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Home My WebLink About182-05003/25/09 A -~~~~ ~l~SWl~~iF"~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh ik N0.515¢. Company: State of Alaska ~~}~~y~~-: ~~ ~, 4~ ~ ~ fy~~ Alaska Oil & Gas Cons Comm Til'~ U Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 .... ne .,::,... MPC-03 AXBD-00015 MEM PRODUCTION PROFILE 03/13/09 1 1 05-276 BOOR-00002 MEM CBL .- 03/08/09 1 1 L2-24 AWL9-00025 PRODUCTION PROFILE 03/22/09 1 1 Y-056 AWJB-00011 MCNL j 11/09/08 1 1 D-12 12113022 RST O - ( 12/04/08 1 1 LGI-04 12103707 RST / ~ 12/25/08 1 1 . .-.-.-.vim r~v.~.~v ~~~~vv~ ri~va-~r ~ u~ p,~~r„rV NIYV f7G1 VI'11Y117V VIYC VVI"T CNV11 1 V: BP Exploration (Alaska) Inc. r ~ , ~," ~ ~ ~ I Petrotechnical Data Center LR2-1 ~ ~~ ,~ -_ 900 E. Benson Blvd. Anchorage, Alaska 99508 r rl) d~ s'9 ~~i'1~1`~ Date Delivered: ''~~ I~ '~ `' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change ESP to Gas Lift 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 45' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1395' NSL, 2326' WEL, SEC. 10, T13N, R10E, UM MPC-e3 At top of productive interval 9. Permit Number / Approval No. 182-050 302-341 1322' SNL, 3790' WEL, SEC. 10, T13N, R10E, UM 10. APl Number At effective depth 50-029-20786-00 1045' SNL, 3695' WEL, SEC. 10, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1045' SNL, 3695' WEL, SEC. 10, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 8848 feet Plugs (measured) true vertical 7820 feet Effective depth: measured 8635 feet Junk (measured) Fish: Baker Model FB-1 Pkr with screen and tail pipe at true vertical 7607 feet 8130' (11/02); Milled out FB-1 Pkr at 8353' MD (11/94) Casing Length Size Cemented MD TVD Structural Conductor 115' 20" Cement to Surface 115' 115' Surface 2316' 13-3/8" 4500 sx Arcticset II 2316' 2316' Intermediate Production 8759' 7" 500 sx Class 'G', 300 sx Arcticset I 8759' 7731' Liner Perforation depth: measured Open: 7894' - 7912', 7950' - 8014', 8062' - 8080', 8086' - 8118' true vertical Open: 6919' - 6935', 6968' - 7023', 7066' - 7081', 7087' - 711 ~li~'C~,/V~,D Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 7771' Packers and SSSV (type and measured depth) Baker Model S-3 Hydro set Packer at 13. Stimulation or cement squeeze summary n~70'~urage C01//1'fl/$$/0/~ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify~o~correct to the best of my knowledge Si.clned Sondr~ , Title Technical Assistant Date ¢ (,..~ Prepared By Name/Number: $ondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPC-03 Common Well Name; MPC-03 Spud Date; 8/15/lg82 Event Name: RECOMPLETION Start: 11/3/2002 End: 11/12/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/12/2002 Rig Name: NABORS 4ES Rig Number: -Date Fr°m.~T°,'HoUrS~i-TaSk. iCod~-!Np~.:~i,~l..~seii.:-!i~:~:'i~- ~ DescriPtion-ofoperati°ns , 11/8/2002 06:00 - 14:00 8.00 MOB P PRE MI/RU & SAFE OUT EQUIPMENT/RIG ACCEPT (~ 1400 HRS. 11/08/2002 14:00 - 16:00 2.00 KILL P DECOMP i PULL BPV/RU TO KILL WELL TEST LINES TO 3500 PSI. 16:00 - 19:00 3.00 KILL P DECOMP ClRC WELL BORE INFLUX OUT WITH SEAWATER. & MONITOR SAME. 19:00 - 19:30 0.50 WHSUR P DECOMP SET TWC & TEST TO 3000 PSI. 19:30- 20:30 1.00 WHSUR P DECOMP NIPPLE DN TREE 20:30- 22:30 2.00 BOPSUI~ P DECOMP NIPPLE UP BOP'S 22:30 - 00:00 1.50 BOPSUI~ P DECOMP TEST BOP TO 250/3500 (TEST WAIVED BY CHUCK SHEVE WITH AOGC) 11/9/2002 00:00 - 03:00 3.00 PULL P DECOMP RIG LUB & PULL TWC & MU LANDING JT. & PULL HANGER TO FLOOR & LAY DN SAME. & MAKE ESP CABLE CHECK. 03:00 - 15:00 12.00 PULL P DECOMP ~POOH LAYING DN 3.5" VAM TBG & ESP ASSY. 15:00 - 17:00 2.00 FISH P DECOMP LOAD 3.5" DP IN PIPE SHED & DRIFT & STRAP 17:00 - 19:00 2.00 FISH P DECOMP MU FTA#1 6" MILL+3-JUNK BASKETS+BUMPER SUB+JARS+10-4-3/4" DC. 19:00 - 00:00 5.00 FISH P DECOMP RIH WITH FTA#1 11/10/2002 00:00 - 04:30 4.50 FISH P DECOMP RIH WITH FTA #1 TO PKR @ 7769' 04:30 - 07:00 2.50 FISH P DECOMP MILL FB-1 PKR (~ 7769' 07:00 - 10:00 3.00 FISH P DECOMP SET KELLY BACK & PUSH PKR TO 8120' 4ES KB & CORRECTED TO ORIGINAL PKR TOP @ 8130' ,10:00 - 12:00 2.00 FISH P DECOMP LAY DN DRILL PIPE TO 5800' 12:00-12:30 0.50 WHSUR P DECOMP MU HES RTTS PKR & SET @ 55' BELOW GL & TEST TO 2500 PSI. 12:30- 14:00 1.50 BOPSUIq P DECOMP NIPPLE DN BOP'S 14:00 - 18:30 4.50 WHSUR P DECOMP NIPPLE DOWN TBG. HEAD GEN. 2 (HARD REMOVAL ) 18:30 - 20:00 1.50 CASE P DECOMP MU UP BAKER CENTER SPEAR & SPEAR 7" 29~ CSG. & ATTEMPT TO REMOVE SLIPS AFTER APPLYING ALL METHODS AVAILABLE DECISION MADE TO MACHINE PACKOFF AND LEAVE SLIPS IN PLACE. 20:00 - 23:00 3.00 WHSUR P DECOMP SENT PACKOFF TO BAKER MACHINE AND MACHINED TO TOLERANCE. 23:00 - 00:00 1.00 WHSUR P DECOMP INSTALLED NEW PACKOFF & TBG. SPOOL 11/11/2002 00:00 - 01:00 1.00 WHSUR P COMP SET PACKOFF ON 7" & NIPPLE UP TBG. SPOOL & TEST PACKOFF TO 5000 PSI. 01:00 - 03:00 2.00 BOPSUI; P COMP NIPPLE UP BOP STACK 03:00 - 04:30 1.50 BOPSUI; P COMP TEST ALL BOP BREAKS TO 3500 PSI. 04:30 - 05:00 0.50 PULL P COMP MU RTTS RUNNING TOOL & RIH TO SAME & OPEN VALVE AND MONITOR PRESSURE 120 PSI & BLEED SAME TO 0 & MONITOR (OK) PULL & LAY DN PKR. 05:00 - 10:30 5.50 PULL P COMP LAY DN 3.5" DP & BAKER FTA #1 10:30 - 12:30 2.00 EVAL P COMP RIG HES & RUN GR/JB TO 7854' & POOH & RIG DN HES. 12:30 - 21:00 8.50 RUNCOll I3 COMP RIG TOOLS & RIH WITH GAS LIFT COMPLETION ON 2-7/8" TBG. TO 7770' SETTING DEPTH. 21:00 - 22:00 1.00 RUNCOll 13 COMP MU HANGER & LAND & RILDS & SET TWC. & TEST TO 3500 PSI. 22:00- 00:00 2.00 BOPSUI; P COMP NIPPLE DN BOP 11/12/2002 00:00 - 01:30 1.50 WHSUR P COMP NIPPLE UP TREE 01:30 - 02:00 0.50 WHSUR P COMP PULL TWC 02:00 - 02:30 0.50 RUNCOlt 13 COMP TEST LINES & 1" BALL & ROD FOR PKR. SETTING. 02:30 - 06:00 3.50 RUNCOll 13 COMP PRESSURE TBG. TO 3500 PSI.. & HAD BLEED OFF & DECISION MADE TO MAINTAIN 3500 PSI. AT 1-BPM FOR 5-MINUTES TO ENEGERIZE PKR. & RELEASE & TBG. Pnnted' 11/12/'2002 1041'49AM Legal Well Name: MPC-03 Common Well Name: MPC-03 Spud Date: 6/15/1982 Event Name: RECOMPLETION Start: 11/3/2002 End: 11/12/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/12/2002 Rig Name: NABORS 4ES Rig Number: Date--. From.-:-:To HOU~ !:~Task ~e ~PT ~ha.se-i ?':DescriP~'.tion~of Operations ?... 11/12/2002 02:30 - 06:00 3.50 RUNCOI~ I3 COMP :BLEED SLOWLY TO 0, & RIG HB&R & PUMP DN ANNULUS WITH DIESEL & CATCH FLUID AFTER PUMPING 33-BBL. & PRESSURE TO 1000 PSI. & SUSTAIN THIS FOR 5-MINUTES & ATI'EMPT TO GO TO 1500 PSI. WITH PRESSURE & RP iVALVE SHEARED 1450 PSI. DUE TO NO HYDROSTATIC IN TBG.ETC. & 1000 PSI. SHOWED THAT PKR. WAS SET BECAUSE WELL BORE WILL NOT SUSTAIN A PRESSURE OF 1000 PSI. AND COLUMN OF FLUID, FREEZE PROTECTION FOR ANNULUS AND TBG. WAS CONTINUED. & BPV WAS RELEASED FOR MOVE TO MPF-09 .AT 0600 HRS. 11-12-02 / PE'S WILL PULL ROD & BALL & SET PLUG & PULL RP & SET DUMMY TO TEST FURTHER TO ENSURE THAT ALL IS WELL. Pnnted- 11/12/2002 1041 49AM bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 31,2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: / Re: Sundry Notice for MPC-03 --- Change out ESP and replace it with Gas Lift. BP Exploration Alaska, Inc. proposes to convert well MPC-03 from a failed ESP /'' producer to a Gas Lifted producer as part of the Milne Point Kuparuk Water / MI Flood Development project. MPC-03 was drilled in 1982 and completed in 1985. The well has had three ESP pumps installed with the longest run,time being 2480 days. The failure is believed to be related to old age and gas~. The GOR has been rising in the well and is currently running around 2500 scf/bbl. At this current level, the environment is considered very poor for an ESP and much more suitable to Gas Lift. A RWO is planned for around the 5th of November, the scope of work is to pull the ESP completion and 3 1/2" tubing, repl, Jace the pack off around the wellhead, and install a 2 7/8" Gas Lift completion. '. Please see attachments for diagrams of the current and proposed wellbore diagrams. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5943 or e-mail me at AivanoMJ@bp.com. Sincerel~,~./lJ/ Milne Point Unit Petroleum Engineer ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: ESP Changed to Gas Lift Temp Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Vadance _ Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3884' FNL, 2326' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 1322' FNL, 3790' FEL, Sec. 10, T13N, R10E, UM At effective depth 1045' FNL, 3695' FEL, Sec. 10, T13N, R10E, UM At total depth 1045' FNL, 3695' FEL, Sec. 10, T13N, R10E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic __ Service__ (asp's 558131, 6029678) (asp's 556643, 6032228) (asp's 556735, 6032506) (asp's 556735, 6032506) 6. Datum elevation (DF or KB feet) RKB 45.0 feet 7. Unit or Property name Milne Point Unit 8. Well number MPC-03 9. Permit number / approval number 182-050 10. APl number 50-029-20786-00 11. Field / Pool Miline Point Unit / Kuparuk River Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 53' Surface 2289' Production 8732' 8848 feet Plugs (measured) 7785 feet 8635 feet Junk (measured) 7593 feet Fish (milled out packer) @ 8353' MD. Size Cemented Measured Depth True vertical Depth 20" Cement to Surface 80' 80' 13-3/8" 4500 sx Arcticset II 2316' 2316' 7" 500 sx 'G', 300 sx AS I 8759' 7024' Perforation depth: RECEIVED measured Open Perfs 7894'-7912', 7950'-8014', 8062'-8080', 8086'-8118' OCT 3 1 '2002 true vertical Open Perfs 6919'-6934', 6968'-7023', 7066'-7081', 7086'-7115' Alaska' 0ii & Gas Oons. Commission Tubing (size, grade, and measured depth 3-1/2" 9.3# L-80 to 7674". ESP @ 7717'. 3-1/2" Screen Assembly from 71~0-01~'. Packers & SSSV (type & measured depth) 7" Baker Model FB-1 Isolation Packer @ 7769'. 3-1/2" X 1" Camco KBUG-CP GLM @ 126'. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: / November 5, 2002 16. If proposal was verbally approved Oil X Name of approver/ ~ ~'l~ate approved Service 17. I hereby certify that tJ~e foreg~f~g"is true an~ c~bb(~ the b-e~. my knowledge. Signed ¢/~~/~~// ~'itle: M ilne Petroleum Engineer Michael ,~no- - (.. V "- ~ FOR COMMISSION USE ONLY Gas__ Suspended_ Questions? Call Michael Aivano @ 564-5943. Date October 31,2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so represent~a~ive may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test__ Ong~nal S~gned By Subsequent.form required 10- Cammy 0echsli Taylor Approved by order of the Commission Approval no. O or r ,ss,o e Form 10-403 Rev 06/15/88 · ORIL IN L SUBMIT IN TRIPLICATE TBG HGfl: 3.5" FMC, 3.5" EUE 8fiD!,// BF. ELEV = 27' (Nabors 27) TOP AND BOTTOM i 20", 92# Grade B 1L~..j._~ ~ // I ~CP PELP KOP @ 2400' Max Angle = 40° @ 3800'MD / / GAS LIFT MANDRELS Min Angle = 26.5° @ 8400'MD / (3.5" x 1" W/BK-2 LATCH~ .'~ I N° MD(BKB/ TVDss Well Profile = Slant Hole ; / ~ 2 / 126 81 ~ // 17557 6580 3.5", 9.3#fit, VAM, L-80 TUBING // I ID: 2.092", Drift: 2.867" .__ _/. CAPACITY: 0.0087 BBL/FT #2 CL-350 ESP POWER CABLE / // ----..il 3.5" X 1" CAMCO KBUG- CP I 7557MD I NOTE: THIS WELL HAS PASSED "NO / FLOW" TEST. / / CENTRILIFT ESP 7674 MD GC1200, 146 STAGES CENTRILIFT MOTOR 7702 MD I 130 HP, 2145 V, 35 A I 7717MD I CENTRILIFT PHD PERFORATION SUMMARY REF LOG: SWS DIL/GR 5/15/82 Z ~ -- BAKER MODEL FB-1 I I TOP PERF AT 6875 TVDSS I]] []:1 PACKER (4.00" ID) 7769 MD ! ~ 20 GAUGE 3-1/2" I I ! ~ ~ BAKERWELD 7772 MD SIZE SPF INTERVAL OPEN/SQZ'D SCREEN 5" I 12 7894'- OPEN.~ WITH3'5" XN NIPPLE (ID=2.75") 7797 MD PXN PLUG 3-3/8" 6 7912' OPEN 3.5" I 7799MD I 7950' - WLEG 8118' NOTE THAT THE DEEPER INTERVAL WAS ORIGINALLY PERFORATED WITH 5"GUNSAT 12SPF ,~ 11/29/94 PBTD~'[ 8353' FISH: MILLED OUT . . k, (FISH) 7" 29#, L-80, PACKER 8759' BTRS DATE REV. BY COMMENTS L/ MILNE POINT UNIT 5/20/82 DBR DRIL WELL C-03 8/11/90 DBR RWO APl NO: $0-029-20789 8/8/94 D H RWO 11/29/94 DBR RWO BP EXPLORATION {AK) GAS LIFT MANDRELS f3.5" x 1" W/BK-2 LATCH3 N° MDfBKB3 TVDss 2 126 81 1 7557 6580 SIZE SPF INTERVAL OPEN/SQZ'D 5" 12 7894' - OPEN 3-3/8" 6 7912' OPEN 7950' - 8118' Proposed MP C-03 WELLHEAD: 13-5/8" 5M'. ,~lC GEN II TBG HEAD: RETROFIT 11" 5M FMC .... ~ .... ORIG. KB. ELEV = 45' TBG HGR: 3.5" FMC, 3.5" EUE 8RD I ~ BF. ELEV = 27' (Nabors 27) PELP ' Camco glm. kbmm. w/bk latch KO~ 2400, I i # i md tvd dg , ~i~ ' ' 6 '7~n Max Angle = 40° @ 3800'MD 5 7337 '~'~ 4 6622 Min Angle = 26.5° @ 8400'MD ::?:i~' ~ 3 5553 Well Profile = Slant Hole : ~i:.!?: 2 4017 13 3/8", 72#/fl, L-80 Butt I 2316' I-- ~ i, 1 2183 , 2 7/8", 6.4#, L-80 TUBING NOTE: THIS WELL HAS PASSED "NO FLOW" TEST. I /2 7/8" X-Nipple ............................................................ ! 7"x 3.5" Packer 17730' ~~ 2 7/8" XN Nipple w/2-205'' ID ' 7750' MI~ PERFORATION SUMMARY 2 7/8" WLEG I 7769' MI~ REF LOG: SWS DIL/GR 5/15/82 I I TOP PERF AT 6875 TVDSS I I 3-3/8" 6 7950' -8118' OPEN - i NOTE THAT THE DEEPER INTERVAL vv^s 8353' FISH: MILLED OUT ik (FISH) 7" 29#, L-80, 8759' PACKER BTRS DATE REV. BY COMMENTS MILNE POINT UNIT 5/20/82 DBR DRILL~ WELL C-03 8/11/90 DBR RWO APl NO: 50-029-20789 8/8/94 D H RWO 11/29/94 DBR RWO BP EXPLORATION {AK) Camco glm. kbmm. w/bk latch # md tvd dg 6 7680 5 7337 4 6622 3 5553 2 4017 1 2183 SIZE SPF INTERVAL 3PEN/SQZ'D 5" 12 7894' - 7912' OPEN 3-3/8" 6 7950'-8118' OPEN MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~~0~ Commissioner Tom Maunder, ~9~~~'~ P. I. Supervisor~' ~,,>%"o\ DATE: May 19, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne point Unit C Pad May 19, .2001' ! traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12/98 supplement to the 3/30/94 S¥S policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy Supplement, I told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Weils.~f4,6 & 14 were shut in for repairs. SUMMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6failures witnessed. 25% failure rate. 20 well houses inspected. Att~,chments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL,. SVS MPU C Pad 5-19-01jc AlnL Oil and Gas Conservation Commis(.on Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme" ' AOGCC Rep:., ~c~hn Cr~,i~'" Submitted By: John Crisp Date: Field/U~ad: Mil~ Point Unit c Pad Separator psi: 'LPS 140 I-~ 5119/01 J i ill Well Pemit Separ ~t ~ T~t T~t T~t Date Number ~umb? PSI PSI ,Trip ,Code Code, Code Pass~ a~ or ~C~ C-01 1811430 140 100 110 P P OIL , , , , , , C-02 1821940 c-o3 .... ~ 82os~ ~4o ~oo " 95 p ~ ' ' om C-~ .... 1821'260 140 100 110 p " 4 ..... 0IL 'C-'05A' 1842430 '140 ' 100 '100 'P P ' ' OIL C-0'6 "i842410 4300 2~0 1950 P 4 ' WAG c-o7 ~8~0o2o "i40~oo' ~5e" ' 4 .....oi~ C-08 ~' 1850140 '4300'2000 1900 P 4 ..... WAG ...................... ,, , ,, ~ ,, , ~ C-09 1850360 140 100' 105 P P OILi C'13 1850670 c-~4 '~85o88o~ ' ~40' ~oo ~00 e ~ ' ' o~ , , ~, ,~, ,~ , ,,,, ~ ~ ~ ,, C-15 1851030 ~C-17 1852630 , , , , , ,, , , ~ , , ,,, C-20 1890150 , , , ,, , , ~. ~ , ~ , , ~ , , ,,, . C-21 1940800 C'22~ ....... 1951980 140 100 'gs e e ....... C'23 1960160 C-25A 1960210 4300 2000 1900 P 4 ....... WAG C.26 .... 1952060 ................. c-28 19602~: C-36 1980610' ' C-39 1972480 , , , ,, ,, ,, ~,, , , 'C-40 2002130 c-10 1850150 4300 2000 1850 ' 'P " ' P ' ......... WAG , , , , J ,,, ,,,,,, , , ,, , , ,, ~ , ~ , , Wells: 12 Components: 24 Failures: 6 Failure Rate: 25.00o,~ 9,0 Remarks: R3F 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ,~.~'" Commissioner DATE: November 18, 2000 THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Grima~, Lo~ ~. SUBJECT: Petroleum Inspector SVS tests BPX C-pad Milne Point Unit Kuparuk River Field Saturday~ November 18, 2000; I witnessed the SVS tests on BPX C pad in the Milne Point of the Kuparuk River Field: This was the three-month test for this pad due to a 26% fail rate witneSsed' by Inspector Jeff Jones on 7~9~00. The wells did somewhat better this. time although the fail rate of 13.6% was still above the 10% expectable limit. Again, the gas injeCtors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV. The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spool adapter, Larry Niles (MPU OI advisor) will pursue this with the wellhead manufacturer as to proper repair and report back to me. The wellhouses were all very clean and it appears to be a high priority in the Milne facility. SUMMARY: I witnessed the SVS test on BPX C pad in the Milne Point Unit. 1 pad, 11 wells, 22 components, 3 failures. Wellhouse InspeCtions; 14 wellhouses, 1 failure (leaking T.S.A.) Attachments: SVS MPU C pad 11-'18-00 LG.XLS ,c,c: Niles/Shipley (MPU OI advisers) NON-CONFIDENTIAL SVS MPU C pad 11-18-00 LG.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Gfimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: K.R.F./M.P.U./C pad Separator psi: LPS 140 Date: 11/18/00 HPS Well Permit Separ Set L~ Test Test Test Date Oil, WAG, G~J, Number Number PSI PSI Tdp Code Code Code Passed GASorCYCLE C-01 1811430 140 100 120 p p O~ C-02 182194O C-03 ~i~8~0~' r i:? 140 100 105 p p O~ C--04 ...... 1821260 140 100 105 P 4 OIL C'05A 1842430' 140: 100 105 P P C'06 1842410 C--07 1850020 140 100 110 p p OIL! C'08 1850140: ' C--09 1850360 ' 140 100 '80 p p O~ C'13 1850670 ' C'14 1850880 140 100 105 p p OIL C'15 1851030 C'17 1852630~ C'20~ 1890150 C'21 1940800 C'22A 1951980 140 1001 110 p p' O~ C'23 1960160 C'25A 1960210 4000 2000 · 2000 P 4' WAG C--26 1'952060 ' 'C'28 1960290 4000 '2000 2000 P p WAG' C'36 1980010 , C-39 1972480 · C-19i 1852960 4000 2000 2000 P 4 WAG Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.6%[~ 9o var Remarks: C-03 has 'gas le_ak on Tubing Spool adapter, Develop plan for repair and report back. 11/20/00 Page 1 of 1 V0kltrl6.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor · FROM: Jeff Jones~, ~/~ ~/~- SUBJECT: Petroleum I DATE: July 12, 2000 Safety'Valve Tests Milne Point Unit B & C Pads July 9, 2000' I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9wells, 18 components tested~..1, failure. 5,5% failure rate. MPU C Pad~' 12 wells, 23 components tested, 6 failures. 26% failure rate. 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NO.N,CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kupamk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 Well PermR Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI T~p Code Code Code gAS or CYCLE C-01 1811430 140 100! 95 P P OIL ~ 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A ~t951980 140 100 · 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 196:0290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 ' WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%W390 var Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). .Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 V 1 v7irqm.xls '( STATE OF ALASKA ( · ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate x Plugging Perforate x Pull tubing x Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1395' NSL, 2326' WEL, SEC. 10, T13N, RIOE At top of productive interval 3958' NSL, 3790' WEL, SEC. 10, T13N, RIOE At effective depth 4277' NSL, 3682' WEL, SEC. 10, T13N, RIOE At total depth 4369' NSL, 3651' WEL, SEC. 10, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical 8848 7785 Repair well x Other 5. Type of Well: Development X Exploratory Strut/graphic Service ORIGINAL feet feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 45' feet 7. Unit or Property name Milne Point Unit 8. Well number MPC-03 9. Permit number/approval number 82-50/94-165 10. APl number 50- 029-20786 11. Field/Pool Kuparuk River Field Effective depth: measured true vertical 8635 feet 7593 feet Junk (measured) Fish - (milled out packer) @ 8353' MD Casing Length Structural Conductor 53' Surface 2289' Intermediate Production 8732' Liner Perforation depth: Size Cemented Measured depth True vertical depth 20" 13-3/8" To surface 80' 80' 4500 sx Arcticset il 2316' 2316' 7" 500 sx "G" & 300 sx AS I 8 759' 7024' measured 7894'-7912', 7950'-8014', 8062'-8080', 8086'-8118' true vertical 6919'-6934', 6968'-7023', 7066'-7081', 7086'-7115' Tubing (size, grade, and measured depth) 3-1/2", 9.2//, L-80 tubing to 7686"MD; Centralifl ESP @ 7800'MD 3-1/2" tail 7862'-7889' MD Packers and SSSV (type and measured depth) Baker Model D packer @ 7859' MD R ~ C ~ ! V ~ D 13. Stimulation or cement squeeze summary AUG S 1 994 Intervals treated (measured) Treatment description including volumes used and final pressure A~aska O~,l & Gas Cons. C0mmissi0a Anch0m~e Perforations fracced with 402M # 16/20 Carbolite Final Pressure -- 3065 psi 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or In!ection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of W,~ll Operations x 17. I hereby certify,~'[a~e fore_going is tru~ Signe~L ~CJ~ 16. Status of well classification as: Oil x Gas Suspended Service and correct to the best of my knowledge. Form 10-404 Rev ~/15/88 Title Drilling Engineer Supervisor SUBMIT IN Dt MP C-03 07/28/94 8,759' MOVE RIG FROM C-21 TO C-03. SPOT OVER WELL. REMOVE KILL AND CHOKE LINE VALVES FROM MUD CROSS AND ANNULUS. ND TREE. PRESSURE UP CONTROL LINE TO OPEN TRSSSV. NU BOPE CHANGING STACK ARRANGEMENT. RIG ACCEPTED @2100 HR'S ON 07/27/94. 07/29/94 8,759' NU BOPE. TEST BOPE AND ANNULAR. XO BLIND RAMS. PULL TWC. RD TEST EQUIPMENT. RU SLICK LINE TO PULL PXX PLUG. 07/30/94 8,759' SERVICE RIG. RU SLICK LINE. TEST BOP AND LUB. RIH W/1.75" GS AND EQ PRONG TO 541'. POH. RIH W/1.75" GS. UNABLE TO LATCH PLUG. POH. FINE METAL FILINGS ON TOOL. RIH W/1.5" PUMP BAILER. BAIL @558'. POH. RECOVERED ICE CHUNKS AND DEBRIS. RERUN SAME. RECOVERED SAME. RERUN EQ PRONG. RERUN 1.75" GS. UNABLE TO LATCH PLUG. POH. RU TO PRESS TBG TO SEE IF SHIFTED. CIRC DIESEL through SYSTEM. RU ON TBG PUMP 1/2 BBL DIESEL AND PRESSURE UP. PLUG NOT SHIFTED. RIH W/1.75" IMP BLOCK. SHOWED TOP OF PLUG CLEAN, MAYBE SOME DEBRIS AROUND OUTSIDE. RERUN PUMP BAILER. RECOVERED MORE METAL AND PIECE OF RUBBER. RERUN BAILER. SMALL AMOUNT OF ICE AND DEBRIS. RERUN EQ PRONG. NO-GO. RERUN BAILER. NO RECOVERY. RERUN PRONG. NO-GO. RERUN BAILER, NO RECOVERY. MADE 2 RUNS W/1.75: DUMP BAILER, ATTEMPTING TO DUMP MECH. UNABLE TO DUMP. RIH W/1.75" GS AND LATCH PLUG. PRESS TBG WITH DIESEL. OPEN ANNULUS AND BLEED OFF VACUUM. JAR ON PLUG. WENT DOWN WHEN RELEASED. LET TBG EQUALIZE. POH. RD SLICK LINE. INSIDE OF PLUG PACKED WITH ICE AND DEBRIS. CIRC WELL W/HEATED SOURCE H20. RETURNS CUT WITH CRUDE AND GAS. WO H20. FILTER AND HEAT ADDITIONAL PROG H20, CIRC TOTAL OF 320 BBL'S TO CLEAN RETURNS. CIRC. PUMP 80 BBL'S DIESEL DOWN ANNULUS. U- TUBE TO TUBING. 