole flowing. RIH while well flowing to 10563' RKB set down due to deviation in high angle hole section right at H-4 perfs. Picked back up and ran in hole fast second time setting down in same location due to high angle. No extra pickup weight all looks good. POOH, rig down Pollard. Spot coil equipment, make up hard lines between coil, pump and tiger tank. Pick up BOP's and stab on well head. Stab injector head and prepare to pump Hippo Turbine. 07/20/2004 SIMOP's with production and construction. Pumped Hippo turbine and Nerfball together. Pumped 1.30" steel ball through coil. Tested BOP's 400# low pressure and 4000# high pressure (OK). Make up bottom connector, pull test to 15K & retighten and pressure test to 3000# (all OK). 07/22/2004 SIMOP's with production & Construction Safety meeting with Peak Crew. Pull wellhead from bottom master up with Peak Pick up BOP's and stab onto master Valve and hook up hard lines. Make up Test plate Pressure test coil and bottom coil connector to 3500# for 1/2 hour. Make up bottom BHA (Blow out plug, XN Nipple, 6' pup joint to bottom coil connector) Pressure test same to 2000#. Stab injector head PIT lubricator. RIH at 50 FPM checking pickup weights every 1000' Cameron on location at this time. RIH checking weights at every 1000'. RIH to 10500' MD (Check Weight 28.5K) set slips and pipe rams. Hold pre job safety meeting on (stripping off lubricator, cutting coil & Making up top BHA) Break head, strip and cut pipe. Making up coil connectors on whip and stump. Stop and have team meeting on zero and approach to space out hanger. Make up MHA and OS on whip. Pull test 15K and pressure test to 3000#. The dual checks have been pulled from the MHA and the OS releases at 500# pump pressure as tested. Pulled and redressed coil connector off stump. Made up on J Hanger pin. Dropped connector over stump with coil unit. Made connector up and pull tested to 12.5K and readjusted. Stab injector head and open BOP's and RIH to set hanger. 07/22/2004 RIH with J-Iock Hanger. 07/23/2004 07/25/2004 Make up bottom BHA, Shear SUB, XN Nipple and 6' pup. Pressure test to 2000# (OK). Stab BHA and injection head. Chain down and Shell test BOP's. Start running in hole with coil. 10550' of coil in hole running 50 FPM checking weight every 1000'. Final weight check 22K RIH, 23K hanging & 32K pick up- weight. POOH to 10500'. Close pipe slip rams and pipe rams and slack off weight. Manually lock out rams and bleed wellhead off. Break injection head chains, release skates and strip injection head off coil. Cut coil above BOP's with sufficient stub to make at least two coil connections if needed. Actual coil between bottom BHA connector and top BHA coil connector is 10489'. Pull injection head back pick up 20' of lubricator. Make coil connection with MHA and test plate. Pull test same to 20K, retighten and pressure test to 3000# (OK). Pull test plate offMHA and put OS on. Function test OS at 500# (OK). Hang PBR on OS and make up Hanger on PBR. Have coil connector made up to pin on SCU 22-04 (162336) morning report summary, CONFIDENTIAL: last revised 2/9/2005, Page 1. , , .. I ) ) hanger bottom. Dress coil stub on wellhead. Stab coil connector over stub on well using crane. Make up connector and pull test to 12.5 max with crane and readjust. Set all set screws on connector. Note hanger location in lubricator, Zero and calculate RKB on PBR setting depth. Strip lubricator over coil and land. Chain injector head down. Pick up 30K on slips, open equalizing ports on BOP's, unlock rams and open pipe rams and slips. 07/26/2004 RIH with coil completion on hanger to set. RIH weight 19.5K, Static weight 22.5, and pick up weight 30.2K. RIH 15' below tubing hanger and picked back up to set at l' and set right at bottom of Shaffer 4 1/2" tubing spool. Bring pump on line and pressure up coil to 1150# releasing GS from PBR and Hanger. Slowly pull up on coil slowly losing negative weight and end up with stripper weight of 1000# . POOH, close master valve, bleed lubricator and BOP Stack. Break chains, Pick injector head, break 20' lubricator, set injection head on. Set lower half of tree inclusive of Flow Tee Hanger and 3 1/16" 5M Valve. Rig Pollard wire line up with 2.5 GR. Rig up test pump. Pressure test Lubricator and lower tree to 3500# (OK). Pick up CT Seal Nipple and Hanger. RIH with CT Seal Nipple and hanger and set, lock down and shear off GR. POOH, break lub and swing aside. Blow down coil tubing to perform negative test across coil X tubing annulus hanger (test OK). Break Pollard connection off tree and make up upper section of tree. Pull top tree section rig up Pollard. RIH with GS and pull CT Nipple and hanger. Swing Pollard aside. Lay down CT nipple and hanger. Redress seals on hanger while on surface. Close master pull lower tree section. Stack lower tree section. Pick up Pollard, pressure test pollard lub and tree together again. RIH set CT Seal Nipple and hanger for same. POOH Swing Pollard aside and perform negative test across coil hanger again (OK). Rig wireline connection off and stack upper section of wellhead. Rig up Schlumberger pump, purge lines and test upper section of tree to 4000#. Open Valve above coil hanger and pressure up on coil and blow shear sub bottom on end of coil. Sub Bottom sheared at 1240# and well went on a vacuum. Turn well over to production. SCU 22-04 (162336) morning report summary, CONFIDENTIAL: last revised 2/9/2005, Page 2. '" Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 143' RKB 1. Type of Request: 8. Property Designation: Swanson River Unit 11. Total Depth MD (ft): 11,140' Casing Structural Total Depth TVD (ft): 10,469' Length Conductor Surface ..~...., \ ',--,----. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic D Suspend U Repairwell D Pull Tubing D Perforate U \JJGPt- Waiver U Annular Dispos. U StimulateB Time Extension D 1 Other ~ olGA- rllv,;(ø.ll "-e.lo~h[ Re-enter Suspended Well D st rtK1 . 5. Permit)o Drill Number: Exploratory D 99-83 / Service D 6. API Number: / D 50-133-10106-01 9. Well Name and Number: U SCU 22-04 / 10. Field/Pools(s): Swanson River Field/Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10,525' 10,469' Size MD Plugs (measured): Junk (measured): TVD Burst Collapse 28' 1,413' 10,100' 10,100' 11,096' 28' 22" 1,413' 11-3/4" 10,100' 7-5/8" 407' 5-1/2" 1,550' 3-1/2" Perforation Depth TVD (ft): 28' 1,409 10,074 10,074 10,477 Tubing Size: Tubing Grade: 4-1/2" L-80 Baker SC-1, 7-5/8", 39# ret. Pkrw/10' 4" ID Packers and SSSV MD (ft): seal bore Production Liner Liner Perforation Depth MD (ft): 10,272 to 10,367' Packers and SSSV Type: 737 psi 683 psi 466 psi 3,070 psi 4,790 psi 8,830 psi Tubing MD (ft): 9470' 9,494' 12. Attachments: Description Summary of Proposal L:d Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Signature '-- /1.-; / Þv~ Phone 907-276-7600 Date / /. j COMMISSION USE ONLY 5/20/2004 Date: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil D Gas 0 Plugged WAG D GINJ D WINJ 0 Service D D Abandoned D D WDSPL D Contact Steve Tyler 907-263-7649 4/14/2004 Mechanical Integrity Test D Sundry Number: .:t) 4 ,-) 3 ¿ LocationClearance ~ECE\VEO ~PR 1 9 'LGO4 C nwn'SS\on O'~ & Gas Cons. 0 ~\as~8' ~nc"o'8ge V' Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Other: fØJIIlò Bf \.. ~~ 1. 1 1\)~~ BY ORDER OF IL'~~/~ COMMISSIONER THE COMMISSION Date: 7~ 47 INSTRUCTIONS ON REVERSE 0 R , G , N A ~ubmit in uplicate Swanson River Well seu 22-04 / As of 10/13/99 . - UNOCAL8 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 28' 1413' 131' 3623' 5654' 6552' 10,100' 10,100' 11,096' SIZE WT 22" 11-314" 47 7-5/8" 39 7-5/8" 33.7 7-5/8" 29.7 - 7-5/8" 33.7 7-5/8" 39 5-1/2" liner 20 3-112" liner 9.2 - Tubing 4-1/2" 12.6 RKB = 18.85' 1 J-55 8rd 11.000 Surface N-80 Speed Tite 6.625 Surface N-80 X-line 6.765 131' N-80 Speed Tite 6.875 3623' N-80 Speed Tite 6.765 5654' N-80 Speed Tlte 6.625 6552' N-80 Hydril 4.778 9693' L-80 Hydril511 2.992 9546' L-80 TDS & Buttress 3.958 Surf JEWELRY DETAIL 2 - 3 - 9470' 4 ¡¡, DVT@ 6983'1 4 NO. I ID OD 3.958 4.500 3.865 5.25 3.833 5.983 Item Tubing Hanger, 7-1/16" x 4-1/2" Butt., Type" H" BPV profile. CL prep. 4-1/2" L-80 12.6 ft/lb Butt. tubing 4-1/2" L-80 12.6 ftllb TDS tubing Chemical Injection Mandrel Macco Cm-3 Six 4-112" Side Pocket Mandrel MACCO SMOR-IA with I" GLVs andBK-2 latches Depth 18' 2 2322' 9489' 2217' 2311 ' 4207' 5997' 7589' 8994' 9447' 9489' 9491' 9494' 9543' 9575' 9546' 9589' 3 4 6, r 7 4-112" buttress x 3-1/2" buttress crossover" Baker Locator type seal assembly (4.0" OD) Baker SCot 7-5/8" 39# ret. pkr with 10' 4" ill seal bore 3-112" buttress X nipple, 2.813" ill 3-112" buttress seal assy, 5.5' long x 4.0" OD Baker ZXP liner top packer, failed pressure test Knock-out Isolation valve, 2.700" inner string clearance 3.437" ill when flapper knocked out 3-112" Hydrill 511 X nipple, ill = 2.813" Baker Bottom Trip Whipstock, 5-1/2" 5-112" DW I packer with slot for whipstock orientation Bottom of slotted liner 5 6 7 7a 7b 8 9 10 G2 11 12 XI- 7a -IX 7b I~ II 9- 3.437 9627' 10,270' 10,276' III 08' DPM ELM 10 84 -- ffi -~~~~~~~---------I12 TopH-4Target@ - - - - - - - - -- 11 G-2 Perfs - 10272' -10367' 10525'MDI10,469' TVD TD = 11140' MD/I0,469' TVD Total Horizontal Section (H-4-H5)= 600' MAX HOLE ANGLE = 95.13 deg WindowlKick offPoint @ 10,267'-10280' 35 degl100' build 4 ¡¡, 3-l/2"perfed liner, 10235'-11033' 04112/04 Drawn by: TAB seD 22-4 Schematic 10-13 SIZE WT m TOP BTM. 22" 28' 11-3/4" 47 J-55 8rd 11.000 Surface 1413' 7-5/8" 39 N-80 Speed Tite 6.625 Surface 131' 7-5/8" 33.7 N-80 X-line 6.765 131' 3623' 7-5/8" 29.7 N-80 Speed Tite 6.875 3623' 5654' 7-5/8" 33.7 N-80 Speed Tite 6.765 5654' 6552' 7-5/8" 39 N-80 Speed Tite 6.625 6552' 10,100' 5-1/2" liner 20 N-80 Hydril 4.778 9693' 10,100' RKB= 18.85' 3-1/2" liner 9.2 L-80 Hydri1511 2.992 9546' 11,096' J L Tubing 4-1/2" 12.6 L-80 Buttress 3.958 Surf 2322' 4-1/2" 12.6 L-80 TDS 3.958 2322' 9470' 1-3/4" Coil HS-80 NA Surf 10,500' H4 ------------------____:,5 - - - - - - - - - - - - - 12 Top H-4 Target @ - - - - - - - - - - - 10525'MDIJO,469' T' ) NO. Depth 1 18' ¿ ), DVT @ 6983' 2 2322' 9489' 3 2217' " 4 2311' ¡, \ ' /5 4207' 5997' 6 7589' , r 8994' 9447' 5 9489' 9491' i 6 9494' 7 9543' 7a 9575' 7b 9546' 8 9589' 9 9627' 10 10,270' 11 10,276' 12 11108' HI G2 11 G-2 Perfs 10272'-10367~ ¿ Window/Kick otTPoint@ 10,267'-10280' I 35 deg/IOO' build ), m JEWELRY DETAIL Item Tubing Hanger, 7-1/16" x 4-1/2" Butt., Type" H" BPV profile. CL prep. 4.500 4-1/2" L-80 12.6 ft/lb Butt. tubing 4-1/2" L-80 12.6 ft/lb TOS tubing 5.25 Chemical Injection Mandrel Macco Cm-3 5.983 Six 4-1/2" Side Pocket Mandrel MACCO SMOR-1A with 1" GLVs and BK-2 latches pD 3.958 3.865 3.833 3.437 4-1/2" buttress x 3-1/2" buttress crossover Baker Locator type seal assembly (4.0" CD) Baker SC-1 7-5/8" 39# reI. pkr with 10' 4" 10 seal bore 3-1/2" buttress X nipple, 2.813" 10 3-1/2" buttress seal assy, 5.5' long x 4.0" 00 Baker ZXP liner top packer, failed pressure test Knock-out Isolation valve, 2.700" inner string clearance 3.437" 10 when flapper knocked out 3-1/2" Hydrill511 X nipple, 10 = 2.813" Baker Bottom Trip Whipstock, 5-1/2" 5-1/2" OW 1 packer with slot for whipstock orientation Bottom of slotted liner 2.813 OPM ELM TD= 11140' MD/10,469' TVD Total Horizontal Section (H-4-H5)= 600' MAX HOLE ANGLE = 95.13 de!! þ-I/2"perfed liner, I 10235'-11033' SCU 22-04 Proposed dwg 04-02-04 Drawn by: TAB 4/2/2004 UNOCAL8 Swanson River Well seu 22-04 Proposed Velocity String eompletion <) t.{ tvI.~Q.N i ~ Sumerized Procedure . MIRU Slickline. RIH wi GR to 10,550'. POOH. RD. /' / . MIRU 1-3/4" CTU. NU BOPE, MU CTC. Pressure test same. . PUMU Lwr BHA. RIH wi 1-3/4" CT to 10,500'. / . Cut CT MU CTC & TIW Hanger. RIH on GS PT. hang CT below tbg hngr. . Release from CT Hngr. POOH. Secure well. RD Demobe CTD. / . ND tree and flowlines above bottom master valve. . NU 2-1/16" flow tee, CT hngr, master valve, flow tee and swab valve. v uø.fta.J (. . RU Slickline. PUMU Tie-Back assy. RIH stab seal assy into hngr tie-back recepricole. Land in CT hangr. // . Turn well over to production. seD 22-04 Proposed dwg 04-02-04 Drawn by: TAB 4/2/2004 Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@ unocal.corn Beverly Harrison Business Ventures Assistant DATA TRANSMITTAL November 16, 2OO1 To' Lisa Weepie 333 W 7th Ave, #100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Beverly Harrison 909 W. 9th Avenue Anchorage, AK 99501 Unocal Alaska Transmitting the following: i: COMPLETION RECORD i5 INCH ;8/16/20 11000-11225 1;SCU 13-34 / ,-7-1"C~ fCOM'"~'i~ETi~"~'-'RE~-~"~D i. 5 INC'~ .......... ii'§~'i6/2~ ........ 1100'~':'i1225; liSCU 13-34 GAMMA RAY/CCL ;i!5 INCH ;8/18/20 10000-10553 ii I lSCU 32-8 '~; ~.'~' -G~M'MA R'~'"/"CCI~ .......................... i!'5 IN'~'H ....... i'"8~i'8/20 ....... i0000L'i'0553 ........ 1~ SCU 32-8 ........ C'~"BPLE'?i'O'N RE'~'ORD ................... i'5'"i'NcFi ................ :!1i'~i'~20 '1'82'81-103'86 1 scu 41A-8 lcJ~/-O~% COMPLETION RECORD ;5 INCH 11/1/20 10281-10386 1 SCU 41A-8 '-'-~~-~'~iB.BEE?ii~NRi~'~0BD'"'"-i'iiiiii.i.iiii../~'"i'~CiH ........... 1'1'111'111!1.7i13~'0111.i;.652'6:16648 .......... i;ii. i'"SRU'i'4-15 COMPLETION RECORD 5 INCH '7/13/20 6526-6648 1 SRU 14-15 COMPLETION RECORD 5 INCH 7/13/20 6526-6648 1 SBU ©LFI~ ~ COMPLETION RECQBD ............. 5 INCH 7/!..3/20..'..'...'65'2'6'i'6648'". ' 1 SBU ~:THROUGH TUBING BRIDGE 5 INCH 8/8/200 6000-6490 1 SBU ii THROUGHTUBING BRIDGE 5 INCH 8/8/200 6000-6490 1 SRU icO'M'PLETIbN RECb'RD ................. 5' iNCR ....8~'i"0/20 -6'0'00-644'2 1'~ SBU i.'. i~ioMPLE~i'0N.B.E~ORD.i.....iiiiiiiiiii'i ....... :.-5_!N.CH .......... 8/10/20 ....... 6000:6.442 '...i' .1: SRU ' ~.~,--"1 iGAMMA RAY/CCL 5 INCH 8/19/20 10220-10853 1 SBU I ~_~Z' '~'G'AMM'~'-RAY'~'"~'cL ........................... !"'5' INC~ ........ :18/i"~20 ::i~'220-10853 1 SRU ;EPOCH REPORT !. 1 SCU ' ~-~ ~1'~'°5' r __EPOCH.REPORT ................................. i ............... ii.'i .i ".'..'.i ..... .............. 1 Mediuml B-Line Film Film B-Line B-Line Film Film B-Line 14-15 14-15 14-15 14-15 14-15 14-15 14A-33 14A-33 22-4 ~ I-9 I Film B-Line Film B-Line Film B-Line B-Line Film PAPER PAPER RECEIVED Ple(~se (~cknowledge receipt by signing c~nd returning one copy of this tr(~nsmiff(~l or FAX~,~?02~)~_6~/~8. Received b z'3 I Date: Anchorage Unocal Alaska Resources Unocol Corporotion 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd@.unocal, com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL April 4, 2000 ii To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas i From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal ii i Transmitting the following items: ' ' .:;."?:,",.;~ Well~,~;.~:, :,;:;~.'.,',!,...':,:;;..'~.~i!,.;',~i' LOG?T3'PE;';~;'.!:.'~:,;'.'.:;:;.'..:'. ;'. SCAI~E~ti.'~,.~:::LOG~i". I:i'?-' INTERVAI~;'.:':'.=.'I~t:..4,1~! COPIES!~...?i':,i'i I," a~diUm'~ [ .','.t' ,".,: ' ~"~ ~',"','~",'" .~ ..... ';:,~. '~':a.";S.' ,"~,,.' .... ' '-" ;",'",: "~': ,'"' ~':"" ' : ' ' ''" ' ;.' '" · '" ";~.'% ~"!' . "' ' '' '' ;~ · ' ,, ':~,:'""" ' , ~ ~.~,g.~' "" ~. ' '~..""'. ·" .'. ~;'.' .'." " "";.." "' ':'. ?~.'.',',,.,;:.,'..'":.,.',"':, ,:.I; ,'.".?'~;','.:, ,,",". ".' ,,. , ,~ .;,'" .' ,'...:',:,: .... ~'~ "'., ~, :., ".,':.. ,' ','{~.',,.."',:";.~,"..~","", ,,. ~ ;,~,"....'...' .'.,",C'~"=I",',,:",~ _ .....:..:.-..,.'.,,-'.',.',...,, ....... ~.~:..:-._..:~.;;...._ ...:::..::._.::"I_..~_A.T_E.'..'J.'.___~_O_._G_G_.~.Q:.~_'-. ~.__.' .... : I .. - . -I I~°1' OI...~'~SC-I~ 1~--9 - '). i i)ermal Decay 'rime Log 5 ir..;h 9/6i99 6400-10714 ! B. Line ~(,,~,. ~z'~scu ~2-'--'-~'~' ............. i"~'e'~f~i~ii~;'~""i~;~i ....................................................................... i"~'"i'r~i~' .............. , .................. ~"/bb'i"i"'O'i"5'b:i"b'~'3"O ................ i ......................................................................... i"?'B':l"i'~;'~' ............... '] i SCU12-9 I Perforatino Record ' 15 inch t 2/3/00~10150-10330 i llFilm } I SCU12-9 [Perforatin9 Record/Correlation Log i5 inch t 1/16/00110000-10500 j liB-Line / i"~'i~'O-i"~";~::~' ........ i~'~;~'~i~;~'t-i~i~'~j"~'d';~'r~'&~;{- .................................. ':~'"i'i~'&i~ ................. I ........... ~7i"i7d'6'"'i'~'66:~'6'~"~' ................ ~i B-Line 't,,' SCU 12A-3 Possiset Plug 5'Cement 5 inch ~ 3/11/00110200-10545 11 Film :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~~:::::::~~~::::: :..:..:::: :.:::::' :.:::......:.:: ...... ...: :"':':'"":':..::" ":'::':, ....... :'. ....... .."..'"'.:'::'" .:..:...'.. ~:~:.~~~~~~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~,~,~'7.,i' SCU 14-4 Perforating Record/Correlation Log 5 inch 1/14/00,10000-10610 1 B-Line ,1,,- ,,' .......................................................... f ...................................................................................................................................................... I .......................................... 1 ........................................... , ......................................................................... i, .......................................................................................... ; ...................................... .~.~, ..,.-.~ISCU 21A-9 iPerforating Record )5 inch 2/1/00~! 0500-10700 1 B-Line F1'1 r...~c) .............................................................................................................................................................................. ~ ................................................................................................................................................................................................................................. .i,-" I SCU 21A-9 'l_P..e~_ora__tin_~.. Record 5 inch 2/1/00 10500-10700 1 Film Pi' ~ -o 3 ~CU 22-4 I~__D ~?mposite Field Print 5 inch 10/8/99.10340-11140 1 B-Line SCU 22-4 Field Print 5 inch 10/8/99 10340-11140 1 Film SCU 22-4 Field Print 5 inch 10/8/99 10340-11140 1 B-Line SCU 22-4 !TVD Composite Field Print 5 inch 10/8/99 10340-11140 1 Film I~O.~,-,u i''§'~'~''''~;~:~':'~ .......... ?~'~.p. letion Record 5 inch! 3/13/00 10200-10640 1 B-Line ~ -" "§'b'O'"~:~:~ .......... ]"~;'~i~'i'~i'i'~'~ ~'~'~'~'i~i "~'i'~'~'i;' i '~i'i"~)'l'i"i~i~"i~:ii~i~';~'i~ , i li~ii'~ .......... '--- ':--- SOU'43'E~:~ ........ i¢&'~i~t'io~"'R'~'&b'i~i ................................. !'5'"i~i~ .... ! ..... i'/i47001'i02'00'::i'05'~0''''~: ................................ i'i'i~Jm ......... Please acknowledge r~c..l~ipt,by signing ond returning one copy of this transmittcll <Sr'FT~X fo'(g07) 263-7828, I ~ , ~ / --il ,/, I .-- ..... .,'" ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 99-83 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10106-01 4. Location of well at surface ~. · . - ?-.~¢¢~-~,,~;~¢~.. 9. Unit or Lease Name 2015' FSL, 2070' FWL, Sec. 4, T7N, R9W, SM i :-.:: · ..'- ;.: ?~~¥~i Soldotna Creek Unit At Top Producing Inte~al (10304',':~~;~~-~~';~ ~'~'~ . :.~. 10. Well Number At Tota12076'DepthFSL' 2096'11,140'FWL'MD Sec. 4, T7N, R9W, SM :~" .~ . ~.~ ~...,: .¢xv::;~: *".~'~'~~" 11 Field and Pool. SCU ¢22-4 2490' FNL, 2273' FWL, Sec. 4, TTN, R9W, SM 5. Elevation in feet (indi~te KB, DF, etc.) 6. Lease Designation and Serial No. Swanson River Fiel~Hemlock 170' KB A-028997 12. Date Spudded 13. Date T.D. Reached ~ 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 16. No. of Completions 9/10/99 10/8/1999~ 10/14/99~ NA feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Direotional Su~ey 20. Depth where SSSV set I 21. Thickne~ of Permafrost 11,140' MD/10469' TVD 11,140' MD/10469' TVD~ Yes: x No: NA feet MD~ NA 22. Type Eleotric or Other Logs Run LWD Gamma Ray 23. CASING, LINER AND CEMENTING RECQRD S~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" 0 28' Driven 0 11-3/4" 47¢ J-55 0 1413' 16" 1000 sx 0 7-5/8" 29.7,33.7,39 N-80 0 10267' 10-5/8" 2000 sx 0 5-1/2" 20¢ N-80 9693' 10267' 6-3/8" 150 sx 0 3-1/2" 9.2¢ L-80 9546' 11096' 4-1/2" None 0 24. Pedorations open to Production (M~TVD of Top and BoSom and 25. TUBING RECORD inte~al, size and numbe0 SIZE DEPTH S~ (MD) PACKER S~ (MD) 4-1/2" 9489' Predrilled liner from 10235' - 11033' MD/10235'- 10478'TVD 3-1/2" 9575' 9494' 26. ACID, F~CTURE, CEMENT SQUEEZE, ~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) 10/19/1999 ~ flowing to production facilities Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 11/05/99 8.52 hrs TEST PERIOD => 3.195 4858 3.195 28/64"~ NA Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 1500 1050 24-HOUR ~TE => 9 13685 9 37 28. CORE DATA Brief de~ription of lithology, porosi~, fractures, apparent dips and presen~ of oil, gas or water. Submit core chips. None · a,ka Oil & ~as Co~s. 6'ommiss~or, Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. Top Hemlock Formation 10,375 10,371 31. LIST OF ATTACHMENTS Wellbore schematic, Daily Summary of Rig Operations, Directional Survey Record 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ..... Title__Drilling Manager Date 1 I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all typos of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on Ibis form and in any attachments. Item 16 and 24: If this well is completed for separate production from more bhan one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Form 10-407 Item 23: Attached supplemental records for His well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Alaska 0il & 6as Cons. (;ommissJ0~ Anc~rage UNOCAL RKB = 18.85' 7b 10 11 G-2 Perfs 10272'- Swanson River Well SCU 22-4 As of 10/13/99 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 47 39 33.7 29.7 33.7 39 20 9.2 22" 28' 11-3/4" J-55 8rd 11.000 Surface 1413' %5/8" N-80 Speed Tite 6.625 Surface 131' 7-5/8" N-80 X-line 6.765 131' 3623' 7-5/8" N-80 Speed Tite 6.875 3623' 5654' 7-5/8" N-80 Speed Tite 6.765 5654' 6552' 7-5/8" No80 Speed Tite 6.625 6552' 10,267' 5-1/2" liner N-80 Hydril 4.778 9693' 10,267' 3-1/2" liner L-80 Hydril 511 2.992 9546' 11,096' Tubing 4-1/2" 12.6 N-80 TDS & Buttress 3.958 Surf 9470' JEWELRY DETAIL NO. Depth ID OD Item 1 18' - Tubing Hanger, 7-1/16" x 4-1/2" Butt., Type" H" BPV profile. CL prep. 2 3.958 4.500 4-1/2" L-80 12.6 fi/lb Butt. tubing 4-1/2" L-80 12.6 ft./lb TDS tubing 3 3.865 5.25 Chemical Injection Mandrel Macco Cm-3 4 3.833 5.983 Six 4-1/2" Side Pocket Mandrel MACCO SMOR-1A with 1" GLVs and BK-2 latches DVT @ 6983' G2 6 7 7a 7b 8 2322' 9489' 2217' 2311' 4207' 5997' 7589' 8994' 9447' 9489' 9491' 9494' 9543' 9575' 9546' 9589' 9 9627' 10 10,270' 11 10,276' 12 11108' 3.437 or 2.70" DPM ELM 4-1/2" buttress x 3-1/2" buttress crossover Baker Locator type seal assembly (4.0" OD) Baker SC-1 7-5/8" 39# ret. pkr with 10' 4" ID seal bore 3-1/2" buttress X nipple, 2.813" ID 3-1/2" buttress seal assy, 5.5' long x 4.0" OD Baker ZXP liner top packer, failed pressure test Knock-out Isolation valve, 2.700" inner string clearance 3.437" ID when flapper knocked out, I)id not .see it with 2.125" weight bar on 10/15/99. 3-1/2" Hydrill 511 X nipple, ID = 2.813" Baker Bottom Trip Whipstock, 5-1/2" 5-1/2" DW_I packer with slot for whipstock orientation Bottom of slotted liner H4 H5 Top H-4 Target @ 10525'MD/10,469' TVD Window/Kick off Point @ 10,267'-10280' 35 deg/100' build 12 TD = 11140' MD/10,469' TVD Total Horizontal Section (H-4-H5)= 600' MAX HOLE ANGLE = 95.13 deg 3-1/2"perfed liner, 10235'-11033' SCU 22-4 Schematic 10-13, Final Drawn by: TAB 11/13/99 UNOCAL Alaska Drilling Drilling Progress Report SCU #22-4 9/2/99 to 10/25/99 9/2/99 RU E-line unit to cut tubing. RIH with chemical cutter and set down in bottom GLM at 9428'.' PU and cut 2-7/8" tubing at 9425' with good surface indications of cutter function. POOH and RD E-line. 9/3/99 Move rig from SCU #41B-9 to SCU 22-4. Dropped sub base when choker line broke. Delay in rig move to inspect and repair sub base beams. 9/4/99 Inspect and repair sub base beams 9/5/99 Continue sub base repairs. Circ 500 bbls lease water down tbg and up annulus at 2.5 BPM/300 psi. Took 125 bbl to fill well and then full returns thereafter. 9/6/99 Finished repairs on sub base and inspected same. Resume rigging up on SCU 22-4 (formerly SCU 323-4). 9/7/99 Rigging up Inlet Drilling Rig #CC-1 on SCU 323-4 for sidetrack operations. RU top drive. 9/8/99 Accept rig at 12:00 hrs on 9/8/99. ND tree, NU 7" BOP stack. 9/9/99 Test BOPE. Witness waived by AOGCC and BLM. MU landing joint and pull tubing, lay down 292 its of 2-7/8" tbg. 9/10/99 MU BHA #1: 2-7/8" tubing overshot plus 6.5" string mill combo. RIH and tag tight spots in 7-5/8" casing at 6563'-6567', 6731'-6733', and 6777'. Ream thru all tight spots with no problem and PU and fall through tight spots with no problem after reaming. RIH and engage tubing stub at 9633' (packer had fallen to top of 5-1/2" liner). POOH with packer and 9 jts of tubing. No problem at tight areas. 9/11/99 RIH with 4.5" mill assy to 10343' to clean out 5-1/2" liner. Circ BU and POH to 5590'. MU 7-5/8" Baker storm packer, RIH one stand and set storm packer. Test packer to 2500 psi. ND BOP stack and tubing head. NU new tbg head. 9/12/99 Pressure test new tubing head and BOPE. Retrieve storm packer and drill pipe. RU E-line and set Baker DW-1 whipstock packer at 10,276'. 9/13/99 RIH with gyro on E-line and measure orienting slot in DW-1 packer at 305.5 deg. POOH and RD E-line. Orient whipstock face at surface at 18.7 deg. RIH with whipstock/window mill assy. Latch into packer at 10270' dpm. Shear up mill assembly from whipstock. Change over to 8.4 ppg FIo-Pro mud system. Mill window from 10255' to 10282'. 9/14/99 Dress window, Circ BU and POOH with mills. RIH with 4-1/2" bit and motor to 1000'. Baker MWD-GR tool failure, POOH and replace GR. 9/1 5/99 RIH with new Baker MWD GR tool to 10,229'. RU E-line and run gyro inside drill pipe to obtain tool face in a vertical well. Gyro failed. POOH with gyro on wireline. Check MWD and pulser failed. POOH with drill pipe and MWD. 9/1 6/99 Test BOPE. LD MWD and RIH with bit and 2.8 deg AKO motor and gyro steering assembly. RU side entry sub and wireline. RIH with gyro on wireline, orient toolface. Drill from 10282' to 10364' while orienting and surveying with Gyro. Good angle build to 27 deg with higher than planned build rates. POOH with gyro. 9/17/99 GR. 150 POOH with bit. Change to 2.3 deg AKO motor assembly and Anadrill MWD- RIH and make GR pass from 10260' to 10364'. Drill from 10364' to 10407' at gpm and 2100 psi, motor rpm = 340. Built angle to 39 deg.\ 9/18/99 Drill from 10407' to 10464', angle built to 60 deg. POOH for bit trip. RIH and drill from 10464' to 10557', angle built to 81 deg. 9/19/99 Drill from 10557' to 10602', angle built to 86 deg. POOH for bit. RIH with PDC bit and Mach 1 motor at 1.2 deg AKO. Drill from 10602' to 10620'. 9/20/99 Drill from 10620' to 10778'. Angle at 88.25 deg. 9/21/99 Drill from 10778' to 10818', angle at 86.47 deg. POOH for new bit. RIH 4-1/2" PDC bit and Mach lXL motor with added 4-1/8" string stabilizer to hold angle. 9/22/99 Drill from 10818' to 11226' with minimal sliding. Angle at 90.60 deg. Pull bit due to angle dropping slightly in rotary mode. 9/23/99 Finish POOH with worn bit. Test BOPE. RIH with new bit. 9/24/99 Drill from 11226' to 11300'. Very difficult to slide, rotary drilling slightly dropping angle. POOH to change BHA to build angle in rotary mode. Backream tight hole from 10620' to 10557'. RIH with new bit and angle building BHA. 9/25/99 Drill from 11,300' to 11,330'. Encountered coal in last 2'. POH to window, RIH for cleanout run before running liner. Unable to work past 10472'. POOH with bit, pinched cones, failed bearings. RIH with 4-1/2" PDC bit. 9/26/99 Attempt to reenter 4-1/2" hole, wash and ream from 10465' to 10,470', no progress. Orient motor to high side, ream to 10,476', no further progress. POOH. RIH with bull nose and 4-3/8" string mill. Took weight at 10,468', rotate down to 10,476', no further progress. Spot Soltex pill and POOH with string mill. 9/27/99 RIH with bent joint of 3-1/2" liner. Set down at 10476', attempt to rotate and orient to high side. Unable to go below 10476' and eventually unable to work below 10470'. POOH with bent joint. 9/28/99 RIH with 2-1/16" cement stinger. Tag bottom at 10470'. Mix and pump 8 bbls (44 sx) of Class G cement at 17.0 ppg. Displace cement as balanced plug on bottom. POH slowly to 10193'. RIH slowly while washing from 10193' to 10330'. No sign of cement returns except for pH spike in mud. POOH with cement stinger. 9/29/99 Test BOPE. RIH with bit to kick-off from cement plug. No indication of cement. Set down at 10452'. POOH with bit. RIH with cement stinger for 2nd attempt to lay kick-off plug. 9/30/99 Wash down to 10452' with cement stinger. Mix and pump 10 bbl (55 sx) of 17.0 ppg class G cement. Displace cement as balanced plug on bottom. POH slowly to 10225'. RIH slowly while washing from 10225' to 10325'. CBU and no sign of cement, only slightly contaminated mud. POOH with cement stinger. RIH with bit to kick-off from cement plug. Tag firm at 10442', circ BU with 60% cement and 40% sand. POOH for plug #3. 10/1/99 RIH with cement stinger, wash down to 10439'. Mix and pump plug #3 - 30 bbl (165 sx) of 17.0 ppg class G cement. Displace cement as balanced plug on bottom. POH slowly to 10022'. RIH slowly while washing from 10022' to 10325'. Good sign of cement in mud returns, dispose of 150 bbl of cement contaminated mud. POOH with stinger. 10/2/99 RIH with kick-off drilling assembly, Mach 1X motor with 2.3 deg AKO setting. Tag cement at 10325'. Drill cement from 10325' to 10340'. Time drill at 45 deg left of top center from 10340' to 10343'. Time drill from 10343' to 10363' at 20 deg left of top center to kickoff form cement in old hole. Continue slide drilling from 10363' to 10396' while displacing to new mud system. Circ BU and POOH to change bits. 10/3/99 RIH with Mach 1X motor at 2.3 deg AKO and tricone bit for building angle. Drill from 10396' to 10501' building angle to 55 deg. POOH for new bit. Change motor setting to 2.1 deg AKO. RIH with new bit. 10/4/99 Drill from 10501' to 10565' while building angle to 75 deg. POOH to change BHA to rotary assembly. RIH with 1.2 deg AKO Mach 1XL motor and 4-1/2" PDC bit. 10/5/99 Drill from 10565' to 10810' while building hole angle to 90.65 deg. 10/6/99 Drill from 10810' to 10840'. POOH for new bit. Perform weekly BOP test for AOGCC. RIH with new bit 10/7/99 Drill from 10840' to 10948', angle at 93.53 deg. Encountered coal in samples at 10,900'. POOH for new bit and angle holding assembly. Encountered tight hole at 10,494'. Decide to drill one more bit run and stop due to hole deteriorating. 10/8/99 RIH with new bit. Set down at 10,491' and work through tight hole. Finish RIH to bottom and drill from 10948' to 11140' with hole angle at 95.13 deg. POOH due to dull bit and decide that 11,140' is TD. Prepare to run liner. 10/9/99 RIH with 26 joints of 3-1/2" Hydril 511, 9.3 Ib/ft, L-80 pre-drilled liner and 23 joints blank 3-1/2" liner. MU false rotary table and run 2-1/16" CS Hydril inner string. Space out inner string and stab inner string stinger into pack-off bushing near bottom of 3-1/2"liner. MU liner hanger assembly to inner string and outer 3-1/2" liner. RIH with liner on drill pipe. 10/10/99 Continue RIH slowly with liner. Rotate thru tight spot at 10485' to 10510'. RIH and tag at 11,108', unable to work deeper. Drop ball and set liner hanger at 1200 psi. Unable to release liner running tool with pressure, ball sheared out at 2900 psi. Displace open hole and 3-1/2" x 5-1/2" annulus to 6% KCL water. Spot 9 bbl Mudzyme in open hole. Rotate drill string to the left to release liner running tool. PU and attempt to set ZXP liner top packer. Did not see a good indication on surface of packer set. Attempt to test DP x casing annulus, no good with returns up drill pipe immediately. (ZXP packer leak or RS running tool seal leak) POH with drill pipe until inner string is above the Knock-out Isolation Valve flapper. Displace well above liner knock-out isolation valve to lease water. Finish POOH with liner running tool and inner string. PU dummy seal assembly and 7-5/8" Retrievamatic test packer to test liner top packer. 10/11/99 RIH with seal assembly and test packer. Stab seals into lower seal bore at 9587' below 3-1/2" liner top. Test annulus with immediate returns up drill pipe. Unsting seals and set test packer. Pressure test annulus to 1500 psi and held for 15 minutes indicating liner top packer leaking. POOH with test packer and seal assy. PU 7-5/8" liner tie-back assembly to repair liner top packer leak. 10/12/99 RIH with seal assembly below SC-1 production packer on drill pipe. Stab seals into seal bore beneath liner hanger, drop ball and pressure up to 3000 psi to set packer. Pressure test annulus to 1500 psi, good test. Rotate drill pipe 20 turns to the right to release running tool from packer. PU free from packer and attempt to shear out ball, ball was already sheared. POOH laying down drill pipe. Prepare to run 4-1/2" tubing completion. 10/13/99 Ran 179 jts 4-1/2" N-80 12.6# TDS tubing and 59 jts 4-1/2" N-80 12.6# Buttress tubing with 10' seal assembly, 6 GLMs and one chem inj mandrel with 2217' of 3/8" stainless steel methanol injection line strapped outside the tubing. Circulate well to clean 6% KCL water with corrosion inhibitor. Landed seal assembly 1' above bottom of packer seal bore extension. Pressure tested tubing to 500 psi and methanol injection line to 500 psi, good test. Set BPV, ND BOPE. 10/14/99 NU tree and test to 5000 psi. Release rig at 0500 hrs 10/14/99. Move rig off well and stack on SCU #22-4 pad. 10/15 thru 10/17 Rig up flowlines on SCU 22-4. 10/18/99 RIH with 3.125" weight bar on slickline and attempt to break Knock Out Isolation Valve flapper at 9589'. Did not see flapper. POOH and unload well with gas lift. 10/19-25/99 Flow well with current rate of 16 MMCFPD, 36 BWPD and 9 BOPD at 1450 psi surface tubing pressure. 0il&'" .... ~ .......... SCU 22-4 Sectio,n 4-T7N-R9W, SM Swa:nson River Field Cook Inlet Kenai Borough, Alaska Rich Swanson, Geologist Scott Carney, Geologist Epoch Well Services Inc. WELL RESUME OPERATOR: WELL NAME: LOCATION: FIELD: COORDINATES: ELEVATIONS: COUNTY: STATE: APl INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE (T.D.): CONTRACTOR: RIG #: RIG TYPE: COMPANY GEOLOGIST: COMPANY ENGINEERS: TOOLPUSHERS: DIRECTIONAL DRILLER I COMPANY: MUD COMPANY: MUD ENGINEERS: MUD TYPES: HOLE SIZES: CASING DATA: MUDLOGGING SERVICES: TYPE UNIT: UNIT #: LOGGING GEOLOGISTS: UNOCAL CORPORATION SCU 22-4 SEC. 4 T7N R9W, SM SWANSON RIVER 2155' FSL, 2446' FWL R.K.B. -- 143' GL = 124' KENAI BOROUGH ALASKA 50-133-10106-01 OCTOBER 1, 1999 11140' OCTOBER 8, 1999 INLET DRILLING COMPANY CC#1 LAND I TOP DRIVE ERIC GRAVEN TERRY COLEMAN I NICK SCALES GEORGE BREWSTER I MIKE LESLIE I JERRY SANDIDGE TOM DUNN ! BAKER HUGHES INTEQ M-I DRILLING FLUIDS, INC. JIM BROWN I PHIL BUMALA FLO-PRO LITE POLYMER 4.5" TO 11140'; 7 518" AT 9628'; 5.5" AT 10280' EPOCH WELL SERVICES, INC. DML 8 RICH SWANSON I SCOTT CARNEY ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~Z~~~~~~~~~~~~~~~~~~~Z~~~:~Z~Z~~~~~~~~~Z~:~:~~~~~~~Z~~~~~~~Z~~~~~Z~~~~~:~~~~~~~:~~~~~~~~~~~:~~~~~:~Z~~~~~:~:~:~Z~-~~~~~~:~~~~~~~~~~~~~~~~:~~:~:~~~~~~~~~~~~~~~:~~::~:~~:~~:~~~~:~:~~:::~~~:~~~:~.~.~~~~~~~~~~~~~~~~~~~~~~~~~~~.`.~~~. ·:.:.:~:.:~:~:.:.:.:.:.:.:.:.:.:~:.:.:.:.:.:.:.:.:~:.:.:.:.:.:.;.;.;.:.;.;.;.;.:.;.:.;.;.:.;~:.;.;.:.;.;.;.;.;.;.~.:.;~;~;.;.;~;~:.:.;.;.:.;.;.:.~.:~:.;~;.:.:.;.:.:.:.:~;.;.:.;.;.:.:.;.;.;.;.;.;.;.;~;.;.:.;.;.:.;.;~:.:.:~:.:~:.:~:.:.:.:.:~:.:.:.:.:.:~:.:~:.:.:.:.:.:+:.:.:+:.:~:. .... 1, i, TyPE , ,I NUMBER ! ,, , i 'N .... I, OUT i ! , , I R°PI LO,W, 4'i!GH',AVG J,, LOW-I'HGH-AVG 12R2 .: 4.5 STR35cD . w62Yj ; 3X14 ; 10330 10397, 67' 4.50 14.9 2-1-2 1496-1800-1~ :: :,;, _ .... . ; .. ..... . ~ .,. ., . ;. . : .. .,.. , . . . 13 4.5 STR35CD W63Ya 3X14 10397 10501 104 5.20 20.0 1-39-22 1519-1700-1621 : ~!4., 4.5 STR35CD :: A42ZL 3X14: 10501 1056~, 63, 3.98 .15.8 3-2'"3-14 1,530-1~1~1 .;.t,5 : 4.5 HYCALOG 19518 2.X14,3X10 10564 10840 276 9.38 29.4 6.-13-9 1926-2317-2158 ~ ~!6 4.5 HYcALo ,G, 020790 2x14,2xlo 10~40 10948 108 3.04 35.5 1-10-4 1735-25.33-2096 ~ 17 ,4.5, HYCALOG H46044 2x14,2x16 10948 11140 192 5.23 38.7 4-10-7 1775-2242-2040 -Ifil : ' i I MUD RECORD UNOCAL SCU 22-4 UNOCAL ) 9129199 10312 8.6 48 7 32 14116 8.0 1.7% TR 3.5194.8 10;2 30l)~ 9~30~99 10442 8.7 48 7 29 12114 12,4 2.3% TR 3.5194.2 11,2 2600 10101199 10325 8.8 45 7 29 12/13 20.0 3.5% TR 2.5/94J) --12-0 2300 10102199 10401 8.4 67 8 25 10114 8.8 0.5% 0.00% 2.1197.4 8.8 2100 10103199 10501 8.5 45 7 27 12115 7.8 0.5% 0.00% 2.3~97.2 9.1 2300 10104199 10565 8.7 48 8 27 11114 7.4 2.0% TR 2.2195.8 8.9 2300 10105199 10800 8.6 50 9 35 12/14 5.6 1.5% TR 2.3/96.2 9.2 2400 10106199 10828 8.6 56 9 26 10111 7.0 1.5% TR 2.3~96.2 9.3 2400 10107199 10948 8.6 56 9 31 12/14 6.6 1.5% TR 2.4196.1 8.8 2300 10108199 11128 8.6 53 9 31 12113 6.6 1.5% TR 3.0195.5 9.5 3900 10/09199 11128 8.7 57 11 25 10111 7.0 1.8% TR 3.0195.2 9.2 3600 Operator' UNOCAL Report For' N. SCALES/T. BRANDENBERG Well Name · SCU 22-4 Contractor · INLET DRILLING · R~ P.9.rt_F_o r.. :.. ~:..S A._N P! _D..