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184-186
2roject Well History File' Cove . ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. j ~ L.jL_ _~ _~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] .Other: ~ NOTES: BEVERLY BREN Vl~ SHERYL MARIA LOWELl. BY: OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other DATE: Project Proofing BY: BEVY BREN VINCENT SHERYL MARIA LOWELL ScaNning Preparation '"-..~ x 30 = /'0~-0 + BY: BEVERLY ~ VINCENT SHERYL MARIA LOWELL Production Scanning Stage, PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' NO Stage 2 ,,~.~N STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: BY: ~.~ BEVER~~ BREN VINCENT SHERYL MARIA LOWELL ' (SCANNING IS COMP rHIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) II : ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General'Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd ALASKA b, AND GAS CONSERVATION COM, SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 508' NSL, 2244' WEL,SEC. 18, T11 N, R13E, UPM At top of productive interval N/A Water Injection Well At effective depth 257' NSL, 918' EWL, SEC. 18, T11N, R13E, UPM At total depth 260' NSL, 907' EWL, SEC. 18, T11 N, R13E, UPM 6. Datum Elevation (DF or KB) KBE = 83.04 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number U-05 9. Permit Number 1841680 10. APl Number 50- 029-21192 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9570 feet Plugs (measured) true vertical 9227 feet Effective depth: measured 9528 feet Junk (measured) true vertical 9186 feet Casing Length Size Cemented Structural Conductor 110' 20"X30" 8 cu. yds. Surface 2634' 13 3/8" 3321 c.f. Intermediate 9129' 9 5/8" 1874 c.f. Production Liner 672' 7" 270 c.f. MD TVD 144' 144' 2668' 2668' 9163' 8834' 8898'-9570' 8579'-9227' Perforation depth: measured 9178'-9225',9289'-9332',9346'-9365' true vertical 8766'-8811',8873'-8915',8928'0'-8947' Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8864' with 4 1/2" tailpipe to 8970' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 8864'; No SSSV 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation (o//~-/O / 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Name of approver Date approved Contact Engineer Name/Number: Joe Ander$, 659-5102 Prepared By Name/Number: Scott La Voie/564-4636 17. I hereby certify,/~0~th~~true and correct to the best of my knowledge / '~"/ Signed JoeAnCrs/KevinYeager Title Well Integrity Engineer Date ~o / 0 / Commission Use Only Conditions of Approval: Notify Commission so representative may witness k~l~ ~ ~ ~ ~ I Approva, No. ~:~/,/~/~) I I Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test '~ Subsequent form required 10- ~.--~x--X ~'..%..~ ~r¢._~-~'~-..~ ~% I I urfglnal $i~ By Approved by order of the Commission [~=,,,,,"'~"~}' ~¢~..*. Commissioner Date Form 10-403 Rev. 06/15/88 Subm~'t'~r~ Tr'r¢licate ORIGIIX,IAL U-05 Sundry Application Action Plan 06/09/01 Well History, and Status Well U-05 (PTD 184-168) is an injector that failed a recent MIT-IA. An MIT-IA conducted on 01/17/01 failed with a leak rate of 5.6 gpm at 1550 psi. A CMIT-TxlA against a tubing tail plug passed to 2500 psi on 02/25/01, indicating competent production casing. This sundry request is to allow for continued injection of water into Well U-05. The following supports the request: - A CMIT-TxlA Passed on 02/25/01 to 2500 psi against a tubing plug, demonstrating competent production casing. - Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. - An annual IA leak rate test will be conducted to monitor the leak severity. - If the leak rate increases over 10 GPM, the AOGCC will be notified and the sundry updated to reflect new conditions. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Perform an annual IA leak rate test. 4. Perform a combination MIT Tubing x IA against a plug every 4 years. 5. Submit a monthly report of daily pressures and injection rate. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. 7. Notify the AOGCC if the leak rate increases over .5 BPM. U 05i WELLHEAD: 6" i BF. ELEV = 48.79 ACTUATOR: OTIS "~ '"'r~~ ~ ' r ~ sssv LANDING NIPPLE ~ (OTIS X)( 4.562" ID) 11'994 Cemented ~.~..~...~. ~ ~ NO CONTROL LINES 13 3/8" 72# L-80 BTRS I 2,668 I ~i I KOP: 4200 I MAX ANGLE: 25* I 5-1/2", 17#/ft, L-80 TUEING ID: 4.892" ~ CAPACITY: 0.0232 BBL/FT SLIDING SLEEVE 18,780 r~ ~ if~....~ OTIS-XA (4.562" MIN. ID) .,.,, ,,x,,.,.... I ~ ~ ~ I.,~ ~~'" (OTIS) (3.813" ID) 8,907 Top of 7"Liner 18,897 I~ I I '~ (OTIS) (3.725" ID) , ,-5/8", 47#/.,BTRS ShoeL-80' 19,163I+~0~ SOS)(4.892",D)(ELMD) 18'970 PERFORATION SUMMARY REF: LOG: BHCS 11/24/84 i TIE IN: GR/CCL 6/2/87 Size SPF Interval Open/Sqzed 3-3/8" 4 9178-9225 Open (Sag) 3-1/8" 4 9289-9332 Open 3-1/8" 4 9346-9360 Open ' 9360-9365 Sqzd , '~ MARKER JOINT 19,362 =ETD 19,828 I-~,. DATE REV. BY COMMENTS PRUDHOE BAY UNIT 11/13/R4 Romberq Initial Riq Completion 1/7/90 PRH MACTIZE WELL: U-05 (14-18-11-13) 8/21/91 Revised APl NO' 50-029-21192 12/25/98 Nords Updateto PC SEC 18; TllN; RG13E BP Exploration (Alaska) Size SPF Interval Open/Sqzed 3-3/8" 4 9178-9225 Open (Sag) 3-1/8" 4 9289-9332 Open 3-1/8" 4 9346-9360 Open 9360-9365 Sqzd BP Exploration Alaska Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp June 12, 2001 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Summary of Current Injectors with Sundries 04-17 (PTD 186-020) Application for Sundry Approval 13-09 (PTD 181-158) Application for Sundry Approval M-13 (PTD 180-124)Application for Sundry Approval U-05 (PTD 184-168) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for wells 04-17, 13-09, M-13 and U-05. These requests are for approval to continue produced water injection with known tubing x inner annulus communication. A proposed Action Plan and wellbore schematic is included for each well. Also attached is a listing of all injectors operating under a Sundry in the Prudhoe Bay and GPMA fields. As the number of injection wells operating under a sundry has increased, the monitoring and test programs have evolved. To provide a consistent approach to monitoring each well type, we have proposed standard test requirement for 4 types of problems. If you require any additional information or clarification, please contact either Kevin Yeager or me at (907) 659-5102. Sincerely, J~oe Anders, P.E. Well Integrity Engineer Attachments Injector Sundry Review Slow TxlA Communication: leak rate < 10 GPM Recommended Requirements: Monthly Report Annual MITIA/LLRT CMIT TxlA 4-years Re-submit sundry if leak rate becomes high enough to log Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-08 8/15/2000 300-198 1 GPM @ 2500 psi Monthly Report Annual MITIA/LLRT CMIT TxlA 4-years 11-29 02/11/98 398-035 0.1 GPM @ 2400 psi Monthly Report Annual CMIT TxlA 12-02 10/20/93 93-286 rvllTIA's now pass Annual MITIA 12-27 10/08/93 93-269 MITIA's now pass Annual MITIA 13-09 1 GPM @ 3000 psi In progress, submitted 06/11/01 13-18 08/15/00 300-200 4 GPM @ 1300 psi Monthly Report CMIT TxlA 2-years 14-14 08/15/00 300-199 .7 GPM @ 2500 psi iMonthly Report LLRT 1-year CMIT TxlA 4-years P1-01 07/22/98 398-188 2.4 GPM @ 3000 psi Monthly Report Annual CMIT TxlA P2-34 09/20/98 398-243 MITIA Pass, 3 days to Monthly Report equalize Annual CMIT TxlA U-05 6 GPM @ 1550 psi In progress, submitted 06/11/01 Y-03 4 GPM @ 1750 psi In progress, submitted 03/19/01 Rapid T x IA Communication: Leak rate > 10 GPM Recommended Requirements: Monthly Report CMIT TxlA 2-years Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 03-11 05/21/99 399-084 1 BPM @ 2400 psi Monthly Report CMIT TxlA - 2 years Note: Sundry aplication action plan refers to an expiration date of 5/21/01 04-17 2.5 BPM @ 400 psi In progress, submitted 06/11/01 04-45 07/05/00 300-173 1 BPM @ 1300 psi Monthly Report CMIT-TxlA 1 year 13-15 06/16/99 399-091 .8 BPM @ 2900 psi Monthly Report CMIT TxlA 2-years S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/1222001 Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 13-17 10/21/98 298-275 >1 BPM Monthly Report OMIT TxlA 1-year 13-20 04/23/97 397-078 >1 BPM Monthly Report OMIT TxlA 1-years 13-31 08/01/00 300-199 2 BPM @ 2325 psi Monthly Report OMIT TxlA 2-years 14-21 12/17/99 399-248 1 BPM @ 2500 psi Monthly Report OMIT TxlA 1-year LPC-02 12/15/99 399-247 > 1 BPM Monthly Report Annual MITQA to 1500 psi Annual LLR on IA M-13 .25 BPM @ 2500 psi In progress, submitted 06/11/01 P-14 02/10/00 300-038 ,2.6 BPM @ 1950 psi Monthly Report Y-10 4/20/2000 300-103 1.5 BPM Monthly Report OMIT TxlA 2-years IA x OA communication Recommended Requirements: Monthly Report CMIT IAxOA 2-years Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 03-10 05/09/00 300-106 1 GPM @ 2125 psi IMonthly Report MIT-T 2 years 04-09 06/05/00 300-145 Rapidly Equalizes Monthly Report CMIT IAxOA 2 years 04-13 10/26/88 8-808 Rapidly Equalizes None 11-10 06/09/89 9-490 Rapidly Equalizes MITIA Annually 12-23 07/11/00 300-174 Rapidly Equalizes Monthly Report CMIT IAxOA to 2100 psi, 2 years Production Casing Leak Recommended Requirements: Monthly Report Annual MIT-OA MIT-T 4-years Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-09 09/27/99 399-185 .7 BPM @ 2000 psi Monthly Report MIT-T Annually CMIT IAxOA 2 years Max IA pressure 1000 psi A-31 01/27/00 300-008 .5 BPM @ 3000 psi Monthly Report S :\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 Injector Sundry Review Slow TxlA Communication: leak rate < 10 GPM Recommended Requirements: Monthly Report Annual MITIA/LLRT CMIT TxlA 4-years Re-submit sundry if leak rate becomes high enough to log Well No. Date Approved Approval No. Leak Rate Currer~t Requirements Comments 01-O8 8/15/2000 300-198 1 GPM @ 2500 psi Monthly Report Annual MITINLLRT CMIT TxlA 4-years 11-29 02/11/98 398-035 0.1 GPM @ 2400 psi Monthly Report Annual CMIT Txl^ i 2-02 10/20/93 93-286 MITIA's now pass Annual MITIA 12-27 10/08/93 93-269 MITIA's now pass Annual MITIA 13-09 1 GPM @ 3000 psi In progress, submitted 06/11/01 13-18 08/15/00 300-200 4 GPM @ 1300 psi Monthly RePort OMIT TxlA 2-years 14-14 08/15/00 300-199 .7 GPM @ 2500 psi Monthly Report LLRT 1-year OMIT TxlA 4-years P1-01 07/22/98 398-188 2.4 GPM @ 3000 psi Monthly Report Annual OMIT TxlA P2-34 09/20/98 398-243 MiTIA Pass, 3 days to Monthly Report equalize Annual OMIT TxlA U-05 6 GPM @ 1550 psi In progress, submitted 06/11/01 Y-03 4 GPM @ 1750 psi In progress, submitted 03/19/01 Rapid T x IA Communication: Leak rate > 10 GPM Recommended Requirements: Monthly Report CMIT TxlA 2-years Well No. Date Approved Approval No. Leak Rate C,u,rrent Requirements comments 03-11 05/21/99 399-084 1 BPM @ 2400 psi Monthly Report OMIT TxlA - 2 years Note: Sundry aplication ~ action plan refers to an expiration date of 5/21/01 04-17 2.5 BPM @ ,40,0 p.si In progress, submitted 06/11/01' 04-45 07/05'/00 300-173 1 BISM @ 1300 psi Monthly Report CMIT-TxlA 1 year 13-15 08/16/99 399-091 .8 BPM @ 2900 psi Monthly Report CMIT TxlA 2-years AIas!{a · S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 Well No. I~ate Approved APproval NO. Leak Rate Current Requirements Comments 13-17 10/21/98 298-275 >1 BPM Monthly Report CMIT TxlA 1-year 13-20 04/23/97 '397-078 >1 BPM Monthly Report CMIT TxlA 1-years '{3-31 08/01/00 300-199 2 BPM @ 2325 psi Monthly Report CMIT TxlA 2-years 14-21 12/17/99 399-248 1 BPM @ 2500 psi Monthly Report- CMIT TxlA 1-year LPC-02 12/15/99 399-247 > 1 BPM Monthly Report ,Annual MITOA to 1500 psi Annual LLR on IA M-13 .25 BPM @ 2500 psi In progress~ submitted 06/11/01 P-14 02/10/00 300-038 2.6 BPM @ 1950 psi Monthly RePort Y-10 4/20/2000 300-103 ,1.5 BPM Monthly Report CMIT TxlA 2-years IA x OA communication Recommended Requirements: Monthly Report CMIT IAxOA 2-years Well No. Date Approved Approval No. Leak Rate Current Req'uiremenis Comments 03-10 05/09/00 300-106 1 G~M @ 2125 psi Monthly Report MIT-T 2 years 04-09 06/05/00 300-145 Rapidly Equalizes Monthly Report CMIT IAxOA 2 years 04-13 10/26/88 8-808 Rapidly Equalizes None 11-10 06/09/89 9-490 Rapidly Equalizes MITIA Annually 12-23 07/11/00 300-174 Rapidly Equalizes Monthly Report CMIT IAxOA to 2100 psi, 2 years Production Casing Leak Recommended Requirements: Monthly Report Annual MIT-OA MIT-T 4-years Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-09 09/27/99 399-185 .7 BPM @ 2000 psi Monthly Repod MIT-T- Annually CMIT IAxOA 2 years Max IA pressure 1000 psi A-31 01/27~'00 300-008 .5 '~PM @ 3000 psi Monthly Report S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 Injector Sundry Review Slow TxlA Communication: leak rate < 10 GPM Recommended Requirements: Monthly Report Annual MITIA/LLRT CMIT TxlA 4-years Re-submit sundry if leak rate becomes high enough to log Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-08 8/15/2000 300-198 1 GPM @ 2500 psi Monthly Report Annual MITINLLRT CMIT TxlA 4-years 11-29 02/11/98 398-035 0.1 GPM @ 2400 psi Monthly Report Annual CMIT TxlA 12-02 10/20/93 93-286 MITIA's now pass Annual MITIA 12-27 10/08/93 93-269 MITIA's now pass Annual MITIA 13-09 1 GPM @ 3000 psi In pmgress~ submitted 06/11/01 13-18 08/15/00 300-200 4 GPM @ 1300 psi Monthly Report CMIT TxlA 2-years 14-14 08/15/00 300-199 .7 GPM @ 2500 psi Monthly Report LLRT 1-year CMIT TxlA 4-years P1-01 07/22/98 398-188 2.4 GPM @ 3000 psi Monthly Report Annual CMIT TxlA 'P2-34 09/20/98 398-243 MI'TIA Pass, 3 days to Monthly Report equalize Annual CMIT TxlA U,-05 6 GPM @ 1550 psi In progress, submitted 06/11/01 Y-03 4 GPM @ 1750 psi In progress~ submitted 03/19/01 Rapid T x IA Communication: Leak rate > 10 GPM Recommended Requirements: Monthly Report CMIT TxlA 2-years ',Well No. Date Approved Approval ,No. Leak FI, ate Current Requirements Comments 03-11 05/21/99 399-084 1 BI~M @ 2400 psi Monthly Report CMIT TxlA - 2 years · Note: Sundry aplication action plan refers to an expiration date of 5/21/01 04-17 2.5 B~M @ 400 p,si In progress~ submitted 06/11/01 04-45 07/b5)00 3~°-173 1 BPM @ 1300 psi Monthly Report :CMIT-TxlA 1 year 13-1~ 06/16/99 ;~99-d9'1 .8 BPM @ 2900 psi Monthly Repod CMIT TxlA 2-years S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 ~Weil No. Date Approved Approval No. Leak Rate Current'Requirements Comments 13-17 10/21/98 298-275 >1 BPM Monthly Report CMIT TxlA 1-year 13-20 04/23/97 397-078 >1 BPM Monthly Report CMIT TxlA 1-years 1.3-31 08/01/00 300-199 2 BPM @ 2325 psi Monthly Report CMIT TxlA 2-years 14-21 12/17/99 399-248 1 BPM @ 2500 psi Monthly Report CMIT TxlA 1-year LPC-02 12/15/99 399-247 > 1 BPM Monthly Report Annual MITOA to 1500 psi Annual LLR on IA M-13 .25 BPM @ 2500 psi In progress~ submitted 06/11/01 P-14 02/10/00 300-038 2.6 BPM @ 1950 psi Monthly Report Y-lO 4/20/2000 300-103 1.5 BPM Monthly Report 'CMIT TxlA 2-years . IA x CA communication Recommended Requirements: Monthly Report CMIT IAxOA 2-years Well No. Date Approved Approva, I No. Leak Rate Current Requirements Comments 03-10 05/09/00 300-106 1 GPM @ 2125 psi Monthly Repod MIT-T 2 years 04-0'9 06/~35/00 300-145 Rapidly Equalizes Monthly Repod CMIT IAxOA 2 years 04-13 10'/26/88 8-808 Rapidly Equali;~es None 11-10 06/09/89 9-490 Rapidly Equalizes MITIA Annually ' 12-23 07/11/00 300-174 Rapidly Equalizes Monthly Repod CMIT IAxOA to 2100 psi, 2 years Production Casing Leak Recommended Requirements: Monthly Report Annual MIT-CA MIT-T 4-years Well No. Date Approved Approval ~o. Leak Rate Current Requirements Comments 01-09 09/27/99 399-185 .7 BPM @ 2000 psi Monthly Report MIT-T Annually CMIT IAxOA 2 years Max IA pressure 1000 psi A-31 01/27/00 300-008 .5 BPM @ 3000 psi Monthly Report S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 STATE OF ALASKA ,L.?.,, ~ .;, ~ii:ii j .!~'~-5~~ ALAS: ~01LAND GAS CONSERVATION COl~' ~;SION WELL COMPLETION OR RECOMPLETION I- EPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [-] SUSPENDED [~ ABANDONED[~ SERVICE [--] 2. Name of Operator 7. Permit Number Union Oil Company of California (UNOCAL) 84-186 / 92-- 125 (approval #) 3. Address 8. APl Number P. O. Box 196247, Anchorage, Alaska 99519 50-733-20374 4. Location of well at surface Leg #4, Conductor #18, Grayling Platform ," -, .~.7.;.~.. 9. Unit or Lease Name 1837' FSL and 1438' FEL, Section 29, T9N, R13W, S.M. L'....~ .,~, ~ ;.~/~ Tradin~ Bay Unit AtTop Producing Interval VI~FI~ [; 10. Well Number G-29 At Total Depth 12733' MD ( 9927' 'I-VD ) ~1~~ 11. Field and Pool 308' FNL and 1996' FEL, Section 30, TgN, R13W, S.M..---,~.w,.,.~,~ McArthur River Field 5.103'ElevationRKB abovein feetMLLW(indicate KB, DF, etc.) 6. LeaseADL 1 Designation7594 and Serial No. Hemlock 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions June 10, 1992 June 11, 1992 (abandoned) 125 Feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Surve~ 20. Depth where SSSV set 21. Thickness of Permafrost 12733' MD/9927' TVD 10114' MD/8050' TVD~ YES ~--] NO L_J feet MD N/A 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SIZE FT. SETTIN~ DEPTH MDI CASING WT. PER GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 911' 25" 1814 sxs 13-3/8" 61# &68# K-55 Surface 6572' 17.5" 4110 sxs 9-5/8" 47# N-80 Surface 12728' 12.25" 1575 sxs window f/11078' - 11090' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) I PACKER SET (MD) All perforations abandoned. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. See attached Schematic and Well History DEPTH INTERVAL IMD) I AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOI; OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA OCT - 5 1992 Alaska 0il & Gas Coas. UornmisSiOn Anch0ra§0 Form 10--407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE !' 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 81. LIST OF A~AOHMENT8 32. I hereby ce~i~ that the foregoing is true and correct to the ~st of my knowledge Ga~ S. Bush~ Drlg Mgr August 14, 1992 Signed..~~~. ~~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types 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 spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing 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.