07/31/94 8,759' SERVICE RIG. BOLDS. PULL HGR AND 7" PKR LOOSE. LD HANGER AND LANDING JT. POH W/TBG TO PKR. MAINTAIN HOLE FILL W/DIESEL. CONT. POH. SLM AND DRIFT VAM AND 3.5" EUE TBG. MIX 30 BBL XANVIS PILL. PUMP DOWN TBG AND CHASE W/32 BBL SOURCE H20. CONT. POH W/TBG. FILL HOLE W! PROD H20. FL LOSS GRADUALLY DECREASED. CIRC WELL 70 BBL'S DIESEL FOR FREEZE PROTECTION @1900'. FINISH POH. CHECK OU AND LD ESP. ND RISER, NU SHOOTING FLANGE. ~ [ AUG ~ ~ ,]994 - Oil & Gas Cons. CommiSsion Anchor~e 08/01/94 8,759' NU SHOOTING FLANGE. RU ATLAS WIRELINE W/46' LUBRICATOR. TEST. RIH W/40' DUMMY GUN. TIE IN TO SOS DIL/GR DATED 5/15/82. TAG UP #8354'. POH. RIH. POOH. HOLE FILL: 10 BBL'S. RIH W/SAME. POH. 22 MISFIRES. HOLE FILL: 6 BBL'S. RIH W/SAME. POH. 1 MISFIRE. HOLE FILL: 6 BBL'S. RIH W/24' GUN. POH. HOLE FILL: 3 BBL'S. RD ATLAS. ND SHOOTING FLANGE. NU FLOW NIPPLE. PU BAKER MODEL C-1 FULLBORE PKR. RIH ON 3.5", 15.5# DRILL PIPE. RU BJ TO FRAC TEST LINES. DATA FRAC. RUN ANALYSIS. 08/02/94 8,759' FRAC AS PER ATTACHED FRAC TREATMENT REPORT. WO GEL TO BREAK IN WATER BATH. OPEN BYPASS ON FULLBORE PKR. MONITOR WELL. RELEASE PKR. POH AND LD PKR. SET WEAR RING. RU TO RUN TUBING. MU SHOE. RIH. CIRC DIESEL OUT OF WELL. CONT. RIH W/TBG. TAG SAND @7276'. REVERSE CIRC SAND F/7276-7737'. CBU EVERY 150'. 08/03/94 8,759' SERVICE RIG. REVERSE CIRC SAND F/7737-8112'. CBU EVERY 150'. MONITOR FLUID LOSS. POH 2 STANDS TO 7925'. MONITOR FL. MIX AND PUMP 30 BBL XANVIS PILL. MONITOR FL AND REFILL PITS. RIH 2 STANDS. REVERSE CIRC SAND F/8112-8353'. CBU EVERY 100'. REVERSE CIRC TWO XANVIS SWEEPS TO CLEAN HOLE. SPOT XANVIS PILL ACROSS PERFS. POH. LD 3.5" DO AND STAND BACK TUBING. 08/04/94 8,759' SERVICE RIG. POH TO 2000'. DISPLACE HOLE TO 70 BBL'S DIESEL FOR FREEZE PROTECTION. FINISH'POH. RU ATLAS WIRELINE. MADE 4 RUNS W/6" GAUGE RING AND JUNK BASKET TO 7890'. FIRST RUN RECOVERED CONTROL LINE AND BAND AND SEVERAL LARGE PIECES OF RUBBER. NEXT TWO RUNS RECOVERED DIMINISHING AMOUNTS, AND SMALLER PIECES OF RUBBER. LAST RUN WAS CLEAN. RUBBER APPEARS TO BE FROM THE ANNULAR PREVENTER. IT WAS APPARENTLY DAMAGED WHILE STRIPPING THROUGH IT DURING THE POST FRAC CLEANOUT. MU AND RIH W/BAKER MODEL "D" PACKER AND SCREEN ASSEMBLY. CORRELATE TO SOS DIL/GR DATED 05/15/94. SET PKR @7859'. WLEG @7889'. POH AND RD ATLAS. PULL WEAR RING. RU, PU AND RUN ESP COMPLETION STRING. 08/05/94 8,759' SERVICE RIG. FINISH RIH W/ESP COMPLETION. MU HANGER AND LANDING JT. MU PENETRATOR AND MAKE PIGTAIL SPLICE. ATTEMPT TO LAND HANGER. HANGER LACKING 8' OF LANDING. WORK WITH HANGER. AUG 5 1 1994 Oil & Gas Cons. Commission Anchorage UNABLE TO LAND. PULL RIG TO FLOOR. LOWER EDGE OF COLLAR BELOW 2.61' HANGER PUP APPEARS TO BE HANGING ON 7" CSG STUB. BELOW LOWER, OUTSIDE EDGE OF TBG COLLAR AND TRY TO RELAND. STILL HANGING. BEVEL AND ROUND SOME MORE. LAND HANGER. RILDS. SET TWC. CHANGE RUBBER IN ANNULAR PREVENTER. ND BOP. CHECK ESP ELECTRIC LINES. NU TREE. 08/06/94 8,759' FINISH NU TREE. TEST HANGER SEALS, ADAPTER FLANGE, AND TREE. OK. FREEZE PROTECT ANNULUS AND TBG TO 2000' W/70 BBL'S DIESEL. SET BPV. SECURE CELLAR. RELEASE RIG @1130 HR'S ON 08/05/94. REEEIVED AUG 5 1 1994 0ii & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date= 8 August 1994 RE: Transmittal of Data ECC $= 6248.01 Sent by= U.S. MAIL Data= NONE Dear Sir/Madam, Reference: /~ BP MPC-03 q~ MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 CCL/PACKR FINAL BL Run # 1 1 CCL/PACKR RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Receive Suite 201 Anchorage, AK 99518 Att.~. ~dney D. Paulson .~.eturn %0. ~ ,~ta Center BP ~.~ .oration ,Alaska) Ino 900 East Benson Boulevard Anchorage, Alaska 99508 Date ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date= 5 August 1994 RE: Transmittal of Data ECC #: 6248.00 Sent by= U.S. MAIL Data= PL Dear Sir/Madam, Reference: BP MPC-03 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: PFC/PERF FINAL BL PFC/PERF RF SEPIA Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Att~dney D. Paulson Received Please sign and return Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 9~08 ~eceived by Dete ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.33 TELECOPY: (907) 2767542 July 28, 1994 Hal Stevens/John Hendrix Prod Spvr Wells BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX ~U~:?!i~ells and L-5 PTD 82-050 and D 90-039 Dear Mr. Stevens/Hendrix: On July 20, 1994, our Inspector Jerry Herring witnessed no-flow tests on BPX's MPU wells No. C-3 and L-5. The wells had been shut-in and were bled down. Both wells were essentially dead, venting a small amount of gas. from the tubing. The Inspector concluded that subject wells were not capable'of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valves from BPX's MPU wells C-3 (?TD 82-050) and L-5 (PTD 90-039) on the condition that the low-pressure sensors and surface safety valves must be maintained in good condition; and, if for any reason, the wells again become capable of unassisted flow of hydrocarbons, the subsurface safety valve(s) must be reinstalled and maintained in good working condition. Sincerely, Blair E. Wonq~fell PI Supervisor c: Larry Niles/John Ketchum Jerry Herring bew/nlmp3cl 5 ~ p~i~ed on recycled paper b y C,D MEMORANDU,., State d. Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto~-'~' Chairman~:~ THRU: Blair Wondzell, ~ P. I. Supervisor -~/~-,~ FROM: J..er. ry.Horri.ng, ~}eI~. I-'etroleum Inspector DATE: July 25, 1994 FILE NO: lw9kgtbe.doc SUBJECT: No Flow Tests BPX, Milne Pt. Unit MPU C-3 & L-5 c.$ Wednesdav,~Julv 20, 1994: I traveled to BPX's Milne Point Unit to witness no flow . testing on wells C-3 and L-5. The~wells were shut-in and depressurized upon my arrival. Both wells demonstrated good no-flow capabilities. Well L-5 had a down hole pump failure problem. A workover of L-5 is planned for the near future. Well C-3 had been on gas lift and traces of gas vented from the tubing throughout the day as the lift gas worked its self out of the system. Both of these wells demonstrated that they are not capable of unassisted flow. Summary: I witnessed no flow tests on MPU wells C-3 & L-5. ~¢...: ..._~ ....... - 1 A KA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVALS Abandon ~ Suspend m Operation Shutdown ___ Re-enter suspended well __ Alter casing ___ Repair well 'x . Plugging Time extension __ Stimulate ~ Change approved program Pull tubing x Variance Perforate x Other 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1395' NSL, 2326' WEL, SEC. 10, T13N, RIOE At top of productive interval 3958' NSL, 3790' WEL, SEC. 10, T13N, RIOE At effective depth 4277' NSL, 3682' WEL, SEC. 10, T13N, RIOE At total depth 4369' NSL, 3651' WEL, SEC. 10, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploram~y Sffatigraphic JUN 22 994 0it & Gas Cons. C0mmissio~ Anchorage 8848 feet Plugs (measured) 7785 feet Effective depth: measured true vertical 8635 feet Junk (measured) 7593 feet Casing Length Structural Conductor 53' Sudace 2289' Intermediate Production 8732' Liner Perforation depth: 6. Datum elevation (DF or KB) -~ KBE = 45' feet 7. Unit or Property name Milne Point Unit 8. Well number MPC-03 9. Permit number 82-50 10. APl number 50- 029-20786 11. Field/Pool Kuparuk River Field Fish - (milled out packer) @ 8353' MD Size Cemented Measured depth 20" To surface 80' 13-3/8" 4500 sx Arcticset I! 2316' 7" 500 sx"G" & 3OO sx AS l 8759' measured 7894'-7912', 7950'-8014', 8062'-8080', 8086'-8118' True vertical depth 80' 2316' 7024' true vertical 6919'-6934', 6968'-7023', 7066'-7081', 7086'-7115' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 tubing to 7807' MD Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 527'MD; Otis RDH Packer @ 548' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 7/20/94 16. If proposal was verbally approved Oil x Gas ~ Name of approver Date approved Service 17. I hereby ce~fy~J, hat~he foregoing is true and correct to the best of my knowledge. Signed ~f (_~~.~7// ///1~' ~/ Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY 15. Status of well classification as: Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ~ OZt Original Slgned By 0avid W. JohnSton I Approval No.? ~7/..../~'~"'-- Commissioner Approved Copy Returned SUBMIT IN TRIPLICATE Approved by order of the Commission Form 10-403 Rev 06/15/88 Suspended~ MP C-03 RW(~' AND FRAC SUNDRY INFORE( rlON Ob!ective: The objective of this workover is to pull a failed ESP from the well, add additional pedorations, perform a fracture treatment on the entire Kuparuk interval, and recomplete the well with the existing 3.5" tubing and an ESP. Scope: , Pre- rig: Shift sleeve or punch hole in tubing immediately above ESP. Bullhead kill well and circulate with source water. Install XX plug in X nipple at 557 MD. Install BPV. Remove wellhouse and flowline. , MIRU Nabors 4ES workover dg. Pull XX plug. Circulate as necessary. Pull existing 3.5" VAM tubing. 3. Perform +/- 200' of wireline conveyed perforations. 4. Perform data frac and frac. Cleanout to below perforations. . Rerun 3.5" tubing with an electrical submersible pump. Set packer at +/- 600' MD. Pressure test tubing and annulus to packer. 6. RDMO Nabors 4ES. 7. Put well on production. RECEIVED JUN 22 1994 At~sk~ 0il & Gas Cons. Commission Anchorage DBR, June 21, 1994, 5:03 PM CORE SAMPLE TRANSMITTAL · FROM: BP Exploration Alaska, Inc. TO: cio Document Storage Core Store · 2410 W. 88th Ave. Anchorage, Alaska 99507 ~ ~' Attn: John Trautwein (907) 522-2684 AIRBILL #: ~ ,&-.~j b CHARGE: WELL NAME: SAMPLE TYPE: NUMBER OF BOXES: REFERENCE: TRANSMITTAL NO' il ~' DESCRIPTION OF MATERIALS TRANSPORTED: Please acknowledge receipt in whOle of the material described above by signing this transmittal a. nd returning a copy to the address shown above. Sent by: ~~'~~.4~,~-_.~,.1,.. Date: Received by: Date: Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 December 30, 1993 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU C-3; REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Johnston, Attached are duplicate copies of the Report of Sundry Well Operations, Form 10-404, for converting Milne Point Unit Well C-3 to gas lift, Approval Number 93-268. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Att: cc: TJY Chevron Occidental C-3 Well File RECEIVED ~AN -.,~ 1994 A/aska Oil & Gas Cons. Co~ni~ion AnChorage ALASKA OIL AND GAS CONSERVATION COMMI ' ON REPORT OF SUNDRY WELL OPERATIONS Operations Performed: Operation shutdown ~ Stimulate ~ Plugging ~ Pull tubing ~ Alter casing ~ Repair well ~ Other X Convert to Gas Uft 12. Name of Operator Conoco Inc. Address 3201 C Street, Suite 305 Anchorage, AK 99503 5. Type of Well: Development Stratigraphic Location of well at surface 1395' FSL, 2326' FEL, Sec. 10, T13N, R10E, Umiat Meridian At top of productive interval 3958' FSI., 3790' FEL, Sec. 10, T13N, RIOE, Umiat Meridian At effective depth 4277' FSL, 3682' FEL, Sec. 10, T13N, R10E, Umiat Meridian At total depth 4369' FSL, 3651' FEL, Sec. 10, T13N, R10E, Umiat Meridain Present well oondition summary Total depth: measured 8848 feet Plugs (measured) true vertical 7785 feet None 6. Datum elevation (DF or KB) 45' KDB ?. Unit or Property name M~lne Point Unit feet 8. Well number 9. Permit number/approval number 10. APl nufnber" 50-029-20786 11. Field/Pool Kuparuk River Field Effective depth: measured 8635 feet Junk (measured) true vertical 7593 feet None Casing Structural Conductor Surface Intermediate Production Uner Perforation Depth: Length Size Cemented Measured depth 53' 20" To Surface 80' 2289' 13-3/8" 4500 sx Arctic Set II 2316' 8732' 7" 500 sx Class G 300 sx Arctic Set I measured 7894'-7912', 7950'-8014', 8062'-8080', 8086'-8118' True vertical depth true vertical 6919'-6934', 6968'-7023', 7066'-7081', 7086'-7115' 0' 2316' 8759' 7024' RE£EIVED Tubing (size, grade, and measured depth) 3-1/2: 9.2#/ff, L-80, 7807' JAN - J~ 1~)94 Packers and SSSV (type and measured depth) Otis FMX SCSSV @527', Otis RDH Pkr @548' Nask~ 0[{ & Gas Cons. Cotamissio; Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation (Injection) Subsequent to operation (Injection) Representative Dally Average Production or Injection Data oiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 670 3O4 25 180 450 152 15 1200 Tubing Pressure 180 160 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Oil X Gas ~ Suspended 17. I hereby certify at the lng is true and correct to the best of my knowledge. Signed k~t~ /~ J.H. Andrew Title Sr. Production Enqineer Form 10-404 Rev 06/15/88 ' ~ Date 12/27/'93 SUBMIT IN DUPLICATE DEC 30 '93 10:15 CONOCO INC. FRO~ P-MILNE ( DAILY WELL ACTIVITY REPORT PAGE.002 A.LASKA FROM TO HOURS ACTIVI~ , .. .~~~ ~ ...... ~~~ ........ ~ ......... , , . , . . ~ ~, ,,, ..... .. , .......... _~ ~~~ .. ... ,~ . ~ ...... , . . ~ '- ~ ' ............ - ' '- ........................... Ih~ ~ 1~O~ ....... .............. _FmlDWPE/DENS~: ...... Pm CpSSES TODAY/CUM. I , BBm ~ CUM, .~UID COST: ,$ ,, RIG 8AFE~ PERFORMANC~ ' ALL DAILY COSTS ,' ) PILLO , DAYSWmOUT ~ ...... $ . ~, ~ PLU. G DESC, , ..... Y~R TO DATE $ COST SUMMARY DALLY CUMU~TIVE 1, ~ ,, , ..... ENVIRONME~A~INOIDE~S $ ,. PR~I~STOT~ ..~ .. , $ _ ,. DAYSW~HOUT $ P~NNED $ $ , , ,, ,,, ,, ,. ,, , .,, ,, ,-, . ,r, ,. Y~ TO DgTE $ TBOUgLE ..... ,,,. ,, , . , . ,,. , ,, .. ~ST ~PE TEST $ TOT~ $ $ ...... . .. .,, , ,, , ,, . , . . ~PE TEST DUE $ AFE ~ST ~ ~ . . · .... , ...... ,= , , - A~CC VlS~? .... $ ' FBI, FINALC~T $, SCHLUMBERGER WELL SERVICE~. A IDIVlSION OF SCHLUMBERGER TECHNOLCX~Y CORPORATION HOUSTON. TEXAS 77251-2! 75 Conoco, Inc.. 3201 "C" Street, Suite 305 Anchorage, AK 99503 Attention: Dorothy Bourbeau PLEASE REPLY TO SCHLUMBERGER WELL SERVICES Pouch 340069 prudhoe Bay, AK 99734-00 Attn: Bernie/Shelley Gentlemen: Enclosed ore 2 BL prints of the Tubing Punch Record, Run 1, 10/24/93 Company Conoco, Inc. Well Milne Point Unit C-3 on: Field Milne Point Additional prints are being sent to: 1 BLprints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb. OF 2018 EPT County North Slope State Alaska 1BL prints, 1RF Sepia Chevron Production Company 1301McKinney Houston, TX 77010 Attn: Gary Forsthoff 713/754-5618 1Blprints Conoco, Inc. 1000 South Pine Ponca City, OK 74602-1267 Attn: Janet Webb~ 1239 EB ERS Cmmmt~mtnn 3001 Porcupine Drive Anchorage, AK 99501 Attn: Larry Grant/../ nrint~'~ 1BL prints, 1RF Sepia OXY U.S.A.. Inc, 6 Desta Drive, Suite 6002 Midland~ TX 79705 Attn: John Carro] gis/6as-58n~ ~.prints prints The film is returned to Conoco~ Dorothy Bourbeau We appreciate the privilege of serying you. Very truly yours, SCHLUMBERGER WELL SERVICES SW~-- t 327.1r CH (7 BL/3 Raymond N. Dickes Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99§03-3999 (907) 564-7600 October 4, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU C-3; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for converting Milne Point well C-3 from being produced by an Electrical Submersible Pump to production by Gas Lift. Please direct any questions regarding this Application to me at 564-7600. Sincerely, Tom Yeager SHEAR Specialist Attachment CC: JHA, TJY Chevron Occidental C-3 Well File EE 'EIVED OCT - 5 199 Alaska 0ii & Gas Cons. C0mmissio,~ Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION ,/ APPLICATION FOR SUNDRY APPROVALS Alter casing ~ Repair well m Plugging m Time extention __ Stimulate / Change approved program Pull tubing Variance Perforate Other x Convert to 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development x 45' KDB feet 3. Address Exploratorym 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic__ Milne Point Unit Service __ 4. Location of well at surface 8. Well number 1395' FSL, 232E FEL, Sec. 10, T13N, R10E, Umiat Meridian C-3 At top of productive interval 9. Permit number 3958 FSL, 3790' FEL, Sec. 10, T13N, R10E, Umiat Meridian 82-50 At effective depth 10. APl number 4277' FSL, 3682' FEL, Sec. 10, T13N, R10E, Umiat Meridian 50-029-20786 At total depth 11. Field/Pool 436~ FSL, 3651' FEL, Sec. 10, T13N, R10E, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 8848' feet Plugs (measured) true vertical 7785' feet Effective depth: measured 8635' feet Junk (measured) true vertical 7593' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 53' 20" TO Surface 80' 80' Surface 2289' 13-3/8" 4500 sx Arctic Set II 2316' 2316' Intermediate Production 8732' 7.' 500 sx Class G 8759' 7024' Uner 300 SX Arctic Set I true vertical 6919'-6934'; 6968'-7023'; 7066'-7081'; 7086'-7115' OCT - 5 199 Tubing (size, grade, and measured depth) 3-1/2" 9.2#/ff, L-80, 7807' Alaska 0ii & Gas Cons. Commission Anch'0rage Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 527', Otis RDH Pkr @548' 13. Attachments Description SUmmaryof propOsal x Detain'ed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: October 20, 1993 16. If proposal was verbally approved Oil x Gas __ Suspended m Name of approver/// Date approved Service 17. I hereby c~ rtifyth~Ithe foregoing is true and correct to the best of my knowledge. /. / Signed k ~I/~ /~' ~ J.H. Andrew Tit~e Sr. Production Engineer Date October 4, 1993 Plug integritym BOP Test Location clearance ~I - Mechanical Integrity Test m Subsequent form required 10- ~du, ...... .;~3!i~i'Cv;.3,~ Origin~I 3~=~d By Approved by order of the Commission [~a¥~J ~, ~,~.~,~,t;~,~.tQ~ Commissioner Date ~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point Unit C-3 Well Gas Lift Conversion The MPU C-3 well was originally completed as a producer in the Middle Kuparuk, Laminated Zone, and Lower Kuparuk intervals in October 1985. While the field was on line, it was produced by gas lift until being converted to ESP lift in August 1990. The initial ESP ran 1134 days until it failed. Surface measurements indicate a probable cable-related failure close to the surface. The well was producing 675 BOPD at the time of failure. It is recommended the well be placed in gas lifted production service at this time. This work will consist of reconnecting surface piping to supply high pressure injection gas and punching a hole in the tubing for communication. The well is expected to produce near the previous 675 BOPD rate. REEEIYED 0 CT - 5 199) Alaska Oil & Gas Cons. G0mm'~ssto~ Anchorage STATE OF ALASKA ~;; ;': ~ GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing X Alter casing Repair well 2. Name of Operator / 5. Type of Well: CONOCO I NC. Development ___X Exploratory __ 3. Address Stratigraphic __ P.0. BOX 340045, PRUDHOE BAY, AK 9973 Service__ 4. Location of well at surface 1395'SL, 2326'FEL, SECTION At top of productive interval 3441'FSL, 3678'FEL, SECTION At effective depth 4359'FSL, 3667'FEL, SECTION Perforate __ Other 10, T13N, RIOE, UH At total depth 4369'FSL, 3651'FEL, SECTION 11, T13N, RIOE, UH 10, T13N, RIOE, UH 10, T13N, RIOE, UN 6. Datum elevation (DF or KB) KDB 45' NSL feet 7. Unit or Property name NILNE POINT UNIT 8. Well number C-3 9. Permit number/approval number 82-50/90-389 10. APl number 50- 029-20789 11. Field/Pool KUPARUK RIVER 12. Present well condition sUmmary Total depth: measured true vertical 8848 ' feet Plugs (measured) NONE 7785' feet Effective depth: measured true vertical 8635' feet Junk(measured) 8353' TOP OF HILLED PKR 7574' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 20" N/A 108' 108' 2288' 13-3/8" 4500 SKS 1316' 2316' 8731' 7" 800 SKS 8759' 7705' measured 7894'-7912' 7950'-8014' true vertical 6919'-6934' 6967'-7023 8062' 8080' 8086' -8118 7065'-7081 7086'-7115' Tubing (size, grade, and measured depth) 3-1/2", L-80, 9.3#/FT BTRS TO 7849' Packers and SSSV (type and measured depth) OT I S "FHX" TRSVI~527', OT I S "RDH" PACKER e548'N/ANNULAR VENT VAI 13, Stimulation or cement squeeze summary Intervals treated (measured) NOT APPLICABLE Treatment description including volumes used and final pressure I\L~,L I ¥ I..U $ E P - 6 1990 Alaska 0il .& Gas Cons. C0mm.'tss'ton 'Anrhnr~ll~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 1175 340 50 1135 871 236 25 201 Tubing Pressure 210 201 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil .Z.. Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed .¢'Z~.,c,.,/ 0"~~ Title SEN]OR PRODUCTION FORENAN Form 10-40~4~ev ~6/15/88 SUBMIT IN DUPLICATE Kuparuk River- North Slope Borough, Alaska Milne Point C No. 3 CONFIDENTIAL JULY 26, 1990 RECEIVED S E P - 6 1990 Alaska Oil & Gas Cons. Com~sSi_Qn Anchorage BLEED OFF ANNULAR PRESSURE, S/I WELL. MOVE IN EWS #4 WORKOVER RIG AND RETRIEVE BPV R/U WIRELINE. RIH W/PRESSURE/TEMP. MEMORY GAUGE. TAG SCSSV FLAPPER. PICK UP. PUMP DOWN TBG TO EQUALIZE ACROSS FLAPPER. CONTINUE TO RIH W TAG FILL @8406' WLM (+_8410'RKB). POOH TO 7894' WLM (+_7898' RKB = +_6922q'VD) FOR 30 MIN STATIONARY SURVEY. CONTINUE TO POOH. UNABLE TO GET UP THROUGH SCSSV DUE TO FAULTY CONTROL LINE QUICK CONNECT ON SURFACE. REPLACE QUICK CONNECT CONTINUE TO POOH. L/D TOOL STRING. JULY 27, 1990 R/D SLICKLINE UNIT. DOWNLOAD PRESSURE DATA. SBHP @7894' (+_7898' RKB=+_6922q"VD)=1904 PSIA WITH A STEADY BUT GRADUAL INCREASE IN PRESSURE (6-1/2 PSI IN 30 MIN) WITH TIME. EMW=5.25 PPG. SITP = 600 PSI. BLEED OFF GAS PRESSURE. PUMP 20 BBL. PILL OF 3.8#/BBL OF HEC FOLLOWED BY 57 BBLS OF SOURCE WATER. BLED OFF GAS -TBG. PRESS. DROPPED OFF TO ¢. PUMP 194 BBLS OF SOURCE WATER DOWN ANNULUS TO FILL TO SURFACE. BLEED 250 PSI OFF TBG. INSTALL BPV. N/D TREE, N/U BOPE, & PRESSURE/FUNCTION TEST BOPE. -OK. MODIFY FLOW NIPPLE. PUMP 15 BBLS DOWN BACKSIDE. UNLAND TBG HNG. UNABLE TO PULL UP THROUGH THE FLOW NPL LAND HMG. N/D FLOW NPL. UNLAND HMG, POOH, LAY DOWN 13" OD HNG. INSTALL 11" HNG. RIH AND HANG OFF STRING ON CSG STUB. REINSTALL FLOW NPL. POOH L/D 11"HNG. JULY 28, 1990 CIRCULATE 439 BBLS @ 3.3 BPM & 200 PSIG. 115 BBLS WERE PUMPED BEFORE RETURNS WERE SEEN. LOST 263 BBLS WHILE CIRCULATING. MONITOR WELL - WELL DEAD. POOH SLM & LAYING DOWN SCSSV, PUPS, XOS GLMS & SBR BARREL. M/V BOWEN OVERSHOT, BUMPER SUB, HVD. JARS, GDC. RIH W/BHA ON 4" D.P. TO + 5000. J U LY 29, 1990 SHOOT A FLUID LEVEL MEASURING APPROX 2200' NO FREEZE PROTECTION REQUIRED. M/U 7" BAKER RETRIEVAMATIC AND STORM VALVE ON TOP OF D.P. RIH AND HANG OFF DRILLPIPE 1 JOINT DEEP. BACK OFF LANDING JR AND POOH. N/D 13-5/8" BOPE. N/U TUBING COMPLETION ATTACHMENT (13-5/8" 5K TO 11"5K TUBING SPOOL) AND 11" BOPE & TEST. FLANGE BETWEEN TC ATTACHMENT AND BOPE LEAKING. BREAK AND HAMMER UP FLANGE STILL LEAKING. N/D BOPS, REPLACE RING GASKET, N/V BOPE. PRESSURE TEST-OK. PRESSURE/FUNCTION TEST MANIFOLD&BLIND RAMS - OK. PIPE RAMS WOULD NOT TEST. CHECK RAMS OK. RETESTING PIPE RAMS AT REPORT TIME. ALSO MODIFYING RIG HYDRAULIC SYSTEM. NOTE: NO AOGCC REPRESENTATIVE PRESENT ON THE SLOPE TO WITNESS BOP TEST. JULY 30, 1990 PRESSURE TEST #2 ON PIPE RAMS FAILED. REPLACE RUBBER SEALING ELEMENTS. RETEST OK. COMPLETE BOPE TEST OK RIH W/STORM VALVE RETRIEVING TOOL. OPEN STORM VALE BLEED OFF GAS PRESSURE. PUMP 10 BBLS OF WATER DOWN ANNULUS AND 10 BBLS DOWN THE D.P. WELL DEAD. RETRIEVE AND L/D STORM VALVE/RETRIEVAMATIC PKR. CONTINUE RIH W/D.P. TAG SBR W/+ 15' IN ON JT#248 (+_7745' D.P. MEASUREMENT) ENGAGE OVERSHOT. PULL 1000 LBS. TENSION & ROTATE OUT OF K-ANCHOR POOH. L/D OVERSHOT W/SBR SUCKSTICK. P/U 2 JUNK BASKETS & BAKER CJ MILLING TOOL. RIH W/BHA ON 6 DCS, JARS & BUMPER SUB ON D.P. WITH 247 JTS. IN THE HOLE SET THE PIPE IN THE SLIPS SHUT THE WELL IN. WORK ON HYDRAULIC OIL SUPPLY TANK. R/U POWER SWIVEL. JULY 31, 1990 CONTINUE TO WORK ON HYDRAULIC POWER SYSTEM AND POWER SWIVEL. AUGUST 1, 1990 REPAIR POWER SWIVEL. WAIT ON PARTS. AUGUST 2, 1990 REPAIR POWER SWIVEL. WAIT ON PARTS. RECEIVED AUGUST 3, 1990 REPAIR POWER SWIVEL. WAIT ON PARTS. AUGUST 4, 1990 S E P - 6 1990 Alaska 0il & Gas Cons. (;omm'~ss'tot~ Anchorage WAIT ON CONFIRMATION THAT MUD MOTOR WERE ON PLANE FOR DEADHORSE. CIRCULATED 258 BBLS W/OIL FOR RETURNS. CLEAN RIG PITS. CIRCULATE AN ADDITIONAL 110 BLLS UNTIL CLEAN RETURNS WELL DEAD POOH W/DP LD CJ MILLING TOOL WAIT ON MUD MOTORS. PU 4/3/4" MOTOR AND MU W/CJ MILLING TOOL BHA CU MILLING TOOL, MOTOR, 2 JUNK BASKETS, BOWEN JARS, BUMPER SUB, 6,4-3/4" DC'S ON 4" DP. RIH W/GHA ON DP. SET DOWN W/JT #248 @7750+RKB & LATCH INTO PKR. BEGAN MILLING W/MOTOR 4.6 BPM 1000PSI. WORK DOWN 40" - PU DRAG INDICATES PKR FREE LD I JT - WORK ON WT INDICATOR. AUGUST 5, 1990 POOH W/DP. PKR NOT ON CJ STINGER. ORDER SPEAR AND GRAPPLE TO FISH PKR LD & CLEAN OUT JUNK BASKETS. RIH W/SPEAR, BUMPER SUB, JARS, DC'S ON 4"DP TAGGED FISH @JT #244 + 150' HIGHER THAN ORIGINAL TAG - FISH FELL DOWNHOLE. RIH TO JR #248, PU 2 JTS, RIH & TAG FISH SAT DOWN W/58K LGS TWICE & PU W/3KLBS OVER PU WEIGHT AND DRAGGING THROUGH COLLARS - POOH. POOH TO DC'S & BHA- DID NOT HAVE PKR PULL WEAR BUSHING & TEST BOPE - ORDER LARGER GRAPPLE & TEST BOPE WHILE WAITING ON TOOLS. CHANGE GRAPPLE TO 3.308". RIH W/SPEAR & GRAPPLE, BUMPER SUB, JARS, DC'S TAG FISH & A'I-rEMPT TO STAB INTO PKR. AUGUST 6, 1990 CONTINUE POOH W/FISH - AFTER PULLING 12 STDS w'r DROPPED & LOST DRAG. RIH TO JT #248 & TAG FISH - SET DOWN W/50K LBS POOH TO RIG FLOOR W/PKR. CLEAR RIG FLOOR & MU "CK" BAKER MILLING TOOL W/SPEAR & BHA AS FOLLOWS: CK.TOOL, 4-3/4" MUD MOTOR, 2 JUNK BASKETS, JARS/BUMPER SUB, 6 DC'S ON 4" DP. RIH - PU 9 JTS 4: DP & TAG PACKER 1/3 OF JT #257 ROTATE DP I TURN & LATCH INTO PKR WICK TOOL BEGIN PUMPING - PUMPED 82 BBLS BEFORE GETTING RETURNS. SET DOWN ON PKR & BEGIN MILLING. MILLED DOWN 18" WHEN MOTOR STALLED OUT PU & POSSIBLE SHEARED SAFETY ON STINGER COULD NOT "J" BACK INTO PKR. ATTEMPTED TO SET BACK DOWN TO MILL- BUT MOTOR STALLS OUT W/1K LBS DOWN WT. & MADE NO PROGRESS AFTER 1-1/2 HOURS MILLING. POOH TO INSPECT CK MILLING TOOL- SAFETY SHEARED ON SPEAR. RIH W/SAME BHA EXCEPT NO SPEAR ON "CK"MILLING TOOL. AUGUST 7, 1990 SAT DOWN ON PKR @ SAME DEPTH ON JT #257 BREAK CIRCULATION & BEGAN MILLING MOTOR STALLING OUT W/VERY LITTLE DOWN WT. POOH CHANGE MUD MOTOR, ADD NEW STINGER TO RIH. TAG PKR +' HIGHER ON JR #257 THAN PREVIOUS TAG*-BEGIN CIRCULATING (80BBLS TO'RETURNS) START MILLING @ 4.5- 5.00 BPM DP = 900-1000PSI PKR FREE LOST TORQUE & POSSIBLE FELL DOWNHOLE PU 10 JTS DP & RIH TO TAG FISH - SAT DOWN 3-4 TIMES & ROTATE TO WORK STINGER INTO PKR BORE. POOH. RECEIVED S E P - 6 1990 Alaska 0il & Gas Cons. Comm'tss'to~' Anchorage AUGUST 8, 1990 POOH W/BHA- SMALL PIECE OF TOP OF PKR IN MILL- BOTTOM OF GRAPPLE ON SPEAR WAS WORN OFF WHERE GRAPPLE PULLED OUT. RE-BUILD MILLING TOOL. TAGGED TOP OF PACKER AT 8353' WITH CK MILLING TOOL MILLEN OUT ID OF SBR INTO MILLING EXTENSION. SET BACK DOWN WITH 4000 LB'S ON MILL TRYING TO MILL UP BOTTOM SLIPS. ABLE TO MILL UP 2" TO 3" OF SLIPS BEFORE PACKER TURNING FREE WITH MILL. PACKER IS APNDX. 235' BELOW BOTTOM SHOT IN LK PERFORATED ZONE. AUGUST 9. 1990 PULLED PACKER UP INTO CASING COLLAR AND JARRED SEVERAL TIMES USING OIL JARS. PULLED 40,000 LBS. OVER STRING WEIGHT. BROKE FREE FROM CASING COLLAR. POOH FOUND THAT THE SPEAR ASSEMBLY HAD BROKE FREE FROM THE SBR AND PACKER. FOUND TOP 6" OF SBR ATTACHED TO GRAPPLE WITH RUBBER AND METAL MATERIAL IN JUNK BASKET. WILL LEAVE PACKER IN PRESENT POSITION AT 8353' (TOP OF PACKER), 235' BELOW KR PERFORATED ZONE. TOTAL LENGTH OF PACKER AND TUBING TRAIL ASSEMBLY IS 47'. LAY DOWN MILL ASSEMBLY AND MUD MOTOR. PU CASING SCRAPER AND 6" BIT. RIH TO TOP OF PACKER AND PULL UP 3.5'. CIRCULATED COMPLETION FLUID AROUND AT 2.8 BBL./MIN AND FILTERED TO 10 MICRON. PUMPED A TOTAL OF 302 BBL'S BEFORE CIRCULATING THE 100 BBL SAFE CLEAN PILL. TOTAL CIRCULATION OF 900 BBL.'S IS ORDER TO CLEAN UP WELL. POOH LAYING 4" DRILL DOWN OUT OF DERRICK. AUGUST 101 1990 PULL WEAR BUSHING FROM HANGER. CHANGE PIPE RAMS TO 3-1/2" FROM 4". PU ESP EQUIPMENT. RIH WITH ESP. AUGUST 11, 1990 CONTINUE TO RIH WITH ESP ASSEMBLY ON 3-1/2" VAM TUBING. RIH WITH SLICKLINE UNIT AND RUN A B-SHIFTING TOOL TO THE SLIDING SLEEVE AND OPEN SLEEVE IN ORDER TO DISPLACE THE TUBING AND ANNULUS WITH DIESEL FOR FREE PROTECTION PURPOSES. POOH WITH SLICKLINE. PUMPED 70 BBL'S OF DIESEL DOWN 3-1/2"X 7". THEN PUMPED A TOTAL OF 28 BBL'S OF DIESEL DOWN TUBING. LANDED HANGER. PRESSURED UP ON TUBING TO 2500 PSI. BLED TUBING DOWN TO 1000 PSI AND CLOSED THE SSSV AND ANNULAR VENT. BLED TUBING TO ZERO, SSSV HOLDING. PRESSURE UP ON ANNULUS TO 500 PSI AND HELD FOR 10 MINUTES. PACKER IS SET AND ANNULAR VENT HOLDING. SET BPV IN HANGER. NIPPLE DOWN BOP'S AND NIPPLE UP TREE. R ~ ~ E ~V ~ ~) SEP - 6 1990 Alaska 0il ,& Gas Cons. Co~ ~nctiorag~ AUGUST 12, 1990 COMPLETED RIGGING DOWN THE EWS RIG AND ASSOCIATED EQUIPMENT AND MOVE TO B-23 WELL. RECEIVED S E P - 6 1990 Alaska 0il & Gas Cons. Commission Anchorage Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. MIKE MINDER STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. MINDER, ATTACHED IS THE REQUEST FOR SUNDRY APPROVAL TO CONDUCT WORKOVER OPERATIONS ON THE C-3 WELL. THESE OPERATIONS WILL BE NECESSARY TO CONVERT THE PRODUCTION TECHNIQUE ON THE C-3 WELL FROM THE CURRENT GAS LIFT DESIGN TO ELECTRIC SUBMERSIBLE PUMP DESIGN. RESPECTFULLY, · D. P(]LYA DRILLING FOREMAN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ! 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing "X-- Variance __ 2. Name of Operator ! 5. Type of Well: CONOCO INC. I Development'X- Exploratory m 3. Address Stratigraphic_ P.0. ROX 3&OO4~. PRllnHI~F RAY; &K qq73_ Service m 4. Location of well at surface 1395' FSL, 2326' FEL, Sec 10, T13N, R10E, Uli At top of productive interval 3441' FSL, 3678' FEL, Sec 10, T13N, R10E, Uli At effective depth Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pedorate __ Other "X- At total depth 4369' FSL, 3651' FEL, Sec 10, T13N, RIOE, UH 12. Present well condition summary ~ Total depth: measured true vertical Effective depth: measured true vertical 8848' :feet feet 7785' feet feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 80' 20" Surface 2,288' 13-3/8" Intermediate Production 8,731' 7" Liner Cemented 6. Datum elevation (DF or KB) KDB 45' Perforation depth: 7. Unitor Property name .)m_NE POINT UNIT 8. Well number 9. Permit number 82-50 10. APl number 50- 029-20789 11. Field/Pool Kuparuk River R EC E IV E il ~,i~;~ska.Oi] & Gas Cons, Comr~iss[o.~' Measured depth ' ....... L ~depth N/A 108' 108' 4500 SKS 1,316' 2,316' 800 SKS 8,759' 7,705' measured 7894'-7912' 7950'-8014', 8062'-8080' 8086'-8118' trueverticaB919'-6934' 6967'-7023' 7065'-7081' 7086'-7115' Tubing (size, grade, and measured depth) 3-1/2", L-80, TO 8085 BOTTOli PACKER IS A BAKER FB-1 PERliANENT PKR @ 8040' liD Packers and SSSV (type and measured depth~'0p PACKER $S$V TS A CAliCO TRDP-1A SSA~ 3-1/2"~ I~ 13. Attachments Description summary of propose__ IS A BAKER 7" SAB HYDRAULIC SET @7757' liD 2066' MDRKB Detailed operations programZ._ BOP sketcl'X__ 14. Estimated date for commencing operation t, IAY ~. 1 qqtl 16. if pr°poS~ was verbally approved Name of approver Date approved 15. Status of well classification as: Oilx . Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed X~xf ~..~~ Title ~FNTOR PRODtllCT,ON FORE.AN FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAE SIGNED BY LONNIE C. gM!TH Approved by order of the Commission Approved Copy Returned , 124.Fio Commissioner Date ~""/~/?//~ o ]Approval No.¢ ~ ._.,~ ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NOTEB: MILNE POINT U , .3 ACTUAL COMPLETION SKETCH RE-COMPLETED ON' 10-6-85 FMC 135/e' TUBING HANGER w/ 3 I/a" FMC BPV PROFILE 1. Aa meeeuremanto ere Irom KDB cf Nabors Rig 17 2. KDB - SL = 45' KDB - GL : 4. MIX. angle 39.4° (~ ~000' 6. KOP ~ 2400' 8. Slant type ho.l.e 7. Min. angla B. FMC 3 1/8' APl 8000~ tree with S 1/2' 8 rd. treetop connection. MI~. raltrlctlon Il 2.635" a XN nipple 8078' 10. APl No. 50- 02g - 20786 11. Completion fluid 9.B PH NoCl brine Citing end cement Information eupplled off cletflO and cement ekatch. PERFORATIONS 12 SPF, 120°phasing, 5'tgune MIDDLE KUP 7894 - 7912' MD 6919 - 6934' TVD LAMINATED KUP 7950- 8014' MD 6967 - 7023 ' TVD ~ 3 I/2'" g.2~ L- B0 Vga tubing 2066' Coreco TRDP-IA SSA SCSSV (2.812" lO) 2124' 2563' 3357' 4348' 5250' 5995' 6622' 7186' 7655' 7730' Baker EBA - I Extra- long Tubing Seal Receptacle 7757' Baker 'K-22"Anchor Tubing Se~l ~7757' Baker SAB Pocket' w/miilout extnnsion (S.250" I.D.) ~3 t/a" Buttress tubing (Pertoroted 7889-789~' wi2" gun at 79i7' 3 I/2" X-Nipple (2.812' LD.) LK -I B062 - BO80° MD 7065-7081' TVD LK- 2 8086- 8116' MD 7086 - 7115' TVD ACID STIMULAT IQN 10-29-85 Middle Kup/LB/L9 1600 gal i5% HCl 2100 gOI 12 -3 Mud Acid 450 got. Acetic 3 I/2' Buttress tubing ~9038' Baker Seal Assembly w/G'22 Locatm, 5Seal Unite ~muleshoe --8040' Icier FB-I Packer ( 5.875' O.D., 4.0' I.D.) w/milieuS extension (5.5"0.D,, '4.5'LD.) .... 8078' 2.75" X-N Nipple w/2.635" No- go ( 2.75" I.D. ) 8635' PBTD · 8759' 7" 29.# L-80 BTRS ( 6.184" LD., 6.059" drift ) PRODUCTION LOGS 2. R/A Tracer Survey (3-1B-66) I. " ' " ( I- 30-B6) MILNE POINT C-3 (P) OPERATOR: CONOCO INC. SURFACE LOCATION: 1395' FSL, 2326' FEL, Section 10, T13N, R10E, U.M. BOTTOM HOLE LOCATION: 8848' ~.D. 4369' FSL, 3651' FEL, Section 10, T13N, R10E, U.M. SPUD DATE: 04/29/82 NOTES:'DV' Tool at 2073' 1. Ail measurements from KDB of Nabors 17 2. KDB - SL = 45' 3. KDb - GL ~ 18' 4. Max. angle = 40° @ 3800' 5. KOP at 2400' 6. Slant Type Hole - YES . . 9 5/8" Surface Casing 1. Pumped 745 Bbl$ of Arctic Set cement. 2. Displaced with drilling mud. NOTE: 240 Bbls cement returns. 'DV'Too at 2073 20" 92#, Peld at 115' 13 3/8" 72#, L-80 Btrs. at 2316' Centralizers: I per 40' 2316' - 2276' 1 per 80' 2276' - 1836' 7" Production Casins 1. Pumped 30 Bbls of spacer 3000 and 20 Bbls CW 100. 2. Pumped 102 Bbls (500 sx) Class "G" cement with .5% D-59, .5% D-65, 3% KCL and .2% D-46. 3. Displaced with 10.5 ppg mud. NO~E: Circulated 300 sacks Arctic Set I cement through 'DV' Tool at 2073'. Centralizers: I per 20' 8759' - 8679' i per 80' 8679' - 6039' I per 40' 2116' - 2033' 1 per 120'2033' - Surface 7,! 29#, L-80 Btrs. 8759' I~IPU KUPARUK RE,~d~RVOER PROCEDURE FOR CONVERSZON OF GAS LXFT WELLS TO ELECTRIC SUBNERSIBLE PUMP 1. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL. WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) C-2 7151 2732 1194 7.85 C-3 7017 2570 1548 7.54 C-7 7192 2370 1240 6.84 C-14 7050 3580 1432 10.3 C-16 7050 3600 1225 10.5 (NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP. 8.33 PPG SOURCE WATER WILL BE USED AS KILL FLUID FOR C-2, C-3, AND C-7. C-14 AND C-16 WILL BE KILLED WITH 10.3 AND 10.5 PPG NABR BRINES, RESPECTIVELY. CURRENTLY, 450 BBLS OF 10.3 PPG AND 450 BBLS OF 10.5 PPG NABR BRINE ARE BEING STORED IN TWO 500 BBL TIGER TANKS ON C PAD. THERE IS ENOUGH DRY BULK BEING STORED AT MILNE POINT ON C PAD TO MIX AN ADDITIONAL 600 BBLS OF 10.3 PPG AND 600 BBLS OF 10.5 PPG NABR IN THE EVENT THAT WE ARE WORKING ON EITHER C-14 OR C-16 DURING BREAKUP. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL. BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 50' PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES NOT LESS THAN 500 FT MD. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. (IMPORTANT NOTE: THE COMBINED MEASUREMENT OF THE DIAMETERS OF THE #2 ROUND CABLE DIAMETER AND THE SCSSV IS 6.0? INCHES -- THE DRIFT OF THE 7" CASING IS 6.059" (TO0 LARGE TO FIT). IT WILL THEREFORE BE NECESSARY TO SPLICE APPROX. 20 FT OF #2 FLAT CABLE TO EXTEND ACROSS THE SCSSV.) 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS TO 500 PSIG FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NEXT WELL. THIS PROCEDURE IS IN ACCORDANCE WITH AN EARLIER PROCEDURE WHICH WAS: PREPARED BY STEVE ROSSBERG, SENIOR PRODUCTION ENGINEER (3/25/90) REVIEWED BY MARC SHANNON, SUPV. PRODUCTION ENGINEER (3/2?/90) APPROVED BY GARY FLOWERS FOR JACK COPELAND, PRODUCTION SUPT. (4/3/90) J.D. POLYA DRILLING FOREMAN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following mategial which was transmitted via is hereby acknowledged: QUANTITY' DESCRIPTION Copy YES sent to sender STATE OF ALASKA ~,-.~ SKA OIL AND GAS CONSERVATION COMJ~'qSION ~ ~ REPOIL. OF SUNDRY WELL O .tATIONS 1. Operations performed: Operation shutdown __ Stimulate -.X.- Plugging __ Pull tubing __ Alter casinc~ __ Repair well __ 2. Name of Operator CONOCO INC. 3. Address 4. Location of well at surface 1395' FSL, 2326' FEL, Sec. 10, At top of productive interval 3441' FSL, 3678' FEL, Sec. 10, At effective depth Perforate -.,X Other 5. Type of Well: Development -X- Exploratory M Stratigraphic __ Service ...J. T13N, RIOE, U.N. T13N, RIOE, U.M. At total depth 4369 FSL, 3651' FEL, Sec. 10, T13N, R10E, U.H. 12. Present well condition summary Total depth: measured 8848' true vertical 7785' feet feet Plugs (measured) Effective depth: measured feet Junk (measured) true vertical feet 6. Datum elevation (DF or KB) 45 KDB 7. Unit or Property name Hi!ne Poi.-.+_ Unit 8. Well number 9. Permit number/approval number ~_?-5n/o-87~ 10. APl number 50-- O~-~137Rq iI' Field/Pool Kuparuk Rivet- feet PBTD-8635 RECEIVED Casing Length Size Cemented Measured depth Structural NOV o 5 1989 Alaska 0/I & Gas Cons. C0mmissl'0ff iAnl~(J~qi~J~ical depth Conductor 80' 20" N/A 108' 108' Surface 2288' 13 3/8" 4500 sks 2316' 2316' Intermediate Production 8731' 7" 800 sks 87519' 7705' Liner Pedorationdepth: measured 7894'-7912'; 7950'-8014'; 8062'-8080'; 8086'-8118'; 7870'-7865' truevertical 6919'-6934'; 6967'-7023'; 7065'-7081'; 7086'-7115'; 6905'-6900' Tubing (size; grade, and measured depth) 3 1/2", L-80 to 8085'; btm pkr is "Baker" FB-! permnt 0 8040' Packers and SSSV (type and measured depth) Top pkr 'is Daker 7" SAB retrvble, l) 7757'; S$$V 'is Camco TP, D lA, 3 1/2"0 2066' 13. Stimulation or cement squeeze summary Frac Lower Kuparuk Intervals treated (measured) 8062-8080; 8086-8118 Treatment description including volumes used and final pressure Total proppant 55,200#. Final press. 5300 ps 14. Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations -X-- 1089 200 41 869 177 720 184 20 841 195 16. Status of well classification as: Oil-X- Gas __ Suspended Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Form 10-~04 R~ 0~/15/88 Title Sr. rors~an SUBMIT IN DUPLICATE DALLY WELL ACTIVITY REPORT DATE 9/27/89 WELL C-5 0400 RIG UP DOWELL FRAC EQUIPMENT. BATCH MIX 1547 BBLS OF LINEAR GEL (40# HPG/iO00 GAL. VISC=55 @ 500 PPM). RIG UP HB&R HOT OIL UNIT @ 0600. PUMP i20 BBLS OF SOURCE WATER (4200 PPM CL) FOLLOWED BY 60 BBLS DIESEL DOWN 5 1/2 X 7" ANNULUS TO FLUID PACK. PRESSURE TEST DOWELL LINES TO 7000 PSI. OK. 1000 PUMP 190 BBLS OF PREPAD (GELLED WATER W/ FLUID LOSS ADDITIVE). INITIAL RATE 20 BPM AT 5500 PSIG. THEN INCREASE TO 25 BPM AT 5900 PSIG AND MAINTAIN. 1020 PUMP 571 BBL OF PAD W/ 5% DIESEL, FOLLOWED BY 518 BBLS OF GELLED WATER AND 16-20 INTERMEDIATE STRENGTH FRAC SAND. PUMP IN A CONCENTRATION OF .5 PPG PROGRESSELY INCREASING TO 8 PPG. MAX TREATING PRESS. 5500 PSIG 1100 FLUSH TUBING W/ 69 BBLS WF40 GEL, S/D . ISIP 3858 PSIG. RIG DOWN. 10/10/89 0700 PRESSURE UP TBG W/ GAS LIFT GAS 0800 RU HLS E-LINE UNIT. PRESS TEST LUBRICATOR, OK. RIH W/ CCL- 2" GO WINDER HOLLOW CARRIER PERFORATING GUN TO PKR. ASSEMBLIES AND CORRELATE DEPTH. PERFORATE TUBING FROM 7870' TO 7865'. 2GM CHARGES SPACED AT 4 JSPF, 0 DEGREE PHASING AND MAGNETICALLY DECENTRALIZED. RIG DOWN APPLICATION FOR SUNDRY APPROVALS ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM ~ION 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator Conoco Inc. 3. Address Box 340045, Prudhoe Bay, AK Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Pull tubing __ Variance __ Perforate __ Other __ 99734 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1395' FSL, 2326' FEL, At top of productive interval 3441' FSL, 3678' FEL, At effective depth Section 10, T13N, RiOE, UM ~totaldepth 4369' FSL, 3651' FEL, 12. Present well condition summary Total depth: measured true vertical Section 10, T13N, R10E, UM Section 10, T13N, R10E, UM 8848 ' feet Plugs (measured) 7 7 85 ' feet feet Junk (measured) feet Effective depth: measured true vertical Casing Length Size Structural Conductor 80 ' 20" Surface 2,288' 13-3 / 8" Intermediate Production 8,731 ' 7" Liner Perforation depth: measured 7894'-7912', truevertical 6919'-6934', 6. Datum elevation (DF or KB) KDB 45' Pad 17 ,,, 7. Unit or Property name Milne Point Unit 8. Well number C-3 ~bing(size, grade, and measureddepth) 3-1/2", L-80 to 8085 Bottom Pac~rsandSSSV(typeandmeasureddepth) SSSV is a Camco TRDP-1A SSA, 9. Permitnumber 82-50 lO. APInumber 50--029-20789 11. Field/Pool Kuparuk River RECEIVEO Cemented N/A 4500 sks 800 sks S£P281 9 Naslm 0ii & Gas Cons. Gomm s¢ chomge Measured depth r~ue vertical depth 108' 108' 2,316' 2,316' 8,759' 7,705' %950'-8014', 6967'-7023', 8062'-8080' 8086'-8118' , 7065'-7081' 7086'-7115' , packer is a Baker FB-1 Permanent PKR @ 8040' MD Top Packer is a Baker 7" SAB Hydraulic set @7757' MD 3-1/2", @ 2066' MDRKB Description summary of proposal __ Detailed operations program 13. Attachments 09-2~-89 Date approved 14. Estimated date for commencing operation September 27, 1989 15. Status of well classification as: BOP sketch __ Oil ~ Gas __ Suspended __ Service 16. If proposal was verbally approved Name of approver L~h 17. I hereby certify tha~e foregoing is true and correct to the best of my knowledge. Signed FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Commissioner Date I Approval No. f..-~,~' ,2,- Approved Copy Returned Date 9 '-~[-"~-~? SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 feet 1 . .. ~sTzlqULAT]ON pROcEDURE Hydraulically Fracture MPU We), Hilne Point Unit Surface Locattop: 1395' FSL, 2326' FEL, Sec. lO, TI3N, RIOE, UM Depths: All depths are measured from KB datum. Casing: Surface -13 3/8", 72J/fi, L-80 btrs., set at 2,316'. Production- 7" 26A/ft, L-80, btrs, set at 8,759'. " Capacity: 3.82 bbl/]O0' Burst Pressure: 7,240 pStg Tubing: 3 ]/2', 9.20#/ft, L-80, btrs ~ 8,085' Capacity: 0.8700 bbl/]O0' . Capacity of tubtng/castng, ann. ul us*: -_2. 64 bbl/]O0,. · ..... Burst Pressure:' 10,160 pslg Eno safety faCtor). -. Rat Hole Volume: 21 bbl. ~ ' ..-..... · -- P~esent Completion: ':Stn91e selecttve Niddle Kuparuk 7,757" 8,040'.. Lower Kuparuk 8i062'- 8,080.', 8,086'- 8.,]]8'. Present Statu~: Kuparuk'productng well. ,.-:-: .-, . ob:lecttve[ Fracture StimUlate 'the LK to Increase .the "rate' of. production. .. ,. . Recommended Procedure: '- .... ;., · ~. Hold a pre-frac meeting 'with all contractors to discuss Job: requirements and safety prior to the Job. ' ... j~ The well contains ~Ca~o. TROP-IA SCss¥. MaJntatn suffJcJent control 11ne pressure to keep the valve open throughout the Job. CLP" (tubtng flutd gradient-control 11ne fluid gradient) *safety valve depth+2200+400+tubtng pressure. Prepare to place a tubing patch across the tubing perforations located at 7,889'-7,893'. as follows: ' - A) Recommended patch ts a, Teledyne-Merla permanent tubing patch for'~: .~?, 9.2#/ft tub tng. ~.~a~,~ing ' dtmens:t,ons are ~~::r*~"?~6~.?lt :~O~;~ae ,~ (~ermenant i.D. is 2,375')....~ifferentia. 1 pressure ratings of the patch are 4,900 pSig burst and 5,250 ps~g Collapse. RJg,up slickline with 10' by'2.765" dummy tool and run in the hole t,o 7,glo'. Pull dummy' out of the' hole. The minimum restriction is 2.8]2" I.D. SCSSV located at 2,066'. Distribution: TRP, JDC, PJG(2), IIPU Senior Foremen RECEIVED sF, 28t989 Anohorage Februar~ 28, ]989 Page 2 C) Rig up electric line company and.run a base GR/CCL. Rig up electriC line with detonating head, eCL and tubing patch. Run in the hole and center the patch across, the tubing perforations (?