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184-221
ect Well History File' e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. I ~ -¢~'~ / Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) n Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~, OVERSIZED (Non-Scannable) [] Other: NOTES: [] : Logs of various kinds [] Other BY: ~ BREN VINCENT SHERYL MARIA LOWEU. ,s, Project Proofing BY: BEVERLY BRE~ SHERYL MARIA LOWELL Scanning Preparation ~ x 30 = ~ - BY: Production Scanning Stage BY: Stage 2 BY: ( BEVERLY)BREN VINCENT SHERYL MARIA LOWELL (SCANNING IS COMPLE~POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT FROM SCANNED FILE: /'~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO III IIIIIIIIIII II I!1 RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked {done) 10/25/02Rev3NOTScanned.wpd ~ ~ . • ConocoPhillips a~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~~~~~~~~ }~(J°~ ; ~~ i(lG~ .~~~sl~~ ~~~~ ;~ ~~~~ ~~~~~ ~~r~mission ~ncharag~ ~~'~~~t~~~ ~ ~ ~~ ~ G ~.~~~ g ~, _ a,~--1 ~,, G -- °`~" Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 20th and October 13~' 2009. The corrosion inhibitor/sealant was pumped October 15~` and 31St + November lst and 2"a 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. mcerely, ~ Perry Kle~~ ConocoPhillips Well Integrity Projects Supervisor . ~ • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C. 2D. 2Z & 3K Pad Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbis ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2G11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/172009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11 /2/2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11/2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11 /1 /2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11 /1 /2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 71 /1 /2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 16" NA 16" ~ NA 5.95 11 /1 /2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K 103 50029233920000 2081150 29" NA 29" NA 11.9 71/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 . . Gary Eller Wells Group Engineer Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 September 27. 2006 RECEIVED SfP 2 7 2006 Alaska Oil & G as Cons. C . AnChorage Dn7mlssion Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage. Alaska 99501 Subject: Report of Sundry Well Operations for 2C-09 (APD # 184-221) Dear Commissioner: ConocoPhillips Alaska. Inc. submits the attached Report of Sundry Well Operations for the recent workover on the Kuparuk well 2C-09. If you have any questions regarding this matter. please contact me at 263-4172. ~CMNtsP SEP 2 9 lDDt: JGE/skad " ^_..L 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other "rf Alter Casing 0 Pull Tubing 0, Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 184-221/306-167 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21237-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 125' 2C-09 8. Property Designat!on: 10. Field/Pool(s): ADL 25654, ALK 2580 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: . Total Depth measured 9660' feet true vertical 6268' . feet Plugs (measured) Effective Depth measured 8702' feet Junk (measured) 8882' & 9253' true vertical 5583' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 75' 16" 101' 101' SURFACE 4136' 9-518" 4162' 3058' PRODUCTION 9594' 7" 9619' 6238' Perforation depth: Measured depth: 9131'-9252',9369'-9412',9436'-9457',9491'-9498' true vertical depth: 5875'-5963',6049'-6081',6099'-6115',6141'-6146' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8794' MD. Packers & SSSV (type & measured depth) Baker FHL pkr @ 8632' no SSSV 12. Stimulation or cement squeeze summary: RBDMS 8Ft SEP 2 is lDDô Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 495 671 2024 -- 139 Subsequent to operation 822 . 1862 2168 -- 151 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-167 C'"tad G~: 2~172 Well Engineer Date ~{'Lìf O~ p""1ed N,me ~ Eller ~ Title Signature , Phone ;"'''''' '"~ Prenared bv Shamn AI/sun-Drake 263-4612 Form 1 0-404 Re~ 04/2004.J , ~b-¡:¿ ~1'¡'7.~ Submit Origin I Onl RECEIVED STATE OF ALASKA . SfP 2 7 2006 ALASKA OllAND GAS CONSERVATION COMMISSION Alaska 01 & REPORT OF SUNDRY WELL OPERATIONS I Gas Cons. Commission . ORIGINAL ;; ~s-/a . . ConocoPhillips. Alaska, Inc. KRU 2C-09 ~ 2C.-09 ....... COMPLETION API: 500292123700 Well Type: PROD AnQle (å! TS: 44 deQ (å! 9131 (0-8794, SSSV Tvoe: NIPPLE OriQ Completion: 3/14/1985 AnQle (å! TO: 41 deQ (å! 9660 00:3.500, Annular Fluid: DSUSW Last W/O: 9/1/2006 Rev Reason: ADD FISH TAG 10:2.992) Reference Loo: Ref LOQ Date: Last Update: 9/24/2006 Last T aa: 8678 TD: 9660 ftKB Last Taa Date: 8/1/2006 Max Hole Ana Ie: 59 d~7600 CasilJY~Irlng .r' ....... Gas Lift Description Size Top Bottom TVD Wt Grade Thread MandrellVatve CONDUCTOR 16.000 0 101 101 62.50 H-40 1 (3918-3919, SURFACE 9.625 0 4162 3058 36.00 J-55 00:5.968) PRODUCTION 7.000 0 9619 6238 26.00 J-55 T(JbihQString-TOS'NG ....... + Gas Lift Size I Top I Bottom I TVD I Wt I Grade I Thread MandrellValve 3.500 I 0 I 8794 I 5643 I 9.30 I L-80 I EUE 8RD 2 (5700-5701, Pèrfórations SlJItlrriårY! < ............ 00:5.968) , Interval TVD Zone Status Ft SPF Date Type Comment 9131 - 9252 5875 - 5963 C-3,C-2,C-1,l 121 12 3/27/1985 IPERF 120deg Ph; 5"Jumbo Jet Gas Lift B MandrellValve 9369 - 9375 6049 - 6054 A-5 6 4 8/27/1985 RPERF 90deQ V Ph·2.125"BarKone II 3 (6511-6512, 9375 - 9376 6054 - 6054 A-5 1 5 8/27/1985 RPERF 90deQ V Ph;2.125"BarKone II 00:5.968) 9376 - 9377 6054 - 6055 A-5 1 4 8/27/1985 RPERF 90deQ V Ph·2.125"BarKone II 9377 - 9378 6055 - 6056 A-5 1 5 8/27/1985 RPERF 90deQ V Ph;2.125"BarKone II 9378 - 9382 6056 - 6059 A-5,A-4 4 4 8/27/1985 RPERF 90deQ V Ph;2.125"BarKone II 9382 - 9387 6059 - 6062 A-4 5 10 10/10/1994 RPERF +/- 90 dea Ph; 2 1/8"EJ 9387 - 9390 6062 - 6065 A-4 3 11 10/10/1994 RPERF +/- 90 dea Ph; 2 1/8"EJ 9390 . 9393 6065 - 6067 A-4 3 10 10/10/1994 RPERF +/- 90 dea Ph; 2 1/8"EJ 9393 - 9402 6067 - 6074 A-4 9 11 10/10/1994 RPERF +/- 90 dea Ph; 2 1/8"EJ 9402 - 9404 6074 - 6075 A-4 2 5 8/27/1985 RPERF 90dea V Ph;2.125"BarKone II 9404 - 9412 6075 _ 6081 A-4 8 4 8/27/1985 RPERF 90dea V Ph;2.125"BarKane II 9436 - 9441 6099 - 6103 A-3 5 4 8/26/1985 RPERF 90dea V Ph;2.125"BarKone II 9441 - 9444 6103 - 6105 A-3 3 5 8/26/1985 RPERF 90dea V Ph;2.125"BarKone II 9444 - 9447 6105 - 6107 A-3 3 4 8/26/1985 RPERF 90deQ V Ph;2.125"BarKane II 9447 - 9450 6107-6110 A-3 3 5 8/26/1985 RPERF 90deQ V Ph;2.125"BarKone II 9450 - 9452 6110 - 6111 A-3 2 4 8/26/1985 RPERF 90dea V Ph·2.125"BarKone II 9452 - 9455 6111 - 6113 A-3 3 5 8/26/1985 RPERF 90dea V Ph;2.125"BarKane II 9455 - 9457 6113 - 6115 A-3 2 4 8/26/1985 RPERF 90dea V Ph·2.125"BarKone II 9491 - 9498 6141 - 6146 A-3 7 1 3/27/1985 IPERF 120 dea Ph' 4" Jumbo Jet Ga$ Lift MandrèlsNãlves SEAL St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv (8617-8618, Mfr Cmnt 00:5.880) 1 3918 2913 Cameo MMG CAMCO GLV 1.5 RK 0.188 1250 9/3/2006 2 5700 3909 Camea MMG CAMCO GLV 1.5 RK 0.250 1290 9/3/2006 3 6511 4354 Cameo MMG CAMCO OV 1.5 RK 0.250 0 9/3/2006 4 6945 4598 Cameo MMG CAMCO DMY 1.5 RK 0.000 0 9/1/2006 PACKER 5 7971 5150 Cameo MMG CAMCO DMY 1.5 RK 0.000 0 9/1/2006 (8632-8633, 6 8561 5494 Cameo MMG CAMCO DMY 1.5 RK 0.000 0 9/3/2006 00:5.970) Other 'plugs,éqÜip., etc.r..COMPLETION Depth TVD Tvpe Description ID 506 506 NIPPLE CAMCO OS NIPPLE 2.875 NIPPLE 8617 5529 SEAL SEAL ASSY W /PBR 3.000 (8776-8777, 8632 5539 PACKER BAKER FHL PACKER 2/12" PBR & SEALS 40K SHEAR 3.030 00:3.500) 8776 5631 NIPPLE CAMCO D NO GO NIPPLE 2.750 8787 5638 WLEG WIRELlNE ENTRY GUIDE 2.992 Fish-FISH WLEG Depth Description Comment (8787-8788, 8887 ESP ASSEMBLY ESP Motor & Seal stuck in hole on too of FISH 3/30/2006 00:3.500) 9253 OLD COMPLETION PARTS 3.5" TUBING STUB, G~~,PUP & PACKER W/28 BLAST RINGS & FIRED I SWS CUTTER - LEFT IN HOLE 8/24/98 General Notes ESP Date [Note ASSEM8L Y 10/29/2003/WAIVERED WELL: T x IA COMMUNICATION (8887-9253, 8/28/2006 I Confirmed hole In 7" CSG (å! 8688' RKB oer PDS Caliper Survev 8/28/2006 00:3.500) - ~ Perf - - (9131-9252) - - - - - - Perf - - (9369-9412) - - == == - == Perf ;;;;;;; (9387-9390) = = = = = Perf = = (9441-9444) ~ ~ = = Perf - - (9491-9498) - - - - ConocóP'hillips We/Mew Web Reportíng Time Log Summary · 13:30 20:00 6.50 MIRU MOVE MOB P 20:00 20:00 0.00 PROD1 RPCO~ SFEQ P 20:00 23:00 3.00 PROD1 RPCO~ SFEQ P Hook up kill lines on tree. 23:00 23:30 0.50 PROD1 RPCO~ SFEQ P Pull BPV. 23:30 00:00 0.50 PROD1 RPCO~ OTHR P Hold safety meeting prior to killing the well. 08/08/200600:00 05:00 5.00 PROD1 RPCO~ OWFF P Kill well by pumping Seawater down tubin and takin returns u IA. 05:00 06:00 1.00 PROD1 RPCO~ OWFF P Monitor well, pressures O. Set Cameron HP-BPV. 06:00 09:00 3.00 PROD1 RPCO~ NUND P ND tree. Set Cameron test dart in BPV. Lift threads on tubing hanger observed to be in oor condition. 09:00 15:30 6.50 PROD1 RPCO~ NUND P NU BOPE. Note: Witnessing of BOP test waived by Lou Grimaldi, AOGCC Field Ins ector. 15:30 23:00 7.50 PROD1 RPCO~ NUND T Function test BOPE. Losing pressure, trouble shoot, had API ring leak on spacer spool. Tighten flange bolts and flange held 3500 psi, no external leak. Still have leak off, continue trouble shooting. Blind/shear rams and pipe rams holding from above, no external leaks on stack, but still bleeding off from 3500 psi. Pull test dart, seals OK, redress and reset, test with same results. IA built up 360 psi while NU & testing. Bleeding off same to tank, down to 70 psi thru small line at 2300 hrs. 23:00 00:00 1.00 PROD1 RPCO~ NUND T RU 2" line to bleed IA and take returns thru choke. Prepare to pull test dart. IA built back to 360 si. 08/09/2006 00:00 01:30 1.50 PROD1 RPCO~ NUND T Continue RU 2" line to bleed off IA and take returns thru choke. Fix leak on bell nipple, cut & install new riser while RU to pump down tubing. Pull test dart out of BPV. 08/09/2006 01 :30 04:30 3.00 PROD1 RPCOI\ CIRC T Close blinds. Start bleeding off 360 psi from IA to outside tank. Break circulation pumping seawater down tubing thru BPV, taking returns thru choke to open top tank, getting lots of crude & diesel in returns. Once returns were clean, brought returns thru poor boy degasser into pits and continued circulating to a full circulation to bottom GLM. Circulated at 2.5 BPM. Lost approx. 111 bbls SW to hole while circulatin . 04:30 06:00 1.50 PROD1 RPCOI\ OWFF T Monitor well. Blowdown lines to tank and pits. Finish loading tubing in pipe shed, stra same. Service ri . 06:00 09:00 3.00 PROD1 RPCOI\ OWFF T Crew change. Bleed off IA and monitor. Discuss options wI WO engineer state. Have gotten acceptance from AOGCC (Tom Maunder) to proceed with pulling completion without full BOP test. Will perform test as soon as conditions allow. 09:00 11:00 2.00 PROD1 RPCOI\ RURD T Decide to pull BPV and inspect. Circulate bottoms up (discussed w/ state rep Lou Gramaudi).Top off stack and watch fluid level drop through BPV. Pull BPV; appears in good sha e. Order out more fluid. 11:00 13:00 2.00 PROD1 RPCOI\ CIRC T 160 psi on IA. Circulate sw down tbg, up IA to tanks @ 4 bpm. Substantial amount of gas and crude strung out in rtns. 140 bbls away; shut down and monitor (50 bbl returned) while waiting on fluid. 13:00 14:00 1.00 PROD1 RPCOI\ NUND T Re-dress and re-set BPV / test dart. Closed blinds and attempted body test; same results, linear leak from 3500 psi. IA pressure has risen to 100 psi. Rig personnel repairing leaking ate valve in choke manifold. 14:00 17:00 3.00 PROD1 RPCOI\ CIRC T Seawater on location, bullhead 50 bbls sw into well down tbg @ 2.25 bpm. Begin taking rtns from lA, circulating @ 4 bpm until clean SW seen at tanks. Swap around and circulate remainder of hole volume back to pits. Floor hands rigging up cable sheave. (357 bbls pumped in this circulation, 214 lost downhole wI the 50 bbls bullheaded). 40 psi on well, bleed off and monitor. No flow, a ears dead. 17:00 19:30 2.50 PROD1 RPCOI\ PULD P Monitor well. RU floor & bring Baker tools to floor. MU TIW valve on joint of 3-1/2" DP. PU & MU Baker spear with ackoff on DP. 08/09/2006 19:30 20:30 1.00 PROD1 RPCOI\ OTHR P Stab spear into hanger and spear tubing approx. 15' below hanger. BOLDS. PU and hanger started out of bowl at approx. 65K# pull. Continue PU to 125K# (10K# Blocks). Continue working pipe to max. pull, not coming free. 20:30 21:30 1.00 PROD1 RPCOI\ OTHR P RU hose to TIW valve. Circulate at 2 BPM & work pipe up to 125K# max. pull. No progress. Circulated about 1/2 tubing volume with gas boiling in flow nipple, showed a 5 bbl gain in last few minutes. Relanded hanger & RILDS. 21:30 22:30 1.00 PROD1 RPCOI\ CIRC P Resume circulating taking returns thru choke and poor boy to pits. Packoff on s ear started leakin . 22:30 00:00 1.50 PROD1 RPCOI\ CIRC P Release spear and LD same. Packoff OK. Rebuilt 110 psi on IA while shut down, no tubing pressure. Close blinds and resume circulating, 3 BPM, 280 psi. Called out load of 9.6 ppg brine from tanks at KCS to blend with SW and wei ht s stem u to 8.8 08/10/2006 00:00 05:00 5.00 PROD1 RPCOI\ CIRC P Blend in brine to weight up to 8.8 ppg, continue circulating at 2 BPM to minimize loss to hole. Low on volume in pits. Call for more SW to blend with brine. 05:00 06:00 1.00 PROD1 RPCOI\ OTHR P Clean crude oil out of pits while waiting for SW to continue blending with brine to 8.8 ppg. SWarrived at 0530. Circulated 523 Bbls, losses increased to a rox. 75%, 392 Bbls lost. 06:00 09:30 3.50 PROD1 RPCOI\ CIRC P Discuss options w/ WO engineer. Order out more fluid. Begin circulating 8.8# brine at 2.0 bpm. Seeing heavy losses; unable to get brine back to surface with the volumes of fluid we have on location (8.4# back to pits). 50 bbls fluid remaining in pits. Bleed small amt of gas off IA to zero and monitor. IA=10 psi, tbg remaining at 0 si. 09:30 13:00 3.50 PROD1 RPCOI\ CIRC P IA pressure at 220 psi; begin mixing 30 bbl 3# Flo-Vis pill w/ 8.8# brine in pits. SW truck on location; top off pits with Sw. Brine wgt blended out to 8.5# in its. 08/10/2006 13:00 16:00 3.00 PROD1 RPCOII. CIRC P Begin to circulate 26 bbls 3# Flo-Vis pill @ 2.0 bpm, bleeding gaslcrude to tanks. Pill at open pocket, close choke and bullhead, displacing with Sw. Pill at perfs, see pressure bump. Tbg=200 psi, IA=180. Shut down and monitor. IA=140 psi, tbg=20. Bleed off. No flow; shut choke and monitor. Begin rigging up E-line while monitorin . 16:00 19:30 3.50 PROD1 RPCOII. CIRC P 45 minute shut in; IA=60 psi, tbg=10. Begin mixing 60 bbl 3# Flo-Vis pill. Circulate crude I gas to tanks; swap back to pits. 546 Bbls total lost s ottin ill and circulatin . 19:30 22:00 2.50 PROD1 RPCOII. OTHR P Monitor well. Transfer 60 Bbl Hi-Vis pill to truck. Top off pits with seawater. Line up to spot 60 Bbl pill. Pull top row of tubing out of shed. 20 si SITP, 0 siSICP. 22:00 23:30 1.50 PROD1 RPCOII. CIRC P Circulate 63 Bbls Hi-Vis pill into tubing, chase with SW to spot at bottom GLM @ 8743', circ @ 2 BPM. Shut in & bullhead pill to perfs, leaving tail at GLM, 2 BPM, small pressure increase as pill hit perfs, 340 psi to 380 psi. Total of 136 Bbls to formation s ottin and in'ectin ill. 23:30 00:00 0.50 PROD1 RPCOII. OTHR P Shut down and monitor well for 2 hour shut-in. ISIP's: 90 psi Tbg, 80 psi Csg. 30 min SIP's: 20 siTb ,60 si Cs . 08/11/200600:00 01:30 1.50 PROD1 RPCOII. OTHR P Shut-in well to let 63 Bbl Hi-Vis pill gel u . 2 hr SIP's: 0 si Tb , 70 si Cs . 01:30 04:30 3.00 PROD1 RPCOII. CIRC P PJSM. Circulate well thru open choke to open top tank, 3 BPM, getting approx. 55% returns. Continue getting crude in returns, with 8.4 ppg Sw. Saw some 8.8 ppg brine returns during circulation. Pumped 342 Bbls, lost a rox. 190 Bbls. 04:30 10:30 6.00 PROD1 RPCOII. OTHR P Shut-in & monitor well while cleaning crude off top of pits, bringing in more SW, and mixing 120 Bbls Hi-Vis slug w/3 b Flo-Vis. 10:30 11:30 1.00 PROD1 RPCOII. WOOR P Confer with WO engineer/M-1. Mix plant to batch 70 bbls calcium carbonate ill. Ri u to rev-circulate. 08/1112006 11 :30 15:30 4.00 PROD1 RPCOJl. WOEQ P Pill being mixed for plug perfs; PEAK truck on order to pick up pill. Waiting on fluid to arrival. Pill recipe: 1.2 ppb Flo- Vis 6 ppb Dual-Flo 7 ppb Safe-Carb 2 (D-10 to 0.5 m) - (D90-10m) 25 ppb Safe-Carb 10 (D-10 to 1.0) - (D90-25m) 9 ppb Safe-Carb 40 (D-10 to 2.2)- ((D90-120m) 17:30 18:30 1.00 70 bbl ill built PROD1 RPCOJl. RURD P Truck on location wI 70 bbl safe-carb pill. Conduct pre-job safety meeting. 340 psi on IA. Begin re-rigging to circ down tbg taking rtns to tanks. Discuss condition of ri crew with Tool usher. PROD1 RPCOJl. WOCC T Crew on shift has been on duty 20 hrs due to change-out I weather hold on flights; shut down and wait for relief to arrive. PROD1 RPCOJl. CIRC P SICP at 410 psi, 10 psi tbg. Begin circulating gaslcrude to to tanks @ 2.0 bpm; approx 25 bbls to surface, "clean" seawater to tanks. Shut down and re-rig to rev-circulate. Initial SICP=170 psi, 0 psi tbg. Online per pumping schedule; 15 bbls 3# Flo-Vls, 13 bbls Safe-Carb pill, 15 bbls 3# FLo-Vis followed by 239 bbls. Began bull heading down IA at 5000 away strokes (42 str/bbl) at 2.0 bpm (csg =280 psi, tbg=30 psi) increasing to 3.0 bpm (SICP=400 psi, tbg=260). Cont. pumping 10,000 strokes, drop rate to 2.0 bpm, csg=340, tbg=320. 11,000 strokes, drop rate to 1.0 bpm csg=21 0 psi, tbg=230. Pill across perfs, watch for pressure bump. None seen; 11890 strokes away. Shut down and monitor. csg=70 psi, tbg=50; still falling. Leave shut-in for 1.5 hrs. Csg=10 psi, Tbg=O si. 15:30 17:30 2.00 18:30 20:30 2.00 08/11/200620:30 23:30 3.00 PROD1 RPCO~ CIRC P Bleed off and blowdown lines. RU lines to circulate well, test line to 2500 psi. Open choke and break circulation down tubing, taking returns to open top tank, then into pits. Circ 2 BPM, 150 psi first 55 Bbls, no losses. Increased rate to 3 BPM, 330 psi to 290 psi, with intermittent slow losses, lost 35 Bbls total on circulation. Returns were clean until 20 Bbls before bottoms up, then got crude and gas in returns, took about 28 Bbls returns to tank to clean up, then finished circulation into pits. Continued seeing some crude in returns. 23:30 00:00 0.50 PROD1 RPCO~ OTHR P Shut-in and monitor well. Initial 1 0 psi Tbg, 30 psi Csg. 30 minutes: 0 psi Tbg, 20 psi Csg. Prepare to spot 25 Bbl Safe-Carb ill. 08/12/2006 00:00 01:45 1.75 PROD1 RPCO~ RURD P Monitor well & RU to reverse circulate pill, test line to 2500 psi. 0 psi Tbg, 10 si Cs 1 hr. PJSM. 01 :45 04:00 2.25 PROD1 RPCO~ CIRC P Reverse circulate 15 Bbls Hi-Vis spacer, 25 Bbls Safe-Carb Pill, 15 Bbls Hi-Vis spacer, followed by 148 Bbls SW, 2 BPM (lost 9.6 Bbls while reversing). SI & Bullhead to place pill in perfs. 35 Bbls @ 2 BPM, 230 psi to 330 psi lead spacer at perfs; 19 Bbls @ 1 BPM, 220 psi, some Pill in perfs; 3/4 BPM last 11 Bbls squeezing pill into perfs, 150 psi. No bump up. Stopped with back of pill between bottom of ESP Motor and top 'C' Sand Perf. 04:00 07:00 3.00 PROD1 RPCO~ OTHR P Shut down & leave well shut-in for pill to cure. 90 psi Tbg, 30 psi Csg at 10 min. 70 psi Tbg, 0 psi Csg at 2.5 hrs. RU lines to circulate. 08/1212006 07:00 10:45 3.75 PROD1 RPCOI\ CIRC P Begin to circulate, taking rtns initially to tanks - clean fluid. Swap back and begin circulating to pits. Initial pressures SICP=O, Tbg=10. Online @ 2.0 bpm, IA=10 psi, tbg=130. 20 bbls away, 4 bbl loss (majority of the loss in initial 1 0 bbls). Increase rate to 3 bpm; 60 bbls away, 6 bbl tot loss IA=10, tbg=300 (maj or losses in first 5 bbls). Increase rate to 4 bpm; 100 bbls away IA=40 psi, tbg=500. Losses increasing averaging 15%; cont. circulating. Bttms up, small amt crude/gas in rtns; divert to tank until clean. Continue w/ hole circulation at 3.0 bpm. Shut down and monitor SICP=50 psi, tbg=20 psi. 39 bbls lost during circ. After 1.5 hr shut in SICP=10, Tb =0. Bleed off, no flow. 10:45 12 :45 2.00 PROD1 RPCOI\ CIRC P Circ across the top of the hole and establish rloss rate = 3 bph. Call out SLB E-line to finish rigging up for jet-cut. Stop circulating across top of hole and resume monitoring. Well dead, bleed small amt of as off IA. 12:45 17:45 5.00 PROD1 RPCOI\ CIRC P Rigging up SLB E-line equipment; continue to monitor well. Tbg=O, IA has small amount of gas, crude. Bleed approx 1 bbl off; rate not dropping off. Circulate bottoms up at 3 bpm; losing 10% rtns. Again, divert to tanks with crudelgas when bottoms up is at surface. Clean fluid, resume taking to pits, stop circulating and shut in well to monitor. SICP=40 psi, SITP=20. Begin weighing up pits to 8.7#. Order out additional load of 9.6 brine for make-u . 17:45 19:30 1.75 PROD1 RPCOI\ OTHR P Weight up surface system to 8.7 ppg. 19:30 23:00 3.50 PROD1 RPCOI\ CIRC P Open well, no pressure. Circualte 8.7 ppg brine into hole, taking returns thru open choke to pits. Weight up SW returns to 8.7 ppg while circulating. Continue circulating until good 8.7 ppg returns at surface. Circulated 430 Bbls total, 2 BPM, lost 70 Bbls on circulation. 23:00 00:00 1.00 PROD1 RPCOI\ OTHR P Monitor well, no flow. Open blinds and keep hole full circualting across top of hole. First hour losses at 42 BPH. Continue monitoring loss. Fill pits with SW and and weight up same to 8.7 08/1312006 00:00 03:00 3.00 PROD1 RPCO~ OTHR P Continue monitoring losses, keeping hole full by GÌrculating across the top. Initial loss rate at 42 BPH, gradually slowed to 36 BPH. then 30 BPH. Maintaining 8.7 ppg in pits mixing brine and SWas needed. 03:00 05:00 2.00 PROD1 RPCO~ OTHR P Continue monitoring losses. Losing 30 BPH to 27 BPH. Call out SWS. 05:00 07:30 2.50 PROD1 RPCO~ RURD P Losses tapering off, now averaging 24 bph. SLB E-line on location rigging up. Monitor IA 1 tbg small amt of gas buildin on IA. 07:30 09:30 2.00 PROD1 RPCO~ PERF P RIH wI 2.5" SLB PowerJet jet cutter. Setting down on the collars on the way in hole. Set down at approx 5030', unable to make hole. Pull out of hole, reconfig tool string (add wgt bar, 2.65 rollers, remove centralizers), and troubleshoot short in tool head. 09:30 11:30 2.00 PROD1 RPCO~ PERF T RBIH wi 2.5" jet cutter. Tag bottom at 8817'. Tie into tubing tally and attempt cut at 8811'. Call out FMC rep. Pull out of hole wi E-line and rig equipment out of the way. Begin moving fishing equipment up to floor. Losses to well averaging approx 22 bbls/hr. At surface with jet cutter; Inspection of jet cutter shows tool did not fire. Loose wire cause tool to short. 