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing 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'. KB @ O.O' 28" @ 324' 20"6911' 13-3/8" @ 6572' // CMT RET @ 10114' CMT RET @ 11328' DRill PIPE FISH (~ 114O1' MB CMT RET @ 11655' CMT RET @ 11960' CMT RET @ 12085' CMT RET @ 12165' CMT RET @ 12330' 9-5/8" @ 12728' SQZD W/4o3 CU FT CMT SQZD W/552 CU FT CMT SQZD W/552 GU FT CMT SQZD W/115 GU FT CMT SQZD W/328 CU FT CMT SQZD W/282 CU FT CMT SQZ PERFS F/10140' - 10145' MD -- COU_APSED CASING AT 11395' MD ( MitrED HOLE IN CASING F/11398' TO 1141 O' MD ) SQZ PERFS F/11680' - 11684' MD SQZ PERFS F/11990' - 11994' MD SQZ PERFS F/12118' - 12122' MD SQZ PERFS F/12180' - 12184' MD SQZ PERFS F/12360' - 12364' MD NOTE: THE WORK SHOWN BELOW 11328' WAS COMPLETED ON 4/8/85 WELL TBUS G-29 ORIGINAL HOLE ABAN DON M ENT SCHEMATIC (6/15/92) UNION OIL COMPANY OF CALIFORNIA (dba UNOCALR E (~ DRAWN' DAC SCALE: NONE EIVED OCT - 5 1992 Alaska Oil & Gas Cons. Oornm~ss~o~ Anchorage G-29 REDRILL 12728'/10536' ETD DaY 1 (6/10/92) 13-3/8" @ 6572' 9-5/8" C @ 12728' COMMENCE OPERATIONS @ 0100 HRS 6/10/92. NU FLOWLINES. NU BOP AND TEST. PU 5" DRILL PIPE AND 9-5/8" CSG SCRAPER, RIH. DISPLACE HOLE W/FIW. POH TO 9912'. PT 9-5/8" CSG TO 3000 PSI. RIG UP ATLAS WL FOR SQZ HOLES. TEST LUBRICATOR. RIH W/PERF GUNS. ATTEMPT TO CORRELATE GUN-CCL/GR FAILED. POH, CHANGE WL TOOLS. RIH. CLOSE ANNULAR & PERF'D SQZ HOLES F/10140'-10145'. POH W/WL. G-29 REDRILL 12728'/10086' ETD DaY 2 (6/11/92) 13-3/8" WINDOW @ 6572' 9-5/8" C @ 12728' CONT'D POOH W/SQZ GUNS. POOH W/D.P. RIH AND SET A CMT RETAINER AT 10,114' WLM. SQZ'D PERFS AT 10,140'-10,145' WITH 350 SXS OF "G" CEMENT. CIP AT 0930 HRS. POOH W/D.P. RAN CBL LOG F/10,114'-9500', TOC @ 9640'. G-29 REDRILL 12728'/10087' ETD DaY 3-5 (6/12-14/92) 13-3/8" WINDOW @ 6572' 9-5/8" C @ 12728' RIH W/WHIPSTOCK PKR, CORRELATED W/WIRELINE, SET PKR AT 10,086'. POOH. RIH W/GYRO AND ATTEMPTED TO CORRELATE, DID NOT ENTER PKR KEY SLOT. SECOND ATTEMPT, SAME RESULT. MODIFIED CENTRALIZERS ON GYRO TOOL, DID NOT ENTER KEY SLOT. MODIFIED TOOL AND ORIENTED PKR. RIH W/WHIPSTOCK AND LATCHED INTO PKR AT 10,086'. CHANGED OVER TO MUD AND MILLED 18" STARTING WINDOW. POOH. MILLED WINDOW F/10,080'-10,083'. POOH. PIN CONNECTION PARTED LEAVING WINDOW MILL AND WATERMELON MILL IN HOLE. RIH, ENGAGED AND RECOVERED FISH. RIH AND MILLED WINDOW F/10,083'-10,087'. BOX CONNECTION PARTED LEAVING WINDOW MILL IN HOLE. RIH, ENGAGED FISH. RECEIVED OOT - § 1992 Alaska Oil & Gas Cons. uommission Anchorage G-29 REDRILL 12728'/10087' ETD DaY 6 (6/15/92) 13-3/8" WINDOW @ 6572' 9-5/8" C @ 12728' POOH W/FISH. RIH W/CONCAVE MILL. MILLED F/10,087'-10,090. WINDOW OPEN. POOH. RIH W/CONCAVE MILL AND WATERMELON MILL. POLISHEDAND SMOOTHED WINDOW. DRILLED TO 10,095'. PERFORMED L.O.T. RECEIVED OCT - 5 1992 Alaska OiJ & Gas Cons. L;ummission Anchorage JUM i2 '92 08:02AM UMOCAL PLAT BAKER , Ala~.ska Oil and [;m~:~ervati on Compri 3001 Po'~upine D~'ive Ancho'~age, Alaska 99501 The ~ollo*ing is a b'r,:Lef summary o'f t, Me .job, ti Oe'~a.~.led histo'Py wi].l be '.included iu bhe subsmq~,e~t 10-40'? fo'Cm. 1, P'ress~.~e tested the 9""5/8" casi~g 'to (~000 psi for 30 min~vteS aqair~s~ the ¢~:~menb .~,etaine'r ,at 11388' ( set squeezed in Al:)'r:L]. 1985), ~?.. ~,'~ho~: ,~q~n~7~'~ r~e'r'f'o'ra'bion!~ f'i'om 10;L40~ to 1014,5' i'll) ( 80G'7~ ~o 80'70~ TUD ). Squeezed 400 cu 'F't o'l" '~(~' ,¢ e r,-.-:.; n 'b ~h'~'OU!lh 'th~ 're~ail'~'~ at :tO18;J' MID, ~, Unstabbed ¢;/t~.: ti'rill pipe w,i, Wi 8..f)~0 p~i p'~'es:~u'¢e below '~he 'the slide va.l. ve in 1;he -re~';aine'r was holding, ':;'" !1 ~o 3000 psi 'fc:)'r 30 6. Pres~.su're tes'be~ 'bhe 9.-,'fiI8" :t;'f you have any questions ¢onoerning ~n],s abando~me¥~C pi. ease c~ll[ ~le 01~ the G'raylii'~g Platform a'O /Z6 - 6633. , ~znoe'rely: JUN ! 2 1,992 ~aska Oil & Gas Oons. Oommission Anchorage 1. Type of request: Abandon X Suspend Alter casing__ Repair well Change approved program m ALA. OIL AND GAS CONSERVATION COMk ~JlON APPLICATION FOR SUNDRY APPROVALS 2, Name of Operator Union Oil of California (UNOCAL) Operations shutdown Re-enter suspended well Plugging Time extension Stimulate Pull tubing Variance Perforate Other 5. Type of Well: Development X Exploratory 3. Address Stratig raphic P. O. Box 196247, Anchorage, Alaska 99519 Sen/ice 4. Location ofwellat surface Leg #4, Conductor #18, Grayling Platform 1837' FSL and 1438' FEL, Section 29, T9N, R13W, S.M. At top of productive interval At effective depth At total depth 308' FNL and 1996' FEL, Section 30, T9N, R13W, S.M. Plugs (measured) 12. Present well condition summary Total depth: measured true vertical 12733' feet 9927' feet Effective depth: measured 11328' feet Junk (measured) true vertical 8880' feet Casing Length Size Cemented Structural Conductor 911' 20" 1814 sxs Surface 6572' 13- 3/8" 4110 sxs Intermediate Production 12728' 9- 5/8" 1575 sxs Liner 6. Datum elevation (DF or KB) 103' RKB above MLEW feet 7. Unit or Property name Trading Bay Unit 8, Well number G-29 9, Permit number 84-186 10, APl number 50-733-20374 11, Field/Pool J~ c.~r,~ ,l~i~e,r,/~em lock L.I' I V.I:U MAY 1 3 1992 Alaska 0ii & Gas Cons. (;0mmissi0~ ' Measured depth Anch°ra~rue vertical depth 911' 911' 6572' 5608' 12728' 9926' Perforation depth: measured 11680'-11684'; 11990'-11994'; 12118'-12122'; 12180'-12184'; 12360'-12364' true vertical Each perf interval was isolated by cmt ret & sqzd w/"G" cmt 9129' - 9133'; 9355' - 9359'; 9448' - 9452'; 9495' - 9499'; 9632' - 9636' Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal X__ Detailed operations program__ BOP sketch X__ 14. Estimated date for commencing operation ~15, May 25, 1992 16, If proposal was verbally approved Oil X__ Gas __ Name of approver Date approved Service ! 17,,~i~ I hereby cfrtify that the foreg,0, ing is true and correct to the best of my knowledge. ned G LD ~_)'~'a~~.~~-~3~"~- Title Regional Drilling Manager FOR COMMISSION USE ONLY Status of well classification as: Suspended Date Conditions ol~ approval: NoUfy Commission so representaUve may witness Plug Integrity _.~ BOP Test m Location clearance __ Mechanical Int~:j'rity Test__ Subsequent form required 10- Approved by the order of the Commission SIGNED BY C. SMITH Approval No. ,----- I .......... C~mmissioner Date ~ ~'/~¢~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TI~DING BAY UNIT TBUS G-29 ORIGINAL HOLE ABANDONMENT PROCEDURE 1. Shoot squeeze holes at 12360' to 12364'. set a cement retainer at 12330'. Squeeze with 282 cu ft cement. 2. Shoot squeeze holes at 12180' to 12184'. set a cement retainer at 12165'. Squeeze with 328 cu ft cement. 3. Shoot squeeze holes at 12118' to 12122'. set a cement retainer at 12085'. Squeeze with 115 cu ft cement. 4. Shoot squeeze holes at 11990' to 11994'. set a cement retainer at 11960'. Squeeze with 552 cu ft cement. 5. Shoot squeeze holes at 11680' to 11684'. set a cement retainer at 11655'. Squeeze with 552 cu ft cement. 6. Set retainer at 11328'. Squeeze with 59 cu ft cement to abandon drill pipe fish a hole in 9-5/8" casing. Note: Steps #1 thru ~6 were completed in April 1985. Steps #1 thru #5 were isolation squeezes that were not drilled out. During the squeeze in Step #5, the 9-5/8" casing collapsed around the drill pipe. Step #6 was done to abandon the fish and a hole milled in the casing during recovery operations. 7. Skid Rig #55 over TBUS G-29, Conductor 18, LEG #4. 8. Nipple up and test BOPE to 3000 psi. 9. Run bit and scraper in 9-5/8" casing to 11328' ETD. 10. Shoot squeeze holes from 10065' to 10069'. Set a cement retainer at 10055'. Squeeze with 250 sxs cement to complete the abandonment of the original hole. 11. Shoot squeeze hole from 9950' to 9954'. set a cement retainer at 9925'. Squeeze for casing stabilization 250 sxs cement. Drill out to 10055' (cement retainer~~ [IV [ D 12. Set casing whipstock and mill window at 10000'. MAY ] 3 ]992 13. Drill 10 ' of new formation and run leak off test~lS.ka 0i~ & Gas Cons. uummis$i~ Squeeze, if necessary. Begin redrill. ~chorag~ MAXIMUM SHUT-IN BOTTOMHOLE PRESSURE IS 3950 PSI AT 9450' TVD. 28" @ 324' 20"@911' 13-3/8" @ 6572' Z (::;MT RET @ 10055' ,/ CMT RET @ 1"1"328' ....... DRILL PIPE FISH @ 11401' MD CMT RET @ 11655' CMT RET @ 11960' CMT RET @ 12085' CMT RET @ 12165' CMT RET @ 12330' 9-5/8" @ 12728' KB @ 0.0' SQZD W/290 · CU FT CMT ~,,~ 5QZD W/, 9 CU FT SQZD W/552 CU FT CMT SQZD W/552 CU FT CMT SQZD W/115 CU FT CMT SQZD W/328 CU FT CMT SQZD W/282 CU FT CMT L RECEIVED MAY 1 199 _ .Oil & Gas Cons. Commissioa .chorag8 -- SQZ PERFS F/9950' - 9954' MD SQZD WITH 290 CU FT CMT SQZ PERFS F/10065' - 10069' MD COLLAPSED CASING AT 11395' MD ( MILLED HOLE IN CASING F/11308' TO 1141 O' MD ) SQZ PERFS F/11680' - 11684' MD SQZ PERFS F/11990' - 11994' MD SQZ PERFS F/12118' - 12122' MD SQZ PERFS F/12180' - 12184' MD SQZ PERFS F/12360' - 12364' MD NOTE: THE WORK SHOWN BELOW 11328' WAS COMPLETED ON 478/85 WELL TBUS G-29 ORIGINAL HOLE ABAN DON M ENT SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 5-10-92 KB @ O.0' 28" @ 324' 20" @911' 13-3/8"@ 6572' ,,/ CMT RET @ 11328' DRILL PIPE FISH @ 11401' MD (3MT RET @ 11655' CMT RET @ 11960' CMT RET @ 12085' CMT RET @ 12165' CMT RET @ 12330' 9-5/8' @ 12728' // SQZD W/552 CU FT CMT SQZD W/552 CU FT CMT SQZD W/115 CU FT CMT SQZD W/328 CU FT CMT SQZD W/282 CU FT CMT COLLAPSED CASING AT 11395' MD ( MILLED HOLE IN CASING F/11398' TO 1141 O' MD ) SQZ PERFS F/11680' - 11684' MD SQZ PERFS F/11990' - 11994' MD SQZ PERFS F/12118' - 12122' MD SQZ PERFS F/12180' - 12184' MD SQZ PERFS F/12360' - 12364' MD WELL TBUS G-29 ORIGINAL HOLE IDRAWN: DAC EXISTING CONDITION (APRIL 8, 1985 ) ISCALE: NONE '_.- ElDDATE : 5-10-92 UNION OIL COMPANY OF CALIFORNIA (dba UN(~C~cL~. F )v MAY 1 ) 1992 Alaska Oil & Gas Cons. Gommission Anchorage BELL NIPPLE I FLOWLINE 3" KILL LINE WITH TWO 2" 5M VALVES KILL LINE FROM MUD PMP & CEMENT UNIT 13-5/8' 3000 PSI ANNULAR ,. [ I I PIPE RAMS BLIND RAMS , I I I PIPE RAMS 13-5/8" 5M FLANGE DOUBLE GATE 5M I 13-5/8" 5M FLANGE I 4' CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4' 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE RISER 1 O' 5M x 13-5/8' 5M ADAPTER CAMERON 5M SPOOL I' I RECEIVED ~/,AY 1 3 1992 Alaska 0il & Gas Cons. commission Anchorage 13-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC APP'D: GSB SCALE: NONE DATE: 11-23-91 ) STATE OF ALASKA ALASKA C.~ AND .GAS CONSERVATION CO,,.,)IISSION WELL COMPLETION OR RECOMPLETION 'REPORT AND LOG 1. Status of Well Classification of Service Well . OIL ~iJl GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7, Permit Number UNION 0IL COMPANY OF CALTFORNTA 84-185 . 3. Address 8. APl Number ,. PO BOX 5247 ANCHORAGE AK 99502 50- 733-20374 4, Location of well at surface 9. Unit or Lease Name 1837'N & 1438'W o¢ SE Cor., Sec. 29, TgN, R13W, SM. Trading Bay Unit At Top Producing Interval .................. 10. Well Number N/A LC<L:,.,,, iONS VE'~iFi.Eb 6-29 At Total Depth! SuF¢ ~ 11. Field and Pool ~08~'St & 1996'W of NE Cot., Sec. 30, T9N, R13W, "5. Elevation In feet (indicate KB, DF, etc.) I 6. Lease Designation and Sera No ~,L.-' '-~2T:.:ZZZ.':~ rvloAtthur Rivet Field RT 99' MSLI ABL-17594 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116' No. of Completions 01-28-85 03-22-85 04-10-8.5I ....... feet MSLI -0- 20. Depth where SSSV set 21. Thickness of Permafrost 17. Total Depth (MD+TVD) 18. Plug Ba_ck_~epth (MD+TVD) 19. Directional Survey I 12,735'MD+9930'T¥] I~~MD+8900'liV~S~ NO [] N/A feetMD 22. Type Electric or Other Logs Run DIL/MSFL/GR/CAL/SP, CNL/LDT/CAL/GR, EPT/GR, SHDT/GR/CAL, D_TL/GR/P_-/~I , RTl /RHC/P.~I /~R/$P~ P. RI /CCI /RR/VRI 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Butt 911' 25,, 1814 sxs cl "G" ___ 13 3/8" 68-61# K-55 Butt 5572' 17 1/2" 6414 sxs cl "G" ___ 9 5/8" 47# S-95&N80 Butt .12,728' 12 1/4" 1575 sxs cl "G" ___ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ., . interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE NONE 26. ACID, FRACTURE; CEMENT SQUEEZE, ETC. . . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · , , SEE ATTACFIED ADDENDUM , 27. PRODUCTION TEST DateN/AFirst Production . Method qf Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKESlZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl {corr) Press.' 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ,:'!~. 1:l;1 ,:: "- ..,: :-q:;? ;: Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 3O. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/G Zone 11005 ' 8658' ~RAR~E-Y-ABANDONED~TE~G-DON~. T/G Oil Zone 11429' 8951' T/Hemlock 11968' 9338' ~t ~'V - ~ ~ T/W. Foreland 12589' 9814' TD 12733 ' 9930 ' 31. LIST OF ATTACHMENTS 32. I hereby certify.,~that the~foregoi~,is true and correct to the best of my knowledge Signed Lawrence O. Cutting Title ENVIRONMENTAL Date 04-24-84 SPECIALTqT INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types 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 spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing 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.). Item 23' Attached supplemental records for this 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". UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE TRADING BAY UNIT WELL NO. G-29 FIELD MCARTHUR RIVER FIELD API# 733-20374 LOCATION: (a-t- Sur-fa-c-e) 1837' N & 1438' W of SE Corner Section _29, _T_gN, Ri_3_W_,__ sM __ _ __ .Leg _4_, Conductor 18 PERMIT NO. 84-186 SERIAL NO. ADL 17594 TD 12733' TVD 9927' DEVIATION- (BHL)-3135' N & 5838" W-of Surf COMPANY ENGINEER_ .W_agen_hoff. er_, Spir_o _L~$_ SPUD DATE 12/19/84 SHEET A ~~ PAGE NO. 1 COMP. DATE 4/11/85 CONTRACTOR CONSERVATIVE RIG NO. #55 TYPE UNIT -National 1320 UE DRILL PIPE DESCRIPTION 5" E/ S135 E[EVAilONS: WATER DEPTH-i'~' RT TO OCEAN FLOOR 224' RT TO MLLW 99' RT 70 DRILL DECK 19.30' RT TO PRO~CTIO~ DE~< ~ 4_--~;~_r APPROVE~ ~.-~-~___ CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 94# Buttress H-40 911' Cmtd w/ 1814 sx "G" cmt w/ additives 13 3/8" 61#/68# Buttress K-55 6572' Cmtd w/ 4110 sx "G" cmt w/ additives 9 5/8" 47# Buttress S-95/N-80 12728' Cmtd w/ 1575 sx "G" cmt w/ additives PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 3/30/85 12360'-12364' 12636' Isolation Squeeze Sqzd w/ 500 sx "G" cmt 4/01/85 12180'-12184' 12155' Isolation Squeeze Sqzd w/ 500 sx "G" cmt 4/01/85 12118'-12122' 12155' Isolation Squeeze Sqzd w/ 500 sx "G" cmt 4/03/85 11990'-11994' 11665' Isolation Squeeze ......... S_qzd w/ 500 sx "G" cmt Isolation Squeeze Sqzd w/ 500 sx "G" cmt 4/03/85 11680'-11684' 11665' INITIAL PRODUCTION - DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS No Production JUL i0 i986 WELL HEAD ASSEMBLY TYPE: Cameron Iron Works CASING-HEAD: 20" SOq X 21 1/4" 2K_ WF HOusing ,-,,,~o,~,~ u. & Gas-Cons. COmmissio A~¢nOrago CASING SPOOL: _Type WF 21 1/4" 2K X 13 5/8" 5K TUBING HEAD: N/A TUBING HANGER: 13 5/8" X 11" 5K DCB w/ 2-2" 5K Side Outlets TUBING HEAD TOP: 11" 5K Flange MASTER VALVES: 11" 5K X 4" 5K single solid block valve tree with 2-4" 5K outlets cHRISTMAS TREE TOP CONN: 4 1/2" 8rd UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 289' TOF/ 350' TD A DAY 12/19/84 33" ~ 283' DAILY COST: $ 55,300 CUM COST: $ 55,300 AFE AMT: $5,085,000 COMMENCED OPERATIONS ~ 0800 HRS, 12/19/84. SKIDDED RIG OVER CONDUCTOR #18. WORKED ON PRIME MOVERS. WORKED ON MUD PUMPS. RN SHOE 3T OF 28" OD, 1 1/8" WALL ASTM 516 GRADE 70 DRIVE PIPE THRU TABLE & WELDED ON ST #2 (+4 HRS). STOOD BACK BOTH 3TS. CUT 30" I RISER OFF 33" CONDUCTOR AT SUBDECK BELOW WELLROOM FLOOR. 289' TOF/ 350' TD 3 DAY 12/21/84 33" ~ 283' DAILY COST: $ 13,200 CUM COST: $ 85,680 AFE AMT: $5,085,000 FABRICATED 2 RINGS TO SEAL 28" DRIVE PIPE TO WELLROOM FLOOR & TO SEAL 28' X 33" ANNULUS SUBDECK BENEATH IT. OFFLOADED BOAT W/ ADDITIONAL PIPE & DRIVE HAMMER. WELDED & RAN STS #7-9, TAGGING TOP FILL ® 281.64' & SET DOWN FULL WT ~ 284.14' (33" SHOE ¢ 283.5'). BEGAN RU HAMMER IN RRER TO DRIVE. 289' TOF/ 350' TD 4 DAY 12/22/84 33" ~ 283' D~ILY COST: $ 69,975 CUM COST: $ 155,655 AFE AMT: $5,085,000 FINISHED RU HAMMER & SPENT 5 HRS ATTEMPTING TO START HAMMER. DERTERMINED THROTTLE TO BE DEFECTIVE. REMOVED & CLEANED DIRT OFF OF THROTTLE WHILE WAITING FOR NEW ONE TO BE FLOWN FROM ANCHORAGE. INSTALLED NEW THROTTLE (DOWN 6 HRS WAITING ON IT) & BEGAN DRIVING 28" PILE. CON'T DRIVING 28" CONDUCTOR TO "REFUSAL" ® .324.36' W/400 BLOWS/FT ~ WHICH TIME PRODUCITON REQUESTED CEASE DRIVING DUE TO PARTING 33" CONDUCTOR WELD ~ SUBDECK APPROX AN ADDITIONAL 1/2". RD PILE DRIVING HAMMER & ASSOC EQUIP. GRAYLING RLA~FORM G-29, CONDUCTOR 18 28" DRIVE RIPE DETAIL ALL PIPE IS 28" OD, A155 KCF 70 (ASTM 516, GRADE 70) THAT WAS ROLLED BY HOUSTON RIPE BENDING FOR WRSS NUCLEAR REACTOR PRESSURE VESSELS~ PURCHASED THRU LB FOSTER CO IN SEATTLE FRoM STOCK IN SALT LAKE CITY- WALL THICKNESS VARIED AS DETAILED; ALL JTS WELDED W/ 7018 ROD. 3T FROM RT # DESCRIPTION LENGTH BTM TOP 1 28", 1 1/8" WALL W/ 40.15' 324.36' 284.21 36" LONG, 29 1/2" OD DRIVE SHOE 2 28" 1 1/8 WALL 40.03' 284.21 244.18 3 28" 1 1/8 WALL 40.03' 244.18 204.15 4 28" 1 1/8 WALL 40.03' 204.15 164.12 5 28" 1 1/8 WALL 40.03' 164.12 124.09 6 28" 1 1/8 WALL 40.03' 124.09 84.06 7 28" 1 5/16 WALL 17.50' 84.06 66.56 8 28" 1 5/16 WALL 18.02' 66.56 48.54 9 28" i 5/16 WALL 17.14' 48.54 31.40 l0 28" i 1/8 WALL 40.03' 31.40 -8.63 RECEIVED JUL 1 o 1986 Alaska Oil & Gas Cons. ¢ommiss[ol/ Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 3 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 289' TOF/ 350' TD 5 DAY 12/23/84 33" 28" ~ 324' DAILY COST: $ 5,060 CUM COST: $ 160,715 AFE AMT: $5,085,000 367' TD/ 290' ETD (TOP FISH) 6 DAYS 1/13/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 71,670 CUM COST: $ 232,385 AFE AMT: $5,085,000 367' TD/ 290' ETD (TOP FISH) 7 DAYS 1/14/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 91,620 CUM COST: $ 324,005 AFE AMT: $5,085,000 CUT OFF 28" DRIVEN CONDUCTOR fl.77' BELOW TOP TO OF RT. WELDED RING IN BETWEEN 28" & 33" CONDUCTORS & WELDED 3 1/4" WIDE RING PLATE TO 28" ® SUBDECK LEVEL TO RESEAL OFF LEG #4. WELDED RING PLATE TO 28" 8 WELLHEAD ROOM FLOOR LEVEL TO SEAL ~ THAT LEVEL TOO. CUT HOLE & INSTALLED NIPPLE FOR RISER DRAIN IN 28" ~ WELLROOM LEVEL. CUT HOLE IN 28" BELOW RT & INSTALLED FLOWLINE. REINSTALLED V-DOOR GUIDES THAT HAD BEEN REMOVED TO PU HAMMER. RELEASED CREWS UNTIL AFTER THE 1ST OF THE YEAR. RECOMMENCED G-29 OPRS ~ 0000 HRS, 1/13/85. RIH W/ JET SUB (ONE SIDE PORT & ONE BTM PORT) ON 1STD 3 1/2" DP, REMAINDER 5" DP. WASHED SAND & CMT FROM TOP FILL ® 282'. PAST TOP OF FISH ¢ 289', TO 322'. DUMPED RETURNS UNTIL HOLE FULL OF GEL-WATER MUD. POH & PLUGGED SIDE PORT IN JETY SUB. RIH & WASHED DOWN TO TOP SHOT CAN ~ 330' CIRC CLEAN & POH RIH W/ SPEAR ON 20" LIP ~UIDE W/ SPEAR PIN ~ STABBED INTO 6" DP FISH. PULLED 260,000# ON FISH W/O MOVING IT. POH. RIH W/ 1 JT 24" WASHPIPE & 16" BOOT BASKET. WASHED DOWN TO APPARENT BOULDERS ~ 307'. CONT WORKING DOWN TO 309' & ROTATED FOR SEVERAL HOURS W/ NO PROGRESS. POH, NOTING LITTLE WEAR ON SHOE & ONLY SMALL AMTS OF SAND, GRAVEL, & METAL SHAVINGS IN BOOT BASKET. RIH W/ 1 JT 16" WASH PIPE & BOOT BASKET. WASHED DOWN TO 325'. POH, NOTING ENTIRE SHOE WORN' OFF & JUNK BSKT FULL OF SHARP ROCK CHIPS & SOME METAL JUNK. WASHED OVER FISH W/ 16" SHOE TO 326'. POH, NOTING MILL WORN OUT & JUNK BSKT FULL OF ROCK CHIPS. RIH W/ 16" SCALLOPED SHOE ON 2 JTS 16" WASHPIPE & CONT WASHING OVER FISH TO 328'. SWEPT HOLE W/ VISCOUS PILL & POH, LD 16" WASHPIPE. PU & RIH W/ 24" SHOE ON 1JT 24" WASHPIPE & CO TO 329' SWEEPING HOLE W/ VISCOUS PILLS. LOST CIRC & COULD NOT KEEP HOLE FULL. SPOTTED LCM PILL ON BMT & UNSUCCESSFULLY ATTEMPTED TO FILL HOLE. POH, LD WASHPIPE. RIH W/ OE DP TO 329' & SPOTTED 108 SX CLASS "G" CMT W/ 2% CACL2 MIXED W/ FIW ON BTM, ADDING 1 SX FLOSEAL TO FINAL 50 SX. CIP ~ 2330 HRS. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 367' TD/ 290' ETD (TOP FISH) 8 DAYS 1/15/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 46,765 CUM COST: $ 370,770 AFE AMT: $5,085,000 367' TD/ 340' ETD (tOP FISH) 9 DAYS 1/16/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 33,223 CUM COST: $ 403,993 AFE AMT: $5,085,000 367' TD/ 340' ETD (TOP FISH) 10 DAYS 1/17/85 33" ® 284' 28" $ 324' DAILY COST: $ 33,440 CUM COST: $ 437,433 AFE AMT: $5,085,000 367' TD/ 340' ETD (TOP FISH) ii DAYS i/i8/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 37,730 CUM COST: $ 475,163 AFE AMT: $5,085,000 POH & WOC 4 HRS. RIH W/RERUN 24" DRAG-TOOTH SHOE ON 1JT 24" WASHPIPE. TAGGED CMT ~ 298' & CO TO 329'. HOLE STAYED FULL. RIH W/NEW 24" DRAG-TOOTH SHOE, i ST 24" & i 3T 16" WASHPIPE. CO FILL F/ 325-329' & MILLED THRU EDGE OF TOP SHOT CAN F/ 329-332'. SLIPPED COMPLETELY OVER SHOT CAN & CONT WASHING OVER TO 333'. SWEPT W/ VISCOUS PILLS & POH. RIH W/ NEW 24" FLAT-BTM SHOE ON i JT 24" & i JT 16" WASHPIPE. CO FILL 328-333' & WASHED OVER TO 339'. SWEPT HOLE W/ VISCOUS PILL & POH. RIH W/ NEW i6" SCALLOPED SHOE ON 2 JTS 16" WASHPIPE TO 325' (HISTORICALLY TIGHT SPOT) W/O TAGGING ANY CMT. POH. WASHED OVER FISH TO 339' W/ 24" WASHPIPE. RECOVERED 49' OF 6" PIPE PLUS 11' SLICE OF SHOT CAN. CONT WASHING FISH AT 339-340' W/O SUCCESS. RAN 14" MAGNET FOR POSSIBLE SUNK. WASHED OVER FISH TO 340' W/ 24" WASHPIPE. WORKED MAGNET & POH W/ NO RECOVERY. RIH W/ #12 (24" DRAG TOOTH). TAGGED TOP OF SHOT CAN SLIVER ~ 329'. SLIPPED PAST & MILLED W/O SUCCESS ~ 340' TRIPPED FOR I6" WASHPIPE & SHOE #13 (16" DRAG TOOTH). MILLED ON JUNK " 331-341'. TRIPPED FOR 24" WASHPIPE & SHOE #14 (#24 FLAT BOTTOM). MILLED ON SUNK 331-344'. POH. RECOVERED REMAINING 10' SLIVER OF THE TOP SHOT CAN INSIDE 24" WASHPIPE. RIH W/ 24" WASHPIPE & SHOE #15 (24" DRAG TOOTH). MILLED ON 2ND SHOT CAN 341-345' ~ 2400 HRS. MILLED ON 2ND SHOT CAN'W/'MILL #15 (24" DRAG TOOTH) F/ 345-350'. CIRC OUT LEAD SHOT W/ HI-VIS MUD. TRIPPED FOR MILL SHOE #16 (24" FLAT BTM). WASHED & MILLED 350'. TRIPPED TO CHECK FOR FISH - NO RECOVERY. MILLED OVER FISH F/ 350-351'. TRIPPED FOR MILL SHOE #I7 (#i6 SCALLOPED) ON 16" WASHPIPE. WORKED OVER SLIVER OF 2ND SHOT CAN F/ 340-350'. MILLED ON OUNK F/ 350-351'. POH. RECOVERED: 1) 9' SECTION OF 2ND SHOT CAN SLIVER. APPROX 50% OF CIRCUMFRENCE & 2) 3 1/2' of 6" PIPE W/ 2/3 OF FLANGE THAT WAS LOCATED BETWEEN lST & 2ND SHOT CANS. RIH W/ 16" MILL & WASHOVER PIPE TO 351'. DID NOT TAG 2ND HALF SLIVER OF SHOT CAN #2. ATTEMPTED TO LOCATE SAME W/O SUCCESS. POH. RIH W/ MILL #i9 (24" DRAG TOOTH). MILLED & WASHED F/ 351-352'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 5 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 367' TD/ 340' ETD (TOP FISH) 12 DAYS 1/19/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 36,630 CUM COST: $ 511,793 AFE AMT: $5,085,000 367' TD/ 340' ETD (TOP FISH) 13 DAYS 1/20/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 35,130 CUM COST: $ 546,923 AFE AMT: $5,085,000 367' TD/ 340' ETD (TOP FISH) 14 DAYS 1/21/85 33" ® 284' 28" ~ 324' DALLY COST: $ 30,348 CUM COST: $ 577,271 AFE AMT: $5,085,000 367' TD/ 352' ETD 15 DAYS 1/22/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 45,725 CUM COST: $ 622,996 AFE ~4T: $5,085,000 MILLED F/ 352-355'. TRIP FOR MILL #20 (24" FLAT BTM). MILLED & WASHED OVER FISH F/ 355- 359'. CIRC HI-VIS PILL. (NOTE: ALL LEAD SHOT IN BTM SHOT CAN CIRC OUT IN MUD.) TRIP FOR MILL #21 (24" FLAT BTM). MILLED & WASHED OVER FISH F/ 359-362 - EST BTM OF SHOT CAN #3. CIRC HI-VIS PILL. TRIPPED FOR 16" SHOE & WASHPIPE. (MILL #22 - SCALLOPED). WORKED 16" WASHPIPE OVER SLICED FISH F/ 344- 362'. POH. RECOVERED 15.6' OF 16" PIPE W/ FLANGE AT MIDPT. (FLANGE-BTM OF SHOT CAN #2, TOP SHOT CAN #3) PLUS 7.4' OF 20" SHOT CAN #3 -APPROX 50% SLIVER. RAN 14" MAGNET TWICE. RECOVERED SMALL CHUNKS OF STEEL ON 1ST RUN, NONE ON 2ND. TRIPPED FOR 16" WASHPIPE W/ 24" CUT LIP GUIDE. WORKED F/ 340-360' W/O RECOVERY. RAN IMPRESSION BLOCK TO 362'. 18 1/2" BLOCK SHOWED MARKS ON OUTER EDGE ONLY. RIH W/ 16" WASHPIPE & BENT SINGLE. ATTEMPTED TO CATCH SHOT CAN #2 & #3 SLIVERS FROM SIDE OF HOLE - NO RECOVERY. RIH W/ 17 1/2" BIT ON 1 1/2° BENT SUB. UNDER REAMED HOLE F/ 335-337'. TRIPPED FOR 2 1/2° KS. UNDER REAMED & ESTABLISHED LEDGE F/ 337-341', TOF, USING 17 1/2" BIT. TRIPPED FOR 16" WASH PIPE & MODIFIED CUT LIP SHOE. ATTEMPTED W/O SUCCESS TO WORK OVER TOP OF FISH. TRIPPED FOR #23, 16" SHOE CHANGE. WORKED OVER FISH-COULD NOT PRY LOOSE. TRIPPED TO LD STABILIZERS ABOVE KS. WORKED OVER TOP OF FISH W/O PRYING LOOSE. TRIPPED FOR 24" WASH PIPE & MILL SHOE ON 2 1/2° KS. WORKED ON FISH ~ 341'. APPEARED TO POP FISH F/ WALL, COULD NO LONGER SET WEIGHT ON FISH. RAN TO TD @ 362'. TOOK 8000# WEIGHT TO GET TO TD DURING LAST 10'. POH. NO RECOVERY IN 24" WASH PIPE $ 2400 HRS. RIH W/ 16" WASH PIPE & MILL SHOE TO TO ~ 362'. NO RECOVERY OF FISH. RIH W/ 17 1/2" BIT W/ 2 1/2° KS & STABILIZERS. REESTABLISHED LEDGE AT 340'. UNDER REAMED HOLE F/ 340-350'. KELLY SWIVEL FAILED. LAID DOWN SOME. PICKED UP RENTAL SWIVEL F/ BS INC. RIH W/ 17 1/2" BIT, 2 1/2° KS & STABS. UNDER REAMED F/ 350'- 351'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 367' TD/ 352' ETD 16 DAYS 1/23/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 31,329 CUM COST: $ 654,325 AFE AMT: $5,085,000 367' TD/ 362' ETD 17 DAYS 1/24/85 33" ~ 284' 28" ~ 324' DAILY COST: $ 98,097 CUM COST: $ 752,422 AFE AMT: $5,085,000 367' TD/ 361' TOF 18 DAYS 1/25/85 33" ~ 284' 28" ~ 324' 67 PCF/ 84 SEC DAILY COST: $ 39,105 CUM COST: $ 791,527 AFE AMT: $5,085,000 CONT CUTTING SHOULDER W/ 17 1/2" BlT #1RR ON 2 1/2° KS TO WASH PIPE & MILL SHOE #21RR W/ PIECES OF DRLG LINE WELDED UP INSIDE TO ACT AS A CATCHER. ROTATED & WORKED DOWN F/ 351- 360'. POH. NO RECOVERY, DRLG LINE INSIDE SHOE MOSTLY TORN OFF. REPLACED & BEEFED UP DRLG LINE CATCHERS INSIDE SHOE & RIH. WORKED 24" WASH PIPE W/O ROTATING OVER FISH DOWN TO 359'. POH & CUT OFF DRLG LINE CATCHERS. RIH W/ SAME SHOE AGAIN & WASHED OVER FISH 357-363'. POH TO CHANGE OUT WORN SHOE. RIH W/ 24" MILL SHOE #24 & WASHED OVER 3UNK TO 363'. CONT WASHING DOWN TO 364' W/ 24" SHOE #24. POH TO CHNG SHOE, NOTING HEAVY SCARRING ON OD OF SHOE THE BTM 2', AS W/ PREVIOUS RUN. RIH W/ 16" WASH PIPE & 17 1/4" OD CUT-LIP SHOE (MODIFIED MILL SHOE #22 RR). BRIEFLY WORKED SHOE ~ 363', THEN POH DUE TO EXCESSIVE BINDING & TORQUE. RAN 14" MAGNET TO 363' & RECOVERED 1 PIECE OF JUNK. RIH W/ NEW 16" MILL SHOE #25 & WASHED THRU JUNK 360-363' & FELL THRU TO 364'. POH & LD 16". RIH W/ NEW 24" SHOE #26 TO 364', TAGGING TOP OF BTM SHOT CAN PIECE ~ 354' BUT UNABLE TO ENGAGE. POH. RIH W/ SAME 24" ASSY BUT W/ 2 1/2° KICK SUB ABOVE WASH PIPE. WORKED FISH OFF WALL ~ 354' & WORKED OVER OR PUSHED DOWN TO 360'. POH & REMOVED KICK SUB. RIH W/ SAME 24", TAGGING FISH ¢ 360' & WASHING OVER TO 364'. POH W/ 16" SHOE #27 ON 16" WASHPIPE. TAGGED JUNK ~ 358' &" WORKED DOWN TO 364'. ROH. CONT ROH W/ 16" SHOE #27, RECOVERING 4.30' RIECE OF SHOT CAN UR INSIDE WASH RIRE. RIH W/ 14" MAGNET, ROH RECOVERING HANDFUL OF SMALL JNK & SHAVINGS F/ 362'. RAN 16" GLOBE. JUNK BSKT ON WASH RIRE & WORKED OVER JUNK 362-364'. ROH-NO RECOVERY, ALL FINGERS BROKEN OUT OF BSKT. RAN 24" LEAD IMRRESSION BLK TO 362', MAINTAINING ORIENTATION. ONLY MARK ON IT WAS ARRROX 1" X 4" RECTANGLE W/ ONE OF THE LONG EDGES CONCAVE. MARK WAS ARRROX 3" F/ EDGE OF BLK ON W. SIDE OF HOLE. RIH W/ 22" CONCAVE MILL. MILLED ON JNK 362-363' & ROH, NOTING SEVERE WEAR ON CNTR 9" OF MILL (INDICATIVE OF CENTERING OVER NECK OF HOLE ORENER). RAN 14" MAGNET ON BENT JT OF DR TO 362', REC DBL HANDFUL OF SMALL JNK. RERAN MAGNET TO 364', REC HANDFUL OF SM JNK. RAN 24" LEAD IMRRESSION BLK TO 360', ARREARING TO SHOW TOR EDGES OF SHOT CAN RIECES. RU & RIH W/ 24" SHOE #29 ON 24" WASH PIPE. CO JNK 361-364' & POH. RAN MAGNET TO 361', TAGGING LEDGE ~ 351' ON THE WAY. POH, REC DBL HANDFUL OF SM JNK. PU & RIH W/ NEW 16" SHOE #30 ON 16" WASH PIPE. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 367' TD/ 300' CMT PLUG 19 DAYS 1/26/85 33" ~ 284' 28" ~ 324' 67 PCF/ 84 SEC DAILY COST: $ 52,649 CUM COST: $ 844,176 AFE AMT: $5,085,000 348' TD 20 DAYS 1/27/85 33" ® 284' 28" ® 324' 67 PCF/ 45 SEC DAILY COST: $ 29,289 CUM COST: $ 873,465 AFE AMT: $5,085,000 CONT RIH W/ SHOE #30 ON 16" WASH PIPE, TAGGING LEDGE ~ 351' AGAIN ON WAY DN (POSS SECTION OF BTM SHOT CAN STILL IN WALL). TAGGED TOP OF FISH ~ 363' & WASHED DOWN 15" TO 364'. PU & WENT BACK DOWN, ROLLING OFF FISH ~ 363', FALLING 11" & WASHING THRU LOOSE JNK ANOTHER 4" SEVERAL TIMES. POH. RAN 14" MAGNET TO 362' & RECOVERED DBL HANDFUL OF SM JUNK. RAN 11 3/4" X 8" OVERSHOT TO 363', UNSUCCESSFULLY ATTEMPTING TO GET OVER NECK OF HOLE OPENER FISH. POH TO CHECK TOOL. REREAN SAME OS BELOW 1 1/2° BENT SUB, BUT STILL COULD NOT GET OVER FISH. POH. RIH W/ TAPER TAP ON 20" SPEAR GUIDE. POH DUE TO GUZDE SHEARING PREMATURELY. REPINNED & RERAN SAME ASSY TWICE MORE, UNSUCCESSFULLY. RERAN SAME ASSY A 4TH TIME ADDING A BENT JT OF DP ABOVE GUIDE-STILL NO SUCCESS. TAP APPEARS TO SIT ON FISH EACH TIME BUT CAN'T PEN ENOUGH TO ENGAGE. TAP WENT AS DEEP AS 370' NEXT TO FISH WHEN IT SLIPPED OFF. RIH W/ 24" LEAD IB TO 369'. POH, NOTING MARK OF PARTIAL FLG W/ BOLT HOLE. RIH W/ 14" MAGNET TO 361', BUT COULD NOT GET DEEPER. POH, NO REC. RIH W/ BENT JT OF DP ON OE DP. ROTATED & SET DN EVERY 45° TO DETERMINE ORIENTATION OF FISH & WASHED OUT HOLE BESIDE IT. SET DN ~ 361' (ON FISH) IN N87°W DIP & WENT TO 368' IN HOLE NEXT TO FISH ~ N87°E. POH. RAN 25" HOLE OPENER TO SHOE ~ 324' TO ENSURE DRIFT ID OF 28" CSG. RIH W/ BENT JT OF DP ON OE 5" DP TO 368' & EQUALIZED 800 CMT PLUG (CLASS "G" W/ 2% CACL2 MIXED W/ FIW) ON BTM, SLOWLY PICKING UP & ROTATING AS CMT WAS PUMPED TO ENSURE STABILIZATION OF REMAINING JNK. CIP ~ 2245 HRS, 1/26/85. PU TO 300' & CIRC OUT EXCESS CMT. POH. WOC 3 1/2 HRS. RIH W/ 17 1/2" BIT #1 RR & TAG CMT $ 300'. CO CMT TO 322' & POH. RIH W/ 25" HOLE OPENER & CO CMT TO 322'. CIRC CLEAN & POH. WOC TOTAL OF 21HRS F/ CIP TIME. PU & RIH W/ 12 1/4" BIT #2 DYNA- DRL (BHA #1) & SIDETRACK HOLE 322-348'. CIRC CLEAN. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 562'/ 214' 21 DAYS 1/28/85 33" ~ 284' 28" ~ 324' 68 PCF/ 40 SEC DALLY COST: $ 38,955 CUM COST: $ 912,420 AFE AMT: $5,085,000 917'/ 355' 22 DAYS 1/29/85 33" ~ 284' 28" ® 324' 70 PCF/ 64 SEC DAILY COST: $ 27,870 CUM COST: $ 940,290 AFE AMT: $5,085,000 917' 23 DAYS 1/30/85 33" ~ 284' 28" ~ 324' 71PCF/ 43 SEC DAILY COST: $ 23,969 CUM COST: $ 964,259 AFE AMT: $5,085,000 917' 24 DAYS 1/31/85 33" ~ 284' 28" ~ 324' 71 PCF/ 43 SEC DAILY COST: $ 29,500 CUM COST: $ 993,759 AFE AMT: $5,085,000 POH. RIH W/ SAME ASSY MINUS THE 24" STAG & CONT SIDETRACKING HOLE W/ 12 1/4" BIT TO 390'. CIRC CLEAN & POH. RIH W/ 17 1/2" HOLE OPENER W/ 12 1/4" STAB BELOW & OPENED HOLE 322' TO 381'. CIRC CLEAN & POH. RIH & OPENED 17 1/2" HOLE TO 25" F/ 317--375'. RAN GYRO SINGLE SHOT SURVEYS EVERY 10' F/ TD TO 10' INSIDE 28" SHOE. RIH & DRLD 17 1/2" HOLE 381-562', TAKING GYRO SINGLE SHOT SURVEYS. CONT DRLG & SINGLE SHOT GYROING 17 1/2" HOLE TO 917'. FOR EVERY 2-3 HRS DRLG, HAD TO SHUT DOWN & SHOVEL OUT MUD DITCH FOR APPROX 1 HR DUE TO POOR DITCH DESIGN. POH. PU 25" HOLE OPENER & OPENED 375-638'. AGAIN STOPPING EVERY 2-3 HRS TO SHOVEL OUT MUD DITCH. OPENED 17 1/2" HOLE TO 25" HOLE F/ 638-917'. CLEANED MUD DITCH AS NECESSARY. CIRC. TRIPPED FOR REAMING ASSY #7. REAMED TIGHT SPOTS F/ 325-347'. CIRC. RIH TO TD ® 917'- CIRC & COND MUD. POH. RIGGED & RAN 20" CSG ~ 2400 HRS RAN 20" 94# CSG TO 334'. CSG STOPPED - COULD NOT WORK DEEPER. POH LAYING DOWN 20" CSG. RIH W/ REAMING BHA #7. REAMED 25" HOLE F/ 324-384'. TRIPPED FOR REAMING BHA #8. REAMED 25" HOLE F/ 324-392'. TRIPPED FOR REAMING BHA #9. RIH TO TD ~ 917'. MAKE WIPER TRIP TO CONDUCTOR SHOE ® 324' CIRC. (NO RESTRICTIONS DURING TRIPS.i UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 917' 25 DAYS 2/01/85 33" @ 284' 28" ~ 324' 20"-® 911' 70 PCF/ 40 SEC DALLY COST: $ 119,898 CUM COST: $1,113,657 AFE AMT: $5,085,000 917' 26 DAYS 2/02/85 28" ~ 324' 20" ~ 911' 65 PCF/ 36 SEC RIGGED & RAN 23 JTS 20" 94# BUTTRESS CSG. LENGTH W/ ACCY'S = 913.55'. FLOAT SHOE ~ 9ii' FC ~ 822'. RIH W/ 5" DP & STAB-IN TOOL. STABBED INTO FLOAT COLLAR. CIRC. PUMPED 50 BBL CAUSTIC H20 FOLLOWED BY 25 BBL FRESH H20 FOLLOWED BY 1584 CF "G" CMT MIXED W/ .75% CFR-2 & 2.25% PHG FOLLOWED BY 230 CF "G" CMT MIXED W/ .75% CFR-2 & 2% CACL2. DISPLACED W/ 29 BBL MUD. CIP ~ 1530 HRS. POH. GOOD CMT RETURNS TO SURF. WOC 6 HRS. CUT OFF 28" COND. CONT BOPE NU & RIG REPAIR. RIH W/ BHA #10. DRLD FC ~ 822'. DISR MUD W/ FIW. TEST BORE & CSG TO 500 PSI FOR 15 MIN - OK. DRLD OUT CMT F/ 853-878'. DALLY COST: $ 22,836 CUM COST: $1,136,493 AFE AMT: $5,085,000 917' 27 DAYS 2/03/85 28" ~ 324' 20" ~ 911' 66 PCF/ 43 SEC DAILY COST: $ 165,020 CUM COST: $1,158,779 AFE AMT: $5,085,000 2102'/ 1185' 28 DAYS 2/04/85 28" $ 324' 20" ~ 911' 70 RCF/ 46 SEC WELDED ON BRADEN HD TO 20" CSG. TSTD SAME TO 500 PSI - OK. NU BOPE & REPAIRED RIG. DRLD FC ® 822'. DISP MUD W/ FIW. TSTD BOPE & CSG TO 500 PSI FOR 15 MIN. OK. DRLD OUT CMT F/ 853-878'. DRL CMT F/ 878-917' W/ SHOE ~ 911'. DISP FIW W/ MUD. TRIPPED FOR BHA #ii, DRLD i7 i/2" HOLE F/ 917-2102'. SURVEYED AS PER PROGRAM, CIRC. POH FOR KICK OFF BHA. DAILY COST: $ 42,980 CUM COST: $1,201,759 AFE AMT: $5,085,000 F--lC) OOO ¢) Z ITIO ~ -O --.! (/)CD O -- r-I o CT~r- z m --lC-) ~-4 z i o o Z O ::~ o Z Z ITl -r- O [-- m CD (;DO Z 3mE:) z:;:0 mc-) i-4..4 H O m-4 ink,4 o i ~ o cD-< o OO -- Fq hOE;C) --4 ~ CD kO Z I C I ~ hO I C7 m o om m o00 c700 o -r'o Z,--I mE:7 ~ - H · O~' Z O · · O(:27 r- o-< o -- m C7 F- ro c) o ED CD [-- C7 O m O Z .-4 '-0 O -r" · · · o r'q z cz: z I-- Z 0 F~ ~0 m c) o c) z o -o z -< '-0 6") f"rl Z o I m m -4 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 11 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. 6-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4851'/ 379' 33 DAYS 2/09/85 28" ~ 324' 20" ~ 911' 69 PCF/ 46 SEC DAILY COST: $ 49,825 CUM COST: $1,418,145 AFE AMT: $5,085,000 4851'/ O' 34 DAYS 2/10/85 28" ~ 324' 20" ~ 911' 69 PCF/ 43 SEC DAILY COST: $ 33,932 CUM COST: $1,452,077 AFE AMT: $5,085,000 5194'/ 343' 35 DAYS 2/11/85 28" $ 324' 20" ~ 911' 69 PCF/ 48 SEC DAILY COST: $ 41,318 CUM COST: $1,493,395 AFE AMI: $5,085,000 5582'/ 388' 36 DAYS 2/12/85 28" ~ 324' 20" ~ 911' 69 PCF/ 44 SEC DALLY COST: $ 52,935 CUM COST: $1,546,330 AFE AMT: $5,085,000 CONT DRLG TO 4675'. POH TO CHANGE BHA DUE TO LACK OF ANTICIPATED TURN. RIH W/ MUD MOTOR & DRLD TO 4851'. MUD MOTOR APPEARED TO BE LOSING POWER & TELECO TOOL WOULD NOT SEND SURVEY UP WHEN ON BTM, INDICATING REDUCED FLOW THRU lT. POH, LOOKING FOR WASHOUT ABOVE TELECO MWD. CONT POH - FOUND PIN OF BTM DC BUSTED OFF (FATIGUE FAILURE). LEFT 142.30' FISH IN HOLE CONSISTING OF ALL NON-MAG DC'S & STABS, TELECO MWD TOOL, & DYNA-DRILL. TIF ~ 4709'. RIH W/ FISH ASSY: 15 1/4" GUIDE, 10 5/8" OVERSHOT DRESSED W/ 8 1/8" GRAPPLE & CONTROL MILL, BS & OIL JARS. ENGAGED FISH & POH - RECOVERING ENTIRE LOST BHA. ULTRASONICALLY INSPECTED ALL 6 5/8" REG BHA CONNECTIONS AS WELL AS ALL CONNS ON KELLY & ASSOC SUBS, CULLING OUT BHO TOOLS. WHILE MAKING BREAK BELOW KELLY, BROKE OFF PIN IN BTM OF KELLY & LOST DBL PIN SUB & SAVER SUB DOWN HOLE. FISH = 4.44' TOTAL LENGTH. PIN RECOVERED F/ BTM OF KELLY INDICATED EXISTING FATIGUE CRACK. RIH W/ FISH ASSY: 15 1/4" GUIDE, lO 5/8" OVERSHOT DRESSED W/ 6 1/8" GRAPPLE & CONTROL MILL & OIL JARS. ENGAGED FISH & POH - RECOVEREDj' ENTIRE FISH. RIH & REAMED PRIOR DD RUN 4660-4851' & DRLD NEW 17 1/2" HOLE TO 5173'. POH TO CHANGE BHA DUE TO DROPPING ANGLE. RIH W/ 30' BELLY BUILDING ASSY & DRLD TO 5194'. CONT DRLG TO 5289' W/ 30' BELLY BUILDING ASSY. POH TO CHANGE BHA DUE TO LACK OF BUILD. RIH W/ 40' BELLY BUILDING ASSY & DRLD TO 5582'. SURVEYS: 5357' 43.0° N72.gW 5388' 43.3° N72.2W 5478' 43.3o N72.5W UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 12 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5889'/ 307' 37 DAYS 2/13/85 28" ~ 324' 20" ~ 911' 70 PCF/ 49 SEC DALLY COST: $ 47,680 CUM COST: $1,594,010 AFE AMT: $5,085,000 6223'/ 334' 38 DAYS 2/14/85 28" ~ 324' 20" ~ 911' 71 PCF/ 49 SEC DAILY COST: $ 46,420 CUM COST: $1,640,430 AFE AMT: $5,085,000 6460'/ 237' 39 DAYS 2/15/85 28" ® 324' 20" ~ 911' 71PCF/ 49 SEC DAILY COST: $ 50,740 CUM COST: $1,691,170 AFE AMT: $5,085,000 6572'/ 112' 40 DAYS 2/16/85 28" ~ 324' 20" ~ 911' 71 PCF/ 49 SEC DAILY COST: $ 46,110 CUM COST: $1,737,280 AFE AMT: $5,085,000 6572'/ O' 41 DAYS 2/17/85 28" ~ 324' 20" $ 911' 13 3/8" 6572' 71PCF/ 49 SEC DAILY COST: $ 44,380 CUM COST: $1,781,610 AFE AMT: $5,085,000 POH FOR WASHOUT. PICKED UP 15 ADD JTS HWDP. REPAIRED CATHEAD. RIH. DRLD 17 1/2" HOLE TO 5889'. SURVEYS: 5566' 44.6° N72.0W 5658' 45.1° N72.5W 5750' 45.4° N72.5W 5844' 46.9° N71.8W 5938' 46.9° N71.8W DRLD 17 1/2" HOLE TO 6066'. TRIPPED FOR BHA #22. DRLD 17 1/2" HOLE TO 6223'. SURVEYS: 6000' 47.8° N71.1W 6138' 48.0° N69.5W DRLD 17 1/2" HOLE TO 6348'. TRIPPED FOR WASHOUT. DRLD 17 1/2" HOLE TO 6572'. CIRC. MADE SHORT TRIP. CIRC. POH. RIGGED & RAN 13 3/8" CSG TO 6572', FC ® 6495'. DV ~ 3080' (13 3/8" CSG - 104 JTS 68# K-55 BUTTRESS & 67 JTS 61# K-55 BUTTRESS). CIRC. CMTD BTM STAGE. CIP ® 1800 HRS, 2/17. CIRC THRU DV. WOC. (CMT SUMMARY TO FOLLOW. 2ND STAGE). SURVEYS: 6313' 45.4° N71.5W 6499' 44.0° N71.5W 6572' 44.2° N72.2W UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 13 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6572'/ O' 42 DAYS 2/18/85 20" ~ 911' 13 3/8" 6572' 71PCF/ 49 SEC DALLY COST: $ 367,740 CUM COST: $2,149,350 AFE AMT: $5,085,000 6572'/ O' 43 DAYS 2/19/85 20" $ 911' 13 3/8" 6572' 71PCF/ 49 SEC DAILY COST: $ 47,240 CUM COST: $2,196,590 AFE AMT: $5,085,000 6572'/ O' 44 DAYS 2/20/85 20" ~ 911' 13 3/8" 6572' 71PCF/ 49 SEC DAILY COST: $ 32,915 CUM COST: $2,229,185 AFE AMT: $5,085,000 6572'/ O' 45 DAYS 2/21/85 20" $ 911' 13 3/8" 6572' 71PCF/ 49 SEC DAILY COST: $ 42,235 CUM COST: $2,271,420 AFE AMT: $5,085,000 CMTD TOP STAGE THRU DV. ND 20". LANDED CSG W/ 150,000#. NU RISER & 13 3/8" BORE. CEMENT SUMMARY: 1ST STAGE 3760 CF "G" CMT W/ .75% CFR-2, .42% HALAD 22, 9% GEL FOLLOWED BY 403 CF "G" CMT W/ .75% % CFR-2, .42% HALAD 22. DISP W/ 6588 CF MUD. GOOD RETURNS. CIRC. HEAVY CONTAMINATED FLUID THRU DV. 2ND STAGE 2654 CF "G" CMT W/ .75% CFR-2, .42% HALAD 22, 9% GEL, 2% CACL2 FOLLOWED BY 403 CF "G" CMT W/ .75% CFR-2, .42% HALAD 22, 2% CACL2. DISP W/ 2660 CF SEA WATER. NU CHOKE & KILL LINES. TESTED BORE TO 3000 PSI - OK. ANNULAR TO 1500 PSI - OK. WORKED ON CHOKE MANIFOLD. TEST WITNESSED BY STATE. RIH W/ BHA #24. MAG'D ALL 6 5/8" CONN & HWDP. LD 4 HWDP. TAGGED CMT ® 3073'. TSTD CSG TO 2500 PSI - OK. CO CMT & DV COLLAR. FELL OUT ~ 3086'. TST CSG TO 2500 PSI. PRESS FELL TO 1650 PSI SLOWLY BLED TO 1600 PSI (DV COLLAR SUSPECT). RIH & TAGGED WIPER PLUG @ 6486'. CIRC. TST CSG TO 2400 PSI. PRESS FELL OFF TO 1200 PSI. ROH. RIH W/ RTTS. SET BELOW DV ~ 3093'. TST OK ABOVE, LEAKING BELOW. RESET RTTS ~ 6482'. TST OK ABOVE TO 2500 PSI, LEAKING BELOW. ROH. RIH W/ BHA #24. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE 'ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6572'/ O' 46 DAYS 2/22/85 20" $ 911' 13 3/8" 6572' 71PCF/ 49 SEC DAILY COST: $ 55,230 CUM COST: $2,326,650 AFE AMT: $5,085,000 6572'/0' 47 DAYS 2/23/85 20" ~ 911' 13 3/8" ~ 6572' 71 PCF/49 SEC DAILY COST: $ 44,685 CUM COST: $2,371,335 AFE AMT: $5,085,000 6581'/9' 48 DAYS 2/24/85 20" ~ 911' 13 3/8" ~ 6572 71 PCF 49 SEC DAILY COST: $ 28,101 CUM COST: $2,399,436 AFE AMT: $5,085,000 CONT RIH W/ BIT ON BHA 24. DRLD UP FC 6486-6490' & SHOE 6564-6565', THEN FELL TO BTM ~ 6577'. NO CMT 8ETWEEN FLOAT EQUIP NOR BELOW SHOE. PULLED UP INSIDE SHOE & PERFORMED LEAK-OFF TEST TO 103 PCF EMW. POOH. RU DIALOG & RAN SPERRY SUN "BOSS" GYRO 6550' TO SURF. RAN 13 3/8" CSG SCRAPER TO 6560'. CIRC BTMS UP & POOH. PU & RIH W/ HOWCO EZSV RET. RET SET PREMA- TURELY ~ 1855'. UNSTABBED FROM RET & POOH. RIH W/ BIT ON BHA #24 & DRLD RET ~ 1855'. DRLG UP RET ~ 1855' & PUSHED JUNK TO 6577' TD. POOH. PU BAKER K-1 RET & RIH. ATTEMPTED UNSUCCESSFULLY TO SET RET ~ 6480'. POOH W/ RET. FOUND SET SCREW CONNECTING SETTING TOOL TO RET NO SCREWED IN. TIGHTENED SET SCREW & RERAN BAKER RET, SUCCESSFULLY SETTING ~ 6481'. RU LINES FOR CMTG, THAWED OUT & CIRC THRU CHOKE & KILL LINES & LINES TO CMT UNIT. PRESS TSTD DP TO RET TO 2600 PSI, LINES FROM CMT UNIT TO HEAD PIN TO 5000 PSI. ATTEMPTED TO OBTAIN FORMATION BREAKDOWN & PUMPED INTO FORM ~ 2 1/2 SPM, 2075 PSI & 3 1/2 BPM, 2150 PSI. SHUT DOWN PUMPS, PRESS BLED TO 550 PSI & HELD AFTER 10 MIN. UNSTABBED F/ RET & PUMPED 280 CF OF 3 PPB CAUSTIC H20 AHEAD, FOLLOWED BY 30 CF FRESH WATER SPACER & 279 SXS CL "G" CMT MIXED W/ FIW ~ 15.8-16.0 PPG. STABBED INTO RET & PUMPED AN ADDITIONAL 221 SXS SAME CMT SLURRY & DISPL W/ 620 CF" _UNFILTERED INLET H20. FINAL 5QZ PRESS WAS 2700 PSI ® 3 1/2 BPM. PRESS DROPPED TO 2200 PSI AFTER 2 MIN & HELD STEADY AFTER PUMPS TURNED OFF. CIP ® 1730 HRS. BLED OFF BACKSIDE PRESS, CLOSED HEAD PIN & UNSTABBED FROM RET, PICKING UP 10'. CLEARED LINES TO HOWCO, OPENED HEAD PIN & REV CIRC CLEAN, SEEING APPROX 2 BBLS'CMT IN RETURNS. POOH. WORKED ON RT BACKBRAKE WHILE WOC. WORKED ON RT BACKBRAKE & DC GENERATORS & CONTROLS. RAN CIW WEAR BUSHING. STRAPPED IN HOLE W/ BIT ON BHA #24 & TAGGED TOC ~ 6475'. CO CMT 6475-6481', RET 6481-6483', & CMT TO 6567' (2' OUTSIDE SHOE). RAN TO BTM ® 6576' & DRLD ON RET JUNK TO 6581'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 SHEET D PAGE NO. 15 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6802' / 221 ' 49 DAYS 2/2~/85 20" 8 911 ' 13 3/8" ~ 6572 66 PCF 63 SEC DALLY COST: $ 41,065 CUM COST: $2,443,310 AFE AMT: $5,085,000 CIRC & PERFORMED LEAK-OFF TEST TO 105 PCF EMW. POH. RIH W/ BHA #25 (30' BELLY BLDG) & CHANGED HOLE OVER TO MUD. DRLD TO 6802'. LOST POWER IN 3 OF 6 GENERATORS. POH. REPAIRED SAME. RIH W/ BHA #26 (40' BELLY BLDG). 7082'/ 280' 50 DAYS 2/26/85 20" ~ 911' 13 3/8" ~ 6572 65 PCF 44 SEC DAILY COST: $ 72,485 CUM COST: $2,515,795 AFE AMT: $5,085,000 DRLD 12 1/4" HOLE W/ BHA #26 TO 6994'. DYNA-DRILLED 12 1/4" HOLE W/ BHA #27 TO 7082'. ROH. REPLACED SWIVEL. 7482'/ 400' 51 DAYS 2/27/85 20" ® 911' 13 3/8" ® 6572 68 PCF 50 SEC DAILY COST: $ 29,664 CUM COST: $2,545,459 AFE AMT: $5,085,000 7849'/ 367' 52 DAYS 2/28/85 20" ~ 911' 13 3/8" ® 6572 68 PCF 51 SEC DAILY COST: $ 61,934 CUM COST: $2,607,393 AFE AMT: $5,085,000 DRLD 12 1/4" HOLE W/ BHA #28 F/ 7082'- 7482'. SURVEYS: 7086' 44.5° N63.9°W 7209' 45.1° N63.4°W 7335' 45.4° N62.9°W 7425' 46.3° N62.3ow DRLD 12 1/4" HOLE F/ 7482-7726'. TRIPPED FOR BHA #29. TIGHT SPOTS F/ 7482-7680'. REAMED F/ 7680-7726'. DRLD 12 1/4" HOLE F/ 7726-7849'. SURVEYS: 7551' 46.3° N62.3°W 7688' 46.6o N62.3°W 7831' 46.2° N61.6°W UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 16 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8220'/ 371' 53 DAYS 3/01/85 20" ~ 911' 13 3/8" ~ 6572' 68 PCF 45 SEC DAILY COST: $ 47,693 CUM COST: $2,655,086 AFE AMT: $5,085,000 8338'/ 118' 54 DAYS 3/02/85 20" ~ 911' 13 3/8" ® 6572' 69 PCF 52 SEC DAILY COST: $ 35,539 CUM COST: $2,690,625 AFE AMT: $5,085,000 8757'/ 419' 55 DAYS 3/03/85 20" ~ 911' 13 3/8" ® 6572' 68 PCF 50 SEC DAILY COST: $ 43,354 CUM COST: $2,733,977 AFE AMT: $5,085,000 DRLD 12 1/4" HOLE F/ 7849-7958'. TRIPPED FOR BHA #30. DRLD 12 1/4" HOLE F/ 7958'- 8220'. POH. TRIPPED FOR BHA #31. DYNA-DRLD 12 1/4" HOLE F/ 8220-8314'. TRIPPED FOR BHA #32. DRLD 12 1/4" HOLE F/ 8314-8338'. DRLD 12 1/4" HOLE F/ 8338-8520'. TRIPPED FOR BHA #33. DRLD 12 1/4" HOLE F/ 8520' -8757'. SURVEYS: 7913' 45.7° N60.9°w 8077' 45.4° N61.6°W 8185' 45.8° N60.9°w 8261' 44.5° N57-1°W - 8326' 46.1° N55.7°w · 8477' 45.2° N55.0°W 8630' 46-7° N53.9°W 9157'/ 400' 56 DAYS 3/04/85 20" $ 911' 13 3/8" $ 6572' 69 PCF 50 SEC DAILY COST: $ 49,228 CUM COST: $2,783,205 AFE P~qT: $5,085,000 POH. PERFORMED BOP TST-OK. RIH W/ BHA #34. DRLD 12 1/4" HOLE F/ 8757-9077'. TRIPPED FOR BHA #35. DRLD 12 1/4" HOLE F/ 9077-9157'. SURVEYS: 8721' 46.7° N53-9°w 8814' 48.5° N53.2°W 8966' 47.0° N52.5°w 9121' 46.2° N52.5°W 9250' 46.6° N51.8°W UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 17 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9602'/ 445' 57 DAYS 3/05/85 20" ~ 911' 13 3/8" $ 6572' 69 PCF 51 SEC DAILY COST: $ 45,320 CUM COST: $2,828,525 AFE AMT: $5,085,000 9804'/ 202' 58 DAYS 3/06/85 20" ~ 911' 13 3/8" ~ 6572' 69 PCF 49 SEC DAILY COST: $ 89,785 CUM COST: $2,918,310 AFE AMT: $5,085,000 10069'/ 265' 59 DAYS 3/07/85 20" ~ 911' 13 3/8" ~ 6572' 70 PCF 58 SEC DAILY COST: $ 56,560 CUM COST: $2,974,870 AFE AMT: $5,085,000 10412'/ 343' 60 DAYS 3/08/85 20" $ 911' 13 3/8" $ 6572' 70 PCF 55 SEC DAILY COST: $ 49,460 CUM COST: $3,024,330 AFE AMT: $5,085,000 10629'/ 217' 61 DAYS 3/09/85 20" ® 911' 13 3/8" ~ 6572' 70 PCF 50 SEC DAILY COST: $ 49,220 CUM COST: $3,073,550 DRLD 12 1/4" HOLE F/ 9157-9311'. TRIPPED FOR BHA #35. DRLD 12 1/4" HOLE F/ 9311'- -9602'. TRIPPED FOR BHA #36. SURVEYS: 9338' 46.9° N51.1°W 9493' 47.8° N50.7°W DRLD 12 1/4" HOLE F/ 9602-9804'. POH. TIGHT SPOT $ 6664'. RU DIALOG COLLAR LOCATOR TO CHECK 13 3/8" CSG. SURVEYS: 9649' 48.7° N50.4°W RAN DIALOG CCL F/ 6750-5850'. 13 3/8" CSG INTACT. RIH W/ BHA #36. REAMED F/ 9585-9804'. DID NOT HIT TIGHT SPOT $ 6664'. DRLD 12 1/4" HOLE F/ 9804-11069'. TRIPPED FOR BHA #37. SURVEYS: 9841' 48.8° N50.4ow 9990' 49.3° N50.2°W REAMED F/ 10010-10069'. DRLD 12 1/4" HOLE F/ 10069-10412'. TRIPPED FOR BHA #38. REAMED F/ 10392- 10412' DRLD 12 1/4" HOLE F/ 10412-10629'. TRIRRE6 FOR BHA #39. AFE AMT: $5,085,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 18 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10864'/ 235' 62 DAYS 3/10/85 20" $ 911' 13 3/8" ~ 6572' 70 PCF 58 SEC DAILY COST: $ 42,610 CUM COST: $3,116,160 AFE AMT: $5,085,000 11029'/ 165' 63 DAYS 3/11/85 20" $ 911' 13 3/8" ~ 6572' 71PCF 57 SEC DAILY COST: $ 48,985 CUM COST: $3,165,145 AFE AMT: $5,085,000 11113'/ 84' 64 DAYS 3/12/85 20" ~ 911' 13 3/8" $ 6572' 71 PCF 51 SEC DAILY COST: $ 44,195 CUM COST: $3,209,340 AFE AMT: $5,085,000 11389'/ 276' 65 DAYS 3/13/85 20" ~ 911' 13 3/8" ~ 6572' 71PCF 51 SEC DAILY COST: $ 51,632 CUM COST: $3,260,972 AFE AMT: $5,085,000 11394'/ 5' 66 DAYS 3/14/85 20" $ 911' 13 3/8" $ 6572' 70 PCF 44 SEC DAILY COST: $ 37,331 CUM COST: $3,298,303 AFE AMT: $5,085,000 REAMED F/ 10575-10629'. DRLD F/ 10629-10836'. TRIPPED FOR BHA #40. REAMED F/ 10776-10836'. DRLD 12 1/4" HOLE F/ 10836-10864'. SURVEYS: 10120' 48.8° N49.3W 10273' 47.7° N49.0W 10551' 46.0° N46.9W DRLD 12 1/4" HOLE TO 10940'. TRIPPED FOR WASHOUT IN "S" PIPE. DRLD W/ BHA #40 TO 10994'. WASHOUT IN "E" RIPE. DRLD 12 1/4" HOLE TO 11029'. TRIPPED LAYING DOWN WORE "E" DR. SURVEYS: 10708' 46.3° N47.6W 10804' 47.5° N47.2W 10898' 47.3° N44.8W 10963' 47.1° N44.8W TSTD BORE TO 3000 PSI-OK AFTER REPAIR TO PIPE RAMS. RIH W/ BHA #41 PICKING UP E DP. REAMED F/ 10999-11029'. DRLD 12 1/4" HOLE TO 11068'. POH. WASHOUT IN "S" PIPE, SECOND TIME IN SLIP AREA. RIH. DRLD 12 1/4" HOLE TO llll3'. SURVEYS: 11055' 47.1° N44.8W TRIPPED FOR BHA #42. DRLD 12 1/4" HOLE F/ 11113-11389'. TRIPPED FOR WASHOUT. SURVEYS: 11211' 46.6° N44.1W 11350' 46.50 N43.7W TROUBLE FINDING WASHOUT. REPLACED 44 JTS S-135. RIH REAMED F/ 11350-11389'. DRLD 12 1/4" HOLE TO 11394'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 19 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 11654'/ 260' 67 DAYS 3/15/85 20" $ 911' 13 3/8" ~ 6572' 70 PCF 46 SEC DAILY COST: $ 50,389 CUM COST: $3,348,692 AFE AMT: $5,085,000 11866'/ 212' 68 DAYS 3/16/85 20" $ 911' 13 3/8" ~ 6572' 71 PCF 45 SEC DAILY COST: $ 49,105 CUM COST: $3,397,797 AFE AMT: $5,085,000 11997'/ 116' 69 DAYS 3/17/85 20'! $ 911' 13 3/8" ~ 6572' 71PCF 50 SEC DAILY COST: $ 40,047 CUM COST: $3,437,844 AFE AMT: $5,085,000 12220'/ 223' 70 DAYS 3/18/85 20" ~ 911' 13 3/8" ~ 6572' 70 PCF 45 SEC DAILY COST: $ 81,050 CUM COST: $3,518,894 AFE AMT: $5,085,000 12435'/ 215' 71 DAYS 3/19/85 20" $ 911' 13 3/8" ~ 6572' 71PCF 45 SEC DAILY COST: $ 61,598 CUM COST: $3,580,492 AFE AMT: $5,085,000 DRLD 12 1/4" HOLE F/ 11394-11654'. POH. RIH W/ BHA #43. DRLD 12 1/4" HOLE F/ 11654-11866'. DRLD 12 1/4" HOLE F/ 11866-11881'. POH. RIH W/ BHA #44. DRLD 12 1/4" HOLE F/ 11881-11997'. POH. TIGHT SPOT ~ 7325'. RIH W/ BHA #45. DRLD 12 1/4" HOLE F/ 11997-12220'. ADDED SOLTEX TO MUD SYSTEM, ROTARY TORQUE AND PICKUP WT STABILIZED. DRLD 12 1/4" HOLE F/ 12220-12284'. TRIPPED FOR BHA #46 SWAPPING 58 JTS E DP OUT FOR 58 JTS S DR. DRLD 12 1/4" HOLE F/ 12284-12435'. SURVEYS: 12118' 42.8° N39.8W 12220' 42.3° N39.5W UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 2O LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12562'/ 127' 72 DAYS 3/20/85 20" ~ 911' 3/8" ~ 6572' 71PCF 49 SEC DAILY COST: $ 52,008 CUM COST: $3,632,500 AFE AMT: $5,085,000 12676'/ 114' 73 DAYS 3/21/85 20" ~ 911' 13 3/8" ~ 6572' 71PCF 53 SEC DAILY COST: $ 52,945 CUM COST: $3,685,445 AFE AMT: $5,085,000 12733'/ 57' 74 DAYS 3/22/85 20" ~ 911' 13 3/8" ® 6572' 71 PCF 47 SEC DAILY COST: $ 37,130 CUM COST: $3,722,575 AFE AMT: $5,085,000 12733' TD 75 DAYS 3/23/85 20" ® 911' 13 3/8" ~ 6572' 71 PCF 52 SEC DAILY COST: $ 125,185 CUM COST: $3,847,760 AFE AMT: $5,085,000 12733' TD 76 DAYS 3/24/85 20" ~ 911' 13 3/8" ~ 6572' 71PCF 52 SEC DAILY COST: $ 76,480 CUM COST: $3,924,240 DRLD 12 1/4" HOLE TO 12562'. POH. SLIGHT TIGHT SPOT AT 7360'. TESTED HYDRIL TO 1500 PSI & BORE TO 3000 PSI RIH. REAMED F/ 12504-12562 SURVEY: 12538' 38° N35.5W DRLD 12 1/4" HOLE TO 12599. TRIPPED FOR BIT & BHA #47. DRLD 12 1/4" HOLE TO 12676'. DRLD 12 1/4" HOLE TO 12733. POH. RU SCHLUMBERGER. RAN DIL/MSFL/GR/CAL/SP FROM TD TO 13 3/8" SHOE. RAN CNL/LDT/CAL/GR. LOGGED UP F/ 11450'- 11100'. PROBLEMS W/ DATA TRANSMISSION. POH. REPAIRED PROBLEM. RIH. RAN CNL/LDT/ CAL/GR F/ TD TO 911'. MINOR TIGHT SPOTS 11422', 11148', 10500', 10250', & 6634'. RIH W/ EPT/GR. RAN EPT/GR FROM TD TO SURF. RIH W/ DIL/BHC/ CAL/GR/SP. TOOLS STOPPED ® 6810". TRIPPED FOR HOLE STANDOFFS & HOLE FINDER. COULD NO? GET PAST 6810". POH. RIH W/ BIT, 3 DC'S, JARS, 42 HWDP, 2-ST'S. 3' FILL ~ TD. CIRC & COND. POH. AFE AMT: $5,085,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 21 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12733' TD 77 DAYS 3/25/85 20" $ 911' 13 3/8" ~ 6572' 71 PCF 52 SEC DAILY COST: $ 23,545 CUM COST: $3,947,785 AFE AMT: $5,085,000 12733' ID 78 DAYS 3/26/85 20" ~ 911' 13 3/8" ~ 6572' 71 PCF 52 SEC DAILY COST: $ 65,635 CUM COST: $4,013,420 AFE AMI: $5,085,000 RIH W/ DIL/BHC/CAL/GR/SP. COULD NOT WORK BELOW 7079'. POH. RIH W/ SHDT/GR/CAL TO TD -NO PROBLEMS. LOGGED TO 12253'. TRANSMISSION PROBLEMS. POH. HEAD PROBLEM. RIH W/ SHDT/GR/CAL TO 5900'. TRANSMISSION PROBLEMS. POH. CHANGED BAD CONDUCTOR. RIH W/ SHDT/GR/ CAL. LOGGED UP F/ 12540-7200'. SHORT IN CABLE. POH. RIH W/ DIL/BHC/CAL/GR/SP. WORKED TO TD. LOGGED UP TO 13 3/8" SHOE. POH. RIH W/ BIT, STAB, 1STD DC'S TO TD. CIRC & COND MUD. POH. MINOR TIGHT SPOTS AT 10460' & 7125'. RIGGED TO RUN 9 5/8" CSG. 12733' ID 79-DAYS 3/27/85 20" $ 911' 13 3/8" ~ 6572' 71 PCF 52 SEC DAILY COST: $ 884,647 CUM COST: $4,898,067 AFE AMT: $5,085,000 12733' ID 80 DAYS 3/28/85 20" $ 911' 13 3/8" $ 6572' 9 5/8" ® 12728' 71 PCF 52 SEC DAILY COST: $ 25,194 CUM COST: $4,780,431 AFE AMT: $5,085,000 12733' TD/ 12636' ETD FC 81 DAYS 3/29/85 20" ~ 911' 13 3/8" ® 6572' 9 5/8" ® 12728' 71PCF 52 SEC DAILY COST: $ 56,865 CUM COST: $4,837,296 RIGGED & RAN 47# 9 5/8" BUTT CSG 63 STS S-95, 251 JTS N-80. FS AT 12,728', FC AT 12,636'. CIRC. PUMPED 50 BBLS 12.6 PPG PREFLUSH FOLLOWED BY 1575 SXS "G" CMT W/ .75% CFR-2, · 28% HALAD 22A, .28% HALAD 24, 5% NaCL. DISP W/ 100 CF H20 & 5103 CF MUD. BUMPED PLUG. CIP ~ 2345 HRS. LIFTED STACK & RISER. SET 9 5/8" CSG ON SLIPS IN 13 5/8" HEAD. CUT OFF 9 5/8" CSG. NIPPLED UP DCB SPOOL. TESTED 2000 PSI. NIPPLED UP RISER & STACK.. TESTED BOPE-OK. RIH W/ BIT & SCRAPER TO FC ~ 12630' DPM. POH. RIH W/ SPERRY SUN GYRO. HAD TWO TOOL FAILURES. RIH W/ CBL/CCL/GR & VDL. LOGGED F/ ETD TO 9500'. RERAN W/ 1000 PSI PRESS ON WELLBORE. POH. RERAN GYRO. AFE AMI: $5,085,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 22 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12733' TD/ 12636' ETD FC 82 DAYS 3/30/85 20" $ 911' 13 3/8" ® 6572' 9 5/8" $ 12728' 71 PCF 52 SEC DAILY COST: $ 101,304 CUM COST: $4,938,600 AFE AMT: $5,085,000 12733' TD/ 12636' ETD FC 83 DAYS 3/31/85 20" $ 911' 13 3/8" $ 6572' 9 5/8" ~ 12728' 71PCF 52 SEC DAILY COST: $ 93,715 CUM COST: $5,032,315 AFE AMT: $5,085,000 12733' TD/ 12636' ETD FC 84 DAYS 4/01/85 20" ~ 911' 13 3/8" ~ 6572' 9 5/8" ~ 12728' 71 PCF 52 SEC DAILY COST: $ 65,588 CUM COST: $5,095,903 AFE AMT: $5,085,000 12733' TD/ 12636' ETD FC 85 DAYS 4/02/85 20" ~ 911' 13 3/8" ® 6572' 9 5/8" ~ 12728' 71 PCF DAILY COST: $ 43,368 CUM COST: $5,102,274 ADJUSTED AFE AMT: $5,085,000 RIH W/ CET F/ ETD TO 9500'. TST CSG TO 5000 PSI - OK. RIH W/ 4" CSG GUN 4 HPF 90°. SHOT HOLES FOR SQZ gl ~ i2360-i2364' DIL. POH. RIH W/ HOWCO EZ DRILL RET ON WL. SET ® 12330' DIL. RIH W/ DP & STINGER. ATTEMPTED TO SQZ BENCH #4 CMT SLURRY CONTAMINATED. REV OUT. SQZD AS PER REPORT #1. RETESTED CSG TO 4000 PSI - OK. RIH W/ 4" GUN 4 HPF 90° TO 12180-12184'. FIRED. POH. RIH W/ HOWCO EZ DRILL ON WL. SET ® 12165'. POH WL. RIH W/ 5" DP & STINGER. DID BLOCK SQZ THRU PERFS (12180-12184'). PUT 274 SX CMT BEHIND PERFS. POH. RIH W/ GUN & PERFED TOP OF BENCH #3 (12118'- 12122'). POH. RIH & SET HOWCO EZ DRILL ON 5" DP @ 12085' DIL. SQZD 85 SX CMT THRU PERFS (12118-12122'). PRESSURES EQUALIZED BETWEEN DP & CSG. REVERSED OUT REMAINING CMT. POH. RIH W/ BIT & SCRAPER TO RETAINER ® 12085'. CIRC. POH. RIM W/ 4" GUN. MISFIRED F/ 11990-11994'. POH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 23 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. 6-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12733' TD/ 12636' ETD FC 86 DAYS 4/03/85 20" $ 911' 13 3/8" ® 6572' 9 5/8" $ 12728' 71 PCF DAILY COST: $ 86,955 CUM COST: $5,189,226 AFE AMT: $5,085,000 12733' TD/ 11665' DPM/ RET 87 DAYS 4/04/85 20" ® 911' 13 3/8" ®'6572' 9 5/8" ~ 12728' 71 PCF DAILY COST: $ 40,039 CUM COST: $5,229,265 AFE AMT: $5,085,000 12733' TD/ 11665' RET 88 DAYS 4/05/85 20" ~ 911' 13 3/8" ~ 6572' 9 5/8" ~ 12728' 71' PCF DAILY COST: $ 39,435 CUM COST: $5,260,700 AFE AMT: $5,085,000 12733' TD/ 11378' TOF 89 DAYS 4/06/85 20" ~ 911' 13 3/8" ~ 6572' 9 5/8" ® 12728' 71PCF DAILY COST: $ 34,415 CUM COST: $5,303,115 AFE ~IT: $5,085,000 RIH. PERFED 4 SPF F/ 11990-11994'. POH. RIH W/ BAKER K-1CMT RETAINER 5" DP & SET ~ 11960' DIL. SQZD 480 SX CMT THRU PERFS ~ 11990-11994'. POH. PERF 4 SPF F/ 11680-11684' DIL. RIH & SET BAKER K-1CMT RET ON 5" DP ® 11655' DIL. SQZD TOP OF HEMLOCK W/ 480 SX CMT THRU PERFS AT 11680-11684'. ATTEMPTED TO UNSTAB FROM RET. DP STUCK. WORKED PIPE. UNSTABBED FROM RET ENOUGH TO CLOSE SLIDING VALVE & REV OUT. REV OUT 4000+ STBS. RU & RAN DIALOG FREE-POINT INDICATOR. FREE TO +iiO00'. PARTIALLY FREE TO +ii400'. ATTEMPTE~ BACK-OFF SHOT ~ i543' (TO C--HANGE OUT DAMAGED TOP JT OF DP) - UNSUCCESSFUL. MADE SUCCESSFUL BACKOFF SHOT ~ BTM OF TOP JT, HOLDING TORQUE W/ RIG TONGS. REPLACED OT W/ OT OF HWDP. PULLED ON DP UP TO 500,000#. 1-2' OF TRAVEL UP & DOWN. CIRC TO INSURE ANN NOT PLUGGED & WELDED PIPE IN PLACE. RERAN FREE-POINT INDICATOR. SHOWED TOOL JT ~ 11367' TO BE FREE; OT ~ 11395' TO BE STUCK. ATTEMPTED BACKOFF SHOT ~ 11336' W/O SUCCESS. RERAN BACKOFF SHOT ~ 11336' WLM. JAM DP INTO TIGHT SPOT TO PREVENT FREE SPINNING ON NEXT BACK-OFF ATTEMPT. ON 2ND UPSTROKE ~ 500,000#, DP CAME FREE. POH, RECOVERING 11349' OF DP. RIH W/ FISHING ASSY #i: UNDRESSED 8 i/2" OD DRAG-TOOTH SHOE ON 3 OTS OF 8 1/8" WASHPIPE, WASHPIPE BOOT BASKET, BUMPTER SUB, OIL JARS, XO, SIX 6 1/4" DC'S, XO & DP. TAGGED TOF ii347' DPM. TAGGED iST RESISTANCE WASHED OVER FISH DOWN TO i1397'. TORQUE INCREASED. POH W/ WASHPIPE, RECOVERING FORMATION SAND & COAL IN BOOT BASKET. RIH W/ FISHING ASSY #2: 1 JT HWDP, BUMPER SUB, OIL OARS, XO, SIX 6 1/4" DC'S, XO, 18 OTS HWDP, ACCELERATOR JARS, & DP. SCREWED INTO TOP OF FISH & OARRED. CONT JARRING ON FISH. RU DIALOG & SHOT STRING SHOT 1JT LOWER THAN PREVIOUS BACKOFF ® 11378' DRM. BACKED OFF & ROH W/ FISHING ASSY #2 & ONE MORE JT OF FISH (NEW TOF ~ 11378'). RIH W/ FISHING ASSY #3: DRESSED FLAT-BTM SHOE ON 3 JTS, 8 1/8" WASHRIRE, BOOK BSKT, BUMPER SUB, OIL JARS, XO, SIX 6 1/4" DC'S, XO & DR. TOF ~ 11378'. WORKED OVER TO TIGHT SPOT ~ 11397' DPM. WASHED DOWN OVER FISH TO 11408'. POH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 24 LEASE TRADING BAY UNIT/ ADL 17594 WELL NO. G-29 FIELD MCARTHUR RIVER FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12733' TD/ 11406' TOF 90 DAYS 4/07/85 20" $ 911' 13 3/8" $ 6572' 9 5/8" $ 12728' 71 PCF DALLY COST: $ 30,035 CUM COST: $5,333,200 AFE AMT: $5,085,000 12733' TD/ 11328' CMT RET 91 DAYS 4/08/85 20" ® 911' 13 3/8" ~ 6572' 9 5/8" ~ 12728' 71PCF DAILY COST: $ 42,080 CUM COST: $5,375,280 AFE AMT: $5,085,000 12733' TD/ 11328' RET 92 DAYS 4/09/85 20" ~ 911' 13 3/8" $ 6572' 9 5/8" $ 12728' 71 PCF DAILY COST: $ 58,135 CUM COST: $5,433,415 AFE AMT: $5,085,000 12733' TD/ 11328' RET 93 DAYS 4/10/85 20" $ 911' 13 3/8" $ 6572' 9 5/8" $ 12728' DAILY COST: $ 20,130 CUM COST: $5,453,545 AFE AMT: $5,085,000 12733' TD/ 11328' RET 94 DAYS 4/11/85 13 3/8" ~ 6572' 9 5/8" ~ 12728' DAILY COST: $ 20,130 CUM COST: $5,453,545 RIH W/ FISH ASSY #4: 2ND FLAT-BTM SHOE ON 4 JTS 8 1/8" WASHPIPE, REMAINDER SAME AS BEFORE. WASHED OVER FISH 11398-11408' & WASHED OVER ADDITIONAL FISH 11408-11410'. POH. RIH W/ FISH ASSY #5: 3RD NEW FLAT-BTM SHOE ON SAME ASSY AS BEFORE. RIH TO 11410' W/O PROBLEMS. WASHING OVER FISH TO 11410 1/2'. TORQUING UP BADLY. POH. RECOVERED ALL BUT 3' OF TOP JT OF DP FISH IN 3 PCS INSIDE BTM JT OF WASHPIPE. LAID DOWN FISHING TOOLS. RIH W/ HOWCO EZSV RETAINER ON DP. SET SAME ~ 11328' SQZD 51 SX CMT THRU RETAINER. CMT FLASH S~T. POH LAYING DOWN DP. RIH TO 10583'. DISP HOLE W/ FIW TREATED W/ 1.2 GAL/ 100 BBLS EA. OXYGEN SCAVENGER & CORROSION INHIBITOR. LD DP, DC, HWDP, SWIVEL, & KELLY. ND BOPE, NU TREE. RIG DOWN EQUIPMENT AND MOVED TO RIG #54. MIXED 6% KCL IN MUD SYSTEM. RELEASED RIG FOR MOVE TO G-4 AT 0000 HRS, 4/11/85. AFE AMT: $5,085,000 !!S i'-i IE iT_'i" L..':, i'::' ('; L':;iE I"..i CJ ,, !. 