~889'-7,893'). Set the patch and pull out of the hole. 4) Run tn the hole with sltckltne and retrteve gas lift valves from'the mandrels shown tn the attached wellbore dtagram. Replace the valves with dummies. Run tn the hole with a tubtng plug and place tn the X ntpple located 7,730'. pressure test the tubtng .to 6,000 pstg ( 9,200 pstg BlIP allows for .a 10.% ~'~etY factor .on the tubing).. Retrteve the .tubtng plug. 'If the well does not hold pressure, contact the Anchorage office before proceeding. .. 5) Spot three 500 bbl frac tanks on locatton approximately ]50' .from the wellhead. Elevate the rear of the tanks approximately 8". Vtsually tnspeCt the tntertor of the tanks 'for cleanliness (do not clt.mb tnto the tanks). Ftll each tank with 412 bbls. of clean ltPU injection water. The water should be heated and maintained at 75-80 degrees F in order to tnsure proper hydration of t.he gelling agent. · - . $)' Rig up'tree saver and service c°mpany-Pump ll ines (use Ino 'threaded cross.I overs., swedges, or valves). Install two shut-off valves on the 'wellhead. Use two tn-line denstometers Set up backup pumps for crossltnker and diesel. Rig uP annulus pump (o maintain.2,000 psig backside pressure. 7) Batch mix 1,236 bbl.. (51,912 gal.)-HP$ gelitn' agent at 40 lbs/lO00 al · ?nta.tn.t.ng 2.% ~K.CL, SO0_ ppm. btoctde and ~.ros. s.m !nKer, ~)reaKer, surfactant,'.non.emUlstfter. 5% dte~l ,mu,o ,oss material will be added on the. fly '~$ schedule ( See Material Detail)..: ' ':- .'.''. '' .: · · ..-, .P g' 8) Fill .'out the fluid report forms. Check all additives against the attached material detail. Continuously roll the tanks until the viscosity is within the recommended limits ( 45 to 55 at 300 rpm on Fan 35 vtscometer).. Check samples from the top and bottom of. the tank, .Values should correspond within 3 cps. · · . 9) Hold a safety meeting with all persOnal on location. 10) Pressure test the surface .lines and tree saver to 6,000 psig. check, the lines to insure that there are no leaks. Pressure up the annulus to 2,000 psig and maintain throughout the job.- 10) Prepare to pump the frac job as follows: A) Standby pumps (50~) are required. These pumps must be manned and primed to immediately come on line if needed. A standby blender must be 'hooked .up and ready to come on line in the case of primary blender failure. Pump the first 5,000 gal of pre-pad on standby blender. Shut down and record the ISIP. Switch to main blender for the remainder of the job. RECEIVED SEP281 9 Alaska Oil & Gas Cons. Commission Anchorage. Fracture I4PU C-3 February 28, 1989 Page 3 B) Tank bottoms are tncluded in the volumes listed Jn step 7. Leave 50 bbls tank bottom. C) Use the ~n-lJne densJometers durtng the Job. Record rate and pressure on a strip chart. Send the charts to the Anchorage offJce. -D) Take Samples of the crossl.tnked gel during the Job. Place them tn a water bath at 165 deg. F. Observe the samples and note when the gel breaks. E) Pre-Pad and flush gel ts not crosSltnked and does not contatn dtesel ot1'. The last 1,500 gal. O'f flush ts ]00~ dtesel to prevent free*zing; . . · . F) O0 NOT OVER' OISPL^CE. R E'C E I.VE D Frac Rate: 25 BPM - $~P28t~]9 Maximum Allowable Surface Pressure: 6,000 Pstg @' 25 BPM Anticipated Surface Pressure:-4,500 pstg to 5,000 pstg A1askaOil&GasCon$.Commissio. n Anchorage Gel Otesel Stage ~ ~ ,P_PA P-Pad 8,000 Pad 22,800 1,200 I 3,730 196 2 2,651 140 3 2,479 ]30 4 2,328 123 5 2,193 115 Flush 1,433 Flush l, 500 3,404 Cum Sand Cum Fluid Pump Time ."lbs. (lbs,) · (cal.) _ Mtnute$ 8,000 32,000 0.5 1,963 1,963 36,000 2.0 5,582 7,545 39,000' 4.0 10,437 ]7,982 42,000 6,0 14,698 32,680 45,000- 8.0 18,468 51,1.48 48,000 . 7~'6 30.5' 34.3 37.1 40.0 42.9 45.7 -' Totals 45,614 51,148 51,148 50,093 47.7 Cum fluid=gel+diesel+sand Pre-pad and Pad should contain 50#/]O00gal. fluid loss additive. . . Il) Shut down. Allow the pressure to bleed off into the formation. Record the ISIP, 5 minute, ]0 minute and ]5 minute pressures. Close all surface val.ves and leave the well shut-in over night. Leave the SCSSV open. Have the set- service company monitor the break time of the last sample colected. Rig down the'service company. 12) Allow the fracture to he'al a minimum of 48 hours. 13) Return the well to production.very sl°wly. Begin with the choke set at 6/64" and increase the choke size by 4/64" every 2 hours to a maximum of 24/64". Fracture MPU C-3 ,,, February 28, 1989 Page 4 14) Monitor for proppant returns. If after 300 bbls. of recovery, there is no proppant return and load recovery is less than 20%, open the choke to 64/64" and obtain a Stabilized post-frac flow test on the lower Kuparuk. 15) Shut-tn the well and rtg up s11ckllne. Run tn the hole with stnker bar and tag ft11. Zf f111 ts present above 8,118' (bottom perf), rtg up cotl .tubtng and clean out to 8,635' PBTD. Engineering wtll prepare a coil tubing procedure, tf necessary. 16) Rig up electric line to perforate tubing. Perforate the'tubing from 7,905'- 7,910' with 4 SPF using a 2 l/8" retrievable through tubing gun. Use CCL for'depth .control and insure that perfs are below the patch. Pul.1 out of the hole and rig down electric l tne. 17) Rig up sltcklfne. Run in the hole and retrieve dummy valves. Replace the dummies with gas lift valves'. Return the well to full rate.production from both the MK and LK. ' HATERIAL DETAIL clean MPU injection water KCL (2%) Gelling Agent (40#/1000gal) Nontontc Surfactant (2 gal./1 000 ga1) Non-Emulsifier (2 gal/lOOOgali Cross Linker (3#/lO00gal) Anti-Foamer (5gal/tank)~ '- Bt oct de (500 ppm) .... OAP (50t/1000gal Pad and Pre-Pad only) Breaker Otesel 16-20 Intermediate Strength Prop~ 51,912 gal. 8,825 lbs. 2,076 lbs. 92 gal 92 gal: -- 114 lbs. .. : 15 gal. ...... ;' 26 al 1,600 Ybs: As recommended by service company. 3,404 gal. 51,148 lbs. Note: Diesel and prop should not be included in service company bid. Either OAP or Adomite aqua will be run as a fluid loss adittve at C°nOco's discretion. · ' RECEIVED SEP281 9 ' TREATMENT HYDRAULICS Alaska' 0il & Gas Cons. Commission · Maximum Rate: 25 BPM Anchorage Average Anticipated Pressure: 5,000 psig Estimated Hydraulic Horsepower: 3,064 hhp (An additional 50% hp capacity is required on location) Backside pump capable of maintaining 2,000 psig static surface pressure is re- quired. Fracture MPU C-3 February 28, ]989 Page 5 The following backup equipment ts required: 1) 50% backup on primary Injection pumps. 2) 100% blender backup. 3) 100% backup on diesel and crossltnktng pumps. Prepared by: Steve Rossber9 P_c~ductto.n Engineer . .uperv~sing Pro ctton Engtnee~ Fteld Superintendent RECEIVED Alaska Oil & Gas Coi~s. Commissio~'~ Anchorage I 1 ! NOTESI ' KDB ' SL · ~' KDB ' GL · KOP ~ ~400' · ~ . .: 1. Completion ~ld Ceelao lad oem~at hfomel~a luppBed . .,. ...:.i... I ' . MIO~E KUP I .I LAMINAT(O l~ 7~5o' eOld' I LK -I. TOSS - 70It* TVO LK*t 'J 8086- OliO' MO 7006- Tile* TVD' ~ ~ * . MILNE POINT UNIT O-.3'~" .ACTUAl. COMPLETION SKETCH iRE-COMPLETED ON' 10-Q-85 · _lOll ST IIdt)LAT ION IO-2e-IS td;ddJt Kvp/L8 1800 Iol. IS % ~CI ' SIO0 ~oI. IS o3 Mud Acid 4S0 1dj. Acetic I · · oltttlll, ' 0~/ct~ lt¥1141kl ..,, fldC I$l/I" TUelN0 HAI~G[I~ ,/ I I/1" FMC 8PV PIqOIrlL[ · . . . . · . ~ B~l# !lEA - I talto. I#l T, llot e#1 RoclplfllO i ' ' '"' ~ ' "' 1'" :~: ' ' ..,.. , .. ..:. . . , "V' ' ds,) ' :'. ' 'L';s;5:;'. ,d ;. : * '''~'t . : .... *--t- . i ,t,&. ~ .... ~'' '1 ' : . . . i · . ~ i- i .' ........... : ~'-~.~::'". ..... ; .... :.~ · : ~ 8040' Bohr FO-I Pochr ( 2.er~' 0.0~ 4.0e.[O.) v/ml,o~ . ' .to.lo~ (S.8'0. O., '4. S'tO.) ::: ' j ' ' ...... ~ ~ ............ ~..~., . · ....... · ..1- :l, · . . "0070' 1.72" X-N Nipple ~/2.63S* ~*'le IS.TS" 1.0.) _ .- ~$' ~1~ 111~ ..... ~. ....... [''' . . . 8636' POT0 ''' Itel' r" te~ L-e0 eTAS - (6.184' eD., 6.059' dciftJ . ' ~ 2. R/l T~ecor Sv~vo/ ( 3-18 -86 } ~ 7 O- 3~ ,. * ..... (,-~o-0,~ HILNE POINT C-3 (P)~ OP EBATOR: COHOCO INC. SURFACE LOCATION= 1395" FSL~ 2326". FEL, Section lO, TI3N~ RIOE, U.H. BO3:TOH BOLE ~OCATION: SPUD DATE= 0~/29182 88~8' ~3690 FSL, 36510 FEL, Section 10, TI3N~ EIOE~ U.H. NOTES:*DV" Tool et 20730 1. All measurements from~DB of Nabor8 17 2. KDB - SL - 3. KDB - GL - 180 ~. H~x. sn$1e - 40' @ 3800* $, KOP at 2&OS° 6. Slant Type Hole - YKS 9 518" Surface CeotnS 1. Pumped 7&5 Bbls of Arctic Set cement. 2. DiSplaced vith drillin$ mud. · . NOTE: 2/i0 Bbls cement returns. Centraltzerst per mOt 25160 - 22760 per 800 2276* - 1836t 20** 921, Feld at 115' 13 3/8" 72J, L-SO Stra. · at 2316' 7" ProductionCastni 1. Pumped 30 Bbls of spacer 3000 and 20 ~bls Cg I00. '' 2. pumped 102 Bbls (500 ex) "G" cameo= vith .5~ D.-59, D-65, 3X KCL and .2ID-&6, 3..Displaced w~th 10.$ pp$ mud. HOTE: CircUlated 3O0 sacks Arctic Set I ceuentthroush °DVe Tool at 2072** Centralizer~: per 200 8750* - 8679' per 80" 86790 - 6039' per &0° 2116' - 20330 per 120'2033' - Surface 711 29#, L-80 Bits. 8759" Tom Painter Division Manager Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and. 5 inactive production wells at Milne Point. ACTIVE: B-3, B-4A, B-6, B-9, B-10, B-It, B-13, B-15, B-16, C-l, C-2, ¢-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: B-20, B-21, B-22 C-17, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. K E F_ E!' f , ~i "": F"~, ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injecbion wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-I; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. if you have any questions on the shutdo%~ procedure please contact G.~c~er at 56 -7637 Don ~-'~ g . Yours very STATE OF ALASKA ALAS . OIL AND GAS CONSERVATION COM _;ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator Conoco I. nc. 3. Address 3201 C Street, Ste. 200, Anchorage, Alaska 99503 4. Location of well at surface 1395' FSL, 2326' FEL, Sec. 10, T13N, R10E, U.M. At top of productive interval 1258' FNL, 3744' FEL, Sec. 10, T13N, R10E, U.M. At effective depth N/A 5. Datum elevation (DF or KB) 59' KB 6. Unit or Property name Milne Point Unit 7. Well number C-3 8. Permit number 82-50 9. APl number 50-- 029-20786 10. Pool Kuparuk River feet 11. Present well condition summary Total depth: measured true vertical 8848 feet 7785 feet Plugs (measured) Effective depth: measured N/A feet true vertical feet Junk (measured) Casing Length Size Structural Cemented Measured depth True Vertical depth Conductor 80' 16" Surface 2280' 13 3/8" Intermediate Production 87 25 ' 7" Liner Perforation depth: measured true vertical To Surface 115' 115' 745 bbls 2316' 2316' 7894'-7912'; 6919'-6934' 7950'-8014'; 8062'-8080' ; 6967'-7023'; 7065'-70817; ~ Tubing (size, grade and measured depth) 3~", L-80, 8085' Packers andSSSV(typeand measured'~h)SCSSV @ 2066'; Ret.' Pkr. @ 7757'; Perm. Pkr. @ 8040' 12.Attachments Description summary of proposal ~;L Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I here~thatRe foregoing is true and correct to the best of my knowledge Signed _ -. ?__ ~ Title Sr. Pr;ductior, Engir, ccr Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Form 10-403 Rev 124-85 by order of the commission Date/.~ Subr~it in t/riplicate STATE OF ALASKA ALASKA(- _ AN D GAS CONSERVATION C~, MISSION SUNDRY AND REPORT:5 CN W;L S 1. DRILLING WELL [] COMPLETED WELLX~ OTHER 2. Name of Operator Conoco ]:nc. 3. Address 3201 'C' Street Suite 200 Anchorage, AK 4. Location of Well 1395' FSL, 2326' FEL, Sec'. 10, T13N, RIOE. U.M. 5. Elevation in feet (indicate KB, DF, etc.) '45' KB Lease Designation and Serial No. APL 47434 12. 7. Permit No. 82-50 8. APl Number 5o-029-20786 9. Unit or Lease Name Milne Point Unit 10. Well Number C-3 1 1. Field and Pool Kuparuk River Fi eld Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other J~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A recent production profi,le log run on the subject well indicated that only 5% of the well's' production was coming from the primary sand (Lower Kuparuk) while the remainder of the production was coming from the selective sand. The proposal is ':. to reperforate a portion (20') of the Lower Kuparuk formation, then observe the well's performance. Verbal approval was given by Mr. Chatterton 'on 2-14-86. RECF!\/FD - .. ..... Sr. Prod. Engr. Signed ~ } ~- ~-- Title The space below for Commission use Date 2-14-86 Cond,tions of Approval, if any: Approved by < Approved Co~p¥ Returned ~ By Order of COMMISSIONER The Commission Form 10403 Rev. 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reporls"in Duplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 February 12, 1986 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Gentlemen: Sundry Notices and Report on Wells Attached for your approval are the original and one copy of the Sundry Notices to fracture stimulate the Milne Point Unit Wells B-8, C-3, C-17, and C-19. Also please find the original and one copy of the Sundry Notice to sidetrack the MPU B-21 well. Please direct any questions to Lynn Alexander at 564-7609. Very truly yours, Everett D. Wilson Division Administrative Manager LA/kss RECEI . ':r) FEB 1 2 1986 ~aska Oil & Gas ~, .................. ~n Anchorage SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. Conoco Inc. 82-50 OTHER [] 3. Address 3201 C Street, Suite, Anchorage, AK 4. Location of Well 1395' FSL, 2326' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 45' KB qqs03 10, T13N, RIOE, U.M. 12. J 6 . Lease Designation and Serial No. ADL 47434 8. APl Number 50- 029-20786 9. Unit or Lease Name Mi]ne Point Unit 10. Well Number C-3 11. Field and Pool Kuparuk River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A fracture stimulation treatment is proposed for the lower' Kuparuk (2)formation to improve the relative permeability. The treatment will increase 'ultimate recovery from the lower' Kuparuk (21) formation. The operation should take place in February or March. RECEiPting,,,, Alaska 0il & Gas Cu~s. u~ ......... si0r~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of APproval, if any: Approved by Date ~--' { \ 'B I~ ~,~turn~ By Order of COMMISSIONFR the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C ' MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLY~ OTHER [] 2. Name, of Operato~ conoco Inc. 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 4. Location of Well 1395' FSL, 2326' FEL, Sec, 99503 10, T13N, RIOE, U.M. 7. Permit No. 82-50 8. APl Number 50- 029-20786 9. Unit or Lease Name Milne Point Unit 10. Well Number C-3 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 45' KB I 47434 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought.on as an oil producing well on 1-1-86, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ho~;~sb:; A~vCa~7~SnS~O: n use By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate .............. i i i i iiii1~ ~ i ~ I i ,1 ..." , /.' ~ i . ' ~ ~ r .......... "" ................. EXIS,TI NG DEVELOPMENT NOTE;: ~' L STATE PLANE CO-ORDINATES AR~ ~H~ 4. Z. A~ GEOD~ TIC POSITIONS ARE . H.A.D. ;9Z7. ~. OFF~ETS TO SECTION LINES ARE COMPUTED :' BASED-ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. L~ATED WITHIN ~ IO, T I~N, RIO[~ ~M.,AK. ~CkTION I~ SECTION STAT[ PLAN8 CO-ORD$. GEODETIC POSITION "~1 ~ ~, -- WELL FROMm. LIN ~ [. UN[ ~RTHINGS LASTINGS LATITUDE LONGITUDE OAT[ ~CH[CN[~ , FIELD B~K C-I I 1168' 2250' 6,029,~.20 . 558,20~57 ~29' 27. esa"a. 14~ 5f 27.056"w' ~ ~ , ............ k I ............~ ' 22-~ c - 7i I009' 2396' 6,029,290. ~ 558 ~ ~5.29 70029' 26.50~'N 149° 31' ~1.162 "W. P ~.~ } ~. ...' ,,o.,~.~ .,,,~,.,.~o'2,',.o,~. ,,,°,,.,.o~o-w. "' ~., ! ......... I .... 1114' 2428' 6 ,029 } ~95.~ $58 ~051.8~ ~°~9' 27.~40"N 149° ~' $~. 12~"W. 6. ............ . 89~ 2~6~ 6,029, 176.48 558 , 101.82 70029' 25.184"~ 1490~' ~. I1~" W. .... :.. , ~, , .... ' ~%~- ' C CERTIFICATE OF SURVEYOR : ~ ~ ~'~ ' ~ . ~_ I HEREBY CERTIFY THAT .I AM PROPERLY ~j oe ,:~ :~'~- :~. AS' BUILT WgLL ~CATION LOCaTiON SURV~? ~aDe e~ ~( oa UNO[r ~ f~ ~ Bernard Tomulich : ~ t - ~?. ~, ,, ,,, ~ ~OV 4 ~85 , . ,oo. , o, ~ ~ ~OF~ %~ ~t, ' cSSION~L ~'.~ ~%~~~ U. ~ ua ~nsf~mmissiot co e.TS: ...... I,~, r~ ,~ -~.. , , ,, - ..... Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are the Sundry Notices for the Milne Point C-3, C-7, C-8, and C-9 wells. Conoco intends to stimulate the above referenced wells. If you have any questions, please call Don Girdler at 564-7637. Very ~ruly yours, R. J. Francis Manager-Engineering DRG/vv cc: MP C-3, C'7, C-8, C-9 Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~: OTHER [] 2. Name of Operator 7. Permit No. CONOCO, INC. 82-50 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50- 029-20789 4. Location of Well 1395' FSL, 2326' FEL, Sec. I0, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KB I ADL 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-3 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject well is proposed for a 12-3 mud acid stimulation treatment to improve the productivity from the Middle Kuparuk formation. The 12-3 mud acid treatment has been successful on the Middle Kuparuk formation in offset wells. RECEIVED OCT 0 ]9 5 VERBAL APPROVAL WAS GIVEN BY MR. CHATTERTON I0-25-8~laska 0fl & Gas Cons. C0mmissJ0~ Anchorag~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed D. R' {~'/~ ~ C~/~..) Title Sr. Production The space below for Commission use Engineer Date 10-28-85 Conditions of APproval, if any: Approved by COMMISSIONER Approvea Copy Re~turr~ By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 2, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached is the Sundry Notice for the Milne Point C-3 well. Conoco intends to move a completion rig onto the subject well and pull tubing in order to install a new safety valve. After rerunning the tubing with the new safety valve the well will be suspended until the production facilities are ready. If you have any questions, please call Don Girdler at 564-7637. Very truly yours, Manager-Engineering DRG/w C-3 sundry letter cc: MP C-3 Correspondence File RECEIVED OCT04 1985 Alaska Oil & Gas Cons. Commission Anchorage SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:E] OTHER [] 2. Name of Operator 7. Permit No. CONOCO, INC. 82-50 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50_029-20789 4. Location of Well 1395 FSL, 2326' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 45' KB I ADL 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-3 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [~ Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In preparation for bringing the C-3 well on line the subsurface safety valve was differentially tested. The valve failed to hold back the formation pressure. We now propose to rig-up a completion rig to pull tubing and replace the subsurface safety valve. Verbal approval was given by Mr. Chatterton on October 2, 1985 RECEIVED 0 19 5 Alaska Oil & Gas Cons. Commission Anchorage 14. I here~h~ fo~oin)~'and correct to the best of my knowledge. ' Signed % ~M~_~ _ TitleManager of Alaskan Operations The space/~for Commission usZ C Kemp Conditiq~n~of Approval, if any: 10-02-85 Date Approved by. IRI~IIA[ $1GIIEB :B,Y L~NHIE C. SMITH Approved, Copy RetUrrt~ ,, By Order of COMMISSION EI~' the'Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA,r[,~ _ AND GAS CONSERVATION CC('~- vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 4. Location of Well SURFACE: '1395' FSL, 2326' FEL, Sec 10, T13N, R10E * As per certified pad drawing 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 45' KB ADL 47434 12. Check AppropriateBoxTolndicate NatureofNotice, Report, or 7. Permit No. 82-50 8. APl Number 50_029-20786 9. Unit or Lease Name Milne Point Unit 10. Well Number C-3 11. Field and Pool Kuparuk River )ther Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate} Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with'a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-3 well was originally completed as a production well in the Lower Kuparuk Formation then temporarily suspended. We now propose completing the well as a single selective with the Lower Kuparuk as the primary and the Middle Kuparuk and Laminated Zone as the selectives. (The Middle Kuparuk and Laminated Zone have been perforated but they are isolated behind tubing). After recompleting, the well is to be fracture stimulated in the Lower.Kuparuk then temporarily suspended pending installation of production facilities. (The completion rig will be released before the well is stimulated.) RECEIVED JUN 2 o 1985 Alaska Oii & Gas Cons. Commission Anchorage 14. I her~rtify that the foregoing is true Signed~'''~ '~ The space below for Commission use and correct to the best of my knowledge. Sr. Production Engineer Title Date 6-17-85 Conditions of APproval, if any: Approved by COMMISSIONER Approved By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MILNE POINT UNIT C NO. 3 CASING DIAGRAM OPERATOR: CONOCO, INC. SURFACE LOCATION: 1395' FSL, 2326' FEL, SIO, BOTTOMHOLE LOCATION: 4369' FSL, :)651' FEL, SPUD DATE: 4/29/B2 Tl3tl, RIOE, U. M. SIO, TI3N, RIOE, U.M. GROUND LEVEL EL. 19' KELLY F. ST. TOP O~ CltlEmT ! ( '"' "" '" ! C-"~'' ~,, I I t--'~' "" s'zE BUSHING EL.: 45' 20'. 92blfl. G~. Bo Pl~LP Cas£n~: ~ 92 lb/ft, grade B, PELP, 0'-115'_* 13-3/8", 72 lb/ft, L-80, BTRS, 0'-2316' ~' C~. St4QE 7fi, 29 lb/ft, L-80, BTRS, 0'-8759' --'/", ?.9 Ik/ll, L-10, SltS tOTE: T#E MAX. HO~.E ANG~F. O~,~3RS Of ~*, m Cement: Primary 13-3/8" - 4500 sks. Arctic Set II 7" - First stage - 500 sks. class G w/0.5% D-59, 0.5% D-65, 3% KC1, 0.2% D-46 Second stage - 300 bbl. Arctic Pack followed by 300 sks. Arctic Set I cement Perforations: Production 8086'-8118', 12 JSPF, 5" Scalloped Vanngun 8062'-8080', 12 JSPF, 5" Scalloped Vanngun 7950'-8014', 12 JS?F, 5" Scalloped Vanngun 7894'-7912', 12 JSPF, 5" Scalloped Vanngun Well Test Results: Test Intv. BOPD No Date Form. (°API) BT~PD ~ICFPD P~ ?wf Pe 1 6/1/82 8062'-80' 1050 0 340 LK-I (22.7°) 8086'-118' LK-2 2 6/5/82 7950'-8014' 250 0 100 Lam. Kup. (23.5°) 3 6/8/82 7894'-912' 113 0 40 MK-1 (22.7°) 145 2285 3540 7S :~68 ~508! 