11:30 15:30 4.00 PROD1 RPCO~ PERF P RIH wI 2.5" jet cutter. Tie into tally and cut at 8811'. Pooh. At surface, tools show cutter fired. Lay down E-line e ui ment and re to sear strin . 15:30 19:00 3.50 PROD1 RPCO~ OTHR P Make up 3-112" dual-grapple spear to joint of 3-1/2" IF. Install headpinlTlW valve. Check SICP= vac, tbg=O psi. Back out lockdowns, RIH wI spear and latch. Pick up 126K (11k blocks) and unland hanger; fill hole watch level. Gas breaking out, fluid falling. Begin working pipe; unable to get tbg broke loose. No upward movent on pipe. Set hanger back in bowl, run in lockdowns and re are to rev-circulate LCM ill. 19:00 20:30 1.50 PROD1 RPCO~ RURD P RU lines to reverse circulate. PJSM. 08/13/2006 20:30 23:30 3.00 PROD1 RPCOII. CIRC P Reverse circulate 5 Bbls Hi-Vis Spacer, 30 Bbl Pill with 50 ppb Safe-Carb, 5 Bbls Hi-Vis spacer. Switch to 8.7 ppg brine and reverse 174 Bbls, taking returns from tubing thru open choke to pits. Shut-in and bullhead pill into place in 'C' Sand: 2BPM, 260 psi until Lead Spacer at perfs; 1 BPM, 150 psi until pill covered perfs, 1/2 BPM, 60 psi until tail end of pill at bottom of ESP Motor. Shut down. ISIP 40 si, 0 si in 5 minutes. PROD1 RPCOII. OTHR P Leave well shut-in. Will fill hole in 2 hrs to monitor losses. PROD1 RPCOII. OWFF P Leave well shut-in until 0130 (2 hr SI). Open well and fill riser up to flow line with 8 bbls (-3.5 bbl for riser, 4.5 bbl to fill hole), refill after w/5 bbl in 7 minutes, initial loss rate 43 BPH. Continue monitoring losses while circulating across the top of the hole. Losses slowed from 40 BPH to 23 BPH in first hour, then steadily dropped to 16 BPH by 06:30. Make re arations to mix "stout" LCM ill. PROD1 RPCOII. OTHR P Discuss options with WO engineer. Circualting across top of hole, losses steady at 20 bph. Mud plant mixing LCM pill, begin viscositying system to 1.5 ppb wI Flo-Vis, 4 ppb Dual-Flo starch . Waitin LCM ill to arrive. PROD1 RPCOII. CIRC P Pit system viscosified; begin circulating at 2.0 bpm to viscosity what's in the hole. Initial losses at 16 bph while circulating across top. Vac truck with pill on location. Spot up to pump. LCM Pill recipe: 1.5 ppb Flo-Vis 7.0 ppb Dual-Flo 50 ppb Safe-Carb 20 50 ppb Safe-Carb 40 12.5 ppb Safe-Carb 250 12.5 ppb Safe-Carb 1000 Sightglasses in vac truck not tracking do to viscosity; appear to have 80 bbls loaded into truck. 23:30 00:00 0.50 08/14/200600:00 06:00 6.00 06:00 12:00 6.00 12:00 14:00 2.00 08/1412006 14:00 16:00 2.00 PROD1 RPCOI\ CIRC P Conduct pre-job safety meeting. Initial SICP=O, tbg=O psi. Online wI LCM pill down tbg at 2 bpm, taking rtns to pits Initial circulating pressures IA=10, tbg=80. 2540 strokes (42 strokes/bbl), begin bullheading. Tbg=250 psi, have discovered IA pressure blocked, open and continue. Sight glass in vac truck doghouse has blown out while pushing fluid to rig; shut down and verify condition of driver - ok. Resume pumping. At 3800 strokes (85 bbl pill), begin chasing wI viscosified brine. Shut down at 7204 strokes. 5200 strokes away, IA=200, Tbg=420. 6000 strokes away, IA=250, Tbg=450 6900 strokes away, IA=290, Tbg=480 7200 strokes awa ,IA=300, Tb =500 16:00 19:30 3.50 PROD1 RPCOI\ CIRC P Shut down and monitor. 30 mins shut in tbg=O psi, IA=30. Begin circulating while finishing viscosifying remainder of system. 17:00-17:30 loss =6 bbls. 17:30-18:00 loss=2 bbls. Continue circulating 8.7 ppg viscosified brine, 2 BPM, returns thru open choke and degasser to pits, pressure increased gradually from 220 psi to 530 psi as viscous brine was circulated around. lost 36 Bbls on circulation, loss rate increased to about 24 BPH last 30 minutes. 19:30 22:30 3.00 PROD1 RPCOI\ OWFF Shut down and keep hole full circulating across top. Showed 1 Bbl gain when pump stopped in first hour. Shut down fill up to observe well, 30 minutes, no flow, no loss, well static. Resume fill across top, 3 Bblloss in 30 minutes (likely mostly filling surface lines. 22:30 00:00 1.50 PROD1 RPCOI\ CIRC Resume circulating at 1 BPM to 1.5 BPM, 490 psi to 550 psi, then to 470 psi after 60-70 sec Visc brine returned to surface, Circulated 120 Bbls, lost 33 bbls. Shut down and monitored well while re are to RU SWS. 08/15/2006 00:00 02:30 2.50 PROD1 RPCOI\ OTHR P PJSM. RU SWS. PU shooting nipple with donut and set in riser on slips, MU E-line BOPs. Run tool string with 2-1/2" SLB PowerJet Jet Cutter into shooting nipple. PU shooting nipple with blocks and stab cutter into tubing and RIH -200'. Lower lubricator into stack, close bag, and pull donut up to bag and secure. RIH and tie-in to tubing detail and GLM @ 3296'. Cut tubing at 3330' MDIELM, near middle of first full joint below GPM, leaving about 14' stub. Good indications of shot at surface. POH, cutter fired. Ri SWS aside. 02:30 04:30 2.00 PROD1 RPCOI\ PULD P PU spear & MU on joint of 3-1/2" DP. Stab spear into hanger and tubing. BOLDS. PU and hanger started moving out of head at 50K# PU, continued up -5' at 57K#, pipe free 10K# Block Wt. Reland han er. 04:30 05:00 0.50 PROD1 RPCOI\ RURD P RD SWS and move equipment off rig. 05:00 07:00 2.00 PROD1 RPCOI\ PULD P Pull tubing hanger above floor, 57K# PU weight dropped to 51 K#. probably indicating breaking ESP Power Cable. Disconnect penetrators in hanger and cut ESP cable. LD spear and joint of DP. Break out and LD tubing hanger and pup. Gas breaking out and rolling fluid in riser after hanger was pulled out of tubing head. Rolling action increasing, no gain or loss. MU TIW valve and XO into tubing & MU circulating hose. PU and cut off 30' of ESP cable at clamp to secure cable. Set back down to floor so cable is below rams. Rolling fluid action in riser due to gas breaking out still increasing. No gain, possible slight loss at this oint. 07:00 09:00 2.00 PROD1 RPCOI\ CIRC P Circulate 2 bottoms up at 3330' cut depth, 3 BPM, 230 psi, 8.7 ppg in & out, 1-2 Bbl gain during initial circulating, overall 2 Bblloss while circulating. Observe well 25 minutes, fluid level slowly rising in flow nipple.. Circulate another 55 Bbls, 3 BPM, 220 psi, no gain or loss. Gas continues rollin in riser. 08/15/2006 09:00 11:00 2.00 PROD1 RPCOI\ OTHR T Shut down and monitor pressures. Order 290 Bbls of Viscosified 9.6 ppg brine from MI Mud Plant. Empty one pit of 8.7 ppg Visc brine to outside tank. Bring in 110 Bbls of 9.6 ppg brine and mix in Flo Vis and Dual-Flo. Blend with remaining surface volume and bring weight up to 9.6 ppg. 8:50 Shut in well to monitor 9:00 Tbg=10, IA=50 9:10 Tbg=20, IA=70 9:20 Tbg=30. JA=90 9:30 Tbg=40, IA=100 9:40 Tbg=50, IA=110 9:50 Tbg=50. IA=11 0 10:00 Tbg=50, IA=11 0 10:30 Tbg=50. IA=130 11 :00 Tb =60,IA=160 11:00 17:00 6.00 PROD1 RPCOI\ OTHR T Continue to monitor tubing and IA pressures while waiting on 9.6 ppg fluids from Prudhoe. Finish weighting up surface volume to 9.6 ppg. 12:00 - Tbg=60. IA=180 114:00- Tbg=50, IA=190 116:00 - Tbg=50, IA=240. 290 Bbls of Viscositid 9.6 ppg brine on location, held PJSM. 17:00 18:00 1.00 PROD1 RPCOI\ CIRC T Start pumping 9.6 ppg kill weight fluid down tubing, taking 8.7 ppg returns thru choke to open top tank. total volume tubing/lA to cut depth of 3330' is 117 bb/s. 3 BPM, 220 psi to 280 psi pump pressure, took 7 Bbls to get returns bleeding gas head off annulus, probably about half that to fill hole. Held back pressure with choke, 90 spi down to 50 psi until 9.6 ppg returned to surface, then brought returns thru poor boy degasser into pits thru open choke, 40 psi back pressure minimum. Circulated an additional tubing volume to 3330' cut depth. Shut down pump. Lost 20 Bbls while circu/atin . 18:00 19:30 1.50 PROD1 RPCOI\ OWFF T Slowly bleed off remaining pressures (40 psi trapped on annulus due to choke line friction) and monitor for flow. no flow. 08/15/2006 19:30 00:00 4.50 PROD1 RPCOII. OWFF T Open bag and fill up stack to flow line, 4 Bbls to fill hole. Gas still breaking out and rolling fluid in riser, but at slower rate. Observe well and fill hole as level in stack falls. Hole losing 6 Bbl to 8 Bbl per hour. Gas rolling about the same, or slightly less. 38 Bbls lost in 4.5 hrs, as of midnight. Change out valve in choke manifold while monitorin well. 08/16/200600:00 05:30 5.50 PROD1 RPCOII. OWFF T Continue monitoring well, gas rolling in stack diminished about 75%, total loss while monitoring, 89 Bbls. Finish replacing valve in choke manifold, test flanges to 3500 psi, OK. Dig hole by cellar for mousehole. 05:30 06:30 1.00 PROD1 RPCOII. CIRC T Circulate once around to assure clean 9.6 ppg in & out, 148 Bbls, 3 - 4 BPM, lost 15 Bbls while circulating. Record slow pump rates and pressures. Observe well, slow loss. 06:30 10:00 3.50 PROD1 RPCOII. PULD P LD 2 joints of 3-1/2" tubing and GLM. PU & MU new tubing hanger. Install BPV and blanking plug with landing joint. Land hanger, RILDS. Rotate off of blanking plug and lay down landing ·oint. 10:00 14:00 4.00 PROD1 RPCOII. RURD P Hook up hose to annulus, fill and monitor annulus.Continue monitoring fluid losses, losses have been 8-10 bph most of the day, Make up kelly, torque connections. MU ported test sub and test ·oint. Pre are to test. 14:00 19:30 5.50 PROD1 WELC1 BOPE P Perform BOP test to 250/3500psi, annular to 250/2500 psi. Witnessing of test waived by John Crisp, AOGCC Field Inspector. Continue filling hole on annnulus while testing. Total loss from 0600 to 1800, 130 Bbls. 19:30 20:00 0.50 PROD1 RPCOII. RURD P PJSM. Stand back Kelly. LD test ·oint. 20:00 22:30 2.50 PROD1 RPCOII. RURD P PU landing joint. Retrieve blanking plug. RU lubricator and pull BPV. LD lubricator. Lost 34 Bbls from 1800 to 2300. 22:30 00:00 1.50 PROD1 RPCOII. CIRC P Close blinds. Circulate once around to cut to assure good 9.6 ppg in & out, 3 BPM, 250 psi, taking returns thru open choke and poor boy de gasser to pits. Lost 15 Bbls while circulatin . 08/17/200600:00 01:30 1.50 PROD1 RPCOII. PULD P PJSM. PU & MU landing joint. BOLDS. Pull hanger to floor and LD same. (Note: Old Tubing Hanger, 2 joints of Tubing, and one GLM already LD . 08/1712006 01 :30 13:00 11.50 PROD1 RPCOfl. PULD P POH LD tubing and GLMs, spool up ESP cable, and removing clamps. Continue to monitor fluid losses, still between 5-8 BPH. Light scale on outside tubin . 13:00 14:30 1.50 PROD1 RPCOfl. PULD P On surface with completion to cut @ 3330'. Length of cut joint is 16.81', cut joint is flared and split to 5" aD. Recovered ESP cable hanging 8' below cut joint. Clean & clear rig floor for make u of mill BHA. 14:30 15:30 1.00 PROD1 RPCOfl. OTHR P Install wear ring 15:30 19:30 4.00 PROD1 FISH PULD P Bring Baker fishing tools to rig floor. Make up BHA #1 (Dressing Mill Assy). PU 6 Drill Collars. BHA #1 is as follows 61/8" x 3.5" mill shoe/5.75" wash pipe extension/ 5.75" wash over boot! double pin connectorl two 4.75" boot junk sub/ bit sub/4. 75" bumper sub/4.75" oil jars/ 4.75" pump out subl 64.75" drill collars/ 3-1/2 IF x 3-1/2 PH-6 Crossover. 19:30 20:30 1.00 PROD1 FISH RURD P RU tongs to run PH-6 work string. MU XO. 20:30 00:00 3.50 PROD1 FISH PULD P PJSM. RIH with BHA #1, PU 3-1/2", 12.95#, P-110/N-80, PH-6 work string. 60 joints picked up at 2400 hrs, a rox. shoe de th 2100'. 08/18/2006 00:00 02:00 2.00 PROD1 FISH PULD P Continue RIH wI BHA #1 (Dressing Mill Assy), PU 3-1/2" PH-6 work string. Tag top of cut-off stub at 3323' Nabors RT. 02:00 03:00 1.00 PROD1 FISH OTHR P PU Kelly out of mouse hole. MU Kell . 51K# PU 1M., 34K# SO 1M. 03:00 04:30 1.50 PROD1 FISH MILL P Break circulation, 3 BPM, 270 psi. Wash & mill over cut-off tubing stub from 3323' to 3329', dressing stub to 3-1/2" OD. Saw pieces of insulation and copper over shaker from ESP cable while dressing stub. Pressure increased up to 600 psi, indicating cable wrapped around stub and inside tapered mill throat. Dressed off 6' of stub, then worked off and back over stub to be sure it was clean. Total fluid lost while circulating 31.5 Bbls, circulated 255 Bbls, 1.5 hours. 04:30 06:00 1.50 PROD1 FISH OTHR P Monitor hole. PJSM. Blow down & set back Kelly. PU 1 joint of PH-6. Pull u stand & set Crown-O-Matic. 06:00 11:00 5.00 PROD1 FISH TRIP P POOH wI mill assembly, standing back PH-6. Continue to monitor well and fluid loses. Loses still around 6-8 BPH. 08/1812006 11 :00 13:00 2.00 PROD1 FISH PULD P Stand aside DC. LD pump out sub, bumper, and jars. On surface with mill assembly, appears mill engaged 5-5.5' of fish stub, recovered small amount of cable debris in mill, lay down mill assembly. Clear floor. Bring in new Baker tools. 13:00 14:00 1.00 PROD1 FISH PULD P MU BHA #2 - Overshot Guide + Overshot wI packoff & 3-1/2" Grapple + Extension + Top Sub + XO to PH-6. Can swallow 5-1/2" of tubin stub. 14:00 17:30 3.50 PROD1 FISH TRIP P RIH w/3.5" PH-6 overshot BHA, crossover/5.75" top sub/ 5.75" over shot extension/5.75" overshot with 3.5" grapple/5.75" overshot guide (total len th BHA 8.27' 17:30 18:00 0.50 PROD1 FISH PULD P MU crossover & 2 - 3-1/2" EUE-8Rd, L-80 pups to catch fish at a good working height. MU full opening valve and circulating hose. 40K# PU, 32K# SO Wt, 10K# Blocks. 18:00 19:30 1.50 PROD1 FISH FISH P Slide overshot over top of fish at 3323', and swallow 5-1/2' to 3328'. PU and engage fish. Work pipe, increase pull up to 164K#, 124K# overpull on fish. Continue working various block speeds between 60K# and 164K#. No ro ress. 19:30 23:00 3.50 PROD1 FISH FISH P Break circulation at 2 BPM and work pipe. Plugging off, initial pressure 500 psi to 600 psi for about 10 Bbls, then fluctuated between 600 psi and 1100 psi, pressured up to 1700 psi at 30 Bbls pumped. Shut off pump and saw only slow bleed off. RU lines & reverse circulate 71 Bbls, 2 BPM, 270 psi to 340 psi. Reversed freely, no indication of plugging, probably reversing thru packoff on Overshot. Attempt to circulate down tubing, pressured up to 600 psi immediately, shut down pump, slow bleed off. Work pipe, pull up to 167K#, 127K# overpull on fish (90% of J-55 strength), no progress. RD and blow down circulatin lines. 23:00 00:00 1.00 PROD1 FISH OTHR T Monitor well. Move SWS unit to end of pad. Prepare to RU slickline. Wait for HES Unit to arrive. 08/1912006 00:00 02:30 2.50 PROD1 FISH OTHR T Wait for slickline unit to arrive. Back in & spot HES slickline unit. PJSM with HES & ri crew on ri floor. 02:30 04:00 1.50 PROD1 FISH RURD T RU HES slickline. PU bailer tool strin . 08/19/200604:00 07:00 3.00 PROD1 FISH SLKL T Slickline "crowned out" in top sheave held in blocks while picking up tool string to start in hole. Parted line at sheave and dropped tool string to rig floor, packoff and Otis union half landed beside driller's console. Tool string layed over against windwalls. No injuries. Some damage to slickline tools, no apparent rig damage. Secure well and suspend operations to examine and investigate near miss. Prepare to pick up tool string and replace damaged tools, to resume o erations. 07:00 08:00 1.00 PROD1 FISH SFTY T Held incident review 08:00 10:00 2.00 PROD1 FISH SLKL T Held PJSM safety meeting, Rig up HES slickline. 10:00 17:00 7.00 PROD1 FISH SLKL T RIH wI slickline and 2.5" DD bailer to 8739'wlm. Encountered restrictions @ 6879',6943',7134',7768'. But able to work down to 8739'wlm. Attempted to circulate long way, but unable to maintain 1 BPM rate without pressuring up to 1300 psi, Able to maintain rate of .5 BPM @ 550 psi, with little returns on lA, pumped 20 BBLS total. POOH wI bailer, bailer had small amount of ESP cable protective coatin ,Ri down Slickline. 17:00 18:00 1.00 PROD1 FISH CIRC T Isolate tubing and bullhead 20 bbls down IA, to verify IA is clear. Maximum ressure seen, 550 si. 18:00 23:00 5.00 PROD1 FISH ELNE T Change to long bails. Spot SWS e-line unit. Rig up SWS E-Llne for tubing perforation. RIH with 1-11/16" tubing punch. Ran tools to 8783', did not tag bottom. Tied into 10' pup and bottom GLM @ 8743'. Pulled up and set gun in middle of 3rd joint above GLM. Perforated tubing from 8668' to 8770' with 9 holes, 2 ft @ 4 SPF, In-Line shots, decentralized, towards low side. POH, all shots fired. LD tubin unch tools. 23:00 00:00 1.00 PROD1 FISH RU lines to circulate. Break circulation at 1/2 BPM, 250 psi, pressure fluctuated up to 530 psi, then broke back to 410 psi, then back to 250 psi in first 10 Bbls. At 20 Bbls pumped, increased rate to 1 BPM,410 psi, as of midnight. No returns at 1/2 BPM, but fluid not falling in annulus. Slow returns at 1 BPM. (Continued circulatin 08/20/2006 00:00 06:00 6.00 PROD1 FISH CIRC P Continue circulating surface to surface, stage rates up to 2 BPM, 800 psi final circulating pressure. Allowed for 170 Bbls fluid lost while circulating. Had periodic plugging of holes throughout circulation, back-surged tubing twice to help remove plugging. Final returns were clean 9.6 in and out. 06:00 09:00 3.00 PROD1 FISH ELNE P Fluid loses continue to be 8 BPH, SWS makes crew change, prep tools for free oint run, Ri u SWS E-line. 09:00 16:00 7.00 PROD1 FISH ELNE P RIH wI SWS E-Line tools (free point) to 5000', pullled up to 25K over string weight of 105K at each check point. 100% movement at 5000', 6000', and 6745'.80% movement at 7500'.20% movement at 8700'.0% movement at 8780'. Come back OOH making stops. 30% movement @ 8645'. 45% movement at 8320'.60% movement at 8000'.73% movement at 7760'.80% movement at 7665. POOH w/ E-line. 16:00 23:30 7.50 PROD1 FISH ELNE P LD free point tools. Set sheave an floor. PU 120K# on string and set weight on slips. Rig -up SWS tools for string shot. RIH and fire string shot across planned cut pint at 8487', middle of a full joint. POH - misfire. Change out firing system parts and re-run string shot. Fire string shot across cut point at 8487'. POH, shot fired, OK. LD strin shot. 23:30 00:00 0.50 PROD1 FISH ELNE P Set sheave on floor. PU on string to 140K# and set weight on slips, for making chemical cut. PU sheave in blocks. 08/21/2006 00:00 03:30 3.50 PROD1 FISH ELNE P PJSM. MU chemical cutter. RIH, tie in, and cut tubing at 8487' MD. POH, LD sent cutter. Set sheave on floor. 03:30 04:00 0.50 PROD1 FISH FISH P PU on pipe and started moving up hole at 127K#, 140K# max pull seen. Chan e bails & elevators. 04:00 04:30 0.50 PROD1 FISH CIRC P RU lines & break circulation, 2 BPM, 340 psi. Pumped 20 Bbls. Shut down to check suction valves on mud um . 04:30 06:00 1.50 PROD1 FISH RURD P RD SWS. Release SWS E-line. LD long bails off floor. Pull debris out of suction valve on pump. Clean and reinstall suction screens. 06:00 08:00 2.00 PROD1 FISH CIRC P Circulate once around to clean hole, 3 BPM, 490 psi, increased rate to 4 BPM, 650 psi. Lost about 25 BPH while circulating at 3 BPM. Monitor well. 08/21/2006 08:00 13:30 5.50 PROD1 FISH TRIP P POOH wI PH-6 work string and 3.5" ESP completion, first two stands pulling @ 135K#, then drop off to 125K#. 13:30 15:00 1.50 PROD1 FISH CIRC T On stand 50, started getting some migrating gas to surface (kick), had to close bag and circulate bottoms up. Notified AOGCC (Jeff Jones). Will need to do a BOP test when we get to surface with com lete. 15:00 16:00 1.00 PROD1 FISH TRIP P Continue out of hole. 16:00 17:30 1.50 PROD1 FISH PULD P On surface with overshot, ESP cable tightly wrapped around pipe, lay down overshot, change out elevators, prep ri for ESP s oolin . 17:30 18:00 0.50 PROD1 FISH SFTY P Held pre-job safety meeting with rig crew/Centriliftls ooler. 18:00 00:00 6.00 PROD1 RPCOFl. PULD P Continue OOH laying down 3.5" ESP completion. Scale caoting tubing, ESP cable, and clamps. Crew has to clean clamps or chisel off bolts due to scale. ESP cable also loading up sheave aand crew having to knock it out periodically. Beating scale off connections to get tongs to bite. 56 . oints laid down at midni ht. 08/2212006 00:00 12:00 12.00 PROD1 RPCOFl. PULD P Continue POOH LD tubing, GLMs, spooling up ESP cable. Note: Scale on tubing/cable/clamps was heaviest at the production mandrel @ 6488'MD. But only light scale on last 30 joints. On surface with fish. Chemical cut 17.5' down on joint number 270, good clean cut. ESP cable pulled apart several feet below cut. 12:00 16:30 4.50 PROD1 RPCOFl. RURD P Lay down ESP spooling equipment, clean rig floor and work area, jet out BOP stack prior to BOP test. Remove wear ring. Make up test plug, install safet valve/dart valve. 16:30 20:30 4.00 PROD1 WELCT BOPE P Perform BOP test 250/3500 psi; annular 250/2500 psi. BOP Test waived by Jeff Jones (AOGCC) 15:30 on 8/22/06. Fluid losses for 24 hrs = 178 bbls. 20:30 22:00 1.50 PROD1 WELCT BOPE NP Re-tested choke manifold valves. 22:00 00:00 2.00 PROD1 WELCT BOPE P Blow down hose flannulus, pull test lu and install wear rin . 08/23/2006 00:00 01:30 1.50 PROD1 WELCT BOPE P Complete weekly BOPE test, including testin Kell . 01:30 04:30 3.00 PROD1 FISH PULD P MU BHA ( Mill shoe, washover boot, junk basket, 7" casing scraper, jars and bum er sub . 04:30 12:30 8.00 PROD1 FISH TRIP P RIH with BHA on workstring for cleanout run. 08/23/2006 12:30 14:00 1.50 PROD1 FISH CIRC P Encountered scale from 6350' to 6490' MD, worked pipe thru this area, circulate bottoms up at 3 BPM, lost 45 BBLS durin circulation. 14:00 17:00 3.00 PROD1 FISH TRIP P Continue in hole with BHA, tag top of fish @ 8483' MD, 10' down on joint 265, up weight 102K. Fluid loses continue to be 6-8 BPH. 17:00 18:00 1.00 PROD1 FISH RURD P Lay down joint 265, make up kelly. 18:00 19:00 1.00 PROD1 FISH WASH P Establish circulation 3 BPM with 800 psi. Tagged up @ 8483'. Lowered mill down over tubing stub and pressure would go up to 1100 psi. Milled over the stub down to 8488' w/2K to 5K down and 5K torque. Unable to mill ast 8488' stackin out on drive sub. 19:00 21:00 2.00 PROD1 FISH CIRC P PU to neutral wt. Circulate hole clean. Not much scale in returns mostly scraps from the old electric insulation and armor from ESP cable. Lost 47 bbls fluid durin clean out. 21:00 00:00 3.00 PROD1 FISH TRIP P Stand back Kelly and start pulling out of hole standin back workstrin . 08/24/2006 00:00 04:00 4.00 PROD1 FISH TRIP P Continue to POH standing back workstrin and drill collars. 04:00 06:30 2.50 PROD1 FISH PULD P Break out and Lay down casing scraper, boot baskets and mill shoe, clean out junk basket, lots of cable debris in basket, clean ri floor. 