20" C(.':;S ]1 i"--,'.G DiE"i"..Y':. :i: i_._ · . . ' .... . ....... ". ....... I .....I' I-"I i' % .'.::)'l I:';: Iii.l(:!') i'dtl)"r'ii.::::,:: :'i :'.::'; 'T-i-.iF' DF;: T L...J_ .~ i".,if'{i .':.:-3i I I::' i:~il F;.". "'-...-'" ]: SC)I::;..' ! i'"-.I C}I"'I(.':'~I::;:{}}IE (:.'~"i' "l'kl!E 'i' :i. "'~:':' .. ' .... i :-.: ;.., [.-, .;-, 1.. ~ -:-; .......... . .._ ,'-i""lJ" I.:., ', I' 0r':''~ .... j.'?l.-'r":}i)~:i~ .... ~.,J-.-~.::~,"-'.. i --; i :.: ,, L/'f )2} ;'.it...i i -Fi ........... Fr":q ....~""'"', L, '.,'.c,,._..,_, H i S r', ,'. ':',':-' i:::, ,-:..., ,..,... r)F;.'... I....Eil;:"~Li!::: ......... C)I::;'. 'J Ii ill '.!3 ............. ~: I I I :"'.,r"'"r'.-, TI,~"i',~--.-' ..... ~.-i'.Ir"l'T: .,:... , i-:i-- i::".'{(::'d..;'T'L_ Y ..... F'c'ir:'i:::'~::-r''-r' ,, I.._ , I .... ,, (3 ,::;'. (':", I", (-:~ H .,'~ ELi ~ i"~ ........ '--. ': ~.. ~. t.-- ',-: I ?ROPOSED T.8.U.S. G- 29 [Conductor -~18) 33" CONDUCTOR DRIVEN TO 284' (EXISTING) 28",1' WALL CONDUCTOR DRIVEN TO 32.4' 20", 94~', K-55 CASING AT 911' NOTE: CURRENTLY FILL AT 281'?FISH FROM 290' TO 367' 13 3/8', 61~ & 68~, K-55 CASING AT 6,572' - 31/2", 9.2~, N-80 TUBING PERM. PACKER AT -+- 9800' 95/8" HEMLOCK FM. , 47~, N-80 CASING AT 12,728' WELL TBUS G-29 CASING & CEMENT DETAIL VOLUMES SHOWN ARE (CMT. VOL./HOLE VOL.) 9 5/8" TOP CMT AT 7259' 28"~, I 1/8' WALL AT 324' 20", 94-~¥ H-40 AT 911' (1814. ft3/1184, ft3) GOOD CMT RETURNS TO SUFACE · 13. 3/8~ DV COLLAR AT 3080' 13 318", 68-~ K-55~ 61~, K-55 AT 6572' STAGE t (4163 ft3/2426 ft~) STAGE 2 (2658 ft~/2425 ft3) (CSG LANDED WI 150,OOC~(LOT .73 psilft GRAD) CMT RETAINER AT 1'1,398' BOTTOM CMT ?? 11,395' DEPTH OF CSG COLLAPSE TEMP. SUSPENDED 4-1C~-85 9 518', 47~' S-95 & N-80 AT" 12,728' 1525sxs (1811 ft~/4215 ft~) (CSG LANDED W1200,O00~') NOTE: ALL CMT TOP ARE THEORETICAL GRAYLING PLATFORM CASING & CEMENT DETAIL OnAWN M,E.G. CKD. ~ APP'D. SCALE NONE UNION OIL COMPANY OF CALIFORNIA ANCHORAGE , ALASKA FORM V 247 A 5/.~ 7~X)· NO HGR. GOOD 0 PSI '.DCB GOOD 0 PSI ClW WF ClW WF ' -~ 10' 5000+ 2' 5K FE G'V ClW · 5000+ · · . 2' 3K~ BV WKM ~0'oo~. '2' 3K " SE BV wKM 20' 13 3/8' 9 5/8' DATE WELL TBUS G-29 GRAYLING PLATFORM LEG ~4 ~JNIO~ OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA ' - , DRAWN JFP CKO. ~ APP'D. SC^LE NONE o~[ 7./2/85 SHEETS SHEET REV. I DATE ~ ' ' WELL TBUS G-29 -. !ii'?; "'.',;~;'-'-- D,~"r F. 7/2/85 GRAYLING PLATFORM LEG -~4 " ._.-..- __ ' .UNION OIL: COMPANY OF CALIFORNIA "" '~"' . ,,,CHO,,~GE. ,,LASKA '- . ~.~GS ),.'~" IMCO Services 2400 West Loop South. P.O. Box 22605 Houston. Texas 77027 A/C 713 671-4800 coMPLETION REPORT.. COMPANY Un-ion Oil Comp_any ADDRESS P.O. Box 6247; Anchorage, AK REPORT FOR MR. J. R. Callender WELL NAME & NO. C-29 STATEAlaska j cOUNTY IMCO WAREHOUSE Kenai 99502 Kenai CONTRACTOR ADDRESS Conservative Drilli_n_g Company REPORT FOR MR. FIELD McArthur/Cook Inlet DESCR,PT,ON OF LOCAT,ON S30, T9N, R10W, SM WELL DATA DATE SPUDDED CSG. 51ZE FROM TO HOLE 51ZE FROM TO 1/27/85 20 O.D. 0 -- 911 25 324 -- 917 TOTAL DEPTH CSG. SIZE FROM TO HOLE SIZE FROM TO 12733 13 3/8 o.o. 0 -- 6572 17½ 917 -- 6572 DATETO REACHED CSG. SIZE FROM TO .OLESIZE FROM TO 3/22/85 9 5/8 O.D. 0 -- 12728 12¼ 6572 --12733 TOTALDAYS CS~.SIZE FROM TO HOLESIZE FROM TO 75 O.D. BITS: NUMBER AND SiZE '' 2- 25" 12- 1v~'' 42 - 12~" MUD UP DEPTHS 0 to 917, 917 to 4480, 4480 to 12733. TYPE MUD FINAL RETURN TICKET NO. 0 to 917 - Gel & Water; 917 to 4480 - Gel & R104998 Water, 4480 to 12733 - Gel, XC, Drispa~d~MESTS Drilled this well to TD with no major problems. Some tight spots located at 6850' proved to be badly washed out on Electric logs. Major contributing factor in mud cost was fluid loss control and resulting additives. Maintain 8 cc or less API and 20 cc or less HTHP below 4480' to TD. This added greatly to drilling fluid expense; however well was very trouble free. .. FINAL DELIVERY TICKET NO. 400830 IMCO FORM 510 15M-!-81 W. K. Wallace/D. F. Doescher/tl IMCO REPRESENTATIVE I SUMMARY OF DRILLING FLUID OPERATIONS IPAGE ! OF 6 I OPERATOR SECTION ITOWNSHIP RANGE MUD TYPE CONDUCTOR SIZE DEPTH BIT SIZE t~n~n~ Ot] Ch. RN I qN 10W N~l/Wnrer 20 91] 25 f WELL FIELD SPUD DATE SURFACE IMC0 Smvices Tsu State G-29 McArthur 1/27/85 13 3/8 6572 17 1/2 AD~sen0II-IALLIBURTONComl]ea¥2~o~onw~,~L ~'n~S~ ~u~O/t~l~7 ~ CONTRACTOR COUNTY/PARISH T.D. DATE INTERMEDIATE 12778 · ~ ' ' Conservative Drilling Co ~ena~ 2/22/85 9 5/8 12 1/4 ENGINEERS STATE DAYS TO T.D. LINER(S) Doescher ~Wallace Alaska 54 MUD VIS. MUD GELS pH APl MT. Hp ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP. lB ! []STRIP FLUID FLUID [-I NaCi ~i~ppM % VOL. % VOL. % VOL. [-IPPG. QT. []F.L.S~i/1 i-]METER LOSS LOSS ~Cl- [] ION DATE DEPTH ~PCF. [-)SMPL PV YP 0 TEMP__ CAKE Pf Mf Pm ~PPM CEC ~ K o 1985 r-{co ~Fo / MIN I-]Gr./Gal r~ 1/16 341 59 64 - 12 30 16/16 Ill.0 - - - .~ 1,6 - 7.500 40 - - - [5-0 Milline tunk, 1/17 -I- 350 165 I ¢~ I - 112 15013~/~4 I10.01 - I- I - I .2 I .4 11.8 I 5,800 I 80 I - I - I - 120.01 I I Fishing. 1/18 t 35o 166 1106 I - 117 I 35 1~7/34 I ~.5 I - I - I - I .1 I ..3 11.4 I 4,800 I 40 I - I - I - 125.ol I I Fishing. 1/1~ I 36o 165+ 1106 I - I1¢ I 34 118/4~ I ¢.5 I - I - I - I .1 I .3 I1.1 I 4,,00 I 4o I - I - I - 12¢.01 I I Fishing. Runnin~ hi vis sweeps to help clean milled cuttings out of hole. 1/2o I ~60 ~ 66 I i1~ I - 12~ I .52 I[~ 4[ I ~,0 I - I - I - I ,[ I .2 I .6 I 4.300 I ~0 I - I - I - I~.0 I I I Fishing. 1/21 I 360 166 I 82 I - I~ I 24 I 9/.~8 I ~.o I - I - I - I .~ I ..~ I .~ I z,.o~N I 60 I - I - I - 128.~ I I I Fishing. 1/22 I 360 167 I. 77 I - 133 I ]9 I _~ /39 19.5 I - I - I - I .] I .3 I .55 I 4.Z00 I SO I - I - I - 130.0 I I I Fishing. ~/2~ I '~F,':l l~,7 I 7~ I - I~, I ~n I ~,/~ I , s I - I - I - I..1 I .R I .~ I /".Tnn I fin I - I - I - I?s.n I I I Fishing. ~/24 ~1 363 161 I 83 I - 12~ 127 I~1/~ I ~.5 I - I - I - I., I .~5 I .8 I ~.400 '1 60 I - '1 - I - 12,~.0 I I I Fishing. 1/~s -I ~ 1¢,7 I ~z, I - I?.R l l~ I~/z,~ I,~.~ I - I - I - I .R I .~ I .7 I v.~nn I nn I - I - I - IPs.n I I I Fishing~ ~/26 ~ ~ I~ I s4 I - I 16 I 2~ I~/84 I ~.~ I - I - I - I .z, I .~ I .~ I 6.sor~ I ,~ I - I - I - 125.o I I I Cmt f~mh ~n hole & ~re~ar~_ i'm ar1 ~rounq, ~/'~ I R~ I~' '1 ~,~ I - · ~n~ ~ I ~/Rt I ~.n I - I - I - I .~ I .R~ I .~ I ~_~nn I ~n I - I - I - I~o.r~ I I I T~NC._ ?T14 ~/1~ 11/, ht'l' ~, T)vnn ~1rl gle~ riFF n~n.',nr~ ¢~1~. gCI14_ ~rl~ .~ ?R" ~¢_ T.?nfpr ~nr~ r.'rnt- 1/28 I ~9o '1 68 I ~,o I - I 9 lid I 7/2i lf~.0-1 - I -' I I ~ I .75 IiL3S I 3.800 I 40 I[ z/~l - I - 120.0 1807[1201 Drl by fish. Drl 324-365 w/17 1/2" bit then w/25" HO. POH for drl~ BHA. TIH & drl ahead. ~/2~ I ~z7 I 70 I 64 I - I 18 I 16 Ill/60 t 9.5 I - I - I - I .1 I .3 t .~ I 3,200 I 80 I1 3/41 - I - 125.o 169 Finish drlg to 917 w/17 1/2" bit. Open hole to 25". Losin~ some mud to formation. _. IMCO FORM No. 131 (P, ev, 1/79) TVD I SUMMARY OF DRILLING FLUID OPERATIONS IPAGE 2 OF 6 I OPERATOR SECTION ITOWNSHIP RANGE MUD TYPE CONDUCTOR ,SIZE ,DEPTH BIT SIZE Union Oil Co 30 I 9N 10W Gel/Water 20 911 2~ WELL FIELD SPUD DATE SURFACE IMm Sa, vices TBu State G-29 McArthur 1/27/85 13 3/8 6572 17 1/2 AO~'~O~tOIHALLI~UR'~Oe4C~t~ CONTRACTOR COUNTY/PARISH T.D. DATE INTERMEDIATE ~,~.~,~,~c,,,,,,~ Conservative Drilling Co Kenai 2/22/85 9 5/8 12778 12 1/4 ENGINEERS STATE DAYS TO T.D. LINER(S) Doescher tWallace Alaska 54 MUD VIS. MUD GELS pH APl HT. Hp ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP.10/ []STRIPFLUID FLUID ~ NaCI []PPM % VOL. % VOL. % VOL. [~PPG. QT. []F.L. ~--,, / [-)METER LOSS LOSS [-] ti- DION DATE DEPTH 1~ PCF. [-~ SMPL PV YP='~""/1 0 TEMP__ CAKE Pf Mf Pm 5~PPM CRC N m o 1985 "qCo[]FO / MIN D Gr./Gal 1/30 917 71 43 - 11 10 7/31 9.5 nc - - .1 .2 .9 2,900 100 1 - - 26.0 72 28 Finish ogenin~ hole. POH. Pick u~ stiff hook-u~ to ream out Dog Leg. TI~ ~O botto~. C. irc bottom8 up. POH to run 20". 1/31 I 917- 171 I 41 I 112 I 81 Z/14 110.01 no/~ I - I .2 I .4 11.3-l ~,800 I 4O 111/2l - I - 124.0~74~27 I Attempt to run 20" Hung up ~t Dog Leg. TIH w/stiff hook u~ & ream through. Pick up stabilizer & re-ream. Trip to bottom, c~rc. PiOH- 2/z I 917 I 7~ I 40. - I zo I 7 I 2/7 I ~,~ / ~o I - I - I .4 I .8 I1.1 I 3,000 I 40 I1, -, - 124.0 ~70 ~29 I ~n 20" cs~. Cmtd. 2/2 I ~11 165 I 36 I - I 6 I 31 [/1 I10.01 nc I- I - I .4 I .8 11.3 I 2,700 I 4O I 1/41 - I - 120.0~81~08 I WOC. Workin~ on ou~p~. ~/3 I ~i~ 6~ I 43 I - I 8 I 6 I s / ~ I 9.0 I nc I - I - I .1 I .3 I .6 I 4.300 I 160 I 1/21 - I - 1 25.0 [737[179 2/4 l'2100 170 I 46{ - I z:t I 15 110/43 I 9.0 114.2 I - I 2 I .1 I .3 { .5 I 4,000 I zoo I 3/4l - 192.0 127.5 ~585~782l Displaced hole w/mud. Drl ahead. Must keep vis & yp lower than planned to keep mud moving in ditch. Drld to 2100. POH to pick up new BHA. 2/5 I 2424 168 I 48 I 69 I 9 I 20 117/22 I 8.5 122.6 I - I 3 I .o5 I .3 I .2 I 5,500 I 400 I 3/41 0 194.9 125.0 ~716~23615.1 Clean mud pits & ditch. RIB w/Dyna Drl. Build Pre Hyd Gel slurry in reserve pit @ 30+ ppb. String into active as needed to maintain mud. 2/6 I 2424 I 69 I 36 I 66 I 7 I 14 Ill /15 I 8.0 128.2 I - I 4 Itr I .3 Itr I 20.000 I 1040 I 1 I 0 194.7 122.5 ~415~.9715.3 POH & lay down Dvna Drl. PU BHA & RIH. Ream 600' Dvna Drill run for direction controll. No hole 9roble~, ~egan additives to lower API FL to 8. 2/7I 3763 1-70 I 46 I - [ 8 I 15112/3~ I~.5112.oI- I 2 I .2 I 1.1 [ .5- I 12,800 I 340 I 1/~1 0 I - 120.0 ~431~.97l- Drlg ahead. POH for bit run. RIH w/no problem. Still working on ~_8cc Fluid Lo 2/8 I 4480 I 70 I 46 I 80 I 10 I 15 I 4/31 I 8.5 110.5! I 2s~s. - .3 I .7 I .25 I 13.000 I 560 I ].141 0 I 93.3 }20.0 ~.485]1..57 16.7 Drlg ahead. POH to XO BHA RIH w/stiff ~rlg. a$~emb%¥. P~ wt 20,000+ slack off wt. Still adding mtl to lower fluid loss below 8cc. 2/9 I 4675 169 I ~6 [ 76 I 14 / 15 I 3/12 I - I 7,4 122.4 I 1/2 I .1 I 1.0 I -35 I 11,500 I 480 I 1/41 0 194.2 117.5 ~598[.1315.8 Drl~ ahead. POH & PU Dvna drl. Lost oumo oressure & incr strokes. POH. Lookine for WO. Parted DC. Left 142' fish in hole incl Teleco. 2/'10 I 4695 I 69 -I 43 I 72 I 17 I i4 I 5 /28 I 8.5 I 7.2 122.0 I 1/2 [ .15 I 1.1 I .25 I 11.800 I 440 I 1/4l 0 194.2 117.5 [631~84915.8 RIH & caueht fish. 142' inet 3-17 1/2 .~tah~]~zers & Tm]eeo Lo.~t Km]lv Saver Sub in hole. RI~ & eaueht ~ame. RIH w/locked BHA ~O 2/11 I ~129 169 I 48 I 72 I 15 I 21 I 9/34 I 8.0 [ 8,8 127.2'1 2/3 I tr I ,8 I .1 [' 13.000 I 720 I 1/41 0,94:3 120.0 [53012.01~5.7 RIH & drlg ahead to 5129. POE to XO BHA. No problems . 2112 I 5489 I 69 I 44 I 78 I 14 I 18/10/29 i 90 I 9.0 124.2 I z/2 I .35 I 1.55 I .8 ] 11,100 I 480 I 314l 0 194.0 120.0 ~524tl.6i5 TIH. Drl ahead.. Pipe drag to 250,000 on connections. Adding Prehydrated Gel. IMCO FORM No. 131 (Rev. 1/79) T~D I SUMMARY OF DRILLING FLUID OPERATIONS IF'AGE 3 OF 6 I OPERATOR SECTION TOWNSHIP RANGE MUD TYPE CONDUC'TOR SIZE DEPTH BIT SIZE Union 0il Co 30 9N 10W Gel/XC/ FIW 20 91! 25 WELL FIELD SPUD DATE SURFACE IMl~lSe~vices T~. Stat;e G-29 H~Atth~= ]/27/85 1~ ~/~ 6572 17 1/2 INTERMEDIATE ~'~--~'~ ....... Conservative Drillin~ Co. Kenai 2/22/85 9 5/8 12778 12 1/4 ENGINEERS STATE DAYS TO T.D. LINER(S) Doescher/Wallace Alaska 54 ' MUD VIS. MUD GELS pH APl HT. HP ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP. ~STRIP FLUID FLUID ~ NaCI ~PPM % VOL. % VOL. % VOL. DPPG. QT. DF.L. ~/ ~ME~R LOSS LOSS . ~Cl. ~ION DATE DEPTH ~PCF. ~SMPL PV YP 0 TEMP__ CAKE Pf Mf Pm ~PPM CEC N K 1985 ~Co~fo / MIN ~ Gr./Gal 2/13 594~ 70 49 80 14 22 17 /41 9.0 9.8 26.8 2/3 .3 1.2 .8 12.400 480 3/4 0 93.0 20.0 474,241 2/[~ I 6254 17[ I n9 I 90 I~* I ~8 1~/2~ I 8,0 I 9:~ 1~7.~-1-~Z3 I -~ '1 ;~ I -~- I-i2~60--1'8~0 [ ~)~l 6- 192.0 IzT.S Sack o~ bo~om a~tet t~l~ 9~ ~d loss to ~4.0. Ad4~n~ ]~e amount8 o~ 2/zs I 6460 170+ ~ ~ - I~u] 17 I]]/ ~ / ~.s/5.7 124.o I 2/~ I .~ I .9 I .~ I ]2:so0 I 920 I ~/41 0 19~.0 125.0 2/z6 I 6572 17z I 44 I ' I z4 12o I 7/24 I a.n I =., 121.4 T 2/~ '1 .~ I~.n T .~ I'll.non '1 a~n I ~/41 n 1~2.0 12o.0 Drld to 6572. Short trio. C~rc ~ottom~ uo. ~nr¢ ~r~n. ~rc hn~nmm nn ~Q~ Cn r,,n Ran 13 3/8 csg.. Pumped cmt. Lost ~artial returns while disolacin~ cmt. Started ~etti ~.~ct severely cmt contam mud. Dumoed & s~itched to ~IW Pumped 2nd sta~e of cmt ~ob, ?egin nippling up stack. BeRin mix. All surface volume w/35 ogb Gel - 1 oob Caustic - 1 oob XC - 1 o~b Drispac SL & 1 oob Polv ~. ?est BOp, 2/20 I 6572 I Inlet b~t,= Rn ,o~g I I ~ I I -I I I I I I I I I I I I I I Continue mix surface volume w/35 ~o~ Ge~ - ] o~ ~a.~t~ - ] ~ %g - 1 ,o~ Dr~ RL & ] nnB Pnlv R%. C~c~ B~A. ~/~z I ~s72 I~=z~=b~=~=[=,b~, I I"/ I I "I I" I I '] '1 I I .I I I I I I 2/22 I 6S72 ] Inlet ~at.r ~n Rnl~] ,ne~a ~itto above on mud system. Drl~ out. Miss set ~ ~r] ¢ 2/23 I ss7~ I i=zLt b~,= ~,o~. I I / I~ I I I I I I I I I I I I I 1 Ditto above on mud ~v~tem. RI~ & ~et ~Z Dr1. ~.~ 1t ~/R ~hn~ w/ SOD ~ar~ 2/25 I 6SO~ I~ I ~ I" I,~ ] ~n'11~/~ I~.n I'Y,n I '1' ~ I'~ I-.~" I~ I s.nHn I - '1 ~/41~ [~n.s 12o.o DO cmt & XO ~o[e to base mud. (Ge[/XC~ & ~]utefl same ~/~T~. ~n~d~ ~o~. ~t~ on ~[, 2/26 I 70s2 16s I 44 I I z2 1~7 I 3/zs I~.0 17.7 12z.~ 12/~ I0 - I L~ 1.2 I 9.900 I 7so I z/21 0 197.0 I~0.0 9Off. 9~c~ up D~a D~[. D~[ to 7082. 9Off ~o~ ~e~ ~A. 1/79) TVD 5710 6000 I SUMMARY OF DRILLING FLUID OPERATIONS IPAGE 4 OF 6 OPERATOR SECTION ITOWNSHIP IRANGE MUD TYPE CONDUCTOR SIZE DEPTH BIT SIZE Union Oil Co 30 I 9N I 10W Gel/XC/FIW 20 911 25 WELL FIELD SPUD DATE SURFACE IMm Slmvices TBU State G-29 McArthur 1/27/85 13 318 6572 17 1/2 I~~ A~,,,~,0,.,~.,~.,~,,,, CONTRACTOR COUNTWPAR,S. T.D. DATE ,NTERMEOIATE .... ~,~c,,~,,,~ Conservative Drillin~ Co Kenai 2/22/85 9 5/8 12778 12 1/4 ENGINEERS STATE DAYS TO T.D. LINER(S) Doe.-. cher 'Wallace ALaska 54 MUD VIS. MUD GELS pM APl MT. HP ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP. 5i~STRIPFLUID FLUID [] NaCl []PPM % VOL. % VOL. % VOL. []PPG. QT. C'] F.L. 2~O,.. / •METER LOSS LOSS {~CI- DION DATE DEPTH [~PCF. ~;~SMPL PV YP 0 TEMP__ CAKE Pf Mf Pm []PPM CEC N K 1985 -~CODFC / MIN (-[ Gr./Gal 2/27 7482 68 50 - 15 22 7/ 20 8.5 7.8 21.4 1/3 .05 .7 .2 9,000 860 3/4 0 95.0 20.0 ,491 2.7~9 Back on bottom. Pump pressure not right. ?OH. Re~la~e ~m~. TIH. Dr] ~head. 2/28 I 788o 168' '1 51 I - I~:~ 1261 7,/18 I,~.01 7..~ 121.01 1/:~ I .2 I .~ I .5 I I~L.OOO I 720 I~ I 0 l¢5.0120.0[46~12.9~195 POH for bit. Drl ahead POH f~or bit~. TIH. Had -+100 ft fill. Ream to bottom. 3/1 I 8220 I 67+ 'l 45 - 18--]--~-]--~? 2O / 9.0--I 7.4 I]9.4 I 1/3 POH for bit. TIH. Drl ahead (no fill after tri~ ?O~ for Dvnm 3/2 I 8342 1~9 I 52 I - 119 I 29 I ~/22 I 9.~ Drl w/Dyne Drl to 8314. POH. iTIH w/~ew ~7&ldrl ahead. ~/3 1 872] I~g I 5o - I]g 7/~ I ~.2 I 7.~ I~.~ I Drl ahead. POH for bit. TIH. iClean fill f~om 8505 to 8520. D~[ ahead w/no problems. PQH ~g~~ 2bit' 3/4 I 9189 169 I 5o - I 17 I 27 I 8/27 ] 9.0 TIH. No fill. Drl ahead w/no problems. POH for bit. TIH. Ream from 9025-9077. Drl ahead w/no problems. 3/5 I 9570 I 69+ I 51 I - I 20 I 28 I 6 /23 I 9.0 I 7.0 t19.8 ] 1/3 I .1 I .8 I .2 I 11,500 I 480 I 1/2] 0 ]93.0 117.5 ~50312.7:~2 POH for new bit. TIH. No fill. Drl ahead w/no problem. POH for new bit. 3/6 I 9804 169 I 49 I - I 16 I 23 I 4/17 t 9.0 I 7.1 119.2 I 1/3 I .os I .7 I .2 I 13.000 I 680 I 1/21 0 194.0 117.5 L58511.[J8 POH & XO bit. RIH & drl~. POH & find obstruction ~ 6925. Run Dialo~ collar locator & check bottom 5Dint 13 3/8 c~g- 3/7 11o07o 170 I 58 I 88 123 I 38 117/31 I 8.5 I 6.6 11~.4 I 1/3 I tr I 1.o Itr I 12.000 I 7~0 I z/~l 0 {94.2 117.5 [496]3.2~ 5.8 RIH w/bit & drl~ to 10~070. POH. A few knots 15 stands off bottom. Still very ratty ~ 6900+,. Mix 200 bbl Pre Hyd Gel Slurry ~ 40 ~pb Gel 3/8 110412 ! 70 I 55 I 94 119 127 I 8/26 18.5 I 6.7 118.~ I ]/3 Itr ].2 Itr I ]4.000 I 720 I 1/~1 o 93.1 I~o.o 149912.67] 6.9 RIH & drlg ahead. Add 150 bbl Pre Hyd Gel Slurry @ 40 ppb Gel. pOH. One knot ~ttll ~ 6900-+. 3/9 ]10629 I 7O I 5O I 92 I 17 I 26 I 7 /2[ I 8.0 I 6.6 118.9 I 1/3 , ni~ I 1.0 I nil I 13.000 I 760 I 1/41 0 193.1 120.0 [48112.77] 6.9 Round trip for' new bit. Still have knot @ 6900_+. Drl~ to 10.629 & POH to XO bit. Add 200 bbl Pre Hvd Gel SlurrY. (40 ~b Gel~. 3/10 110836 170 I 58 I 92 116 1261 8'/26 t-9.0 I 7.8 121.6 11/3 I .2 I1.1 I .1 [ 13.000 I 640 I -z/41 0 193.1 117.5 146612.91~ 6. Prl~ to 10.836 & POH. Still have knot 0 6900_+. May ~eat. No nroblem~. RT~. Add 150 bbl Pre Nvd Ge] glurrv 0 45 Dob Ge]. 3/~1 11102~ I~1 I 57 I 9o 118 124 I 6/~3 18.5 I }.4 I~0.0 I 1/~ I .05 I .8 ] t= I ~4.000 I'g40 I 1/41 0 1~2.[ 1~7.5 151512.7N?.9 RIH & drlg. POH. Lookin~ for washout. RIH w/new bit, POH 5~ stands & find 2nd washout. RIH & drlg t~ 11,027. POH. Hole still tight @ 6900_+. 3/12 111113 ]71 / 51 I 89 117 128 111/28 18.5 / 8.0 121.4 11/3 I .1 I .7 I .2, 12,500 I 62o I1 I - t92.0'120.0 146213.2j8.0 DA w/no problems. POH for washout. TIH. Drl 2½ hrs. POH for new bit. TVD 6246 6575 6775 6860 7127 7444 IMCO FORM NO, 131 (P, ev. 1/79) SUMMARY OF DRILLING FLUID OPERATIONS p OPERATOR SECTION TOWNSHIP RANGE MUD TYPE CONDUCTOR SIZE EPT Union Oil Co. 30 9N i0W Gel/XC/FIW 20 3.1.1 WELL FIELD SPUD DATE SURFACE 111/1[:8 Sl~vices TB. State G-29 McArthur 1/27/85 13 3/8 A I~o~ 01HN.L~URTON Comm~ CONTRACTOR COUNTY/PARISH T,D. DATE INTERMEDIATE ~,~.~--~,~c ...... ~ Conservative Drillin~ Co. Kenai 2/22/85 9 5/8 12~Z2~ 1/~ ENGINEERS STATE DAYS TO T.D. LINER(S} ~.~.~ Doescher ~Wallace Alaska 54 MUD VIS. MUD GELS pH APl HT. Hp ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP. 10 / ~i~STRIP FLUID FLUID I-~ NaCI ~i~ppM % VOL. % VOL. % VOL. ~PPG. QT. l-I F.L. SEC i-IMETERLOSS LOSS I~Cl- r-IlON /, -~-.i ' DATE DEPTH I"IPcF. ~SMPL PV YP 0 TEMP~ CAKE Pf Mf Pm ~]PPM CEC ~ m 1985 --IcoF-iF¢ / MIN i--]Gr./Gal 3/13 11389 70+ 48 93 15 19 5 /15 9.5 7.6 19.8 1/3 .1 .9 .5 13~000 520 1/2 - 92.8 17.5 .5271.68 7.f Back on bottom 4:30 am. DA w/no ~roblems, 3/14 I 1139~ I 7o I ~4 I 8~ |13118 15/15 I 8.51 7.~123.01 1/~ I .~ I .8 I .3 I 11.000 I 56o I 1/21 - 192.~118.751.50511.73~.4_~ ..Drl to l:30am. POH for washout. LD pipe. PU new pipe. TIH on bottom ll:30pm. 3/15 I 11654 I 70+ } 46 I 98 ! 16 I 21 I 4 / 16 8.5 I 7..2 I 19.2 I 1/3 I .