42 2332 3487 RECEIVED J U N 2 0 t985 Alaska Oil & Gas Cons. Commission Anchorage The hole angle and direction at T.D. is ±25°, N 27° E. ORIGINAL: JBF, 5/6) RE.¥1SIOtlS: Mi'LNE' Po'iN~= uNIT 'C"'N-o OPERATOR: CONOCO, INC. ' = =- '= ..... SURFACE LOCATION: 1395'F~SL, 2-$26'FE~_'; SEC IO,TISN, RiOE, U.M. BOTTOMHOLE LOCAT ION: 4`369'FS L, .3651' FEL, SEC I0, TI3N, RIOE, U. M. RIG KB. TO THE TOP OF THE TUBING HANGER = 23' DESCRIPTION LENGTH O.D. I.D DEPTH DEPTH (RKB) 2a' ~~ ~ 3 I/2" 8TRS PUP ,JOINT 2.63' 3.90" 2.992" 24' I/2" 9TRS x 3.5" VAM CROSS-OVER 0.73' 5.90" 2.992" 27' I/Z" VAM TUBING AND 4 PUP JOINTS 59.98' 3.90" 2.992" 27' 2074' 3 I/2'~ 9.2LB/FT, L-80, VAM TUBING 1999.29' 3.90" --I/4" SAFETY VALVE coNTRoL LINE ' d:;2085' 0.25`° 2.992" CAMCO TRDP SAFETY VALVE 1AE 19.55' 3 I/2", 9.2LB/FT, L-80, VAM TUBING 289.84' 2.812" 2074' 2.992" 2093' 2383' INTERFACE No. I 7.5' 5.313" 2.875" 2383' 8- $ I/2" CAMCO K8UG GAS LIFT No. 2 7.5' 5.313" 2.875" 3357' MANDRELS SPACED OUT No. 3 7.5' 5.313" 2.875" 4348' WITH 3 I/2" VAM TUBING No.4 7.5' 5.:313" 2.875" 5250' AND PUP JOINTS. ALL VALVES WERE RUN WITH No. 5 7.5' 5.:31-'i" 2.875" 5995' TYPE "E" DUMMIES ANO N~6 7.5' 5.:313" 2.875" 6622' BK-2 LATCHES. No. 7 7.5' 5.31:3" 2.875" 7186' No. 8 7.5' 5.:313" 2.875" 7655' _ ~ 7", ZgLB/FT, L-80 BTRS CASING 7730' 3 I/2" VAM TUBING (2 JTS) AND PUP JT. 66.85' 3 I/2" VAM x :3.5" BTRS CROSS-OVER 0.67' "PXN" PLUG (W,/."x" KEYS) AND PRONG INSTALLED IN 'X'L NIPPLE. BAKER EBA-1 EXTRA-LONG TUBING SEAL RECEPTACLE W/2.81 "X"-NIPPLE 26.65' 3.90" 2.992" 7662' 3.90" 2.992" 7729' 7757L . ~ BAKER K-22 ANCHOR TUBING SEAL 0.9:>' ~ BN(ER SAD PACKER 84 x 40 x 32 4.63' BAKER MILLOUT EXTENSION 5.75' 4 I/2" 8RD BOX x .35" 8TRS PIN CROSS-OVER 0.78' 7894'~- _ 3 I/2" BTRS TUBING (5 JTS) 148.4' 7912"- ': _:'~ PERFORATIONS (MIDDLE KUPARUK) 7917' -------'- ' 3 I/2" x "X"- NIPPLE W/2.812" I.D. I. 16' 7950' -= __. $ I/2" 8TRS TUBING (4 ,ITS) 120.68' ..T. -- .~- ~ PERFORATIONS (LAMINATED KUPARUK) 8014' '~ - ~ BAKER SEAL ASSEMBLY WITH LOCATOR 6.90' 3.998" 3.000" "'"'--'-'1 G- 22 LOCATOR, 5 SEAL PACKER 2.65' 5.875" 4.000" 8040' __ . III1 I /UNITS AND MULE SHOE MILLOUT 5.42' 5.500" 4.500" ii i i-i' -8AKER FB-, ~CKER DS-40EXT. 1__ 3 I/2" BTRS PiN x 5" 8RD CROSS-OVER 0.73' 5.500" 3.000" 8078' :3 I/2" BTRS JT. TUBING 29.47' 3.90" 2.992" 8062' ~ [~, 2,75" X-N NIPPLE W/2.635" NO-GO 1.5' 3.90"(NO-GO) 2.635" -- 3 ,/2" 8TRS PUP ,IO,.T ,.7' 3.~0" 2.992" ~§~'--:~oB~ = _ 3 ,/~" MULE S.OE 0.67' 3.90" ~.992" '~ ~ PERFORATIONS { LOWER KUPARUK) 8118' " 8635' _ CEMENT BAFFLE -PBTD ,o o ?o{ '"F OATS.OE JUN20 8848' 10.5PPG MUD S ' TOTAL DEPTH · Alaska Oil & Gas Cons. Commission Anchorag~ NOTE: ATIGHT SPOT WAS ENCOUNTERED IN THE TUBING AT 3069' ON 4/29/83 WHILE RUNNING A "PXN" PLUG. 5.750" N/A 7730' 4.000" :3.000" 7756.6' 5.697" :3.250" 7757.5' 4.500" 4.000" 7762' 5.000" :3.000" 7768' 3.90" 2.992" 7769' 3.90" 3.182" 7917' :3.90" 2.992" 7918' 8038' 8040' 8043' 8048' 8049' 8078' 8079.5' 8084' 8085' ORIGINAL: JBF, 5-83 REVISIONS: November 6, 1984 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Jim Trimble Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-I, B-2, B-3, B-4A, B-5, C-l, C-2, C-3, D-i, L-l, M-IA, N-lB, and Gwydyr Bay State 2A. Ail of the above are classified suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questJ, ons. You~rs very truly,, . //manager of Al. askan Operations ,,-// Attachments RECEIVED NOV 0 91984 Alaska 0il & Gas Cons. Commissior~ Anchorage K(i STATE OF ALASKA ALAS OIL AND GAS CONSERVATION ~' MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~X OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 82-50 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50- 029-20789 4. Location of Well 1395' FSL, 2326' FEL, Section 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) KB=45' I 6. Lease Designation and Serial No. ADL 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-3 11. Field and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other i'-I Pull Tubing [] Other ~X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your. representatives to conduct an inspection each year as long as the status of the well is suspended. This well w±ll be utilized in the Phase I development of the Milne Point Unit. Work to re-activate this well will begin prior to production in early 1986. 14.1 hereby,p~rtif?that.,~e foregoing i~ue and correct to the best of my knowledge. Signed Title The spac/i~ow fo; Commission ~use ~' Condi~oM~ of APproval, if any: Date Approved Returned /l - Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate H. D. Haley Manager of Alaskan Operations Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 October 17, 1983 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-i, A-2, B-i, B-2, B-3, B-4A, C-I, C-2~., C-4, D-I, and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells, and Conoco will be contacting one of your representatiVes to conduct an inspection of these wells each year as long as the wells remain under this status. Also attached is a completed 10-407 form requesting a change in status for Milne Point B-5 from plugged and abandoned to suspended. You will also find photographs enclosed covering the cleanup operations that took place subsequent to this year's inspection of Gwydyr Bay State #1 and #2A. Photographs are also included that show the new signs mounted on Milne Point C-4 and D-2A. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. H. D. I-Ialey Manager of Alaskan Operations JTD/kp cc: A. E. Hastings, Anchorage " STATE OF ALASKA L ALAS OILAND GAS CONSERVATION OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~1 OTHER [] 2. Name of Operator Conoco Inc. 3. Address 2525 C Street, Suite 100, ^nchoraqe, Alaska 99503 4. Location of Well 1395' FSL, 2326' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) _ KR=45' ' I 6 . Lease Designation and Serial No. ADL 47434 7. Permit No. 82-50 8. APl Number 5o- 029-20789 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-3 11. Field and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~( Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension fo.r a suspended well. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plugged and abandoned status. 14., "erebv7~t]~/~he fore:Ding is true and correct to the best of my knowledge. Signed .... ~" /~'7'~''~'''~ '7~ Tit~eMana§er of Alaskan Operations The space below for Commission use H, D. Hal ey Date 10-19-83 Conditions of Approval, if any: Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Fo~m 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate H. D. Haley Conoco Inc. Manager of Alaskan Operations 2525 C Street Suite 100 Anchorage, AK 99503 October 1, 1982 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble' Attached are completed 10-403 forms for: Milne .Point A-l, B-l, B-2, B-3, B-4A, C-1;~C~3, D-l, Kavearak Point 32-25; and Gwydyr Bay State #2A. All of the above are classified as suspended wells and Conoco will be contacting one of-your representatives to conduct an inspection each year until the wells have a plugged and abandoned status. Also attached is a completed 10-407 form requesting a change in status for Gwydyr Bay State #1 from suspended to plugged and abandoned. You will also find the photographs you requested concerning the recent inspections of Gwydyr Bay State #1, #2A, and Milne Point A-1. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. Yours very truly, H. D. Haley Manager of Alaskan Operations JTD/tt cc' G. A. Merriman -"w/o attachments A. E. Hastings w/o attachments [ STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchoraqe, Alaska 99503 4. Location of Well 1395' FSL, 2326' FEL, Sec. 10, RIOE, T13N, UM 5. Elevation in feet (indicate KB, DF, etc.) KB=45' 6. Lease Designation and Serial No. ADL 47434 7. Permit No. 82-50 8. APl Number 50- 029-20789 9. Unit or Lease Name Miln~ Pnint Unit 10. Well Number Milne Point C-3 11. Field and Pool Kuparuk Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well.. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plUgged and abandoned status. 14. I hereby cern,, ~. ng is true and correct to the best of my knowledge. Signed /~,~~~~ Title Manager of Alaskan Operations Date The space below for Commission use ~ / Conditions of Approval if any' '--~' Approved Returned An inspection will be nece.s._s.~ry by ...August 1983. BY tt'R~l¥ W, KUGLER By Order of Approved by COMMISSIONER the Commission Date 10-6-82 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM State of Alaska ALASKA OIL A~TD GAS CONSERVATIO~ COMMISSION Chai~n ~ THRU: Lonnie C. Smith // ~:f'~' Commissioner DATE: FILE NO: TELEPHONE NO: September 2, 1983 10SA:J12 FROM: Harold R. Hawkins ~etroleum InSpector '.'"~"/ suBJECT: Cleanup Inspection For Extension of Suspended Status, Conoco, Milne Point C-3, Surf. Loc. 1,395' FSL, 2,330' FEL, Sec. 10, T13~,R10E,U~, Permit No. 82-50. Wednesday, August 17, 19832 I left Conoco's C-2 Well, subject of '~no%~e'~"'reP0r~ to c0~0~o,s c-3 Well. I inspected Conoco's Milne Point C-3 and found all requirements of A.O.G.C.C. regulations were m~t for extension of suspension. I filled, out an A.O.G.C.C. report which is attached. In summary, I inspected ConocO's Milne Point C-3 Well and found all retirements of A.O.G.C.C. regulations were met. I recommend approval of extension of suspension. Attachments 02-001AfRev. 10/79) Suspended Well and Location Repo 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator ~- ~ ~ ~ ~-~ Addre s s Surface Location of Well _/.~_~' Ft. F ~ L, ~ ~P Ft. Sec. /D, T~..~ __~_~, R/~ ~ , ~) $. Date Suspended Permit No. F_~ L API No. 50 Unit or Lease Name Well No. Field & Pool Condition of Pad Condition of Pits _. b'__~ ~_~_ _. Well head - Ail outlets plugged Well sign - Attached to well~ Attached to wel · Attached to No Ye s ~ No Information correct No Cellar - Opened Yes No Rat Hole Fi 1 led Ye s No WaterWell - Plugged off capped Open Explanation Open Yes No Ye s No No Photographs taken to verify above conditions Yes No Exp la na ton Work to be dOne to be acceptable This.well and location i s ( (unacceptable) to be suspended for the period o 19_8~thru Inspected by: classified as Revised 8~24/82 N 0 R T H · 0 ¢ 0 -A :,. ,". GEODETIC POSITiO · . ..' ',' . . . , · '.!: ~ .{, .~.~;:~?': 4 ~ 70°29' 29,607" AD ' A~a P C . .-.- . ..,:,, . O,l & Ga~ Cons 0i~=m~o~. ~'~ ~ .'..: i ''' iii i IlCERTIFICATE O~ SURVEYOR: I HEREBy CERTIFY THAT i AM PROPERLY ." II ,, , , .. , . REGISTERED AND LICENSED TO PRACTICE LAND "' I~ -. ' SURVEYING IN THE STATE OF ALASKA ~D ~UAT I~ . : .' ~';,.{', ~15_ RLAT REPRESENTS A LOCATION SURVEY II · .:: Ii , , MADE BY ME OR UNDER MY SUPERVISION, AND II . ' ~ II THAT ALL DIMENSIONS AND OTHER DETAi-e .... Il I lILY Ii ' ~ ~ · II ~~n~ IIm[C~g RM ~ I - II ...... i[ '. ' ' · . . . ' . J~ . llaOa ~. e2o2~ ."/;' ,. VICINITY .: 'MAP ~ .;,: .': . r' .... LOCATION !N SECTION " ~ELL ,i FROM SOUTH LINE j FROM EAST LINE IlIi'i' IllllIeellllIlllq, ..ielIllll~.......IIi ... I . " 168' ; 2256' 2.494' ,. ':" ".~: I "," .. e... PLANE COORDINATES ~"o- --o-~,~ o o-o - -o ------ - o--- -- -- ~..- .~...e.e....... · ELI. :. IIORTHIN~S : EASTINS$ :.?~ · -------- cee ~-----& -., .,-., ....,. e... e.e". e......... "','1 * : . 6 029 4~0.18 ;. - 558 203.55 : · . · . .~'?!;:'~ 3 :' 6 029 677. 35 : 358 ,3t. ia · - 4 : 6 029 625.19'. 557 963,3/ .I ZONE 4 · · ----- --- -,...e ..ce,. e~.......~.. ' -- ' ...... ~ "- 3noco Inc. -'- : ~-cord of Shipment-of (CO~OC .)nfidential Information beological SeCtion r~o Lo~ie_. ~f~i~- ~~i55io~c From ~0~0~0 I~C Under Separate Cover [~nclosed luantity Contents 7- z.i- E~2. · W. it ~: · Z" ,- 6" RECEIVED · Signed By _ I"tO~! ~ _1~.~,~ Date ~;~..15r~~ AUG - 6 iq~9 ansmittal. Approved By ~,~J~), ~.~o~..~ .... Structions: Pleas~¢no~dge receip~ ~o~R~y b~sig~ and returning carbon coPy.. Alaska Oil & Gas Cons. C0mm~ss/0n ~ce?ed By_ ~ ~ ~~ Date Anch0raqe., ansmittal Copy Only To ;-98 PCX1, 7-79 NORICK OKLA. CITY PRINTED IN U.S.A. onfidential Information ~eological Section U n.~.~ .... - L~_¢ }uantity Contents RECEIVED ;~,~;~ A~,ov~d ~ ~,~, ~. ~ Da't; ~¢t~tions: Please acknowledge receipt'Pro~pt y by sign .g and returning ' Date '.' ~ ~ -~ ~ansmittat Copy Only To 3-98 PCX1, 7-79 NORICK OKLA. CITY PRINTED IN U.S.A. July 19, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Lonnie Smith, Commissioner ...... Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: 'Subject- Completion Reports, Milne Point Unit Well Nos. B-3,~C-3'~B-4. Montly Report of Operations - Milne Point B No. 4A. The subject reports are attached. If you have any questions, please contact Gary Merriman at. 279-0611. Yours very truly, W. M. Haskell Administrative Coordinator SHB/kp Attachment cc: Mr. E. A. Blair, Hamilton International, Denver, w/Attachments Mr. D. S. Motazedi, Champlin, Long Beach, w/Attachments Mr. Bryan D. Humphries, Cities, Houston, w/Attachments Mr. Glenn E. Wood, Reading & Bates, Tulsa, w/Attachments Mr. John W. Walker, Chevron, Concord, w/Attachments .Mr. Robert T. Anderson, Union, Anchorage, w/Attachments Mr. T. J. Jovin, Phillips, Denver, w/B-4A only Mr. L, B. Agers, Mobil, Denver, w/B-4A only Mr. L. A. Dinges, Offshore Explo, Adm., Houston, w/Attachments STATE OF ALASKA ALASKA AND GAS CONSERVATION CC .,.i. SSION WELL COMPLETIOI _O_R RECOMPLETION REPORT AND LOG 1. Status of Well.- 1 ;,_0Ni~lll0 E ~!V~ ~_ ._ Classification of Service Well OIL [] GAS [] SUSPENDED~ ABANDONED [] I RC'A'--~r-:.[i,.,<~ . 2. Name of Operator VE'MFi~2D 7. Permit Number Conoco Inc. sud. £. . 82-50 3. Address 8. APl Number 2525 C Street, Suite 100 Anchorage, AK -~ 50-029-20786 4. Location of well at surface 9. Unit or Lease Name 1395' FSL, 2326' FEL, Sec. lO, RIOE, TI3N, U.M.. Milne Point Unit At Top Producing Interval 10. Well Number 3958' FSL, 3790' FEL, Sec. 10, RIOE, T13N, U.M. Milne Point C No. 3 At Total Depth 1 1. Field and Pool 4369' FSL, 3651' FEL, Sec. lO, RIOE, T13N, U.M. Kuparuk River Field ,5. Elevation in feet (indicate KB, DF etc.) 6. Lease Designation and Serial No. KB - 45' ' ADL 47434 Kuparuk River Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore J 16. No. of Completions 4/29/82 5/15/82 6/16/82 N/A feet MSL I · 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8848' 7785' 8635' 7593' kS No feetMD ' , YES [] N/A +-1800' 22. Type Electric or Other Logs Run BHCS/DIL/GR, GR/CNL/FDC, GR/CBL/CCL, NGT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 92# B O' 80' '26" To Surface O' 13 3/8" 72# L-80 O' 2316' 17~-'' 4500 sks Arctic Set II O' 7" 29# L-80 O' .8759', ."8½" 500 sks 'G' - 300 O' bbls. Arctic Pack - 300 sks Arctic Set ] 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) Intervals' Size SPF Diameter 3~" 8085' 8040' 8062'-8080' 18' 1 2 0.7" '..- · ' ' '''~ "~ 8086' -8118' 32' 12 0.7" 26. ,. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7950"'8014' 6.4' ' 12 0.7" , DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 7894'7912' 18' 12 0.7" " ' ' ttc, - 27. PRODUCTION TEST see A .., - a h e d~ ~t~l~ ~ Date Fi[st Production Me.thod of Operation(Flowing, gas lift, etc.) " Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHO~ ~IZ~ I GAS-OIL RAT. IQ L- TEST PERIOD * :."· ' ' . ¢~',~ R,"L~'2,$ Flow Tubing . Casing Pressure CALCULATED OIL-BBL GAS-MCF . ,wATER-BBL,? ~vl'~: 'Press. 24-rHr~OUR''RATE * ' "'" 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips.and presence of oil, gas or water. Submit core.chips. b~actu~es/ Core Lithology .~ :~' P. orosit7 .~.. Apparent.D. ip O, G, W 8063'-8123' Interlam. 52% Poor None/dip Oil and gas bleeding s.d/Sh . horizontal, from sandy laminae· Sandstone 48% Good - Fair '" free oil in sandstone w/good oil stain. 8123' -818;3! Interlam. 98%. PoOr. ".' ' Nofie/dip sd/sh horizontal -Good oil stain and L.Sandstone 2% Poor .odor i.n. sandy. ].ami, n. ae Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE & s a n d s t o~l.~-:.b]' e.~,~j.Dg oil & gag-T~"i'bh'g~-l'a'~'~nae planes. .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Schrader Bluff 3881 (3711 TVD) West Sak 4603 (4274 TVD) Middle Kuparuk 7894 (6919 TVD) Kuparuk 8062 TVD) V~ Lower Kingak Shale 8654 (7592 TVD) 31] LIST OF ATTACHMENTS .... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . ~/~_,f,,~ Title Sup. Engineer Date INSTRUCTIONS General' This forrn 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 shoTM the details of any m'Ultiple 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". Form 10-407 MILNE POINT NO. C No.3 WELL COMPLETION REPORT AND LOG PRODUCTION TEST DATA Listed below are representative test data on the intervals tested in Milne Point C No.3. Interval Tested (M.D.) Date of Test Method of Operation Hours Produced Oil Produced (BBL) Gas Produced (MCF) Water Produced (BBL) GOR (CF/BBL) Choke Size Flowing Tubing Pressure (PSI) Casing Pressure (PSI) Gauge Depth Flowing Bottomhole Press.(PSIG) Final Buildup Pressure (PSIG) Average Production Rates: BOPD BWPD MCFPD Oil Gravity (°API) Production Test No. 1 Production Test No. 2 Production Test No. 3 8086'-8118' 8062'-8080' 7950'-8014' 7894'-7912' 6/1-3/82 6/5-7/82 6/8-10/82 Drillstem Test Drillstem Test Drillstem Test 6.5 9.5 11.0 282 80 52 92 46 40 Nil Nil Nil 330 400 290 1" 1/2" 1/2" 110-145 42-75 9-42 1000-1100 1100 1275-1400 7919' 7807' 7751' 2622-2286 2705-2168 2872-2273 3471 3417 3400 1050 250 113 Nil Nil Nil 340 100 40 22.7 23.5 22.7 NOTE: Downhole pressures are reported at gauge depth. WELL HISTORY MILNE POINT C NO. 3 4-25 4-26 4-27 4-28 4-29 4-30 5-1 5-2 5-3 5-4 5-5 5-6 Skidded sub base over hole. Erecting windwalls. Install motors & mud pumps. Set in mud tanks, generator, boilers & continue R/U. API 50-029-20786 Elevation: 45' KB. Location: 1395' FSL, 2326' FEL, Sec. 10, R10E, T13N, Umiat Meridian. R/U rotary table. Finish setting in back end of rig, pipe sheds, Dowell bulk tanks and skid unit. Fired boilers. R/U steam and water lines. R/U rotary table & plumb rig. N/U annular preventer & diverter lines. R/U diverter lines & rig floor. Spudded well at 8:00 p.m. on 4-29. Drlg. @ 481'. Drlg. @ 877' , made 797'. Cond. mud. D/O cmt. in conductor pipe. Work on pumps, unplug flow line & thaw air line. Drlg. @ 2330', made 1453'. Survey dev: 1~° @ 988'. Circ., wiper trip, SLM. Service rig. R/U casing crew. Run 13-3/8", 72#, L-80 to 2316'. Cmt. w/4500 sks. Arctic Set II. Returns - 1636 sks. Hang 20" stack. Cmt. 65' of 20"x13-3/8" annulus. Hang csg., cut off & N/D 20" stack. Install 13-3/8" packoff. Lock down 13-3/8" packoff, N/U casing & tbg. head, test packoff to 2000 psi f/30 min. - o.k. N/U 13-3/8" BOPE, mix mud, change liners in pumps. Drlg. @ 2430', made 100'. N/U 13-3/8" BOPE, test to 5000#. D/O to float collar. Tested casing to 2000# f/~ hr., bled down approx. 50 psi. Drlg. cmt., shoe, and new hole to 2350'. Tested casing seat to 13.8# E.M.W. Drlg. to K.O.P. @ 2430' Circ. & POOH to P/U kick-off assembly. L/D 7-3/4" drill collars. 9#/g~l. mud in hole, pumped 2 bbl., reached 620 psi & bled back to 590 psi & stabilized. Ran gyro survey: 3.68°, N51°56'E @ MD, total 2300'. Mud Wt. 8.9#. Visc. 45. Drlg. @ 2972', made 542'· P/U Dynadrill, bent sub & monels. Slip & cUt drlg. line. TIH w/Dynadrill & drlg. to 2565'· Circ. & B/U mud volume· Survey - Dev: 13° N43W @ 2734' Dev: 15° N34W @ 2797' Dev: 19° ~ud ~t, 8.9#, ~isc, 38. Drlg @ 3608' made 636' POOH & change BHA. TIH, drill & survey · , · · Circ. & POOH· Change BHA & TIH- packed hole @ 2960'.~O~~q~ge BHA. TIH & work hole f/2960'-3608'. Survey - Dev: 2~~3~~203', 31° N37W @ 3328', 34.5° N37W @ 3454'· Mud Wt. 8.9#. Visc. 40. JO[ 2 1 1882 Oil & Gas Cons. 5-7 5-8 5-9 5-10 5-11 5-12 5-13 5-14 5-15 5-16 5-17 Drlg. @ 5104', made 1496'. Work tight hole from 2960'-3608'. Circ. & condition hole. POOH & change BHA. TIH & drill to 3895'. Circ. & work pipe f/3835'-4816'. Survey - Dev: 38.75° N37W @ 3835', 38.5° N36.5W @ 4353', 39° N35W @ 4816'. Drlg. @ 5820', made 716'. Drill & survey f/5104'-5356'. Circ. & POOH. P/U kelly & circ. POOH & change bit. P/U 6 jts. HWDP & TIH. Wash through bridge f/3895'-4030'; spot wash through bridges f/4370'-4500'; TIH, drill & survey f/5356'-5820'. Survey - Dev: 38.5° N34W @ 5296', 38° N32W @ 5761'. Drlg. @ 6680', made 860'. Drill & survey f/5820'-6198'. POOH & change bit & BHA; TIH & drlg. f/6198'-6680'. Survey - Dev:37° N29W @ 6180'. Mud Wt. 9.7#. Visc. 45. Drlg. @ 7337', made 657'. Drill & survey f/6680'-6865'. POOH, retrieve survey, change bit & TIH. Drill & survey f/6865'-7337'. Survey - Dev: 36.5° N26W @ 6640', 36.5° N24W @ 6802', 34° N16W @ 7277'. Mud Wt. 10.4#. Visc. 44. Drlg. @ 7825', made 488'. Drill & survey f/7337'-7560'. Survey - Der: 32° N13W @ 7500'. Circ. & POOH. Test BOP's. P/U bit, TIH & slip drlg. line @ shoe. Mud Wt. 10.3#. Visc. 45. Drlg. @ 8063', made 238'. Circ. & drop survey. Strap out of hole & retrieve survey, no good. R/U Schlumberger. TIH & log w/DIL-GR f/8059'-2316'. R/D Schlumberger. Mud Wt. 10.3# Visc. 55. Coring @ 8183', made 120'. R/D Schlumberger. P/U core barrel & TIH. Core f/8063'-8123'. POOH & L/D core - rec. 60'. Redress core barrel & TIH. Core f.8123'-8183'. POOH & L/D core - rec. 60'. M/U bit & TIH. Mud Wt. 10.3#. Visc. 46. Drlg. @ 8533', made 350'. TIH. Ream core run f/8063' to 8183'. Drill & survey f/8183' to 8188'. Survey - Dev: 30° N13E @ 8000'. Drill & survey f/8188' to 8533'. Survey - Dev: 28° N14E @ 8128', 26° N20E @ 8473'. Circ. & drop survey. POOH, change bit & TIH. Drlg. @ 8848', made 315'. TIH to shoe, cut & slip drlg. line & TIH. Wash down last 30'; pump clutch lines frozen, unable to circulate; BHA packed off & partially stuck; worked pipe free, thaw air lines & regained circulation. Drill f/8533' to 8848'. Circ. & cond. mud for logs. Sweep hole w/30 bbl. vis. pill, 20 std. wiper trip. Depth @ 8848'. Circ. & cond. for log run. Ran surve~6~:V~° N27E @ 8748'. POOH. R/U Schlumberger & ran logs: DIL-SP-GR-BHCS; CNL-FDC-NGT (developed tool problems @ 6900', POOH & ~%k¢lu~ckup tool). Mud Wt 10.5# Visc 46 Al~$ka 0il & .... u~s (}0ns. C0~f~m~ss~0~ Depth 8 8848'. Logging: CNL-FDC-NGT, (second tool run) no good. Worked on tools, made third run, no good. Problem appears to be in wireline or computer unit. Schlumberger has no other units to change out with at this time. Attempt tool run w/dipmeter, no good. Another logging unit now available and on its way to replace unit on location. Change out units. Attempt logging w/dipmeter, having trouble with opening and closing of arms. L/D dipmeter, P/U CNL-FDC-NGT. Tool won't check out on dock, L/D NGT. Ran CNL-FDC without NGT. Mud Wt. 10.5#. Visc. 60. 