06:30 09:00 2.50 PROD1 FISH PULD P MU BHA consisting of 5-3/4" overshot w/3-1/2" grapel, bumper sub and h draulic ·ars. 09:00 15:00 6.00 0 8,458 PROD1 FISH TRIP P RIH w/ overshot BHA on PH-6 to 8480'MD, total of 132 stands. 15:00 16:30 1.50 8,458 8,480 PROD1 FISH RURD P Check weight, Up weight 97K, Down weight 55K, Pick up two pup joints totaling 28', add headpin and circulating hose, circulate min. rate 1/2 BPM 280 psi, engage fish, pressure coming up to 540 psi, shut down um ,fish latched. 16:30 17:00 0.50 8,480 8,480 PROD1 FISH FISH P Got total of 10 jar licks to 60K over string in 10K increases, fish came free, string weight 112K, monitor well condition 15 mins. 17:00 19:30 2.50 8,480 8,480 PROD1 FISH TRIP P RD circulating hose and head pin. LD pup jts used for space out for jarring. MU tools for pulling workstring and fish out of hole. Drop rod for pump out sub. Pumped down and sheared out. Pullin wet, um ed 25 bbl d ·ob. 19:30 00:00 4.50 8,480 2,600 PROD1 FISH Start pulling out of hole standing back workstring. 94 stands out at midnight. Fluid losses for last 24 hrs = 89 bbls. 08/25/2006 00:00 02:00 2.00 2,600 0 PROD1 FISH TRIP P Continue POH standing back workstrin . 02:00 06:00 4.00 0 PROD1 FISH PULL P Stand back drill collars. LD BHA Oars, bumper sub, overshot) with 10-' cutoff. Also retrieved 8 jts 3-1/2" tubing, 1- 3-1/2" GLM, 10' pupjt, 1&1/2jts 3-1/2" tubing with Sentry Guage clamped on. Bottom of cut flared out from jet cut (@8811'), and ESP cable pulled apart 20' below cut. Left in hole to fish is 10' cut off piece of 3-1/2" tubing, "D" Nipple, 4' pup, 10' pup, ESP Tandem Pump, Intake Seal, and Motor, 138' total left in hole. 06:00 07:30 1.50 PROD1 FISH PULD P Lay down overshot BHA and tubing stub. 07:30 08:00 0.50 PROD1 FISH SFTY P PJSM, clear rig floor, monitor well. 08:00 10:00 2.00 PROD1 FISH PULD P Make up spear BHA, spearl 4.75" bumper subl 4.75" oil jarsl 4.75" pump out sub/4.75" six drill colllarsl 4.75" intensifirel crossover. 10:00 16:30 6.50 0 8,811 PROD1 FISH TRIP P RIH wI spear BHA on PH-6 workstring to 8811' MD. 16:30 20:30 4.00 8,811 8,811 PROD1 FISH JAR P Tagged fish at 8806' drill pipe measurement. RU pump in sub, broke circulation @ 2 BPM 740 psi. Up Wt 102K Dwn Wt 58K. Washed into fish. Latched spear, pulled 20K over with jars (122K). Slacked off, loaded jars, start jarring with 20K over. Worked up to 50K over in 10K increments. Fish came loose @ 50K overpull (152k total wt). Pulled 10' slacked back down took wt at same depth as latching spear. PU pulled 152K, jarrred fish came free again. Pull another 20' saw 18K and 48k overpull, dropped off as we pulled. Monitored well, well took about 5 bbls. RD pump in sub and pup jts. RU to POOH. Inspect derrick after' arrin . 20:30 00:00 3.50 8,811 5,657 PROD1 FISH PULL P POH standing back workstring. Dropped dart for pump out sub. Attempted to pump and shear with no luck. Continued to pull wet. Pull 1 0 more stands. Pressured up, sheared pump out sub w/21 00 psi. Continue to POOH wet, fluid losses for last 24 hrs = 83 bbls 08/261200600:00 05:00 5.00 5,657 0 PROD1 FISH PULL P Continue POH with fish on spear, standing back workstring. Stand back collars. 05:00 07:30 2.50 0 PROD1 FISH PULD P Lay down fishing spear BHA, drill collars, etc. Fishing spear empty, no recove 08/2612006 07:30 08:30 1.00 PROD1 FISH RURD P Lay down elephant truck and ESP sheave from ri floor, clear ri floor. 08:30 12:30 4.00 PROD1 FISH WOEQ P While waiting on jars from prudhoe, cut 100' of cable from drill line, inspect brake pads, linkage, and adjust rollers. Baker jars on location at 10:00 am. Ad'ust brakes and linka e. 12:30 16:00 3.50 PROD1 FISH PULD P Make up milllovershot BHA, 5.75" cut lip guide/5.75" hollow mill container/5.75" overshot w/3.5" grapple/ 5.75" overshot extension/ 5.75" overshot top sub/ 4.75" bumper subl 4.75" oil jarsl 4.75" pump out subl 64.75" drill collarsl crossover. 16:00 22:00 6.00 0 8,806 PROD1 FISH TRIP P RIH wI Hollow milllovershot BHA on PH-6 to 8806' MD 22:00 00:00 2.00 8,806 PROD1 FISH MILL P Spaced out, PU and MU Kelly. Established circulation @ 4 BPM w/600 psi. Up Wt = 1 02K Dwn Wt.=58K. Lowered kelly and tagged top offish @ 8806'. Milled over approx. 8" to dress up the 3-1/2" stub looking up. Swallowed 8' of tubing and latched on with Grapple. Started jarring w/30K over increasing by 10K incriments. Pulled fish loose with 155K approx. 50K over. Pulled up 10' above ori inal ta and had 12K over. 08/27/200600:00 03:00 3.00 PROD1 FISH RURD P Break out and lay down Kelly. Break out u s. 03:00 10:30 7.50 8,806 0 PROD1 FISH TRIP P Start pulling out of hole standing back workstring. Pulling 10K over coming out. Slow oin , ullin out wet. 10:30 11:30 1.00 0 PROD1 FISH PULD P Lay down intensifire, stand back drill collars. 11:30 14:30 3.00 PROD1 FISH PULD P Lay down rest of fishing assembly and ESP assembly. Medium scale build up on ESP pump assembly, fish came apart at bolted flange between lower pump and intake seal section, leaving seal section/upper & lower motor with 6" centralizer in hole total length 62.95'. Only two of eight flat guards recovered and no carbon steel band recovered, approximately 14' of motor lead cable attached to motor. 14:30 17:30 3.00 PROD1 FISH PULD P Make up scraperlbit BHA. 6.125" bit/5 3/8" casing scraperl bit subl 4.75" bumper jars/ 4.75" oil jars/6 4.75" drill collarsl crossover. Drain BOP stack and check for debris. 17:30 00:00 6.50 0 8,882 PROD1 FISH TRIP P Trip in hole with bit and scraper on workstring. Tagged top offish @ 8882'. PU and MU Kelly. Fluid Losses for last 24 hrs = 13 Bbls. 08/28/2006 00:00 01:30 1.50 8,882 PROD1 FISH CIRC P Established circulation 580 psi @ 4 BPM. Circulated, rotate and recipricate to clean hole. No signs of anything in returns. No fluid losses or qains durinq circulation. 01:30 02:00 0.50 PROD1 WELCT OWFF P Monitor well. Static. 02:00 04:00 2.00 PROD1 FISH PULD P Break out, rig down Kelly and two pups. Pump dry iob. 04:00 16:00 12.00 PROD1 FISH TRIP P POOH w/ scraper BHA on PH-6 laying down. 16:00 19:00 3.00 PROD1 FISH PULD P Lay down drill collars, scraperlmill BHA. 19:00 19:30 0.50 PROD1 RPCOI\ SFTY P Spot Haliburton Slickline unit. Held pre-job safety meeting with both crews. 19:30 00:00 4.50 PROD1 EVALv\ RURD RU Haliburton slickline. RIH with 2.85" gauge rign down to 8882'. POOH. 08/2912006 00:00 05:00 5.00 PROD1 RPCOI\ SLKL P Run PDS memory caliper for 7" casing starting from 8882' log to surface. Field interpretation shows hole in 7" casing @ 8688' RKB. 05:00 06:00 1.00 PROD1 EVALv\ RURD P Rig down Halliburton Slickline unit. 06:00 07:00 1.00 PROD1 RPCOI\ RURD P Load completion equipment in pipe shed. Prep tools to run completion. 07:00 09:30 2.50 PROD1 RPCOI\ RCST P Began picking up new 3-1/2"completion equipment and RIH. 09:30 13:00 3.50 PROD1 RPCOI\ RCST P 35 jts in the hole at 09:30. CIO company reps. 13:00 15:00 2.00 PROD1 RPCOI\ RCST P Continue running new completion. 140 jts in the hole at 13:00; averaging 25 jts / hr. Zero fluid losses to the well since 06:00. Drift tubing (its 259-272) from DS nipple to surface to 2.91". 15:00 19:00 4.00 PROD1 RPCOI\ PACK P Continue running new completion, on bottom @ 1800 hrs. Dropped ball & rod. Space out to set the FHL Packer @ 8620'. RU circulatinq hose. 19:00 20:00 1.00 PROD1 RPCOI\ PACK P Up wt = 70K Dwn.wt= 42K Pressured up to 2700 psi set FHL packer @ 8620'. PU and sheared PBR @ 65K. LD 1 it & space out. 20:00 21:30 1.50 PROD1 RPCOI\ CIRC P Pull seals out of PBR, MU Hanger with 1 space out pup jt positioned one full jt below the hanger. PJSM on pumping Corrosion Inhibitor. Spot 20 bbls of 9.6 brine containing 1 % by volume SafeCor corrosion inhibitor in the 7"x 3-1/2" annulus from PBR to the gas lift Mandrel #6 @8550. Pumped 4 BPM w/550 psi. 21:30 23:00 1.50 PROD1 RPCOI\ HOSO P Drain stack/Stab seals in PBR I Land hanqer, RILDS. 08/29/2006 23:00 00:00 1.00 PROD1 RPCO~ HOSO P RU Chart Recorder to tubing and IA. With IA open, pressure test tubing to 3000 si hold for 30 min. 08/30/2006 00:00 00:30 0.50 PROD1 RPCO~ HOSO P Bled pressure on tubing down to 2000 psi. Holding the tubing pressure @ 2000 psi, pressure test the IA to 3000 psi for 30 min. Bleed off tubing pressure while holding IA @3000 psi and SOV in GLM #6 sheared at 1200 si. Bled all ressure off. 00:30 06:30 6.00 PROD1 RPCO~ NUND P Install 2-way check. ND BOPE. Clean its. 06:30 10:30 4.00 PROD1 RPCO~ NUND P Rig down hardline to tanks. Install tubin head ada ter and tree. 10:30 12:00 1.50 PROD1 RPCO~ SFEQ P Test voidltree to 25015000 psi. Good test. 12:00 14:00 2.00 PROD1 RPCO~ PULD P Pull 2-way check and set BPV. 14:00 16:00 2.00 PROD1 RPCO~ Lay down Kelly. Release rig at 16:00, 8/30/06. 16:00 20:00 4.00 PROD1 RPCO~ Continue with rig demob and prep for move. . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. F~ËC;E\\/E[J To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 "., ;,...' RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1) 2) 3) 4) 5) 6) 7) 1 BL / EDE Disk 2C - 09 CAliper Repnrt 29-Auq-06 I ~L..I-ddl <ft 1~OCJ1 SCANNED AUG 312008 Signed: G.1L- Date: 7( l<? l,J () (0 ( ¡. Print Name: C.~rtst-¡IA~ (Ì1t\.L 11Iv.....e.VI PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E..MAIL: ?S:~;,:,;\j'DHOGt~\-3E(QJj'E=;V1C"'Z"(~::3,:~J0i~ WEBSITE: '';'?N1N.~'1E;VìOR:YL)C'.:>:;''.i1 D:\OO _ PDSA.'C-2006\Z _ W ord\DistributionITrnnsmittal_ Sheets\Transmit _ Original.doc I I I I I I I I I I I I I I I I I I I i "64- 'J'd I #'00,9 RECEIVED . Memory Multi-Finger Caliper AUG 3 0 2006 Log Results Summary ~OiI&GasCons.Commission Anchorage Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 29, 2006 7096 1 7" 26 lb. J-55 Casing Well: 2C-09 Field: Kuparuk state: Alaska API No.: 50-029-21237-00 Top Log Intvl1.: Surface Bot. Log Intvl1.: 8,850 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the Casing Hanger @ 0' Depth. This log was run to assess the condition of the 7" casing with respect to corrosive and mechanical damages. The 7" casing logged appears to be in good to poor condition with respect to corrosive damage. A hole is recorded in joint 211 (8,657'). A 66% penetration is recorded in joint 215 (8,845'). Penetrations in excess of 20% are recorded in 51 of the 215 joints logged. The damage appears in the forms of general corrosion, lines of corrosion, and isolated pitting. No significant areas of cross-sectional wall loss are recorded throughout the 7" casing interval logged. A moderate dog leg is recorded in joint 128 (5,245'). A slight bend is recorded in joints 119 (4,878'), 120 (4,910'), and at the makeup of joints 178 and 179 (7,334'). Deposits are recorded in joint 215, with a recorded minimum 1.0. of 5.72" (8,821') Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum - recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Hole ( 100%) Jt. 211 @ 8,657 Ft. (MD) Isolated Pitting ( 66%) Jt. 215 @ 8,845 Ft. (MD) Line Corrosion ( 49%) Jt. 83 @ 3,307 Ft. (MD) Line Corrosion ( 46%) Jt. 86 @ 3,458 Ft. (MD) Corrosion ( 40%) Jt. 90 @ 3,617 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the casing interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Deposits Deposits Minimum 1.0. = 5.72" Minimum 1.0. = 5.95" Minimum 1.0. = 5.96" Minimum 1.0. = 5.97" Minimum 1.0. = 5.97" 215 @ 77 @ 124 @ 189 @ 213 @ 8,821 Ft. (MD) 3,076 Ft. (MD) 5,060 Ft. (MD) 7,780 Ft. (MD) 8,745 Ft. (MD) Jt. Jt. Jt. Jt. Jt. I Field Engineer: Wm. McCrossan Analyst: M. Tahtouh Witness: Freeborn/ R. Overstreet .: l~:j/ 565-9085 Prudhoe Bay Field Office I I I Well: Field: Company: Country: 2C-09 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 7ins Weight 26 f Grade & Thread )-55 I Penetration and Metal loss (% wall) I penetration body rnetalloss body 150 I 100 I 50 o o to 1% 1010 20% 20 to 40 to 40% 85% 1 to 10% I pene. loss I I Damage Configuration ( body) 100 80 I 60 40 I 20 o I isolated pitting general line ring hole I poss corrosion corrosion corrosion ible hole I I I I I over 85'Yo 1 o PDS Repo Body Regia Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 6.276 ins Nom. Upset 7ins penetration body o 1 Bottom of Survey 215 Analysis Overview page 2 Overview Analysis August 29, 2006 MFC 40 No. 00432 2.75 40 M. Tahtouh Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) rnetalloss body 50 100 51 101 151 201 I I Pipe 1 I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 7. in (0.0' - 881 7.7') 100 (¡¡ ..J:J E :J z 125 +-' c 'õ 150 I Bottom of Survey = 215 I I Well: Field: Company: Country: Survey Date: 2C-09 Kuparuk ConocoPhillips Alaska, Inc. USA August 29, 2006 Approx. Tool Deviation Approx. Borehole Profile 25 50 75 175 200 215 o 50 Damage Profile (% wall) I Tool Deviation (degrees) o 937 1944 2965 4024 0 2 .,..; LL c 5103 6178 7178 8200 8818 100 I PDS REPORT JOINT TABULATION 5 EET I I Pipe: Body Wall: Upset Wall: Nominal!.D.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 2C-09 Kuparuk ConocoPhillips Alaska, Ine. USA August 29, 2006 I Joint Jl. Depth PCI Pen. F'¡;¡ ¡ \,Ie!;:! Min. Damag e Profile No. (Fl.) Body I.D. Comments (% wall) ( (Ins.) (Ins.) 0 50 100 1 0 n 0.03 h 6.27 2 31 n 0.03 (, 6.27 Shallow oittir)Q. 3 72 n 0.04 0 4 6.26 Shallow nittinQ. 4 113 n 0.04 0 h 6.27 Shallow nittinQ. 5 153 n 0.04 11 4 6.27 Shallow Dittin\:!. 6 192 ¡) om c¡ 4 6.26 Shallow Dittin\:!. 7 229 n 0.04 11 ill 6.26 Shallow Dittin\:!. 8 266 ¡) 0.04 1( {, 6.25 Shallow oittin\:!. 9 306 n 0.05 I H 6.25 Shallow Dittim~. 10 345 n 0.04 I 6.22 Shallow Dittim!.. 11 386 I 0.04 11 6.26 Shallow nittinq. 12 427 ( 0.05 11 {j 6.25 Shallow nittínq. 13 467 I 0.05 14 4 6.26 Shallow nittínq. 14 504 I 0.05 14 h 6.27 Shallow oittinq. 15 543 0.04 ill 6.25 Shallow oittim!.. 16 584 n 0.05 1 {, 6.25 Shallow oittim!.. 17 620 I 0.04 1 4 6.27 Line shallow corrosion. 18 660 n 0.04 1 ¿¡ 6.27 Shallow oittinQ. 19 701 n 0.04 I 'i 6.26 Line shallow corrosion. 20 737 n 0.04 In 4 6.25 Line shallow corrosion. 21 777 n 0.05 3 6 6.27 Shallow Dittin\:!. 22 817 n 0.04 6.26 Line shallow corrosion. 23 858 n 0.05 ! 6.26 Line shallow corrosion. 24 899 n 0.04 6.26 Line shallow corrosion. 25 937 0 0.05 6.27 Line shallow corrosion. 26 976 0 0.05 4 6.26 Line shallow corrosion. 27 1015 0 0.05 ill 6.26 Line shallow corrosion. 28 1055 n 0.07 20 :I 6.26 Line shallow corrosion. 29 1096 n 0.05 1 i :I 6.26 Line shallow corrosion. 30 1136 n 0.07 2( F 6.26 Line corrosion. 31 1175 n 0.06 1 {j 6.26 Line shallow corrosion. 32 1216 n 0.06 1 :I 6.26 Line shallow corrosion. 33 1257 n 0.06 I '.J 6.25 Line shallow corrosion. 34 1297 (] 0.06 1 4 6.26 Line shallow corrosion. 35 1338 n 0.07 11 4 6.25 Line shallow corrosion. 36 1379 n 0.06 17 :I 6.26 Line shallow corrosion. 37 1419 n 0.08 21 6.25 Line corrosion. 38 1460 (] 0.07 1 6.24 I ine shallow corrosion. 39 1498 () 0.07 6.25 Line shallow corrosion. Denosits. 40 1538 n 0.06 6.25 Line shallow corrosion. 41 1579 () 0.08 6.23 Line corrosion. 42 1620 0 0.06 6.24 Line shallow corrosion. 43 1659 II 0.06 6.24 Line shallow corrosion. 44 1700 n 0.08 22 6.23 Line corrosion. 45 1737 II 0.06 I 6.24 Line shallow corrosion. 46 1778 n 0.06 1 6.24 Line shallow corrosion. 47 1819 () 0.07 7 6.25 Line corrosion. 48 I 1860 0 0.06 ~~ i=t 6.22 Line shallow corrosion. 4q I 1901 ¡) 0.07 6.23 Line corrosion. 50 1944 n 0.08 6.25 Line corrosion. I I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: Nominall.D.: 7. in 26.0 ppf )-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 2C-09 Kuparuk ConocoPhillips Alaska, Inc. USA August 29, 2006 I I Joint Jt. Depth Pel Pen. Pen. !vk'ldl Min. Damage Profile No. (Ft.) Body I LD. Comments (%wall) (Ins.) (Ins.) (Ins.) 0 50 100 51 1986 0 0.08 2 6.25 Line corrosion. 52 2027 0 0.08 2 6.25 Line corrosion. 53 2067 0 0.08 1 6.21 Line corrosion. 54 2107 () 0.05 14 6.22 Line shallow corrosion. 55 2150 0 0.08 22 1 6.23 Line corrosion. 56 2188 0 0.07 1 , 6.07 Line shallow corrosion. Lt. Deoasi ts. , 57 2232 () 0.06 1 I 6.20 Line shallow corrosion. 58 2273 () 0.06 I 1 6.19 j rrosion. 59 2316 () 0.08 2. 1 6.20 Line corrosion, 60 2353 () 0.05 I I 6.20 Line shallow corrosion. 61 2397 0 0.07 19 ¡ 6.17 Line shallow corrosion. 62 2441 0 0.06 IE I 6.20 Line shallow corrosion. 63 2484 0 0.06 6.21 Line shallow corrosion. 2524 0 0.09 6.20 Line corrosion. 65 2562 0 0.08 6.20 Line corrosion. 66 2602 0 0.09 6.22 Line corrosion. 67 2639 0 0.08 I 6.19 Line corrosion. 68 2682 () 0.09 :: 6.21 Line corrosion. 69 2723 00', 0.09 24 2 6.19 Line corrosion. 70 2764 0.06 0.10 :: 6.20 Line corrosion. 71 2804 0 0.09 1 6.21 Line corrosion. Lt. Deoasits. 72 2843 0 0.10 4 6.22 Line corrosion. 73 2883 0 0.08 4 6.21 Line wrrosion. 74 2924 0 0.09 2 6.22 Line corrosion. 75 2965 0.16 0.10 2 6.22 Line corrosion. 76 3003 0.117 0.14~ 6.22 Line corrosion. 77 3044 0.06 0.13 5.95 Line wrrosion. Deoosi ts. 78 3085 0 0.10 =îH± Line corrosion. 79 3126 0.09 I inp corrosion. 80 3166 (( 0.08 6.16 Line wrrosion. Lt. Denosits. 81 3203 i I 0.08 6.18 Line corrosion. 82 3247 i 0.13 6.15 Line corrosion. U. Deoosi ts. m 3290 I 0.18 6.16 Line wrrosion. Lt. Deoosits. 84 3333 0 0.11 31 2 6.17 Line corrosion. 85 3377 0 0.10 6.15 Line corrosion. U. Deoosi ts. 86 3420 0 0.17 6.18 Line corrosion. 87 3464 OO'i 0.08 6.16 I ine corrosion. l.t. Denosits. 88 3504 (J.06 0.11 6.15 Line corrosion. Lt. Deoosits. 89 3547 0 0.14 6.14 Corrosion. l.t. Deoosits. 90 3591 0.06 0.15 0 :: 6.14 Corrosion. Lt. Deoosits. 91 3634 0 0.11 10 3 6.14 Line wrrosion. Lt. Deoosits. 92 3677 006 0.13 J! 2 6.14 Corrosion. l.t. Deposits. 93 H721 OU2 0.11 I 6.13 Corrosion. Lt. Deoosits. 3764 0.10 j 6.15 Line corrosion. Lt. Deoosits. 95 3808 01 IS 0.09 I 6.15 Line wrrosion. l.t. Deoosits. 96 3851 o. IS 0.10 ¡ 6.14 Corrosion. Lt. Deoosits. 97 3895 C 0.07 I 6.14 Line corrosion. Lt. Deoosits. 98 3938 0 0.09 26 , 6.16 Line corrosion. Lt. Deposits. , 99 3981 U 0.08 21 I 6.17 Line corrosion. 100 4024 U 0.07 "19 I 6.17 Shallow corrosion. I I I I I I I I I I I I Penetration Body Metal Loss Body Page 2 I I I PDS REPORT JOINT TABULATION S EET I I Pipe: Body Wall: Upset Wall: Nominall.D.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 2C-09 Kuparuk ConocoPhillips Alaska, Inc. USA August 29, 2006 I Joint Jt. Depth Pet: Pen. Pen VIf'lal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 101 4067 () 0.06 1 1 6.17 Shallow corrosion. if 102 4110 n 0.09 2 , 6.17 Corrosion. ¡ 103 4154 () 0.09 2 I 6.16 Corrosion. L1. Deoosits. 104 4197 n 0.05 1 I 6.14 Shallow corrosion. L1. Deoosits. 105 4241 n 0.07 íß I 6.13 Shallow corrosion. L1. Deoosits. te~ 106 4284 n 0.06 16 1 6.14 Shallow corrosion. U. Deoosits. te~ 107 4328 () 0.05 14 1 6.13 Shallow corrosion. L1. Denosits. 108 4371 0 0.05 'I ¡ I 6.10 Shallow corrosion. L1. Denosits. te 109 4414 () 0.06 1 1 6.13 Shallow corrosion. Lt. Denosits. 110 4457 0 0.06 1 1 6.12 Shallow corrosion. Lt Denosits. , 111 4500 0 0.09 2: 1 6.12 Corrosion. Lt. Deoosits. te~ 112 4542 0 0.05 15 1 6.10 Shallow corrosion. U. Deoosits. IIIII~ 113 4586 () 0.05 14 1 6.13 Shallow corrosion. U. Denosits. 114 4630 () 0.06 1 1 6.10 Shallow corrosion. Lt. Denosits. te 115 4673 0 0.06 1 1 6.09 Shallow corrosion. Lt. Denosits. 116 4717 0 0.06 I '( 6.11 Shallow corrosion. Lt Denosits. 117 4760 0 0.04 I I 6.12 Shallow corrosion. Lt Deoosits. 11III 118 4803 0 0.05 1 0 6.15 Shallow corrosion. Lt. Deoosi ts. te 119 4846 0 0.05 1 I 6.09 Shallow corrosion. Slight Bend Lower Bodv. te~ 120 4889 0 0.05 13 I 6.10 Shallow corrosion. Slight Bend Middle Bodv. te 121 4931 0 0.05 13 I 6.16 Shallow corrosion. 122 4973 U 0.06 H I 6.17 Shallow corrosion. Lt. Deoosits. te 123 5016 0 0.06 11 1 h15 Shallow corrosion. Lt. Denosits. 124 5060 o,u\ 0.06 1. I 5.96 Shallow corrosion. Denosits. otllli 125 5103 U 0.05 I I 6.08 Shallow corrosion. Lt. Deoosits. otllli 126 5146 0.03 0.07 I 1 6.14 Shallow corrosion. Lt. Deoosits. 127 5189 0 0.07 20 j 6.14 Corrosion. Lt Deoosits. ~o 0.06 17 1 6.03 Shallow corrosion. Dog Leg at 5245 ft. 0 "II h,1h Shallow corrosion. I O. 6.17 Shallow corrosion. Lt. Deoosits. 11III 131 5359 ( 0.1 6.17 Shallow nittinQ. Lt. Denosits. ot 132 5403 ( 0.151 6.18 Shallow corrosion. otllli 133 5447 I 0.c151 6.17 Shallow corrosion. it 134 5490 0 0.08):: 6.16 Corrosion. 135 5534 () 0.03 I / I) 6.16 ~ o~ 0 6.16 Shallow pitting. 0 ] 6.16 Shallow nittiml. Lt. Denosits. 138 4 o 0.03 e () 6.16 Lt. Denosits. II 139 5707 0 0.04 11 I 6.13 Line shallow corrosion. Lt Deoosits. ot 140 5750 0 0.06 15 I 6.12 Line shallow corrosion. Lt. Deposits. 11III11 141 5793 0 0.03 ') '1 6.02 Shallow corrosion. L1. Deposits. Ill! 142 5837 0 0.01 j 11 6.12 L1. Deposits. 143 5880 0 0.03 1! Ci 6.13 L1. Deoosi Is. 144 5924 0 0 0 0 6.11 L1. Deposits. 145 5968 0 0.04 1 I 6.11 Shallow nittinQ. Lt. Denosits. 146 6011 0 0.06 1 , 6.10 Shallow corrosion. Lt. Deoosi ts. II I 147 6054 0 0.03 7 0 6.08 L1. Deoosits. 148 6096 0 0.03 g I 6.13 Lt. Deoosi ts. 149 6137 CI 0.03 9 I 6.13 Line shallow corrosion. It. Denosits. 150 6178 0 0.03 9 I 6.15 Shallow oitting. Lt. Denosits. I I I I I I I I I I I I I Page 3 I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Coun try: Survey Date: 2C-09 Kuparuk ConocoPhillips Alaska, Inc USA August 29, 2006 I I Joint Jt. Depth Pel Pen. F'e¡ hAe!al Min. Damage Profile No. (Ft.) ,\ Body 1.0. Comments (%wall) (Ins.) (Ins.) 0 50 100 151 6259 I \; 0.ü3 n 6.14 Lt Denosits. 152 0.04 n 6.16 Shallow nittinQ. 1.1. Denosits. 153 6297 0 0.04 I 6.16 Line shallow corrosion. Lt. DeDosits. to 154 6337 n 0.04 j 6.15 Shallow oittinQ. Lt. Deoosits. to 155 6376 0 0.04 10 I 6.15 Line shallow corrosion. Lt. Deoosits. (0 156 6416 I 0.05 14 1 6.17 Line shallow corrosion. (0 157 6457 0 0.07 19 I 6.16 Line shallow corrosion. Lt. Denosits. '(ffffI 158 6498 (I om U. Deoosi ts. (0 159 6538 (I 0.04 '" 1 6.16 Line shallow corrosion. U. Deoosits. , I 160 6579 Iì 0.05 11 1 6di±Líne shallow corrosion. U.Deoosits. 161 6620 I 0.ü3 9 1 6 Shallow oittinQ. U.DeDosits. (0 162 6660 0 0.ü3 a 0 6.14 Lt. Deoosi ts. III 163 6704 0 0.04 10 ~! 6.15 Shallow corrosion. Lt Deoosits. ¡iBIì 164 6743 0 0.03 I 6.02 U. Deoosi ts III 165 6784 0 0.03 !1 \ 6.13 Lt DeDosits. 166 6820 ¡ 0.04 II 'j 6.02 . Lt. Denosi ts. 167 6861 i 0.03 I 6.16 It. Denosits. to 168 6900 ! 0.05 S 1 6.16 Shallow nittinQ. U. Deoosits. III 169 6936 I 0.ü3 '1 1 6.15 Lt DeDosi ts. III 170 6977 0 0.04 1 'I 6.15 Shallow DittinQ. Lt Deoosits. to 171 7018 0 0.04 12 6.17 Shallow oittím~. . 172 7058 I 0.06 17 6.15 Line shallow corrosion. Lt. Denosits. .IE 173 7099 0.04 I 1 6.17 {tinQ. Lt. Denosits. 