~ E. DRILLING ASSEMBLY CASING Bit Size 4.5 in 2.062 CMT ASSM Surface _N. _q?=z }_CS- .5_3./_ .J /) '_..;'_ ...................... _7_. 6_~_5.i z.U3~9._5_ .4. _3/_t.. ( 9..5.4. ~.'.r_v. t.)). Drill Pipe Size Lcngth lntcrmcdiatc .3.5. in 10102..ff 5.Sin(q? !o268ft (,IO26~TV.D) Drill Pipe Size 'Length Intermediate 2.16 in 210 ft tDrill Collar Size Length Production or Liner in ft Field/Area: SOLDOTNA CREEK Description: Location: SWANSON RIVER M-I Well No.: SCU 22-4 MUD VOLUME (bbi) ' CIRCULATION DATA Hole ............... 3_7.8_._3_ .............. Activc Pits ....... !9.1._7 .......... Total Circulating Vol 570 In Storage _Pump Mak_cL_?d:)NER DENVER !_[ _O. ILWE_'LL__214-P Pump Si.z_c~_ 5 X 9.in [ 5.3 X.. 14.in , ....... ..... -' 'lsm. np stkJnqi-nt ...... 74~5~2o ....... [ ........ _.L. ....... ............... 7~ia~TAata,"t ........... -95 'ga~ifi ..... Bottoms Upi 138.2 rain ~806 stk Total Circ Time I 260.2 rain 1'0929 stk Circulating Pressure[ 650 E§J__ t PRODUCTS USED LAST 24 HRS _M.:L~._/_m_._tLnxLn_~p__r3^o) ..... !_09X_~39 L .... }_o_ ....... P[-I 6 50 LB BO I SOLIDS EQUIP Size Hr BRANDT SHAKER SSOXSS0 1 BRANDT SHAKER S40XS60 1 Desilter 8 CONE ..C_:e_n_ .m.' fug_e .......... _S__W_A C____O_-5_[.8 .......... _2_ .... MUD PROPERTY SPECIFICATIONS ..... Weight_L_ 8.4-8.6 REMARKS %/Ib/bbl) ./.2 .2/1.9 1.9/17.4 1.5/14. NAJ NA -/3.8 9.9388" MUD- PROPERTIES, Sample From ...... ~-/ P-f%3,m00 Pib~v-Liii~"~fiiii~ ............................ F-[ ..... 'g~- ......... 5 ..... NX ......... '~r~VD ............................................... -fi"1. 'i-0~ 1'~/-i52ii5' ~-'5~5'1~i51~6 ..... R600/R300 * 46/39 46/39 ~i~5/~106 ................................................................................................. 34/30 35/30 ...................................................................................... R6/R3 16/14 16/13 ~'V a'~ ......... ~ ........................ f ............... ....................................................................... ~ ...............................Jb/~.0(~=_. 32 32 HTHP FL T~mp cc/30 rain Cak~ API/HT 1/32" 1/ 1/ Solids % Vol 1.7 1.7 .~i.~!0[ ............................................... ??~ .XO] .......... }:~./2.~:,~ .... 3.7/94.6 Sand % Vol TR TR MBT ' lb&bi -5' 1.25 1.25 .pU 10.2 11.0 ,3lAd_M~d~Em) .......... I.X ....... ].4 Pf~f .4/1.9 ' .4/2.~ ......................................................... [_ ................ Chlorides m~ 3000 - ' 2900~ Harness Ca 'i 40" 40 Est. Soltex Con ~p~. .:7 5. .8 Kla-G~d Con pp_b 5 6 . ~.h~ ..................................................... }&.~y_,:d ............. 3Z .............. 3.7 .......................... : .................................................................................................. .................................. ,U .................................................................... ~ _. , ,, , . ..... 7~; ........................................ iL ~ .~ ................................ REMARKS AND TREATMENT RIH TO.. TAG C~'. NONE FO~). ~)H. RIH TO SET C~ PLUG gZ. , " :., ~lMe D~STR ~;CZi~rg MUG VOt accm (b~0 SOUDS a,aLYSlS Rig Up/~mce ' [ Oil Added .. NaCI ,~llinR / Water Added ~pp~g [ Mud R~eived ' 0 Lo Wash ~ ,, l Mud Dis~_ ., 66 B~tonite Circulate ~ Shak~s Loss ' 0 ~II ~li~ B~ ' ~ E~rati0n Loss 0 Wei~t Matmal Cmentin~ ~ C~tfi~ge Loss ' 0 Choral Cone Cgnditi°n ~ff ..... ~ [~t~n Loss - 0 ~mct W.O.O. q L~ in Hole 0 Dev. S~ev ........... [ (~ 0 ~ M4 E~GR / PHONE ~ ...... RIG Averqg. e SG .... 2.6 Carb/BiCarb._(_~. mole__/L_l._- 7.8/2.5 !WAREHOUSE PHONE} MUD RHEOLOGY & HYDRAULICS ppaValues , 0.415/0.088 a (lb.s,,n/tOOtFD Bit Loss (psi / %) I / .2 Bit HHP (hhp/HS1) ~_~-- / Bit Jet Vel (.flYsee) 14 Annular Vel DP (R/min) 144.69 Annular Vel DC (ft/min) .... 144.69 Cdt Vel DP (ff/min) - 353 Crit V~I DC (fl./rain)" I 3..53 ECD0~3. 10312 ~ I 9.08 -7-c-6k-6 -fi FC-6 :r' .... ' Operator' UNOCAL Field/Area' i Report For ' T. COLEMAN/S. LEWIS Description · , Well Name · SCU 22-4 Location · Contractor · INLET DRILL]NO M-i Well No. · ! · Rep.o~_.F_or.:_ .H._.L,.~S_~!_E .......... '~ DRILLING ASSEMBLY t -CASING Bit Size 4.5 in ttTC/STR35CD [ Surface i-lqo-~,z)~S'--5-.~"fl-l')~;- ................ ! 7.625in ~b':9543fl (,954YI'VI)) Drift ¢{p~glkc ........ L~gL}i ...... / .......i~tcrme-~iat-c .3.: 5_ _i.n_ .............................. _9_3..,7_6.~ ..... Drill Pipe Size Length Intermediate 2.875 in 850 fi Drill Collar Size Length '-----Pi:~uc--fi-6-~'~i:L'i-~( ....... ...i_n_ .............................. fi.. ...... SOLDOT~A CREEK SWANSON RIVER SCU 22-4 MUD VOLUME ._(_b_b_l)_ CIRCULATION DATA Hole .......... _P_ump_.__M_ak~D_.NE'._R_ _DE_' ~_E_R._I_J..__O__IL_~..L.L...2. L4.:~ 381.6 Pump Sizq 5 X 9.in [ 5.5 X 14.in -- XcilVc iskS ...........f,i~n~i~"i~i,d .......... >_A~-xai/si~ ~--':i 740 gai/stk .............. _2.!..23 ................. ;'j,_-u_i:¢'~'.is?O-0.1-_~.~ %~_9__s_~";Y2~ ....... .i~L 175' ..... Total Circulating Vol Flow Rate[ 153 gallmin ...... 594.4 Bo. tt_oms .U_p__[ 84.3 min 5902 stk ............. I--~'-St-;>i:ag--c ................ Total Circ Tii~_l l--~-.2-m-~h 'HY2Y~ik PRODUCTS USED LAST 24 HRS ....... 2L77.7i'; MUD PROPERTIES S_.a~_ p_l_e__Frg_m. ................................ _F_L_Q _W_~_).-6.~ .-. ...... P.I..T ~.~)J _3.{).0_ ..... Flow Line Temp. °F 90 _De_pth/TVD tt 10442/10320 Mud Weight. lb/gal .__8.__65_~_)_0°F .... 8_ ._6. 5_~ 8__5_ ?___ Funnel Viscosity s/qt 48 48 R600/R300 43/36 45/38 R200/RI00 32/27 32/28 ......................................... ...... ........ [ ......... ........ ........................................................... Vl7 ........... .................. F ............. ................ '?P- .............................................. i~/i O-o-'~t~ .......... ~ ........................ ~i' ............... 10s/10m/30m Gel lb/100 il~ 12/14/14 13/15/15 API Fluid Loss cc/30 rain 12.4 10.0 HTHP FL Temp cc/30 rain Cake API/HT 1/32" I/ 1/ Solids ....................................... %___V_oJ_ 2.3 2.3 Oil/Water oz "ol 3.5/94.2 ...... ............................................................... ~_O.._y .................................................... ._S_a~_d_ .................................. ?_o. Vgl.. TR TR MBT lb/bbl 1.5 1.5 ~H ...... "'~¥1'Y ...................... l-Ti(-] ............. Alk,'fl Mud _Cpm_),__ 2.2 2.0 PffMf 1.1/2.1 1.0/1.9 Chlorides mq/l 2500 2600 Hardness Ca 100 80 Est. Soltex Con pp.b_..__ .5 ............ -.'~' .......... Kla-G~d Con ppb 5 5 ._L..u.b_e_t.~,x_ ............................. _'..'/_ .o..py.. v__o!_ ....... 2;_2._5. ..................... 3:.5 ................. SOLIDS EQUIP Size Hr BRANDT SHAKER S50XSS0 6 BRANDT SHAKER S40XS60 6 DesiRer 8 CONE _C__en_tri_Luge .......... SWACO 518 8 MUD PROPERTY SPECIFICATIONS Weight 8.4-8.6 Viscosity{ 4_--0-2-3~ 6-8 Filtrate] ...........___.~_..-__~..~ ............................. REMARKS AND TREATMENT [--" REMARKS TREAT MUD WITtfpH-6 AI, TER PUTrlNG CEMENT IN PLACE. { ADD WA'II-iR TO BUILD PiT VOLUME DUE TO DUMPING 52 BBLS (.)F MUD WASH DOWN TO I0,325'. POll. RIH W/MWD A~ ,IxLD,," BIT. WASH J AFI~R WASHINO DOWN 1'O CEMENT TOP. DOWN TO 10,442' WHEN BIT STARTED TAKING WEIGHT. CBU. POH. TIME DISTR Last 24 Hrs~ Ri8 Up/Service / Dri!!ing / Trippin~ Wash Down 'Circulate Bt-IA ! Cementing Condition Mud w.o.o. I Dev, Survey_ ...... MUD VOL ACCT(; (bbi) SOUDS ANALYSIS Oil Added NaCl Water Added 102 KCI Mud Received 0 Low Gravity Mud Disposed 52 Bentonite Shakers LOSs ' 18 Drill Solids 2./17.9 Evaporation Loss 0 Weight Material Centrifuge Loss 12 Chemical Cone - / 3.8 Formation Loss 0 Inert/React 10.6056 Left in Hole 0 Average SO __ 2.6 I Other .... 0 Carb_/BiCarb (_m.. mole&) 20.4/.6 %/Ibibbl) ./-. 1 np/na Values .2/1.9 kp/ka (lbos~n/lOOftz) 2.3/21.2 Bit Loss (psi/%) 4/.6 -.1/-.5 Bit HHP _(.hhp./HS~-- / Bit Jet Vel (fi/see) 23 NA/NA Annular Vel DP (tVmin) ' 240.62 Annular Vel DC (_~__mJn_U)~ 240.62 Crit Vel DP {fl/min) 333 Cfit Vel DC (~min) 333 _E_CJ)__~._.]0__4_42 (Jb~_l)__r__ 9.08 DAllY COST MUD RHEOLOGY & HYDRAULICS 0.453/0.100 Operator: Report For: Well Name: Contractor: Report For: UNOCAL T. COLEMAN/S. LEWIS SCU 22-4 INLET DRILLING M. LESLIE Field/Area: Description: Location: M-I Well No.: SOLDOTNA CREEK SWANSON RIVER SCU 224 DRILLING ASSEMBLY Bit Size 4.5 in HTC/STR35CD Nozzles 3x14 / 1/32" Drill Pipe Size Length 3.5 in 9259 ft Dfi.[1. Pipe Size Length 2.ii~5 in 850 ft Drill Collar Size Length in fi CASING SI/l-face 7.625in (~9543 ft (9543TVD) Intermediate 5.5in ~ I0268ft (10268TVD) Intermediate Production or Liner MUD VOLUME (bbl) Hole 379.8 Active Pits 111.6 Total Circulating Vol 491.4, In Storage MUD PROPERTIES · Sample From Flow Line Temp Depth/TVD Mud Weight Funnel Viscosity Rheology Temp ~ R600/R3O0 } PIT~2100 OF fi 10325/10320 lb/gal 8.8~86°F 120 FLOW_('q, 1300 89 10325/10320 8.75~88°F 45 120 43/36 31/27 44/37 R200/R100 32~27 K6/R3 t3/t2 t3/t t PV cPI 7 7 YP lb/100 ft2 29 30 10s/10m/3~ Gel lb/100 tt2 12/13/14 12/14/14 API Fluid Loss cc/30 rain 20+ 20+ HTHP FL Temp cc/30 min Cake API/HT 1/32" Solids % Vol Oil/Water % Vol Sand % Vol 1/ 3.5 2.5/94 TR 1.25 12.0 2.6 1.6/2.4 2300 MBT lb/bbl pH 3.5 2.5/94 TR 1.25 12.0 2.5 1.5/2.4 2400 Alkal Mud (Pm) Pr/Mr Chlorides mo Hardness Ca 40 20 Est. Soltex Con .5 .5 ppb Kla-Gard Con ppb Lubetex % by vol 4.5 4.5 2.5 2.5 REMARKS AND TREATMENT RIH WICMT STINGER AND 6,1TS OF 2.16" DP. MIX AND PUMP 30 BBLS CMT. PUT IN PLACE AND WASH DOWN TO 10325' GR. DUMP CMT CONTAMINATED MUD. BEGIN MIXING NEW MUD. CIRCULATION DATA Pump Make ?J)NER DENVER.~-[ OILWELL 214-P Pump Siz* 5 X 9.in 'Y 5.5 X 14.in Pump Cai:4, 2.18 gal/stk I 4.749 gal/stk Pump stk/mia 72~95% [ Flow Rate i 157 gal/min Bottoms Up 81.9 rain 5899 stk Total Circ Time I 131.5 rain 9465 st& Circulating Pressure 890 psi PRODUCTS USED LAST 24 HRS Products Size ENGINEERING SERVICE 1 EA M-I BAR (LINED BAO) FLOVI$ 100 LB BO 25 LB BO SOLTEX 50 LB BG iBORAX 50 LB BG RESINEX 50 LB BG PH 6 50 LB BG DRISPAC SL 50 LB BG SOLIDS EQUIP Size Hr BRANDT SHAKER S50XS80 I0 BRANDT SHAKER S40XS60 10 Desilter 8 CONE Centrifuge SWACO 518 12 MUD PROPERTY SPECIFICATIONS Amt Weight/ 8.44.6 Viscosity 40-55 Filtrate " ,44 REMARKS TIME DISTR Last 24 HZ MUD VOL ACCTG (bbi) Rig Up/Service Oil Added Drillin~ Water Added Tripping . Mud Received Wash Down Mud Disposed Circulate Shakers Loss BHA Evaporation Loss Cementing Centrifuge Loss Condition Mud Formation Loss W.O.O. Left m Hole Dev. Survey Other t 0 0 85 t8 0 M4 ENGR/~PHONE [ RIG PHONE SOLIDS ANALYSIS NaC1 KC1 Low GraVity BenWn/te Drill Solids Weight Mater/al Chemical Conc [nert/~eact .Average SG 'Carb/BiCarb (m mole/L) } WAREHOUSE PHONE t %/Ib/bbl) ./-.2 np/na Values .2/1.9 lq~a (lb-s%/100fi2) 3.4/31.2 I Bit Loss (psi / %) -.2/-2. [ Bit, HHP (1-fl~p / IISI) 3.2/29.4 [ Bit Jet Vel (fi/sec) NA/NA } Annular Vel DP (ft/min) - / 3.8 } Annular Vel DC (Wmin) 20.939 { Crit Vel DP 2,6 ~ Crit Vet DC (ft/min) 22./. I { ECD (_& 10325 0b/gal) DAILY COST MUD RHEOLOGY & HYDRAULICS 0.453/0.100 1.206/10.881 98/11 9 /.6 112 246.91 2~6.91 330 330 9.22 CUMULATIVE COST Operator' UNOCAL Field/Ama' SOLDOTNA CREEK Report For' T. COLEMAN/S. LEWIS I~scription · Well Name · SCU 22-4 Location · SWANSON RIVER Contractor' INLET DRILLING M-I Well No. · SCU 22-4 R~ pp_~_Eo_ r_ :_ _M_._L_ _~3.L_ I_E DRILLING ASSEMBLY .... _C.. _A_S!.N__G- ......... _ _M.._.U_._D__V.O_.L._U__M.. E___.(b_ ~!)_. Bit Size 4.5 in IFFC/STR35CD Surface Hole ._No_.z_zlcs 3x14 / 1/32" 7.625m (&9543 fl (.9_5_4yi.__~'v_].))_ 380.2 Drill Pipe Size Length Intermediate Active Pits ._3_.5 in 9518 ft 5.5in~a-)lq2_6_8ft (.10268TVD) 178.3 Drill Pipe Size Length Intermediate Total Circulating Vol 2.875 in 850 fi 558.5 D--fi-~¥o]]-a¥g~e L-'~-~ Production or Liner In Storage 3 !25.in_ ............................ CIRCULATION D~TA ....... ~ ~'v~ ~c~ '~ i5 ~q¥~ '~-~-V-[FFR ........ iS_~3.-gl)~d ......... -3'7,f~.ih- ..... / ........ ~3'k'f:i'.~h ...... Pump. Cap, 2.18__gal/stk~_ 4.749 gai/stk . Flow RateI 150 gal/min B6-~r~--0~J~85.5 min 5899 st..k ....... TotalCircTimeJ 156.4min 10790stk MUD PROPERTIES s_ .am_ ~_ l_e_ fz _o m ..F_ L Q _w_ ~_2_ 3_ oq _. Flow Line Temp_ __ °F 80 _D~_pth/TVD ft 10401/I0380' _M. _u_d__W__eighL ............................ J_b/ga!___ Funnel Viscosity ................... 67 ................. si_q[ ._Rbeo/ogv TemL °F 120 R6o__o_/_~_~ 0__0_ .................................................. __~4.'~_~_-~1, 2 ........ R200/RI00 28/23 R6/R3 10/g PV cP 8 9~ ........................................................ ibff0b"iV ....--58- ........... 1 Os/10m/30m Gel .._?_.I_T.~._]. 600 __ 8O 10380/10363 ..... ~. 4(_03,,,.8_0° F _ 68 120 42/35 30/25 ........ !?) ........... 7 28 lb/100 W 10/14/15 11/14/15 API Fluid Loss cc/30 min 8.8 10.2 HTHP FL Temp.. cc/30 min Cake API/HT 1/32" . .S.91id. s_ .................................. °_/o. V_9)_ ..gi.L ./3V_.at.e_r_ ......................... %y_ol Sand % Vol _MBT._ .................................... _l_bJb_b_L ~H Alkal Mud,. P(_p_m) PffMf Chlorides mg/I Harch~css Ca Est. Soltex Con ppb .5 .5 2.1/97.4 2.1/97.4 8.8 .25 .1/.7 2100 8.6 .1/.6 Kla-Gard Con ppb Lubetex__ % by v__o..l. 2100 2O 20 3 4 4 2.1 2.1 PRODUCTS USED LAST 24 HRS Products Size Amt ENGINEERING SERVICE 1 EA 1 ;M-I BAR LL._INED BAG)_ 10(3 LB BG ___3_.0. ........ FI,OVIS .__g_5.J,_B_...B_O_~__ [ ........ [_4. ...... SOLTEX 50 LB BO [ ..... ?_ ...... MYACIDE-AS PLUS BIOCIDE I LB CN l 20 PT.X:o-X~ .......................... s~ UX-ff~l ...... ~ ..... LUBETEX ~~ i'7-- -,~' ........ YfE~-~," ) ..... ~ ....... .~sru~x. ............................. _'.ko."_~;~ 'i~.9: .......... ",3 ....... .!)_ _R!.SJ?. A_ .q..S2., ............................ SOLIDS EQUIP Size Hr BRANDT SHAKER S50XS80 7 BRANDT SHAKER S40XS60 7 i Desilter 8 CONE SWACO 518 I MUD PROPERTY SPECIFICATIONS REMARKS AND TREATMENT RIH WITH BIT//12 AND MOTOR· TAG FIRM CMT AT I0327'. ROTATE DOWN TO 10335'. ORIENT TOOL AND BEGIN SLIDING TO KICK OFF PLUG. TIME DISTR Last 24 Hrs~ MUD VOL ACCTG (bbt) Ril~Up/Serviee | Oil Added . . [_)&-i_' l_li__ng ..... ___/_W~a t=cr__A_d_.d_est' ~ 539 'l'.h_p_ping ] | Mud Recciv~ 0 ~Wa-~h Down ] --["~-~--~.~sed 491.4 Circulate / [ Shakers Loss 0 BHA' / [ Evaporation LOss 0 Cementing / . [ Centrifuge Loss , 0 Cqndition Mud . [ [ Formati_9_on Loss . i 0 W.O.O. [ ....... 1 [,eft in Hole .2. 0 '~)-~.-~_-~Z~ .....25 ...... ~-_-~'~'; ............................. Weight [ 8.4-8.6 Viscosity 40-55 Filtrate 6-8 ' RE~ARKS DRL CMT AND NEW HOLE TO 10380 THEN BEGIN DISPLACING NEW MUD INTO HOLE. DRLO CONTINUED WttlLE DISPLACING' NEW MUD WAS BUILT WHILE TRIPPING. ' SOUDS ANALYSIS NaCI , KCI Low Cna vity Beatomt~ Drill Solids Weigh~ Chemical Cone %/Ib/bbl) J .1 · I/1.4 .4/3.9 ./. ./-.2 NM HA -/4. Ine~dReact - .~e SG Carb/BiCarb (m mole/L) 2.6 2./15.8 1 WAREHOUSE PHONE t MUD RHEOLOGY & HYDRAUUCS 0.585/0.151 ---'~.445/6.678 86/4.1 7/.5 np/na Values Bit Loss (psi / %) Bit Jet Vel (~see) ' , 107 / Armula~ Vel DP (fi/rain) 306.77 Annular Vel ~ (~) 350·66 Cdt Vel DP (~) 315 C~t~e~ (~) __ 319 Operator' UNOCAL Field/Area' SOLDOTNA CREEK Report For · T. COLEMAN/S. LEWIS Description · Well Name · SCU :>2-4 Location · SWANSON RIVER Contractor · INLET DRII.I.ING M-i Well No. · SCU 22-4 : Repqrt For :. M,. LESLIE. DRILLING ASSEMBLY 'CASING i MuD'V~L'U'ME' ' (bbi)' { .......... Cii:}C~ui~.:FI-C~N"~i.':r~ Bit gize: ...a ~ .... in irro$'i'i~i}>~zb,_ .._ ....... 'gut(acc ..... i:l'o]c ." N oz2.1cs ....... 'tx14 / I/'t2" 7 625in ta)9543 ft L9543TVI)) 381 .8 P t~m @S .... iZu ............ 5X9~n: ! ............ 5 5 X 14 m: ---.: .... ;.- -: ................................................................... ; ......... · ..................................... · ............... ~ ............... ~.:-_ ..... : ....... Drill P~pe S~ze Lcngth Intermediate - ' Active Pits t Pumn Cal~, 2 18 eal/stk I 4 749 eal/stk ' 3:5..i~ ......... 9.6tS. fl. 5.$in ;bj_2J!!26~ t!.o2.68.1~.¥I)) I .... ..21(:..4. [ "iSump st~/mih] ...... Drill Pipe Size Length Intermediate '] Total'ciicuia'tin-g V0i I ............... iqb~;~'g'Ze'l .............. i~6"gh'0ihih "' 2.875 in 850 fi [ 598.2 -[ .................. '~)ttbm's :U~'I ....... i~ -7 i-bin' -~'[3,"s'tk ..... MUD PROPERTIES PRODUCTS USED LAST 24 HaS .S.'amplc.'F_ro.m ........... ' '..' .......... ~'i¥~j,5'~0.'6'' .. F__~_.'~:.L-m__e_T_ .em p ...................................... °..F_ .................... ]_..'_.'_ !)_'.~_2 f.i p_ _~. .~_ _ _V_ .D_ _ ............................................. ¢ . ~..I. . O.5._oj L Lo_4_6.0_ ........... L o4__6_~L ..... _Mud .W..e. ight ..................... lb/ga! ....... .8.,.45.~9..0.°..F. ...... S,4t~J.°F' ...... Funnel Viscosity. .. s/.ctt .4.5 .44 . · R'. hml9_g:y .Temp ................... °F. .............. [.2_(.). ................. [.2_9. ......... R600/R300 ~' ~ t34 40/33 'i~66/A'i-ii6 ........................... :39,,'~'4 .............. ~/~ ....... "~ ~;2~.~ ............................................................. 7' :~'~'/.-ii ....................... i'~? i' ii'"'.'i ....... PV cP 7 7 YP lb/lO0 Il'27 26 i:b. ~. (:i '.m':o_(i,~.:~oi..' .::. :.:......':::. !'_b.'_2:! 0_0.'. _:...::":':.i":2.73.3_/'i'.:~:'.'::.:...:'.:.:"'i :J:.'./'j.'.4?:J.~'.: .".' APl Fluid Loss cc/30 mir 7.8 8.2 iJ'J):l!5. F..L. _~ic..mp Cc/30 mi'n " Cake API/HT 1/32" 1/ I/ Solids % Vol .5 Oii/.Water' .i'. ....' .. '...i ....... ...... !~_~.~o! ....... '.i.~..~/!)~..~i"i.. ' .2.~i.}.)~'~:.:}i .... Sand % Vol 0 'Mg? i[~i~'i ............ ~":A ...................... ?'~ ............ ,P.t.<.'..':.'....'.' .............. :_:..:..'.:'. ...... :..::'...:...::.' ...... ': ..... ..%.i.'..'.. "' Alkal Mud (Pm) , 35 ....... .~3 ........ J~iSM'~ / .............. ::i?i":i ................. :57'i':5' ......... O~i0'~d~ ............... m~i'[ ..... ~360 .... 1 ~.~ii6' .'.t-b~:&,.¢~'.~_ ~ .a.'.': ..: .'. '. :'...:'...i::'....: Z':.:::i.::.il.'.:.i........'..].:'i:.::.::i:',.'g'.~,...:...:....:.:. ,:." ..'. :_':._~ 6':i :'...:: ....' ' 'i~S'/i-gSi~k-C0h ............................................. ~b:b'.' ................ : .................................. : ................. Kid-Card Con .................................................................. ~p..b_ ............ _4,_5. .......................... .4_4 ............. Lubetex ........ % byvol .... 2.3 , .2.3 ' ' ' REMARK?,'AND YREATMENT .... , ...... I ................. REMARKS ORIENT BIT' SLIDE TO I0 501 (3R. SL,rRVEY EVERY 10. POH FO.R NB AN]) M1.)D MOTOR Ai~O. .__T.!