5-18 Depth @ 8848'. Complete CNL-FDC run. Ran one sidewall core gun, R/D Schlumberger. TIH, circ. & condition mud. 20 std. short trip - no excessive drag. Circ., POOH, & L/D drill pipe. Mud Wt. 10.5#. Visc. 50. 5-19 Depth @ 8848'. POOH, L/D D.P. & D.C. Pull wear bushing & change to 7" rams. R/U & ran 222 j ts. of 7" csg. Pipe stuck @ 8759', could not free pipe. R/U Dowell head & establish circ.; work pipe, tension to a max. of 375,000#, compression to 50,000#, could not free pipe. Mud Wt. 10.5#. Visc. 40. 5-20 Depth @ 8848'. L/D landing it. Pumped 20 bbls. CW-100, 30 bbls. Spacer 3000. Mixed 500 sks. Class "G" cmt. w/.5% D-59, .5% D-65, 3% KCL, .2% D-46. Displaced w/323 bbl. mud & bumped plug to 1500#, float held. Drop opening D.V. bomb. Pressure up and open D.V. collar. Circ. mud in 7" x 13-3/8" annulus out w/water. Pump 300 bbls. of Arctic pack, followed w/300 sks. Arctic Set 1. Displaced w/78 bbls. diesel, bump plug & pres. up to 4000 psi. R/D Dowell. Lift BOP stack & hung off 7" csg. w/slips & packoff. Cut off 7" csg. N/U BOP stack. Pressure test csg. head & packoff, leaking @ 2900#. Bled off & tightened leaking plug. Pres. up, leaking @ 3500#, bled off & tightened flange. 5-21 Depth @ 8848'. Tightened wellhead flanges & retest head & packoff w/4000#, o.k. N/D BOP stack & flange-up wellhead & master gate. Release rig @ 6:00 a.m., May 21, 1982. RDMO. 5-25 Rig up workover rig. 5-26 Continue rigging up. 5-27 R/U equipment. Install rams. Remodify kill lines & manifold lines. Build up flow tee on top of BOP stack. Pressure test blind rams and choke manifold to 3000 psi. P/U, tally & TIH with 6" fluted mill, casing scraper, 10 - 4½" D,.C.'s & 6 jts. of 3~" D.P. 5-28 TIH w/3~" D.P. to 2027' KB. Test BOP's to 3000 psi. D/O cmt. to DV collar at 2073' KB. Drill on DV collar f/2073' - 2075'. Circ. B/U, POOH. Inspect & change out mill. TIH w/mill & D.C. Latch broke on bottle neck elevators, W/O spare elevators. TIH w/D.P., R/U kelly, dril on D.V. 5-29 Milled out D.V. tool, circ. hole clean. R/D kelly, dress up csg. w/scraper. TIH to 2135' KB, pressure test csg. to 3000 psi, held 15 min. POOH w/D.P., D.C., scraper & mill. TIH w/mill, scraper & 3~" VAM tbg. Circ. every 1000' to dilute heavy visc. drlg. mud. Condition oo.. J U L 2 1 1982 A!~.ska Oil & Gas Cons. Commission 5-30 5-31 6-1 6-2 6-3 6-4 6-5 6-6 POOH w/remainder of tbg., scraper & mill. R/U Schlumber, run GR-CBL-CCL log f/8432' to 5390'. Change over, start running NGT log f/8432'. Finished running NGT, surveyed f/8431'-2300'. Changed over to run gyro survey f/8431' to surface. R/D Schlumberger. Changed over rams on BOP stack. Put blind rams on bottom, pipe rams on top. Tested blind rams to 3000 psi, 15 min. TIH w/6" mill, scraper & tbg. Rev. circ. 10 bbls. CMC pill, 100 bbls. fresh water, 10 bbls. caustic pill, 100 bbls. freshwater, 10 bbls. CMC pill, 100 bbls. fresh water.. Start circ. filtered NaBr 10.2# ppg. Finish circ. 300 bbls. NaBr water. Steam-cleaned mud tanks. TIH w/tbg., scraper, & mill. Assemble Vann guns & Halliburton equip. TIH w/4300' of tbg. & load same w/water. R/U Otis. Set pkr., pres. annulus, open APR valve. Run GR-CCL f/8120' - 7800'. R/D Otis, pull 6 its., space out & set pkr. top @ 7970'. R/U & pressure test manifold, DST tree & flowline. Drop detonating bar & perforate intervals: 8062'-8080', 8086'-8118' w/12 SPF, 5" hollow carrier. Instant strong blow at surface. Liquid to surface in 42 min. Initial flow test. Close APR valve, R/U Otis slick line. TIH w/Otis locking mandrel. Had problems setting mandrel, POOH. TIH & retrieve locking mandrel. TIH & set locking mandrel in "x" nipple. R/U Otis wireline, TIH w/HP gauge. Pressure annulus to open APR valve. Well test - see Test Data. Continue final flow test. Pressure 2285 psi at shut-in of flow test. Shut-in for pressure buildup survey. Final pressure before equalizing, 3471 psi. Close APR valve. Otis working with wireline trying to release H.P. gauge from locking mandrel. Load tbg. w/22 bbls. NaBr brine, pressure tbg. to 1500 psi, release H.P. gauge f/locking mandrel & POOH. R/D wireline. Pressure annulus to 2600 psi & sheer APR circ. valve. Rev. circ. 90 bbls. NaBr brine. Wait 20 min. checking for flow. POOH w/tbg., Halliburton equipment & Vann guns. Pulled 5 stands, filled hole w/NaBr brine & checked for flow. R/U Schlumberger. TIH w/gauge & junk basket, 8325' KB, POOH. TIH w/pkr, on wireline & set top of pkr. @ 8040' K.B., POOH & R/D Schlumberger. TIH w/Baker DR pkr. plug, latch in pkr. & sheer off. Pressure test to 2000 psi. POOH w/tbg. TIH w/Vann gun, Halliburton equipment & tbg. Load 1500' of tbg. w/water. Set pkr., pressure annulus to 1000 psi, open APR valve & R/U wireline. TIH w/GR-CCL, run log strip & POOH. S/O tbg. & set top of pkr. @ 7858' K.B. R/U DST - flowline & pressure test. Dropped bar & perforated w/12 spf f/7950'-8014'. Instant blow at surface. R/U slickline, TIH & latch locking mandrel in "x" nipple & POOH. R/D slickline & R/U to swab. Well flowing. R/U electric line. Shut well in for pressure buildup. Continue pressure buildup. R/U electric line unit & TIH w/H.P, gauge & latch into locking mandrel. Pressure annulus to 1000~ ~~' &~. . PR valve. Flow well for 10 min. & shut in for 100 min. ~l~~t~ll. Test No. 2 - Lower Laminated Zone, packer @ 7858'. Pkr. @ 8040'. Test d U L 2 1 9½ hrs. - see Test Data. 6-7 Continue pressure buildup survey. Release pres. on annulus, close APR valve & load tbg. w/22 bbls. of water. Release H.P. gauge f/locking mandrel & POOH. R/D electric line. Pres. annulus to 2800 psi, open Halliburton circ. valve. Rev. circ. oil in tbg. to production tanks w/80 bbls. NaBr brine. S/D & check for flow 20 min. R/D DST equipment on floor. Relase Halliburton pkr. & check for flow. POOH w/5000' of tbg. First 1000' filling annulus w/NaBr brine ever 5 stands & check for flow. Continue filling annulus w/brine & check for flow every 10 stands. 6-8 Finish POOH & R/D Halliburton tools & Geo Vann perf. guns. TIH w/Model "3" retrievable bridge plug and set top of plug @ 7939' K.B. Pres. test to 2000 psi for 10 min. Dump 1 sack of sand & POOH. P/U Geo Vann perf. gun & halliburton equipment. TIH, SET PKR. & open APR valve. R/U electric line, TIH w/GR-CCL & ran strip. POOH & R/D electric line. Re-space and set top of pkr. @ 7802' K.B. 6-9 Pressure annulus to 1300 psi & open APR valve. R/U DST tree & Howco manifold & pressure test. Dropped detonating bar & set off charges in perf. gun. Fluid to surface. Released pres. on annulus & closed APR valve. R/U Otis slick line & TIH to set locking mandrel. POOH, locking mandrel still attached to setting tool. TIH & latch locking mandrel in "x" nipple, POOH. R/D slick line. R/U electric line, TIH w/H.P, gauge & latch into locking mandrel. Pres. annulus to 1300 psi & open APR valve. Open well for 10 min. flow. Shut in for 100 min. Open well for final flow test. Fluid at surface. T.D. 7939', K.B. Top of pkr. set @ 7802' K.B. Perf'd Middle Kup f/7894'-7912'. See Test Data. 6-10 Continue to flow well. Shut in for pressure buildup. 6-11 Continued pressure buildup survey. Circ. kill fluid & POOH. Break out DST tools. Run CCL from Howco bridge plug @ 7935'-7800'. TIH to sanded-out bridge plug @ 7930'±. C/O sand, released BP & POOH. 6-12 Finished POOH w/Howco 7" bridge plug. Tally in hole w/3½" VAM to recover Baker "DR" blanking plug. Cleanout perf gun debris & latch on DR plug. Release & POOH. Making up seal assembly, Baker pkr. & TIH w/completion string. 6-13 Continue TIH w/3½" VAM Tbg. & gas lift mandrels & Camco safety valve. Spaced out & landed tbg. R/U Otis wireline, tried to TIH w/Otis "n" test plug. Unable to pass 6500' or pump plug downhole. 6-14 Attempt to TIH w/Otis "n" test plug, unable to pass 6487'. Made run to 8080' w/1.75" & 2.25" tools. Unland tbg., POOH w/completion string & found over-torqued collar @ 6487'. Redress seal assembly & inspected pkr. - o.k. TIH w/completion string & found 6 flared collars in 1st 1500'. Changed out & redrifting w/slickline after make up. 6-1-5 Continue TIH w/3½" tbg. & mandrels. Spaced out, s,tabbed into pkr. & II II ~ fl 11 landed tbg. TIH w/Otis n test plug on wirel~C~'~i xn profile @ 8064'. Set Otis "SAB" pkr. w/2500#, tested backside to 1000# - o.k. J U L. 6-16 Pulled dummy valve f/mandrel @ 2376' & changed over to diesel. Re-run dummy & R/D Otis. N/U tree. Break out rental equipment & clean location. RECEIVED Eastman / . , Whipstock A PETROI_ANE COMPANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY CONOCO. TNC. COMPANY Milne Point~ Well Number: C-3 WELL NAME Milne Point~ North Slope, Alaska LOCATION JOB NUMBER A0582G0438 SURVEY BY Pefferkorn TYPE OF SURVEY Gyro Multi Shot RECEIVED J U L 2 1 1982 A13ska 0il & Gas Cons. Commission Anchorage OFFICE Alaska DATE 30-Ma y-8 2 ~o2 R2 Eastman Whip st oc k june 1, 1982 CONOCO~ INC. 2525 C Street Anchorage, Alaska 99503 (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 Well Number: C-3 Location: Milne Point, North Slope, Alaska Type of Survey: Gyro Multi Shot Date: 30-May-82 Method of Computation: Radius of Curvature Surveyor: D Pefferkorn Job Number: A0582G0438 Attn: Terry Lucht Dear Mr. Lucht, We are enclosing the original and five copies of the Gyro Multi Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A;-'i copy telecopied to E/WNorth Slope office for delivery to CONOCO fie~d' representives. B'''5 copies delivered to d~illing for in-house distribution. C;''3 copies for E/W permanent well files. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, District Operations Manager ST/bb cc: files J U L 2 1 1982 A~3sk~ 0i~ & Gss Cons. commission AnChOmge enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ......... CONOCO'~ .... INC · MILNE F'OINT, WELL NO) C-3 JOB NO: AO582G0438 MILNE F'T, NORTH SLOF'E, ALASKA ......... GMS,' O-8400~MD, SURVEYORI"F'EFFERKORN ......... DATE RUN: 30'MAY'82 CAMERA NOI 1488, GYRO NOI 562, 90 DEG A/U NO: 1562 FORESIGHT: N19W RIG: NABORS 17E ............................................................................................................................................. R.ECORD~OF~SURVEY RADIUS OF CURVATURE METHOD : ' COHF'UTATION, . PAGE NO. ;ONOCO, INC. -. ........................................................................................................................... JOB - 'NO':'-"AO582G0438 ........................... TIHE .................... DAT~ ' ~ILNE POINT, WELL '~ILNE PT, NORTH SLOF'E, ALASKA 10:56:40 O1-JUN-82 TRUE tEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET ' D M D FEET ' FEET ....... FEET FEET ..... FEET .............. FEET D M DG/IOOFT O. 0 0 0 O, 0,00 0.00 -45,00 0.00 0,00 0.00 0 0 0.00 ~'100. 0 0 0 ....... 100. 100,00 ....... 0,00 55,00 .......... 0,00 0,00 ................. 0,00 0 0 0,00 200, 0 0 0 100, 200,00 0,00 155.00 0,00 0,00 0.00 0 0 0.00 ~ S 1 0 W 0.25 300. 0 15 S I W 100. 300.00 -0.18 255.00 0.22 S 0.00 W J400o 0 0 0 100,' 400,00 -0,38 355,00 ......... 0,43 S 0,01W ............0,43 S I 0 W 0,25 ~.~'0. 0 0 0 100. 500.00 -0.36 455.00 0.43 S 600.' 0 15 ' S'-49 W ............... 1'00';' ............... '~600' ;'00 ...................... "0-, 39 .............. 555';00 ........................... 0~58 700. 0 15 S 6 W 100. 700.00 -0.61 655.00 0.95 S 800. 0 15 S 33 E 100. 800.00 -1.01 755.00 1.37 S ..... 900. ' 0 0 0 ................ 100, ............. 900+00 .................. '1 ;23 ........... 855;00 ...................... O0: 1 300 0 0 0 O0 0.01W 0.43 S I 0 W 0';17~'W ............. 0.60 S 16 34 W 0.37 W 1.02 S 21 6 W 0.27 W 1.40 S 11 5 W 'O';15"W .................. 1,56 ...... S 5 31 W 0,00 0.25 0.18 0.17 0,25 1.76 S 8 48 W 0.25 1',96 .... S 1'I"24'"W 0.'25 1.96 S 11 24 W 0.00 1.96 S 11 24 W 0.00 1;'g& ....... S"'11 24'W ........ 0.00 100. · 1500. 0 0 0 ' 100. 1500.00 -1.41 1455.00 1.92 S 0.39 W 1.96 S 11 24 W 0.00 ' '1600. 0 0 0 ...................... 100; .....1'600;00 ....................... I"'.'4i ............. X'555'~"00 ....................... 1";92'~S ........... '0'~'~9' W ..................... 1'~96 ....S 1I' 24 'W ....... 0~00' 1'700. 0 15 N 37 E 100. 1700.00 -1.33 1655.00 1.74 S 0.26 W 1.76 S 8 21 W 0.25 1800. 0 30 N 17 W ~ 100. 1799.99 -0.87 1754.99 1.12 S 0.15 W ~ 1.13 S 7 2~ W 0.41 1~..3.' 0 30 N 51 ..... E~"'~"100;'""'~'1899';~9 ............... ='0,'33 ........... 1'854;99 .............................. 0;~4"~S ................... O'09'"E ............................ 0,35 .... S I5 ~41 E 0.56 2000. 0 30 N 32 E ~ ~0.~1999.99 -0.0~ 1954.99 0.32 N 0,67 E 0.74 N 64 48 E 0.17 0 0-' 0 ....... ..................... ......... ...................... ........... 0. 0 ....................... . 0. 0 : 2200. 0 15 N 4 E '~o 1~. ~199,9 0.15 2154.98 0.84 N 1.05 E 1 35 N 51 11 E 0.25 2300. 0 0 0 ~ 1~. ~29~.~8 0.20 2254.98 1.00 N 1.20 E I 5~ N 50 3 E 0.25 2400. .... 0 30 ...... N 28 'W ........ ~=~-1'~'~ ..... ~9~'~'98 ....................... 0~'4 ........... 2354 ~98 ...................... I~ 37~""N .......................... O'~9""E .................... :'1'~'71 .......... N 35 ~34 ~ E ........ O, 50 2500. 5 0 N 49 W ~'100. 2499.84 5.38 2454.84 ~5.12 N 1.98 W 5.49 N 21 & W 4.54 2~00'. ............ ~-15 ....... N~'-49- W ................. ~100" ........ 25~9~"05 .................... 17¥27 ....... 2554 ¥05 ....................... 13 ~'26~'~"N ..................... 11' 34' W ............ 17 ~ 44 N 40 32 W ........ 4.25' 2700.. 13 0 N 44 W 100. 2~77.15 35.~8 2~52.15 2~.53 N 25.32 W 3~.~8 N 43 40 W 3.87 ;ONOCO, INC · ~ I LNE 'PO I NT ~ILNE PT, NORTH SLOPE, ALASKA · . JOB-NO!'--AO582GO~4 ;38 COHF'UTATION.. ..,PAGE NO. 2 FIH£ ........................ DA-T£-= ......................................................... 10:56:40 01-JUN-82 ~' ............................................................... TRUE .............................................. iEASURED DRIFT DRIFT COURSE VERTICAL VERTICAl_ SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG I)EPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET' ~' D H D ' FEET ......... FEET .......... FEET .......... FEET .................. FEET ......................... FEET D- M DG/iOOFT 3000. 23 0 N 35 W 100. 2982.19 127.91 2937.19 101.39 N · 31000" 260 N 34 W .................... 100; ....3073~'18 ............ 169,34 3028,18 135.56'-N 3200. 28 30 N 34 W 100. 3162.07 215.11 3117.07 173.52 N 3300. 31 0 N 34 W 100. 3248,89 264.71 3203.89 214.65 N ~400. 34 0 N'34 W 100,' '3333.w~.~ 318~41 3288~22 ...... 259.19' N 78.93 W 128.49 N 37 54 W 102,42~W ........ 169,90 N 37 4 W 128.02 W 215.63 N 36 25 W 155.77 W 265,21 N 35 58 W 185.81W ........ 318.91 N 35 38 W 3.00 3.03' 2.50 2,50 3.00 3~,,~.0. 36 45 N 34 W 100. 3414.75 376.28 3369.75 307.18 N 218,18 W 376.78 N 35 23 W 2.75 3600.' 38 45 N'34 W ................ 100, 3493,81 ......... 437,47 .... 3448,81 .............. 357.93'N ,~,,,~.41'"'W .......... 437.98 N 35 1'1 W 2.00 3700. 39 0 N 34 W 100. 3571.66 500.21 3526.66 409.97 N 287.51 W 500.73 N 35 3 W 0.25 3800. 39 45 N 35 W 100. 3648.96 563.61 3603,96 462.25 N 323.44 W 564.17 N 34 59 W 0.98 3900. 38 45 N 35'W ................ 100. ........ 3726'°40 ................. 626;82 ..... 3681";~40 ................ 514.07 N 359'73 W ......... 62·7.44 .....N 34 59'W 1.00 · 4000. 39 0 N 34 W 100, , 3804.~ -~&8~ o4~;,~3~',":-~,-~:~:~- ~6~,80 4200 38 45 N 35 W 100. i':~F:'~:~13960.09 814.74%:391o.09 ~668.16' 4s~63 815. N 34 59 W 0 · 10 i~.:.-~;~038 ~, 87~.,0~;,~ ~.2~,.~,~71~::~9.~;N:: o0~43 W 877.97 N 34 59 W 0.25 '4400 3~ 45 N 35 N .... ~::' ~' ~':~ ~ '~ '~: -...:-~' ';~ ~-~' o~;'~ ~: , 4500. 39 30 N 35 W 100. 4193.92 1002.49 4148.92 822.11 N 575.42 W 1003.49 N 34 59 W 0.75 4600.' 38 45 N 33 W ............. 100, .............. 4271'~'50 .......... I065,'56 4226,50 ............... 874~'42~N .............. &10'i71 W ........ 1066~57 ....... N 34' 5& W ...... 1~47 4'700. 37 0 N 33 W 100. 4349.35 1128.32 4304.35 727~06 N &44.89 W 112~.30 N 34 4~ W 0~25 4800. 38 45 N 33 W 100. 4427.20 11~1,08 4382.20 ~7~.70 N 679.07 W 1172.04 N 34 44 W 0.25 4~ 3 · ....38 '-45 .... N'~ '34 "W ........... 100T~="'4505,~1 ~ ........ 1253'i'6~ ........ ~4"460V1~ .......... 1031 ~; 8~"~ N ................. 713 ~"62W ......... I254',"61 ............ N 34'"40'~ W 5000. 3~ 0 N 34 ~ 100. 4583.05 131&.40 4538.05 1083.~3 N 748.72 W 1317.37 N 34 38 W 0.25 ' 5100 ~" ' 38 45 '" N "33 ~' .............. 100'~ ......... 4660~ ~0--- 137~ ~' 15 ......... 46~ 5~"'~0 .......... 113&';26'-~ N ................ 783 ,' 36-"W ............ 1'380"~ 12 ....... N~' 34 '~'"~5" W 0 5200. 38 45 N 32 W~ ~10~ 4738,8~ 1441.74 4&~3,8~ 118~.05 N 81&,~9 W 1442.68 N 34 30 W 0.63 5300. 38 45 N 32 ~ ~ 10~ 481&.87 1504~34 4771.87 1242.13 N 850.16 W 1505.21 N ~4 23 W 0~00 5400.~'' 38 45" N'30'~ ....... ~"10~ ......... 48~4,'8& ........... 1'56&'~71 ........... 484~',86 ........... 12~5.78-N ................ 882',"39"-W .....1567,'70 ........ N~'34'lS'"W ~'1',25 5500. 38 30 N 30 ~. ~10~ 4~7=.~ 16~.~7 4~7.~ 134~.84 N ~13.60 W l&~.~ N 34 5 W 0~25 5600. .... 38 30 ...... N'-30'~'W~o ....... ~'~10~~ ....... ~0~1 ~ ........I6~I;~'4& 500&~-~ ......... 1-403;7~~+~ N ................ 944 ."73~W ............. l&~' Oo ...... N'- 33' '56-' W .......... 0. O0 5700. 38 0 N 30 W~ 100. 512~,78 1753~32 5084.78 1457.~7 N 975.68 W 1753.82 N 33 48 W 5800'; 38 0 N 2~ W~' 100. 5208,58 1814.80 5163.58 1510.~5 N 1006.00 W 1815~22 N 33 ~ W 5900, ........ 37 '45 N 2~ o ............................. ~ .... =o ......................... =~ ~'~'~ ='~ W= ~00. ~87.~ 1876.08 u.4~.~ 15'&4*"65-"N ........... ~035';'7&-W ....... 1876;'41 N J3 30"'W ;ONOCO, INC. ' , ~ILNE POINT, WELL NO: '~-3 .................................................. JOB NO": ....A'O582G0438 'ilLNE PT, NORTH SLOPE, ALASKA COHF'UTATION .... PAGE NO. "TIHE DATE" ' 10:56~40 01-JUN-82 ......... TRUE IEASURED DRIFT DRIFT COURSE VERTICAL VERTICAl. SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG ' DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY _ .. ~ FEET D M D FEET FEET FEET FEET ............. FEET FEET D M DG/IOOFT 6000. 37 15 N 28 W 6100. 37 0 N 28 W 6200. 37 0 N 28 W 6300. 36 30 N 27 W ~400. 36 30 N 26 W 100. 5366.85 1936.82 5321.85 1618.14 N 1064.81W 1937.06 N 33 21W 0.79 100. 5446.58 .......1996.99 5401.58 1671,44 N 1093.14 W 1997.16 N 33 11 W 0.25 100. 5526.45 2056.99 5481.45 1724.57 N 1121.40 W 2057.11 N 33 2 W 0.00 100. 5606.57 2116.60 5561.57 1777.64 N 1149.02 W 2116.67 N 32 53 W 0.78 100. 5686.96 ...... 2175.77 5641.96 "1830,88 N 1175,57'W .... 2175.79 N 32 42 W ' 0.59 ~..~0, 36 45 N 25 W 100. 5767.21 2234.99 5722.21 1884.7'2 N 1201.25 W 2234.99 N 32 31 W 0.65 6600. 36 30 N 24 W 100. 5847.47 .......2294"07 ..... 5802;47 ......... 1939',01 N 1225.99 W 2294.08 N 32 18 W 0.65 6700, 37 0 N 23 W 100. 5927.60 2353.18 5882.60 1993.88 N 1249.85 W 2353.~ N 32 5 W 0.78 6800. 37 0 N 23 W 100. 6007.46 2412.55 5962.46 2049.27 N 1273.36 W 2412.67 N 31 51W 0.00 6900. 37 0 N 22 W 100. 6087.32 ...... 247'1"83 6042"32 ..... 2104;87 N 1296';39"W ........ 2472.07 .... N 31 38 W 0.'60 7000. 36 30 N 20 W 100~:~:;.~167.4~,~5~0~.~6~--~~ ~iz160.73 N 1317.83 W 2530.90 N 31 23 W 1.30 7100. 36 0 N 19 W 100'-.~L~6248.0~1:2588~..~.~¢:.~6203~0~ ~221:~;4:~~33~:.57 W 2588';79 ......... N" 31 7 7200. 35 0 N 19 W 100~'~: 6329.50 264~.58~"6284.50 2271.37~N 1356.!i~48 W 2645.59 N 30 51W 1.00 7300. 33 30 N 16 W 100~i6412,..1.6,~2698;~',~3~7;~l~~'25~:0~' 1-Z~40 W 2700.38 N 30 34 W 2.26 7400 32 0 N 15 W 100. ~:;~76~-~'~7~;~.~'i~ ~451~:2:6~77~1:~~- 1~i~.85 W 2752;'65 ....... N 30 17W 7500. 32 0 N 16 W 100. 6581.07 2801.39 6536.07 2428.23 N 1402.02 W 2803.92 N 30 0 W 0.53 .. 7600. 32 0 N 16 W ............... 100', ........ 6665,87 ............. 2852,22 ..... 6620.87 ...... 2479;17-~N .... 1416'62"W ...... 2855,37 N 29 45 ~ ' 0o00 7'700. 31 0 N 3 W 100. 6751.13 2900.24 6706.13 2530.59 N 1425.23 W 2904.34 N 29 23 W 6.85 7800. 30 0 N 5 E 100. 6837.30 2942.56 6792.30 2581.30 N 1424.34 W 2948.20 N 28 53 W 4.18 7 0.'" ~0 '0-' N'il E ............ 100~ ....~923;'90 ....... 2980;"~0 ......... ~878'~90 ....... 2630;~79'"'"N ........ 1417;3~"'W ..... 2'988~32 ....... N'28 19"W ......... 3,00 8000. 29 0 N 11 E 100. 7010.93 3016.36 6965.93 2679.13 N 1407.99 W 3026.58 N 27 43 W 1.00 '8100. ..... 28 15 N 12-E ................. 100~ ........... 7098"71 ......... 3050';86 ......... 7053i'7! ........... 2726~07'"N .......I398i"44"-'-W ......... 3063.84 .......N27 '~ 9'W ........ 0i89 8200. 28 0 N 12 E 100. 7186.90 3084.52 7141.90 2772.18 N 1388.64 W 3100.53 N 26 36 W 0.25 --8300. 27 15 N 13 E 100. 7275.50 3117.34 7230.50 2817.45 N 1378.60 W 3136.65 N 26 4 W 0.88 8400." 26 30 N 16"E 100, ............ 7364',70 ........... 3148.~0 .......... 7319.'70 ........ 2861-,21 ....N ....... 1367.29""W ......r-3171+12 'N 25 33 W'- 1.55 DISTANCE.* 3171.12 FEET CONOCO ~' -'I NC-~ MILNE F'OINT~ WELL NOI C-3 JOB NOI AO582G0438 MILNE F'T,~ NORTH SLOPE, ALASKA GMS~ 0'8400 'MD'~ ..... SURVE¥OR~ ..... F'EFFERKORN ..... ]]ATE~"-'RUN~ .... 