[ I .9 I .3 I 11,500 { 280 I 3/4 I - I 92.7 I 21.25{.518{1.92:~7.3 DA w/~o oroblems. Water oumos down. Had to shut off solids control e~uio for 5 hrs. POH fo:.new bi~. ~/16 111865 I ~1 I 45- I ~4 I 14 120 16z22 I ~.01 7.4119:31~ 1/~ I .15 I .9 '1 .5 I 11,000 I 24o I 1/41 - 191.9118.751.49~11.9918.~ Back on bottom @ 0700._DA w/no problems. 3/17 I 11997 I 71 I 52 I 93 I 17 I 28 I1~ /34 I 9.01 7.4 I 19.8 I 1/3 I .! . I ,.~.o I .5 I lO,00o I $60 I 3/4 I - { 91.8 { 21.251.46213.2218.2 3/18 I 12220 I 70+ I 45 I101 I 14 120 I 7 /22 I 8.s I 8.6 1 21.4 1 1/3 I .1 I. 1.1 I .4 I 11,5oo I 240 I 1/2 1 - I 92.7 I 22.5 1.49711.9917.3 POH. TIH on bottom 0700. DA. Drag up to 350,000 on connections. Add 4 ppb Soltex @ Co orders. Had rise in AP1 & HTHP w/addition of Soltex. 3/19 I 12435 I 71 I 45 I - I 13 I 18 I 4 /14 I 8.51 7.91 18.41 1/2 I .[ I 1.1 I .5 I 11,000 I 200. I 1/21 - ] 91.9 I 22.5 1.50511.73]~8.1 DA w/no problems. Trip for bit ~ 0500. Back on bottom 1500 DA. API FL went to 9.2 after trip. 3/20' I 12565 I 71 I 49 I 74 I 16 124 I 6 /15 I 9.0'1 7.5 I 18.01 1/2 I .15 I. ;I,.2 I .~, I lO,OOO I 220 I 1/4 I - I 92.01 21.251.48512.5118.0 DA w/no oroblems. POH for b~t. Test BOP's. TIH. Back on bottom _+2300. DA. ~/21 1-12678 I 71 153 190 I 18 124 17/24 I 8.51 7.5117.41.1/2 I .~. I 1., I .5 I 11,000 I 320 I 1721 - 191.~121.~51.51~1~.2318.5 DA 2-3 ft/hr. POH to check bit. TIH on bottom _+1500 hfs & DA. 3/22 I ~273~ I 71 I 47 I ~0 I 17 123 I ~ /]9 I 8.51 7.2l 18.8l 1/2 I .1 I z.z I .6 I 11.000 I 300 I 1/41 - I 92.0l 20.0 1.51112.16~8.0 Drl to TD. Circ bottoms up. POH to 3/23 I 12733 I ~8 141 146 Ill 13 /6 I 8.01 10.81 31.41 1/3 I .1 I .9 I .3 I lO,OOO I 600 I 3/41 - 195.01 18.751.585I .78~5.o B,~I t 40 bbls Gel/water to ~ut in oits due to low volume. Mud check On oit volume. Does not reflect mud in hole. Logging last 24 hrs. ~./~ I ~ I 7~ I 5~' I ~0'1 1~1~5 17 /23 I 8.~1 ~.~12~.5[ ~/3 I .o5 I 1.0 I .~ I ~0,~00 I ~20 I 1/21 - 192.0122.51.504~.4218.0 Lo~in~ TI~ for wioer tri~. No oroblems ~oin~ to bottom. Circ bottoms uo. Added fresh Gel & water. POH tO 3/~ i ~_~ I 7'~ I s;~ I ~;~ I ~9 1~9 I-,~ /24 I 8.51 9.9I - I ~/3 I .z I .8 I .3 I 11,0o0 I 360 I 1/2l 192.0122.5 1.48113.081.8.0 3/27 ~1 12733 I 72 I 62 I - I 12 138 121 /39 I 8.01 11.21 - I 2 I 0 I 9.8 I nil I 13,000 I 360 I 1/41 0 I 91-01 20.0 RIH &circ BU. POH & run 9 5/8 c$~ ~o 12,728. Cm~ same. IMCO FORM NO. 131 (Rev. 1/79) I SUMMARY OF DRILLING FLUID OPERATIONS IPAGE 6 OF6 I OPERATOR SECTION TOWNSHIP RANGE MUD TYPE CONDUCTOR SIZE DEPTH BIT SIZE Union Oil Co 30 9N 10W Gel/XC/FIW 20 911 25 O WELL FIELD SPUD DATE SURFACE IMC0 Services Tsu State G-29 McArthur 1/27/85 13 3/8 6572 17 1/2 ~,.j A D~s" "' HN-LIBURTON CemC'aW CO N T R ACTOR COUNTY/PARISH T.D. DATE INTERMEDIATE ~r4~o w,~ Line S~. P O Be, Z'~'~6 ~.~--~'~"~ .... Conservative Drillin~ Co Kenai 2/22/85 9 5/8 12778 12 1/4 ENGINEERS STATE DAYS TO T.D, LINER{S) Doe~ :her/Wallace A] as~ 54 MUD VIS. MUD GELS pH APl HT. HP ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP. ~ ~ ~STRIP'FLUID FLUID ~PPG. QT. ~F,L. ~M~R LOSS LOSS ~Cl- ~ION DATE DEPTH ~PCF. ~SMPL PV YP==~10 TEMP~ CAKE 1~85 ~C°~Fo / MIN ~ Gr./Gal ~/28 12733 70 61 / ~/2¢ I z~7~ I I I I I I Y I I I I I I I I I I I I I I I I [u~ C~. 3/3o, I z2733 I I I I I I / I I I I I I I I I I I I I I I I Run Gyro & CET. ~/~z I z~7~ I I I I I I / I I I I I I I I I I I I I I I I Squeeze. 4/z I z=733 I I I I I I / I I I I I ,! ,, I I I I I I I I I t Seueeze. Engineer released. I I I I I I I z ~ I I I I I I I I I I I I I I / I I ~ ~ I I I I I I I I I I I I z I I I I I I I I I I I I I ~ ~ I I I I I I I I / I I I I I I I I I I I I I I I I IMCO FORM No. 131 (Rev. 1/79) T~ SUMMARY OF MUD MATERIAL USAGE PAGE 1 OF COMPANY LOCATION FIELD IM~0~{~ Union Oil Company S30, T9N, R10W McArthur River ~'~ "~ ¢~HA U-~mU ~2 ~'"z~ WELL COUNTY STATE WAREHOUSE .... ~ ....... G-29 Kenai Alaska Kenai DATE DEPTH DALLY CUMULATIVE 1/17 341 9,068.68l 9,068 68 367 6 2 15 1/18 350 1~815.32' 10,884 00 88 1/19 350 1,978.90 12,862 90 90 3 2 1/20 360 858.80 13,721 70 25 3 1/21 360 604.82 14,326 52 13 1/22 360 1,452.58 ~5,779 ~0 57 4 1/23 360 1,008.32 16,787 42 1/24 363 1,169.72 17.957 %4 48 1/2~ 363 859.80 18,816 94 20 4 1/26 363 422.28 19~244 22 2 1/27 365 395.00 19,639 22 .. 1/28 590 959.90 20,599 12 35 " 1/29 750 3~109.74 23,708 86 166 1 1/30 917 901.78 24~610 64 27 2 1/31 917 979.22 25,589 86 23 6 2/1 917 750.00 26,339 86 10 2/2 911 395.00 26~734 86 2/3 911 396.00 27,129 86 2/4 2100 5,299.16 32,429 02 2~9 .. ~ 2 6 10 ' 2/5 2424 5,130.38 37,559 40 287 2/6 2424 ~,2~.12 41.85~ ~Z 40 88 2 8 10 2/7 3763 13,933.98 55.788 ~0 40 72 2/8 4480 8,298.02 64,086 52 ~ ~/9 4675 18.012.28 ~Z,098 8o 100 9 2/10 4675 1~726.601 83~825 40 70 9 2/11 5129 8,258.50' 92,083 90 103 6 20 2/12 5489 11,903.48 103,987 38 30 6 16 40 18 2/13 5941 6,798.18 110~785 55 6 4 19 7 IMCO FORM NO. 132 (Rev. I 1/79) SUMMARY OF MUD MATERIAL USAGE PAGE 2 OF ~1~ COMPANY LOCATION FIELD ~--_~lM~SSe. vices~ Unio, Oil Company S30, T9N, R10W McArthur River A~m~T~C~e~W~~ ,o ~,~ WELL COUNTY STATE WAREHOUSE ........... G-29 Kenai Alaska Kenai i ~ O DAT~ OE.TH DA,LY CUMULAT,VE cost COST 2/14 6254 7,951.00 118,736 56 70 2/15 6460 10,948.00 129,684 ~6 80 3 37 28 2/16 6570 113,171.40 142,855 96 50 110 6 51 Z 4 2/17 6572 395.00 143.250 96 2/18 6572 395.00 143,64~ 96 2/19 6572 7.780.56 151.426 52 ]06 4 ]~ 16 8 2/20 6572 1,935.79 153.362 31 3§ 5 2 5 2/21 6572 395.00 153.757 31 2/22 6572 2,616.10 . 156,373 41 40 4 2/23 6572 395.00 156,768 41 2/24 6572 2,616.10 159,384 51 40 4 , lO 2/25 6802 4,063.36 163.447 87 40 113 3 2/26 7082 12,310.18 175,758 05 83 90 6 1 30 ]4 2/27 7482 11,267.41 187,02~ 46 77 57 11 20 3 5 2/28 7880 14,115.72 201,141 18 35 35 9 10 39 16 _3/1 8220 18,104.77 219,245 95 71 75 19 15 31 . 15 3/2 8342 5,224.87 224,470 82 42 30 4 10 7 5 3/3 8721 13,026.27 237,497 09 75 102 13 10 19 7 ...3/4 9189 12,022.94 249,520 03 71 66 10 2 24 10 3/5 9570 13,537.70 263,057 73 91 30 5 9 43 12 3/6 9804 9,216.80 272,274 53 60 40 5 10 20 14 3/7 10070 17,916.22 290,190 75 60 35 19 14 '35 14 3/8 10412 14,869.97 305,060 72 55 70 14 33 7 3/9. 10629 11,891.30 316,952 02 §0 10 8 27 14 3/10 10836 10.626.60 327.578 62 60 70 10 10 20 3/11 11029 13.745.06 341.323 68 160 12 12 22 18 ! 3/12 11113 7.581.92 348.905 60 R0 40 4 12 16 4 3/13 11389 10,374.12 359,279 72 25 4 10 31 22 IMCO FORM NO. 132 (Rev. 11/?~ SUMMARY OF MUD MATERIAL USAGE PAGE 3 OF 3 COMPANY I LOCATION FIELD 81MCOlrvicl Union Oil Company S30, T9N, R10W McArthur River ,,,~..,_..--,..~,, .,~ o,, ,~ ,.~ G-29 Kenai Alaska Kema~I- DATE DEPTH DALLY CUMULATIVE ,-I~ cO ~0 ~0 O0 ~ ·---- ~ ~ ,~ ,~ COST COST 0 ~' ~ 0 0 ~ ~ 0 ~-0 ~ o0. ~ oO 0 ~cmo -0 0 u~ u'~ ~ . · 1985 ~ ~ ~ ,o 3/14 11394 395.0( 359,674 72 1 3/15 11654 13,700.72 373,375 44 36 125 4 8 36 26 1 3/16 11865 7,402.74 380,778 18 45 8 10 14 1 3/17 11997 6,376.11 387,154 29 110 35 2 6 10 11 1 3/18 12220 29,144.58 416,298 87 42 7 32 22 160 1 3/19 12435 :11,054.88 427,353 75 72 24 4 6 26 22 5 1 1 3/20 12565 3,567.51 430,921 26 62 59 9 3 6 1 3/21 12678 12,340.59 443,261 85 68 10 3 9 ~6 7 16 1 3/22 12733 9,122.60 452,384 4~ 102 3 34 7 1 3/23 12733 491.84 4~2,876 29 § 3/24 1273~ 1.714.4~ 454.590 77 55 32 .. 1 3/25 12733 395.0~ 454,985 77 " 1 3/26 12733 1~536.9~ 456,522 71 55 21 1 3/27 12733 588.68 457,111 39 12 1 3/28 12733 395.00 457 ~506 39 1 3/29 12733 395.00 457,901 39 1 3/30 12733 395.00 458,296 39 1 3/31 12733 2~ 147.00 460,443 39 120 1 4/1 12733 395.00 460,838 39 ' 1 TOTAL }RODUCTS U ;ED: 2200 3531 12 215 301 567 406 2 150 36 40 10 353 194 1 75 INVENTO]IY CORRE(TIONS: 270 13 60 6 MATERIAi~ LEFT O~ BOARD: 49 38 25 TOTAL P~)RCHASED PRODUCT F]R G-29: 2200 $850 25 215 301 .567' ~06'. 2* 188 96 40 35 353 194 7 IMCO FORM NO. 132 (Rev, 11/79) UNION OIL COMPANY Summary of IMCO Mud Material Usage GRAYLING PLATFORM Product Aluminum Stearate Bar Caustic Soda Drispac, SL Gel Gelex Kwikseal Maxpac, reg. Maxpac, SL Plug, crs. Poly RX Soda Ash Soltex VC-IO XC Polymer Eng. Services ~Total G-29 Sacks Cost 1 75.30 2200 14.60 301 34.40 567 184.00 3531 16.14 12 20.10 36 34.90 2 172.40 406 175.80 40 19.30 353 83.95 150 35.50 194 125.60 10 36.25 215 -- 420.18 75 ~ 395.00 Total $ 75.30 32,120.00 10,354.40 104,328.00 56,990.34 241.20 1,256.40 344.80 71,374.80 772.00 29,634.35 5,325.00 24,366.40 362.50 90,338.70 29,625.00 $457,509.19 Cost of Well Less Eng. Services Inventory Adjustments Material Left Onboard Total of Delivery and Returned Goods Tickets $457,509.19 (29,625.00) 427,884.19 7,164.90 3,046.11 $438,095.20 {eed:D s on Reed International CONTRACTOR OIL COMPANY RIG MAKE ~ ~ODEL LEAIE/WELL NO RECORD NO. NO. I PUMP MAKE & MODEL ~"'S"6,,J ' BIT RECORD COUNTY. SHEET NO:, SPUD DATE UNDER SURF. ' ' Lq lc. 14 C-o, STATE, SEC./T'SHIP/ RANGE TOOL JOINTS: MAKE, ,SIZE/TYPE ,;" O.D.~ DRILL COLLARS: NO, O.D.,-- I.D. LENGTH ODE OF BIT CONDITION NO, Z PUMP MAKE & MODEL, INTER. .T. ti. DRILL COLLARS: NO~ O.D.,--I.D, LENGTH DEGREE OF TOOTH DULLNESS NE/''-'~ .TI T2 T3 T4 TS 16 17 T8 HOW TO REPORT BIT WEAR IN EIGHTHS ACCUM WT. VERT. PUMP NO, I NO, Z MUD DULL COMO. REMARKS SIZE MAKE TYPE JETS.32ND BI" DEPTH FOOT. HOURS ' OOO RPM DEV, PRESS (FAILURE. MUD, ETC.) ~ I 2 3 SER. ~O. OUT AGE HOURS LB. ' SPM LIN. SPM LIN. WT. ViS. T B G'" 0r.t+~..~ t I ,' .,,., =" ~e~ H,~5~ IS ,s ,si q~,~q glo_75. t~!~ : ~ [ ~ -z-=' ,,__ ' , Reed D~v~s~on t -.~ "- ................ .~ur ~~ REED INTEENATIONA[, INC., HOUSTON, TEXAS 770 TOOTH DULLNESS (general examination) TI T2 T3 T4 T5 T6 T7 T8 tooth height 1/8 gone tooth height 1/4 gone tooth height 3/8 gone tooth height 1/2 gone tooth height 5/8 gone tooth height 3/4 gone tooth height 7/8 gone tooth height all gone NOTE: If any one row has a maiorlty ofleeth broken, add the letters "BT" BEARING CON D.~ION (check the v~st cone) BI . . . bearing ~e B2 . . . bearing ~:~e i (tight) .... bearing ~ beari .~g, I)~....~ (medii~)FJ beorlr~' I~e bearir~ I~ (Ioo,,-~ B7 . . . bearing life use~/8 B8 . . . bearing (locked or~ost) BIT GAGE I...in gage O ...~t of gage 'NOTE: If out of gage, foll~-~ the 'O" · ,hh the amount out of gage in trac- t;ohs of an inch) E,emple ~1 ... TZ.B4-1 (Teeth 1/4 9one, bearing medium, bit in gage) E,omple #2 . . . T6BT.B6.0 1/2 (Teeth 3'4 gone, broken teeth, bearing loose ~,d bit out of gage 1/2 in~h) used: 1/8 used: 1/4~ '~/2 ('~ ___ u,e~'~: .~/8 u ,dl~. 314 ~-~ Reed I ws on Reed International CONTRACTOR OIL COMPANY PUSHER _ RIG MAKE & MODEL RIG NO, .~"~ ~-mj BIT RECORD COUNTY RECORD NO. STATE SEC./T'SHIP/ RANGE SHEET TOOL NO, JOINTS: MAKE. .SIZE/TYPE NO. 1 PUMP MAKE & MODEL. CODE OF ,BIT CONDITION DEGREE OF TOOTH DULLNESS AA.AAA. NO. 2 PUMP MAKE & MODEL RUN 51ZE MAKE NO. (,.,J~TI T2 T3 T4 T5 T6 T7 T8 HOW TO REPORT BIT WEAR IN EIGHTHS TOOTH DULLNESS i'f' 'T~-,~ (general examination) T1 tooth height 1/8 gone T2 tooth height 1/4 gone T3 tooth height 3/8 gone T4 tooth height 1/2 goneI..-~ T5 tooth height 5/8 gone T6 tooth height 3/'4 gone T7 tooth height 7/8 gone'"~' T8any tooth height all gonea "~ NOTE: If one row has majority ,-~ of teeth broken, add the letters "BT" BEARINgs, CONDITION (chej~r the worst cone) B1 . . . [~haring life used: 1/8 B2 .. I~aring life u~,.~1/4 L~ht) . B3 .. ~';aringf,~_e usJ~="~/8 B4 · . ~rin~e us~/2 ~(l~se) B8 . . b~ing ~ ol~ ~ohe BIT ~GE I... in gage .... out of gage (NOTE: If out of g~¢, follow the "O" with the amount o~of gage in frac- tions of an inch) Example ~1 ... T2-B4-1 (Teeth 1/4 gone, bearing medium, bit in gage) Example ~2 ... T6BT-B6-0 1/2 (Teeth 3/4 gone, broken teeth, bearln9 loose and bit out of gage 1/2 inch) ,, r~ r ~' n P~'Pr~FqFNTATIVF JETS.32NO BIT DEPTH SER, NO. OUT SPUD DATE. INTER. UNDER J,,~URF. DRILL COLLARS: NO. O.D. ,, DRILL COLLARS,, NO. O,B.-- NO.! MUD Reed Division I.D.-- LENGTH I.D. LENGTH REMARKS (FAILURE, MUD, ETC.) RFFF) INTFRNATI©NAI IN(- HC")I IC, TC")N TFYAc, 77N11 Reed D v s on Reed International CODE OF BIT CONDITION DEGREE OF TOOTH DULLNESS I~E. ~l~ T 1 j~2 T3 T4 15 16 17 T8 HOW TO REPORT BIT WEAR IN EIGHTHS TOOTH DULLNESS (general examination) TI . T2 T3 T4 T5 T6 T7 T8 tooth height 1/8 gone tooth height 1/4 gone tooth height 3/8 gone tooth height 1/2 gone tooth height 5/8 gone tooth height 3/4 gone tooth height 7/8 gone tooth height all gone NOTE: If any one row has a majority of teeth broken, add the letters "BT" BEA NG CONDITION ~"heck the worst cone) BI . ~.. bearing life used: 1/8 B2 . .~. bearing lif, lt.,~l~ed: 1/4 ~ (tight) j 83 , ~ berg li~d: 3/8 ~ ~ (me, urn) ~ ~ (Ioo~e), ~(Iock~*or T GAGE I.., in gage ~- O .,.out of gage (NOTE: If out ~gage, follow the "O" with the amou .~out of gage in frac- tions of an inch) Example ~1 , , . T2.B4.1 (Teeth 1/4 gone, bearing medium, bit in gage) Example ~2 ... T6BT.B6-0 1/2 (Teeth 3./4 gone, broken teeth, bearing loose and bit out of gage 1/2 inch) BIT CONTRACTOR.~___C','" ~ ~,V *.,' "t', "' .'e" R'G ,O.d''''''~' _~ '~7'Ie~£CORD o,, o, I ..... PUSHER / . COUNTY RIG HAKE SHEET & MODEL RECORD NO.. NO. NO. 1 PUMP UNDER HAKE & MODEL. SPUD DATE NO. 2 PUMP MAKE & MODEL INTER ,T. D, RUN NO, JETS.32ND git DEPTH SIZE MAKE SER. NO. OUT .FLD./TOWN . . SEC./T'SHIP/ RANGE TOOL JOINTS: MAKE SIZE/TYPE O.D ..... DRILL COLLARS: NO.~O.D.-- ',, DRILL COLLARS: NO ..... O.D, NO, I MUD I.D.----LENGTH DULL COND. LENGTH REMARKS (FAILURE, HUD, ETC.) ., ~rrn DFF'DF<" r HTA TIV F J OO6~<i IOn-il Reed Division DFF F') IhlTFDNI^TI~NAI 3 3 "/o° 3-/? hl(' HC"311C.,T('~,FI TFYAc, 77~11 Reed D v,s on , Reecl Internabonal CODE OF BIT CONDITION DEGREE OF TOOTH DULLNESS AAA&A NOTE: of teeth NEW T1 T2 T3 T4 T5 T6 T7 T8 HOW TO REPORT BIT WEAR IN EIGHTHS TOOTH DULLNESS (general examination) T1 . . . tooth height 1/8 gone T2 tooth height 1/4 gone T3 tooth height 3/8 gone T4 tooth height 1/'2 gone T5 tooth height 5/8 gone T6 tooth height 3/4 gone T7 tooth height 7/8 gone T8 tooth height all gone If any one row has a majority broken, add the letters "BT" BEARING CONDITION (check the worst cone) B1 . . . bearing life used: 1/8 B2 . . . bearing life used: 1/4 (tight) B3 . . . bearing life used: 3/8 -. B4 . . . bearing life used: 1/2 (medium) B5 . . . bearing life used: 5:8 B6 . . . bearing life used: 3/4 (loose) B7 . . . bearing life used: 7/8 88... bearing life all gone (locked or lost) BIT GAGE I... in gage O ...out of gage (NOTE: If out of gage, follow the "O" with the amount out of gage in frac. t;ons of an inch) Example ~I ... T2.B4-1 (Teeth 1/4 gone, bearing medium, bit in gage) Example #2 . . . T6BT-B6-0 1/2 (Teeth 3/4 gone, broken teeth, bearing loose and bit out of gage 1/2 inch) BIT RECORD COUNTY- RIG MAKE & MODEL. RECORD NO. NO. 1 PUMP MAKE & MODEL SPUD DATE. NO. Z PUMP MAKE & MODEL. RUN 51ZE MAKE NO, JETS.32ND BIT DEPTH SER. NO. OUT INTER.. SHEET NO. UNDER ~URF. T, D. ti fLD./TOWN SEC./T'SHIP/ RANGE STATE TOOL JOINTS: MAKE SIZE/TYPE. DRILL COLLARS: NO. ,.. DRILL COLLARS: NO, 1 I.D.~LENGTH O,D.-- I.D. MUD DULL COND. LENGTH REMARKS ( FAILURE, MUD, ETC. ) Reed Division Directional Services Pressure Services Chemical Transmission Systems April 11, 1985 Mr. Roger Stickne¥ Union Oil Co. of CA P.O. Box 6247 Anchorage, Alaska 99502 Re: Boss Gyroscopic Survey Job No. AK-BO-50016/50059. Well: G-29 Trading Bay Unit Survey Date: Feb. 22, & March 30, 1985 Operator: Samec, McGuire Hr. Stickney: Please find enclosed the "Original" and one (1) copy of our- Boss Gyroscopic Survey on. the ab,ore wel~. ~,., Bo~ Gyro. ~K-~O-~O0~ ~a~ ~i~d in~o Bo;s Gyro. ~K-BO-~OOl~,~er request of Union Oil Company. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager L Enclosures NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 .... TOTAL ..... £G REF:TI ON .... ANGLE ........ VERTIC:Ar" .......... EAT l TUDE ............ DEF'ARTURE .........~TERT ICA LL---D~ DEF'TH DEG MIN DEG MIN DEF'TH FEET FEET F;EC:TION LEG .......... 0 ..... N 0' 0 I": ........ 0 (':) ................. C): 00 ................. O:'O0'"N (])'.'00 E .......... 0: O0 ......... 0-'200 ............ 100 S 12 54 W 0 19. 1 ('). O.. 00 (").. ._._.-q ?] .S (')_. :/:3 w.. - 0.15 0 . ._,="-" 200 :.--_: 7:1. 8 W 0 .17 200.00 1.0/:, :5: 0.20 W -0. :--:2 0.04 ...... --300 ........ N--'6-'.-.-r-54'W ............ 0--I'9 ............. :_'-r00':-OC~ .................. 0'78,'-:'-S ....................... 0","72'-W ................ 0"Z2:3 ...... O":"4B ............. 4 o. 0 N 9. 3/:, F ._,'--' 4 :--:_ 9. ':~... ,..,.._':' ?] 4 ,43 N ()., 18 E 1 , ,-?....'7.' :3, 0:2: ."-]":' '..-":3 /:,0 N 8.."-?:.? E ':' 5(:) 0:2/:, 1 I c)0 N 2 :::_ 1 ~:"':' E 1 7 1 ('). 9. 9. . ._ ~. ..... ._,. .1. 200 ...... ='-' ' ':~'-' ='' '-' ""'" '? '-' ''~ ..... ' '-"~ ....... ' N 47 6 Ir.. 0 ..., ;, 1:1_; .-.,, ._, 1 ..'.4, / / N ; . .:,._, E ,-'-..'..:, (.)..:,/:, .... -I.~:00 ................. N 46 .:, o' ........................ E c.~...,"--'".:, ................. I ~:""::~"-"=;~ .... , ......................... 0 ---,=-.- o--~~ ~., ...... :, ....................................... N i O. '-?.. .......................... 7 E ~'-' ...., ';-~ o= .............................. O, 11 .1. 40 ........ 0 N :--: 96 lie 0 F'; A 1:39'Y .48 .~ 7. 1 A N 1 -,.:"". 00 E '2". 13 0 . 1 ._,':' . 1' .~t-) ....... t'x ...... N--'49---' 4' :.--r '"E ............... 0-"- -?,'q: .................. 1"4 ? 'i~ ':' "'4'7 ................... -2' 8'Z"I'2 .......................................... N i .:," .-' ~::'-' (.) .......................... E 1' ..... ..... ~ "--', ......... i.) ....... -'i'?"',_-: ................ J./-._ 00Ixl ._ 4 3 (') E 0 44 .159 ? .4/:, .,...'",:,'-'. 8.6 iq :1. 4 .24 E 0 . 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N-~8'""30-'W ..... 48--~O---~rS=)ztO~r¢ ........... ~71=~"'8~-'~ ....... 4-~;'1'0T'21 ..... ~ ....... 4S~] 57;"4'7 ...... ~D'-I ........ 10200 N 48 24 W 48 ":' '-'~'"/- '~ ~ = " = ,:, · ....... 1 18 4'~ '-"-' . - ~' ':, ' ~ .......... 0 ......0 ................ ~ ~ ......... ,: .... Z ---~ ~ ...... ~'~--';~"~ .............. ~ ................ ~:' ~-~ ~ ..... ~ ..... I cr:,oo ~ (']4C)0. N 47 42 N 46 ._~':'._, 8242. :::;'~2... 1'F247.66 N 477._,. 13 W 5 ~ :3C). 47 ~ . OF;_ 1 (:)500 N 47 18 W 46 10 8:311.64 l';'~'F~6,. 58 N 4828. 14 W 52C)0, '25 O, 77 _ - _ =- ~ ..,. ..... .... ~ o6t~) N 4c .... ,=,4...,0 7'F¢ --,.-)c,~ 27 10700 N 46 42 W 46 .-,o ,~, . . .~,.; ..., N 4'~32 .., 1 W ~"-"-"-' .... ,.=,..:, o. 74 0. '~ 7 ..... i-t-~30t}--'N-4':_:r"3'6-W' 46 ..' ,:,,:,60.67 .,::40,= ....... z, hr ._,..'.',,:,. 7 7 ~ .j7._i6...-4 Ir .... ..... '-' /C) ':T~4 ':-"'-"-' %'-"-' . _. 114(:)0 N 4.'_--: 6 W 4.5 5:2: ::: '-.-~ :--: C) . 2::: ~.4 :, . Iq ._,~,:,7. :::2 W ._,:,.-'4 16, O. :--:9 11='~'' 25 %'-"-" 2(:) W 1 41 · :, (. 0 N 42 4 :::W 4.5 ..' ._,'-' = 9 .... 0 c) C) .48 1:3.20 N .=, .... ::: 9 . 0 . .=~ '~' ....... ~-.---------,~, '-' ~ ................. ---., ~ ./--~-~---'~-.~ .... ~. -X, ~,~ ..... ~-.--- ' ---~-'- .~ .... '/ ........ J:1-'60O---txf--4'-l-'-4:2-W 44 4/_', .?0/_t. 4-7 ..-.Jo.J. /,_r-N ..., ....... :,. o.., W-- ._, .... 7-;-.4/ 1-;-0-I 117(')0 N 40 6 W 4.'_::44 9143 7.'_--: 2/=,1':' 67 N 5427 .~'-.-~ W 6(.')21 6:'-': I ._-,.. -- . I I-I lit i .- ,' ii ............................................................ .SF'ERR¥-=E;UN' Z NCORF'ORA'TED .................................. F'AGE-- 5 '-- BC~:_::'.S GYRnK-;C:OPIF: ::;URVEY ..... UNION-OIL"CO. ..... OF- CA .......................... G-'-F'9 FEB '-"-' ~, MARCH 30, 19:::Fi . ." .z:., ..... -~--TOTAIz ...... DI'RE CTI'C31',] ....... ~NGILE ........ VERT I _.A,__ L~T I TLI~. _E ..... DEPARTI-IRE- ......... VERTI i-:~l. ........ 'l]l'ii] ...... DEF'TH DEF~ MIN I]EG MIN DEPTH FEET FEET SEC:TIC~N LEi3 ........... 1"1800 ..... N-"40 24"W --43' 42" 'P216-,; 02 ' '267i,'2,"_--; Iq ...... 5472."3,S W - '60L--,'5. ,'_:;G 0'; 21 ............... 11 'PO0 N 40 6 W 43 21 '.~.'2E',8.7:.']; 2'723.7,.::; N 5516.58 W ,S .1. 4'.:.?. 55 O. 41 :I..'P 0 ('~_ (]. N 3'.-:.' ,_/-, W 42 .~,,"-, 'F' 36 t. 'F' 5 .-.'-' 7 '7 ,:,'. 64 N .=,-.=;', ~ ':~.- F., 3 W ,S :212.2'.-.-~0. :'-': 0 .......... .t21_-00 ...... N'-:'-:8 '-24- N .....~.' ~'~ .... ..- ,:,"'-' ....... 'P4._,':'~' .... ~, I ............... .-.,,:,.-)..c,... ..... :...."DE; '"N .......... 5;':_.;01' ,"~:~.7 ' W ..... 5274; :[7 ..... ~'i. _';;q~;' ..... ....... .1. 2200 N :'::8 12 W 42 8 ':.-¢509. 86 28;::2.2:::: N 5642. 'pA W 6335,, 56 O. :_::6 12400 N :.-':'7 .1. 2 W 3'P :'.'::9' 'P662..42 2':';'85. :':::4 N 5721.04 W ,':,452. 8'.:.;' 1.26 12500 N 36 42 W 37 31 'P741.73 30.34..1.7 N 5757.43 W 6507.95 2.15 ............. -"~' ~.-~t '" ................ t"~ · .... ,~ .............. ~, ........ '~ ............ ,-~,-~..,"",.?, .................. -.-.~,. .,-, ........ ~ ................ £.-.,.,~,.-,;.-,-,-..~, ............. I""~._l~, .L . .z:..", £ q ._1.~ :t...'L,~.~.~ N ..:,? 'U g ..:,6 r:~ ~,,=,.¢...', 64 .-',0,=,I. I,.'. N ...,/.'...', ,:,I W '-/'"'="""- ....... - .......... ' ="-' ............... ............................. THE--'" POGLEG-'-'SEVER I'T Y"--'I' S"'"I N' DE GREES'""PER'-'ON[S-HL~NDRED "FEET, .................................................................... ]'HE VERTIC:~L SEC]'ION WAS COMPUTED ALONG N /_-,2 0 W /. ..... k,._. ....... BA SED-"LIF'O N" ' TA NGENT-I'A L-'-'TYF'E-"]]:A ECL~LA T']:C~NS';- ............ THE"-BOTTOM'" HOLE ............................................................................... DISPLACEMEN]' IS /_-,561.23 FEET, IN THE DIREC:TION OF N 62 C.:, W (- 5CRLE :- i INCq '1'0 LOO8. O0 / iOflO. 0 LINION OIL tt~. OF Ce. 0-2'} FEB, i)2, ,s !4Ai,C,t-t 30. ,!.bSF.,, I:::tK-L.i¢-C::;Ofii5, ,qK-50-SOL;39 -50bO, O0 ,-5000,00 .-40~0.00 --1000. O0 o.,qo 5CRLE :- 1 INCM TO 2000~ O0 / 7000, 0 dN!Ol~ OIL. C3. OF Cti. FEB 22. ~, hG~',SH 30. 1035 RK-bO-500i5. qK-~J-SO0']~ N 5~ ~d ['4 N 81 5'~ ~4 2OOa. Oq ..£ 40nO, qO GO00, On 5000~00 9822.64 'Oq~O. nO ..................... x, ¥£RTICRL SECTIQN IS 6581,23 RLONG R~. 323.00 12600 2009. O0 4.000. O0 8000. O0 80~JO. O0 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. o~PE~OR, WELL NAME AI~ NUMBER ~ Reports and Materials to be received by~ ~7 .... Date Required Date Receive~ f Remarks CompletLon R.e..p o r t y~_~ Well History ['~ Samples Core Chips Core Description Registered Survey Plat Inclination Survey Drill ts Production::.:...., Test Reports Digitized Data ~ ALASKA OIL AND ~A$ GONSEI~¥ATION.f, OMMI$$10N Bill Sheffield, Governor We wish to bring to yoUr attention that the Commission has no~* yet received t. he following required items on the subject well which our records indicated was completed ~~-.://~-~C5-~ 300t PORCUPINE DRIVE ANCHORAGE.ALAgKA OOSOI~3JO2 TELEPHONE(g07) 27g~-1433 Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. · ~~''~~C. vlrlhlltter Chairman lc:C.024 Union Oil and Gas Division: Western Region Union Oil Company ..,, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union June 18, 1985 Dear Bill: Alaska Oil & Gas Conservation Commission Attn: Bill Van Alen 3001 Porcupine Drive Anchorage, AK 99501-3192 Accompanying this letter, please find the well data ,for TBU G-29 (31-30) NcArthur River Field Cook Inlet, AK Sec 29, TgN R13W API#5073320374 We regret the delay in distribution, however there was a question regarding consistency between the log data and the tape. It was felt that the final prints and tape should not be distributed until all the questions could be satisfactorily resolved. Although this did require considerable investigation, the data was finally verified as correct. We hope this has not caused an inconvenience to you. Thank you for your patience. RBS/pg 1040D Sincerely, Development ol~gist RECEIVED JUN ! 91985 Alaska Oil & Gas Cons. Commission Anchorage Union Oil and Gas Division: Western Region Union Oil Company . California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union DOCUMENT TRANSMITTAL 'June 18, 1985 HAND DELIVERED TO: Bill Van Alen FROM: R.C. Warthen R. B. Stickney LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: Logs are included herewith for the following well: TBU G-29 (31-30) McArthur River Field Cook Inlet, AK Sec 29, TgN R13W API#5073320374 DLL-MSFL-SP-GR 6570 to 12724 2" & 5" DIL-SFL-SP-GR 6570 to 12709 2" & 5" BHC-GR 6570 to 12680 2" & 5" CNL-LDL-GR-CAL 780 to 12720 5" CNL-LDL-RHOB-PEF 6550 to 12720 5" CNL-LDL-RHOB-PEF (1.2" sampling) 11100 to 11450 2" & 5" CNL-LDL-POROSITY (1.2" sampling) 11100 to 11450 2" & 5" EPT-TPL-EATT 6550 to 12700 5" EPT Qual Control 6550 to 12700 5" Gyroscopic Survey 0 to 12600 LIS Tape w/verif. listing 6546 to 12753 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: Alaska Oil & Gas Cons. Commission Anchorage Union Oil and Gas Division: Western Region Union Oil Company'S,"¢ ..;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 April 24, 1985 C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: WELL COMPLETION REPORT G-29 Attached is the Well Completion Report for G-29, Trading Bay Unit, for your information and file. If you have any questions please feel free to contact me at the telephone number listed above. Very.truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/ti Attachment ADDENDUM TO COMPLETION REPORT 25.) DEPTH INTERVAL (MD) 329' 368' 12,085' 11,328' AMOUNT & KIND OF MATERIAL USED Set Plug w/108 sxs cl "G" Set Plug w/800 sxs el "G" Set Plug w/85 sxs cl "G" Set Abandonment Plug w/51 sxs el "G" Perf'd & Sqz'd f/12,118-12,122' ~ 4/HPF w/83 sxs cl "G" 11,990-11,994' ~ 4/HRF w/480 sxs el "G" 11,680-11,684' ~ 4/HRF w 480 sxs el "G" Sqz'd f/12,360-12,364' ~ 4/HPF w 232 sxs cl "G" 12,180-12,184' ~ 4/HPF w 274 sxs cl "G" Union Oil and Gas Division' Western Region Union Oil Company/~'', ,.;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union April 3, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for G-29 and K-8RD for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOO/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST STATE OF ALASKA . ALASKA ~' _ AND GAS CONSERVATION C~..,vllSSlON &ONTHLY REI ORT OF DRILLING AND WORKOVE:R O ERATION$ · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-186 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 733-20374 4. Location of Well at surface 1837' N & 1438' W of SE CDr, Sec. 29, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RT 99' MSL ADL-17594 9. Unit or Lease Name Trading Bay Unit 10. Well No. 6-29 11. Field and Pool McArthur River Field For the Month of March ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DEOH=12,733' TMD 13. Casing or liner ru.n and quantities of cement, results of pressur9 tests Ran 9 5/8",S-95 & N-80, 47#, Butt to 12,728' W/1575 sxs cl "G" tstd to 5000 psi - OK. 14. Coring resume and brief description NONE 15. Logs run and depth where run CCL f/6750-5850' DIL/MSFL/GR/CAL/SP f/12,733-6572' CNL/LDT/oal/GR f/12,733-911' EPT/GR f/12,733-Surf. SHDT/GR/CAL/ f/12,540-7200' DIL/BHC/CAL/GR/SP f/12,733-6572' CBL/CCL/GR/VDL f/12,636-9500' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE RECEIVED APR 4 985 Alaska 011 & Gas Cons. Commission Anchorage 17. I hereby certify that th_.e foregoing i~ true and correct to the best of my knowledge. SIGNED Lawrence 0. Cutting TITLE.ENVIRONHENTAL SPECIALIST DATE 04-N3-R5 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Union Oil and Gas~[~-",ision· Western Region %- Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union March 10, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for KBU 23X-6, and G-29 for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOC/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED (;';i &. ,'.. o::..'$ [;t)rl$. COIT]ITJJSSJOrI (~ STATE OF ALASKA ALASKA ,~AND GAS CONSERVATION COIl, ~llSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 84-186 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50_733-20374 4. Location of Well at surface 1837' N & 1438' W of SW Cor, Sec. 29, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSII ADL-17594 9. Unit or Lease Name Trading Bay Unit 10. Well No. 6-29 11. Field and Pool McArthur River Field For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DEOM=7849' TMD 13. Casing or liner ru.n and quantities of cement, results of pressure tests Ran 20" 94# Butt to 911' w/230 sxs cl "6"- OK. Ran 13 3/8" K-55 68# - 67# Butt to 6572' w/6414 sxs cl "G" - OK. 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED Lawrence O. Cutting TITLEENVIRONMENTAL SPECIALIST NOTE--.Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the ALaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 MEMORANOUM State of Alaska ALASKA/~.~/_OIL.~AE.rD GAS CONSERVATION COMMISSION lO: C. ~. C,'.'~~rton DATE: February 22, 1985 · ,- ~ -- . ..,?. ,,'~ . ,,,' FILE NO: D. H~t. 15 ~-IRU: ~onn~e C. Smith "~ ~ Co,is s ioner ' TELEPHONE NO: FROM: Harold R. Hawkins SUBJECT: Witness BOPE Test Union Oil G-29, (Grayling Platform), Sec. 29, TgN,R13W,SM, Permit No. 84-186. Tuesday, February 19, 1985: I left Anchorage at 1:00 pm by ERA Flying serv~ce,"arri~i'~g'in Kenai at 1:30 pm and at the Grayling Plat'form at 3:45 pm. Ntppling up BOPEs were in final stages. BOPE test started 7:45 pm. Wednesday, February 20, 1985: I witnessed the BOPE tests on Well NO.: "G-29, ~'Th~re Were two failures. The hydraulic choke and the choke control gauge, which were repaired and tested. I fill.ed out an AOGCC report which is attached. In summary, when the BOPE test's were completed on Union Oil's well No. G-29, they were satisfactory. (See remarks on AOGCC report). Attachment 02-00IA(Rev. 10/79) , , Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Well Operator p,/~/~.~ F7 /A Location: Sec,~ ~ T ,~' R! ~' 5 M Drillin~ Contractor g..M2z ~ z~ Ri Location, General f~/ii Well Sign~/[ Representative Permit /.~asing Set Representative ACCUMULATOR SYSTEM General Housekeeping z?~ Rig Reserve Pit ~,/[ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Full Charge Pressure,,..,'o ¢~.~ ~ psig Pressure After Closure . / .~j ~, psig Pump incr. clos. pres. 200 psig -~ min/D sec. Full Charge Pressure Attained: ~ min--- sec. N2 ~ /%, P~A'?.-~ .'.~ ~? psig Controls: Master ~/~ Remote ~/~ Blinds switch cover ~/~ Kelly and Floor Safety Valves Upper KellM Lower KellM Ball Type Inside BOP Choke Manifold No. Valves, No. flanges /~' "' Adjustable Chokes...~/~/~ ~/~ ,drauicall~ choke Test Pressure Test Pressure, Test Pressure Test Pressure Test Pressure Test Results: Failures ~f~' ~:?~ Test Time .~. ' hrs. ./ J~',7 ./~,/~,2 Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. : , Distribution orig. - AO&GCC cc - Operator cc - Supervisor Union Oil and Gas Di,'~ion: Western Region Union Oil Company OT California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union February. 9, 1985 Hr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Rorcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for KBU 23X-6, and G'29""for you information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOC/ti Attachments" Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED 'FE t3 1 '2 19B5 Anchorage L STATE OF ALASKA 'O(' ALASKA .L AND GAS CONSERVATION C IwMISSlON ,4THLY REPORT OF DRILLING AND WORKOVER OPERATIONS Orilling well [] Workover operation [] 2. Name of operator UNION 0IL COMPANY OF CALIFORNTA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well atsurface 1837'N & 1438' W of SE Cot, Sec. 29, TgN, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSII ADL-17594 7. Permit No. 84-186 8. APl Number 50- 733-20374 9. Unit or Lease Name Tradinq Bay Unit 10. Well No. G-29 11. Field and Pool McArthur River Field For the Month of l~n,,~'r,v 19 R~ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Recommenced Operations 01-13-85 ® 0000 Hfs, WOrked on fish DEOM:917' TMD 13. Casing or liner run and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE "\Lt,.. L I V [ 6. DST data, perforating data, shows of H2S, miscellaneous data Spotted 108 sxs cl "G" f/329-298' Spotted 800 sxs cl "G" f/368-300' Alaska Oil & Gas Cons, C0mmissJ0n Anchorage 17. I hereby certify that the fo~regoing is true and correct to the best of my knowledge. SIGNED Lawrence O. Cutting TITLE ENVIRONMENTAL SPECIALIST DATE 02-08-85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Union Oil and Gasi" sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Oanuary 15, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports for KTU 13-5, CPS 32-13, and G-29 for you~ information and file. If you have any questions, please feel free to contact me at the telephone number listed above. LOC/tj Attachments (5) Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED JAN 7 1985 Alaska Oil & Gas Cons. C0mmJssion Anchorage (~ STATE OF ALASKA ~"i ALASKA .~ AND GAS CONSERVATION C ..,MISSION . NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 84-186 :3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 733-20774 4. Location of Well at surface 1837' N & 1438' W of SE CDr, Sec. 29, TgN, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. RT 99' MSLJ ADL-17594 9. Unit or Lease Name Trading Bay Unit 10. Well No. 8-29 11. Field and Pool MeArthur River Field For the Month of December ,19~8.5 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced Operations ~ 0800 Hrs. 12-19-84 Temporariiy ReIeased Rig I2-2~-84 13. Casing or liner run and quantities of cement, results of pressur~ tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE D~rr~r~ 6. DST data, perforating data, shows of H2S, miscellaneous data NONE JAN 1 ? 985 Alaska 0il & Bas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED Lawrence O. Cutting TITLE ENVIRNOMENTAL SPECIALIST DATE 01-15-85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ,, .4 ~]ovember 23, 1984 Mr. Lawrence O. Cutting Environmental Technician Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99501-0247 Re: Tradimg Bay State G-29 Union Oil Company of California Permit No. 84-186 Sur, Loc. 1837' N, 1438' W, Sec.29, TgN, Rt3W, SM. Btmhole Loc. °48309 N, °2320' W, Sec. 30. Dear Mr. Cutting~ Enclosed is .the approved application for permit to drill the. above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). if available, a.tape containing the digitized log information shall be submitted on all logs for copying e×cept experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code), Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70)and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may~be contacted by a representative of the Department of Environment~! Conservation. Mr. Lawrence O. Cunting Trading Bay State G-29 -2- ~ovember 23, 1984 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Co~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Verh~-~ru 1M yours, /-. I / s C. ¥. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION lc Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. Bill H. Lamoreaux Environmental Supervisor 437 "E" Street, Suite 200 Anchorage, Alaska 99501 Union Oil and Gas .(- 'ision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union November 19, 1984 Mr. C.V. Chatterton AK Dept. of Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: PERMIT TO DRILL G-29 Enclosed is additional information on 6-29 per my conservation with Harold Headlund. Hopefully this will answer all questions and concerns relative to the proposed casing program outlined in the permit application. If I can be of further assistance, please feel free to contact me at the above telephone number. LOC/tj Attachment Very truly yours, Lawrence O. Cutting ENVIRONMENTAL TECHNTC'rAN Ak Environmental Group TO: Larry Cutting FROM: Paul Spir~J Union Oil Compan{, f California unl, n NOvember 12, 1984 Alaska Oil & Gas Cons. commission RE: G-29 CASING PROGRAM This is in response to your request.for further information on the G-29 casing design as proposed. A primary design criteria for the casing program was to run 9 5/8" casing to bottom - per the reservoir department's request. In order to accomplish this, the shoe of the 13 3/8" casing must be set deep enough to: 1.) reach TD within a reasonable amount of 12 1/4" open hole exposure time, and 2.) ensure the D-2 coal is behind pipe. From past experience we've found that the D-2 coal only allows about 7 days of exposure time before it flows enough to risk loss of the hole. In the proposed G-29, we anticipate being through the D-2 coal by 5800' MD. Allowing two days to log and two days to run and cement 13 3/8" casing, that leaves a maximum of three days drilling beyond the D-2 before we must stop and set pipe. At our historical rate of approximately 500'/ day in this section, we could conceivably be at 7300' MD by the time we made the decision to cease drilling the 17 1/2" hole. In reality, we will probably make the decision to' run pipe sooner, but we have permitted for 7200' MD to allow us the leeway to extend the 17 1/2" hole should we feel comfortable doing so. The deeper we can set the 13 3/8r~, the less 12 1/4" op~en hole exposure time we will have to contend with and increase ourchances of setting 9 5/8" casing on bottom. In G-28, the bottom of the D-2 was at 5950' MD and we set 13 3/8" at 6028'. This allowed us to successfully set 9 5/8" on bottom at 12,420'. On G-27 we again set 13 3/8" below the D-2 (D-2 at 5900', 13 3/8" casing point at 6395'). In this case we were forced to set 9 5/8" at 11,600' and drill an 8 1/2" hole to 12,948'. In both of these wells we drilled the 17 1/2" hole to below the D-2 with less than 830' of 20" surface pipe set. There are gas-bearing sands above the D-2 in most of the Trading Bay Unit. However, G-29 is being drilled into the Northwest Feature, beyond the gas-water contact of all the sands but one. Based on our most current geology, there is a possibility that the C-1 sand might be penetrated within the gas-water