_M_E_P.I_S_T.R. ..... ~.s.t.._2_4__H.:~_._M.._U...p_.y_O_L._..A.._C..C....T..~.. (bbl) [ S_QUOS ANALYS_IS__(.~6/Ib/bbl} [ MUD RHEOLOGY & HYDRAULICS Ri~ _U2/ServiPe | "-T--Ch~[ Added ..... | ..................... I ~q~i'- ..................... --T ....... :T.2 ..... T~.~_'"'Vi~'~ ............................. "['"'~:4¢7~:1~7 .... ...... ii: .... ':": ::':::::':::' "':":" ' :::"::'"'"'" ':" / ?2dt'n&iii'iiii' ........... F ............ TS~,;/:i:a[: ';.;:~ ..... : ~. I.,.-:m .a: t ,,,.,e . : :~ m .....ei ~. ;~ .' v;, :' ' , /'co'id~tion=~d'' l .....'.....:i:; ;;:,,,' i i,:., ' ' ', :,~::: JL.,,'~,'" i'..;.. ':':;: ~'~:~')'.('"£ .......... [ ...... :.,,C: :.'~: h-t' ! , ~,:',':a,,?,' %~, .: ", f. tS~.?:"~.u,~a~; ....... l" '7.:" .:.'. [i~h~:." .'...'.' .' . ,....:,..."~t'.,~, :.: :,.,,,,,. ~ : .:,., : ,...;~ :: ..: .... ; .,....-:,, ,,. I M4 ENOR I PHONE ] RIG PHONE WAREHOUSE PHONE DAILY COST ' CUMULATIVE COST / ' ::'::'~x:':4~¥ ~-x~5 ........... :5_.-Fo::-~'~ ..... -~'6 ..... 'i.'i:iS~¥~ .......................... -T---':~-[:[::6 .......... iii .... 'sisi. fi"i:~ ..................................... ~(i i':'[i"flfi ....... c;' ' 'S(')l')itJM' BicARBO~A'I'E "50 I.I.:1 BG . 'iV/gAi~iiS/i:X'~-i;i';0~'i'i/iS/SiSi:~ ......... i"L~'~ .... 'ii':×':Siii'/3 ........................ ['"Si"LSX i¥,,i ....... "f.i'i~i'~Fffi'~' ........................................ }-"~-i'&VfS'~ ............. i ..... ~..m!.~.!'~.C'.. :s!., .......................... 1 .... ~!?.J..t}..!}~! .... 4 ~'bLiD§"~bqJi~ ..................... §iii- ....................... '-fii- ...... '[~R:L'N-bY '§i4X'ff[g, ................ S:~bX~0- ..................... ~ ..... ...~..i:~.?..:...~..x:.:g:~.~.:.:.:..::.:...:.::.~3...(:8:.~..~:~.::....::..:.: ...... ,! ..... Desilter 8 CONE '~.&'./~!:~i:/F::'2'7":'::::'.:.:F'::;:g~-~:'.e.o':.'~:i,f:TT: ...... :~".':':' MUD PROPERTY SPECIFICATIONS Weight I 8.4-g.6 :.'..'.'.':":"'::'":':.::-:::~:.Osi~'.L::::::::::::::::::::::::::::::::::: .'.:'::'.:.':..' '. '.' Filtrate| 6-8 Report For' T. COLEMAN/S. LEWIS Description · Well Name: SCU 22-4 Location ' SWANSON RIVER Contractor: INLET DRILLING MA Well No.: SCU 22-4 Report For: M. LESLIE DRILLING ASSEMBLY I CASING I MUD VOLUME (bbl) CIRCULATION DATA Bit Size 4.5 in HTC/STR35CD Surface Hole Pump Mak~ ?,DNER DENVER ! OIl.WELL 2 I4-P Nozzles 3x14 / 1/32" 7.625in ~9543ft (9543TVD) 383.9 Pump Size 5 X 9.in 5.5 X 14.in Drill Pipe Size Length Intermediate Active Pits Pump Cap 2.18 gal/stk 4.749 gal/stk 3.5 in 8776 ft 5.Sin ~..I0268ft (10268TVD) 205.3 Pump stldmin 68~95% Drill Pipe Size Length Intermediate Total Circulating Vol Flow Rate 148 gal/rain 2.875 in 1746 ft 589.2 Bottoms Up 88 rain 5984 stk Drill Collar Size Length Production or Liner In Storage Total Circ Tim.__e 167.2 rain 11370 s~-~ 3.125 in 43 ff Circulating Pressure. 1450 psi _ MUD PROPERTIES PRODUCTS USED LAST 24 HRS Sample From PIT~2200 FLOW~0900 Products Size Amt Flow Line Tamp °F 97 ENGINEERING SERVICE I EA 1 ~, th/TVD ft. 10565/10477 10535/10463 M-I BAR (LINED BAG) 100 LB BO 72 Mud Weight lb/gal 8.65~88°F 8.6~91 °F FLOVlS 25 LB BG 5 Funnel Viscosity. s/qt 48 49 SOL'I'EX 50 LB BO 6 ' Rheology Tamp °F 120 120 DRISPAC SL 50 LB BG 6 R600/R300 43/35 44/36 ' ' R200/R. 100 30/2430/24 R6/R.3 11/9 1 I/9 , PV cP 8 8 YP lb/100 fi: 27 28 10s/10m/30m Gel lb/100 ftz 11/14/15 11/14/15 ..... .API Fluid Loss ce/30 rain 7.4,.. 7.8. " 1-ITHP FL Tamp . cc/30 rain -- cake API/HT 1/32" 1/ 1/ .Solids '% Vol 2 i.75 Oil/Water % Vol 2.2/95'.8 2.3/95.95 - ,Sand--_ % Vol TR TR -- SOLIDS EQUIP Size Hr .MBT lb/bbl .5 .5 BRANDT SHAKER S50XS40 7 ...pH '8.9 9.0 BRANDT SHAKER SSOXS60 7 Alkal Mud (Pm) .25 .3 Desilter 8 CONE -.. PffMf .15/1.2 .2./1.2 Centrifuge SWACO 518 8 Chlorides mgtl 2300 2300 Hardness Ca 20 20 , , 'Est. Soltex Con ppb 3.5 3.0 Kla-Gard Con ppb 4.5 4.5 ..Lubetex % bE v_p! 2.2 2.3 -- MUD pROPERTY SPECIFICATIONS' Weight 8.4-8.6 Viscosity 40-,55 Filtrate 6-8 REMARKS AND TREATMENT REMARKS RIH W/BHA #22 & BIT #l 4. WORK THRU TIGHT HOLE GEN'I~y ' INCREASE SOLTEX TO 4 PPB BY TRICKLING IN WHILE DRLO. 10460.480. SLIDE FROM 10501 TO 10565' OR. POH FOR NB AND BHA. · .., TIME DiSYR Lagt 24 His MUD VOL ACCTO {bbl} SO~OS ANALYSIS, %/II:UI~I} MUD RHEOLOGY & HYDRAULIC-8 Rig U~Service Oil Added NaC1 ./. 1 i rip/ha Values 0.556/0.138 Drilling , ,, WaterAdd~ KCI .I/1.5 kp/ka (lb-s~n/100fF) 0.565/7.666 Tripping MudR~qved 0 LowCn'av~ty 1.4/13.' Bit Loss (psi/%) 86/5.9 Wash Down Mud Disposed 0 Benionite -. 1/-.6 Bit HHP (hhp / HSD 7 / .5 Cixeulate Shakers Loss 1 Drill Solids I. l/9.6 Bit J~ Vel (~see) 105 BHA Evaporation Loss 0 Weight Material .4/6.3 Annular Vel DP (lb'rain) 302.68 Cementing Centrifuge Loss 8 Cbem~ieal Cone - / 4. Anm,_ia_r Vel DC (fi/rain) 345.98 Condition Mud Forrmtion Loss 0 Inert/React 16.9898 Crit Vel DP (ftYmin) 320 W.O.O. Left in Hole 0 Average SO 2.97 Crit Vel DC (ft/min) 324 ,,Dgv. Survey Other 0 Carb/BiOirb (m mole/L) 3./18.9 ECD ~ 10565 0b/gel) 9.02 M4 ENGR / PHONE RIG PHONE { WAREHOUSE PHONE I DAILY COST CUMULATIVE COST Operator' L:NL)CAb Field/Area' SOLDOTNACREEK Report For' T. COLEMAN/S. LEWIS Description: W~II Name · SCU 22-4 Location · ~WAP4:~UN KIV~K Contractor' INLET DRILLING M-i Well No. · SCU 22-4 Report For: M. LESLIE DRILLING ASSEMBLY ' - CASING MUD VOLUME (bbl-j- CIRCULATION DATA Bit size 4.5 in HYC/DS-74HFJK Surface Hole Pump Make ~2)NER DENVER ! OI~/'WELL 214-P Nozzles 2x16/2x14 / 1/32" 7 625in.~9543ft (9.543TVD) 387.5 P.ump Size 5 X 9. in 5.5 X 14.m Drill Pipe Size Length Intermediate Active Pits . Pump Cal~ 2.18 gal/stk 4.749 gal/~tk 3.5 in 9007 ft 5.Sin (~,I0268ft (10268TVD) 202.4 Pump stk/min 68~95% Drill Pipe Size Length Intermediate Total Circulating Vol Flow Rate 148',~a!/m. in 2.875 in 1746 ft 589.9 Bottoms Up 88.5 mm 6019 stk Drill Collar Size Length Production or Liner [ In Storage Total Cite Time 167.4 mm 11383 s~-- 3.125 in 47 ft.I Circulating Pressure 1725 psi. MUD PROPERTIES PRODUCTS USED LAST 24 HRS Sample From PIT~2300 FLOW~ 1306 .... products Size Amt _ Flow Line Temp °F 95 90 ENGINEERING SERVICE I EA 1 Depth/TVD ft 10800/10491 10650/10487 cAosTic SODA 50 LB BO' 2 MudWeight lb/gal 8.55~90°F 8.65~88°F. FLOVIS... 25 LB BO ...2. Funnel Vi-seosity .. s/qt 50 48 SOLTEX 50 LB BG 16 Rheology Temp °F 120 '" 120 LUBETEX 55 GA DM 1 R600/R300 53/44 45/36 RE$INEX 50 LB BG .. 4. ~.00/RI00 36/27.. 31/25 DRISPAC SL _ 50~LB BO 3 R6/R3 13(11 ,.. ! Il9 . PV cP 9 9 YP lb/lO0 ft: 35 27 10s/!0m/3.0m Gel lb/100 fi2 12/14/14 'i 1'./i3)13 .... . ...... API Fluid Loss . ced30 mtn .5.___6 7.6 ........ HTHP FL.Temp cc/30 rain . .. Cake API/HT 1/32" ' 1~ 1/ .............. Solids ..... o,20 Vol 1.5 2.3., ..... Oil/Water .... % Vol 213/96.2 2.3/95.4 .... Sand ..... % Vol TR TR SOLIDS EQUIP Size Hr ._ MBT '' lb/bbl .25 .25 ~RANDT SHAKER s50XS40 18 . pH ..... 9.2 8.8 -- BRANDT SHAKER S50XS60 18 '. Alkal Mud (pm) .4'.5 '.. 14" - i Desilter 8 CONE Pf/Mf .2/!.5 .15/1.4 Centrifuge' SWACO 518 .. 24 Chlofid~s .... mW1 2400 2500 ................... Hardness .Ca 20 . . 20 Est.$o!texCgn .... ppb ...4 3.5 ' ' ' . .. Kla-Gard Con ppb 4.75 4.75 Lubetex... % by yol 2.~ ' .2.3. "' ' ...... ' ..... MUD pROPERTY SPECIFICATi, ONS .... Weight 8.4-8.6 ...... . Viscosi .ty 40-55 Filtrate 6-8 ................ REMARKS AND TREATMENT ' ' REMARKS ........ ADD ONE LUBETEX AND ONE KLAGARD. SOLTEX TO INC PPB TO ADD 10 BBLS OF WATER DUE TO EVAPORATION AND RUNNING 4. DRISPAC TO REDUCE FLUID LOSS. PUMP HV SWEEP TO INSURE CE~OE. GOOD HOLE CLEANING; NOTHING ON BU. · · TIMk DisTR .LaSt 24 ,H. rs' MOa VOL accVo YbbI} ' SOUDS ANALYSIS %/lb/bbl) MUD RHEOL '..OG¥ & HYDRAUUCS ~g Up/Service Oil Added NaCl ./.2 np/na Values 0.536/0.130 ...Drilling Water Added 12 : KCI ..... .1/1.5 ' kp/ka (lb's'~.' 100tl;~' 0/754/9.497 "~I'ri'l~in~ .........../~;IudReeeived O" LowCrm.vitY 1.2/i0.7 i Bit Loss (Es.i/%) 36/Z'1 ' WaSh Down .... Mud Disposed' 0 Bentonite ' ~. 1/-.6 Bit ~ ~fihp./HSI) "~ ' 3 / .2' "Circulate' Shakers Loss " 2' Drill Solids ..... 18/7.2 Bit Jet Vel (fi/see) 68 BHA ......... EVaporation Lo.ss .... 5 We. ight Material .2/2.7 Armular. VeI DP (.fi/..rain) 302.68 -'.Cementing ' ' Centrifiage Loss . 7 Chemical Cone - / 4. ' Annular Vel DC, (ftg. min) 345.98 Co..ndi. 'tion.. Mud Formo. tion Loss .... 0 Inert/React 25.6534 C..rit Vel DP (ft/min) 352 '.' . . W.O.O. Left in Hole i 0 Average'SO '[ 2.82 C.rit Vel DC (R/mm) . "" 356 .... Dev. Survey OtherI 0 Carb/BiCarb (m mole/L)[ 4[./~2.6 , , "' . . . . ECD (~, 10800 Ob/~l) 9.02.. M4 ENGR I pHoNE I RIG PHONE '" WAREHOUSE PHONEI DAILY cOsT 1 ~UMULATlVE COST ,riM BROWN 252-7~1~n ~-~.~ ~ -,-.~. or.o~ .......... Operator' LJNOCAL Report For: T. COLENG-~u'H/S. LEWIS Well Name · SCU 22-4 Contractor' INLET DRILLING Report For' M. LESLIE FieiatArea · SC)LDOINA CKEEix Description - Location · SWANSON R.P~R M4 Well No.: SCU 22-4 DRILLING ASSEMBLY CASING MUD VOLUME (bbi) I CIRCULATION DATA [BitSize 4.5 in HYC~S-74HFJK Surface Hole ! PumpMak~LDNERDENVERII OILWELL214-P Novyles 2x16/2x14 / 1/32" 7.625in ~9543t~ (9543TVD) 432(Tot)/24.3(Bit) ! Pump Sizd 5 X 9.m t 5.5 x 14.in 3.5 .in ff Drill Pipe Size Length I Intermediate Total Circulating Vol Flow Rate 148 gal/mm 2.875 in 573 15 Drill Collar Size Length I Production or Liner In Storage Total Circ Time 46.9 rain 3188 stk 3.125 in 47 t5~ '-~ Circulating Pressure 1725 psi MUD PROPERTIES PRODUCTS USED LAST 24 HRS ,Sample From PIT~23:30 F.L.~,09:00 Products Size Ami 'Flow Line Temp of. NA 92 ENG~G SERVICE 1 EA. 1 .Depth/TVD 15 10828/11)'491 10828/10_491 M-I BAR (LINED BAG) 100 LB BG 45 Mud Weight l~/gal 8.6(~82°F .8.5~.,92°1 Funnel Viscosity s/qt 56 48 EM1-544 55 GA DM 1 Rheolo.~ Temp °F 120 120 R600/R300 44/35 45/36 R200/R100 , 30[24 31/24 R6/R3 to/g 10/8 PV cP 9 9 YP lb/lOO ft2 26 27 10s/10mJ30m Gel lb/100 fl' 10/11/12 10/11/12 API Fluid Loss cc/30 rain 7.0 6.8 HTHP FL Temp cc/30 rain Cake API/HT 1/32" 1/ 1/ Solids % Vol 1.5 1.5 Oil/Water % Vol 2.3/96.2 2.3/96.2 Sand % Vol TR TR SOLIDS EQUIP Size Hr , , MBT lb/bbl .5 .5 BRANDT SHAKER S50XS40 9.5 pH 9.3 9.2 ~NDT SHAKER S50XS60 9.5 Alkal Mud (Pm) .25 .25 Desilter 8 coNE 0 Pf/Mf .15/1.5 .15/1.5 Centrifuge SWACO 518 24 Chlorides mg/l 2400 .. 2400 Hardness Ca 20 20 Est. Soltex Con ppb 4 4 Kla-Gard Con ppb 4.75 4.75 Lubetex % by vol 2.3. 2.3 MUD PROPERTY SPECIFICATIONS Weight 8.4-8.6 Viscosity 40-55, ~ Filtrate 6-8 REMARKS AND TREATMENT REMARKS Pumped 2 dry jobs. Soltex concentration now a 4 ppb. Drl tY10800-10828'. Problems with s_ _aWe~ and top drive. POOH. Bit worn and out of gauge. Test BOPE. Start 22H w/new bit and MWD probe. TIME DISTR La;s..t. 24 Hfs~ MUD VOL ACCTG (bbi) SOUDS ANALYSIS ~dlb/bbl) MUD RHEOLOGY & HYDI~RUI. lC~ Rig Up/Service 2.0 Oil Added NaC1 ./. 1 rip/ns Values 0.613/0.164 Drilling 3.0 Water Added KCI .1/1.5 kp/ka Ob, s~vJl00~z) 0.397/&536 Tril>pin~ 7.0 Mud Received 0 LowGravity .8/7.2 Bit Loss (psi/%) 36/2.1 Back Ream 1.0 Mud Disposed. 0 Bentonite ./.2 Bit I-fftP (hhp / HSI) 3 / .2 Circulate 2.0 Shakers Loss 0 Drill Solids .3/2.5 Bit Jet Vel (fi/see) 68 BHA 2.0 Evaporation Loss 0 Weight Material .6/8.2 Annular Vel DP (fi/mia) 101.8~~ B.O.P.Testing 4.5 Centrifuge Loss 4 Chemical Cone - / 4.5 Annular Vel DC (fi/mm) 106.3 Der. Sum'er 2.0 Formation Loss 0 Inca/React 4.413 Crit Vel DP (fi/min) ~97 Pills 0.5 Left in Hole 0 Average SG 3.26 Crit Vel DC (fi/mm) 299 Dev. Survey. Other 13 Carb/BiCarb (m mole/L) 3./7.5 ECD ~ 620 (lb/gal) 8.87 , M-i ENGR I PHONE I RIG PHONE J WAREHOUSE PHONE J DALLY COST [ CUMULATIVE COST Operator: bNL)LAL Report For: T. COLEMAN/S. LEWIS Well Name: SCU 22-4 Contractor: INLET DRILLING Report For: M. LESLIE Fietc~Area: b©LDO'I'NA Description: Location: SWANSON MA Well No.: SCU 22-4 DRILLING ASSEMBLY CASING MUD VOLUME (bbi) t CIRCULATION DATA Bit Size 4.5 in HYC/DS-74HFJK Surface , Hole Pump Makd >,DNER DENVER ! [ OIl.WELL 214-P Nozzles 2x16/2x14 / 1/32" 7.625in (~9543fl (9543TVD) t 436.4(Tot)/.4-(Bit) Pump Si~ 5 X 9.m 5.5 x 14.in Drill Size Len~ Intermediate Active Pits 2.18 3.5 in fl ,5.5in @10268ft (10268TVD) { 136.5 { Pump stk/miri 68(495% Drill Pipe Size Length Intermediate Total Circulating Vol { Flow Rate / 148 gal/mm 2.875 in fl 136.8 I BotlomsUp] .1 mtn 6stk Drill Collar Size Length Production or Liner In Storage t Total Cite Time 38.8 mtn 2641 stk 3.125 m 10 fi:I Circulating Pressure 1950 psi MUD PROPERTIES PRODUCTS USED LAST 24 HRS Sample From F.L.~ 11:00 71T~24:00 ProduCts Size. Amt Flow Line Temp °F 92 NA ENGliN-EF. RiNG SERVICE ! AA D~th/TVD fl 10948/10486 10890/10489 M-! BAR (LINED BAG) 100 LB BO 38 Mud Wei,~at lb/gal 8.6,~,92°F 8.6(~84°F SOLTEX 50 LB BO 5 Funnel Viscosity , s/qt 56 47 DRiSPAC SL 50 LB BG 4 Rheolo~ Temp °F 120 120 R600/R300 49/40 47/36 R200/RI00 35/26 33/26 R6/R3 12/t0 t t/9 'PV cB 9 l 1 YP lb/100 fi:= 31 25 10s/10rrff30in Gel lb/t00 fl= 12/14/14 11/' 12/13 API Fluid Loss cc/30 mm 6.6 7.0 HTHP FL Temp cc/30 mtn Cake APl/I-IT 1/32" 1/ 1/ Solids % Vol 1.5 1.5 Oil/Water % Vol 2.4/96.1 2.4/96.1 Sand ~' V61 TR .25 SOLIDS EQUIP Size Hr MBT lb/bbl .75 .5 BRANDT SHAKER S50XS40 12 pH 8.8 9.0 , BRANDT SHAKER S50XS60 ' 12 Alkal Mud (Pm) .2. .25 ;Desilter 8 CONE 0 PffMf .1/1.4 . 15/1.5 Centrifuge SWACO 518 .24.__ Chlorides m,v. fi 2300 2400 Harduess Ca 40 20 Est. S°ltex Con ppb 4.2 4.0 Kla-Gard Con ppb 4.6 4.75 Lubetex % by vol 2.4 2.4 MUD PROPERTY SPECIFICATIONS ,. Weight 8.4-8.6 Viscosity 40-55 ..... I Filtrate 6-8 REMARKS AND TREATMENT REMARKS RIYI t/10818',. _sm-y_.eying da in open hole. Ream 1081'8-10828'. Hole in good shape. ~ _& pump Hi-V. is sweep ~ 10828' t/recover any metal left in .hole f/worn Drl f/10828-10948'; an~le increasing t/~95 deg. Coal m sample f/10890~, decreasing as bit. None seem at IXms up. Soltex added f/coals, Drispac S/L f/fluid loss. drlg eontinueck back to primarily safid: Ciro hole olean and W.O.O. Pump dry job ahd PODH f/low angle BI-IA. Change out bit t/St 17. i Mixed & pumped dry job. , TIME DISTR Last 24 Hfs MUD VOL ACCTG (bbi) SOLIDS ANALYSIS ~dl'b/bbl) MUD RHEOLOGY & HYDRAUUC~ Rig Up/Service 0.5 Oil Added NaC1 ./.2 np/x~ Values 0.559/0.139 Drilling 5.5 Water Added KCl .1/1.4 kl~ka (lb.s~rffl00R;) 0.619/8.500 Trilx~ing 11.5 Mud Received 0 Low Gravity .8/7.3 Bit Loss (psi / %) 36 / 1.9 Ream 0.5 Mud Disposed 0 Bentonite .1/.5 Bit HHP (hhp/HSI) 3 / .2 Circulate 1.5 Shakers Loss 0 Drill Solids .3/2.3 Bit Jet Vel (flffsec) 68 BHA 2.0 Evaporation Loss 0 Weight Material .6/8.3 Annular Vel DP (fl/rain) 106.3 ... W.O.O. 1.5 Centrifuge Loss 0 Chemical Cone - / 4.5 Annular Vel DC(R/mm) 106.3 Der. Survey 0.5 Formation Loss 0 Inem'Reaet 2.7049 Crit Vel DP(flYmin) 322 Pills 0.5 Left in Hole 0 Average SG 3.26 Crit Vel DC (fthnm) 322 Dev. Survey. Other 0 . Carb/BiCarb (m mole/L) 2./15.8 { ECD ~ I0 0b/gal1 8.95 . .. M-! ENOR / PHONE ] RIO PHONE { WAREHOUSE PHONE { DAILY COST / CUMULATIVE COST Operator: UNOCAL Report For: T. COLEMAN/S. LEWIS Well Name: SCU 22-4 Co~: INLET DR1LLING Report For: J. SANDIDGE Field/Area: SOLDOTNA CREEK Description: Location: SWANSON RIVER M4 Well No,: SCU 224 DRILLING .ASSEMBLY CASING MUD VOLUME (hbo ! CIRCUI~AT!ON DATA Bit Size 4.5 in HYC/DS-74HFJK Surface Hole I Pump Make/~DNER DENVER 1 i OILWELL 214-P Nozzles 2x10/2x14 / 1/32" 7.625in .~..9543R (9543TVD) I 434.7(Tot)/65. l(Bit) t Pump Si~ 5 X 9.in 5.5 X 14.in Drill Pipe Size Length Intenr~ediate Active Pits t Pm~ Cap 2.18 gal/stk 4.749 gal/stk 3.5 in Ii 5.5in (~10268ff (10268TVD) 148.3 Pump stk/mini 68~95% Drill Pipe Size Length Intermediate Total Circulating Vol Flow RalTe i 148 gal/rain 2.875 in 1604fi 213.4 BottomsUpl 16.2min 1101 stk Drill Collar Size Length Production or Liner In Storage Total Circ Time 60.5 mm 4117 stk 3.125 in 47 Ii Circulating Pressure 2060 psi MUD PROPERTIES PRODUCTS USED LAST 24 HRS Sample From PIT~24:00 F.L.~I 1:30 Products Size Amt Flow Line Temp °F NA 88 ENGINEERING SERVICE 1 EA. 1 DepiYrVD Ii 11128/10465 10090/10468 M-I BAR (LINED BAG) 100 LB BO 38 50 LB BO 9 MUdFunnelWeightviscosLty lb/gals/qt8'6~87°F53 8'65~88°F54 KLA4'3ARDPOTASSIUM CHLORIDE (KCI 55 GA DM 4 Rheolo.~ Temp °F 120 120 LUBETEX 55 GA DM 3 R600/R300 _ 49/40 50/41 R200/R100 33/25 34~26 R6/R3 12/10 12/10 PV cP 9 9 YP lb/100 ti' 31 32 10s/10m/30m Gel lb/100 ftz 12/13/t4 12/14/14 API Fluid Loss cci30 rain 6.6 6.6 HTHP FL Temp cc/30 min Cake API/HT 1/32" 1/ 1/ Solids % Vol 1.5 1.7 Oil/Water % Vol 3.0/95.5 3.0/95.3 Sand % Vol TR 0.25 SOLIDS EQUIP Size Hr MBT lb/bbt .75 .75 BRANDT SHAKER S50XS40 13.0 pH 9.5 9.0 BRANDT SHAKER S50XS60 13 Alkal Mud (Pm) .3 .25 Desilter 8 CONE 0 Pf/Mf .2/1.5 .15/1.4. Centrifuge SWACO 518 24 Chlorides rog/1 3900 3400 Hardness Ca 20 20 Est. Soltex Con ppb 4.4 4.3 Kla-Gard Con ppb 8.0 8.0 Lubetex % by vol 3.0 2.8 MUD PROPERTY SPECIFICATIONS Weightt 8.44.6 Viscosity 40-55 Filtrate 64 REMARKS AND TREATMENT [ REMARKS lncr Kla-Gard cone tbr inhibition of clays. Deposits on previous bit when I Cont RIH. Tag ~ 10485'. Wk thru fight spots (~ 10485' 10673-I0683', 10708', and pulled. Incr. Lube-Tex cone. due to torque on {,xaxem ran mad to enhmac~ 10754-107925 A'p_pears to be caused ~ B HA, Fsi trip-w~Sa~t; (4.375"). Ro _tary drl Iubficity for liner. Soltex trickled in durn~_ drilling. Lfixed dR job. MLxed 10936-11128'. B~i~k ream t/window, cue out. Only rfiinor spots encountered on CBU. 13.25 b~ls ( .r~lmred amount necessary f6r 15 bbl-s completeitZper BY) 6% KCL Cim bans up ffwindow and POOH. brine for MmtE3a=e pill Cim btms .up ~ .window prior t/POOH, less than 1 qt cuttings returned in 25 minutes prior to blms up.