174 7140 0.03 q 1 6.01 Shallow oittinQ. Lt. Deoosits. to 175 7178 0.06 I 2 6.01 Shallow oittimI. Deoosits. 176 7218 0.03 9 , 6.15 Shallow oittinQ. Lt. Deoosits. to 177 7257 i 0.05 14 2 6.14 Shallow oittinQ. U. Deoosits. 178 7294 ( 0.04 I I 6.04 Shallow oittinQ. U.Deoosits. 179 7335 n 0.04 I, 3 6.09 Shallow oittinQ. Slight Bend at Makeun. Lt. DPi 180 7375 n 0.04 J 3 6.06 Shallow pittim::. Lt. Denosits. 181 7416 n 0.06 ( ;> 6.10 Shallow nittinQ. U. Denosits. 182 7456 n 0.05 J 3 6.14 Shallow oittinQ. Deoosits. 183 7500 n 0.06 1 2 6.15 Shallow oittinQ. Lt DeDosits. 184 7540 n 0.04 10 1 6.13 Shallow pitting. Deposits. , 185 7584 0 0.04 ! 6.13 Shallow oitting. U. deposits. 186 7628 I 0.05 I 6.12 Shallow pitting. Lt. Deposits. 187 7664 Iì 0.0' 1 6.12 Shallow nitling. Denosits. 188 7704 I 0.05 I 6.15 Shallow pittinQ. Lt. Deoosits. 189 7745 Iì 0.05 1 5.97 Shallow oittin2. Lt. Deoosits. 190 7786 0 0.04 I 6.13 Shallow oittín2. Lt. Deoosits. 191 7826 Iì 0.05 1 I 6.15 Shallow oittin2. U.Deoosits. 192 7867 0 0 0 0 6.12 Lt. Deoosits. 193 7911 0 0.03 ß , 6.11 U. Deoosi ts. III 194 7954 II 0.05 6.16 Shallow pitting. ¡iBIì 195 7995 IlI),2 0.04 12 6.14 Shallow pitting. Lt. Denosits. 196 8038 0 0.05 14 .2 6.14 Shallow nittin2. It. Deoosits. 197 8076 {] 0.05 11 I 6.14 Shallow oittin2. Lt. DeoosÎts. 198 8118 (] 0.06 16 1 6.17 Shallow oining. L t De oosi ts. 199 8157 0 0.04 11 6.13 Shallow oìttin2. Lt. Deposits. 200 8200 C) 0.05 15 1 6.15 Shallow oittin2. Lt. Deposits. I I I I I I I I I I I I Penetration Body Metal Loss Body Page 4 I I I I Pipe: Body Wall: Upset Wall: NominaIID.: I PDS REPORT JOINT TABULATION SHEET 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in I Joint No. 201 8244 202 203 8331 204 8370 205 8408 206 8451 207 8487 208 8530 209 8571 210 8612 211 8655 212 8696 213 8736 214 8777 215 8818 I I I I I I I I I I I I I I I Well: Field: Company: Country: Survey Date: Min. I.D. (Ins.) 6.16 Shallow 6.15 Shallow 6.18 Shallow 6.18 Shallow 6.1 8 Shallow 6.1 7 Shallow 6.16 Shallow 6.12 Shallow 6.15 Shallow 6.1 7 Shallow 6.11 HOLE! 6.02 Shallow 5.98 Isolated 6.05 Shallow 5.72 Isolated Page 5 2C-09 Kuparuk C:onocoPhillips Alaska, Inc. USA August 29, 2006 Comments Damage Profile (%wall) o 50 1 00 Body Metal Loss Body ....-..-.. Well: Field: Company: Country: Tubin : ........ ...... .. .. .. .. .. .. P S Repo Cross Secti ns 2C·09 Kuparuk ConocoPhillips Alaska, Inc. USA 7 ins 26 f ·55 August 29, 2006 MFC 40 No. 00432 1.75 40 M. Tahtouh SUlvey Date: Tool Type: Tool Size: ,'\10. of Fingers: Anal st: Cross Section for Joint 211 at depth 8656.783 ft Tool speed = 65 Nominal 10 = 6.276 Nominal 00 = 7.000 Remaining wall area = 96 % Tool deviation 650 Finger 12 Penetration 0.403 ins Hole 0.40 ins = 100% Penetration HIGH SIDE = UP Cross Sections page 1 ---....- ..--........ - .. ....-.. PDS Report Cross Sections Well: Field: Company: Country: Tubin : 2C·09 Kuparuk ConocoPhillips Alaska, Inc. USA 7ins 26 f ·55 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: August 29, 2006 MFC 40 No. 00432 2.75 40 M. Tahtouh Cross Section for Joint 215 at depth 8844.72 ft Tool speed = 67 Nominal 10 = 6.276 Nominal 00 = 7.000 Remaining wall area = 98 % Tool deviation = 740 Finger 7 Penetration = 0.24 ins Isolated Pitting 0.24 ins = 66% Penetration HIGH SIDE UP Cross Sections page 2 ------ Well: Field: Company: Country: Tubin : ------- - - PDS Report Cross Sections 2C·09 Kuparuk ConocoPhillips Alaska, Inc. USA 7ins 26 f ·55 August 29, 2006 MFC 40 No. 00432 ;1.75 40 M. Tahtouh Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Cross Section for Joint 215 at depth 8821.304 it Tool speed = 72 Nominal 10 = 6.276 Nominal 00 = 7.000 Remaining wall area = 100 % Tool deviation = 590 Finger 30 Projection = -0.544 ins Deposits Minimum 1.0. = 5.72 ins HIGH SIDE = UP Cross Sections page 3 - - .. - I KRU 2C-09 I ~C.,(l9 GasUl! API: 23700 .¡~ SSSV Tvne: NONE andrei/Dummy Annular Fluíd: DSUSW 1/13/1999 - Valve 1 fa R Last Update: 512006 (97-98, : 8702 . 9660 ftKB . 5/1412006 Max 59 dea æ¡¡ 7600 GasUl! Descriotion I Size Top Bottom TVD wt Grade Thread andrei/Dummy Valve 2 CONDUCTOR I 16.000 0 101 101 62.50 H-40 (145-146, SURFACE I 9.625 0 4162 3058 36.00 J-55 00:5.500) PRODUCTION I 7000 0 9619 6238 ?6OC J·55 {xii GasLifi Size TOD I Bottom I TVD I wt I Grade I Thread andrei/Dummy 3.500 0 I 8827 I 5664 I 9.20 I J-55 EUE 8RC Valve 3 / (193-194, Interval TVD Zone Status Ft SPF Date TilDe Comment 00:5.500) 9131 - 9252 5875 5963 G-3,G-2,C-1,L 121 12 3/27/1985 IPERF 120deg Ph; 5"Jumbo Jet B Ii 9369 - 9375 6049 - 6054 A-5 6 4 8/2711985 90dea V Ph·2.125"BarKone II GasUft 9375 - 9376 6054 - 6054 A-5 1 5 8/27/1985 90dea V Ph·2.125"BarKone II MandrelNalve 9376 - 9377 6054 - 6055 A-5 1 4 8/27/1985 90deo V Ph·2.125"BarKone II 4 (3296-3297, 9377 - 9378 6055 - 6056 A-5 1 5 8/27/1985 90dea V Ph.2.125"BarKone II 00:5500) 9378 - 9382 6056 - 6059 A-5 A-4 4 4 8/27/1985 9Odeo V Ph.2125"BarKone II 9382 - 9387 6059 - 6062 A-4 5 10 10/10/1994 RPERF +/- 90 deo Ph' 2 1/8"EJ 9387 - 9390 6062 - 6065 A-4 3 11 10/10/1994 RPERF +/- 90 deo Ph' 2 1/8"EJ 9390 - 9393 6065 - 6067 A-4 3 10 10/10/1994 RPERF +/- 90 dea Ph' 2 1fB"EJ GasUft 9393 - 9402 6067 - 6074 A-4 9 11 10/10/1994 RPERF +/- W dea Ph' 2 1/8"EJ MandrelNalve 9402 - 9404 6074 - 6075 A-4 2 5 8127/1985 RPERF 90deQ V Ph.2. 125"BarKone II 5 (5546-5547, 9404 - 9412 6075 - 6081 A-4 8 4 8/27/1985 RPERF Ph·2.125"BarKone II 00:5500) 9436 - 9441 6099 - 6103 A-3 5 4 8/26/1985 RPERF Ph·2.125"BarKone II 9441 - 9444 6103 - 6105 A-3 3 5 8/26/1985 RPERF 25"BarKone II 9444 - 9447 6105 - 6107 A-3 3 4 8/2611985 RPERF 25"BarKone II 9447 - 9450 6107 - 6110 A-3 3 5 8/26/1985 125''BarKone 11 GasUft 9450 - 9452 6110-6111 A-3 2 4 8/2611985 RPERF V 25"BarKone 11 MandreINaIve 9452 - 9455 6111 - 6113 A-3 ~: 5 812611985 RPERF V 125"BarKone 11 6 (6488-6489, 9455 - 9457 6113 - 6115 ¡ A-3 4 8/2611985 V 125"BarKone II 00:5500) 9491 - 9498 6141 - 6146 A-3 1 3/27/1985 IP Jumbo Jet (::"" 1ft st MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt GasUft 1 97 97 Cameo KBMM CAMeO DMY 1.0 BK 0.000 0 12/19/1999 andrel/Oummy 2 145 145 Cameo KBMM CAMCO DMY 1.0 BK 0.000 0 7122/1999 Valve 7 3 193 193 Cameo KBMM CAMCO DMY 1.0 BK 0000 0 7122/1999 (8743-8744, 4 3296 2555 Cameo KBMM CAMeO GLV 1.0 BK 0.188 1282 1012712003 00:5.500) 5 5546 3825 Cameo K8MM CAMCO OV 10 BTM 0.250 0 10/2712003 6 6488 4341 Cameo KBMM CAMCO OPEN 1.0 0.000 ~ NIP !II 5009 C.moo KBMM CAMCO DMY 0 BK2 0.000 (8822-8823, 00:3500) TVD Type DescriDtion ID 5661 NIP CAMCO D Níoole 2.750 5671 PUMP Centrílíft 163GC10000 Series 513 Tandem 0.000 8887 5704 SEAL Centrílift Tandem Seal Section 0.000 PUMP ~ MOTOR HP KMH :i'iROffJR )noo (8837-8887, OD:6151) DescriDtion 1 Comment SEAL (8887-8902, 13.5" TUBING STUB, GLM, PUP 8. PACKER W128 BLAST RINGS & FIRED 00:6151) "UTTER -I FFT IN HOI F 8124/98 Perf - - Date I Note (9131·9252) - - 10/2912003 WAIVEREDWELL T x IA COMMUNICATION - - - - - -. FISH (9253-9256, OD:3.500) Perf - f-- (9369-9412) - I-- == Perf ~ (9387·9390) f-;;;: = = Perf - (9441-9444) ~ :;; Perf - f-- (9491-9498) - !-- - e-- I I I I I I I I I I I I I I I I I Nabors 38 well control & Doyon 15 fire incident . Hello Jim, FYI, Nabors 3S (John Freeborn) contacted me on 8/21/06 to report that they had used the annular and choke to circulate some gas out of well KRU 1~. They said it was a minor amount of gas that they observed & assumed was resíctual gas in the control line armour sheathing while TOH with the ESP completion while perfoming the W/O. I told them to test BOPE as soon as they were out of the hole if conditions were stable. z-C-oC\ S£.P- CPAI (Wendy Mahan) contacted me 8/22/06 to report a fire incident on Doyon 15. Insulation was ignited by welding sparks during repairs in the mud pits causing heat & smoke and was extinguished. My scheduled flight to Anchorage this morning has been cancelled due to weather flight minimums and the fact that the FAA has an equipment malfunction that requires visual flight rules for aircraft landing at Deadhorse. I am scheduled to depart on the evening flight and arrive Anchorage around 10:00 PM if the weather improves and AA can land a plane. Thanks, Jeff SCANNED SEP 052006 1 of 1 8/23/2006 12:44 PM e e j ')~J FRANK H. MURKOWSKI, GOVERNOR ¡ :~=J :l :¡ :i,,,J AI/ASKA. OIL AIQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Mukavitz Well Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 l 'Ó'lr ð- ')..-1 Re: Kuparuk River Field, Kuparuk Oil Pool, 2C-09 Sundry Number: 306-167 ;....<Î"~Ï'.iN¡;;:¡f . í!J ¡\1 1 ..~ ')nnr¡ ..,?~q-;~ \; ~ "... .'...,./i> ¿ ç~, L. ..... v '''<f Dear Mr. Mukavitz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 014~ Cathy P. Foerster Commissioner I,) DATED thisZ3 day of May, 2006 Encl. e e Steve Mukavitz Well Engineer Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4021 May 8, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 2C-09 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 2C-09. If you have any questions regarding this matter, please contact me at 263-4021. Sin. cerely, I, .01_ ~ :1:. ~~ð S. Mukavitz Well Engineer CPAI Kuparuk Drilling SM/skad e STATE OF ALASKA e ~'7 ALASKA OIL AND GAS CONSERVATION COMMISSION ;) APPLICATION FOR SUNDRY APPROVALfU~~ka 20 MC 25.280 ii!,,:! "';r.r D D D D D , D 1. Type of Request: Abandon Suspend Operational Shutdown Perforate Waiver Other Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 0 Exploratory D 184-221 . Development 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21237-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 125' 2C-09 . 8. Property Designation: 10. Field/Pool(s): ADL 25654: ALK 2580 Kuparuk River Field 1 Kuparuk Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9660' r 6268' 8583' 5508' 9253' Casing Length Size MD TVD Burst Collapse CONDUCTOR 75' 16" 101' 101' SURFACE 4136' 9-5/8" 4162' 3058' PRODUCTION 9594' 7" 9619' 6238' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9131'-9252',9369'-9412',9436'-9457',9491'-5 5875'-5963',6049'-6081',6099'-6115',6141'-6146' 3-1/2" J-SS 8827' Packers and SSSV Type: Packers and SSSV MD (ft) no packer No SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0' Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 15, 2006 Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name 2~ve~ ~.. Title: Well Engineer Signature. ~ '3 S-( ~J b-b Phone 26'-4021 Date 0 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness sund:m~_ \ lD' Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: ~~-r'~ \(.. ~\-OL"-o.~rtI..~t--'.tt'\ ~~\l... ,\~R ~~ ') ~k~\~_ 3000~s\ ",\~\~~~\3>O\>\ts.\- Subsequent Form Required: 40 \.......\ RBDMS 8Ft MAY 2 4 2006 Approved by: (}Jt ~ ¡J!l ~ ~L APPROVED BY Date: $".2--5 ~{) h COMMISSIONER THE COMMISSION I W 'URIGINAL ¿6b S-- I'Z '0' Form 10-403 Revised 7/2005 Sub . . n Duplicate ~ f(tþ!ttS e e Rig Workover - Description Summary of Proposal Well 2C-09 Kuparuk Producer Replace 3-1/2" Tubing and ESP with 3-1/2" Gas Lift Completion · MIRU Nabors 3S. Kill well with weighted brine (to be determined based on pre-workover BHSIP). Nipple down tree and nipple up and test BOP (pressure test BOP to 3500 psi, based on maximum anticipated surface pressure of 2900 psi). · POOH with 3-1/2" J-55 tubing and ESP completion. If the ESP is not free, chemical cut the tubing in the first full joint above the ESP and fish ESP assembly. · RU slickline. RIH with gauge ring and junk basket to -9100' (top of the "C" sand perfs at 9131' MD). RIH with 40 arm caliper log for 9-5/8" casing to -9050' MD and run log to surface. Download data at surface for preliminary indication of casing condition. · Run a new string of 3-1/2" 9.3# L-80 tubing, Baker FHL packer and a new gas lift completion. Set packer and shear PBR. · Space out and land tubing. Pressure test tubing and tubing/casing annulus to 3000 psi for 30 minutes. · Nipple up the tree and test. RDMO Nabors 3S. 81M! 05-08-06 ConocoPhillips Alala, Inc. e KRU 4:-09 . 20-09 » API: 500292123700 Well Type: PROD Anale ((j) TS: 44dea((j)9131 ~ SSSV Tvpe: NONE Oria Completion: 3/14/1985 AnQle (âJ TD: 41 deQ (âJ 9660 Annular Fluid: DSUSW Last W/O: 1/13/1999 Rev Reason: Pull GLV Gas Lift Reference LOQ: Ref LOQ Date: Last Update: 5/14/2004 ,ndrellDummy Last Taa: 8583 TD: 9660 ftKB Valve 1 Last Taa Date: 1/7/2000 Max Hole Anale: 59 dea (âJ 7600 (97-98. Oª$joå··StdOg.;tèA$IISI~$ > .. .. Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 101 101 62.50 H-40 Gas Lift alii SURFACE 9.625 0 4162 3058 36.00 J-55 'ndrel/Dummy DPnn"f'T,n", 7.000 0 9619 6238 26.00 J-55 Valve 2 (145-146, I.· ... OD5.500) Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 8827 I 5664 I 9.20 I J-55 I EUE 8RD ;.\ Gas Lift M Interval TVD Zone Status Ft SPF Date Tvpe Comment .ndrel/Dummy 9131 - 9252 5875 - 5963 C-3,C-2,C-1,l 121 12 3/27/1985 IPERF 120deg Ph; 5"Jumbo Jet Valve 3 (193-194. B OD;5.500) 9369 - 9375 6049 - 6054 A-5 6 4 8/27/1985 RPERF 90dea V Ph;2.125"BarKone II 9375 - 9376 6054 - 6054 A-5 1 5 8/27/1985 RPERF 90dea V Ph;2.125"BarKone II 9376 - 9377 6054 - 6055 A-5 1 4 8/27/1985 RPERF 90deQ V Ph;2.125"BarKone II Gas Lift :IItIt 9377 - 9378 6055 - 6056 A-5 1 5 8/27/1985 RPERF 90dea V Ph;2.125"BarKone II MandrelNalve 9378 - 9382 6056 - 6059 A-5,A-4 4 4 8/27/1985 RPERF 90dea V Ph;2.125"BarKone II 4 9382 - 9387 6059 - 6062 A-4 5 10 10/10/1994 RPERF +/- 90 deQ Ph' 2 1/8"EJ (3296-3297, 9387 - 9390 6062 - 6065 A-4 3 11 10/10/1994 RPERF +/- 90 deQ Ph; 2 1/8"EJ 9390 - 9393 6065 - 6067 A-4 3 10 10/10/1994 RPERF +/- 90 dea Ph' 2 1/8"EJ 9393 - 9402 6067 - 6074 A-4 9 11 10/10/1994 RPERF +/- 90 dea Ph' 2 1/8"EJ 9402 - 9404 6074 - 6075 A-4 2 5 8/27/1985 RPERF 90deQ V Ph;2.125"BarKone Gas Lift .. 9404 - 9412 6075 - 6081 A-4 8 4 8/27/1985 RPERF 90deQ V Ph;2.125"BarKone MandrelNalve 9436 - 9441 6099 - 6103 A-3 5 4 8/26/1985 RPERF 90dea V Ph;2.125"BarKone 5 9441 - 9444 6103 - 6105 A-3 3 5 8/26/1985 RPERF 90dea V Ph;2.125"BarKone (5546-5547. 9444 - 9447 6105- 6107 A-3 3 4 8/26/1985 RPERF 90deo V Ph;2.125"BarKone 9447 - 9450 6107-6110 A-3 3 5 8/26/1985 RPERF 90deQ V Ph;2.125"BarKone 9450 - 9452 6110-6111 A-3 2 4 8/26/1985 RPERF 90deQ V Ph;2.125"BarKone 9452 - 9455 6111- 6113 A-3 3 5 8/26/1985 RPERF 90dea V Ph;2.125"BarKone Gas Lift --- 9455 - 9457 6113-6115 A-3 2 4 8/26/1985 RPERF 90dea V Ph;2.125"BarKone MandrelNalve 9491 - 9498 6141 - 6146 A-3 7 1 3/27/1985 IPERF 120 dea Ph; 4" Jumbo Jet 6 ~.." .¡ft. (6488-6489, St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt 1 97 97 Cameo KBMM CAMCO DMY 1.0 BK 0.000 0 12/19/1999 2 145 145 Cameo KBMM CAMCO DMY 1.0 BK 0.000 0 7/22/1999 Gas Lift 3 193 193 Cameo KBMM CAMCO DMY 1.0 BK 0.000 0 7/22/1999 , ndrel/Dummy 4 3296 2555 Cameo KBMM CAMCO GLV 1.0 BK 0.188 1282 10/27/2003 Valve 7 5 5546 3825 Cameo KBMM CAMCO OV 1.0 BTM 0.250 0 1 0/27/2003 (8743-8744. 6 6488 4341 Cameo KBMM CAMCO OPEN 1.0 0.000 0 5/10/2004 OD:5.500) 7 8~ 143 5609 Cameo KBMM CAMCO DMY 1.0 BK2 0.000 0 ~,.¡ ·iôi.~·.\. U=\AI~ RV ;.;t NIP Depth TVD Type DescriDtion ID (8822-8823. 8822 5661 NIP CAMCO D Nipple 2.750 OD3.500) 8837 5671 PUMP Centrilift 163GC 1 0000 Series 513 Tandem 0.000 8887 5704 SEAL Centrilift Tandem Seal Seetian 0.000 8902 5714 MOTOR Centrilift 570 HP KMH 3560/98 0.000 FishiEISH PUMP Depth DescriDtion I Comment (8837-8887. OD:6.151) 9253 FISH I ~.5" TUBING STUB, GLM, PUP & PACKER W/28 BLAST RINGS & FIRED SEAL ,~. .~~, ,-,.,~ . CUTTER - LEFT '''' ~nl (8887-8902. Gåôårål N otåš .... OD6.151) Date Note 10/29/2003 WAIVER ED WELL: T x IA COMMUNICATION Perf - '-- (9131-9252) - - - - - - - - FISH (9253-9256. OD;3.500) 'RODUCTION (0-9619. OD:7000. Wt:26.00) Perf - - (9369-9412) - - Perf == = (9375-9376) - - - Perf = = (9387-9390) :: :=: Perf = = (9382-9402) = = Perf = = (9441-9444) - - -- = -- ~ ~ Perf (9491-9498) - - - - - - 2C-09 and 2C-I6 Workovers e e Tom, r-'"' \ % '"\ - d-d--I As a follow up to our discussion this morning. 2C-09 and 2C-16 are currently producing on gas lift and we currently don't have a good number on shut in pressures. The reservoir engineer's early estimate of BHSIP based on offset wells was 3340 psi at 6200' tvd. For a absolute worst case of a full gas column to surface with a .65 gas gravity, maximum surface shut in pressure calculates at approximately 2900 psi. This is the number I stipulated in the Description Summary of Proposal for the two wells. The chances of ever seeing this pressure are obviously very small... the shut in period would have to be extremely long with a full gas column developing. This calculated pressure requires the use of a minimum 3000 psi stack with two rams and an annular. Since the available stack for Nabors 3S is currently a 13-5/8" 5000 psi stack, I stipulated a 3500 psi test pressure. We briefly shut in 2C-09 last week for 36 hours, and a bottom hole pressure of 2371 psi was measured at 5582' tvd with a SICP of 1250 psi (the annulus was likely mostly a column of gas lift gas). The extrapolated BHSIP at the "C" sand perfs was only 2500 psi. We don't feel this was a stabilized pressure. We will get a BHSIP with a longer shut in period just prior to starting the rig workover to better estimate our kill weight fluid. Call with questions. Regards, Steve Mukavitz ConocoPhillips Alaska, Inc. Drilling and Wells Group 907-263-4021 1 of 1 5/23/2006 11:35 AM ) ) '('~,iQ=' " u:r 1.:iJ~ ,/,'ß,ì\" iC""""',!,_TI ¡-:¡ ! I ~ " ':, ',' !.. i II '-".', :! 'i,l\ '\ : I ! i:".., .'\'~ !¡ ,1;'.\ ¡! ~ ? rù~ i: i J':....~~I\ i! ì L \::!J L-.:: t-.,' I~ l~ ~~:J ,~'-'~"'j if r~ j: ,L,r' :,[!I: ¡I"? \\ : i ;'¡ !, ¡I '\;:!.JJ ~\-~ FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 Brad Gathman Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 \ q)L\:-~~ Re: Kuparuk 2C-09 Sundry Number: 305-293 ~ANNED NO'# 0 ~ 2005 Dear Mr. Gathman: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Su perior Court unless rehearing has been requested. ---- DATED this/vcG.y of October, 2005 Enc!. (/ ) Cl} (D ./L,¿,/O 'J STATE OF ALASKA ~ I .) «(5' ALASKA Oil AND GAS CONSERVATION COMMISSION 1. Type of Request: o o o Suspend 0 o o Abandon Repair well Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 125' Pull Tubing 8. Property Designation: Kuparuk River Field 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9660' 6268' Casing Length Size CONDUCTOR 101' 16" SURFACE 4037' 9-5/8" PRODUCTION 9494' 7" Perforation Depth MD (ft): 9131'-9252',9369'-9412',9436'-9457',9490'-9496' Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Immediately Date: Signature RËCË/L- SEP :1 0 2~O~ Alaska Oil & G as Cons COrhft.. A, h . "'U' IS~ Waiver 0 Ie.. ora ee r 0 Time Extension 0 Re-enter Suspended Well 0 Perforate 0 o Stimulate 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: 184-221 6. API Number: 50-029-21237-00 9. Well Name and Number: 2C-09 Exploratory 0 Service 0 APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational Shutdown 0 Plug Perforations 0 Perforate New Pool 0 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD Perforation Depth TVD (ft): 5875'-5953',6049'-6082',6099'-6115',6141'-6145' Packers and SSSV MD (ft) no packer no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brad Gathman .~? 101' 4162' 9619' Tubing Size: 3-1/2" Contact: Title: Phone 659-7224 Commission Use Only Burst Collapse Tubing Grade: J-55 Tubing MD (ft): 8827' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Brad Gathman, 659-7224 Problem Wells Supervisor Date ? ...l.. ý... 0 S".. Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ 3oS--.;l.,:(?) Location Clearance 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 ~, 'S-:I ~~ ~~\\é":> \Of l-Ùl "-4 o.-\---\-M 'JQ:.<L D~5-- -\- c..:, L \-'t... ÞanlHt BF' . , , ø~ 8..- OCT 1 3' 2D05 ~ APPROVED BY URitjt N A L:HE COMMISSION Date 'of1~ Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk We1l2C-09 (PTD 1842210) September 27, 2005 This application is for an extension of Sundry 303-274 for we1l2C-09 (PTD 1842210) and to document that the AOGCC and ConocoPhillips concur the well maybe produced with a variance from 20 AAC 25 .200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. We1l2C-09 was originally completed in March 1985 as a gas lifted producer. The well was re- completed with an ESP in August 1998. The well had a workover in January 1999 to repair an ESP failure. The well produced via ESP until January 1999, at which time the pump failed a second time. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gas lift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gaslift mandrel at 6488' measured depth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 3296' and 5546' to keep annular fluids to the lowest possible depth. The well is equipped with a wellhead Safety Valve System as per regulations. As per this request, ConocoPhillips intends to produce 2C-09 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. .··~·~~()CO;~ill¡PS· ·A~~~~a, 1:~'50029212370a SSSV Type: NONE Annular Fluid: DSL/SW Reference Log: Last Tag: 8583 Last Tag Date:, .1/7/2000 : Casing String· CASINGS Description CONDUCTOR SURFACE PRODUCTION 1).ibinQ.Stii@+Tl1I3INß:>.··.·:··· Size r Top ··1""" 3.500 0 : Perforations Summary Interval TVD 9131 - 9252 5875 - 5963 Gas Lift mdrel/Dummy Valve 1 (97-98, Gas Lift andrei/Dummy Valve 2 (145-146, 00:5,500) Gas Lift mdrel/Oummy Valve 3 (193-194, 00:5,500) Gas Lift MandrelNalve 4 (3296-3297, Gas Lift MandrelNalve 5 (5546-5547, Gas Lift MandrelNalve 6 (6488-6489, Gas Lift mdrel/Oummy Valve 7 (8743-8744, 00:5,500) NIP (8822-8823, 00:3,500) PUMP (8837-8887, 00:6,151) SEAL (8887-8902, 00:6,151 ) Perf (9131-9252) FISH (9253-9256, 00:3,500) jROOUCTlON (0-9619, 00:7,000, Wt:26,OO) Perf (9369-9412) Perf (9375-9376) Perf (9387-9390) Perf (9382-9402) Perf (9441-9444) Perf (9491-9498) r ~ i i :)~:l 1 tI~ :: ./: ~ ~ :¡¡¡¡if:::::::: ~! :¡: ..." "" c IIII ~....~ tJ"""·:. I *'1"1 t:m:mm:. j~b ~ (''':(1 ~;: .:;: ~:: :): ~ ~ : }{i): ,... ~ ~..,"",. I : """"::, "'~I ~ ' ~ ~ : '" .:,: , ~ ~~;.ç..:.:,:-:.....",.." ::;:::;:::: . ,.~.:.". ~ , ..:. '.: ¡ : ,)j 1 i ~ i ~ ~i~ ~..."