30-:MAY~'82 ..... ~ ..................................................................... CAMERA NO~ 1488, GYRO NOI 562, 90 DEG A/U NOI 1562 FORESIGHT'~"NI~W RIG: NABORS 17E ~ONOCO, INC. .- ' ; COMPUTATION iILNE"POINT~ 'WE['["'NO~'~C~'3 JOB'NO** 'AO582G0438 TIME · ' iILNE PT, NORTH SLOPE, ALASKA ........................... TRUE MEASURED VERTICAL MD-TVD VERT DEF'TH DEPTH DIFF CORR FEET FEET FEET FEET 11117126 SUBSEA .............................. VERTICAL R E C T A N G U L A R DEPTH C O 0 R D I N A T E S FEET FEET [mATE O1-JUN-82 .,F'AGE NO. C L 0 S U R E DISTANCE DIRECTION FEET D M 45.00 45.00 0.0 .. 145.00 145.00 0.0 245.00 245.00 0.0 345.00 345.00 0.0 445.00 445.00 ................... 0~0 .... 0.0 0.00 0.00 0.00 0.0 ' ' 100.'00 0.00 0.00 0.0 200.00 0.10 S 0.00 W 0.0 300.00 0.31 S 0.01 W 0.0 ........ 400.00 ............. 0.43"S ' 0.01 W " 545.00 645.00 745.00 845.00 945.00 545,00 0,0 0,0 500,00 0,50 $. 0,08 W 645*00 ................................... 0,0 745.00 0.0 0.0 700.00 1.14 8 0.32 W 845.00 0.0 0.0 800.00 1.45 S 0.22 W 945.00 .............................. 0.0 ............................. 0.0 ............ 900.00 1.64 S 0.20 W ' 1045.00 1045.00 ............... 1145.00 1145.00 1245.00 1245.00 1345,00 1345.00 ........... 1445.00 .......... 1445.00 , 1545.00 1545.00 0.0 0.0 1500.00 1.92 S 0.39 1645.00 1645.00 ................................... 0,'0 ......................................... 0,0 .................. 1600,'00 1',84 S 1745.01 lY45.00 0.0 0~0 1700.00 1.4~ S 0.21 1~45.01 ~B45.00 0.0 0~0 1~00.00 0.77 5 0,04 1945 · O1 ................... 1945 ;'00 0-;'0 0'~ 0 ......................... : 900'* O0 ...................................... 0; 04" ~ ........ 0 * 35" ,. 0.00 0 0 0.00 0 0 0.10 S 1 0 0.31 S 1 0 0.43 S 1 0 0.51 S 9 16 0.79 S 19 12 1.19 S 15 48 1.47 S 8 25 1.65 S 7 5 W 1.85 W ' 1.96 W 1.96 W 1.96 W " '1.96 W 1.96 W ......... 1,87 W 1.48 W 0.77 E ............. : 0.36 S 10 2W S 11 24 W $11 24W S 11 24 W $ 11 24 W S 11 24 W S 10 6 W S 8 2 W S 2 50W S 83 7 E ~45.02~ 2245.00 0.0 0.0 2200.00 0.92 N 1 2345.02 o= 2-~45~ 0.0 0.0 2300.00 1.18 N 1 ................ 2445.08 ....... ~ ..... '-~45~ ................................. 0";1 ............................... 0;"1 ........................ 2400;'00 .................................. 3~07"N .........0 2545.52 ~ ~ °?+545'~ 0.5 ................ .......................... 2045.01 ~ 2045.00 0.0 0.0 2000.00 0.48 N 0.77 2145.02 .......~ ........ 2145;-0'0 ...................... 0.'0 ..................... 0';"0 ........................ 2100TO0 ..................................... 0';76'N ...... 0.97 .12 11 E 0 91 E ................ 1:23 E 1,44 E 1.61 W ................. : ......... 3'09 0.4 2500.00 8.82 N 6.24 '1';'3 ............. 2600;'00 ................. 19'~47"N ............ 17,89' 2+6 2700,00 36,11 N 32.95 4.2 2800.00 59.56 N 49.95 W 10 W .......................... 26 W 48 W 77 N 58 N 51 N 50 N 43 N 6 6 59 38 13 26 E .81 N 35 .44'-N 42 · 89 N 42 .73 N 39 15 W 34 W " 22 W 59 W ~6;"4 ................... 2900';00 89'~39""N ................. 70,53"W ......................... 113.86 N 38 16 'W ....... ....... ..................................... JONOCO, INC. _,- '. ~ILNE F'OINT" WELL'NO~'~O'3 JOB NOI .....AO582G0438 ~LNE F'T, NORTH SLOF'E, ALASKA COMF'UTATION , TIME" DATE 11~17~26 O1-JUN-82 .,PAGE · TRUE SUBSEA MEASURET_m VERTICAL MT.I-TVT_m VERT VERTICAL R E C T A N G U L A R C L 0 S U R E DEF'TH r_IEF'TH r~IF'F CORR DEF'TH C 0 0 R D I N A T E S DISTANCE r{IRECTION FEET FEET .......................... FEET ................ FEET ................... FEET FEET ............... FEET D M 3069°03 3045.00 24.0 9,0 3000,00 124,98 N 95,15 W 157,07 N 37 17 W 3180,79 .... 3145,00 ....................... 35,8 ................ 1I',8 ..... 3100~'00 166,23 N 123,10 W 206.85 N 36 31W , , o ~ 99 N 35 59 W 3295,52 3245,00 50 5 14,7 3200 O0 212,81N 154,52 W 3414.45 3345,00 69,5. 18,9 3300,00 266.13 N 190,49 W 327~27 N 35 36 W ~'! .... 3538'27 .... 3445'00 93,3 23.8 ·3400,00 ...... 326.60 N 231,28 W 400.20 N 35 18 W 3665,75 3545,00 -120,8 27,5 3500°00 392,15 N 275,49 W 479,24 N 35 5 W ........ 3794.87 :'3645+"00 ...................... 149;9 .............. 29~1 ............ 3600~'00 459,57 N 321.60 W 560,92 N 34 59 W 3923,89 3745,00 178,9 29,0 3700,00 526,43 N 368,22 W 642,43 N 34 58 W 4052,34 3845,00 207.3 28,4 3800,00 592,70 N 414,12 W 723,05 N 34 57 W 4180~64 .................... 3945';00 235';'~ ......................... 28;3-": ............... 3900;00 ......................... 658;30 N 460,59 W ..... 803,43 N 34 59 W 4308,68 4045,00 .............. 4436,94 ..... i ...... 4145;00 4565,84 4245,00 4694,41 4345,00 4822,82 4445;00 37 883,38 N 34 59 W 963,69 N 34 59 W 1045,02 N 34 57 W 1125.80 N 34 50 W 1206,32 N 34 43 W 4951.13 4545,00' 406.1 28.3 4500.00 1058.50 N 731.56 W 1286,70 N 34 39 W 5079,58 4645;'00 ..................... 434;'6 ........................ 28;4 ...................... 4600;00 ....................... I125,58'N 776,28 W 1367.31 N 34 36 W 5207,84 4745,.00 462,8 28,3 4700,00 1193;21 N 819,59 W 1447,58 N 34 29 W 5336,06 4845,00 491,1 28,2 4800.00 1261,48 N 861,78 W ~ 1527.75 N 34 20 W ........... 5464'.18 .............. 4945;'00 519';2 28;'1 .............. 4900;00 ........... 1330;~8~'N .... 902~42'W ................... 1607.65 'N 34 9 W 5592,02 5045,00 547,0 27,8 5000,00 1399,45 N 942,24 W 1687,09 N 33 57 W 5719'31 ............... 51'45~00 .................... 574;3 ....................... 27i'3 ........................ 5100i00 ................... I467;'72"N .... 981,54 W .............. 1765,68 N 33 46 W 5846,14.~. 5245.00 601,1 26,8 5200,00 1535,73 N 1019,73 W 1843,45 N 33 35 W 5972,4~i~~ 5345,00 627,5 26,3 5300,00 1603,41 N 1056,81 W 1920,36 N 33 23 W · 6098 O~ .................. 5445~00 ....................... 653'~0 ................................ 2a'~'6 ...................... ~400~'00 ..................... 1670,38 N 1092,58 W 1995,97 N 33 11W 6223,::L6~ ~551q:B,O0 678,2 25,1 5500,00 1736,86 N 1127,79 W 2070,90 N 33 0 W 6347~t~K~'~-'~-56~'00 ....................... 7'02';8 ......................... 24'~'6 ...................... 5600;~00 1803~09'~'N'~'1161~71 W ....................... 2144,93 N 32 48 W '6472,3~Z~ ~57~,00 727,3 24,5 5700,00 1869,82 N 1194,14 W 2218,60 N 32 34 W 6596.~ ~;58~F~;.00~ 751,~ 24,6 5800,00 1~37,34 N 122~,23 W 22~2,2~ N 32 1~ W :~-':&721~'79~ ............. ~59~'~00 ........................ 776';8 ................................ 24;~ ............................. 5900~'00 ............................... 2005'~SN"1254.'97'W ............ 2366,17 N 32 2 W ~'ONOCO, INC. '- ~ILNE POINT, WELL NO; C-3 JILNE F'T, NORTH SLOPE, ALASKA . , COHF'UTATION ,..PAGE NO. · JO~ NOt AOSS2G0438 TIHE DATE 11:17126 01-JUN-82 Y~UE SUB'SEA HEASURED VERTICAl.. H[I-TV[I VERT VERTICAl. R E C T A N G U L A R C L 0 S U R E DEF'TH DEPTH [mIFF CORR DEPTH C 0 0 R[m I N A T E S DISTANCE DIRECTION FEET FEET ........... FEET FEET FEET .............. FEET ...... FEET [m H 6847.00 6045.00 802.0 25,2 6000.00 6971,98 " 6145.00 ............. 827,0 '" 25,0 6100,00 7096.16 6245.00 851.2 24.2 6200.00 7218.75 6345.00 873.7 ~.~ 6 6300.00 7339.05 6445.00 ..... 894.0 ...... 20.3 6400.00 7457.47 7575,39 7692.81 7808.90 6545.00 912.5 18.4 6500°00 2075,41N 1284,19 W 2440,59 N 31 45 W 2145.08 N 1311,82 W '" 2514,41 'N 31 27 W 2214,33 N 1336.81 W 2586.57 N 31 7 W 2281.44 N 1359.65 W 2655,86 N 30 48 W - 2345.40 N 1379.04 W ..... 2720.78 N 30 27 W 2406.52 N 1395.99 W 2782.11 N 30 7 W &~4'S.O0 ......................... 930",'4 ............................ 17;9 .............. 6600,"00 .............. 2466.64 N-1413.03-W ......... 2842.70 N 29 48 W 6745.00 947,8 17.4 6700.00 2526.90 N 1424.61W 2900.81 N 2? 25 W 6845.00 963.9 16.1 6800.00 2585.70 N 1423,72 W 2951,75 N 28 50 W 7924.24 .................... ~9'45o'00 ...................... 9'7~v;2 ........................... 15;3 ...................... 6900;00 ............2642'51 N 1415o11'W ........... 2997.56 N 28 10 W 8038.81 7045,00 8152,49 7145.00 8265.57 7245.00 8377.91 7345.00 404 o28 W 3-9'3.30 W 3041,00 N.27.30 W 3083.06 N 26 52 W 3124.18 N 26 15 W 3163.48 N 25 39 W · ----~---Z --,--~--~----..,_:__:~ 'It ;i ......... ....... ]:~ ........... :.~-:.:_~ ..... ._~ ___:.::_..~ .... :~_L .: ~__: ....... .~ ...... ~ L~_ ~. _~J ~ .... 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'..- .'-'-"-'"'. ...... ! ......... i ........... !- , i ..... . : ~ '~ : : ........ i ...................... ; ............~ ....... I ................. 4 .... ......... ~ ...........3500 ....... , .................................... . ..................................... , ........................................ , ....... , ......... ..... !.m ....... i ...................................... ._4 ....... _, .................... : ..... , -': ' ~ ' - '~-7 ' -~i~' ............. ...... :m"': ...... 4: - .... i ~L'~ ....i i " '-: ' ' ~ .._ .;. ~ ~. . ooo.. ....... _...'.. ,-, ..... 4000 .............. ~ .......... t .......... : .......................... ,.., ,.?.;..; ;;_.. i '.,' _ ...... !_ ~ ...... '--,'-~'~ ..; ..... -~ .... --~-~....,~-'~ - ......... ._ ., .-~ ...... ~?-.--:.%- 5000..~ , ......... __~ .... : .... ~ ................ ~ . _ ~ ...... ! ......................... . ..... ~ -4 .... ~ . .~'., .__ ..... I '%~ ....... · ......... ....... '" ~ ~' ............ I ~ ............ ~ ..... ........ i '" .i .... i ..... !- -. \..: ....... :--! ...... i ....... ~ ........ ~ ........ i -.: .... ............... ' · , i .............. , · : 5500 : , . , , .-.,-- · ---- ........ ~-~---., ........... , ........................................... .... _z,.~,_- ............. !.-_~~,:-c! ..... :. --- -~ ...... --I ..... ~- - ........ t ...... :--i ..... I~l .... ! ..... !-' '% ........... 1 ...... ~-.~ ........... t ..........~ ................................ · ' I '-':'' - ' · - t ...... I ...... ~ .... I ' ~ ...... I-'' ; ...... ! ....... i '" ~ - ' ~ -' : '' .... '...t .... ~ ..... / ~._.-~..-.~'~,,. 7000 ........ !--~ - i · -i -- :- . i ..... ....... t ........ i ...... , ' ' ' ! - ' J ............. t'--+ i ' ' ! ....... t ' : ..... ! .... ....... q ............. ~ ............ -' .............. ~ .............. ! .......... ! ............... i ............. '! ....... \' ...... ,soo ..... ~, .................... ! ....... : ........ : ....... :-7':'"i ............................... !-: ...... . ...... ..' ..... · -~ - ''! ' · ~, ._~ .. ;--~ · . t · · ~ '' ~ : '~ ' ' ' '; ' ' : ~ ' ' ' ~ ' ' ' I ..... ...... i..Tooo_: ...... ..}_i_:,C.L.:_\. .... ooo .......... : .............. : ......... i ............... ;- ............... Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Well 'Name and Number Report's and Materials to be received by: Date Required Date ReceiVed Remarks Ccmpletion Report . Yes Well History Yes' ~ ._~/.__OQ, ~ -~:::;~,' · , _Core Chips . y~3 ' Core Description !~. .'.~e~gistered Survey Plat ,..~.__%~.~ .'-',. -_ ~..~' "y~ d~ 0.~'_.(~. . L-,~.'~ Inclination Survey ~'~ , Directional SurVey t/~,~...?"'~l Drill .Stem Test Reports .y,~___~. " . ' , , Production Test Reports '7 ~'' ~ '~"--~' /''- &~''' ' ~" Logs Run, Yes Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 June 10, 1982 Mr. Lonnie Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: SUBJECT: MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Attached are the subject reports for the month of May. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Attachments cc: Working Interest Owners, w/Attachments RECEIVED JUN 1 ? 1982 Alaska 0ii & Gas Cons. Commission Anchorage .~: ~' .~· STATE OF ALASKA ,,~ ALASKA {, . AND GAS CONSERVATION C< dlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~] Workover operation I-1 2. Name of operator 7. Permit No. Conoco Inc. 82-50 3. Address 8. APl Number 2525 C St., Suite 100, Anchorage, Alaska 99503 5o-029-20786 9. Unit or Lease Name Milne Point Unit 4. Location of Well atsurface 1395' FSL, 2326' FEL, Sec. 10, RIOE, T13N, Umiat Meridian 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 45' KB ADL 47434 10. Well No. Milne Point C No. 3 11. Field and Pool Kuparuk River Field Kuparuk River Pool For the Month of May ,19_~.__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks T.D. - 8848' - Drilling is finished - a workover rig has been moved on the well for completion and testing operations. 13. Cas, j, ng o[ liner,,run and quantities of cement, results of pressure tests casl ng: ~l ze Wt. Grade From 13 3/8" 72# L-80 O' 7" 29# L-80 O' 14. Coring resume and brief description To Cement 2316' 4500 sks. Arctic Set II 8759' 20 bbls. CW-IO0, 30 bbls spacer 3000, 500 sks. Class G-300 bbls. Arctic Pack, 300 sks. Arctic Set I. Core information not available - will follow on next report. 15. Logs run and depth where run Logs From To BHCS-DIL-GR 8848' 2316' GR-CNL-FDC 8192' 2316' GR-CBL-CCL 8432' 5390' RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data None JUN 1 7 1982 Alaska 0ii & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ..... TITLE Drlg. Superintendent DATE 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 AFE 1002 AO & GCC (2) Submit in dupl cate Rev. 7-1-80 ' Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 May 18, 1982 Mr. L. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Attached for your approval is a sundry notice for Milne Point C No. 3. If you have any questions please contact either Don Girdler or Terry Lucht at 279-0611. Yours very truly, T. S. Lucht Drilling Supervisor tt RECEIVED MAY 1 1982 kl3ska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK '~' ,~ AND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL I~C COMPLETED WELL [] OTHER [] 2. Name of Operator Conoco Inc. 3. Address 2525 "C" Street, Suite 100, Anchora§e, Alaska'99503 4. Location of Well RECEIVED 1395' FSL, 2330' FEL, Sec. 10, T13N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 49' KB 12. 7. Permit No. 82-50 8. APl Number s0- 029-20786 9. Unit or Lease Name Milne point Unit 10. Well Number MAY'I 9 ]982 Milne Point C-3 / 11. Field and Pool Alaska 0il & Gas Cons. C0mmislq0~:uparuk River Field Ie'LeaseDesig'nati°nandserial/~'h0rag8 ' ' I Kuparuk River Pool. ADL 47434 ' . Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (S~Jbmit in Triplicate) (Submit in Duplicate) Perforate ~:] Alter Casing D ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] - Stimulation [:::] ' Abandonment D Repair Well [] Change Plans ['-] Repairs Made [] Other D Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The well was drilled to a T.D. of 8848' MD. After running 7" production casing, the following procedure will be used to test and complete the well' a. After setting casing, run CBL-VDL-CCL-GR logs. RIH and clean up the well'. Displace well with 10.2 ppg. NaBr (Sodium Bromide), POOH. b. RIH with a Vann gun system, RTTS packer and APR test valve. Perforate the lower Kuparuk sand at 8087'-8116' and 8063'-8078' underbalanced then flow test the formation. c. Kill the well then POOH with the test string. RIH with electric line and set a packer 30'+ above the-~perforations. Set a packer plug in the packer. d. RIH with a similar test system and perforate then test the middle Kupa'ruk interval 78'94'-7909' using the same method as for the lower Kuparuk. e. K~ll the well, then POOH wi th the test system. f. RIH with 3½", 9.3#/ft, N-80 DSS-HT production tubing with a production packer with a 130'+_ tail pipe assembly including ajoint of ~2~-~" perforated pipe. Subsurface safety valve to be installed at 2100'. g. Land the ~'" tubing and install a 3½". 5000 psi tree. Close the subsurface safety valve and install a back-pressure valve. Rig down. 14. I hereby certify that the foregoin's true and correct to the best of my knowledge. Signed0~~/~/~ Title Drilling Supervisor The space below for Commission use DateMay 18, 1982 Conditions of Approval, if any: Approved by Form 10-403 Approved Copy Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate MEMORA, IDUM St )e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: ~~ert0n DATE: May 13, 1982 / /'~'~ FILE NO: T'hru: Lonnie C. Smith Commi ssione r FROM:Edgar W. Sipple, Jr~--~- Petroleum Inspector TELEPHONE NO: SUBJECT: Witness BOPE Test on Conoco's Milne Point C-3, Sec. 10, T13N, R10E, DM Permit No. 82-50 Nabor's Rig 17 82 - Upon arrival at Conoco'S Milne Point g 17 was in the process of nippling up. The BOPE test commenced at 8:00 p.m. and was concluded ~ }~y 3_, 19~,~ at 10=45 aomo There ~as one failure. The H.C.R. ~lve would not test. With the removal of the old H.C.R. valve and the installation of a new B.C.R. valve it retested to 5000 psi satisfactorily. I filled out the A.O.G.C.C. report which is attached. In summary I witnessed the BOPE test on Conoco's Milne Point C-3, Nabors Rig 17. There was one failure, the H.C.R. valve failed, with the replacement of the H.C.R. valve it tested to 5.000 psi satisfactorily. I left Pru~hoe Bay at 3:25 p.m. and arrived in Anchorage at 5=05 p.m. this date Tuesday, May 4, 1982. 02-O01.'~(Rev.10/79) ~ ..-..__ Inspector · -o .,, Operator ~ t).~JO C., '~ . ~ Location: .Sec / ~ T Drilling Contractor. _~J~" _. Date Location, General. Well Sign General HousekeePig.g' . Reserve pit O Rig /ii':."?i.'. Kilt L~'he Valves .... . Check Valve BOPE Stack Annular preventer' '~" Ch.oke°Line Valves 0 ACCUMULATOR SYSTEM Full Charge Pressure ~0~0 psig Pressure After Closure.I~-O psig ., 200. psig Above Precharge Attained: / mind,sec Full Charge-?ressure Attaine. d: ~ min ~ s=ec N2~76o ~7~o~ 07~ ~'7~.,0 psig Controls: Master ~1~ <',,~,, .~ t~(.,~ ': Remot~ &' ~ ' Blinds swi _- ..... ~ .............. tch cove~ Test PrePare Kelly and Floo~.fety 'Valves 3 ~O~ '. ,:Upper Kelly ~ ~~ Pressure ~"O~ O Lower Kelly ~/'~st Pres sure ,~O O ~O00 Ball Type T Test Pressure z siae q' f ~000 Choke Manifol'd ~ Test Pressure ~OO0 , SO0~ NO. Valves ~ '/~ No . ~/~mo~ ' · No. flanges ~ i & Adjustable Chokes 't-A~I l]ydrauicalky operate, d choke /~. ~~ '~ Test Results: ~ailure~ / · ' 'Tes~ %:il~Z--7-~ .... ~h ~F~ Repair or Replacement .of failed equipment to be made within days an ' Ins~ctor/Com~ssion office notified. . . . . J.- . j J ff"l.,vrt j e %"; o~ ?,,,.,. Distribution orig' - LO&GCC cc - Operator cc - Supervisor Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 May 10, 1982 Mr. Lonnie Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: SUBJECT: MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Attached are the subject reports for the month of April. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Attachments cc: Working Interest. Owners, w/Attachments RECEIVED A!r',.ska Oil & t-k~r~ Cons. Co,;m~ission A~chorage /( STATE OF ALASKA , , ALASK LAND GAS CONSERVATION C( MISSION MONTHLY REPORT' F DRILLING AND WORKOVER OPERATIONS · Drilling well ~] /~I~O'M ~/11 h ~ U i~ i jj~I 2. Name of operator Conoco Inc. Workover operation [] 7. Permit No. 82-50 3. Address 8. APl Number 2525 C. Street, Suite 100 Anchorage, AK 9950 350-029-20786 4. Location of Well atsurface 1395' FSL, 2326' FEL, Sec. 10, R10E, T13N, Umiat Meridian 5. Elevation in feet (indicate KB, DF, etc.) 45' KB 9. Unit or Lease Name Milne Point Unit 10. Well No. Milne Point C No. 3 11. Field and Pool 6. Lease Designation and Serial No. ADL 47434 Kup a r uk KUparuk River Field River Pool For the Month of April ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud - 4/29 Depth on 4/30 - 877' Set conductor pipe and begin drilling. 13. Casing or liner run and quantities of cement, results of pressure tests Casing: Size Wt. Grade From To Cement 20" 91.5# B 0' 80' To surface 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 ~/ ~ TITLE Dr lg'. ' Superintendent RECEIVED MAY1 2 i982 At3ska 0il & Gas Cons, C0mrnjSsior, Anchorage DATE May 10, 1982 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 10404 AFE 100 2 AO & GCC ( 2 ) File Submit in duplicate Rev. 7-1-80 April 5, 1982 Mr. Gary A. Merriman Supervi sing Engineer Conoco Inc. 2525 C. Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit,. l~lilne Point C-3 Conoco Inc. Permit No. 82-50 Sur. Loc. 1395'FSL, 2330'FEL, See 10, T13N, RIOE, L~. Btmhole Loc. 4342'FSL, 4203'FEL, Sec 10, T13N, R10E, UM. Dear Mr. Merriman: Enclosed is the approved application for permit to drill the above refel~enced well. Well samples 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 infor~nation shall be submitted on all logs for copying except 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 15.05,870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to cong/mncing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and. Game. Pollution of any walters of the State is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?9) 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 Environmental Consel'vation. Gary A. Merri~an -2- ~dilne Point Unit, ~lilne Point April 5, 1982 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Ve~*y truly yours, C. V. Chat te~to.n Oha i rman o f ~Y OF, D~ OD. T~i~ Alaska Oil and Gas ~nse~atton ~ission Ene I o sure Department of l~ish & Game. Habitat SeCtion w/o enel. Department of ~nvi~o~ntal Conservation w/o encl. Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 March 31, 1982 Mr. Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage. Alaska 99501 Dear Mr. Smith. Enclosed for your approval are three copies of the Permit to Drill for Milne Point C No. 3, and a check for $100.00 is attached to this 1 etter. If you have any questions, please contact me at 279-0611. Very truly yours, ~.~rim~an~ Supervising Engineer tt Enclosures RECEIVED STATE OF ALASKA ALASKA .~.AND GAS CONSERVATION C .MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator Conoco ]Inc. lb. Type of well EXPLORATORY [] DEVELOPMENT OIL]~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE.'; . 