~Hole dean prior to ealculal.ed btm~ up TIME DISTR Last 24 Hfs4 MUD VOL ACCTG (bbi) SOUDS ANAL~ Vd~m~:vbi) MUD RHEOLOGY & BYDRAI.RdCS Rig Up/Service [ 0.5 ~ Oil Added NaC1 .1/1.1 rip/tm Values 0.559/0.139 Drilling { 7.25 [ Water Added 10.1 KC1 I .1/1.4 kp/ka (lb s"v./100fi2) 0.619/8.500 Tripping I 10.5 [ MudRecei-~t 0 LowGravity [ .7/6.7 IBit Loss (psi/%) [ 84/4.1 Ream I 3.5 [ Mud Disposed 0 Bentomte [ . l/.6 ] Bit HHP (hhp / HSD 7 / .5 Cixeulato [ 1.75 [ Shakers Loss 0 Drill Solids .2/1.7 [ Bit Jet Vel (fi/sec) t 105 Monitor Well } 0.5 } Evaporation Loss 0 Weight MalerJeJ .5/8. ] / Ammlar Vel DP (fi/mm) 101.82 W.O.O. / ! Centrifuge Loss 0 Chemical Cone [ - / 4.5 ] Annular Vel DC (fi/mm) 106.3 Der. Survey [ ~ Formation Loss 0 ~ct 1.9818 [ Cdt Vet DP (fi/rain) 320 Pills / ~ Left in Hole 0 Average SG t 3.28 / Crit Vel DC (It/mm) 322 Dev. Survey I ~ Other 0 Carb~iCarb (m moleg~) [ 4./6.3 [ ECD ~ 1651 (lb/~l) [ 8.92 operator· L~OCAL Report For' N. SCALES/T. BRANDENBURG Well Name: SCU 22-4 Contractor: iNLET DRILLING Report For' J. SANDIDGE Field/Area: Description: Location: MA Welt No.: SOLI~TN'A CREEK SWANSON RIYER SCU 22-4 DRILLING ASSEMEILY Bit Size 4.5 in Nozzles 2x10 ~x14 / 1/32" Drill Pipe Size Length 3.5 in 6577 ff Drill Pipe Size Length 2.063 in 1441 ff Drill Collar Size Length in ft CASING Surface 7.625m 5~9693ft (9693TVD) ' Intermediate 5.5in (3,1028Oft (10280TVD) Intermediate Production or Liner MUD VOLUME (bbl) Hole 411.7(Tot)t3 13. t (Bit) Active Pits 153.3 Total Circulating Vol 466.4 In Storage CIRCULATION DATA Pump Maka U2)NER DENVE-~ 1 t OILWELL 214-P Pump Si~ 5 X 9.in I 5.5 X 14.in Pump Cal5 2.18 ~l/stk 4.749 gal/stk Pump stldmin 6&~,95% Flow Rate Bottoms Up 148 gal/min 73.6 min 5007 stk Total Circ Time I 132,4 rain 9001 stk Circulating Pressure I 2060 psi MUD PROPERTIES Sample From Flow Line Temp °F Depth/TVD Mud Weight lb/gal Funnel Viscosity s/qt PIT~24:00 NA R200fR100 11128/10465 8.65~77°F 57 PITt~I2:00 NA l 1128/10465 8.65~83°F 55 Rheolot~ Temp °F 120 120 R600/R300 47/36 49/40 30/22 33/25 R6/R3 PV cP YP lb/100 fi2 I Os/10rrd30m Get lb/100 ftz' 10/8 12/10 I0/1 t/12 11 25 3I 12/13/14 APl Fluid Loss cc/30 min HTHP FL Temp ce/30 min Cake API/HT 1/32" 7.0 6.6 Solids % Vol 1.8 1.9 Oil/Water % Vol 3.0/95.2 3.0/95,1 Sand % Vol MBT lb/bbl .75 pH 9.2 .25 .15/1.5 3600 2O 4,0 Alkal Mud (Pm) Pf/M£ Chlorides mg/l Hardness Ca Est. Soltex Con ppb Kla-Gard Con ppb Lubetex % _b_v_ yp i TR .75 9.4 .2/1.6 3900 20 4.4 8.0 6.5 2.5 3.0 PRODUCTS USED LAST 24 HRS Pr~-~ucts Size Amt ENGINEERING SERVICE 1 EA I . POTASSIUM CHLORIDE (KCI 50 LB BG 44 SOLIDS EQUIP Size Hr BRANDT SHAKER S50XS40 1.5 BRANDT SHAKER S50XS60 1.5 Desilter 8 CONE 0 Centrifuge SWACO 518 2.0 MUD PROPERTY SPECIFICATIONS W~4~t/ 8.44.6 ViscosiW 40-55 Filtrate 6-8 REMARKS AND TREATMENT Mix 90 bbls 6% KCL bt/ne. REMARKS Cont. POOH. L/D BHA. P/U 3.5" liner & 2.063" inner string. Space out hanger. Pump vol of liner. R1H slowly w/liner. TIME DISTR Last 24 Hrs Ri8 Up/Service 2.5 Drilling 1755 Tripping PJSM Circulate BHA { 1.0 P/U Liner/I. St 7.5 P/U Hanger 1,0 RIH wfl .inet 8.5 Dev. Survey MUD VOL ACCTG (bbl) Chi Added Water Added Mud Received Mud Disposed Shakers Loss Evaporation Loss Centrifuge Loss Formation Loss o 18 Left in Hole 0 SOUDS ANALYSIS M4 ENGR I PHONE NaC1 KC1 Low Gravity Bentonite °Mi~bbO .1/.9 · l/1.4 We/ght Material 1./8.8 ./.3 0 Drill Solids .4/4. 0 .6/9.3 Chemical Cone RIG PHONE InerVReact -/4.5 4.7991 3.23 MUD RHEOLOGY & WfDRAUL,ICS np&a Values k-pm 0b.s~t00ft~) Bit Loss (psi / %) Bit HHP thhp / HSD Bit Jet Vel (fl/sec) Arm~l~ Vel DP Annular Vel DC (ff/min) Crit Vel DP (fi/mm) Cdt Vel DC (R/mia} 0.659/0.188 0.333/6.283 85/4.1 114.64 ' Average SO Carb/BiCarb (m mole/L) 3./9.4 { ECD ~ 8078 Ob/gal) I WAREHOUSE .;~ONE ! DAILY COS:T { CUMULATIVE COST 1'14.64 316 316 9 DAILY CHRONOLOGY SCU 22-4 09-29-99: 09-30-99: 10-01-99: 10-02-99: 10-03-99: 10-04-99: 10-05-99: 10-06-99: 10-07-99: 10-08-99: 10-09-99: 10-10-99 Run in hole to tag cement, None found, Pull out of hole, Run in hole to set cement plug number two, Treat mud with pH-6 after puffing cement in place. Wash down to 10325'. Pull out of hole. Run in hole with MWD and bit. Wash down to 10442', when bit started taking weight. Circulate bottoms up and pull out of hole. Run in hole with cement stinger and 6 joints of 2.16" drill pipe. Mix and pump 30 barrels cement. Put in place and wash down to 10325', Dump cement contaminated mud, Begin mixing new mud, Run in hole with bit number 12 and motor, Tag firm cement at 10327', Rotate down to 10335', Orient tool and begin sliding to kick off plug, Drill ahead from 10335' to. 10397', Puli out of hole, Cut and slip drilling line, Pick up bit number 13 and run in hole, Finish running in hole, Rotate and slide .from 10397' to 10501', Pull out of hole, Pick up bit number 14 and run in hole, Finish running in hole., Rotate and slide from 10501' to, 10564'. Pull, out of hole. Pick up bit number 15, Start running in hole, Run in hole to shoe, .Change out drilling line spool. Run,in hole to 10564'. Drill from 10564' to 10827', Pull out of hole to shoe for top drive repair, Run back to bottom, Drill ahead from 10827' to 10840', Encountered problems with MWD tool and top drive. Pull out of hole, Service rig and test BOPE Pick up new bit and MWD tool, Run in hole, Finish running in hole, Drill from 10840' to 10948', Coal seen in samples from 10830' to 1.0905', Coal decreasing as drilling, continued~ Circulate hole clean, Pump dry job and pull out of hole for Iow angle BHA, Change out to bit #17, Complete running, in hole. Drill from 1.0948' to 11140'. Back ream to window. Circulate out. Circulate bottoms up at window.. Pull out of hole. Complete pulling out of hole, Lay down BHA, Pick up3,5" liner and 2,063" inner string, Space out hanger, Pump volume of liner, Run in hole slowly with liner. UNOCAL: SCU 22-4 LITHOLOGY SUMMARY 10385' Tuffaceous Claystone = very light gray to greenish gray; soft to slightly firm clayey to gritty texture; moderate to good cohesion poor to moderate adhesion; occasionally amorphous lumps embedded with sand grains; moderately calcareous. 10410' Coal/Carbonaceous Shale = black to dark brown; irregular to subblocky to planar habit firm to hard; brittle; smooth texture; resinous luster; lignite to subbituminous grade. 10435' Sand/Sandstone = light gray to very light gray; firm to friable; very fine upper to medium upper; subrounded to subangular; mod sorted; clay matrix cement; grain supported; dominantly clear to milky quartz; dark lithics; chert; no sample fluorescence; no petroleum odor; no cut. 10505' Tuffaceous Siltstone = medium to light gray soft to moderately firm; platy to blocky cuttings habit; planar to blocky fracture; argillaceous; carbonaceous in pa.rt; slightly calcareous; ashy texture; bentonitic; interbedded with tuff and claystone and thin beds of sandstone, no cut, no fluorescence 10550' Sand/Sandstone = medium to light gray; firm to friable; fine upper to coarse lower; subrounded to angular; moderate to poorly sorted; generally grain supported with clay matrix cement; dominantly clear translucent quartz; dark lithics, and chert; composed of quartz (40-50%), lithics (20-40%),chert (10%). 10600' Sand/Sandstone -- light to medium gray; firm to friable; fine upper to coarse upper; subrounded to angular; moderate to poorly sorted; grain supported; clay matrix; chiefly quartz; dark lithics minor amount of chert; composed of quartz (40-60%); lithics (20-40%); chert (10). 10625' Sand/Sandstone -- medium to light gray; moderately hard to friable; fine upper to coarse lower; occasionally granular; moderately to poorly sorted subrounded to angular; grain supported; clay matrix; mostly clear to milky quartz; some chert; composed of quartz (30-50%); lithics 20-40%); chert (10%); abundant mineral fluorescence; trace oil; milky white cut fluorescence; clear visible cut color. UNOCAL: SCU 22-4 LITHOLOGY SUMMARY 10675' Sand/Sandstone = overall light to medium gray; friable to firm; occasionally hard; fine upper to coarse with a few granules; generally subrounded to angular; poorly sorted; grain supported clay cement matrix; fair visible porosity; dominantly quartz; chert lith; trace milky white cut fluorescence; clear visible cut color; no petroleum odor. 10725' Siltstone -- light gray to medium gray; firm to moderately hard; friable to slightly brittle; irregular to subblocky cuttings; composed of dominantly silt to very fine grain sand; earthy to slightly resinous luster; silty to slightly clayey surface texture; no oil indicators present. 10740' Ash Fall Tuff = very light gray to white; moderately firm to firm; occasionally soft to crumbly cuttings; dominantly irregular to platy; dull, chalky luster; brittle to slightly crumbly tenacity; occurs locally interbedded with sand and conglomerate; non to slightly calcareous. 10800' Shale -- grayish black to black; moderately firm to firm; crumbly to brittle tenacity; irregular, elongated, tabular cuttings habit; hackly, splintery habit; dull, earthy luster. 10830' Sand/Sandstone = light gray to white; firm to hard; friable in part; fine upper to very coarse; some broken granules; poorly sorted; clay matrix; grairh supported; dominantly quartz; lithics; chert. 10875' Sand/Sandstone = light to medium gray; friable to hard; fine upper to very coarse with granules; fragments of broken pebbles; poorly sorted; subrounded to very angular; clay matrix cement; grain supported; chiefly composed of quartz (30-50%); dark lithics (20-30%); and chert (10%); trace milky white cut fluorescence. 10885' Coal/Carbonaceous Shale = black to dark brown; firm to hard; brittle; planar to blocky fracture; good cleavage; smooth texture; resinous to dull luster; subbituminous in grade; interbedded with sandy siltstone. UNOCAL: SCU 22-4 LITHOLOGY SUMMARY 10920' Sand/Sandstone = light to medium gray; friable to moderately hard; fine lower to coarse grains poorly sorted; subrounded to angular; clay matrix dominantly quartz; lithics; some chert; interbedded with carbonaceous shale; ashy tuff; siltstone and minor amounts of coal. 10970' Sand/Sandstone = generally light to medium gray; fine upper to very coarse grains with some granules; poorly sorted; subrounded to very angular; clay matrix cementation grain supported; friable in part; unconsolidated in part; dominantly quartz (30- 50%); lithics (30%); chert (10%); minor amounts of feldspar; interbedded with tuffaceous siltstone and ashy tuffs; argillaceous sandy siltstone; no discernible petroleum indicators. 11025' Tuffaceous Siltstone/Tuff = very light gray to light grayish white; soft to slightly firm; soluble in part; ashy to clayey slightly gritty texture; soft glassy to earthy luster; very small glass shards; sticky when hydrated; bentonitic; good adhesion; poor cohesion; micro-mica; interbedded with ash fall tuff; and clastic sediments. 11100' Sand/Sandstone = overall light gray to very light gray; fi~;e lower to coarse; friable to moderately hard; subrounded to angular; poorly sorted; gr~',ir: supported in part; generally clay matrix cement; dominantly quartz; chert; dark lithics; ct-,e~'t and some feldspar; interbedded with tuffs and siltstones; no discernible petroleum indicators. UNOCAL $CU 22-4 I _EPOCH Date · 9/30/99 Time ' 5:00 AM MORNING REPORT DEPTH: 10,472' REMARKS: Yesterday:. 10,472' 24 Hour Pro.{lress: BIT INFORMATION: No. Size Type S/N Jets Interval Footage Hour~ Condition Rate of Penetration Surface Torque Weight on Bit Bit RPM ..pu. mp Pressure High at at at at at Low Average ff./hr amps Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.6 48 GAS SUMMARY: Total Ditch Gas 0~: Methane (C-1) Ethane (C-2) Propane (C-3) Butane (C-4) Pentane (C-5) Background Gas: 2-5 Connection Gas: N/A units High at 0 un~ Trip Gas: Wiper Gas: Low N/A N/A units unibs Average units ppm ppm ppm ppm ppm HYDROCARBON SHOWS: NONE LITHOLOGY: NO NEW FORMATION DRILLED DAILY ACTIVITY SUMMARY: PUMPING CEMENT AT REPORT TIME. Epoch Personnel on site: 2 Pailv cost: $! 39500 UNOCAL Da~ · 101t199 Time · 5:00 AM DEPTH: 10,472' REMARKS: EPOCHi MORNING REPORT Yesterday: 10,472' 24 Hour Proqress: BIT tNFORMATION: No. Size Type Jets Integral Footage Hours Condition Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure High at at at at Low Average ftJhr Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.6 48 GAS SUMMARY: High Low Average Total Ditch Gas Out: at at units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Per. ne (C-5) at at ppm u,ni~, s (max) Trip Gas: Wiper Gas: units units Background Gas: 2-5 units Connection Gas: ...... N/A,, ,units ~(av~.) , ,,0 HYDROCARBON SHOWS: NONE LITHOLOGY: NO NEW FORMATION DRILLED DALLY ACTIVITY SUMMARY: RIH WITH CEMENT ASSEMBLY AT REPORT TIME. ( '~P0Ch Personnel on site: 2 Daily cost: $1395.00 UNOCAL Date: 10/3_./99 Time: 5:00 ANi DEPTH: 10,325' REMARKS: E P OC-Hi MORNING REPORT Yesterday: 10,325' 24 Hour Progress: BIT INFORMATION: No. Size 12R2 4,5" Type ST~35CD SIN W62YJ Jets 3x14 Interval 10325'- Footage N/A Hours NIA Condition RIH Rate of' Penetration Surface Torque Weight on Bit Bit RPM PumP Pressure High at at at a~ at Low Average Klbs RPM .psi DRILLING MUD REPORT: MW VIS 8.75 45 GAS SUMMARY: High Low Average Total Ditch Gas Out: at at un~ Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Background Gas: 2-5 units Connection Gas: N/A units (ave) 0 units .(.m..ax} Trip Gas: Wiper Gas; N/A units N/A units HYDROCARBON ~IOWS: NONE LITHOLOGY: NO NEW FORMATION DRILLED DAILY ACTIVITY SUMMARY: RIH Wi NEW BOTTOM HOLE ASSEMBLY AT REPORT TIME. Epoch PersOnnel onsitei .... ~ UNOCAL SCU 22.4 Date: 18/3/99 Time: 5:00 AM DEPTH: 10,397' REMARKS: F POCHi, MORNING REPORT Yesterd~: 10,330' 24 Hour Proqress: 67' BIT INFORMATION: No. Size Type 13 4.5" ST~35CD 12R2 4.5" STR35CD W63YJ W62YJ Jets Interval 3xl 4 10397'- 3x14 10330'-10397' Footage NtA 67' Houm 0 4.5 Condition RIH OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM P.ump Pressure 45 N/A 2 N/A 1,900 High at at at at at 10,333' N/A 10,351' N/A 10,383' DRILLING MUD REPORT: MW ViS 8.75 45 Low 30 at 10,337' N/A at N/A 1 at 10,342' bi/A at N/A 11.496 at 10,352' Average 19 NIA 2 N/A 1,608 Klbs RPM psi GAS SUMMARY: High Low Total Ditch Gas Out: 7 at 10,356' 1 at 10,392' ~lethane (C-1) 1,293 at 10,356' 152 at 10,392' Ethane (C-2) 0 at N/A 0 ~t NIA Propane (C-3) 0 at N/A 0 at N/A Butane (C-4) 0 at N/A 0 at Pentane (C-5) 0 at N/A 0 at N/A Average 1 units 252 ppm 0 ppm 0 ppm 0 ppm 0 ppm Background Gas: 2-5 uni~ Trip Gas: N/A units Connection Gas: N/A units (ave) , o units (max) Wiper Gas: N/A units HYDROCARBON GHOW~: NONE LITHOLOGY: 10% SAND, 90% CEMENT CONTAMINATION I~ 10395' DAILY ACTMTY SUMMARY: RIH WIBHA ~/~20, TAG CEMENT AT 10330', DRILL FROM 10330' TO 10397', POOH, CUT AND SLIP DRILL LINE, PAl NEW BIT, RIH. Epoch Personnel on site: :2 Daily cost: $1395.00 ~ ..-,~ ~:,,-.t. ,.,"~, ~.. ~ t,'~ ~J .,D. ', A t :', ~.1 ,~ r'-,,',. ~ ,~', ,-,..,, ,I-.,-.;. ,~-, .~ ~ ..,~. UNOCAL ~GU 22.4 Date: 1014199 Time: 5:00 AM DEPTH: 10,501' Yesterday: 10,397' EPOCHI MORNING REPORT 24 Hour Progress: 104' REMARKS: BIT INFORMATION: No. Size Type 14 4.5" S'i-~35CD 13 4.5' STR35CD 12 R2 4.5" STR35CD S/N A42ZL W63YJ W62YJ Jets 3x14 3x14 3xl 4 Intewal 10501'- 10397'-10501' 10330'-10397' Footage 104' 67' Hours 5.2 4.5 Condition RIH OUT OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure 96 N/A 39 N/A 1,700 High at at at at at 10,428' N/A 10,473' N/A 10,418' 5 N/A 1 N/A 1,519 Low 10,451' N/A 10,404' N/A 10,481' Average 34 N/A 22 N/A 1,621 ft./hr amps Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.4 44 GAS SUMMARY: High Low Total Ditch Gas Out: 19 at 10,480' 1 at 10,433' Methane (C-1) 3,310 at 10,480' 135 at 10,402' Ethane (C-2) 34 at 10,480' 0 at N/A Propane (C-3) 15 at 10,486' 0 at N/A Butane (C-4) 0 at N/A 0 at N/A Pentane (C-5) 0 at N/A 0 at N/A Background Gas: 5 units Tdp Gas: N/A units Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units Average 5 units 816 ppm 0 ppm 0 ppm 0 ppm 0 ppm HYDROCARBON SHOWS: NONE LITHOLOGY: 20% ASH FALL TUFF, 20% TUFFACEOUS SILTSTONE, 20% SILTSTONE, 10% SAND, 30% SANDSTONE @ 10500' DAILY ACTIVITY SUMMARY: RIH, ROTATE AND SLIDE FROM 10397'- 10501', POOH, P/U NEW BIT, RIH. Epoch Personnel on site: 2 Daily cost: $1395.00 ',", ...... ..,. ~... ,,-,~ , ~,a,~,l~,,~ .~ ..... ,..,.:....-....,. ,.*.,-, ,~-~ -...~ UNOCAL Date: 1015199 Time: 5:00 AM DEPTH: 10,564' EPOCHI MORNING REPORT Yesterday: 10,501' 24 Hour Progress: 63' REMARKS: BIT INFORMATION: No. Size Type 15 4.5" HYCA 14 4.5" STR35CD 13 4.5" STR35CD S/N 62642 A4?_ZL W63YJ J ets 2x14,3x12 3x14 3xl 4 Intewal 10564'- 10501'-10564' 10397'-10501' Footage 63' 104' Hours 3.98 5.2 Condition RIH OUT OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure 73 NIA 23 N/A 1,800 High at at at at at 10,501' N/A 10,519' N/A 10,555' 5 N/^ 3 N/A 1,530 Low 10,527' N/A 10,501' N/A 10,537' Average 23 N/A 14 N/A 1,651 ftJhr amps Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.4 44 GAS SUMMARY: High Low Total Ditch Gas Out: 33 at 10,501' 2 Aethane (C-1) 8,559 at 10,501' 346 Ethane (C-2) 739 at 10,501' 7 Propane (C-3) 448 at 10,501' 3 Butane (C-4) 80 at 10,501' 4 Pentane (C-5) 18 at 10,501' 0 10,538' 10,552' 10,552' 10,538' 10,538' N/A Average 4 units 977 ppm 58 ppm 21 ppm 13 ppm 4 ppm Background Gas: 2-5 units Trip Gas: Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: 80 units @ 10501' N/A units @ HYDROCARBON SHOWS: NONE LITHOLOGY: 50% SAND, 20% CONGLOMERATE SANDSTONE, 30% CONGLOMERATE SAND @ 10560' DAILY ACTIVITY SUMMARY: RIH, ROTATE AND SLIDE TO 10564', POOH, P/U NEW BIT, CURRENTLY RIH. Epoch Personnel on site: 2 Daily cost: $1395.00 UNOCAL ~=U 22.4 Date: 1016/99 Time: 5:00 AM DEPTH: 10,815' Yesterday: 10,565' EPOCHI MORNING REPORT 24 Hour Progress: 250' BIT INFORMATION: No. Size Type 15 4.5" HYCA 14 4.5' STR35CD 13 4.5" ST~35CD S/N 62642 A42ZL W63YJ J ets 2xl 4, 3xl 2 3xl 4 3x14 Interval Footage Hours 10564'-10815' 251' 7.8 10501 '- 10564' 63' 3.98 10397'- 10501' 104' 5.2 Condition IN HOLE OUT OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure 165 NIA 19 NIA 2,215 High at at at at at 10,803' N/A 10,568' NIA 10,597' Low 9 at 10,698' N/A at N/A 1 at 10,585' NIA at N/A 1,642 at 10,702' Average 48 fi/hr N/A amps 6 Klbs N/A RPM 1,954 psi DRILLING MUD REPORT: MW VIS 8.55 50 GAS SUMMARY: High Low Average Total Ditch Gas Out: 13 at 10,778' 1 at 10,725' 5 units .t4ethane (C-1) 5,112 at 10,648' 169 at 10,698' 1,091 ppm Ethane (C-2) 814 at 10,648' 3 at 10,721' 88 ppm Propane (C-3) 219 at 10,648' 2 at 10,703' 28 ppm Butane (C-4) 56 at 10,648' 2 at 10,815' 12 ppm Pentane (C-5) 23 at 10,648' 0 at N/A 5 ppm Background Gas: 5-10 units Trip Gas: N/A units Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units HYDROCARBON SHOWS: 10540'-10630' LITHOLOGY: 10% SHALE, 10% SILTSTONE, 20% SAND, 40% SANDSTONE, 20% CONGLOMERATIC SAND @ 10815' DAILY ACTIVITY SUMMARY: RIH TO SHOE, CHANGE OUT DRILLING LINE SPOOL, RIH TO 10564', DRILL FROM 10564' TO 10827', POOH TO SHOE FOR TOP DRIVE REPAIR, CURRENTLY RUNNING BACK TO BOTTOM. Epoch Personnel on site: 2 Daily cost: $1395.00 UNOCAL Date: 10/7199 Time: 5:00 AM DEPTH: 10,840' Yesterday: 10,815' EPOCH MORNING REPORT 24 Hour Progress: 25' REMARKS: BIT INFORMATION: No. Size Type 16 4.5' HYCA 15 4.5' HYCA 14 4.5" STR35CD S/N 20790 62642 A42ZL J ets 2x14, 2x10 2x14,3x12 3x14 Interval 10840'- 10564'- 10840' 10501'- 10564' Footage . 