..,.,..". ~ '\ :::: 1 ~ i::: ~ t ..:: ~ ~ œ, ~ ::! ~ I ----t ~ ~ ~~ =Jt.1 ~ L~ ~ ~ E ~ ) ) KRU 2C-09 Well Type: PROD Orig Completion: 3/14/1985 Last W/O: 1/13/1999 Ref Log Date: TO: 9660 ftKB Max Hole Angle: 59 deg @ 7600 Angle @ TS: 44 deg @ 9131 Angle @ TO: 41 deg @ 9660 Rev Reason: Pull GLV Last Update: 5/14/2004 Top Bottom TVD Wt Grade Thread 0 101 101 62.50 H-40 0 4162 3058 36,00 J-55 0 9619 6238 26,00 J-55 1 TVD 1 Wt I' Grade . r Thread 5664 9.20 J-55 EUE 8RD Size 16.000 9.625 7.000 Bottom 8827 9369 - 9375 6049 - 6054 9375 - 9376 6054 - 6054 9376 - 9377 6054 - 6055 9377 - 9378 6055 - 6056 9378 - 9382 6056 - 6059 9382 - 9387 6059 - 6062 9387 - 9390 6062 - 6065 9390 - 9393 6065 - 6067 9393 - 9402 6067 - 6074 9402 - 9404 6074 - 6075 9404 - 9412 6075 - 6081 9436 - 9441 6099 - 6103 9441 - 9444 6103 - 6105 9444 - 9447 6105 - 6107 9447 - 9450 6107 - 6110 9450-9452 6110-6111 9452-9455 6111-6113 9455 - 9457 6113 - 6115 9491 - 9498 6141 - 6146 f;;~$.Wj;Mð@¡;øi$N~IV~$··:·,·.. ... St MD TVD Man Mfr Man Type Zone C-3,C-2,C-1,L B A-5 A-5 A-5 A-5 A-5,A-4 A-4 A-4 A-4 A-4 A-4 A-4 A-3 A-3 A-3 A-3 A-3 A-3 A-3 A-3 Status 1 97 97 Cameo KBMM 2 145 145 Cameo KBMM 3 193 193 Cameo KBMM 4 3296 2555 Cameo KBMM 5 5546 3825 Cameo KBMM 6 6488 4341 Cameo KBMM 7 8743 5609 Cameo KBMM v Mfr V Type CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO Depth 8822 8837 8887 8902 5714 Fišh~FISH Depth 9253 PUMP SEAL MOTOR Description FISH CAMCO 0 Nipple Centrilift 163GC10000 Series 513 Tandem Centrilift Tandem Seal Section Centrilift 570 HP KMH 3560/98 Ft SPF 121 12 Date 3/27/1985 Type Comment IPERF 120deg Ph; 5"Jumbo Jet 6 1 1 1 4 5 3 3 9 2 8 5 3 3 3 2 3 2 7 4 8/27/1985 RPERF 90deg V Ph;2, 125"BarKone II 5 8/27/1985 RPERF 90deg V Ph;2, 125"BarKone II 4 8/27/1985 RPERF 90deg V Ph;2.125"BarKone II 5 8/27/1985 RPERF 90deg V Ph;2.125"BarKone II 4 8/27/1985 RPERF 90deg V Ph;2.125"BarKone II 10 1 0/1 0/1994 RPERF (+/-)90 deg Ph; 2 1/8"EJ 11 1 0/1 0/1994 RPERF (+/-)90 deg Ph; 2 1/8"EJ 10 1 0/1 0/1994 RPERF (+/-)90 deg Ph; 2 1/8"EJ 11 1 0/1 0/1994 RPERF (+/-)90 deg Ph; 2 1/8"EJ 5 8/27/1985 RPERF 90deg V Ph;2,125"BarKone 4 8/27/1985 RPERF 90deg V Ph;2.125"BarKone 4 8/26/1985 RPERF 90deg V Ph;2,125"BarKone 5 8/26/1985 RPERF 90deg V Ph;2.125"BarKone 4 8/26/1985 RPERF 90deç¡ V Ph;2, 125"BarKone 5 8/26/1985 RPERF 90deg V Ph;2.125"BarKone 4 8/26/1985 RPERF 90deg V Ph;2, 125"BarKone 5 8/26/1985 RPERF 90deg V Ph;2.125"BarKone 4 8/26/1985 RPERF 90deç¡ V Ph;2.125"BarKone I 1 3/27/1985 IPERF 120deg Ph; 4". .J.un'1boJet.. DMY DMY DMY GLV OV OPEN DMY VOD Latch 1.0 BK 1.0 BK 1,0 BK 1,0 BK 1,0 BTM 1,0 1,0 BK2 Port TRO Date Vlv Run Cmnt 0,000 0 12/19/1999 0,000 0 7/22/1999 0,000 0 7/22/1999 0.188 1282 10/27/2003 0.250 0 10/27/2003 0,000 0 5/10/2004 0,000 0 1/26/1999 ID 2,750 0,000 0.000 0,000 Description Comment 3,5" TUBING STUB, GLM, PUP & PACKER W/28 BLAST RINGS & FIRED SWS CHEMICAL CUTTER - LEFT IN HOLE 8/24/98 G~n~~::dNQtøs Date I Note 10/29/2003 WAIVERED WELL: T x IA COMMUNICATION -,,-' ConocÓPh ill i pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 2, 2004 Mr. Tom Maunder ß011 ¡f Alaska Oil & Gas Commission ' ~J 333 West ih Avenue, Suite 10 5('-{,"" 0 1.-\ Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on April 29, 2004. Dowell-Schlumberger batch-mixed Arctic Set II cement to 15.7 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, ~~'~<L~~\-'\"'\ ~'<i.':\~ ~ ~~k~Q(\~ . \",;> "0 \- ú~'-.Y:>~-x),\ .~\\-~ Œ~Q:~~ -\ö~ -\-Ð \L ~ \ \ \o~~\¿\(. ~ \ \ (g\\'-^-..Qu,,- \-\O~~ \""v\ ..\-~~ ~\~~ ~<èw ~\.\~"'\(¡'-- "\\* Cû~-D~~~ . kf-1'Y1S-(~-Ot;j ?c~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment RECEIVED MAY 0 4 2004 Alaska Oil & Gas Cons. Commission Anchorage , , - ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field April 29, 2004 WEll PTD# SERVICE CEMENT TOP VOLUME 'J^ -J~ ~ NAME TYPE ft BBlS \jC)\'J~Q: 2C-09 1842210 Producer 54.0 9 ,., 'c~\ 2M-33 1960720 Producer 40.0 5 ç~ ~ 3H-21 1880080 Producer 34.0 5 \..\ 1'-\ 3H-24 1960150 Injector 25.0 3 ~< ;) 3H-28 1960370 Producer 20.0 4 g., <0 3H-32 2000010 Producer 10.0 2 \,"3 3K-12 1861650 Injector 48.0 10 (" < d.. Arctic Set 1115.7 PPG Cement \ ~~ "('~ \S I( \ \:> -.¡. ~~l Fs;" û. ~ "" -::::. . \if ~ b \0 y+ \- { STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon F1 Suspend E] Operation Shutdown E] Perforate BI Variance F1 Annular Disp. F1 Alter Casing Fl Repair Well E] Plug Perforations [] Stimulate Fl Time Extension E~] Other r-~ Change Approved Program Fl Pull Tubing Fl Perforate New Pool r'"] Re-enter Suspended Well [--'] 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development __ )[~] Exploratory 3. Address: Stratigraphic Fl Service [--1 6. APl Number: P. O. Box 100360 50-029-21237-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 125' 2C-09 8. Property Designation: 10. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9660' feet true vertical 6268' feet Plugs (measured) Effective Depth measured 9529' feet Junk (measured) true vertical 6168' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 101' 16" 101' 101' SURFACE 4037' 9-5/8" 4162' 2997' PRODUCTION 9494' 7" 9619' 6222' Perforation depth: Measured depth: 9131'-9252', 9369-9412', 9436'-9457', 9490'-9496' true vertical depth: 5875'-5953', 6049'-6082', 6099'-6115', 6141 '-6145' Tubing (size, grade, and measured depth) 3-1/2", J-55, 8827' MD. Packers & SSSV (type & measured depth) no packer no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation 451 737 2103 797 156 Subsequent to operation Not yet tested 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory E~ Development Daily Report of Well Operations __X 16. Well Status after proposed work: Oil["~ Gas["-] WAGE] GINJ r-'~ WINJ Fl WDSPLE] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I 303-274 Contact Jerry Dethlefs, 659-7043 Printed Name Je~ Dethlefs," ~-- ~ Title Problem Well Supervisor Form 10-404 Revised 2/2008 ORIGINAL ConocoPhillips Alaska, Inc. REPORT OF SUNDRY WELL OPERATIONS 10-404 Kuparuk Well 2C-09 (PTD 1842210) October 27, 2003 As per conditions set in Sundry #303-274, the following well work was performed on Kupamk well 2C-09. The operation was intended to lower the gaslift injection point into the tubing to the lowest point possible, minimizing the exposure of the casing to produced fluids. The original plan was to move the production valve (CV) to the lowest station (#7); however, scale problems necessitated moving up one station. Following are excerpts from the daily work logs. 10/24/03: ATTEMPT GL INSTALLATION. FOUND SCALE~ GRIT AT 6478' WLM. PUMPED DIESEL, WORKED 2.18" GAUGE RING DOWN TO 7600'. PUMPED 20 BBLS DOWN FLOWLINE. 10/25/03: WORKED DOWN TO 8180' WLM WITH 2.72 GAUGE RING WHILE PUMPING DIESEL. PUMP TRUCK CALLED AWAY. PULLED STA 5 AT 5418' WLM / 5546' RKB. 1" HFCV, BEK. GOT PUMP TRUCK BACK. ATTEMPT TO RUN DEEPER W/2.72" GAUGE RING. SAT DOWN HIGHER AT 7420'. SLOW PROGRESS. RAN 2.74 LIB. SHOWS SCALE. 10/26/03: PULLED STA 4. 3275' WLM / 3296'RKB, HFCV, BK. SET STA 4, 1" LGLV, 3/16 PORT, 1282 TRO. SET STA 5520' SLM / 5546' RKB. 1" OV, BOTTOM LATCH, 1/4" PORT. ConocoPhillips i Gas landret/Durnmy Valve 1 (97-98, Gas Lift landrel/Dummy Valve 2 (145-146, OD:5.500) Gas Lift landrel/Dumrny Valve 3 (193-194, OD:5.500) Gas Lift MandrelNalve 4 (3296-3297, OD:5.500) Gas Lift MandrelNalve 5 (5546-5547, OD:5.500) Gas Lift MandrelNalve 6 (6488-6489, OD:5.500) NIP (8822-8823, OD:3.500) PUMP (8837-8887, OD:6.151) SEAL --/ (8887-89O2, OD:6.151) Perf (9131-9252) FISH (9253-9256, OD:3.500) Ped (9369-9412) Perf (9387-9390) Perf (9441-9444) Pert (9491-9498) ,ska, Inc. KRU 2C-09 -- 2C-09 APl: 1500292123700 Well Type: PROD Orig Completion: 3/14/1985 Last W/O: 1/13/1999 Ref Log Date: TD: 9660 ftKB NONE DSL/SW SSSV Type: Annular Fluid: Reference Log: Last Tag: 8583 Last Tag Date: 1/7/2000 Casing String - CASINGS Description CONDUCTOR Max Hole Angle: ! 59 deg @ 7600 Size 16.000 Top 0 Bottom 101 SURFACE 9.625 0 4162 3058 PRODUCTION 7.000 0 9619 6238 Angle @ TS:l~deg @ 9131 Angle @ TD: 41 deg @ 9660 Rev Reason: GLV design Last Update: 10/27/2003 Gas Lift Mandrels/Valves 9131 -9252 5875-5963 9369-9375 6049-6054 9375-9376 6054-6054 9376-9377 6054-6055 9377-9378 6055-6056 9378-9382 6056-6059 9382-9387 6059-6062 9387-9390 6062-6065 9390-9393 6065-6067 9393-9402 6067-6074 9402-9404 6074-6075 9404-9412 6075-6081 9436-9441 6099-6103 9441 - 9444 6103 - 6105 9444 - 9447 6105 - 6107 9447 - 9450 6107 - 6110 9450-9452 6110-6111 9452-9455 6111-6113 9455-9457 6113-6115 9491 -9498 6141 -6146 Interval Perforations Summary Tubing String - TUBING Size Top i Bottom TVD Wt Grade Thread 3.500 0 I 8827 5664 9.20 J-55 EUE 8RD I Zone /Statusl Ft ISPFI Date )Type I Comment 3,-3,C-2,C-1,~ 121 12 3/27/1985 IPERF 120deg Ph;5"Jumbo Jet A-5 / 6 4 8/27/1985 RPERF 90deg V Ph;2.125"BarKone II A-5 [ I 1 5 8/27/1985 RPERF190deg V Ph;2.125"BarKone II A-5 / I I I 4 I 8/27/1985 I RPERFI9Odeg V Ph;2.125"BarKone II A-5 / 1 5 8/27/1985 I RPERF 190deg V Ph;2.125"BarKone II A-5,A-4 ~ 4 4 I 8/27/1985 I RPERFI90deg V Ph;2.125"BarKone II A-4 ] 5 I 10 I10/10/19941RPERF/(+/-)90degPh;21/8"EJ A-4 / I 3/11 /10/10/1994/RPERF/(+/')90degPh;21/81'EJ A-4 / I 3110 I10110/19941RPERFI(+/')90degPh;2118''EJ A-4 ~ / 9 /11 /10/10/19941RPERF/(+/-)90degPh;21/8"EJ A-4 / / 2 I 5 /8/27/19851RPERFt90degVPh;2.125"BarKonell A-4 / ~ 8 ~ 4 ~ 8/27/1985 / RPERF/90deg V Ph;2.125"BarKone II A-3 / I 5 / 4 /8/26/19851RPERF/90degVPh;2.125"BarKonell A-3 / / 3 / 5 /8/26/19851RPERF/90degVph;2.125"BarKonell A-3 I / 3 / 4 ~8/26/1985/RPERF~90degVPh;2.125"BarKonell A-3 / / 3 J 5 ) 8/26/1985) RPERF)90deg V Ph;2.125"BarKone II A-3 I / 2 / 4 )8/26/19851RPERF[90degVPh;2.125"BarKonell A-3 / / 3 ) 5 /8/26/1985)RPERF)90degVPh;2.125"BarKonell A-3 / ) 2 / 4 / 8/26/19851RPERF/90degV Ph;2.125"BarKone II A-3 | ~ 7 ) 1 /3/27/1985/ IPERF~120degPh;4"JumboJet St MD TVD Man I Man I V Mfr I V TypeI V OD I Latchl Port I TROI Date VIv i i Mfr Type Run I Cmnt 1I 971 971 Camco/ KBMM I CAMCOI DMY 11.01 BK 10.000I 0 112/19/19991 2 145 145 Camco KBMM CAMCO DMY 1.0 BK 0.000 I 0 17/22/19991 3 193 193 Camco KBMM CAMCO DMY 1.0 BK 0.000 / 0 /7/22/1999/ 4 3296 2555 Camco KBMM CAMCO GEV 1.0 BK 0.188 I 1282 110/27/2003/ 5 I 5546l 3825l Camc°l KBMM I CAMCO I OV I 1.0 I BTM I 0.250 [ 0 110/27/2003/ 6 / 64881 43411 Camco / KBMM [ CAMCO I HFCV / 1.0 I BEE / 0.000 / 0 /1/8/2000/ 7 [ 87431 5609/ Camco/ KBMM I CAMCO I DMY I 1.0 / BK2 / 0.000 / 0 [1/26/1999/ Other (plugs, equip., etc.- JEWELRY Depth I TVD I Type Description '21D0-75 8822 J 5661 I NIP CAMCO D Nipple 8837 I 5671 I PUMP Centrilift 163GC10000 Series 513 Tandem 0.000 8887 5704 I SEAL Centrilift Tandem Seal Section 0.000 8902 5714 MOTOR Centrilift 570 HP KMH 3560/98 0.000 Fish - FISH Depth I 9253 FISH Description Comment 3.5" TUBING STUB, GLM, PUP & PACKER W/28 BLAST RINGS & FIRED SWS CHEMICAL CUTTER - LEFT IN HOLE 8/24/98 TVD Wt Grade Thread 101 62.50 H-40 J 36.OO J-55 26.00 J:55 ALASI~k OIL AND GAS CONSERVATION COMMISSIO~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: KRU Kuparuk Pool. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 ESP failed flowing well KRU 2C 16 184-202 303-275 ESP failed flowing well KRU 3B 13 185-023 303-276 ESP failed gas lifted well KRU 3A 01 185-186 303-277 ESP failed gas lifted well KRU 3B 14 185-024 303-278 ESP failed gas lifted well KRU 3H 04 187-076 303-279 ESP operating KRU 3J 10 185-250 303-280 ESP failed gas lifted well KRU 3M 13 187-040 303-281 ESP failed gas lifted well KRU 3M 14 187-051 303-282 ESP operating Dear Mr. Dethlefs: You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells capable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 11, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3H-16 should be allowed to continue production with no restrictions. , The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configured. 3. In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C-16 should be changed to be similar to the other failed ESP wells with the fluid entry 'I' Jerry Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, Rand5; Ruedrich Commissioner ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon [--1 Alter casing I~l Change approved program ~] Suspend r~ Operation Shutdown I--I Perforate Repair well I~l Plug Perforations r--1 Stimulate Pull Tubing I--I Perforate New Pool [~ [] Variance [~ Time Extension Re-enter Suspended Well Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ :[~ Exploratory Stratigraphic I---1 Service 5. Permit to Drill Number: 184-221 6. APl Number: 50-029-21237-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 125' 2C-09 8. Property Designation: 10. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9660' 6268' 9529' 6168' 9253' (fish) Casing Length Size MD TVD Burst Collapse CONDUCTOR 101' 16" 101' 101' SURFACE 4037' 9-5/8" 4162' 2997' PRODUCTION 9494' 7" 9619' 6222' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9131 '-9252', 9369-9412', 9436'-9457', 9490'-9496' 5875'-5953', 6049'-6082', 6099'-6115', 6141 '-6145' 3-1/2" J-55 8827' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no packer no SSSV no SSSV 12. Attachments: Description Summary of Proposal I-~ 13. Well Class after proposed work: Detailed OPerations Program r'-I BOP Sketch r-'l Exploratory [~ Development [] Service r"-I 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil E~ Gas E~ Plugged ['-1 Abandoned WAG [~ GINJ [] WINJ [~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name //Jerry Dethlef, s--~, ¢----~., _ Signature ~/~ ~ ~ l [~ Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone 659-7043 Date ~~.~..~ Conditions of approval: Notify Commission so that a representative may witness ISundry Number: Plug Integrity E~] BOP Test [~ Mechanical Integrity Test E~ Location ClearancREf% j~,~,, Subsequent Form Required: ~0~ ~ OCT Approved by: . COMMISSIONER THE COMMISSION SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 2C-09 (PTD 1842210) September 11, 2003 This application for Sundry approval for well 2C-09 (PTD 1842210) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 2C-09 was originally completed in March 1985 as a gas lifted producer. The well was re- completed with an ES~ 1998. The ~eli ha~orkover in January 1999 to repair an ESP failure. The well ~-6duced vi'g ESP until Janua~ich time the p----fimp failed a second time. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing via (3) gaslift mandrels from 3296'- 6~th. From that point produced fluids flow up the tubing and Out the wellhead to production facilities. Gaslift is maintained on the well to keep annular fluids to the lowest possible depth (top open GLV). The well is equipped with a wellhead Safety Valve System as per regulations. Recent well test data shows the following results: WELL TEST SUMMARY REPORT " TOTAL DS WL LENGTH CHK FTP FTT OIL WATERI%WClFLUID GAS GOR 2C 9 18:00 176 2C 9 20:49 176 156 126 451 2103 ~, 82 //2554 737 1635 484 2C 9 20:00 176 149 125 537 2139 ~80 ~, 2676 674 1255 436 2C 9 18:00 176 152 127 437 2147 /83 12584 777 1778 499 2C 9 20:00 176 149 127 446 2176 I 83 /2622 819 1836 506 FORM TOTAL LIFT GAS GLR RATE 499 493 513 5O8 GAS PRESS 797 797 775 As per this request, ConocoPhillips intends to produce 2C-09 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. ARCO Alaska, Inc. A Gas Lift -- tandrel/Dummy Valve 1 (97-98, Gas Lift landrel/Dummy Valve 2 (145--146, 0D:5.500) Gas Lift ~andrel/Dummy Valve 3 (193-194, 0D:5.500) Gas Lift MandrelNalve 4 (3296-3297, 0D:5.500) Gas Lift MandrelNalve 5 (5546-5547, 0D:5.500) Gas Lift MandrelNalve 6 (5488-6489, 0D:5.500) NIF (8822-8823, 0D:3.500) PUMF (8837-8887, 0D:6.151) SEAL -/ (8887-8902, 0D:6.151) Perf (9131-9252) FISH (9253-9256, 0D:3.500) Per[ (9369-9412) Per[ (9387-9390) Per[ (9441-9444) Per[ (9491-9498) GKA 2C-09 2C-09 APl: J 500292123700 SSSV Type:I NONE Annular Fluid: DSL/SW Reference Log:J Last Tag: 8583 Last Tag Date: 117100 Casing String - CASINGS Well Type: J PROD Odg Completion: J 3/14/85 Last W/O: 1/13/99 Ref Log Date: J TD: 9660 ftKB Max Hole Ang e: 59 deg @ 7600 Last Update: Angle @ TS: 144 de.q ~,, 9131 Angle @ TD: 141 decj @ 9660 Rev Reason: TAG (POSSIBLE SCALE IN TUBING) BY VG 1/10/00 Size Top Bottom I TVD I Wt IGrade I Thread 16.000 0 101 [ 101 [ 62.50 [ H-40I 9.625 ....... 7.000 0 9619 / 6238 / 26.00 ~ J-SS Tubing String - TUBING Size Top Bottom TVD Wt Grade Thread 3.500 0 8827 5664 9.20 J-55 EUE 8RD Perorations Summa~ Inte~al ~D ~ Zone ~Status~Feet~SPF~ Date ~ Ty~e ~ Comment 9369 - 9375 ~ 6049- 6054 ] A-5 ~ ~ 6~ 4 ~8/27/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9375 - 9376 ~ 6054 - 6054 ~ A-5 ~ ~ 1 ~ 5 ~8/27/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9376 - 9377 ~ 6054 - 6055 ~ A-5 ~ ~ I ~ 4 ~8/27/85] RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9377 - 9378 ~ 6055 - 6056 ~ A-5 ~ ~ 1 ~ 5 ~8/27/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9378 - 9382 ~ 6056 - 6059 ~ A-5,A-4 ~ ~ 4 ~ 4 ~8/27/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9382- 9387 I 6059- 6062 I A-4 I I 5[ 10 ~0/10/9~ RPERF ~(+/-) 90 deg. Phasing; 2 1/8" EnerJet 9387 - 9390 ~ 6062 - 6065 ~ A-4 ~ ~ 3~ 11 ~0/10/9~ RPERF ](+/-) 90 deg. Phasing; 2 1/8" EnerJet 9390- 9393 ~ 6065- 6067I A-4 I I 3~ lO~OI1019~RPERF~(+l-)90deg. Phasing;2118"EnerJet 9393 - 9402 J 6067 - 6074 ~ A-4 ~ ~ 9~ 11 ~ 0/10/9~ RPERF ](+/-) 90 deg. Phasing; 2 1/8" EnerJet 9402 - 9404 ~ 6074 - 6075 ~ A-4 ~ ~ 2~ 5 ~8/27/85~ RPERF ]90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9404 - 9412 ~ 6075 - 6081 [ A-4 ~ ~ 8~ 4 ~8/27/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9436 - 9441 ~ 6099 - 6103 ~ A-3 ~ ~ 5~ 4 ~8/26/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9441 - 9444 ~ 6103 - 6105 ~ A-3 ~ ~ 3~ 5 ~8/26/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9444 -9447 ~ 6105-6107 ~ A-3 ~ ~ 3~ 4~8/26/85~ RPERF ~90 deg. 'V' Phasing; 2 1/8" Bar Kone II 9447 - 9450 6107 - 6110 A-3 ~ 3 5 ~/26/8~ RPERF 90 deg. 'V' Phasing; 2 1/8" Bar Kone II -~~'~'/-~'0~-~'~--I .... ~:~"-"1 ......... 9452-9455/ 6111-61~3 / A-3 I / 31 5~8126185~RPERFI90deg.'V'Phasing;2118"aarKonell 9455-9457 [ 6113-6115 ~ A-3 ~ ~ 2~ 4~8126185~RPERF~90deg.'V'Phasing;2118"BarKonell 9491-9498 ~ 6141-6146 A-3 [ 7 l~3/27/85~IPERF 120deg. Phasing; 4" Jumbo Jet Gas LiffMand~elS~al~es:; :: : ::: :: :::::: : ::: : :: Stn MD ~D' Man '] Man VM'fr VType VOD Latch PoA TRO Date ~ Vlv I I I Ufr ~ Type ~ I ~ J I I r Run IComment 1.. 97 ...97 Camco KBt. IM . C~O DMY 1.9 ~K...0.00O 0 12'~9.'99 .. 2 145 145 Camco KBM.M CAMCO D;.tY 1.9 BK 0.000 0 7 22 99 3 193 193 C,.-,m¢:o KBMM CAMCO P,:..IY 1.0 BK 0.000 0 -7 4 3296 2555 C&mco KB;.lt.1 C,\MCO HFCV 1.0 BE/` 0.000 0 1 ~"30 5 5546 3825 C,.-,."ic-(~ '"KBMM CAMCO A'?C~.7'' 1.0 B.--./`0 0C,0 0 1 ~ 90 6 6488 433,'1'"Camco KB:,IM C/\~,IC~ ' HFCV 1 ,') 'B~/`' 0.000 0 1 ,". 00 " 7 8743 5609 Car".co KB:.lr.1 CA%IC~ ....... D;.1Y 1.0 '~l~""".r'~'.'i;~'O00 ~'2~9~-i ....... ............................................ Other (plugs, equip., etc.)- JEWELRY Depth TVD Type Doscription ID I 8.8221 56611.. _N!.P. I CAMCO D Nip. Fie I 2.750 ............. ...... 8837 5671 PJMP Centril!ft 163GC~0000 Ser,es 513 Tand,'.;rn 9.C,00 8.~¢,7 5704 SEA'L .... -~,~i{~il:[t i ando.~ S.aa', Secti(~ .................. 9.000 8902 571'4 '--M--~;','OR Contrilift 570-~,~ ~,';~1'~5(~0 98 ........... 0.¢.90 ................................................................... Fish - FISH Depth Description 9253 F SH Comment 3.5" TUBING STUB, GLM, PUP & PACKER W/28 BLAST RINGS & FIRED SWS CHEMICAL CUTTER - LEFT IN HOLE 8/24/98 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 1, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORiGiNAL Subject: 2C-09 (Permit No. 84-221) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the Report of Sundry Well Operations for the recent workover operations on KRU 2C- 09. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Drilling Engineer AAI Drilling RECEIVED Oil & ~as Cons. Commjssio~ Anchora~o~. GLA/skad STATE OF ALASKA ALAS14e-,, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Stimulate__ Plugging __ Perforate _ Pull tubing ._X Alter casing __ 2. Name of Operator: 15. Type of Well: ARCO Alaska, Inc. I Development 3. Address: Exploratory _~= P.O. Box 100360 Stratagrapic Anchorage, AK 99510-0360 Service 4. Location of well at surface: 115' FNL, 78' FEL, Sec. 21, T11N, R9E, UM At top of productive interval: 1285' FNL, 1368' FEL, Sec. 15, T11N, R9E, UM At effective depth: At total depth: 1007' FNL, 1145' FEL, Sec. 15, T11N, R9E, UM Repair well __ ther __X Install ESP 6. Datum of elavation (DF or KB feet): 31' Rig RKB 7. Unit or Property: Kuparuk River Field 8. Well number: 2C-09 9. Permit number/approval number: 84-221/ 10. APl number: 50-029-21237 11. Field/Pool: Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured 9660' true vertical 6269' Effective Depth: measured 9253' true vertical 5954' Casing Length Size Conductor 75' 16" Surface 4136' 9.625" Production 9594' 7" Liner Plugs (measured) Junk (measured) Cemented 250sx CS II 1000 sxAS III & 600 sx Class G 430 sx Class G & 250 sx AS I Measured depth 101' 4162' 9620' True verticaldepth 101' 2997' 6222' Perforation Depth measured true vertical 9131'-9252',9369'-9412',9436'-9457',9490'-9496' 5875'-5953',6049'-6082',6099'-6115',6141'-6145' ORIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 8950' Packers and SSSV (type and measured depth) None t3. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) Alaska C .: 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~ Oil X Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 Suspended__ Service__ Title: Drilling Team Leader Questions? Carl Mark Chambers 265-1319 Date '~/ I /~ ? Prepared by Sharon AIIsup-Drake SUBMIT IN DUPLICA~.~ Date: 2/23/99 ARCO ALASK3~ INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2C-09 RIG:NORDIC % 3 WELL ID: 999294 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:01/08/99 START COMP:01/07/99 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21237-00 01/07/99 (C1) TD: 9620' PB: 9529' 01/08/99 (C2) TD: 9620' PB: 9529' 01/09/99 (C3) TD: 9620' PB: 9529' 01/10/99 (C4) TD: 9620' ?B: 9529' 01/11/99 (C5) TD: 9620' PB: 9529' 01/12/99 (C6) TD: 9620' PB: 9529' 01/13/99 (C7) TD: 9620' PB: 9529' TAKE ON SEA WATER. R/U FM MW: 0.0 UNKNW SUPV:DONALD L. WESTER Turn key rig move pad to pad from 2T to 2C. Accept rig @ 1800 hrs. 1/7/99. Rig up. N/U 11" 5M TRIPLE GATE BO MW:ll.2 BRINE SUPV:DONALD L. WESTER Start kill pumping seawater down 3.5" tubing. Displace seawater w/kill weight fluid. SPOTED LCM PILL ACROSS PE MW:ll.2 BRINE SUPV:DONALD L. WESTER Circulate down tubing with kill fluid. Monitor well dead on tubing flowing from annulus. Shut in. Test BO?E to 250/3500 psi. Circulate down tubing w/ll.2 ppg kill fluid. Monitor well. Losses increasing WELL STARTED TO FLOW W/ 2 MW:ll.2 BRINE SUPV:DONALD L. WESTER Pump LCM pill, calcium carbonate & flow-vis across perforation 'C' sand. Shut down monitor well. Spot %2 LCM pill across perforation. Shut down monitor well. Pull 3.5" tubing. CONTNUE TO MAKE UP 3-1/2" MW:ll.2 BRINE SUPV:DONALD L. WESTER POOH w/ESP stand back 3.5" tubing change seal ring. Well started to flow w/pump 250' below surface. Close Hydril bull head 40 bbls slowly. Well started taking fluid again 15 bph. Continue to POOH. Fluid loss increasing to 20 bph. Spot LCM pill 45 ppb calcium carbonate and flow-vis across perforation. POOH w/3.5" tubing. TESTING TUBING TO 2500 PS SUPV:D.P.BURLEY RIH with ESP assembly. MW:ll.2 BRINE MOVING RIG TO 3M-23. MW:ll.2 BRINE SUPV:D.P.BURLE¥ Make final splices of ESP cable and pressure sensor, Date: 2/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 connect to penetrators, well began flowing slightly during last hour of make up. Tested tubing to 2500 psi. ND BOPE. NU tree and test packoff to 250/5000 psi. Freeze protect tubing. Released rig @ midnight. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing X __Stimulate_ Plugging__ Perforate_ Alter casing __ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1 15' FNL, 78' FEL, Sec. 21, T11 N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, Sec. 15, T11 N, R9E, UM At effective depth At total depth 1007' FNL, 1145' FEL, Sec. 15, T11 N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service _ 9660' feet Plugs (measured) 6269' feet 6. Datum elevation (DF or KB) RKB 125' 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-09 9. Permit number/approval number 84-221/398-197 10. APl number 50-029-21237 11. Field/Pool Kuparuk River feet Effective depth: measured true vertical 9529' feet 6168' feet Junk (measured) fish @ 9253' (refer to note below) Casing Length Structural Conductor 75' Surface 4136' Intermediate Production 9594' Liner Size Cemented Measured depth True vertical depth 16" 250 SX CS II 101' 101' 9.625" 1000 sx AS III & 4162' 2997' 600 sx Class G 7" 430 sx Class G & 9620' 6222' 250 sx AS I Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 9131'-9252', 9369'-9412', 9436'-9457', 9490'-9496' 5875'-5953', 6049'-6082', 6099'-6115', 6141 '-6145' 3.5", 9.3#, J-55 @ 8957' N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf 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 16. Status of well classification as: Water Injector__ Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 0-4~04 Rev 05/17/89 Form 1 Title Kuparuk Drilling Team Leader Date SUBMIT IN DUPLICATE NOTE: Old completion equipment left in hole top of fish 9253' cut off, GLM, pup, seal assy. Otis 7' x 3.5" 'WD' packer assy EOT 9311' with 28 blast ring broken up on top of GLM. ~t~. Date: 10/6/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2C-09 RIG:NORDIC ~ 2 WELL_ID: 999244 TYPE: AFC: 999244 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:08/12/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21237-00 08/12/98 (C1) TD: 0' PB: 0' 08/13/98 (C2) TD: 0' PB: 9529' 08/14/98 (C3) TD: 0' PB: 9529' 08/15/98 (C4) TD: 0' PB: 9529' 08/16/98 (C5) TD: 0' PB: 9529' 08/17/98 (C6) TD: 0' PB: 9529' 08/18/98 (C7) TD: 0' PB: 9529' 08/19/98 (C8) TD: 0' PB: 9529' Rigging up MW: 0.0 SUPV:RICK OVERSTREET Turn key rig move from pad to pad 2C. Road from pad 1G soft, rig stuck several times. Rig on location @ midnight. MW:ll.3 BRINE SUPV:RICK OVERSTREET Spot and level rig. Accept rig @ midnight 8/13/98. Circulated well to seawater. POH W/ 3 1/2" TUBING, CHA MW: 0.0 BRINE SUPV:RICK OVERSTREET Spot Thixsal pill. Monitor well, dead. N/D tree, N/U BOPE and test. RIH w/chemical cutter, cut 3.5" tubing at 8941' PULLING LAST OF 3 1/2" TU SUPV:RICK OVERSTREET Continue POOH with 3.5" tubing. MW:ll.3 BRINE CBU AFTER ENGAGING FISH. SUPV:RICK OVERSTREET Continued POOH with 3.5" tubing. MW:ll.3 BRINE POOH WITH OVERSHOT. MW:ll.3 BRINE SUPV:RICK OVERSTREET Continue to TIH with 3.5" DP. Tag fish. POOH slowly, hole swabbing. RIH w/overshot. Latched onto fish @ 9079'. Could not circulate and could not pull. CONTINUE POOH W/ WASHPIPE MW:ll.3 BRINE SUPV:DONALD L. WESTER Release overshot f/fish @ 9079'. Wash over fish from 9079' to 9195' just by sliding over. Stop unable to slide down. Fluid loss during washover. CONTINUE CIRC GAS, RAISE MW:ll.3 BRINE SUPV:DONALD L. WESTER P/U 5.75" overshot dressed w/pack off & 3.5" grapple. RIH on 3.5" DP. Well started kicking through drill pipe install dart valve RIH to 1869' Circulate mud gas & oil cut. RIH 08/20/98 (C9) TD: 0' PB: 9529' 08/21/98 (C10) TD: 0' PB: 9529' 08/22/98 (Cll) TD: 0' PB: 9529' 08/23/98 (C12) TD: 0' PB: 9529' 08/24/98 (C13) TD: 0' PB: 9529' to 4268' Circulate mud light oil cut. RIH w/5.75" overshot to top of fish @ 9059' Work over fish @ 9079' Work fish free & CBU gas @ bottoms up. Raise mud weight to 11.5 ppg. POOH FOR SHORT CATCH OVER MW:ll.3 BRINE SUPV:DONALD L. WESTER Raise weight to 11.5 ppg brine. Observe well dead. POOH w/fish (blast joints). RIH w/ 5.75" overshot. Work down to top of fish @ 9248' Unable to get over 3.5" stub to grapple. SET BAKER 7" STGORM PKR @ MW:ll.3 BRINE SUPV:DONALD L2 WESTER POOH w/BHA 95. No fish. RIH with overshot to 9222'. Work down to fish @ 9248' POOH (no fish). RIH to 9200' scraper @ 9000' P/U ESP PUMP WIRE IN CABL MW:ll.3 BRINE SUPV:DONALD L. WESTER Set 7" storm packer 40' below rotary table and test. N/D BOPE to change out tubing spool. Pull storm packer. CONTINUE RUNNING 3.5" ESP SUPV:DONALD L. WESTER Run 3.5" ESP completion. MW:ll.5 BRINE RELEASE RIG @ 1800 HRS 8/ MW: 0.0 DOIL SUPV:DONALD L. WESTER Continue RIH w/3.5" ESP completion. N/D BOPE, install tree. Freeze protect well. Release rig @ 1800 hrs. 8/24/98. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 6, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2C-09 (Permit No. 84-221/398-197) Report of Sundry Well Operations Dear Mr. Commissioner: Enclosed is the report of Sundry Well Operations to cover any changes made to the completion during the recent workover operations on KRU 2C-09. If there are any questions, please call 265-6120. Sincerely, Graham C. Alvord Kupamk Drilling Team Leader GCA/skad 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 _ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate_ Pull tubingX Variance_ Perforate_ Other X Install ESP 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 115' FNL, 78' FEL, Sec. 21, T11 N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, Sec. 15, T11 N, R9E, UM At effective depth 1067' FNL, 1192' FEL, Sec. 15, T11N, R9E, UM At total depth 1007' FNL, 1145' FEL, Sec. 15, T11 N, R9E, UM 5. Type of Well: Development _~X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 125' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-09 9. Permit number 84-221 10. APl number 50-029-21237 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 9660' feet Plugs (measured) None (approx) true vertical 6269' feet Effective depth: measured 9529' feet Junk (measured) (approx) true vertical 6168' feet Casing Length Size Cemented Structural Conductor 75' 16" 250 sx CS II Surface 4136' 9.625" 1000 sx AS III Intermediate & 600 sx Class G Production 9594' 7" 430 sx Class G Liner & 250 sx AS I ORIGINAL Measured depth True verticaldepth 101' 101' 4162' 2997' 9620' 6222' Perforation depth: measured 9131'-9252', 9369'-9412', 9436'-9457', 9490'-9496', true vertical 5875'-5953', 6049'-6082', 6099'-6115', 6141'-6145' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 8957' Packers and SSSV (type and measured depth) NONE RECEIVED sEP 19glt Naska 011 & Gas Cons. C0mmls~lon Anchorage 13. Attachments Description summary of proposal X Contact Mark Chambers at 265-1319 with any questions. Detailed operation program __ BOP sketch _X 14. Estimated date for commencing operation November 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_ 4,~ '(~, ~ Title Kuparuk DrillinqTeam Leader · / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so represe/qtative may witness Plug integrity _ BOP Test _~' Location clearance Mechanical Integrity Test_ Subsequent form require 10- ,Ung~nal Signed By Approved by the order of the Commission David W. Johnston Commissioner Form 10-403 Rev 06/15/88 IAppr°val ~.~ ,(~'-- <3~ Date p----?~ -- ~ ~) SUBMIT IN TRIPLICATE KRU 2C-09 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH w/wireline and set standing valve in D-Nipple @ 8824" 2. RIH w/wireline and pull Dump Kill Valve from GLM gl @ 8751' 3. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt - 11.5 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH w/3-1/2" ESP Completion standing back tubing and spooling up cable to re-run in this well.. 5. Locate and repair electrical short in ESP Cable. 10. Re-run 3-1/2" ESP Completion on as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivities as needed. 11. ND BOPE. NU and test tree. Freeze protect well with diesel. Lower Limit: 2.5 days Expected Case: 5.0 days Upper Limit: 6.0 days Short is located at tubing hanger Short is located at the pump and no problems are encountered pulling or re-running ESP completion. Difficulties encountered pulling or re-running ESP completion MAC 9/24/98 2C-09 Proposed Completion L. 3-1/2' 5M FMC Eccentric tubing hanger with 'BIW' penetrators for ESP cable (125 amp) and downhole gauge conductor wire. 3-1/2' L-80 EUE 8rd tubing pup below hanger. Flat #1 power cable with tech wire in double armor wrap K. Rerun 3-1/2" J-55 EUE 8rd Mod tbg to surface. Space-out 3-1/2' x 1" Camco 'KBMM' mandrels (box x box', w/DV's as follows: GLM# MD-Oriqinal RKB 2 6458' 3 5546' 4 3358' 5 100' NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 10' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as per procedure Cable splice from motor lead to flat #1 power cable adjacent to 10' pup above pump LaSalle ////1 Protectolizers at each flange of ESP assembl, J. 3-1/2' X 1 ' Camco 'KBMM' mandrel (box x box) with STS-1 dump kill valve (pinned for 3500 psi tubing to casing differential). I. Pup jt, 3-1/2' x 10' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 10' pup and full jt. H. I jt Rerun 3-1/2" J-55 EUE 8rd Mod tubing with LaSalle cable protector on cplg below joint. G. I jt of Rerun 3-1/2' J-55 EUE 8rd Mod tubing with annulus sensing Baker 'Sentry' gauge clamped to OD of tubing. Conductor Wire for gauge will be run to surface with-in the 2nd Armor wrap of ESP cable. F. 3-1/2' Camco 'D' landing nipple with 2.75' No-Go profile. Standing Valve to be set as nipple is made-up. E. Pup jt, 3-1/2' x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. D. Centrilift '163GC10000' Series 513 Tandem Pump with bolt-on intake and bolt on discharge head. 3-1/2' x 10' L-80 handling pup on top. C. Centrilift 'GRSXBCTH6' Tandem Rotary Gas Separator. B. Centrilift 'GST34B HL PFS' Tandem Seal Section. A. Centrilift '570 HP KMH 3560/98' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/- 8961' MD RKB. 7" 26# J-55 @ 9619' C Sand Perfs 9131' - 9252' A Sand Peds PBTD @ 9529" 9369'-9382' 9382'-9402' 9436'-9457' 9490'-9496' RECEIVED SEP 25 1998 Alaska 0il & Gas Cons. Commission" Anchorage MAC 8/3/98 MEMORANDUM TO: David Jo~n, Chairman~ State of Alaska Alaska Oil and Gas Conservation Commission DATE' August 14,1998 THRU: Blair Wondzell, ~~,~e FILE NO: .DOC P. I. Supervisor FROM: Larry Wade,~'~ SUBJECT: Petroleum Idfspector BOP Test Nordic 2 KRU 2C-09 PTD 84-1 O5 August 14,1998: I traveled to Kuparuk to witness a BOP test on Nordic 2. The rig had to wait on mud for 24 hours to kill the well and the rig showed it. The rig was clean and in order. Even with all the new employees, the test went well and the equipment worked as expected. SUMMARY: i witnessed a BOP test on Nordic 2, 0 failures,3.5 hours. Attachments' abvghnfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nordic Rig No. Operator: ARCO Well Name: KRU 20-9 Casing Size: 7" Set @ 9529' Test: Initial X Weekly Other 2 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 8/14/98 Rig Ph.# 859-7565 Rick Overstreet Shawn Mckernan T. R. Meridian MISC. INSPECTIONS: Location Gen.: ok Well Sign X Housekeeping: (Gen) Drl. Rig ok PTD On Location X Hazard Sec. X - Standing Order Posted X "' BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/3,000 P 250/3,000 250/3,000 250/3,000 250/3,000 250/3,000 250/3,000 250/3,000 P P P P P P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. Test Pressure P/F 250/3, 000 P 250/3,000 P 250/3,000 P 250/3, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 36 250/3, 000 P 12 250/3, 000 P 1 X Functioned Functioned X ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2200 3, 000 2,200 minutes 25 sec. minutes 25 sec. x Remote: x Psig. :, ,,, i :' TEST RESULTS: Number of Failures: 0 ,Test Time: 3.5 Hours. NumDer of valves testea 43 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to tile AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev.12/94) Abvghnfe.xls " STATE OF ALASI<A ' A.AS o,. CONS .VAT,ON COrM,SS,ON APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon_ Suspend_ Operation Shutdown Re-enter suspenoe - e _ - ;~~~ Alter casing _ Repair well _ Plugging ~ ~me e~ension _ Stimulate _ Change approved program _ Pull tubing ~ Vadance _ Pedorate _ Other X Install 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 115' FNL, 78' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, Sec. 15, T11N, R9E, UM At effective depth 1067' FNL, 1192' FEL, Sec. 15, T11 N, R9E, UM At total depth 1007' FNL, 1145' FEL, Sec. 15, T11 N, R9E, UM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 125' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-09 9. Permit number 84-221 10. APl number 50-029-21237 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured 9660' feet (approx) true vertical 6269' feet Plugs (measured) None Effective depth: measured 9529' feet Junk (measured) (approx) true vertical 6168' feet Casing Length Size Cemented Structural Conductor 75' 16" 250 sx CS II Surface 4136' 9.625" 1000 sx AS III Intermediate & 600 sx Class G Production 9594' 7" 430 sx Class G Liner & 250 sx AS I Measured depth 101' 4162' 9620' True ve~icaldepth 101' 2997' 6222' Perforation depth: measured 9131 '-9252', 9369'-9412', 9436'-9457', 9490'-9496', true vertical 5875'-5953', 6049'~6082', 6099'-6115', 6141'-6145' Tubing (size, grade, and measured depth) 3.5", 9.3#, @ 9311' Packers and SSSV (type and measured depth) Otis 'RRH' @ 8967' MD, Otis 'WD' @ 9284', Camco TRDP-1A SSA @ 1792' ORIGINAL 13. Attachments Description summary of proposal X Contact Mark Chambers at 265-1319 with any questions. Detailed operation program BOP sketch _X 14. Estimated date for commencing operation August 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'~~~ ~'~ ~,~_.,, ~/,Vo~,.~ Title Kuparuk Drilling Team Leader ' II FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_~ Location clearance Mechanical Integrity Test_ Subsequent form require 10- ~ Approved by the order of the Commission Original Signuu .,, David W. Johnston Commissioner Form 10-403 ~R~){~i;/15/88 ~99~o,~e6 ~. IIAppr°valI KRU 2C-09 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH w! wireline. Dummy off all GLM's. 2. RU CTU and cleanout down to PBTD. 3. RIH w/wireline and pull DV from GLM gO @ 8917' and GLM #12 @ 9267' leaving open pockets. 4. RU E-line unit. Chemical cut tubing 2' down into 8' pup joint below bottom GLM @ 9277'. 1' down into 5' pup joint below blast joints @ 9263'. In middle of full joint above blast joints. 5. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.7 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH w! 3-1/2" tubing changing out couplings to modified thread. Stand back tubing and lay down all jewelry. 5. PU DP and RIH with overshot. Latch onto slick stick and pull retrievable packer free. POOH with packer, GLM's and tubing down to cut above blast joints. RIH w/overshot. Wash over tubing stub and fish blast ring joints. POOH and lay down fish. RIH w/overshot and fish bottom GLM. POOH and lay down fish. RIH w/overshot and fish remaining completion equipment down to bottom production packer. POOH and lay down fish. 7. RIH and mill permanent packer. POOH. RIH with spear and fish permanent packer. POOH w/fish. 8. PU bit and scraper. RIH cleaning out well to PBTD. Circulate hole clean. 9. Set storm packer and change out tubing head for ESP completion compatibility. Pull storm packer and verify well is dead. POOH laying down DP. 10. RIH w/Electric Submersible Pump completion on 3-1/2" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 11. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 9.0 days Expected Case: 10.0 days Upper Limit: 12.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or running ESP completion C-09'-Proposed COmpletion L. 3-1/2' 5M FMC Eccentric tubing hanger with 'BIW' penetrators for ESP cable (125 amp) and downhole gauge conductor wire. 3-1/2' L-80 EUE 8rd tubing pup below hanger. Rat #1 power cable with tech wire in double armor wrap K. Rerun 3-1/2" J-55 EUE 8rd Mod tbg to surface. Space-out 3-1/2' x 1" Camco 'KBMM' mandrels (box x box; w/DV's as follows: GLM# MD-RKB 2 TBD 3 TBD 4 TBD 5 100' NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 10' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as per procedure~ Cable splice from motor lead to flat #1 power cable adjacent to 10' pup above pump LaSalle Protectolizers at each flange of ESP assembl' J. 3-1/2' X 1' Camco 'KBMM' mandrel (box x box) with STS-1 dump kill valve (pinned for 3500 psi tubing to casing differential). I. Pup jt, 3-1/2' x 10' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 10' pup and full jt. H. 1 jt Rerun 3-1/2" J-55 EUE 8rd Mod tubing with LaSalle cable protector on cplg below joint. G. 1 jt of Rerun 3-1/2" J-55 EUE 8rd Mod tubing with annulus sensing Baker 'Sentry' gauge clamped to OD of tubing. Conductor Wire for gauge will be run to surface with-in the 2nd Armor wrap of ESP cable. F. 3-1/2' Camco 'D' landing nipple with 2.75' No-Go profile. Standing Valve to be set as nipple is made-up. E. Pup jt, 3-1/2' x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. D..Centrilift '163GC10000' Series 513 Tandem Pump with bolt-on intake and bolt on discharge head. 3-1/2" x 10' L-80 handling pup on top. C. Centrilift 'GRSXBCTH6' Tandem Rotary Gas Separator. B. Centrilift 'GST34B HL PFS' Tandem Seal Section. A. Centrilift '570 HP KMH 3560/98' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6' centralizer threaded into base. Bottom of motor set at +/- 8961' MD RKB. C Sand Perfs 9131' - 9252' A Sand Perfs 9369'-9382' 9382'-9402' 9436'-9457' 9490'-9496' 7" 26# J-55 @ 9619' PBTD @ 9529" MAC 7/21/98 STATE OF ALASKA AI~,~KA OIL AND GAS CONSERVATION COMMIb~,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 115' FNL, 78' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, Sec. 15, T11N, At effective depth 1067' FNL, 1192' FEL, Sec. 15, T11N, 12. R9E, UM R9E, UM 6. Datum elevation (DF or KB) RKB 125 feet 7. Unit or Properly name Kuparuk River Unit 8. Well number 2C-09 9. Permit number/approval number 84-221 10. APl number 50-029-21237-00 11. Field/Pool Kuparuk River Field/Oil Pool At total depth 007' FNL, 1145' FEL, Sec. 15, T11N, R9E, UM Present well condition summary Total Depth: measured 9 6 6 0 feet true vertical 9 2 6 9 feet Plugs (measured) None Effective depth: measured 9 5 2 9 feet true vertical 6168 feet Junk (measured) 1.5" DV in rathole Casing Length Size Structural Conductor 8 0' Surface 4 1 3 6' Intermediate Production 9594' Liner Perforation depth: measured Cemented Measured depth True vertical depth 250 Sx CS II 101' 101' 1000 Sx AS III & 41 62' 2997' 600 Sx Class G 430 Sx Class G & 9620' 6222' 250 Sx AS I 1 6" 9-5/8" 7" 91 31'-9252',9369'-9412',9436'-9457',9490'-9496' true vertical 5875'-5953',6049'-6082',6099'-61 15',6141 '-6145' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 9311' Packers and SSSV (type and measured depth) Pkr: Otis 'WD' @ 9284'; SSSV: Camco TRDP-1A-SSA @ 1792' 13. Stimulation or cement squeeze summary Refracture "A" sands on 8/3/97 and 8/8/97. 0RI6INAL Intervals treated (measured) 9369'-941 2',9436'-9457',9490'-9496' Treatment description including volumes used and final pressure Pumped 142 M lbs 20/40 and 12/18 ceramic proppant into formation, fp was 8000 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 30 5 215 40 1390 130 Subsequent to operation 4 7 5 324 118 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended 17. I hereb/y,~ertify that the foregoing is true and correct to the best of my knowledge. Form ,1~-~6~,e/v/¢0~/1~8;~" 1403 142 Service , . . Date /,~,--/.-- X~ Title Wells Superintendent .-""'~,ii~,,~[,,~![,.,7,1 V~;~T II~1 DUPLICATE ,~Jaska Oil & Gas Cons. Commission ,~chor~e · ~ARCO Alaska, Inc. .... KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~ K1(2C-09(W4-6)) WELL JOB SCOPE JOB NUMBER 2C-09 FRAC, FRAC SUPPORT 0726970824.3 , DATE DAILY WORK UNIT NUMBER 08/03/97 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O No! O Yes (~) No DS-GALLEGOS CHANEY FIELD AFC,# CC# DAILY COST ACCUM COST Sig,ned ESTIMATE KD1412 230 DS28CL' $56,279 $63,607 . , , Initial Tbq Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann.- 1 100 PSI 900 PSI 590 PSI 500 PSII 200 PSII 300 PSI DALLY SUMMARY "A" SAND REFRAC INJECTED 15204 LBS OF PROP IN THE FORMATION W/2# PPA OF #12/18 @ THE PERF'S, PRESSURED OUT AND HAD TO SHUT DOWN W/SAND BACK TO SURFACE. MAXIMUM PRESSURE 7600 PSI W/F.G. @ (1.02) TIME ILOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, AND APC VAC TRUCK. HELD SAFETY MEETING (15 ON LO,CATION). PT D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D H!GH PRESSURE LINES TO 7900 PSI. 07:00 09:15 10:00 10:55 12:10 #20/40 PROP. MAXIMUM PRESSURE 7200 PSI AND ENDING PRESSURE 5000 PSI. S/D. AND OBTAINED ISIP OF 3529 PSI W/F.G. @ (1.02). STOOD-BY AND MONITORED WHTP. PULSED FOR CLOSURE. (+/- 18 MIN CLOSURE TIME) PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 176 BBLS. MAXIMUM PRESSURE 7200 PSI AND ENDING PRESSURE 4500 PSI. S/D AND OBTAINED ISIP OF 3502 PSI W/F.G. (1.02). STOOD-BY AND MONITORED WHTP TO DETERMINE CLOSURE. (+/- 19 MIN CLOSURE TIME). PUMP FRAC W/20# GSW@ 25 BPM, 50#DELAYED XL GW @ 10 BPM. PRESSURED OUT AND HAD TO SHUT DOWN W/SAND TO SURFACE. VOLUME PUMPED 700 BBLS. PUMPED 22875 LBS OF PROP (14560 LBS OF #20/40 & 8315 LBS OF #12/18). INJECTED 15204 LBS OF PROP IN THE FORMATION W/2 # PPA OF #12/18 @ THE PERF'S. LEFT 7671 LBS OF PROP IN THE WELLBORE. MAXIMUM PRESSURE 7600 PSI. 13:15 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL UNIT. 14:15 15:15 REMOVED TREESAVER (LOST 50% OF THE CUPS). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND DSO NOTIFIED OF STATUS. Gas Cons, Anchorage SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $820.00 APC $5,600.00 $5,900.00 DIESEL $125.00 $125.00 DOWELL - $48,574.00 $48,574.00 HALLIBURTON $0.00 $6,208.00 LITFLE RED $1,980.00 $1,980.00 TOTAL FIELD ESTIMATE $56,279.00 $63,607.00 --ARCO Alaska, Inc. KUPARUK RIVER UNIT '~, WELL SERVICE REPORT '~' K1(2C-09(W4-6)) WELL JOB SCOPE JOB NUMBER 2C-09 FRAC, FRAC SUPPORT 0726970824.3 DATE DAILY WORK UNIT NUMBER 08/08/97 REFRAC A SAND DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes, O NoI (~) Yes O No DS-YOKUM KRALICK ESTIMATE KD1412 23ODS28CL $1 1 3,513 $191,218 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Ou.ter Ann \, Final Outer Ann 892 PSI 2225 PSI 850 PSI 500 PSII ~.0_.PSJ~J' 400 PSI DALLY SUMMARY REFRAC COMPLETE W/TIP SCREENOUT - 8 PPA 142,000# IN FORMATION - 21,900# IN PIPE TO SURFACE TIME LOG ENTRY 07:00 MIRU DS AND LITFLE RED 08:15 SAFETY MEETING AND FLUID REOLOGY TESTS 08:40 P/T TO 10,000 PSIG - TREE SAVER SET 09:00 START PUMPING 50# DELAY XL GW 25 BPM 115 BBL - BREAKDOWN STAGE FOLLOWED PER SCHEDULE 09:15 S/D ISIP - 3340 PSi -2796 PSI CLOSURE -9.5 MIN. ~. 09:45 PUMP 5 BPM INITIAL DATA FRAC - 75 BBLS - DATA FRAC FOLLOWED PER PROCEDURE 10:15 S/D ISIP - 3400 PSI - 2888 PSI CLOSURE - 16 MIN - ADDED 50 BBLS TO PAD 11:10 PUMP FRAC BREAKDOWN AND RAMP PER PROCEDURE W/GW/50 # DELAYED XL GW AND 40~ DELAYED XL GW - START BREAKDOWN @ 25 BPM AND 15 BPM DROP DOWN AFTER XL ADDED 12:00 ADJUST ACTIVATOR UP AND DOWN WITH PRESSURE / 8 PPA 12:45 TIP SCREENOUT WITH 8 PPA IN PERFS AND TO SURFACE 13:00 142,000# 12/18 IN FORMATION (204,000# PLANNED)- 21,900# 8PPA IN PIPE TO SURFACE - 8000 PSIG MAX SURFACE PRESSURE SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $883.00 APC $5,250.00 $17,150.00 ARCO $0.00 $600.00 DIESEL $0.00 $125.00 DOWELL $103,763.00 $158,537.00 HALLIBURTON $0.00 $6,843.00 LI'I-FLE RED $4,500.00 $7,080.00 TOTAL FIELD ESTIMATE $113,513.00 $191,218.00 ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 May 28, 1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commissioon 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate is a Report of Sundry Well Operations (Form. 10-404) on the following well: 2C-09 Stimulate W ellsJeffery-" ;K:p~ir?ntendent Kuparuk Production Engineering Attachments File: FTR052898 (w/o attach), ATO 370 CWG files (w/o attach) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ 2. Name of OperatorPull tubingAlter casi'i~5."-- Type of Well: ' I Development ARCO Alaska, Inc. I Exploratory _ 3. Address I Stratigraphic ~ P. O. BOX 100360, Anchorage, AK 99510 I Service 4. Location of well at surface 115' FNL, 78' FEL, SEC.21, T11N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, SEC.15, T11N, R9E, UM At effective depth 1067' FNL, 1192' FEL, SEC.15, T11N, R9E, UM At total depth 1007' FNL, 1145' FEL, SEC.15, T11N, R9E, UM Stimulate X Plugging Repair well ~ 12. Present well condition summary Total Depth: measured 9660' feet true vertical 6269' feet Plugs (measured) Perforate Other 6. Datum elevation (DF or KB) RKB 125 feet - 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-09 9. Permit number/approval number 84-221 10. APl number 50-029-21 237 11. Field/Pool Kuparuk River Oil Field/Pool Effective depth: measured 9529' feet Junk (measured) true vertical 6168' feet Casing Le n gt h Size Cemented Structural Conductor 7 5" 1 6" 250 SX COLD SET II Surface 41 36' 9 5/8" 1000 SX AS III & Intermediate 600 SX CKASS G Production 9 5 9 4' 7" 430 SX CLASS G Liner 250 SX AS I Perforation depth: measured 91 31 -9252', 9369' - 9412', 9436' - 9457', true vertical 5875' -5953', 6049'-6082', 6099'-6115', Tubing (size, grade, and measured depth) 3 1/2" J-55 SET AT 9311' Packers and SSSV (type and measured depth) OTIS 'WD' @ 9284', CAMCO TRDP-1A-SSA @ 1792' ~ 13. Stimulation or cement squeeze summary A Sand Refracture Stimulation 5 / 2 6 / 9 7 Intervals treated (measured) 9369-9412', 9436-9457', 9490-9496' MD-RKB Treatment description including volumes used and final pressure Refraced "A' sands, flushed early due to pressure. Pumped 82746 lbs of prop in Perfs w/6 PPA of 12/18 @ perfs. Freeze )rotectd w/66 bbls diesel Measured depth True vertical depth 101' 101' 41621 2997' 9620 -.- 61 1 - 145 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2581 2099 1271 820 151 Subsequent to operation 3336 3246 1570 1297 151 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas ~ Suspended Service 17. I hereby.,~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~ //~,{ ~,~J...,,~.~' Title Wells Superintendent Form f-4(~40 R~,/ ~)~'~5~§ - Date ~.-'~.,z./?-' /' SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT .J' WELL 'SERVICE REPORT ~ K1(2C-09(W4-6)) WELL JOB SCOPE JOB NUMBER 2C-09 FRAC, FRAC SUPPORT 0517971802.1 DATE DAILY WORK UNIT NUMBER 05/26/97 RE FRAC "A" SANDS UNIT #1 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes ~ NoI (~) Yes O No DS-YOKUM BLACK ESTIMATE KD1796 23ODS28CL $87,290 $87,290 , Initial Tbq Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 901 PSI 901 PSI 21 9 PSI 220 PSII 300 PSII 500 PSI DAILY SUMMARY I RE FRACED "A" SANDS. FLUSHED EARLY DUE TO PRESSURE. PUMPED 82746 LBS OF PROP IN PERFS W/6 PPA OF 12/18 @ PERFS. FREEZE PROTECTED W/66 BBLS DIESEL. TIME LOG ENTRY 06:00 07:00 07:30 08:30 10:00 11:45 MIRU DS FRAC EQUIPMENT, APC VAC TRUCK & LRS HOT OIL. TGSM-JOB OVERVIEW & MAINLY SLIPS & FALLS W/ ICE ON LOCATION (15 ON LOCATION). SET TREESAVER. PT BACKSIDE LINES TO 3200 PSI & HIGH PRESSURE LINES TO 8900 PSI. ALL OK. PUMP BREAKDOWN 50# DELAYED XL GW F/10 TO 25 BPM. VOLUME PUMPED 505 BBLS. MAX PRESSURE 7465 PSI. ENDING PRESSURE 3945 PSI. ISIP 2716 (FG - .89). STANDBY & MONITOR WHTP F/CLOSURE. PULSED 3 TIMES. PUMP DATAFRAC W/50# DELAYED XL GW F/10 TO 25 BPM. VOLUME PUMPED 170 BBLS. MAXIMUM PRESSURE 5822 PSI. ISIP 3226 PSI (FG-.98). STANDBY & MONITOR WHTP SO TO ADJUST PAD. ADJUST PAD TO 250 BBLS F/ DESIGN OF 150 BBLS (CLOSURE TIME ESTIMATED TO BE +/- 13 MINUTES). PUMP FRAC W/CORRECTED PAD. WORKING CLOSE TO MAX WHTP. AT 430 BBLS IN RAMP @ 15 BPM BEGAN TO SEE MAX WHTP (6000 PSI). WORKED WITH RATE & REDUCED GEL F/50# TO 40#. PRESSURE KEPT CLIMBING. CALLED FLUSH @ 1143 BBLS & 6123 PSI IN FRAC (280 BBLS BREAKDOWN / 250 BBLS PAD / 613 BBLS SLURRY) DURING RAMP @ 6 PPA (1822 BBLS TOTAL SLURRY). FLUSHED 14 BBLS XL GW & 66 BBLS DIESEL. LEFT 600 LBS SAND IN WELL BORE. PUMPED 82746 LBS SAND IN FORMATION (54,000 LBS 20/40 & 29,346 LBS 12/18). BEGIN RD. LRS DEPRESSURE INNER CSG TO 500 PSI & RD LRS. PULL TREESAVER (ALL CUPS RETURNED). CON'PD RD. 13:15 DS OFF LOCATION. TURN OVER TO PRODUCTION FOR 5/27/97 CTU CLEANOUT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $5,500.00 $5,500.00 DOWELL $79,260.00 $79,260.00 LI'I-i'LE RED $2,530.00 $2,530.00 TOTAL FIELD ESTIMATE $87,299.00 $87,290.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Repair well . Perforate Other ,2. Name of Operator ARCO .Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 115' FNL, 78' FEL, SEC.21, T11N, R9E, UM At top of productive interval . 1285' FNL, 1368' FEL, SEC.15, T11N, R9E, UM At effective depth 6. Datum elevation (DF or KB) RKB 125 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-09 9. Permit number/approval number 84-221 10. APl number feet 1067' FNL, 1192' FEL, SEC.15, Tll At total depth 1007' FNL, 1145' FEL, SEC.15, Tll N, R9E, UM N, R9E, UM 12. Present well condition summary Total Depth: measured 9660' true vertical 6269' Effective depth: measured 9529' true vertical 6168' feet Plugs (measured) feet feet Junk (measured) feet 50-029-21237 11. Field/Pool Kuparuk River Oil Field/Pool ORIGINAL Casing Length Size Structural Conductor 7 5" 1 6" Surface 4136' 9 ~5/8" Intermediate Production 9594' 7" Liner Perforation depth: measured 9131 -9252', true vertical 5875' -5953', Tubing (size, grade, and measured depth) 3 1/2" J-55 SET AT 9311' Packers and SSSV (type and measured depth) Cemented 250 SX COLD SET II 1000 SX AS III & 600 SX CKASS G 430 SX CLASS G 250 SX AS I Measured depth True vertical depth 101' 101' 4162' 2997' 9620' 6222' 9369'- 9412', 9436'- 9457', 9490'- 9496' 6049'-6082', 6099'-6115', 6141'-6145' OTIS 'WD' @ 9284', CAMCO TRDP-1A-SSA @ 1792' 13. Stimulation or cement squeeze summary A Sand Refracture Stimulation Intervals treated (measured) 9369-9412', 9436-9457', 9490-9496' MD-RKB Treatment description including volumes used and final pressure SEE A'FI'ACHED WELL SERVICE REPORT SUMMARY 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf ' Water-Bbl Casing Pressure 2581 2099 1271 820 3336//3246 1570 1297 Tubing Pressure 151 151 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. A - Subsidiary. of Atlantic Richfield Company WELL DESCRIPTION OF WORK 2C-09 RE-FRAC. "A" SANDS DATE 10/21/94 DAY 1 TIME 0630 09OO 0930 0935 1109 1250 1319 1326 1347 CONTRACTOR / KEY PERSON DOWELL-RICK G. PBTD (RKB) [LAST TAG (RKB) . DATE I KUPARUK RIVER UNIT WELL SERVICE REPORT FIELD COST EST. · $119,100 SSSV TYPE ! STATUS FRAC. SLEEVE IAFC/CC# - SCA# 998325-80-5-29 ACCUMULATED COST $237,100 ! milesI mpht l Xl COMV T . t.1 INCOMPLETE i'CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather :.~.[Temp. Chill Factor Re,port LOG ENTRY MIRU FRAC EQUIPMENT HELD JOB SAFETY MEETING Q.C. GEL AND PROPPANT SET TREE SAVER , PRESSURE TEST SURFACE LINES TO 7200 PSI- OK START PUMPING BREAKDOWN STAGE W/1015 PSI WHP. PUMPED 215 BBLS 40~ LINER GEL AT 22 TO 15 BPM. SHUT DOWN 2898 ISIP .93 F.G. PUMPED DATA FRAC. AT 15 BPM, SHUT DOWN W/2925 ISIP INCREASED PAD SIZE TO 350 BBLS. PUMP 350 BBL. PAD W/40g DELAY XL GW.TREAT PRESS. 4092 PSI, 15 BPM START PUMPING 2# PPA 20/40 AT 4000 PSI 15 BPM START RAMP UP TO 6g PPA 12/18 AT 3896 PSI 15 BPM START RAMP TO 10 PPA 15 BPM GEL SAMPLES LOOKS LIKE GEL IS NOT X-LINKING, CHANGED ACTIVATOR WELL PRESSURED OUT W/MAX. PRESS. OF 6100 PSI SUMMARY: .~ FRAC'ED "A" SANDS WITH 63,289# IN PERFS. 6.9# PPA 12/18 AT PERFS. ~20,595 # IN PIPE. JOB DESIGN WAS 166,000 # MAINTAIN 3000 PSI ON 7" ANNU. DURING FRAC., BLED TO 1500 PSI AFI'ER FRAC. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 115' FNL, 78' FEL, SEC.21, T11N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, SEC.15, T11N, R9E, UM At effective depth 1067' FNL, 1192' FEL, SEC.15, T11N, R9E, UM At total depth 1007' FNL, 1145' FEL, SEC.15, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 9660' feet true vertical 6269' feet Effective depth: measured 9529' feet true vertical 6168' feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 125 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-09 9. Permit number/approval number 84-221 10. APl number 50-029-21237 11. Field/Pool Kuparuk River Oil Field/Pool ORIGINAL Casing Length Size Structural Conductor 7 5" 1 6" Surface 4136' 9 5/8" Intermediate Production 9 5 9 4' 7" Liner Perforation depth: measured 9131 -9252', true vertical 5875' -5953', Cemented 250 SX COLD SET II 1000 SX AS III & 6OO SX CKASS G 430 SX CLASS G 250 SX AS I Measured depth 101' 4162' 9620' 9369' - 9412', 9436' - 9457', 6049'-6082', 6099'-6115', Tubing (size, gr'ade, and measured depth) 3 1/2" J-55 SET AT 9311' Packers and SSSV (type and measured depth) OTIS 'SBR' @ 8956', CAMCO TRDP-1A-SSA @ 1792' Trueverticaldepth 101' 2997' 6222' 9490' - 9496' 6141'-6145' RECEIVED 13. Stimulation or cement squeeze summary Perforated A sands Intervals treated (measured) 9382-9402' w/6 SPF and oriedted +/-90 degrees Treatment description including volumes used and final pressure SEE A'I-I'ACHED WELL SERVICE REPORT 0ii & Gas Cons. Commission 14. Prior to well operation Subsequent to operation Re0resentative Daily Average Production or Injection Date OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2581 ~ 2099 1 2 71 3336/ 3246 1570 Tubing Pressure 820 151 1297 151 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent Date //r,/~~' ~' SUBMIT IN DUPLICATE ARCO Alaska, Inc. A Subsidiary of Atlantic Richfield Company WELL DESCRIPTION OF WORK 2C-09 SHOOT RE-PERFS., TO PREP. FOR REFRAC. DATE CONTRACTOR / KEY PERSON 10/10/94 SCHL~ERGER - RATHERT I LAST TAG (RKB) - DATE DAY1 PBTD (RKB).i 9466'-10-09-94 TIME LOG ENTRY HELD SAFETY TALK ON JOB RIG UP 0800 MIRU E-LINE; PRESSURE TESTED TO 3000 PSI W/VECO PUMP. 0900 RIH W/20', 2-1/8" PERF GUN, ORJE~D RIGHT SIDE 0930 TIE-IN WITH CCL 5-26-85 0950 SHOOT PERFS W/TOP SHOT AT 9382', POH W/ALL SHOTS FIRED 1040 RIH W/20' , 2-1/8" PERF. GUN , ORIENTED TO LEFT SIDE 1220 CHECK TIE -IN, 1231 SHOOT PERFS W/TOP SHOT AT 9382' POH W/ALL SHOTS FIRED. 1340 RDMO SUMMARY: :REPERFORATED A-4 SANDS W/2-1/8" ENER. JET GUNS , NEW PERFS 9382' TO 9402' W/6 SPF AND ORIENTED +/- 90 DEGREES KUPARUK RIVER UNIT WELL SERVICE REPORT [AFC/CC# - SCA# [ 998325 - 80-2-23 . IFIELD COST EST. IACCUMULATED COST [ $19,172 ] $20,909 .~. [SSSV TYPE / STATUS !REMovED , _ I CHECK TtHS BLOCK IF SUMMARY IS CONTINUED ON BACK [ X INCOMPLETE Report I I milesI mph] THOMAS JOHNS ARCO Alaska, Inc. Post Offi~'--'"~x 100360 Anchorag~ .faska 99510-0360 Telephone 907 276 1215 October 7, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~"~ --1A-03 Stimulate $'5-Iaz. -1G-12 Stimulate c/~-oa fl H-01 Perforate -- 2C-09 Stimulate ~q-~'?'~ 3H-14 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED OCT 1 1 1993 Alaska 0il & Gas Cons. uuminisstu' Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ~ ~ OIL AND GAS ~SERVATION COMMISoiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging_ __ Perforate ' j//~ Pull tubing Alter casing Repair well Other 5. Type of Well: 6. Datum elevation (DF or KB) Development _.X_ Exploratory _ RKB 125 feet 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service 4. Location of well at surface 115' FNL, 78' FEL, SEC.21, T11N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, SEC.15, T11N, R9E, UM At effective depth 1067' FNL, 1192' FEL, SEC.15, T11N, R9E, UM At total depth 1007' FNL, 1145' FEL, SEC.15, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 9660' feet true vertical 6269' feet Plugs (measured) 7. Unit or Property name Kuparuk River Unit 8. Well number 2C-09 9. Permit number/approval number 10. APl numbe~'~' ' 50-029-21237 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9529' feet true vertical 6168' feet Junk (measured) Casing Length Size Structural Conductor 7 5" I 6" Surface 4136' 9 5/8" Intermediate Production 9594' 7" Liner Perforation depth: measured 9131 -9252', true vertical 5875' -5953', Tubing (size, grade, and measured depth) Cemented 250 SX COLD SET II 1000 SX AS III & 600 SX CKASS G 430 SX CLASS G 250 SX AS I Measured depth True vertical depth 101' 101' 4162' 2997' 9620' 6222' 9369' - 9412', 9436' - 9457', 9490' - 9496' 6049'-6082', 6099'-6115', 6141'-6145' R CEIVED 3 1/2" J-55 SET AT 9311' Packers and SSSV (type and measured depth) OTIS 'SBR' @ 8956', CAMCO TRDP-1A-SSA @ 1792' 13. Stimulation or cement squeeze summary A Sand Refracture Stimulation Intervals treated (measured) 9369-9412', 9436-9457', 9490-9496' MD-RKB Treatment description including volumes used and final pressure A Sand refrac, stim. w/ 51,262# 16/20 & 12/18 Carbolite proppant in formation (752 bbls slurry total). )ressure 4800 psi. r)CT 1 1 1.qg ~aS G0rls. C0m~ Anchorage Final treating 14. Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf 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 54O 257 6O 55O 646 j 383 34 600 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 116 150 17. I he~rtify that the foregoing is true and correct to the best of my knowledge. Sic, lned ~r ~~, ~ Title Senior Engineer ssion ARCO Alaska, Inc. WELL SERVICE REPORT SubeldiIry of AtlIntlc Richfield CompIny ....... · ' ' ' .... WELL/~ '. :.~l&' I~ :1 ,~ '-'"~ =l~I -' - ' C I FIELD . DISTRICT. STATE IDAYS DAT~(,,, ,NTRACTO~ . /1 REMARKS ,,, & ·_. ~' . -'. OCT 11 199;~ J--J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITImp' IChillFlct°r JVlIlblllty }WlndRel:X)lt 'F 'F ' ' mileI Vel. Anchorage REMARKS CONTINUED: DESCRIPTION DALLY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS ~owE,, _.~/~,~/~'.-" HALLIBURTON ARCTIC COIL TUBING . FRACMASTER B. J. HUGHES Roustabouts ,~ Diesel ,~' .~,.~"O- Methanol Sup~. rvision _ Pre-Job Safety Meeting AFE .~ ~,~ ? ~,o~,- TOTAL FIELD ESTIMATE . ~'/~'/~," .,~/~'~3 ~"7_...~ i s,~.,~) ~, ~..~ ~ · · STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~i,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1115' FNL, 78' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, Sec. 15, T11N, R9E, UM At effective depth 1067' FNL, 1192' FEL, Sec. 15, T11N, R9E, UM At total depth 1007' FNL, 1145' FEL, Sec. 15, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9660' feet 6269' feet 6. Datum elevation (DF or KB) RKB 125 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2C-09 Producer 9. Permit number/approval number 84-221/90-333 10, APl number $o-0;g9-21237 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 9529' true vertical 6168' feet Junk (measured) feet None Casing Length Structural Conductor 7 5" Surface 41 3 6' Intermediate Production 9 5 9 4' Liner Perforation depth: measured 9131'-9252', true vertical 5875'-5963', Size Cemented Measured depth True vertical depth 1 6" 250 Sx Cold Set II 1 01' 1 01 ' 9 5/8" 1000 Sx AS III & 41 62' 2997' 600 Sx Class G 7" 430 Sx Class G 9 6 2 0' 6 2 2 2' 250 Sx AS I 9369'-9412', 9436'-9457', 6049'-6082', 6099'-6115', Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 6900" Packers and SSSV (type and measured depth) Baker 'FH' @ 6881', Camco TRDP-1A-SSA @ 1840' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 9490'-9496' 6141'-6145' Treatment description including volumes used and final pressure ~'~'~/~&'~'~//7 Refractured the A Sand with 59,000 lb. 16/20 Carbo-Lite. Final treatincj pressure 4625 psi Reoresentative Daily Averaoe Production or Iniection Data - OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1730 1850 1540 1050 160 2025 1690 1200 1550 185 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector. Oil X Gas Suspended Service !17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Form 10-404 Rev 09/12/90 Date SUBMIT IN DUPLICATE _ ARCO Alaska, Inc. ~ WELL SERVICE REPORT Subsidiary of Atlantic Richfield Company WELL ._~. CONTRACTOR Do ~,~II · ._MARKS .~OT FIELD- DISTRICT. STATE OPERATION AT REPORT TIME ,S,, // u / DAYS ] DATE ..L 6 -/e-?o V/all S/T~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ]Temp. *F Chill Factor0FI Visibility miles Wind Vel. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 2C-09 Stimulate May, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 Ar~chora~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompa~W .... -" STATE OF ALASKA ~'-'--" 0 AL/-~-- ~, OIL AND GAS CONSERVATION COMMI~;,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1115' FNL, 78' FEL, Sec. 21, T11N, R9E, UM At top of productive interval 1285' FNL, 1368' FEL, Sec. 15, T11N, R9E, UM At effective depth 1067' FNL, 1192' FEL, Sec. 15, T11N, R9E, UM At total depth 1007' FNL, 1145' FEL, Sec. 15, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 9660' feet Plugs (measured) 6 2 6 9' feet None 9529' feet Junk (measured) 61 6 8' feet None 6. Datum elevation (DF or KB) RKB 125 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2C-09 9. Permit number ~4-221 10. APl number 50-029-21 237 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Structural Conductor 75' Surface 41 3 6' Intermediate Production 9594' Liner Perforation depth: measured 9131 '-9252', Size Cemented 1 6" 250 Sx Cold Set II 9 5/8" 1000 Sx AS III & 600 Sx Class G 7" 430 Sx Class G 250 Sx AS I 9369'-9412', 9436'-9457', true vertical 5875'-5963', 6049'-6082', Tubing (size, grade, and measured depth 2 7/8" J-55 set at 6900' Packers and SSSV (type and measured depth) Baker 'FH'@ 6881', Camco TRDP-1A-SSA @ 1840' 6099'-6115', Measured depth True vertical depth 101' 101' 4162' 2997 9620' 6222' 9490'-9496' 6141'-6145' R E C E IV i? i iA¥ o 9 0il & ~as Cons. C0mmi 13. Attachments Description summary of proposal _ Fracture Stimulate A Sand w/56~000 lbs. of ceramic 14. Estimated date for commencing operation May. 19~)0 16. If proposal was verbally approved Name of approver Date approved Detailed operation program X.~ BOP sk~{~'"~-~' proppant in gelled water (Well schematic attached). 15. Status of well classification as: Oil X Gas __ Suspended _ Service Oil Producer Signed17' I he,~~if,~a~ the~,~~foregoing is true and correctTitle to~4,t~the best of myo~¢'~l''t 5kn°wledge' FOR COMMISSION USEtONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- ~ Date JApprov_~l No. ~...-, .-~ Approved by the order Commission Form 10-403 Rev 5/03/89 ORIGINAL S1GNF0 BY LONNIE C. SMITH Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE J0n APPLICATION FOR SUNDRY APPROVALS - Addendum I . . , No workover fluid is required for this operation. No BOP's are required for this operation. The estimated A Sand BHP at 6200'ss is 2400 psi. M: Lyden/L. Wade May 4, 1990 Page. 3 Kuparuk Well 2C-09 Refracture Procedure Including Pre and Post Frac Wireline Cost Tracking AFE #K80992 , . , . . . , MIRU slickline unit. Tag fill. NOTE: If the fill level is above the bottom A3 Sand perforation at 9457', a CTU cleanout is recommended before fracturing. The last tag was at 9447' on 7/1 4/87. Pull 1.5" HFCV's from mandrels at 9003', 9070' and 9267'. Set DV's in mandrels at 9070' and 9267'. Set 5000 psi Petredat gauge in mandrel at 9003'. The gauge should be programmed for the following data gathering frequency: Time Interval Pressure Data Frequency Temperature Data Frequency All 15 minutes 1 hour Pull 1" OV's from mandrels at 6016' and 8476' and replace with DV's. Pull 1.5" X 5/16" OV from mandrel at 8917' and replace with a 1.5" X 3/16" OV. RDMO slickline. Obtain a minimum of two 24 hour A Sand only well tests. Adjust lift gas rate as necessary to maintain stabilized flow. MIRU slickline unit. Pull Petredat gauge from mandrel at 9003' and replace with a DV. Pull GLV's from mandrels at 2114', 4118' and 7295' and replace with DV's. Pull OV from mandrel at 8917' and replace with 8000 psi Petredat gauge. Set SV in 'D' nipple at 9300'. Fill annulus with diesel. Pressure test tubing and annulus. Pull SV. RDMO slickline. The Petredat gauge should be programmed as follows (assuming gauge is run 48 hours prior to frac): Time Interval Pressure Data Frequency Temperature Data Frequency 0-48 hours 1 hour I hour 48-68 hours 30 seconds 5 minutes 68- I hour 1 hour MIRU fracturing equipment. Carry out all fluid quality control procedures (will be done by onsite Operations Engineer). Conduct a sieve analysis on several proppant samples. Obtain samples of proppant and gelled water with breaker prior to pumping, and from the pad and slurry stages while pumping. Verify and record proppant weight before and after job execution. M Lyden/L. Wade May 4, 1990 Page.4 , . 