3. Address 2525 C Street, Suite 100, Anchorage, AK 99503 9. Unit or lease name M51ne Point Unit 4. Location of well at surface 1395' FSL, 2330' FEL, Sec. 10, T13N, R10E, UM At top of proposed producing interval 3960' FSL, 3960' FEL, Sec. 10, T13N, R10E, UM At total depth 4342' FSL, 4203' FEL, Sec. 10, T13N, R10E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 45' KB Elevation I ADL 47434 12. Bond information (see 20 AAC 25.025) Type B 1 anket Surety and/or number .8086-15-54 13. Distance and direction from nearest town 14. Distance to nearest property or lease line Deadhorse; Southeast 33 m,es 1395 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8935', MD; 7745' TVD feet 2560 Acres 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2400 feet. MAXIMUM HOLE ANGLE39 20. Anticipated pressures · 4° (see 20 AAC 25.035 (c) (2) 10. Well number Milne Point C-3 11. Field and pool Kuparuk River Field Kuparuk River Pool Amount $200,000 ~ _ ~18. Approximate spud date April 9i, 1982 ~1 95 psig@ (~' Surface 3850 ps~g~ 7695 ft. TO (TVD) 21 Proposed Casing, .iner and Cementing Program SIZE CASING AND LINER Hole Casing Weight Grade CouplingI LengthI 26" 20" 94'# )lainenJ line~ioe-ROl 17~" 13 3/8' 72# L-80 Btrs'] ~300' 8~" 7"' 29# . -J._~Bt~.s] F~935' 2'i. Describe proposed pro§ram: SETTING DEPTH MD TOP TVD / i 0 ~ 0 O' ' 0' i I MD BOTTOM TVD 00* I R0*. 2300 ~2300 I I t QUANTITY OFCEMENT (include stage data) Cement to s,]r.Cace __ 4.~1 CF (appro.~_imate! 2400' of cement fill See attached Supplemental Data Sheet. ~.~,~ I !98~ Proposed surface and bottom hole location plat enclosed. ," See attached Wellhead and BOP sketches· Ala,ka 011 & ~s ~ .... ,.:, ~ .... m~10, (An as-built surface location survey plat will be submitted after sea,lng conductor casing.) *set 80' from ground level; all other figures are basec on 45' KB elevation 23. I hereby certify that the foregoing is true and correct to the best of my knowledge . S.GNED ~'~-'",' ~/_-~~ T,TLE Supervising Engineer DATE 3--30-_82 The spac~elov~ f'o,r.~-om m i ss io r~use CONDITIONS OF APPROVAL Samples required []]YES J~xlO Permit number APPROVED BY Mud log required i-]YES [~NO Approval date Directional Survey recuired I APl number [~YES []]NO I 5o.- oZ.? - 'z: o7~j SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Ap~il 5:1982 by order of the Commission Yup) Form 10-401 Rev. 7-1-80 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT NO. C-3 CONOCO INC. 2525 C STREET, SUITE 100 ANCHORAGE, ALASKA 99503 I. CEMENTING PROGRAM A. The 20" OD conductor pipe will be cemented to the surface with permafrost cement in 30" hole prior to moving in the rig.. B. The 13 3/8" OD surface casing will be run to 2300' and cemented to the surface with permafrost cement through a drill pipe stinger stabbed into the float collar and through the float shoe. C. The 7" OD production casing will be cemented from 8935' (TD-MD) to 6500' MD with 450 CF of cement. This interval will be cemented through a float collar and float shoe. Isolation of the 13 3/8" X 7" casing annulus at the 13 3/8" shoe will be accomplished by running a "DV" stage collar/external casing packer at 2100'+ and by dis- placing the annulus with non-freezing arctic pack followed by 280 CF of cement. II. ANTICIPATED GEOLOGY MEASURED DEPTH O' - 5000' GEOLOGY Surface conglomerates; shale, silt and sand sequences. Base of permafrost is 1800'-+. 5000' - 7950' Siltstones and shales. 7950' - 8935' GEOLOGIC MARKER Kuparuk River Formation; sandstones, siltstones, and shale. Depth TVD / MD Seabee Lower Cretaceous Unconformity Middle Kuparuk River Formation Lower Kuparuk River Formation 4605' 4870' 6795! 7705'. 7128' 8135' 7289' 8345' III. FORMATION EVALUATION A. Standard mud logging equipment will be used from 80' to T~ECEI~/~.!i~D -. Supplement Data Sheet B. Conventional cores may be taken as determined by the wellsite geol ogi st. C. The following wireline logs will be run from 80' to 2300': SP-DIL, GR-BHCS. . The following logs will be run from 2300' to 8935': SP-DIL, GR- BHCS, FDC-CNL, NGT. RFT runs will be determined by the wellsite engineer. Sidewall cores will be determined by the wellsite geologist/engineer. IV. DRILLING FLUIDS DePth Type Dens i ty 80' - 2300' Gel/Fresh water 9.0- 9.5 ppg High viscosity mud (250-300 sec/qt) Low sol i ds-nondi spersed mud Lightly dispersed lignosulfonate mud 2300' - 7000' 7000' - 8935' 9.0 - 9.5 ppg 9.5- lO.O Jones -% V£Ft ' · · 37~, Ce/VTe~ ~ i7 .. FACI~ HOUS£ J !10' I 'i~..._OENTERLINE j- ^cc=_ss ROA~ LOCATION IN SECTION i · W ELL '.FSL FE L NO ~ I I 167 ~..256 , , , , ,,, , ,! ,, FSL = FROM ~)UT'H LINE Alaska FEL= F~M ~ LINE DRILL SITE "C" WELL LOCATIONS · LOCATED WITHIN SECTION !0, TI:SN, RIOE, U.M. ALASI~A PREPARED BY BOMHOFF I~ ASSOCIATES, INC. ANCHORAGE~ ALASKA - D~WN C.L.F. ICW~C~ZD 'R.R.K. ,, Fv~ IDO0--- ~oo0- - I 4.000 ~oo0 · _ ( I /oo0 o~ ~ uP, FAC E ,.kc~oo (,80' 2-..~; 6,5~ N ~, o ~ -.~J~,~,Ac4E CA sl~,J(.,-,- ~ 0 ? i I · RECEIVED CHO(~'.,.:. 8: ,,KILL MANIFOL FOR 1:3~/J' a '7 OD CASING BOP STACK . · KILL MANIFOLD ~~.o,. MUD . PRESSUR~ PUMP REMOTE PR£$SURE GUAGE SENSOR r ~ DRILLING SPOOL . HYDRAULIC CONTROLLED REMOTE OPERATED NOTE: I. Hydraulic Control Systen for BOpUBL££DLI~E ECEIV~D Stack ~ Choke Manifold to include (5) Re..crvoir ~ Auxiliar,' Ener;y'source. (S) Station Cont~ol Manifold plu~ variable Choke Alaska 0ii & G-~ ~ ..... Coz[roi to be locatt~ on ~ floor. 2. ~il: 6 ~okc ~anr~old5 to met: APl Cla~s 5H BOP .%:~'NIFOLD LAYOUT CO;:OCO, I,NC. i ....... i E" i ..... ~ CHOKE !~o MANIFOLE ~ TO SHALE 10 PiT CHECK LIST FOR NEW WELL PERMITS Comp any ~4~ &~-~-~O Lease & Well No. (1) Fee , , (2) Loc APPROVE DAT~ . /(2 t ru 8) · 4. 5. 6. 7. 8. (3) Admin Z;'- %"3/-8'u-~9 ~y'thru, 11) 11.10~ (4) CasE 2~hthru ~"/"g20) ' ~ ~:gl--ihru 24) 12. .13. 14. 15. 16. 17. 18. 19. 20. 21:, 22. 23. 24. 25. Is the permit fee attached ........................................ 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 .: ........... YES NO Is operator the only affected party ................ Can permit be approved before ten-day ~;~ .~.~[i .[[..[ [~[ ..... ~es c°Poensraetr~: thioa~eo~deb~ndne~edf°:c,e' ...... : ', ,, Is conductor string provided ........................................ (~, Is enough cement used to circulate on conductor and surface ......... Will cement tie ±n surface and intermed±ate or production strings W±ll cement cover all known product±ye horizons Will surface casing protect fresh water zones .......... Will all casing give adequate safety in collapse, ;~i~n'~ burs~2 · · 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 ......................... Is a diverter system required ..................................... .~ Are necessary diagrams of .diverter and BOP equipment attached ...... ,,~ Does BOPE have sufficient pressure rating - Test to. ~O psig . Does 'the choke manifold comply w/AP1 RP-53 (Feb.78) ................ Additional requirements ........................................... Additional Remarks: Geology: E.n,,gi/~ ~r ing: HWK _~ LCS /c~6 BEW~' r-~,. fl1/13/89 ' INITIAL "GEO. UNIT. ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History 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 APPENDIX~ ,. No 'speCial'effort has been made to chronologically organize this category of information. ,o COI~I:IDE~TI~[ &- -. -': . 2.: ?: - ] : 2.~:'5: -: ? : 'J:' .L._,~- : -'17. '.' - : 1"-. _ :',' i f:Z ; :.. :.'4Z r2j .- k..:7 -: j-: G ~:?? :- ?~: ; - .~]~k2:::~l,CO~TI:f~UA~tON ~,~jj;~ ~ ~: '~,e~.~.;.~;: ::"; 10I; ~:,~.1 ~ ~ :: ;:;]~]: ~ ~. 7;. ::.::, .:~. % _ -t-. :: -..,:~: .~:~::~. ::.:: ~ ~'~?: :::.'..":~:':' ~.: :..::',~.:'~'_7~"~f~':::::'-;~?:':;":?;:~J~:~':::'":;:;'..'::3:..:?.: [. , . . :~:6::...:':-.. --, -:~-U:PARUK:., .,:::" .:--' ':~ ·: .......... -:.:. ::. ":., ::: ;. ,:._.:~.. .......... ..:. ;-.: _. ~.. ,_;-. :;~;:0.~)0~ -. .:. 0.:00 : ,. OOa 065 ~-6f:, ,; 'i 0:~" .:,' :.- ,:.;: .::~,: =:..: ...... :?._ :...:,::::.;.,.:~::.::~,: :_-,:,:. :::,_:,.:.: .... - :..::_ .... "':'; ":' ::::' ':":'~::0'~00-- -'::'000": 003 065 ;'t~:fJ:~;:; t3N.-..; .'.: ': .::-::,-:,: ,: :;::,., -,:::= .:~: .,:.: .;: ..:..~: .~' ,., :~,:::00.0 , .:'O00 003 065 .3.;~CT~: 10 ..... : -- :':~ :'::':-':: ':':" :'~ :.;" :-'~;::'~':;~ ':;:"::" '::': ';"':::' ~'O0-O ;::;000": 002 065 ..... ~ N~- NO~: :~ [- -~ · ' ..~:~:~:.?,:.: :.,~,..~_sbO::~:.... :-- :_:.,:~:..:.:. ,: . ,_ =,:, .:. .:~.._~ .. ~ . ;.::::. .. ,: o12 065 ,,C~ ~Y .... :~,J ,:~, a.,: .: ::.- .... - ::;-:~..,~..' :. ~:.-,_. 000 - 00~ 065 :: . : :. : :- :: : :' : ::::: -::::- : u -,' -: : -- ;_ :~ ::j: :~: ...; .. :...; j;:i:.~ . O65 ~NTRY ! 6O 0 SG_R ~CT GA_BI $~Op ~.,~ CT ~p~a - 7.2~91 6.7930 3:2,7500 THOR O~,,A~n'r' 2,0020 URA!'.,i 3.2520 pnT,~, 210020 U~!AN 2.5938 .. 7.4570 b. 55(38 6.0625 4.07B1 7.3281 S.6172 p?¢T-i~' .... ij'~: :'-': ::--::' :::~::-::-:':~:-::' .',: :';: - ' · : · ' - - .¢ - -.: ---: .-: · '..--: .... : 4. -:;-- -.:'.': - ~'.- m...:'..:! ~.:_- _-:: :-: ....:r ?: .':':' -:.,.:'--~:::: ;:&:-:- -: .:;;.- . ~ -< ~ . ~. ¢. '~ , ~ .~ ..... ~ ~ - ::: 4Uu.:~;~:¢ ~:O:;;.,,~ :.:;~.?:::;~.;.:::;:.:,::..& 5:..:. ::': -<:. ~:;~:;: '::::'?~: :~; 0:8v2:5..:;:- :'::.T:.~:QR : 7,0000 POF~ : : ~:; -i :'-' .......... :: ...... ~ .~::-.-.::~; 2 ~ .;;: ::'04>:~ ~:~:: .::::. :,: :~.:.:/:? L::~'.~":..:: ::.:~:*~::. ..... ..:~:: ........... aE.P ~. ~ ~ ~. 0,0,00 CGR ......... ;': ....... :,~,~:;.:2.50::0.?.;.~.::T~0R.: ,,....-._ 8,2969 . : . . : - · ->- '-- ~%- - :.: _.'::: 4:>7 .: ::', '.:::'.x :::; ..':. ' :' D:E~P:T~ ::: :?:. :;:.:.- ::-::..: :':.::':..: :~71::,:1~75::.-.':~:(~'~ ..'.: .::::::-:'?::: ,.::..:: ,:.:::'~:8:::iO 0:~::., .'..:.:I:H.OR ........ - ,: 8,1641 P'a'T-~ - ::"'2;"63:6:7': ....... U~"~:'" : ..... '"'"' - ' ¢ _ : :-' :; ':/':-3: :.. :¢ .... . :':...' -:~.-.~--x:%.--:,:::-...::. h::. -m_ ::.'::0:;:':;::;:; ::::.:.: T-- ' 7:OO8 .: :',::: L:2~O:::..::..:.SGB ::.:: ::::::::::::::::::::::::::: ;~6.::~,;:~ 8~5:~ .~.OR' - . ~ · 9 g 22 PST~ - :i';6"6'02:': - :0R:~4:' ..... :: "'":""':' ~';:'8:~.4~-3::: ..... -;:"::~-,':::.' '::~::<::'-"-~::':--::""';~;~-: :.. P~'A · .' ~ ~:'0508.'~ :;.;:U::R:A3~4 :'::~$..:~::5~:~::8:1:::. :.:: &:::' .:;:::::/':;.:.~:;'::::;:::~?:::~.~::::.:::: - :: '~:?<~: :: -.::- :r:~ - -* '-,':;-~:-.._' ;~':? :;x':7 -...- .: ,_ : ............ .... ..:_~:.~. . : : -:' ~: - .:~ ': ::: ::'.. c :.': :,. -. ~:: ?~ ::..:::,:. _:,..?: .-:,- -~:~.-:7 : '-.::: ::"-:7 ::::":L. :P:'~T:~ ' :~;'~ t i"]:::::: ':::'V::P:~::.? ::'" ~ :: ::":: :::::::::::::::::::::::::::::::::: ::':: :< :":: ::: :::":~::< :::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::'.:::: ::::::::::::::::::::::::::::::::::::::: ': o" :O,.~;P,~:: ,',-: -: b:o:O 0-',09(1~):::..>;:;C:6 ~. :.. ?, ::. : ......... .,, -.,:~6 5:.:&,2:50. :-T~QR ::. b. 4 3 3 6 . :::...:/L 33. :: ::::: :: :::__ ,: ::.:::: :::: :::: :::::. ::::::::::::::::::::::::::::::::::::::::::::: : ::::.:..:: POTA 1.31~4 LJ~A~ 1,0859_,. PrITA :1~2695; ; UR,aa': ~': '-~ '~.u254 i'~ .... ~"r~O nOOn CC;R 4a 500 Sa~ .a ~50-0 _,s ..... ,. ,. I.,7578 .... ..., ~ ~,- , ,, ~ ~ ~ .. O~;F'T b490.0000 CG~ 4~.5:31.~ ~GR - 55..~t88 THOR . pr'~TA ~,953~ 0~,~ 0;8325 O~PT 4o~0. 0000 CGR 52. 093~ S(~R 63. 4888 THO~ POTA ..... ' .... ' '' ~' - .4 '' . . - D?PT 47r, 0.o000 CG'P a2:~a37 SCR - 5~,9062 T~OR POTA ]. 41 60 URA~:~ 1. 2920 : O*'pT 4500.0000 CGF' 44.6875 'SGR 55,9687 TNO~ pa~., I ,: !. i230 i..!FcA~,~ 0.9580 (t. :' - OEPT 4.~00. ~'¢ t.300 Ct;~: 46,90e~ SGR 57. 5000 P[;TA 1; 31 84 kJ}~N i... 3574 ' 4100.0000 ' ¢ "" ~'~' '¢ ""' _ 5.7695 5.2539 5.5078 5.8320 ~.b094 6.2,.227 b.4883 6.6719 6.6953 7.3984 b.6680 5.289l 5.4023 5.5859 a.4883 2.3105 7.0234 5.8867 POT.A' . .;, . ;:- ~::. , ~ ;,; ,.:; ..~ ~ ;~- :.:.:_ ; .. .: :;:- .. :x~' :.:.~ ?::-57 ; ~:~;'~.. ;::.; '.f,; .:. ::.:;jLa; );.._ . :~'..'~:; _ .. 2;- ?,: ; ;.. :: · 0E .-- ;:.~ ~3~90'~:,0,0-00~::~:-'~,~:.~:~::-~'.':~:.?~::-:~:,~::~:::~:~;7~;~:~.::.,~::. :::~ '2 ~ ~OR; 5. 8984 POTA I' ,~4160' ........ URt':'~I ' ........"i"~":'~'i02: ~' '"'~ ...... ':' 6.019S 4.2227 :,P'O.~:'-:~ :-.- POT~ i;2'20'7 -OR ~'f::'- ' ':::~-:'::-'f;"2'0-6':i'-:~- ',`'',~ ...... -'"' '~':' :":" "'~ ?:':= ...... ::::::::::::::::::::: :"-':"' ' ~.4~95 .. - : t.-:. ~": -o:'... 4... .... ..': ..: .... _ :.:::.--,~.'.- .~.: ..~:.=:~. :.:2,:. -:'-:.-- 11::. :'- x: - ~P~" ~ ,,.,,: ~; .:~; ,37~,';:1~;~.'75,".:-T.~OR ,: 4.5117 4.1523 2.8437 3.T324 5.3711 ~":: - - ': - ~.: ' '.~ ':-..'7: ~:. :: ' -' :?' ~' - ::::: :: :: : :::: :: ::: ::: :::: : : :/::'-:~ :::f :~:-~:: :'?' .:'~!:~:i': ::.;:. [':~: .' - [::'~[% ::~_ 2. 0 391 2,i738 CONI:[, ENT?AL ~.2031 LV~ OIO.HOI ¥~Ri~ICA'rIoN LISTING SERVICE NAME :SERVIC OATE :~2/06/i5 ORIGI~ : REEb ~AME :RE£b ID CONTIMUATION ~ ~VIOUS REEL .ME~TS :~MEL COmMeNTS ** TAPE HEADER ** SERVICE NAmE :SERVIC DATE :82/06/15 ORIGIN :6511 TAPE NAME : CONTIMUATIO~ # :0! PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ** FILE HEADER ** FILM NAME :SERVIC.OOl SERVICE NAME VERSIO~ # DATE : MAXI~U~ LENGTH : 1024 FIbE '~YPE ** INFORMaTIOn] ~ECORD$ ** MNEM CONTENTS CM : CONOCO INC. ~N : MIbNE POINT C-3 FN : KUP~UK RANG: TOWN: SECT: 10 C~UM: NORTH SLOPE STAT: ALASKA CTRY: U.S.A. MME~ CONTENTS PRES: DIDO01F LV'P OIO,HO1 V~RIFICA~ION LISTING : S C H L U ~, B F_, ~ G E : ALA6KA CO~,[TING. FIEI~D : KUPARUK STATE : ALASKA :. ~ ~-- :::::::::::::::::::::::::::::::::::::::::::::::::::::::: :.: :::_ ~ ,.:. : ~ , 8OB NU~BE~ AT ACCI JO707~511~ ~J ' ~0~ ~2~ PAT[ LOGG~:DI 17 MAY 82 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:. :.: :;.: ..::: .: .::... _ ::,.z. ,~ ._ 8192 FT 7 1~ ~/8 I:u, 2~1, -T.,. BOTTOM DEPTH TOP DKPTH CASING BIT SIZE TYPE FLUID DENSITY VISCOSITY 8.5 IN. GEL WATER 10.5 41 $ 010 h'Ol VERIFICATION LISTta(.~ P H = g. 3 ::::::::::::::::::::: ..:~ < : _ _ FLUID LOSS : 4.4 C3 R~ : 2,7 8 66 DF ~ i t :.:::.::!!' .:.: "-: : -- R~iC : 3.0 ta 66 DF ~ :::::~ : ::-. · -:::::::::::::::::::::: .:~::::?: :~:~2<~::?::::~:':;:'<'(.:'~.::~:':~:: ::.:;:~;:~.:::4<::>-<:~:Q:'~Z'~:.:?~:>~:::~::~.~:~ ': ~ : : :: : -' --: - ::'~ :- "-- 4>: J~. :~:''%~.::~' T:'- ::': :'::'":: :T:¢¥ Y :f.: .-"~:T-¢x>- i : ** DATA FORMAT RECOPD ** ENTRY BLOCKS TYPE DaT{.!~ SPECIFICATION MNEM &E, RVICE SERVICE ID &RDER ~ DEPT SFLU DIL'-'~' ILD DIL" ILM CIL-' SP DID" GR DT BHC/ dR P~C / NPHI RHOB FDN~ D~HO CALI FDN---- GR fDN NCNL FDN FCNL FDN NRAT FDN CGR SGR ~GT THOR 5GT BLOCKS Fl' OHM ~i GAPI US/F GAPI PU G/C3 G/C3 GAPI GAPI PPM DVP POT~ URA~ OiO.HOI NGT ~GT V ER [ F! CA TX Oi,~ PU ** PATA DEPT SP NPHI GR CGR URAN DEP? SP URA~ DMPT SP NPHI GR CGR URAN DEPT SP CGR URAN DEPT SP NPHI GR CGR URAN DEPT SP NPHI CGR DEPT SP NPHT CGR URAN 8875 -999 37 34 -39 9 1 . 25, 95, 7 8700. -27, 23. ~5 ! .0000 SFLU 2500 GR 4512 RHO~ 5625 NCNb 4375 SGR ,6484 0000 SFLU 67iq GR 7324 RHOB 8750 NCNb 7500 SGk 3672 0000 SFLU 1562 GR 7793 RHOB 875 NCNb 875 SGR 5010 . og:oooo 2 5313 GR 107,5625 SGR 1.6641 8500.0000 8FLU -15 9062 GR 33[1543 RHOB 105 3750 NCN~ 2.4824 8400 0000 $FbU 2~8613 GR 3~:8906 RHOB lo 6875 NCN[, 83 801. ~300.0000 SFI,U -28 3281 GR 17~0410 RHOB 71.5000 NCNL 70.6875 SGR 0.1079 LISTING 0 - - 25oe 34. 5625 ' THOR ": ........ '~'2'~"~:'4'::65:'" ~'~'POTA": "': ~0;T8:$'3- ': :"":~ :' : - ' 2. 566 ~ DB. H0::, ....:::::: :::'~. :,.:<:::I:::2::::::::<CA.~:'t :::.' :. ::..:,. :_:.:~,.~ :::::::_-: . :: .: .::.::: ::.: :: - : . : 12 O. 3,I7 9 0 103-6e. t5 .:., : 60.1, 875 5 O00 :: :D~:~::O: "-':':' ::"': ::: :::::::: : ::::: ::::::: :: :: ~::C ~' L"'i '< :~: :" ":':: "9<;'5:':6::2:5':::'' :': ..... .... : ' - ' 33 ] 2.0 O00 ~CNL ::: ....... !:657. ():0:.0..O:_<::N:~A:::.::.,::, :: :<:<:::.::L ~::: :~-::,-:: :: ::: ..:.-.:- : 7 .5000 ' T~O'P DEPT SP NPHI GR CGR URA~ DMPT NPHI GR CGR URAN DEPT SP NPHI G~ CGR U~ AN DEPT S9 NP~! GR C~ URAN D~P~ NPH! GR CGR URAN DEPT SP GR URAN DEPT NPHI GR CGR URAM DEPT SP NPHI GR OIO.HO! 820 -4 4 lO -4 ? 5 5 8 O0 -2 2 7 790 -4 5 4 3 12 VERIFICATIOki I, IST~NG 0 0000 SFLb 6~6250 GR 0,4785 RHO~ 3.0625 MCteL 7 50OO 2:0313 0 n ?: oo.,2s GRSFr'U 9,7852 RHCr: 6,5000 NCNb 1.2500 SGR 0.~816 0 0000 5FLU 5:4063 GR 9.8340 RHOB 8.2500 NC~L 7.4375 $GR 1.4150 0.0000 SFLO 1,5313 GR 2,5586 RHOB 3,5938 NCNb 0.5625 SGR I,b992 0.0000 SFLU 2.4531 GR 2 1777 RHOB 4:3750 0 1875 5:7578 7700.0000 SFDU -15 7500 GR 43:3594 RHOB 12~.8750 NCNb ~15.3750 1.1123 7 o :oooo -1 7344 GR 44 3848 RHO8 ~17[3750 NCML 99.3750 SGR 2.339~ 7500.0000 SFLU -24.5000 GR 38.964a RHO~ ~a3.1250 NCNb 2 9004 I 4 2,257:~ 3356.0 56: 5000 75.250~:~ <~ 2 .. ~ ~:82 3126 ' O 0 O0 4 ~ · :875.0 3854.0 000 2.627-0 123.3750 2 · 4 609 124, :~ 3 7 I 2 3; 8750 119~ 1907. _, 148 · 5000. ~ ' 441~ :!' bVP O~O.M01 V~:~IFICATIOgd LISTING CGR URAN OEPT SP CGR U~A~ DEPT SP GR CGR URAM DEPT SP CGR U~AN DMPT SP NPHI GR CGR URAN DEPI NPHI CGR URAN DEPT SP NPHI CGR URAN DEPT SP NPHI CGR DEPT 9375 SGR 7400.0000 SFbb -17.7344 GR 8750 NCNb qo 5000 SGR 4~4922 7300.0000 4531 130o7500 q6.7500 4.4336 7200,0000 -31.0000 39 1113 146~7500 106.0625 5.3O47 7100,0000 -25 5156 31:8359 125 1~75 96:06~5 3,8008 000 24 31 3 6152 10~ 8750 84.8125 2.0977 6900.0000 -31.46@~ 30,3711 9 . 625 2.5234 6~00 0000 34:0625 30,7617 111.5000 :999.2500 099.~500 6700.0000 -~3.7500 SFLU GR RHO~ NCNb SFLU GH RHOS SFLU RHOB NCNb 8FLU G~ RHO8 NCNL SGR GR ~H08 NCNb SGP SFbU GR RHOB MCNL SG~ GR 2450 . 0000: 'F:CN'L-'=~ :-:w~ .,~:B:75~:;:.0~)~:0~ q~:R.A~T-..:. -.: :::,, _,., 3;20~:5.:~i:..~:--,.-: ..... ~_~ 1 30.~ 5625 :: D~" -:.: :~ ~ :~:_:: :::-~i. 0.2', 9:::,..:-':~:::: :. :: ~ · ::t09.8:~:' :~::..~ ~:.,::- :: ~ 2 ~: 4 ~o 2-' -..': ?':":'~':~ ::: o; : ~ :':- ~:~':~/;.s ??,-~':I ::::'-~.':' ::::. ':'.: ::' ': ' 130 ~ 7500 T~.OR: ':: ' '~::: '::~'~-I'3::;6~75"::' :~:PgT~~:`-' :::~': :~ ~'-:~ -":::2:~:'68:55~- ...... : . . 1 00 CO :DT'-' ': ~:' ' :'~'~;~::'9~;~5o~::'~''~'`~'~'':''' :~'-..~ 23::;~00~00 .:.:: .~. ~ ~ - _ -~.:-_ :: ':.% :L::; ~.;~?~- :~:' .: &.'::'.%:?: '::{:~; .:::." :'~::- ::::: · '[ · _'::':.-:.' '.::.- ; ? ':.2' xc~/'~'::/: "::::""5: :...>: 7 ::{,/-:-: :' ::::': -%' . ;: · -: 3, ~ 777 B 1.~-.DT ."~ :?-;:~: ~.~:~..9:4~!~.~:5.~ ~,.:.~.. '.::-::: .:~ ..... '.: : 11.' 50 39 ~'':~ ~C'~I~: :'":=:"' ~:::':~'~: :; ........... ':: ' ' 2 5 . 1 8 7 ~ T ~ 0 P :._ :~: ........ ..~:::3::.;.~:.= 5~?Ri:..:. :::_:.::POTA . .... ,.:~:- ......... 2" 2~ ';':' ;":;?~:::: ::::::::::::::::::::::::::::::: ::; :: 27 Z 00. ~ 104.6 25~ '.,:. :D'~-:::. =:... :::?' :-,,: .':: .,::.:~:9~:: '.:,:; :.: ~: < ,:': ,: :, ..-: 2 ' ~ 51 2 _. :DR:H:O?::.:~ ::' C~::'L:I .... ':: ': :' ' 1 I ~ . 9 375' ' T~{'O.R :' ::-:' '~': ::::-~::;:~:- 7-¥':- :~:' :- :': ' "': :: :':' '- ': : 3.0 0.59. :~ t~D:.:.. :~..:~:::-: ........ ~.._ :: :~::;;..~:.~: ...:2.::. .::~.::.~.~:_ :.~-:-: 2,2o-49-. ~?... ~:~..:-: NPHI CGR UR. AN 010.H01 VE;RI~-'ICAT ION 33.9844 RHOR 114.0000 NCNb -999.2500 SGR -999.2500 DEPI 6600 OOOO SFLU SP -36:1875 NPHI 34.0820 RHOB GR 115.5000 NCNb CGR -999.2500 URA~ -999.~500 DEPT SP NPH! CGR URAN SP NPHI DEPT NPHI GR C~ URAN DEPT SP NPHI GR NPHI GR CGR URAN SP NPHI GR CGR URA~: oo.oooo 8125 ~HOB 1250 NCNb -9q9~2500 -999o250U 6400.0000 SFLU -31.2031 ~R 35 7910 RHQB 114~7500 NCNL -999.2500 SGR -999.2500 6300.0000 SFLU -2 95 R~08 96 500 NC b 500 SG -999.250o 6200 OOUO 8FLO ~ 1055 RHO~ :7500 NCNb -999,2500 SGR -999.2500 6100.0000 -36,9062 GR 32.6172 RHOB 94.2500 NCNb -999.~500 -999.2500 6000 0000 SFLU -R8~9375 31.6406 106.6875 NCNL :999,2500 q99.2500 LISTING 2. 3'1 ~ ~ ,~., ~ . . ~ ~-. ,, . ~ .._ ,.' _ - ._~ ... :- _ _ -99~.. 99 .~ ~ O0 'T~O'R' - ~99 9. '2 5'00 POTA' ~-999:"-250O 2. ,~ 9~5 :." -DR:HO,.' .:,.':-- ..... ~:--.: '999, ~05- '~- - 9 9 9.2500 ~ ~-0 R' '::.--9 · ;""; :"? ~3~ :::'. ~.<:~.:~7%; ~99 ~;6:5-~'-":~ :;:":':::::::';~:~:~:~?~': 2~ ~ DRHO -0-,--0-0-29' .-CAL...1..- ...... 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GR CCR URAN DEPT SP NPHI GR CGR DEPT SP NPHI CGR URAN SP NPHI CGR 5900.0000 SFLU -3~.6875 GR 3 .7402 RHOP 102.3125 NCNL -999.2500 SGR -999.2500 5900.O000 SF[,U -40.2500 GR 92.6250 NCNt, -999.2500 SGR -999.2500 5700.0000 SFLU -39 7500 GR 31:7353 RHnB 79.50OO NCNL -999.2500 SGR -999,2500 32.3730 RHOB 80.5625 NCNL 99¢: 5oo SGR . 50 o 5500.0000 SFEU -44 1562 GR 33[7402 RHOB 98 2500 NCNb -Q99~2500 -999.2500 5400.0000 SFLU -56.6875 GR 37.5488 RHOB 77.8125 NCNb 2: soo 5300.0000 SFLU -5~.2187 G~ 3 .5000 RMQB 105 8750 NCNL -999~2500 SGP -999°2500 5200.0000 SFLU -47.9375 GR 42 675~ RMOB 102~1575 -nn9.2500 SGR 3 2'Si. :D,~,~'.U:::,': ,:.::.:O :.:: ~Li,~:_::::~ ,,.: ~4:'. 9.-..:': ::: .,:::.,' ,: ':_':. :: _ -999' 2500 --PCNL :: :::':3::';:~8'7:1'":: ;' ::":::" "' - -999.2500: 2.9355 < ~25-u:, 2 ~ 027 -:., DR. 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' ":~-': ::'-~:'~::.t:;'~78:13 -~99:2500--'TN:'OR '>" hVP 010.~01 ¥CRIFICATION bISTING DEPT 2~00 0000 8FLU Sp 46:2187 GR NPHI 44,7266 RHOB GR 68,5625 NCNb CGR -999,2500 SGR URAN -999,2500 DEPT 2700.0000 SFLU Sp -15,~906 GR NPHI 50. 395 RHOB GR 77 ~875 NCNb CGR -999~~500 SGR URAN -999,2500 DEPT 2500.0000 SFLU p -29,4375 GR PHI 42 ~28 RHOB i8! 5 h GR 73 2 NCN CGR -909 2500 SG~ URAN -999,2500 DEPT 2400 0000 SFbU SD -59~4063 GR NPHI 53,~109 GR 35. 938 NCNb CGR -999 ~500 U~AM -999~2500 DEPT 2300.0000 SFLU Sp -21,3906 GR NPHI -~99.2500 RHOB GR -999.2500 NCNb CGR -999.2500 SGR URAN -999,2500 DEPT 227~ 0000 SFLU SP -9q=~2500 GR NP~ -999 25OO RHOS GR -99912500 NCNL CGR -999 2500 SGR U~AN -q99~2500 -999 [ 2'500 -g 9 9. ~50 .... 2.'. ! 64-1 -999;~S0:'6-~ 6~, 1250 ' i914`..? F -999 2500- -999: ~500 -99~; 999.2 '999; :999- 250 0 :': ',:~'C~::NLv:'<:::':':~':::~ '=;':', :'.:, 9 ~9:250:0'':~ 2 50'0 -999.~509- ** FIbE TRAIbER ** FILE NA~E :$ERVIC.O01 SERVICE MA"~ : 5VP 010.HOI VErIFICATiON 5ISTI~G VERSION # : DATE : MAXIMUM bEi,iGTH I 1024 FILF TYPE': NEXT FiLE NAME : ** Ta~E T~ILER ** SERVICE ~ ,E :SERVIC DATE :82/06/15 ORIGIN 1651~ TAPE CONTinUATION # 101 NEXT TAPE COMMENTS :TAPE COMMENTS ** PEEL TRAILE~ SERVICE NAME :SERVIC DATE :82/06/15 ORIGIN REEL ~A~E :REEL ID CONTINUATION # 101 NCXT ~EEL ~AME : COMMENTS :REEL COMMENT&