276' 63' Hours 9.38 3.98 Condition RIH OUT OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure 84 N/A 13 N/A 2,317 High at at at at at 10,825' N/A 10,829' N/A 10,826' 3 N/A 6 N/A 1,926 Low 10,837' N/A 10,838' N/A 10,822' Average 37 N/A 9 N/A 2,158 ~,Jhr amps Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.6 56 GAS SUMMARY: High Low Total Ditch Gas Out: 16 at 10,822' 3 at 10,839' ,vlethane (C-1) 2,772 at 10,822' 528 at 10,839' Ethane (C-2) 113 at 10,822' 15 at 10,839' Propane (C-3) 64 at 10,822' 10 at 10,839' Butane (C-4) 17 at 10,822' 5 at 10,839' Pentane (C-5) 0 at N/A 0 at N/A Average 7 units 1,302 ppm 49 ppm 29 ppm 9 ppm 0 ppm Background Gas: 5-10 units Trip Gas: N/A units Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units HYDROCARBON SHOWS: NONE LITHOLOGY: 10% SILTSTONE, 30% SANDSTONE, 30% CONGLOMERATE SAND, 30% CONGLOMERATE SANDSTONE @ 10840' DAILY ACTIVITY SUMMARY: DRILL TO 10840', PROBLEMS WITH MWD AND TOP DRIVE, POOH, SERVICE RIG, TEST BOP'S, P/U NEW BIT AND MWD TOOL, RIH. Epoch Personnel on site: 2 Daily cost: $1395.00 UNOCAL ~ 22-4 Date: 1018/99 Time: 5:00 AM DEPTH: 10,948' EP OCH MORNING REPORT Yesterday: 10,840' 24 Hour Progress: 10ff REMARKS: BIT INFORMATION: No. Size Type 17 4.5" HYCA 16 4.5" HYCA 15 4.5" HYCA S/N H46044 20790 19518 Jets 2x14,2x16 2'x14,2x10 2x14,3x10 I~ew~ Footage Hours 10948'- - 0 10840'-10948' 108' 3.04 10564'-10840' 276' 9.38 Condition RIH OUT OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure 351 NIA 10 N/A 2,533 High at at at at at 10,886' N/A 10,841' N/A 10,888' Low 2 at 10,840' N/A at N/A 1 at 10,856' N/A at N/A 1,735 at 10,880' Average 77 N/A 4 N/A 2,096 ftJhr amps Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.6 47 GAS SUMMARY: High Low Total Ditch Gas Out: 30 at 10,904' 3 at 10,840' Methane (C-1) 4,858 at 10,904' 507 at 10,840' Ethane (C-2) 401 at 10,904' 35 at 10,840' Propane (C-3) 31 at 10,904' 3 at 10,840' Butane (C-4) 45 at 10,904' 4 at 10,840' Pentane (C-5) 25 at 10,904' 2 at 10,840' Average 15 units 2,604 ppm 98 ppm 22 ppm 12 ppm 4 ppm Background Gas: 10-20 units Trip Gas: N/A units Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units HYDROCARBON SHOWS: NONE LITHOLOGY: 50% SAND, 10% SANDSTONE, 20% CONGLOMERATIC SAND, 20% CONGLOMERATIC SANDSTONE @ 10945' DAILY ACTIVITY SUMMARY: RIH, DRILL TO 10948', COAL SEEN IN SAMPLE FROM 10830'-10905'; DECREASING AS DRILLING CONTINUED, CIRC HOLE CLEAN, PUMP DRY JOB AND POOH, CHANGE OUT BIT, RIH. Epoch Personnel on site: 2 Daily cost: $1395.00 UNOCAL ~,cu 22.4 Date: 1019199 Time: 5:00 AM DEPTH: 11,140' EPOCH MORNING REPORT Yesterday: 10,948' 24 Hour Progress: 192' REMARKS: BIT INFORMATION: No. Size Type 17 4.5" HYCA 16 4.5" HYCA 15 4.5" HYCA S/N H46044 20790 19518 Jets 2x14,2x16 2x14,2x10 2x14,3xl 0 Inte~al Foo~ge Hours 10948'-11140' 192' 5.23 10840'-10948' 108' 3.04 10564'-10840' 276' 9.38 Condition OUT (TD) OUT OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure 341 N/A 10 N/A 2,242 High at at at at at 11,090' N/A 11,086' N/A 11,087' Low 14 at 10,948' N/A at NIA 4 at 10,951' N/A at NIA 1,775 at 10,949' Average 66 N/A 7 N/A 2,040 ftJhr amps Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.6 53 GAS SUMMARY: High Low Total Ditch Gas Out: 42 at 11,103' 3 at 11,139' Methane (C-1) 7,938 at 11,103' 500 at 11,139' Ethane (C-2) 153 at 11,103' 55 at 11,139' Propane (C-3) 147 at 11,103' 40 at 11,139' Butane (C-4) 71 at 11,103' 3 at 11,139' Pentane (C-5) 14 at 11,103' 0 at NIA Background Gas: 15-25 units Trip Gas: 42 Connection Gas: N/A units (ave) 0 units (max) Wiper Gas: N/A units units 10,948' Average 20 units 3,780 ppm 73 ppm 70 ppm 34 ppm 6 ppm HYDROCARBON SHOWS: NONE LITHOLOGY: 30% SAND, 30% SANDSTONE, 20% CONGLOMERATE SAND, 20% CONGLOMERATE SANDSTONE (~ 11140' DALLY ACTIVITY SUMMARY: RIH, DRILL FROM 10948' TO 11140' (TD), BACK REAM TO WINDOW, CIRCULATE OUT, CBU FROM WINDOW, POOH. Epoch Personnel on site: 2 Daily cost: $1395.00 ~ ...... ~,.. -.,~,, ~, ,,, -. ..... ,, ~-- ....... ~_~: ...... ~. ~ .~ .~ c~ ~. c~ ,'",~ UNOCAL ~CU 22-4 Date: 10/10199 Time: 5:00 AM DEPTH: 11,140' EPOCHi MORNING REPORT Yesterday: 11,140' 24 Hour Progress: REMARKS: BIT INFORMATION: No. Size Type 17 4.5" HYCA 16 4.5" HYCA 15 4.5" HYCA S/N H46044 20790 19518 Jets 2x14,2x16 2x14,2xl 0 2x14,3xl 0 Inte~al 10948'-11140' 10840'-10948' 10564'-10840' Footage 192' 108' 276' Hours 5.23 3.04 9.38 Condition OUT (TD) OUT OUT Rate of Penetration Surface Torque Weight on Bit Bit RPM Pump Pressure High at at at at at Low at at at at at Average ~dhr amps Klbs RPM psi DRILLING MUD REPORT: MW VIS 8.65 57 GAS SUMMARY: High Low Average Total Ditch Gas Out: at at units Methane (C-1) at at ppm Ethane (0-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm units units 10,948' Background Gas: units Trip Gas: N/A Connection Gas: N/A units (ave) 0 units (max} Wiper Gas: N/A HYDROCARBON SHOWS: NONE LITHOLOGY: NO NEW FORMATION DRILLED. DAILY ACTIVITY SUMMARY: POOH, LID BHA, P/U 3.5" LINER AND 2.063" INNER STRING, SPACE OUT HANGER, PUMP VOL OF LINER, RIH W/LINER. Epoch Personnel on site: 2 Daily cost: $1395.00 m ANADRILL SCHLUMBERGER Survey report 8-Oct-1999 14:21:32 Client ................... :Unocal ORIGINAL Field .................... : Swanson River Field Page 1 of 4 Well ..................... : SCU %22-4 API number ............... : 50-133-10106-00 Engineer ................. : N.Rose Rig: ..................... : CC %1 State: ................... : Alaska Spud date ................ : 9-17-99 TIP Date Last survey date ......... : 08-Oct-99 Total accepted surveys...: 71 MD of first survey ....... : 10304.00 ft MD of last survey ........ : 11140.00 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference .......... Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller Pipe Tally + 12 ft GL above permanent ....... : 0.00 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 170.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 28-Sep-1999 Magnetic field strength..: 1106.05 HCNT Magnetic dec (+E/W-) ..... : 21.61 degrees Magnetic dip ............. : 73.55 degrees SLIMPULSE survey Reference Criteria Reference G .............. : 1002.02 mGal Reference H .............. : 1135.00 HCNT Reference Dip ............ : 71.50 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 18.72 degrees Corrections Magnetic dec (+E/W-) ..... : 21.61 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.61 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6 0C 04] -- -- RECStVE.D Alaska Oil & Gas Cons. Comm~ion Anchorage ANADRILL SCHLUMBERGER Survey Report 8-Oct-1999 14:21:32 Page 2 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 10304.00 7.10 21.40 2 10312.69 8.91 10.44 3 10323.71 11.87 2.46 4 10335.10 14.10 357.11 5 10345.08 15.87 353.85 6 10355.06 17.51 351.51 7 10365.03 19.47 350.99 8 10375.02 21.92 350.50 9 10385.04 25.10 351.13 10 10395.02 28.51 352.06 11 10404.96 32.18 354.18 12 10413.52 35.91 356.22 13 10425.01 40.79 359.65 14 10435.01 44.12 2.47 15 10445.01 46.77 5.64 16 10455.06 49.34 8.60 17 10465.05 52.29 10.22 18 10475.04 55.19 11.64 19 10485.02 59.41 12.57 20 10495.02 62.89 13.23 21 10505.02 66.01 13.93 22 10515.02 69.16 14.60 23 10525.02 71.94 15.50 24 10535.02 74.84 15.86 25 10545.10 77.91 16.24 26 10555.01 81.11 16.51 27 10565.01 82.60 16.71 28 10575.01 83.44 16.42 29 10585.01 83.71 16.60 30 10595.02 84.23 16.50 0.00 8.69 11.02 11.39 9.98 9.98 9.97 9.99 10.02 9.98 9.94 8.56 11.49 10.00 10.00 10.05 9.99 9.99 9.98 10.00 10.00 10.00 10.00 10.00 10.08 9.91 10.00 10.00 10.00 10.01 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 10303.00 66.46 61.40 25 10311.61 67.67 62.56 26 10322.44 69.60 64.53 26 10333.54 72.01 67.09 26 10343.18 74.38 69.66 26 10352.74 76.96 72.50 25 10362.20 79.76 75.63 25 10371.54 82.88 79.11 24 10380.73 86.41 83.06 24 10389.63 90.42 87.51 23 10398.21 94.95 92.49 22 10405.30 99.34 97.27 22 10414.31 106.01 104.39 22 10421.69 112.44 111.14 22 10428.71 119.33 118.24 22 10435.42 126.65 125.65 23 10441.74 134.29 133.29 25 10447.64 142.27 141.20 26 10453.03 150.61 149.41 28 10457.86 159.32 157.95 30 10462.17 168.31 166.71 32 10465.98 177.52 175.67 34 10469.31 186.93 184.78 37 10472.17 196.50 194.00 39 10474.54 206.29 203.42 42 10476.35 216.02 212.76 45 10477.77 225.91 222.25 48 10478 . 98 235 . 83 231 . 76 50 10480.10 245.76 241.29 53 10481.15 255.71 250.83 56 .90 .22 .42 .40 .19 .83 .34 .78 .14 .48 .89 .49 .25 .38 .88 .81 .08 .61 .37 .33 .45 .73 .17 .76 .47 .22 .05 .88 .70 .54 66.64 67.83 69.73 72.10 74.42 22.87 0.00 22.74 27.16 22.26 29.81 21.48 22.22 20.61 19.64 76.97 79.76 82.90 86.49 90.61 19.61 17.76 18.53 19.73 17.39 24.59 16.21 31.83 15.02 34.43 95.28 99.83 106.73 113.37 120.43 13.90 38.45 13.02 45.57 12.03 46.32 11.38 38.35 10.95 34.81 127.89 135.63 143.69 152.08 160.83 10.73 33.67 10.66 32.09 10.67 31.21 10.75 43.01 10.87 35.28 169.84 179.07 188.48 198.04 207.80 11.01 31.83 11.18 32.10 11.38 29.07 11.58 29.20 11.79 30.68 217.52 12.00 32.40 227.38 12.20 15.03 237.28 12.38 8.88 247.19 12.55 3.24 257.13 12.70 5.29 TIP - SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis [(c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 8-Oct-1999 14:21:32 Seq Measured Incl Azimuth Course TVD Vertical Displ # depth angle angle length depth section +N/S- - (ft) (deg) (deg) (ft) (ft) (ft) (ft) 31 10605.04 84.75 16.35 10.02 10482.11 265.67 260.40 32 10615.08 84.92 16.51 10.04 10483.02 275.67 269.99 33 10625.07 85.23 16.49 9.99 10483.88 285.61 279.53 34 10635.02 85.64 16.41 9.95 10484.67 295.52 289.05 35 10645.03 85.95 16.60 10.01 10485.40 305.50 298.62 9.97 12.88 7.17 9.98 10.05 36 10655.00 86.36 16.77 37 10667.88 86.53 16.51 38 10675.05 86.81 16.49 39 10685.03 86.98 16.67 40 10695.08 86.91 16.81 10.00 9.96 10.00 9.96 9.99 41 10705.08 87.22 16.73 42 10715.04 87.50 16.47 43 10725.04 87.80 16.17 44 10735.00 88.22 16.60 45 10744.99 88.56 16.57 10.02 10.03 9.98 9.99 10.02 46 10755.01 88.83 16.52 47 10765.04 89.18 16.30 48 10775.02 89.73 16.36 49 10785.01 90.24 15.95 50 10795.03 90.65 15.89 9.98 9.98 10.01 10.01 10.00 51 10805.01 90.90 15.16 52 10814.99 91.15 15.33 53 10825.00 91.20 16.06 54 10835.01 91.58 15.46 55 10845.01 91.65 15.31 10.01 9.99 10.07 9.93 10.00 10486.07 10486.87 10487.29 10487.83 10488.36 10488.87 10489.33 10489.74 10490.09 10490.37 10490.60 10490.77 10490.87 10490.87 10490.79 315.44 308.15 328.29 320.46 335.44 327.33 345.40 336.88 355.43 346.49 365.41 356.05 375.35 365.58 385.33 375.17 395.28 384.72 405.26 394.29 56 10855.02 91.95 15.51 57 10865.01 92.28 15.36 58 10875.08 92.60 15.51 59 10885.01 92.93 15.44 60 10895.01 93.15 15.28 415.27 403.90 425.29 413.52 435.26 423.09 445.24 432.69 455.25 442.32 10490.66 465.21 451.94 10490.48 475.17 461.57 10490.27 485.16 471.20 10490.03 495.16 480.83 10489.75 505.14 490.47 Displ +E/W- (ft) 59 62 65 67 70 .36 .19 .01 .82 .66 73 77 79 82 84 .52 .20 .23 .07 .96 87 90 93 96 99 .85 .69 .50 .30 .15 102 104 107 110 113 .01 .84 .65 .42 .17 115 118 121 123 126 .84 .47 .18 .89 .55 Page Total displ (ft) At Azim (deg) 267.08 277.06 286.99 296.90 306.86 12.84 12.97 13.09 13.21 13.31 316.79 329.63 336.78 346.73 356.75 13.42 13.54 13.61 13.69 13.78 366 376 386 396 406 .73 .66 .65 .59 .57 13.86 13.93 13.99 14.05 14.12 416 426 436 446 456 .58 .60 .57 .56 .57 14.17 14.23 14.27 14.32 14.35 466.55 476.53 486.53 496.54 506.53 14.38 14.40 14.42 14.45 14.47 3 of 4 DLS Srvy Tool (deg/ tool qual 100f) type type 5.40 2.32 3.11 4.20 3.63 4.45 2.41 3.92 2.48 1.56 3.20 3.76 4.31 6.03 3.42 2.74 4.12 5.54 6.55 4.14 7.73 3.03 7.31 7.04 1.70 10489.44 515.12 500.11 129.20 516.53 14.49 3.60 10489.07 525.09 509.74 131.86 526.52 14.50 3.63 10488.64 535.14 519.44 134.54 536.58 14.52 3.51 10488.16 545.04 528.99 137.18 546.49 14.54 3.42 10487.63 555.01 538.62 139.83 556.48 14.55 2.66 SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis [ (c) 1999 Anadrill IDEAL ID6_0C_04] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 10905.02 93.53 15.11 62 10920.00 93.95 15.06 63 10935.00 94.38 15.21 64 10950.00 94.28 15.16 65 10980.00 94.18 14.96 8-Oct-1999 14:21:32 66 11009.98 94.15 14.98 67 11040.02 94.30 15.16 68 11070.04 94.55 15.06 69 11099.96 95.13 14.78 70 11105.27 95.13 14.96 Projected to TD 71 11140.00 95.13 14.96 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) Total displ (ft) 10.01 10487.05 564.98 548.27 142.45 566.47 14.98 10486.07 579.90 562.70 146.34 581.42 15.00 10484.98 594.83 577.14 150.24 596.38 15.00 10483.85 609.76 591.58 154.16 611.33 30.00 10481.63 639.62 620.47 161.94 641.25 29.98 30.04 30.02 29.92 5.31 34.73 Page At Azim (deg) 14.56 14.58 14.59 14.61 14.63 10479.46 10477.24 10474.93 10472.40 10471.93 10468.82 4 of 4 DLS Srvy Tool (deg/ tool qual i00f) type type 4.16 SlimPulse 6-Axis 2.82 SlimPulse 6-Axis 3.04 SlimPulse 6-Axis 0.74 SlimPulse 6-Axis 0.74 SlimPulse 6-Axis 669.45 649.35 169.66 671.15 14.64 ~0.12 699.35 678.28 177.45 701.11 14.66 0.78 729.22 707.18 185.25 731.04 14.68 0.90 758.97 735.99 192.93 760.85 14.69 2.15 764.25 741.10 194.28 766.14 14.69 3.38 798.76 774.52 203.21 800.73 14.70 0.00 SlimPulse 6-Axis SlimPulse 6-Axis SlimPulse 6-Axis SLIMPULSE 6-axis SLIMPULSE 6-axis Projected [(c)1999 Anadrill IDEAL ID6 0C 04] -- -- ANADRILL SCHLUMBERGER Survey report Client ................... : Unocal Field .................... : Swanson River Field Well ..................... : SCU #22-4PB1 API number ............... : 50-133-10106-70 Engineer ................. : N.Rose COUNTY: .................. : Soldotna Creek Unit STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drillers Pipe Tally + 12 ft GL above permanent ....... : n/a KB above permanent ....... : Top Drive DF above permanent ....... : 170.0 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft- Azimuth from rotary table to target: 18.72 degrees 25-Sep-1999 11:45:47 ORIGINAL Page 1 of 4 Spud date ................ : 17 Sept 99 TIP Last survey date ......... : 25-Sep-99 Total accepted surveys...: 67 MD of first survey ....... : 10334.00 ft MD of last survey ........ : 11331.00 ft Geomagnetic data .......... Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 17-Sep-1999 Magnetic field strength..: 1106.06 HCNT Magnetic dec (+E/W-) ..... : 21.62 degrees Magnetic dip ............. : 73.55 degrees MWD survey Reference Criteria Reference G .............. : 1002.02 mGal Reference H .............. : 1106.06 HCNT Reference Dip ............ : 73.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 21.62 degrees Grid convergence (+E/W-) .: 0.00 degrees Total az corr (+E/W-) .... : 21.62 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6 0C 04] REC, = VED , --', 3999 ,....iv 15 Ala. ka Oil & Gas Cons. mmi sion ANADRILL SCHLUMBERGER Survey Report 25-Sep-1999 11:45:47 Page 2 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 10334.00 16.54 352.80 2 10344.00 21.47 357.40 3 10354.00 24.68 0.19 4 10364.00 27.39 3.20 5 10374.00 30.14 5.88 6 10384 . 00 33.46 8.43 7 10394 . 00 36 . 65 11.91 8 10404 . 00 39 . 00 16 . 00 9 10414.00 41.88 18.27 10 10424 . 00 45 . 04 20 . 68 11 10434.00 48.17 22.51 12 10444.00 50.56 23.38 13 10454.00 56.09 23.85 14 10466.00 60.43 23.97 15 10476.00 65.12 24.49 16 10486.00 68.16 24.78 17 10496.00 73.37 24.37 18 10506.00 76.75 24.88 19 10516.00 79.00 24.86 20 10526.00 79.77 25.07 21 10536.00 80.32 25.17 22 10546.00 80.67 25.41 23 10561.00 80.98 25.09 24 10588.00 82.16 25.32 25 10593.00 82.71 27.07 26 10605.00 86.05 26.46 27 10614.00 87.56 26.38 28 10629.00 88.59 25.76 29 10644.00 88.73 25.43 30 10661.00 89.62 25.54 0.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 12.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 15.00 27.00 5.00 12.00 9.00 15.00 15.00 17.00 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 10332.40 72.08 67.30 26.00 72.15 21.12 10341.85 75.07 70.54 25.74 75.09 20.05 10351.05 78.76 74.46 25.66 78.76 19.02 10360.04 82.95 78.85 25.80 82.96 18.12 10368.80 87.62 83.64 26.18 87.64 17.38 10377.30 92.78 88.87 26.84 92.83 16.81 10385.49 98.46 94.52 27.87 98.54 16.43 10393.38 104.57 100.46 29.35 104.66 16.29 10401.00 111.05 106.66 31.26 111.15 16.34 10408.25 117.93 113.14 33.56 118.01 16.52 10415.12 125.18 119.89 36.24 125.25 16.82 10421.63 132.75 126.88 39.20 132.80 17.17 10427.61 140.74 134.23 42.41 140.77 17.53 10433.92 150.90 143.55 46.54 150.91 17.96 10438.49 159.75 151.66 50.19 159.75 18.31 10442.46 168.88 160.00 54.02 168.88 18.66 10445.75 178.27 168.59 57.94 178.27 18.97 10448.33 187.87 177.37 61.97 187.88 19.26 10450.43 197.59 186.24 66.08 197.61 19.54 10452.27 207.37 195.15 70.23 207.40 19.79 10454.00 217.15 204.07 74.41 217.21 20.03 10455.65 226.95 212.98 78.62 227.03 20.26 10458.04 241.66 226.38 84.94 241.79 20.57 10462.00 268.20 250.54 96.31 268.42 21.03 10462.66 273.11 254.99 98.50 273.35 21.12 10463.83 284.94 265.65 103.88 285.24 21.36 10464.33 293.84 273.70 107.88 294.19 21.51 10464.84 308.71 287.16 114.47 309.14 21.73 10465.19 323.60 300.69 120.94 324.10 21.91 10465.43 340.48 316.03 128.26 341.07 22.09 DLS Srvy Tool (deg/ tool qual lOOf) type type 0.00 51.49 33.90 30.14 30.37 35.81 37.63 34.36 32.34 35.68 34.00 24.79 55.43 36.18 47.13 30.52 52.24 34.16 22.50 7.97 5.59 4.23 2.95 4.45 36.40 28.29 16.80 8.01 2.39 5.28 TIP - SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis [(c)1999 Anadrill IDEAL ID6 0C 04] -- -- /kNAJDRILL SCHLUMBERGER Survey Report 25-Sep-1999 11:45:47 3 of 4 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 31 10679.00 90.62 25.41 32 10694.00 90.14 24.84 33 10709.00 90.21 24.63 34 10721.00 89.97 24.21 35 10735.00 89.38 23.82 36 10752.00 89.07 23.62 37 10767.00 88.25 23.77 38 10784.00 87.80 23.75 39 10818.00 86.48 23.22 40 10849.00 86.60 23.37 41 10882.00 86.70 23.37 42 10913.00 86.38 23.95 43 10946.00 87.68 23.52 44 10964.00 89.03 23.50 45 10977.00 89.18 23.14 46 10992.00 89.70 22.97 47 11007.00 89.98 23.17 48 11026.00 90.30 22.97 49 11041.00 90 . 55 23 . 22 50 11055.00 90.78 23.25 51 11070.00 90.45 23.14 52 11085.00 90.28 23.35 53 11100.00 90.33 23.35 54 11115.00 90.38 23.37 55 11130.00 90.43 23.12 56 11145.00 90.55 23.12 57 11160.00 90.43 22.99 58 11174.00 90.70 23.07 59 11190.00 90.60 22.72 60 11206.00 90.48 21.80 Course length (ft) 18.00 15.00 15.00 12.00 14.00 17.00 15.00 17.00 34.00 31.00 33.00 31.00 33.00 18.00 13.00 15.00 15.00 19.00 15.00 14.