contact. Should gas be encountered here, its pressure will be 1800 psi. G-27 penetrated the gas sands with 73 pcf mud and G-28 had 72 pcf mud. Since we anticipate similar drilling conditions in G-29 and will have to have that weight to control~ the D-2 coal approximately two drilling days later, we will drill the possibly gas containing C-1 sand 200-400 psi overbalanced. This has not caused a problem in the past when drilling through known gas- bearing sands, and we do not anticipate problems here, where only one sand may possibly contain gas, and where 20" casing will be set deeper yet, at +900'. Larry Cutting Page 2 November 12, 1984 In summary, the empirical data collected from the drilling of 28 wells and the redrilling of 8 has enabled us to optimize our drilling and casing program to allow us to complete with a large casing size at TD while minimizing .time and money spent to accomplish that goal. The last two wells were uneventfully drilled with the same casing program proposed here, except that we plan on setting the 20" casing even slightly deeper and have permitted for a deeper 13 3/8" casing point, should we experience hole conditions that will allow it. jeg/ 0158d co: JRC ALASKA OIL AND GAS CONSERYATION.COMMI$SION / 3OOl PORCUPINE DRIVE October 12, 1984 ADMINISTRATIVE APPROVAL NO. 80.48 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit, to drill, complete, and produce the Trading Bay Unit No. K-8RD, No. G-29, and No. D-43 wells as part of the pressure maintenance project approval by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502-0247 Dear Mr. Anderson: The applications were received on October 12, 1984 and all stated that the drilling, completion, and production of the Trading Bay Unit No. K-8RD, No. G-29, and No. D-43 wells will provide crestal final withdrawal points in the Hemlock Pool and increase ultimate recovery from the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion, and production of the three referenced wells pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry ~q. Kuglefr, Commissioner BY ORDER OF THE COMMISSION be:l Union Oil and Gas ~.' sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen Robert T. Anderson District Land Manager 'October ll, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9~504 TRADING BAY UNIT State of Alaska NcArthu'r River Field Application to Drill and Complete TBUS G-2~, ADL-175~4 (8-86-71-5575-60134~) Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State G-29 in the Hemlock Oil Pool Pursuant to Rule 5, Conservation Order No. 80. This proposed completion at a crestal final withdrawal point will result in additional recovery of Hemlock Production. Your approval of this request will be appreciated. Very truly yours, sk cc: C. Case R. Warthen STATE OF ALASKA ALASKA'¢[' _ AND GAS CONSERVATION C~.~ .MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL ~] SINGLE ZONE J~] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address P.O. BOX 6247 Anchoraf'ie, Alaska 99502 4. Location of well at surface 9. Unit or lease name 1837'N & 1438'l,,,' of SE Cor Sec 29', T9N, R13W, SM TRADING BAY UNIT At top of proposed producing interval Leg 4 conductor 18 to. Well number +4580'N & +1800'W of SE Cor Sec 30* G-29 At total depth 11. Field and pool +_4830'N & +_2320'W of SE Cor Sec 30* McARTHUR RIVER FIELD 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RT 99' MSLI ADL-17594 12. Bond information(see 20 AAC 25.025)National Fire Insurance Co. of Hartford Type Statewide Suretvand/ornumber #B5534278 Amount $200,000 13. Distance and direction from nearest town 14. Distance t° nearest property or lease line 1 5. Distance to nearest drilling or ComPleted NW 23 miles +500 feet well +1200 feet 16. Proposed depth (MD & TVD) ~7. Number'of acres in lease 18. Approxi~0~te, spud date . ~,~. ~ ~..,,, _?",!,' ,:~ .,' ..... +12,650 MD & +10,000 feet 5116 ~-:-1-5,-84 / ~.:?,'" 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~ psig@__ Surface KICK OFF POINT +200(~eet. MAXIMUM HOLE ANGLE 44°I (see 20 AAC 25.035 (c) (2) 4035. psig@9999 ft. TD (TVD) , . 21 Proposed Casing, Liner and Cementing Program ~, SIZE __CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24 20 94 K-55 Butt. 900' Suri~ace +gOO l+gflr) +700 cf nl "¢," ' 17½ 13 3/8 61&68# K-55 Butt. 7200' Sure, ace +7-200 ~+6070 +2400 cf r. 1 "G" 12¼ 9 5/8 47# N-80 Butt. L2,650' Surf~ace _T12,650-+10-0)0 +--2000' cf c1 "G" I I 22. Describe proposed program~-- -7---_-7~_-~,,,: /~, - 1. 6lear conductor of fish 12. Run prod equip., perforate, and 2. Dril] 24" hole to +900 place ~el~ on production. 3. Run & cdt. 20" 4. Install & test diverter asSembly to 1500 PSI 5. Drill 17½" hole to +7200 6. Run &cmt. 13 3/8" c-sg.RECEIVED 7. Install & test DOPE to 3000 psi 8. Drill 12¼" hole to +12,650' TD OCl" i 21984 9. Log 10. Run & cmt. 9 5/8" csg. Alaska 0il & Gas Cons. Commission 11. Run CBL and gyro Anchorage 23. I hereby ~hat th~ego~ trl~l~ect to the best of~q~2nowledge SIGNED LAWRENCE 0. CUTTING~' ~' TITLEENVIRONMENTAL TECHNICIAN DATE 10-02-B4 The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required I APl number []YES ~LNO []YES ,~'NO [~¥ES []NOI 50--'? ~ ~-~J_ O ~ '? ~ Permit number - Approval date I~~ 6/~,/'~/-')11//~3/~4 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED B L ~'/~'~' 7/ .... ~%,~_~__~/~///,/~r~ by'COMMISSIONERorder of the Commission DATE ~o~em~e~' 2.'~.; ] Form 10-401 ~ 1, / Submit in triplicate Rev. 7-1-80 FOR 24" 26" RISER ASSEMBLY HOLE and 20" CASING TO +_900' FLOW LINE 2 6" RISER 26" X 28" ~ CROSSOVER~ 2 8", 1" W ALL DRIVE PIPE RECEIVED OCT ~ 2. 1~84 Alaska Oil & Gas Cons. Commission Anchorage ......... ~ SURFACE PIPE RISER 2~-~_ ......... .... !. :_.i _ :,. '_. :._ ' W£Lt. G'2g. GRAYLinG ?I. AIF§R~ UNION OIL COMPANY OF CALIFORNIA · ALASKA DISTRICT 5-EE'S , , FOR 17 2.0" LOW sPiRESSURE R!,.$ER & 2 ~O00p HYDRIL A'S~OEMBLY 1/2" HOLE and 13 3/8" CASING TO -!-7200' FLOW LINE 20" FLOWLINE RISER 20' 2000psi HYDRIL 20" LOW PRESSURE RISER RECEIVED Alaska Oil &.Gas Cons. Commission /~nChorage 20", 2000psi 20' 2000psi 20" CASING X 20" S.O.W. ............... 20" RISER ASSEMBLY ~'~'~- ~'~ ........... ............ 5'£,~ ' E ...................... DATE ....... ..... : .............. GRAYLING PLATFORM "';-- ''';".--_.-~_-'~.,;' UNION OIL COUp~I'Ny OF CALIFORNIA ALASKA DISTRICT 12',t,'i~'~O00psi BOPE STA{~K Flow Line Angled Fill Up Line ~12" 3000psi HYDRIL Blind Rams 12" 3000psi Shaffer% Double Gate - Check Valve Kill Line Gate or.Lo-Torque--~ Gate Valve ,, ~,--P i p e Rams RECEIVED Al~ska Oil &A~_a? COns. C°mmis$1orl nChorage Hydraulic Operated Valve Gate or "' Lo-Torque tChoke Lin( ~'-Gate Valve 2' 3000psi Shaffer Single Gate with Pipe Rams 20" 2000psi X 12" 3000psi Casing Spool FOR 12 1/4" HOLE and 9 5/8" CASING TO ToDo REV. DATE B.O.P.E. STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT DRAWN BAW CKD. APP'D. SCALE DATE CHOKE MANIFOLD L.P. VA L VE L.P. VALVES AUXILIARY CHOKE ~ POSITIVE CHOKE TARGETED TURN A DJUS TA BL~E CHOKE TARGETED TURN NOTE: ~~"--GAUGE Entire assembly is 3,000psi upstream of chokes. 'TARGETED TURN RECEIVED OCT .~ 2. ]~8t4 Alaska Oil & Gas Cons. Comrnisslo. Anch_o[age W.P. minimum CHOKE MANIFOLD GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT SwEE'"~ ' E-EET PRO?OS "' 1'.8.U.s. G- 9 IC 33" CONDUCTOR DRIVEN TO 284' (EXISTING) 28",1" WALL CONDUCTOR DRIVEN TO ----+ 370' 20", 94~, K-55 CASING AT ~ 900' NO TE: CURRENTLy FILL A T 281 '/FISH FROM 290' TO 367' 13 3/8", 61-V, & 68~,, K-55 CASING AT~---~ 7200' 3 1/2", 9.2~, N-80 TUBING PERM. PACKER AT ~ 9800' HEML 0 CK FM. E.T.D. 12,653' 95/8' RECEIVED ,. . OCT I 2 198a, Alaska O, & Gas Cons. Commission Anchorage , 47v,, N-80 CASING AT ...+ 12,650' ~,".'~ ~ .... I--',";-':'~-'"--'F-~-- '. ~ - i ; :" ' ~ ~ ; ! ' ' i ~ i i ~ J--4- I i : .t" ' -~ ' ;-.4-' ~ r ' ~ ~ .. .;_~_.~"~,..' ': _1_-I--',.~-' ........ : ......... =- ..... ~ ......... ,--r .................. ---~- '-~'--,'- .... .-'--~-- -'t-i-' "T' f '"'---' ,'T" · } ~ , , ; ~ : ~ . : , ~ . . i , , , ~ = - , ~ ' i ' ~ , . . [ ~ . , . . . ' -~:~~--i -':-'I- ~'--)'--" ' -: 4C DO - ! ........ ! -! :5000 ' -:'-~' -?' .... ~r-2000 :-- t--.+--?1-: ..... lO00" ,' '~' !-~ .... :" .... 0 ....... ; ." : ' .' 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' ! .... ~" i-' ~--;.- i -: -: °. :. ..... ; ~..: .. ;. , ~ : _~ :_'.. ;. ! ..i..: _ i-: : .... ;-.~ ~l-..' -: .... '.-;:4..-'...'~.-I'- ;--~.- .- .' -.-F' -,~ ..-,- '.:-.'f'?. ~'.' '.': ? ' ' IN,T:OF --,r-..r.I. ,.y .2O 0 I-- ~ .$0 0 F- .4C < .70 .80 .90 1.00 0 Et:FECT OF AXIAL TENSION UN COLLAPSE FOR LONE STAR STEEL CO. CASING .i0 .20 .;~0 .40 .50 .60 30 .SO .90 1.00 TENSION LOAD AXIAL LOAD FACTORX/I~= BODY YIELD STRENGTH Fornulae: · Collapse r'esistance in tension X (Collapse pressure ratify) Calculations: Burst Pressure = ~P +.Depth ( Hyd. Gr. II --,5) BF (Bouyancy Pac'tor) =" ~.oo- (o.oz~ × Nua wt. z) CASING AND TUBING DESIGN WELL CASING STRING BOROUGH STATE DATE ~'~/~ DESIGN BY . . . MUD WT. I "~ f;/~r-~ HYD GR. I O.~E) psi/ft. MUD WT. II f;/q. HYD. GR. II psi/ft. M.S.P. psi. · INTERVAL CASING SIZE Bottom Top . LENGTH '7 o' WEIGHT TENSION MINIMUM COLLAPSE COLLAPSE W/ BF ~ -top of STRENGTH PRESS. ~ RESIST. ,,, DESCRIPTION W/O BF~ section TENSION bottom tension Wt. Grade Thread lbs ' lbs 1000 lbs ,,TDF psi psi CDF BDF INTERNAL BURST MINIMUM PRESSURE YIELD psi psi CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~~ IT EM APPROVE DATE (1) Fee ~, ~'~ /~-/L'~ / (2) Loc ~:8) '(8) (3) Admin (~ thru 11) (10 and 11) (~) Cas~ ~ //-~./-fq (12 thru 20) (6) Add: · ,, 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO REMARKS Is the permit fee attached ........................................ · /~'t__ Is well to be.located in a defined pool ............................ Is well located proper distance from property line ................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-~ay wait .......................... f(,,_, Does operator have a bond in force ................................. Is a conservation order needed .... ~ ....... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... .~u~. Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ...................... Will surface casing protect fresh water zones ........... Will all casing give adequate safety in collapse, tension and burst..~,/~# Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .......................... · fz~/~ Is a diverter system required .. ...................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,¥/,~ psig .. Does the choke manifold comply w/AMI RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: FlSg O HO I--I Geology: Engipe~ering: HWK ~'LCS;f~ BEW / JAL~4~MTM~/ rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE . , Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file.. To improve the readability of the Well History file and to simplify finding information, information, of this "nature is accumulated at the end of the file under APPENDIXi ,, No special'effort has been made to chronologically organize this category of information. ,o : T6!)c-29 PAGF I 2~9~ * 6,0 12687 * 1.0,0 ~. 2677 * ~ ~.2~7~ ~ ! 2670 * . ~ 12667 ~ .4 ~ 2.666 · 3,0 ! 2~65 * 9.0 70,0 ,2 ,3 ~ 3,0 4,0 2,0 20,0 '20,0 * .1 2654 , 12663 * 12662 , 1266J * J 2660 * 1265~ * ! 265~ * ~ 265~ * 12653 * ~_ 265! * 1264~ , , ~2643 * ]2637 * 1263O !7.5 lg.4 16,0 13.V ~6,7 13.! lP,P 14,5 15.6 17.g !5.~. !.4,0 ****************************** VCL *i-PHIE * !-HYD *I-MV-g * ptl · FT * F~ * MT * ****************************** , , 2t. * , 2~ * , 16 * 9 * , ? * 6 * 6 * ~ * , 2~ * 2~ * 20 * .1~ * 7 * 27 * 2~ * 19 * , 2O * !I * 18 * 15 * , 9 * ~ * ~ * ~6 * * ~ , lP * 26 * , * , · · · 45 * * , 5~ * * , 63 * * 56 *- * , 73* * 43* * 6,9 * · , 63 * * 56 * * 52 * * 56 * * 57 * * 53 * * 60 * 6~ * * 57 * * · , 5~ * * 50 * * 56 * * 56 * , 5~ * * 57 * * -53 * * · , 5~ * 51 * * 63 * * 5~ * * 50 * * 53 * * 53 * , 51 * * · , 5q * * ************ , , , ,g * * ~.~ * !,5 ~,7 * 1.8 * 'I,9 , ?,5 * * ?,~ * 2,9 * ~.t_ * ,3 * 3,7 * ),~* ~,0 * ~.3 * 4.5 * 4,6 * 4.~ , 5,0 * 5,l * 5.2 * 5,~ , , 5.8 * 5,9 * 6.~ * 6.P * 6.4 * 6.5 * 6,9 * 7.4 * ****************************** OF * D~PTFT , WT * ~262~ * ~_ 2625 * ~ P67~ * 1262~ * ! 262P * ~26~1 , 126.i~ * ~261~ * 12~1~ * * ~ 2606 * ~260~ * 12~U3 , * * !. 2~'1~ * ~. 2~'1 ~ , * * ~2534 * ~.~53~ * 12531 6.0 ~ i4.6 * b~ * t0,0 * 1~.4 * 5n * 30.0 * 17.9 * 46 * ~u.O * i9.3 * b! * 9,0 * ~,~ * 55 * .2 * i!..6 * 6o * ~0.0 * 2~.,~ * ~ * 2,0 * 14.0 * ~0 * z,O * 1q,6 * A~ * .a * 13.4 * ~4 · .5 * !~,n * 4fi * 40,0 * !o.8 * Sa * ~0.0 * iV.6 * 4.4 * PO,O * 17,0 * 49 * ~0.0 * 17,q * 40 * ~O.;} · 17,3 * 4~ * ,4 * !0.7 * 87 * .I * ~.~ * 56 * 3,0 * 19.3 * 3g * ,'7 * i~.3 * 56 * , · 4.0 * i].R * 36 * 9.0 * 14,7 * 5] * ,2 * 10.9 * 60 * PO.O * 16.~ * 67 * ~,0 * la.6 * 66 * i.O * !!.P * 64 * ********************** **************************** VC!, *I-PHiM * T-HYD * PU * FT * MT * ********************** ROidY * G/C3 * , , , , , , , , , , , , , , , , , , , , , , , 6 * 7,5 3 * 7.7 ~ * 7 ~ · 14. * ~,1 17 * 8,~ 23 * 8.~ 2~ * 9,~ , 0 * 9.0 2° · , 11 * i0 3 1~ * !0.? 1! * 10,~ 0 , !!,5 ~ * 17.3 17 * , I1 * iP.? !~ * I~.9 20 * 13,? o * 14, t , 7 * 15.~ 0 * 15.4 6 * 15,5 4 * 15.6 0 * 15.~ i~ * 15,~ 13 * I6.1 I----MV-H FT * · * ~,8 * !.4 * 2,9* 14, 3,0 * ~_~4 * 3.0 * !.5 * 3.1 * 1.5 , ],~ * ~_.5 * 3.P * t.5 * 3,~ * 1.6 * 3,4 * !,6 * , 3.5 * 1.7 * 3.6 * ],7 * 3,7 * 1,8 3.7 * ~.,8 * 3.9 * !,~ * 4,0 i !.9 * · * 4.4 * 2.0 * ~,5 * ~,0 * 4.6 * ~,0 * 4.6 * ~.~ * 4.6 * P, ~ * · · ~.o , 2.p , 5.0 , ~.2 5,0 * ?,? * 5.1 * ~,2 * 5.~ * ~.P * · * 5.] * P.2 * . , 5.6 * P.3 5,7 * ~,3 * ~,~ * ~,3 * 4 * o , 16,? * 6 n , '~.4 * ****************************** C_.n.M PAM y w~L,b : Tbs! 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, 5~ , · lJ.9 * 57 * * i!,0 * 54 * * 17.o * 55 * * 13.!. * 54 * * , , , il,9 * 5n * * 13.1 * 57 * * 12.9 * 57 * 10,~ * 67 * * , , · o.! * 67 * * ~.8 * 57 * * ii.! * 62 * * 10.7 * 6~ * * , · , 1!.2 * 5O , · ~.4 * 5~ * · , !0,1 * 5~ * · in,4 · 5~ * * 9.~ * A~ * * , · , , , · ia.6 , 50 · , 1,~ ~ , ¢o · , 11.4 * 56 * * 1!.7 * $3 * * !~,0 * 57 · · , · , 4.3 4.3 4.3 4.3 4~. 3 4,3 4.3 ********************** vCI, *t-PHIM * !-gYP * P!.I * FT * FT ********************** , 1~ * 54.~ * 17.2 * · , , 5* 54.5* 17.4' ~ * 54.6 * 17.4 * 6 * 54.7 * 17,5 * ~ * 54.8 * 17.5 * 17 * ssi6 · 17is · 16 * 55,2 * 17,7 * I0 * 55,3 * 17'7 * !g * 55,4 * 17,8 * · , · 17 * 55.7 * 17.9 15 * 55.g * 1~.0 * 15 * 56,o * lg,O * 15 * 56'1. * 1~.1 * 21 * 56,2 * 18.1 * · , · 3 * 57.~ * i~.4 * ~ * 57.4 * lP.~ * , 1o * 50,0 * 18,6 * O * 5~.!. * 18.6 * 1t * 5~.? * 18.7 * , , ~ * 5~.4 * 18.7 * g * 58,5 * 18,g , · , ~ * 58.~ , l~,g * o , 59,~ * ig.9 * ~ * 59.0 * 16.0 · · , 5 * 59,~ * !g.1 * · , 3 *- 60.I * i0.3 o , 00,3 * 19,4 7 * 60.~ * 19.4 * O * 60.6 * 19,5 * 17 * 60~7 * 19,6 * 2t * 6n 8 * lq 6 * 20 * 60.~ * l~:7 · 2n * 6!.0 , · , o , b!,3 * i9,8 * 4,4, 14 * 61,4 * lg.9 * · 1~ * bl,~ , 1o ******************************* , * * ! 20~- * 12o3o * 1.2o2~ * 1~027 ~ t2026 * 12025 , 1201° * 1201~ * ~ 200n * ~_ 200¢ * 12004 , 1 * ~ 2000 * ! 199~ , * , .2 * ID,o * ,2 -~ 1t.? 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RHOB 2.63R9 16,2598 -q99.2500 -q9O.~bO0 -999,250U -o99.2500 LVP OlO.H02 VERIFICATION LISTING PAGE ~-~ REEL HEADER SERVICE NAME :E T DATE : OR IGIN : CDNTINgAT!SN ~ COMMENTS :LIERARY TA~E ~ TA]PE HEAO~R SERVICE NAME :EDIT gATE :85/0~/30 g-RIG IN :~SiA TAPE NAME CONTIN~ATIDN PREVIOUS TAPE : COMMENTS :LiSRAR~ TAPE RECORD TYPE [37~-'~ *~ FIL~ HE~DER FILE NAM~ :EDIT .001 SERVICE NAME : VERSIaN ~ OA'TE:: MAXI MU~, LENGTH : FI~E TYP;.. ' PREVIOUS FILE : ~* INFDRMATI~N REC~RgS *~ MNEM CONTENTS TYPE CATE .SIZE CO~E CN : ON.iON OIL COMPANY OF CALIFORNI 000 000 030 065 ~N : TBJ G-Z9 (31-30) 000 000 0t6 065 FN : MCARTNUR RiVeR 000 OOO 01~ 055 RANG: iSW 000 gOO 004 065 T~WN: gN 00'0 000 002 SECT: 29 000 000 002 065 COON: KENAI ~OROdGH 000 000 0i4 065 ~TAT: ALASKA OOO 000 006 065 MNEM CONTENTS ~NiT TYPE CATE SIZE CODE PRES: ~ 000 000 001 COMPANY W~LL COUNT~ ALASKA SCHLUMBORSER ALASKA COMPUTING CENTER = UNION OiL COMPANY OE 'C4LiFORNIA = T~U G-Z9 (31-30) : MC.~RTHUR RiV~R . uRu~GH : ALASKA ~JO5 NUMSER AT ACC: RUN ~ONE, DAT~ LOnG SECTION: Z9 TOWNSHI ENGINEER: M. -SA£H~U LOP: STEPHAN F. STE ~O' /Z-MAR-~5 P:-gN RANGO: VENS .CASING CASiN~ : 13.375 g 2.563 = .,[3.375 ~ 6572 TYP VIS PH FLU FLuI2 = GEL/XC/EiW SiTY = 9.5 LS/G COSITy = 47.0 S LOSS = 7.2 C3 RM ~MF RM AT 5HT = -0.~57 a 66°0 DF : 0..359 2 6~.0 DF = 0.199 ~ 160.0 DF RiX SAND ASE NOTE - THIS DATA IS 'DEPTH SHIFTED TO THE DLL GR LVP OIO.HOZ VERIFICATION LISTING PAGE SCHL~:~G~R LOGS INCLUDe.ED ~[TH THIS MAGNETIC TAPE: 2PEN HOLE- DUAL INDUCTION SPHeRiCALLY F~CUSED L~G (OIL) DUAL LATERLOG ~RE~OLE CO~MPENS~TE~ L~G LITHO OENSIT¥ COMP~NSATEO ~O~ (LOT) COMPENS&TEO NEUTRON LOG £L~CTRgMAGNETIC PROPaGaTION ~OOL (~PT) CASED HGLE- LITHO DENI-SITY COMPENSaTeD LgG Hi SAMPLIN~ RATE- (TWO FILES) LITHg DENSITY CCM~PENSATEO cOMPeNSATED NEUTRON ' ~G (LH? L~TH~ DENSITY COM.P~NSATEO LO~ CL~Z - FiL~ 2) COMPENSATED NEUTRON LOG (LHZ -- FiL~ LVP OiO.HOZ VERIFICATION LISTING PAGE ~ DATA FORMAT REC3RO ~¢ ENTRY 3LOC(S TYPE SIZE 2 I 16 0 JATUM SPECiFiCATION 5LOCKS MN~M SERVICE SERVICE UNiT ID ,O~O~R ~ gEPT DT GR SFLU ILg SP SR. GR CALI RHO5 ORHO NRAT RNRA NPHI PE,~ NCNL FC NL GR MSFL CALl L~ TPL EATT SR FT 5HC ~S/F BHC ~API OIL OHMM OIL DHMM OIL OHMM ~IL GAPI cDT ~API LDT iN LDT G/C3 LDT G/C3 LDT LDT LOT PU LDT LDT CPS LD'T CPS ~LL GAPi ~LL ~MMM ~LL iN DLL OHMM OL L 0 H M M DLL MV EPT NS?M EPT OB/M EPT IN EPT GAPI OEPT ILO GR NRAT NCNL 12753.0000 -999. Z~00 101.96%8 3.~331 -999°2500 3T ILM CALI RNRA FCNL APt LOG O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 90 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 APZ TYP~ CLASS OOO O0 520 80 3i0 O1 220 O1 IZO ilo 44 010 O1 310 01 31~ 01 280 350 02 356 O1 ~20 O1 000 O0 890 O0 358 01 330 330 30 310 270 O~ 280 O1 220 i'0 220 Og 010 132 Ol i30 Ol ZSO O1 REPR COO~ 6.6 6~: 6~ 6:5 API FI~E MOD NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -999.2~00 SR -999.2500 SP '7.Z7~£ RMO8 3.9241 NP~t. 641.8125 GR --99:9.2500 LLS ENTRY 0 1 bO .liN- 1 0 REPR PRgC~SS CODE (OCTAL) 68 00000000000000 ~8 O00OO000000000 68 00000000000000 68 OOOO000000000O ~8 O000000000000O 68 00000000000000 b8 O00000OO000000 68 O000000000000O 68 00000000000000 68 O0000OO000000O 68 O000000000000O 68 00000000000000 68 00000000000000 58 O000000000000O 68 O00000000OO000 58 00000000000000 68 00000000000000 58 00000000000000 ~ 00000000000000 68 OOO00000000000 68 00000000000000 68 00000000000000 68 00000000000000 58 00000000000000 ~8 0000000000000~ 58 O000000000000O 68 00000000000000 68 00000000000000 -999.2500 SF~.U -999.2500 GR 2-'1331 ORHO 47'2656 PEF --999.2500 MSFL -999. 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