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 14.00 16.00 16.00 TVD depth (ft) 10465.39 10465.29 10465.25 10465.23 10465.31 10465.54 10465.89 10466.48 10468.17 10470.05 10471.98 10473.85 10475.56 10476.08 10476.28 10476.42 10476.47 10476.42 10476.31 10476.15 10475.99 10475.89 10475.81 10475.72 10475.62 10475.49 10475.36 10475.22 10475.04 10474.89 Vertical section (ft) 358.35 373.26 388.18 400.12 414.06 430.99 445.93 462.85 496.69 527.54 560.37 591.20 624.03 641.96 654.92 669.87 684.83 703.77 718.73 732.69 747.64 762.59 777.54 792.49 807.45 822.40 837.36 851.32 867.28 883.24 Page Displ Displ Total At DLS Srvy Tool +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (deg) 100f) type type 136.00 142.37 148.65 153.61 159.30 332.28 345.86 359.49 370.41 383.20 166.14 172.17 179.01 192.55 204.78 398.76 412.49 428.04 459.19 487.61 217.85 230.27 243.53 250.70 255.85 517.85 546.19 576.36 592.86 604.80 261.72 267.60 275.04 280.93 286.45 618.60 632.40 649.88 663.68 676.54 292.36 298.27 304.22 310.16 316.08 690.33 704.11 717.88 731.66 745.44 321.97 327.85 333.32 339.55 345.61 759.23 773.03 785.92 800.66 815.46 359.04 374.02 389.01 401.00 414.99 22.26 22.37 22.46 22.52 22.57 431.99 446.98 463.97 497.92 528.87 22.62 22.65 22.70 22.75 22.78 561.81 592.75 625.70 643.69 656.69 22.82 22.86 22.91 22.92 22.93 671.69 686.69 705.69 720.69 734.69 22.93 22.94 22.94 22.94 22.95 749.68 764.68 779.68 794.68 809.68 22.95 22.96 22.97 22.97 22.98 824.68 839.68 853.68 869.68 885.68 22.98 22.98 22.98 22.98 22.97 5.60 4.97 1.48 4.03 5.05 2.17 5.56 2.65 4.21 0.64 0.30 2.11 4.14 7.50 2.93 3.65 2.24 2.03 2.36 1.65 2.30 1.75 0.27 0.45 1.70 0.80 1.18 2.01 2.27 5.87 SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis [(c) 1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 25-Sep-1999 11:45:47 Page 4 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 11221.00 90.48 22.05 15.00 62 11236.00 90.33 21.95 15.00 63 11251.00 90.20 21.87 15.00 64 11266.00 90.15 21.95 15.00 65 11284.00 90.25 21.57 18.00 66 11299.00 90.47 21.52 Survey Projected to TD 67 11331.00 90.47 21.52 15.00 32.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- disp1 Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 10474.77 898.22 829.38 351.21 900.67 22.95 1.67 10474.67 913.20 843.29 356.82 915.67 22.93 1.20 10474.60 928.17 857.20 362.42 930.67 22.92 0.93 10474.55 943.15 871.12 368.01 945.67 22.90 0.57 10474.49 961.12 887.84 374.69 963.66 22.88 2.13 10474.39 976.10 901.79 380.19 978.66 22.86 1.50 10474.13 1008.07 931.56 391.93 1010.65 22.82 0.00 Srvy Tool tool qual type type SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis SLIMPULSE 6-axis Projected [(c)1999 Anadrill IDEAL ID6 0C 04] -- -- Unocal Alaska Resources Unocal Corporation 909 West 9th Ave, Anchorage, AK 99519-6247 ?ele: (907) 263-7889 Fax: (~7) 2~3-7828 E-mail; childersd@, unocal, corn UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL November 10, 1999 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Resources Transmitting the following items: f!~e~r~d~:LOG?Yp~. :.4~SCALE I:LO~ DATE ii:JNTERVAL~ ICOP I Medium l?:::sa~r.To-:. ~.:.;:! SCU 22-4 SLIM-PULSE GR 1:600/1' 10/2/99110340-11140 1 B-Line AOGCC SCU 22-4 SLIM-PULSEGR 1:600/1' 10/2/99~10340-11140 1 Film AOGCC : SCU 22-4 ...... §[[-M-PLJ~SE-GR 1:600/1: ' 10/2/99 1034~-¥i-1-4-0- '- 1 B--~in-e - '~,-0G(~c ..... SCU 22-4 SLIM-PULSE GR 1:600/1' 10/2/99:10340-1114~ ~ 'TFii~- ...... ~-~)'~Cc ....... scu 22-4 PBI SLIM-PULSE~3R--'-I:6~-0~-i ..... ~-7~-~9-i-~0~:-1-1-~3~ ...... -1-~71-i~e' -~,~0-(~ ....... 'SCU22-4PBI SLIM-PULSE-Gi:i ..... ~-.:e-d07i.7 - 9117199 10355-11331 ...... -1- ;Fiin~ ....... ~,0-G(~C- ..... §C0--:2-~:~,-~Bi--sLi~-P~uLSE-G-R'-' '~i600~ - -9~17i9-9'~-~55:i'i33i' '1 'B:Line -A-0GCC ' §~-2-~--~,-P-Bi-:§-I~i-I~:~Ui_§E-G~I .... 1-.'6~)~7- -- 9/1-:~9-9- ~5-5:i i-331 1- Film ' '~,~G'CC CDROM with: Formation Evaluation Logs Formation Evaluation Digital Data Survey Pleose ockno ,~¢Ci~;~-~e'~ipt b,~ signing Qnd returning one copy of this trQnsmiHd or F~ to Received ~ ~ Date' / ) ,~ ~ti & Gas ~ns. DATA SUBMITTAL COMPLIANCE REPORT 2/5/2O02 Permit to Drill No. 1990830 Well Name/No. SOLDOTNA CK UNIT 22-04 Operator UNION OIL CO OF CALIFORNIA APl No. 50-133-10106-01-00 MD 11140 TVD 10469 Completion Date 10/14/1999 Completion Status l-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Samples No Directional Survey No -- .". ~7'£~7~-'_._. 7 i-~ ._2~ K'_._--'---2-~--2~-.'~-~---2.~-?-'~--'~-~--~-~'i~--~Y£TM -7~.~2Y~7.'. .L-~ ~'£ ~ 2~ '-2~__-'~ _ ~ ~ ~ ~'~ ' ._ ~£~-~._~ ~-~ Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name C ................................. ~ sLIM:GR-~D' ,,.l.-'"' MUD ~ SLIM-GR-TVD ~ MUD Rpt Cnotz ,,&"~' SLIM-GR-MD ~ SLIM-GR-TVD ~ SLIM-GR-MD ~E~''' SLIM-GR-TVD ~\ SRVY RPT D D (~) SRVY RPT L'~ PACK (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Scale Media No Start Stop CH Received Number Comments 25 FIELD 10340 11140 OH 4/10/2000 2 FINAL 10330 11134 OH 11112/1999 25 FIELD 10310 10490 OH 4/10/2000 2 FINAL 10294 11330 OH 11/12/1999 PB1 final 0 11140 Cas 11/23/2001 Well Resume 25 FINAL 10300 11140 OH 11/12/1999 25 FINAL 10332 10474 OH 11/12/1999 PB1 25 FINAL 10235 11300 OH 11/12/1999 PB1 25 FINAL 10300 10496 OH 11/12/1999 10304 11t40 OH 11/15/1999 SCHLUM . 10334 11331 OH 11/15/1999 SCHLUM PB1 5 FINAL 9590 10320 CH 11/12/1999 LGR ............ ~ ............................................................................................ O 11/15/1999~"O'~):~ 10235-11140 Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored'? Y (~ An aly s ~i.x~l~--¥,,./-N Daily History Received? ~/N Formation Tops Receuived? (~ N DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990830 Well Name/No. SOLDOTNA CK UNIT 22-04 Operator UNION OIL CO OF CALIFORNIA API No. 50-133-10106-01-00 MD 11140 TVD 10469 Completion Date 10/14/1999 Completion Status 1-OIL Current Status 1-OIL UIC N Z_~ -~._.~.~77'~-'-__?-~ .~ ~?~_-'~..----~_._-~_-.~'~'. '-~-~-~.-"-~_~.~7 ................... ~. ~ .... £-. ~ i~' Z~ -_~'~ ----~-~-~'~_~ ~ ~_".' ~.-__~--~--~£.-~-~,'.~--~--'_~_.~_._~_i~_~-~ .... .~-~'_- i~_~~'. Comments: Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 ?ele: (907) 263-7889 Fax: (907) 263-7828 E-mail: chi/dersd@, unocal, com UNOCAL Debra Childers Geotech Ass/stant DATA TRANSMITTAL November 8, 1999 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Resources Transmitting the following items: SCU 224 Fo~a~ Mudlog : 95~:10320 1'._. '...B:~i_~ ....... A~ ......... scu 224 Fo~a~ Mudlog .................................... 9590-10320 _ . ! ...... ~ ...... AoGcc_ ...... scu 224 Packer Se~nq Re.rd 5 INCH 9/1~99' 9590-10320 1 Film AOGCC SCU 22-4 PB1 Fo~a~n Mudlog .................................................. ~6/~ 1. 0~94~1~3~ _~ .... . ~.'~_.-. "~-~;~'e- .... ~OG_C'~.'..- ~C~-~ ~_ ~ ~ ~ .... Fo~a~ Mudlog ......................... 9/~6199; 1~:~ 13~_ .... TBF A-9 RD Comp~ Record / Correlation L~ 5 INCH 10/11/99:4260-5930 1 B-Line AOGCC TBU D-27 Correla~ Log / Pedora~ng Re~ 5 INCH 10/4/99 ' 10300-10300 1 B-Line AOGCC ............................................................................................... . _ TBU B-31 RB Co~ela~n L / Pedoradng Re.rd 5 INCH 10/8/99 9900-10450 1 B-Line AOGCC .TBU_D;31?_D_ __~o~?~n~[_~d~mSng~r~ .......... ~ I~C_~ ...... ~[~/~9__9~_0_-~ ..... ~ . Film ~O.GCC ~BU_~;4~ ...... ~l~a S~i~ I~.~ge~ip[O~o~[S~ ........................ ~0~1~/_~9~6_02106~0. 1 B-U,e AOGCC TBU ~ .... Ul~a S~ ImaqeL~!p_~ro~¢~¢p~_ ......................... 10/17/99 9860-10660_ . 1. . Fi~m . ~OGCC TB~8 ....... Ul~O~_l~g?~901~__99~a Ray ~_ ........... 5_ ~.~ .... _)~/1~/~9 ~o~o~!o6e~ .. ~.. B:Line . ..AOG_CC... TBU .......... D48 Ulka Sonic Imag¢~_T.9.o~,_~m~Ra%~C~ ........ 5 I~CH_ .. 10/17/99 10~0-10~.0~_ . !_ ?(Ira .... ~OGCc ~D_~8 ..... ~h~t~k~.~g._~[~ ....................... 5~H__ 10/18/99 1040~-)0~00 ..... ! .... e;Lin_e .AOGCC . TBU B48 ...... ~p?~k~?~igg_~_¢0rd ..................... ~ I_N_~.~_ .......... ~0~79~_~4~0-~600 _ . 1 Fil~ .... AOGCC_ . . .... T~_~M225 ....... ¢om~n RgC~r~ 2~'_~s~p~e_~F_ ....... ~ I_~C~ ......... )~/!5/_9~_ 93~'!0~0_ .... 1_ B-Lige. .~OGCC. TB~.M-25_ __C~p~n_Rec~r~ ~ H~D~?e~ej~SPF .... __5J~C~ .... !0/j_~(~ 9~0g:j0~5p_ ! ~ilm AOGCC ~B~. ~F2~ .... _~_m~y_C Cp./~gEel~o¢ L_~ ......... ~_~CH_ ....... ~/~9.: ~00:12.~5 1 B-Line AOGCC TB~:28 ...... ea_~m~R~y~~ (_C~r~l~p~L_~ ............... 5_INC~ ..... ~N99_ ~0~;~845 . i'.' ' Film" AOGcc'" .TB_~_M:28 _ _ ~?.~ Cg~l¢~oo_bog ................. ~_1~_~_ ..... 9/.1799- !_000~-~0550 1 . Film _ .AOGCC TB~-M-;2~ .... ~g, C9~¢~2_~_ Lgg_ .................................. ~N_C~_ .... ~[)~9_~ ~_o_ ~0'~ o55~_ 1 B-Line ~O6CC ZB~_~z28 ~gg,~gEel~fi~.o ~og ......................... ~. I~C~ ....... 9(5J9~_ !g4~0:!0¢28_. )_. B-Line ~oecc TBU M-28 Plu Co~ela~on Lo 5 INCH 9/5/99 10400-10628 1 Film AOGCC :~B~-~:~ - _~O?~le_~n_R~cord_2.7J8" HSD Powedet 6 SPF 5 INCH 10/17/99 8940-10435 1 B-Line AOGCC TB~-29' __Co_Bple~n Record 2 ~/8~ ~SB_ Pow¢¢~[ ~_S?~ .' -' ~'_~ .... . _~0~ ~9~'~9~40:~ ~43'5' -i Film" AC'GCC TBS. M231 ..... C_9~ple~°P R~c°rd 2_~/_8'~D_ ~S?F_ ...... ~_.I_N_~_ _10/~799_~60~7] 9~.3.. ]. B-Line ~OGCC T~_~_M:31 . _~omp~e~_Rec0¢~7/8"H~S~ ..... ~_IN~ . !0(1.8/~9 ~60~:!0]_43. . 1 Film .AOGCC Please acknowledge receipt ~signing and returning one copy of this transmiffal or F~ to (907) 263-7828, Peceived bv: ".., '~-~ - Dote: MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson,~/~ DATE' October 7, 1999 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Petroleum Insf)ector BOPE Test CC-1 Unocal SCU 22-4 Soldotna Creek Unit PTD #99-83 NON-CONFIDENTIAL Wednesday, October 6, 1999: I witnessed the weekly BOPE test on CC-1 which was drilling Unocal well #SCU 22-4 in the Soldotna River field. The rig was about ready to test when I arrived and after one hour we began. During this stand-by time I made a tour of the rig. All BOPE equipment was tested with the following failures observed. The upper kelly valve leaked, a redressed valve was picked up and tested "OK". A test of the Gas detectors revealed that the methane detectors were out of calibration, this was fixed during the test. The rig is still improving and shows that extra attention has been paid to upkeep, I commend Jerome Dodge (owner Inlet Drilling) and his toolpushers and hands for the resurrection of this once troubled rig. SUMMARY: I witnessed the weekly test of the BOPE on CC-1 working over Unocal well #22-4 in the Soldotna River Unit. 2 failures observed. Test time 5 hours. -- Attachments: BOP CC-1 SCU22-4 10-6-99 LG.xls CC: Dan Williamson (Unocal drilling supervisor) NON-CONFIDENTIAL BOP CC-1 SCU22-4 10-6-99 LG.doc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Inlet Drilling Operator: Unocal Well Name: SCU 22-4 Casing Size: Test: Initial Workover: X Set (~ Weekly X DATE: Rig No. CC~I PTD # 99-47 Rig Ph,# Rep.: Nick Scales Rig Rep.: Mike Leslie Location: Sec. 4 T. 7N R. Other 10/6/99 283-2535 9W seward TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gan) PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P BOP STACK: Annular Preventer Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 2 Check Valve 1 Quan. Test Press. 1 250/3000 250/3000 250/3000 250/3000 250/3000 250~3000 250~3000 250/3000 FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly / I BOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/3000 F 1 250/3000 P 1 250/3000 P 1 250/3000 P 11 32 1 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 250/3000 P 250/3000 P P Functioned P ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 2,400 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 rain's 21 sec. Trip Tank P P System Pressure Attained 0 min's 45 sec. Pit Level Indicators P P Blind Switch Covers: Master: P Remo----'~t-P Flow Indicator P P Nitgn. Btl's: Four bottles @ 2600 Math Gas Detector F F H2S Gas Detector P P TEST RESULTS Number of Failures: 2 ,Test Time: 5 Hours. Numl3er of valves test 23 Repair or replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the A0OCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Upper kelly valve failed, picked up spare and retest OK. Methane Gas detectors in need of calibration which was performed during test. Rig continues to show improvement. Distribution: Grig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES _ x~._ NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Lou Grimaldi BOP CC-1 SCU22-4 10-6-99 LG.xls 10/11/99 Re: SCU #22-4 Mechanical plug back and sidetrack Subject: Re: SCU #22-4 Mechanical plug back and sidetrack Date: Tue, 28 Sep 1999 11:02:26-0800 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Billingsley, Tim -Contract" <billita~unocal.com> Tim, Thanks for the information. Blair Wondzell "Billingsley, Tim -Contract" wrote: Blair, SCU #22-4 Permit # 99-83 has encountered problems. The well was drilled to 11,330' Then on a trip back in the hole, the bit could not pass by 10476' There were some excessive doglegs at this point in the well. We have been unable to regain the original hole and are in the process of setting a cement plug from 10, 476' to 10,330' This will allow us to redrill the hole and avoid hole problems with hopefully less doglegs. Tim Billingsley 263 - 7659 1 of 1 9/28/99 11:07 AM TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 2, 1999 Dan Williamson Drilling Manager Unocal P O Box 196247 Anchorage, AK 99519-6247 Re; Soldotna Creek Unit SCU #22-4 Unocal Permit No: 99-83 Sur. Loc. 2015'FSL. 2070'FWL. Sec. 4. T7N, R9W. SM Btmhole Loc. 2155'FNL. 2446'FWL. Sec. 4, T7N. R9W. SM Dear Mr. Williamson: Enclosed is the approved application for permit to redrill thc above referenced The permit to redrill does not exempt you from obtaining additional permits required bx- law from other governmental agcncies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection xvells must be dcmonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling nexv hole must bc given so that a representative of the Commission may xvitness the tests. Notice may be given bx' contacting the Commission at 279-1433. Sin Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC~ Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill Redrill X lb. Type of well Exploratory Stratigraphic Test Development Oil Re-entry Deepen Service Development Gas X Single Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Unocal 143' RKB Swanson River Field 3. Address P.O. Box 196247 6. Property Designation Hemlock Anchorage. Ak 99519-6247 A-028997 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (see 20AA025.025) 2015' FSL and 2070' FWL Sec. 4, T7N, R9W, SM Soldotna Creek Unit AK Statewide Oil & Gas Bond At top of productive interval Hemlock H-4 @ 10435' TVD 8. Well Number Number 2178' FSL and 2125' FWL Sec. 4, T7N, R9W, SM SCU #22-4 U 62-9269 At total depth 9. Approximate spud date Amount 2155' FNL and 2446' FWL Sec. 4, T7N, R9W, SM 9/4/99 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15 Proposed depth (MD and TVD) property line 820' (SCU #332-4) 1 1550' MD 2155' @ Hemlock TD Lease 2560 acres 10460' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Kickoff depth 10270 feet Maximum hole angle 88.6° Maximum Surface 1254 psig. At total depth (TVD) 2300 psig 18. Casing Setting Depth program size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD 4.5" 3-1/2" 9.2 L-80 Flush Jt 1950' 9600' 9600' 11550' 10460' None, slotted liner 19. To be completed for Redrill, Re-entry and Deepen Operations Present well condition summary Total depth: measured 10775 feet Plugs (measured) 10388' MD true vertical 10775 feet Effective Depth measured feet Junk(measured)ORIGINAL true vertical feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 28' 22" Drive 28' 28' Surface 1413' 11-3/4" 1000 sx 1413' 1413' Intermediate Production 10375' 7-5/8" 1500 sx 10375' 10375' Liner 1077' 5-1/2" 150 sx 10770' 10770' Perforation Depth: measured 10272'-10714' true vertical 10272'-10714' 21. I here~'"~rti, fy that ~/~o/~/~f~ is true and correct to the best of my knowledge Signed ~t,¢./~¢~.,,~/'~ ~'~/~_~___~/~/¢~"¢/¢, Title: D r i I ling Manager Date ~// ~' Commission Use Only Permit Number I APl Number I Approval date See cover letter ~"~'-- ~.~" 50-/..~,.~ -/'"~;;I,,'/~:;~'- O I ~'.~ ...¢ ~' for other requirements Conditions of approval Samples required Yes ~ Mud Icg required Yes ~ Hydrogen Sulfide measures Yes ~ Dire.¢~onal Survey required ~ N o,._~. - Required working pressure for BOPE"-'~M ('"~M.) 5M 10M 15M Other:~ by order of Approved by ~,,-,,,, ^, o,~,,=r~. ~v Commissioner the commission Date Form 10-401 Rev. 12-1-85'Robert N. Chdstenson Submit in triplicate Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager August 19, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner Robert N. Christenson Application for Permit to Drill (Form 10-401) Swanson River Field Soldotna Creek Unit #22-4 (Formerly SCU #323-4) Commissioner Christenson: Enclosed is the Application to Drill (Form 10-401) for Soldotna Creek Unit Well #22-4. This proposed well will be a Hemlock sand gas producer sidetracked from an existing vertical wellbore, SCU #323-4. The existing SCU 323-4 wellbore will not be abandoned with cement plugs. The proposed sidetrack has a total course length of 1280' of which approximately 1000' will be "horizontal" through Hemlock benches 4 and 5. The horizontal completion interval in the Hemlock will span two quarter-sections. The proposed completion will be the third active Hemlock completion in both the NW/4 and SW/4 of Section 4. Unocal is the owner of all offsetting quarter sections to the proposed redrill so is therefore the only affected owner to this proposal. The proposed sidetrack point in the 5-1/2" liner will be at 10,270' approximately and the new well will be drilled to a TD of 11,550' MD/10,460' TVD. An MWD/GR will provide directional and lithological control for the wellpath. This deep kick-off point will result in only the depleted Tyonek G-2 and Hemlock formations being open to the new wellbore. This should avoid the high pressure drilling problems which were encountered during the drilling of SCU #11-9. Since there will be no need to isolate the G-2 from the Hemlock target interval, a 3- 1/2" slotted liner will be run. Due to the close proximity of the original SCU 323-4 wellbore and G-2 completion interval to the proposed sidetrack well, cement plugs will not be placed for abandonment purposes in SCU #323-4. There is no history of hydrogen sulfide in the Swanson River Field in any of the formations that this proposed sidetrack will encounter. The expected start date for this well is Sept 4, 1999 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. ORIGINAL Sincerely, Dan Williamson Drilling Manager A-28396 UOC I I 1- I 21-3310 31-3:urD I A-28399 ,1-~ A-28396 _ _ _ j uoc I uoc _ . ~-~ I 41-5 ~1~ ~ A-28gg6 {~ 224 ~ I+ ~ ~ ~-28007 ~ UOC 21-8 341-8 SI v.., -~- A-28996 - - -~ UOC I ~ 312-9 43-8 43B-8 ! ° I SOLDOTNA + ~ CREEK L J I + ! I I --~~-28406 1 I "'-~' UOC I ~ ! 12-34 I i A-289g0 I UOC I 14-~ I , I + I 21-3'~' I A-28997 UOC I I I I o 1,OEO 2,o0o 3,0~0 SCALE IN FEET 41B-9 321-9 41 A-28997 ,~. 1o i'"',,. ' 41~-10 I 9 ~ I I _1 ~__l ;997 10 U#Or. AL~ Sold0tna Creek Unit #22-4 PROPERTY PLAT UNOCAL. RKB = 18.5' SIZE 22" 1 t-3/4" 7-5/8" 7-5/8" 7-5/8" 7-5/8" 7-5/8" 5-1/2" liner 3- I/2" liner Tubing 4-1/2" WT Swanson River Well SCU 22-4 10,270' KOP/Proposed Completion CASING AND T'U"BING DETAIL GRADE CON%' ID TOP BTM. 47 39 33.7 29.7 33.7 39 20 9.2 12.6 J-55 8rd N-80 Speed Tite N-80 X-line N-80 Speed Tire N-80 Speed Tire N-80 Speed Tire N-80 Hydril L-80 Flush Joint L-80 Imp Buttress 28' 11.000 Surface 1'413' 6.625 Surface 131' 6.765 131' 3623' 6.875 3623' 5654' 6.765 565'4' 6552' 6.625 6552' 10,100' 4.778 9693' 10,100' 9600' 11,550' 3.958 Sug 9600' NO. Depth ID 18' 2 3 2000' & deeper 4 2,500 5 9600' 6 9600' 7 9620' 8 10,270' 9 10,270' I0 11550' 3.958 3.833 3.865 JE~,t?ELRY DETAIL OD Item 4.500 5.983 Tubing Hanger, 7-1/16" x 4-1/2" Butt., Type" iT' BPV profile. CL prep. 4-1/2" L-80 12.6 ffflb Imp Butt. tubing Five 4-1/2" Side Packet Mandrel MACCO SMOR-1A 5.25 Chemical Injection Mandrel Macco Cra-3 Baker Locator type seal assembly (5.25" OD) Baker "ZXP" Liner Hanger with 10' tieback extension 4-1/2" x 3-1/2" crossover Baker Bottom Trip Whipstock, 5-1/2" 5- I/2" EZSV Bottom of slotted liner G-2 Perfs 0272'- 1 ~ 8 G1 G2 Kick offPoint @ 10,270' 30 de~100' build H4 Top H-4 Target @ 10550'MD/10,435' TVD 3-1/2" slotted liner H5 10 TD = 11550' MD/10,460' TYD Total Horizontal Section (H-4-H5)= 1000' MAX HOLE ANGLE = 88.5 deg SCU 22-4 Proposed Schematic 10270 KOP Drawn by: TA_B 08/17/99 UNOCAL Swanson River Well SCU 323-4 Actual Completion 7/7/95 CASLNG AND TUBING DETAIl, SIZE WT GRADE CON~' ID 22" 11-3/4" 47 J-55 8R 7-5/8" 39 N-80 Speed Tile 7-5/8" 33.7 N-80 X-Line 7-5/8" 29.7 N-80 Speed 'lite 7-5/8" 33.7 N-80 Speed Tile %5/8" 39 N-80 Speed 'lite 5-1/2" 20 N-80 Hydril Tubing 2-7/8" 6.4 L-80 Butt/EUE 2-3/8" 4.6 L/N-80 Butt TOP BTM. 28' 11.000 Surface 1,413' 6.625 Surface 13!' 6.765 131' 3,623' 6.875 3,623' 5,654' 6.765 5,654' 6,552' 6.625 6552' 10,375' 4.778 9,693' 10,770' 2.'441 18.49' 9,733' 1.995 10,392' 10,700' Dummy GLM 6 7 8 9 10 11 12 13 .14 15 16 17 DV @ 6983' Calc 7- 5/8" TOC @ 8514' 5-1/2" x 7-5/8" TOC @ 10,005' G2 Fill Tagged at 10357 (ELM) 4/3/99 H2 H3 H4 H5 H8 H9 HIO JEWELRY DETAIL NO. Depth ED OD Item , - , 20' 2 2,246' 2.347 4.631 3,646' 2.347 4.631 4,580' 2.347 4.631 5,292' 2.347 4.631 5,848' 2.347 4.631 6,496' 2.347 4.631 7,116' 2.347 4.631 7,696' 2.347 4.631 8,279' 2.347 4.631 8,894' 3.347 4.631 9,446' 2.347 4.631 3 9,496' 2.416 6.437 4 9,543' 2.313 3.500 5 9,733' 2.'441 3.700 6 10,388' NA 2.65 7 10,392' 2.688 4.500 8 10,398' 2.992 3.500 9 10,403' 1.87 3.100 l0 10,489' 1.87 3.100 11 10,496' 1.995 4.500 10,498' 1.995 2.375 12 10,525' 13 10,562' 14 10,594' 15 10,627' 16 10,661' 17 10,667' Tubing Hanger, 2-7/8", Purchased from DSR, P/N: 421760, Type "H" BPVP (2-7/8" Butt T x B) GLM Camco, KBMM, 2-7/8" x l", 05673-000-00001 GLM GLM GLM GLM GLM GLM GLM GLM GLM Camco, FCBMM, 2-7/8" x 1" Camco, KB NlM, 2-7/8" x 1" Camco, KBMM, 2-7/8" x I" Camco, KBMM, 2-7/8" x 1" ' Camco, KBMM, 2-7/8" x 1" Camco, KBMM, 2-7/8" x I" Camco, KBMM, 2-7/8" x 1" Camco, KBMM, 2-7/8" x I" Camco, KBMM, 2-7/8" x i" 1" "FIT' 2-7/8" x 7-5/8" GLM Camco, KBMM, 2-7/8" x Packer, Retrievable, Baker Mod. Nipple, 'X' WLEG Baker "F" Latching packer plug with 5 sx CaCO3 on to Packer, Baker SC-25-1/2" Baker Millout Extension 5.60' Sliding Sleeve, Baker CMU Baker "X" nipple Baker High Pressure tubing pack-off Top Stub of Original tubing Packer, Baker FH Otis "S" nipple Brown "CC safety Joint Otis "XA" sleeve Packer,Baker FH camco "D" nipple PERFORATION HISTORY Interval I IAccum' ' Top Btm Amt spf ' }Comments Date 7/13/95 5/9_5/95 Zone G2 10,272' 10,3229' G2 G2 10,332' 10,332' 7/12/95 10,350' 4/1/61 H2 10,394' 4/1/61 I-I3 10,426' 4/1/61 H4/5 10,454' 10,510' 10,539' 10,633' 4/1/61 4/1/61 4/1/61 H8 H9 H10 10,367' 10,406' 10,434' 10,621' 10,648' 10,714' I0' 17' , , 56' i0,670'. 12 12-1/8", EJ 4 2-1/8", F_J 12 2-1/8", EJ 4 Casing .,_mm 4 , Casing g'un 4 Z Casing gun 4 Casing gun 4 J Casmggun 4 JCasing gun Last Workover = 7/95 · ETD = 10,740', TD 10,775' MAX HOLE ANGLE = 2 deg. DRAWN BY: NM REVISED: 5/6/99 General Sidetrack Procedure SCU #22-4 (Formerly SCU 323-4) 1) RU E-line and punch holes in 2-7/8" tubing at appx 9450' (above packer at 9496'). 2) Move in Inlet Drilling Rig #CC-1. 3) NU and Test BOPE to 3000/250 psi. 4) Circulate well to 8.6 ppg lease water and ensure well is dead. 5) Pull completion tubing and retrievable packer at 9450'. 6) Run casing scraper to 10,300' 7) RU e-line and set 5-1/2" bridge plug at approximately 10,270'. 8) RIH with bottom-trip whipstock assembly. 9) Orient and set whipstock on top of bridge plug at 10270'. 10) Mill window at 10270' though 5-1/2" liner and 7-5/8" casing. 11) POOH with window mills. 12) RIH with 4-1/2" bit and angle building motor assembly. Build hole angle and directionally drill from 10100' MD/TVD to 11,550' MD/10,550' TVD. 13) Run 3-1/2" 9.3# L-80 flush joint slotted liner from TD to 9600'. 14) Set hanger, release from hanger and flush out mud inside and outside of slotted liner. 15) Set 3-1/2" x 7-5/8" liner top packer, pressure test liner top to 2500 psi.. POOH with drill pipe. 16) Run 4-1/2" tubing completion with seal assembly in top of 3-1/2" x 7-5/8" liner hanger. 17) Install and test tree. 18) Move drilling rig off location. General Redrill Procedure 22-4 rev 2 Hazard Section Application for Permit to Drill SCU #22-4 There are no known over-pressured intervals in the proposed drilling of SCU #22-4. The deep kick-off point of 10,270' MD/TVD is in the G-2 interval. The rest of the drilling to TD of 11,550'MD/10,460'TVD will be in the Hemlock. Data from the Hemlock and G-2 zone indicates a depleted pore pressure of 0.22 psi/ft for an equivalent mud weight of 4.3 ppg. The proposed mud program of 8.4 ppg to 8.6 ppg mud density will be sufficient to control the reservoir pressure down to 11,611' TD. Lost circulation is possible while drilling the well so attention will be directed towards good drilling practices including slow trips in/out of the hole, accurate monitoring of trips with a trip sheet and keeping the hole full by circulating over the top of it. Lost circulation will be treated initially with 100 ppb liquid casing. A formulation of graded nut plug and calcium carbonate will also be utilized if losses become severe. Mud and Cuttings Disposal The mud from SCU #22-4 will be disposed in the mud disposal well, SCU #43- 4MD. The cuttings generated by drilling #22-4 will be disposed in the solid waste facility at Swanson River Field. Swanson River Well #SCU 22-4 Bottomhole Pressure Information The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the sidetrack SCU 22-4. The pore pressure gradient was estimated from the following information: BHP Depth Well psi TVD EMW, ppg Comment 323-4 2300 10460 4.2 ppg or .22 psi/ft, Depleted Hemlock and G-zone The fracture gradient at sidetrack window at 10,270' is estimated at .70 psi/ft or 13.5 PPg. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling (in.) (TVD ft) (Ibs/_qal) (Ibs/_qal~ (Ib/.qal) (psi) (psi) 5-1/2" 10270 13.5 4.2 8.4 2243 1254 3-1/2" Inr 10460 NA 4.2 8.4 2300 Procedure for Calculating Anticipated Surface Pressure While Drilling ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with gas bubble just below shoe and mud gradient above shoe) or 2) formation pore pressure at the next casing point less gas gradient to the surface as follows: 1) ASP : (FGx.052xD) - (MWx.052xD) = (13.5 x .052 x 10270) - (8.4 x .052 x 10270) =2724 psi OR 2) ASP = FPP - (0.1 gas gradient xD) = 2300-(.lx10460) = 2300 - 1046 = 1254 psi SCU #22-4 Casing Design 7-5/8" Production Casing, 29.7#, 33.7# and 39# N-80 5-1/2" Liner, 20#, N-80 Worst case for burst is tubing leak near the surface after the well is completed. Burst 10,460' x((4.23 formation x .052) - 0.1 gas grad)) 7-5/8" 29.7# rated @ 6890 psi for burst = 1254 psi Safety Factor = 5.5 OK Worst case for collapse is if lost returns occur while drilling below the 7-5/8" casing. Collapse = (8.33x.052x10100') -(10100' x .1 ) 39# rated @ 8810 psi for clpse -- 3365 psi for full evacuation Safety Factor = 2.6 OK Tension = NA (casing already in place and cemented) 3-1/2" 9.2#, L-80, slotted liner @ 11550' MD/10460' TVD Tension = (11550'-9600') x 9.2#= 18K Rated - 207K for body yield Safety Factor = 11.5 OK Collapse = Not applicable for slotted liner Burst = Not applicable for slotted liner SCU #22-4 Casing Specifications Proposed Casing Liner 3-1/2" 9.2#, L-80,Flush Joint Tubing, slotted Joint Strength, K lbs 2O7 Body Strength, K lbs · 207 Burst Rating, psi NA, slotted liner __ Collapse Rating, psi NA, slotted Cplg OD, in (flush jt) 3.5 CSGSPEC 22-4 rev 2 SCU 22-4 Cementing Program 3-1/2" Slotted Liner The deep kick-off point of 10,270' results in the proposed sidetrack penetrating only the G-2 and Hemlock intervals, It is not necessary to isolate the G-2 from the Hemlock productive intervals so a slotted liner will be run instead of cementing a solid liner. Inlet Drilling Rig #CC-1 7-1/16" 5000 psi BOP Stack 7-1/16" Annular Preventer I I 5k psi Blind Rams 3-1/8" Kill Line 5k psi Pipe Rams 1~1 Drilling Spool I psi Pipe 5k Rams [X~7-1/16 5M~,1 .... TubinglheadF ~ Casing 4-1/16" Choke Line 1 = HCR Valve 2 = Gate Valve Blowout Prevention Equipment Inlet Drilling Rig #CC-1 or Equivalent 7-1/16" BOP Equipment 1 ea 7-1/16"x 5000 psi wp single ram type preventer 1 ea 7-1/16"x 5000 psi wp double ram type preventer 1 ea 7-1/16" x 5000 psi wp annular preventer 1 ea 7-1/16"x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on choke line and two manual valves on kill line. 1 ea Koomey BOP control unit with 120 gallon volume tank, w/twelve 10-gallon accumulator bottles and nitrogen back-upsystem. 1 ea 5 station, remote control panel 1 ea 5,000 psi choke manifold with Cameron automatic hydraulic choke 3" - 10,000 psi with control choke panel. ,- 1 lot Hydraulic pipe and fittings from manifold to BOP stack. Interval Summary- SCU 22-4 · :;.: :::.::...:::,.:;...: .. ....... :..:: ..' : .:....: ..... : · . ........ :- ' ::. it:i:::.. : ,': :::::::::'!::.- ::::':Z. · : ' ::. : ::-- : ::;:: : :.: :: -::: -.:.::: - FIo-Vis / Kla-Gard / Barite / Soltex / Caustic Soda / Lubetex / FloTrol ::::::::::::::::::::: !iSOl:idS. Contro{: Shale Shakers / Desilter / : :::::: :.i Pot:ential:'Problems: JWindow Milling / Hole CteanL':g / Los: Circulation / Directional Con- Depth ' Mud Plastic 'Field AP! Lubricant · '..Total Interval Weight . VisCOsity. Point Fluid Loss Percentage Solids· '-:-(f-t) (ppg) (cp): (Ib/lO0Pc=) (ml/30rnin) (%}. .::. (.%) .ge0'o' ea:i~g) s.4 5 - 7 25- 35 I 8 - :0 0 - 1 0 -: 8.4-8.6 6-8 20-30 i 6-8 t-2 1-2 ~__.~,',',',',','~2~~' '". -~-'--'"' '_ ..... ' '-"..v~-_.~;..~.~:~~ Build initial volume with 2+ ppb Flovis, Caustic for 9.0 p:-~l, d ppb KIa-Gard, 1 ppb FloTrol, 2 ppb Soltex, 1/4 ppb Greencide 25G. Initial volume requirements should be d00+ bbts RI:H, set whipstock, displace well to FloPro fluid, begin ~lling when fluid passes mill. Add Lubetex as needed to reduce torque and drag and allow for directional control. Pump hi~=jq-viscosity sweeps as needed to insure good hole cleaning. Keep drill solids to a minimum by aggressive use of ali solids control equipment, dilution, and maintaining 4+ ppb concentration of Kla-Oard (shale inhibitor). Let Kia-Gard concentration drop to 3 -4 ppb upon drilling sandstone formation. Maintain fluid loss control with additions of FloTrot. · At T.D., sweep hole, spot a clean FloPro pill (3 5 -40 yield point) with 5% Lubetex in the open hole prior to running ~ 1/2" liner. Estimated volume 80 - 90 bbls · Run and cement liner, clean pits, displace well to 6% KCL completion fluid. _ i iii i i i ii i i i ii i i iiii i i i ii i i i i ii lllL II M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax rl~ BRILLI~Ei FLUIBS Drilling Fluid System Description Inlet Drilling Rig #CC-1 Mud Pumps 1 ea PZ9 Gardner Denver, 3"x 5000 psi shear release valve and a 4"x 4000 psi gates bumper hose powered by a 398 TA Cat. 1 ea 214P Oilwell powered by twin 671 Detroit diesel engines. Mud Tank System (466 bbl Total Volume) Tank A- 88 bbl suction tank Tank B- 150 bbl middle tank Tank C- 172 bbl shaker tank Tank D- 27 bbl pill tank Tank E- 17 bbl centrifuge tank Tank F- 12 bbl sand trap Trip Tank- 35 bbl 501 bbl total Mud System Equipment 1 ea 1 ea 1 ea 1 ea 1 ea 3 ea Brandt dual tandem 800 gpm shale shakers Drilco See-FIo degasser 36"x 6' Poor Boy gas buster Pioneer eight cone desilter Pioneer Model S-800 mud hopper Medearis 3" revolving mud agitator guns 1 ea 1 ea 1 ea Pit level indicator with audio and visual alarms Fluid flow sensor Gas monitoring for H2S and LEL with sensors at rig floor, sub and shakers. MUD TANKS ATTACHMENT · Iff ,13 , UNOCAL Wmil : SCU22-4 ~e~d : Sc~dolna Cr~k Unit Laoatle. n I ~,~I ~lnsula, Ak~kq East (feel) -> 200 1 O0 0 1 O0 ZOO O0 UNOCAL. 400 800 SCU 22-4 HSB I V g4oo g60o g700 ggo0 10000 10100 O300 10400 1060O 07oo ZOO 100 0 SCU22-4 H4/5 Top CU22-4 H4/5 Tup SCU 22-~ HSB zoo ..soo 4o~ 5oo 600 700 ~ goo 10~ Ved[co[. Seer[on (feel) -> Azlmufh 18.72 with reference 0.00 S, 0.00 E from ~2~-4 700 600 ~00 200 1oo IOO Z 0 I ""1 '"--=1 1 1 · ! ~ i 1100 t200 1.300 1400 1500 UNOCAL SCU 22-4 SCU22-4 323.4 Soldotna Creek Unit Kenai Peninsula, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : SCU 22.4 Version i~aS Our ref : prop3485 License : Date printed : 17-Aug-1999 Date created : 30-Ju1-1999 Last revised : 17-Aug-lgg9 Field is centred on n60 43 10.024,wi50 51 4.527 Structure is centred on 342288,857.2455952.696.999.00000,N Slot location is n60 43 29.866,w150 52 9.048 Slot Grid coordinates are N 2457939,618, E 344385.537 Slot 1Qcal coordinates are 2015,00 N 2070.00 E Projection type: alaska - Zone 4. Spheroid: Clarke . 1866 Reference North is True North UNOCAL SCU '22-4.SCU22-4 Soldotna Creek Untt.Kenai Peninsuln, Alaska Measured Incltn. Azimuth True Vert Depth Degrees Degrees Depth 0,00 0,00 18,72 0,00 500,00 0,00 18,72 500,00 1000,00 0,00 18,72 1000,00 1500.00 0.00 18.72 i5oo.oo 2000.00 0.00 18.72 2000.00 2500,00 0,00 18,72 2500,00 3000,00 0,00 18,72 3000,00 3500,00 0,00 18,72 3500,00 4000.00 0.00 18.72 4000.00 4500.00 0.00 18.72 4500.00 5000.00 0.00 18.72 5000,00 5500,00 0,00 18,72 5500,00 6000.00 0.00 18.72 6000.00 6500,00 0,00 18,72 6500,00 7000.00 0,00 18,72 7000,00 RECTANGULAR COORDINATES O,OOS O,OOE O,OOS O,OOE O,OOS O,OOE O,OOS O,OOE O.OOS O.OOE PRDPOSAL LISTING Page 1 Your ref : SCU 22-4 Version #5 Last revised : 17-Aug-1999 Dogleg Vert Deg/lOOft Sect 0.00 0,00 0,00 0,00 0.00 0.00 0,00 0,00 0,00 0,00 0,00 S 0,00 E 0,00 0,00 0.00 S 0,00 E 0,00 0,00 0,00 S 0,00 E 0,00 0.00 0,00 S 0.00 E 0,00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S O.O0 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0,00 S O,O0 E 0,00 O.OO 0.00 E 0.00 0.00 0.00 E 0.00 0.00 0.00 E ' 0,00 0.00 0.00 E 0.00 0.00 0,00 E 0,00 0.00 7500,00 0.00 18,72 7500,00 0,00 S 8000,00 0,00 18,72 8000,00 0,00 S 8S00.00 0.00 18,72 8500,00 0.00 S 9000.00 0.00 18,72 9000,00 0,00 S 9500,00 0,00 18,72 9500,00 0,00 S 10000.00 0.00 18.72 10000.00 0.00 S 10270.00 0.00 18.72 10270.00 0.00 S 10370.00 30.00 18.72 10365.49 24.23 N 10470.00 60.00 1~.72 10435.40 90.44 N 10550.59 84.18 18.72 10460.00 162.53 N 0,00 E 0,00 0.00 0,00 E 0.00 0.00 ~op 30,64 E 30,00 95.49 55,07 E 30,00 171,60 SCU 22-4 H4/5 Top 10550,63 84,19 18,72 10460,00 162,57 N 55,09 E 30.00 171.65 10565.34 88,60 18,72 10460,93 176,47 N 59,79 E 30,00 186.32 11000.00 88.60 18.72 10471.54 588.02 N 199.24 E 0.00 620.86 11500.00 88.60 18.72 10483.76 1061.43 N 359.65 E 0.00 1120.71 11550.96 88.60 18.72 10485.00 1109.68 N 375.99 E 0.00 ]171.65 SCU 22-4 HSB All data is in feet unless otherwise stated, Coordinates from 323-4 and TVD from estimated rkb (170.00 Ft above mean sea level), Bottom hole distance is 1171,65 on azimuth 18,72 degree~ from wellhead, Total Dogleg for wellpath is ~,60 degrees, ~ertical..~ar-t, io~i~ fr~m~wellhead on ~ztmuth 18,72 degrees, C:lcul~tion uses the minim~n curvature method, Presented by Baker Hughes INTEQ UNOCAL SCU 2_2- 4. SCU22- 4 $oldotna Creek Unit.Kenai Peninsula. Alaska PROPOSAL LISTING Page 2 Your ref : SCU 22.4 Version Last revised : 17-Aug-1999 Comtmnts in wellpath _ _ mlw MD TVD Rectangular Coords. Comment i;~;;]~¢'i;~;i;~ ..... i~]i~'~ ...... ~;];~'~"~'~]~'~Jii'+;; ............................................. 11550,9§ 10485.00 1109,68 N 375,99 E SCU 22-4 HSB Target~ mssociatedwith this wellpath Target n~me Geogrmphic Location T.V.D. Rectangular Coordinates Revised .~ ............................................. o.,...,...m..-o,,.,,~.,,,..,.. ............. ooo,o.,,..,,...,, SCU22-4 H4/$ Top 10460,00 162.57N 55.09£ 30-Jul-1999 SCU 22-4 HSB 10485.00 1109.68N 375.9gE 30,Ju1-1999 DATE 05 -AUG- 99 FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. INVOICE/CREDIT MEMO NO. DRILLPERMITSCU23 VOUCHER NO. ~4 0899300012 VENDOR NO. 1031548 GROSS 100.00 DATE DISCOUNT CHECK NO. 2003572 NET 1OO.OO 100.00 100.00 --- CITIBANK DELAWARE 62-20 a Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil Company of California Accounts Payable Field Disbursing UNOCAL Pay One Hundred Dollars And O0 Cents******* 200 ;572 To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE AK 99501 ll'~OO~5? ~"' i:O~O0 ~Oqi: Date 06 -AUG ''l' 99 Check Amount ****100.00 Void after six months from above date. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION ENGINEERING COMPANY~---¢',-,.)~,~¢._,~ (~ WELL NAME ,~'~.~__~ .Z_,2_- (-/ . PROGRAM: exp I INIT CLASS ~,,~ ?'- ~., ~ GEOL AREA .. 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ ~_(~_ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ N ~N (~N ~ N N GEOLOGY APPR 28. 29. 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE GEOLOGY: dev Comments/Instructions: Work will occur without operation shutdown ........... (:~ N Is presence of H2S gas probable ................. Y(~p ~Y ~ ... Permit can be issued w/o hydrogen sulfide measures ..... ~YY N ~' .,,,~~ Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) Contact name/phone for weekly progr~s~ ;el~(:;rt~ '[e'~;l~r'at'o~y~ly] Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not co~'~minate fres~e drilling waste . .~~Y N to su,-rap; ._ / (C) will n/o{'irnpair~hanical integr~t~~l used for disposal; Y N (D) will ot ~on or impair recovery from a Y N poo, and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N a EW(~., $/f.~ENGINEERING: ~A/IC/~ DWJ COMMISSION: JDH ~ RNC CO ~.~o/'~ ~ redrll ~ serv UNIT# wellbore seg or/?,y~ ;ann. disposal para req_ ON/OFF SHORE ~ c:\msoffice\wordian\diana\checklist