10. NOTE: 11. 12. 13. Install wellhead isolation tool. Pressure test lines. Pressure up 7" x 3 1/2" annulus to 3500 psi and maintain throughout job. Pump the 200 barrel pre-pad at 25 BPM. Shut down and determine the ISIP. Stop adding crosslinker after 120 barrels to avoid leaving crosslinked gel in the tubing. Pump the fracture treatment at 25 BPM as detailed in the attached pumping schedule. Expected treating pressures are: WHTPE (calculated) -- 4100 psi Frac gradient - 0.70 psi/ft Tubing Friction = 210 psi/1000 ft (6070' TVD) (9311' MD, 25 BPM) If treating pressure exceeds 5000 psi during the pad, shut down and confer with Operations Engineering. The maximum wellhead treating pressure based on tubing strength analysis is 5500 psi. If the treating pressure exceeds 5000 psi in the proppant laden stages, reduce the pump rate in 2 BPM increments and allow for stabilization to determine if pressure increase is due to friction or reservoir conditions. Go to flush if the rate of treating pressure increase is excessive or if the treating pressure exceeds 5200 psi. Rig down frac equipment. Leave well shut in overnight. MIRU slickline unit. Tag fill. Pull Petredat gauge from GLM at 8917' and replace with a DV. Pull DV from GLM at 5328' and replace with a 3/16" OV. RDMO slickline. Proceed with the attached flowback schedule. Use lift gas if necessary to unload the well. 1 4. After flowback, obtain a 24 hour well test. KUPARUK WELL 2C-09 APl #: 500292123700 SPUD DATE: 03/04/85 ADL LEASE: 25654 COMPLETION DATE: 04/03/85 PERMIT #: WORKOVER DATE: 84-221 SURFACE LOCATION: 1115'FNL,78'FEL,SEC21,T11 N,RgE TOP OF KUPARUK: 1285'FNL,1368'FEL, SEC15,T11N,R9E TD LOCATION: 1007'FNL,1145'FEL, SEC15,T11N,R9E All deplhs am MD-FIKB to t~p of equipment unless otherwise noted ORIGINAL RKB: 125 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.54t H-40 101 9.625" 36# J-55 4162 7' 26# J-55 9619 3.5' 9.2# J-55 EUE 9311 TUBING SPOOL: 26 WELLTYPE: PRODUCER LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ri'EM TYPE ID DEPTH SSSV CAMCO TRDP-1A 2.813' 1792 SBR OTIS 2.813' 8956 PKR OTIS RRH 8967 PKR OTIS WD 9284 N~ CAMCO 'D 2.75' 9300 SHROUT OTIS 9310 L PAD ELEVATION: 89 STN 1 2 3 4 5 6 7 8 9 10 11 12 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2114 CAMCO KBUG 1' 4118 CAMCO KBUG 1' 5328 CAMCO KBUG 1' 6016 CAMCO KBUG 1' 6610 CAMCO KBUG 1' 7295 CAMCO KBUG 1' 7943 CAMCO KBUG 1' 8476 CAMCO KBUG 1' 8917 CAMCO MMGII 1.5' 9003 CAMCO MMGII 1.5' 9070 CAMCO MMGII 1.5' 9267 CAMCO MMGII 1.5' PERFORATION DATA INTERVAL ZONE FT SPF PHASE 9131-9252 C234 121 12 120 9369-9412 A4,5 43 4 90 9436-9457 A3 21 4 90 -949-t-94~ A3 6 ~ 120 PORT SIZE o. 1875 o. 1875 .DY 0.3125 .DY 0.25 .DV 0.3125 .or .or .OV COMMENTS DA 5' GUN ~'~,l, ~1 II IIII~'N Iff ~iIi i Z'/~" DA 4" JUM~ J~ MISC. DATA DESCRIPTION DEFTH KICK OFF POINT: 600 MAX HOLE ANGLE: 58 deg HOLE ANGLETHRU KUP~ deg ~IH~7 LAST TAG DATE: FISH/OBSTRUCTION: PBTD: 9529 PBTDSS: 6043 RECEIVE ? v!AY 0 (9 Oil & Gas gons, Comrni8~ion An~horaga REVISION DATE: 01/20/89 REASON: ARCO Alaska, Inc. Date: December 30, 1988 Transmittal Ct: 7392 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 Z- 1 4 Kuparuk Fluid Level Report 1 2- 2 7- 8 8 Tubing 1 Y- 0 6 Kuparuk Fluid Level Report 1 2 - 2 6 - 8 8 Casing 2A-05 Kuparuk Fluid Level Report 1 2-26-88 Tubing 2 X- 1 4 Kuparuk Fluid Level Report 1 2- 2 5 - 8 8 Tubing 2 Z- 1 3 Kupaurk Fluid Level Report 1 2- 2 6 - 8 8 Tubing 2C-09 Kuparuk Fluid Level Report 1 2-22-88 Casing 2 W - 0 1 Kuparuk Fluid Level Report 1 2 - 2 2 - 8 8 Casing 3 K - 0 6 Kuparuk Fluid Level Report 1 2 - 2 1 - 8 8 Casing 3 B - 1 3 Kuparuk Fluid Level Report 1 2 - 2 1 - 8 8 Casing · Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska , Unocal Chevron Mobil SAPC STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION uuMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-221 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21237 4. Location of well at surface 9. Unit or Lease Name 1115' FNL, 78' FEL, Sec.21, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1285' FNL, 1368' FEL, Sec.15, TllN, RgE, UM 2C-9 At Total Depth 11. Field and Pool 1007' FNL, 1145' FEL, Sec.15, TllN, R9E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 125' ADL 25654 ALK 2580 12. Date Spudded 13, Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 03/04/85 03/13/85 03/14/85'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. D, iSectional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9660'MD, 6268'TVD 9529'MD, 6168'TVD YES~J~ NO [] 1792' feet MDI 1500' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 101" 24" 250 sx Cold Set II 9-5/8" 36.0# J-55 Surf 4162' 12-1/4" 1000 sx AS Ill & 600 s~ Class G 7" 26.0# J-55 Surf 9620' 8-1/2" 430 sx Class G & 250 s,~ AS I "~4. 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) Perforated w/12 spf, 120° phasing 3-1/2" 9311' 8967' & 9284' 9375' 9377' 9387' 9389' 9393' 9395' 9397' 9399', 9401', 9403', 9441', 9443', 9447', 9449', 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 9452' 9454' 9491' 9493' 9495' 9497' ~ ~ ~ ~ ~ DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9131'-9252' See attached Adder~lurn, for fracture data. Re-perforated w/4 spf 9369 ' -941 2 ' 9436 ' -9457 ' -. 27. N/A PRODUCTION TEST . Date First Production I Method of Operation (Flowing, gas lift, etc.) I . Date of Test Hours Tested PRODUCTION FOR OiL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO · .. TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.1~ OIL-BB'E ' ' GAS-MC~ WATER-BBL OIL GRAVITY-APl icorr) Press. 24-HOUR RATE 28.. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of None °il' gas °r water' Submit c°re chips' ~, t~i,~1~ ¥"~) *Note: Tubing was run and the well perforated 4/3/85. Form 10-407 Rev. 7-1-80 WC,~/66 :DAN I ~ Submit in duplicate/x-,~/~ CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS: ' ' ' '-' ' ' """;"~)~-I~'MATIONTESTS .. .: . . . : · ; - : .; . ,.. .~ · :. - · .-. - . . . '~: NAME " Include interval tested, pressure data, all fluids recovered and ~rav'itY, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · _ _ . Top Upper 5and : '" 91.27' 5871 ' N/A Base Upper Sand 9212' 5933' Top Lower Sand ' -'- 9357' 6039' '- · Base Lower Sand 9524' 6165' · . , . · . · .. 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of mY knowledge . · Signed ~-~~~' ~Lff.L~s{''~' Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct Well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tOol. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 4~08~85 4/11/85 4/13/85 9/24/85 2C-9 RIH w/impression block. RIH & latch onto blanking plug, POH. Frac well in 8 stages w/356 bbls gelled diesel, 750# 100 mesh & 7900# 20/40 mesh. RIH w/CTU. Circ cln w/gelled diesel to TD @ 9509'. Arctic Pak w/250 sx AS I, followed by 59 bbls Arctic Pak. Drilling guperintendent Date ARCO Alaska, In,~~' Post Offic~ .... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 27, 1987 Transmittal #6047 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2C-9 Static Kuparuk Well Pressure Report 7-17-87 Receipt Acknowledged: DISTRIBUTION: BPAE Chevron N~s~ Oit & Gas Cons commiss~o~ ~il S~C Unocal D&M :~,,S,ta,teof,,,Alaska , ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL I)(1 OTHER [] 2' NaA~ ~foOP~ S KA, INC. 3' A~:)dr. ess 0, BOX 100360, 4. Lo~Ji~nFo~ ~/~' L 0 C AT ! 0 N' T11N, R9E, UN feet (indicate KB, ~F, etc.) 5'Elevati°~.~5. 7' (RKB ANCHORAGE, ALASKA 99510 1115' FNL, 78' FEL, SEC. 21, 6. Lease Designation and Serial No. ADL 25654 AL K 2580 7. Permit No. 84-221 8. APl Number 50- 029-21237 9. Unit or Lease Name KUPARUK R!VER UNIT 10. Well Number 2C-9 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 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 )/C] 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). On August 26 and 27, 1985, the "A" sands of Kuparuk well 2C-9 were ~e-perforated for production. After testing the lubricator to 2850 psi, the well was shot with a wireline conveyed gun. Interval (MD)- 9412-9389' (4 SPF) 9457-9436' 9369-9389' ECEIVED Alaska 0il & Gas Cons. Commission Anchorage 14.1 hereby certify that the foregoing is true and correct to the best of mx 0r~l~C~eK Sign , , The space below for Commission use COORDINATOR 9/9/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ,~.~' Post Office E~ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 10, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed 1Q-2 Fracture 9/1/85 1Q-3 Fracture 9/1/85 1R-5 Acidi ze 8/23/85 1R-6 Acidi ze 8/24/85 1R-9 Fracture '8 / 27 / 85 1R-1 0 Fracture 8/26/85 1R-11 Fracture 8/26/85 1R-12 Fracture . 8/27/85 2C-9 Perforate 8 / 26 / 85 2Z-1 Fracture 8 ! 19/85 2Z-2 Perforate 8/25 / 85 2Z-2 Fracture 9/2/85 2Z-3 Fracture 8 / 19 / 85 on the If you have ~ M. Drumm Kuparuk Operations TMD/kmc Attachment (Duplicate) any questions, please call Coord ina tor me at 263-.4212. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary o! AllantlcRIchfleldCompany ARCO Alaska, Inc. Post Office B~,.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 21, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached are our notices of intention to reperforate Kuparuk field wells 2C-9 and 2Z-2. If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (In Triplicate) RECEIVED Oil & Gas Cor~s. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~lL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC, 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 1115' FNL, 78' FEL, SEC. 21, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 125.7' (RKB) 6. Lease Designation and Serial No. ADL 25654 ALK 2580 7. Permit No. 84-221 8. APl Number ,50- 029-21 237 9. Unit or Lease Name KUPARUK RIVER UN'iT 10. Well Number 2C-9 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). It is proposed that the "A" sands in Kuparuk well 2C-9 be reperforated for production. Procedures call for the well perforated with a wireline conveyed gun under a lubricator. Proposed Intervals (MD)- 9369'-9412' (4 SPF) 9436'-9457' ANTICIPATED START DATE. AUGUST 25, 1985 to be RECEIVED AUG 2 .t 1985 Alaska 0il & G~S Cons. C0f,amissl0ii Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,.~//~v~ ~~ Title KUPARUK The space below for Commission use OPERAT IONS COORD I NATOR Date 8/21/84~. Conditions of Approval, if any: Approved by ~kpproved Cop)' Roturn~cl ~l~y Urder of COMMISSIONER the Commission Form 10~,03 Rev. 7-1-80 Submit "lnte0tions" in Triplicate and "Subsequent Reports" in Duplicate '"; ARCO .~/ ~, !nc. Post OffiCe Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-2 4-85 TFWtNSMITTAL NO: 5227 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENCINEERING RECORDS CL~K ATO-1!15B P.O. BOX 100360 ANCtlORAGE, AK 995 zF, J~NS4~.T~D HEREWITtt ARE THE 10 FOLLOWING ITEMS. RECEIPT KU PARUK lB-3 \ 04-21-85 PBU BOTH SD. 1C-4~. 04-25-85 .SBIIP BOTH SD. !!!-3 ~, 03-06~-85 PBU BOTII SD. IQ-i-. 05-26-85 SBHP 'A ' SD. lQ-2-. 05 ^6-85 SBHP 'A' SD. lQ-3~- 05-!8-85 SBHP 'A' SD. lQ-4-, 05-14-85 SDHP BOTH SD. lQ-5 ,. 06-06-85 SB[IP 'C' SD. lQ-6.. 04-23-85 SEt!P iQ-7-, 04-17-85 SBHP 'A' SD. iQ-8--. 04-03-85 SBHP 'A' SD. 2A-2x. 05 ~ 7-85 SBHP "~ ' 2A-4 ~. 05-11-85 SBIIP 'A' SD. 04-23-85 , 20 SD. ~-!~~'!' 0~-06-85 SGIIP 'A ' SD. 2C-!0\ 04-40-85 SBHP BOTH SD. 2C-1i\ 03-29-85 SBHP 'A' SD. 2C-12x 03-26-35 SBHP 'C' SD'. 2C-14% 04-23-85 PBU 'A' SD. 2C-1~ 0~-29-85 FBIIP 'A' SD. . 2H-l,. 05-23-85 ???? ???????? 2!{-!'- 05-27-85 SUHP 'A' SD. 2H-2'- 05-23--35 ???? ???????? 2'I-3 ~. 05-~3 85 en,~n 'A' · - - o~.~ SIP. 2!'!-4 %' 05-23-85 SD!iP 'A' SD. 2V-9'- 05-18-85 SBHP 'A' SD. 2V-!0'~ 05-17-85 SBi!P 'A' SD. 2V-i!~' 05-12-85 SB!IP 'A' SD. 2V-!2" 05-14-85 SBIiP 2X-2'- 06-16-85 SBIIP BOTH SD. 2X-2" 06-14-85 SB!/P BOT]I SD. 21<-5'- 06-12-85 oD,~P BOTit SD. 2Z-6' 04-08-85 SBiiP 2Z-7- 04-23-85' PBU EOT!! SD. 2Z-8~ 04-01-85 SE[IP BOT!i SD. - ~ ACKNOWLEDCED: PLEASE ACKNOWLEDGE AND ~' ~ ~ RmTURN ONE SIGNED COPY OF THIS TRANSMITTAL. WELL ?~-.'.o~URE REPORT ENVELOPE DATA CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMC 0 BAKER NORTH SLOPE OTIS OTIS OTiS OTIS OTIS & BAKER CAMCO CAMCO OTIS CAMCO OTIS OTIS OTIS OTIS OTIS OTIS ~ /~-- OTIS --(_~ ~~ OTIS OTIS BAKER NOTH SLOPE OTIS DATE K ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06/18/85 TRANSMITTAL NO: 5218 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 T~S~ITT~D H~IT~ LeS TH~ ~OLLO~ING ITEMS. PL~AS~ ~CK~'~OWLS~G~ /~-~'~qFINAL PRINTS/SCHL OPEN HOLE DATA (ONE * OF EACH) 2C-9 5" DIL/SFL-GR 03-12-85 RUN #1 4162-9584 2" DIL/SFL-GR 03-12-85 RUN #1 4162-9584 5" DEN/NEU-GR PORO 03-12-85 RUN #1 4800-9559 2" DEN/NEU-GR PORO 03-12-85 RUN #1 4800-9559 5" DEN/NEU-GR RAW 03-12-85 RUN #1 4800-9559 2" DEN/NEU-GR RAW 03-12-85 i{UN #1 4800-9559 CYBERLOOK 03-12-85 RUN #1 4800-9530 2E-14 5" DIL/SFL-GR 11-26-84 RUN #1 4030-8658 ?" DIL/SFT,-~P 1 i-'~-8.~ KU~T ~'~ -8 ............. ~-! 4030 658 5" DEN/NEU-PORO 11-26-84 RUN #i 8100-8632 2" DEN/NEU-PORO 11-26-84 RUN #1 8100-8632 5" DEN/NE U-RAW 11-26-84 RUN #1 8100-8632 2" DE N/NEU-RAW 11-26-84 RUN #1 8100-8632 'COMPUTOR PROCESS 11-26-84 RUN #1 8150-8600 2V-10 ~" DIL/SFL-GR 04-03-85 RUN #1 3345-7567 2" DIL/SFL-GR 04-03-85 RUN ~1 3345-7567 5" DEN/NEU-GR PORO 04-03-85 RUN #1 6860-7542 2" DEN/NEU-GR PORO 04-03-85 RUN #1 6860-7542 5" DEN/NEU-GR RAW 04-03-85 RUN #1 6860-7542 2" DEN/NEU-GR RAW 04-03-85 RUN #1 6860-7542 CYBERLOOK 04-03-85 RUN #1 6860-7542 RECEIPT ACKNOWLEDGED: B PAE B. CURRIER CHEVRON D & M*BL DRILLING*BL L. JOHNSTON MOBIL NSK CLERK*BL DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL*BL Alaska Oil & (;as Cons. C0m,'~iss~0ri DATE: -STATE OF ALASKA*BL/ SOHIO SE UNION K.TULIN/VAULT*FILMS ' ARCO Alaska, Inc. ~'"-- Post Office Bo,. J360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 11, 1985 Mr. C. V. Chatterton CommissiOner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' If you 2B-13 2B-14 2C-9 2C-12 2Z-4 Prudhoe Bay State #1 have any questio.gs, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L50 Enclosures RECEIVED JUN 1 2 ]985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichlieldCompany STATE OF ALASKA ~---- , ALASKA~ _AND GAS CONSERVATION CC .~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-221' 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21237 4. Location of well at surface 9. Unit or Lease Name · 1115' FNL, 78' FEL, Sec.21, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1285' FNL, 1368' FEL, Sec.15, TllN, R9E, UM 2C-9 At Total Depth 11. Field and Pool 1007' FNL, 1145' FEL, Sec.15, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 125' RKB ADL 25654 ALK 2580 12. Date Spudded 13. Date T:D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 03/04/85 03/13/85 03/14/85' N/A feet MSLI 1 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I~O.~,,t~r, SSSV,, 121.Thickness of Permafrost 9660'MD,6268'TVD 9529'MD,6168'TVD YES F~X NO [] 1792 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/$P, FDC/CNL, Gyro 23. CASING, LINER AND CEMENTING RECORD . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 101 ' 24" 250 sx Col d Set I I 9-5/8" 36.0# J-55 Surf 4162' 12-1/4" 1000 sx AS Ill & 600 s; Class G 7" 26.0# J-55 Surf 9620' 8-1/2" 430 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number)~ SIZE DEPTH SET (MD) PACKER SET (MD) 9375', 9377', 9387', 9389', 9393', 9395',1 W/12, spf, 3-1/2" 9311' 8967' & 9284' 9397', 9399', 9401', 9403', 9441', 9443'~I 120° phas ng 9447' 9449' 9452' 9454' 9491' 9493' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9495 ' 9497 ' , DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum dated 5/2/85. 9131' - 9252' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested iPRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure 'CALCULATED,I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECeiVED A!aska Oil & Gas Cons, Co-mmiss~or; Anc.hora9~ Form 10-407 NOTE: Tubing was run and the well perforated 4/3/85. GRUg/WC36 Submit in duplicate Rev. 7~1-80 CONTINUED ON REVERSE SIDE ' ::i ,-;: ¢;. ? ~-'i;i GEOLOSi'CI~'-kR:K-'I~'R~i (?:;~ ~?.~? :~' ..... ,:'.,!.:: :.~ ~-~_ ;'~-¢.-,,,'; ': .... ; !<-L, :~;-'.' - :"'.:.:.. :FORMATION'"':: ";'"'¥': :"-:'-7,~ ~-'.'..:rESTS,. '" "" ' ' ; .-'" .- · · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. - : Top Upper Sand 9127'. 5871' N/A ." Base Upper Sand 9212' 5933~ TOp Lower Sand !' 9357' 6039' ...... .. ' .... -': Base Lower Sand - 9524' 6165' . . . .. ,_ . . . . , 31. LIST OF ATTACHMENTS .- .: Arld~nrh~m '~ : -' 32. I hereby certify that the foregoing is true a..n.d correct to the best of my knowledge Signed (~~ ~ Title Associ ate Engineer Date INSTRUCTIONS , General' This form is designed fOr submitting a complete and correct well completion report and log on all types of lands and leases in Alaska; Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), ~o state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the Cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 4/08/85 4/11/85 4/13/85 2C-9 RIH w/impression block. RIH & latch onto blanking plug, POH. Frac well in 8 stages w/356 bbls gelled diesel, 750# 100 mesh & 7900# 20/40 mesh. RIH w/CTU. Circ cln w/gelled diesel to TD @ 9509'. Drilling S~Zperintendent RECEIVED Date JUN 1 2 i~B5 Alaska Oil & Gas Cons. Commission ARCO Alaska, Inc. Post Office Bux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2C-9 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L03 Enclosures RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '.~- STATE OF ALASKA '~-' ALASKA . AND GAS CONSERVATION C( MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-221 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21237 4. Location of well at surface I L~-'CA,;©r~b! 9. Unit Or Lease Name 1115' FNL, 78' FEL, Sec.21, TllN, RgE, UM I VFRjFi/~ .-J Kuparuk River Unit At Top Producing Interval [ Sur~.~j 10. Well Number 1285' FNL, 1368' FEL, Sec.15, TllN, RgE, UM B.H.~_~} 2C-9 At Total Depth 11. Field and Pool 1007' FNL, 1145' FEL, Sec.15, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125' RKBI ADL 25654 ALK 2580 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 03/04/85 03/13/85 03/14/85* N/A feet MSLI 1 , 17. Total Depth (MD+TVD, 18. Plug Back Depth (MD+TVD, 19. DirectionalSurvey I 20. Depth where SSSV set ] 21.Thickness of Permafrost 9660'MD,6268'TVD 9529'MD,6168'TVD YES I~X NO [] 1792 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 101' 24" 250 sx Cold Set II 9-5/8" 36.0# J-55 Surf 4162' 12~1/4'' 1000 sx AS III & 600 s: Class G 7" 26.0# J-55 Surf 9620' 8-1/2" 430 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) 'x, SIZE DEPTH SET (MD) PACKER SET (MD) 9375', 9377', 9387', 9389' 9393' 9395',~v~/12 spf, 3-1/2" 9311' 8967' & 9284' 9397', 9399', 9401', 9403', 9441' 9443' 120° phas ng 9447' 9449' 9452' 9454' 9491 ' 9493' 26. ACID, FRACTURE, CEMENT SOUE~ZE, ETC. 9495' 9497' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 9131' - 9252' 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~! 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core c_hips. NONERECEIVED Naska Oil & ~as Cons. Commission Anchorage Form 10-407 NOTE: Tubing was run and the well perforated 4/3/85. TEMP/WC09 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . · NAME .... I Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time, of each phase. _ Top Upper Sand 9127'~ 5871' N/A Base Upper Sand 9212' 5933' Top Lower Sand- 9357' 6039' Base Lower Sand 952.4' 6165' . . . . _- . . : . . 31. LIST OF ATTACHMENTS Well History (including completion details)~ Gyroscopic Survey (2 eo~ies) 32. I hereby certify that the foregoing is true'and correct to the best of my knowledge INSTRUCTIONS General: This form 'is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so .state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval tO be separately produced, showing the data pertinent to Such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water I~- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken,, indicate "none". ARCO Oil and-Gas Company,~,"~' - Well History - Initial Report - Daily Inll~uctionl: Prepare and submit the "lnil]ll R~lmrl" on the first Wednesday after a well is _spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 503355 Pool #102 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. 3/27/85 ICounty, parish or borough North Slope Borough Lease or Unit Trna ADL #25654 Comp 1 e t ion State Alaska Well no. 2C-9 3/28/85 API 50-029-21237 I ARCO W.I. IHour IPrior status il S W.O. 1030 Hrs. -: thru 4/01/85 4/02/85 4/03/85 3/26/85 Complete record for each day reported 56.24% 7" @ 9619' 9510' PBTD, POOH w/gun #6 9.8 NaC1/NaBr Accept rig @ 1030 hrs, 3/26/85. ND tree, NU & tst BOPE. RU WL, perf w/4" csg guns, 12 SPF, 120° phasing @ 9375', 9377', 9387', 9389', 9393', 9395', 9397', 9399', 9401', 9403', 9~1~/, oK 9443', 9447', 9449', 9452', 9454', 9491', 9493', 9495', 9497'. Perf w/5" csg guns, 12 SPF, 120° phasing f/9192'-9252'. 7" @ 9619' 9509' PBTD, Prep to rn 3½" CA 9.8 NaC1/NaBr RIH w/5~'csg gun, perf 12 SPF, 120° phasing f/9131'-9192' w/pkr, set @ 9284'. Prep to RIH w/3½" compl string. · RIH 7" @ 9619' 9509' PBTD, RIH w/3½" compl 9.8 NaC1/NaBr Wait on FL45 its. Begin_rn'g 290 its, 3½" completion. "~ 7" @ 9619' 9509' PBTD, Prep to kill well Crude/Diesel Rn 290 its, 3½", 9.3#, J-55 EUE IPC tbg. Shear out SBR, lnd tbg. Set BPV, ND stack, NU tree & tst. Displ well to crude. Press inc'g. RIH & pull ck vlv. Compl w/displ of crude. Tst SSSV. RIH, set dummy vlv; small leak. RU elect in, RIH w/temp spinner logs; shows leak 9 jts above GLM @ 8917' dummy. Set tailpipe plug. RU to kill well. 7" @ 9619' 9509' PBTD, Pull hgr to flr 9.8 ppg NaC1/NaBr Set BPV. ND tree, NU BOP. . RU WL, pull Pull BPV. Tst BOP. POH w/hgr. 7" @ 9619' 9509' PBTD, Pull orifice vlv 9.8 ppg NaC1/NaBr POH w/3½" tbg, lk'g f/leak. RIH w/3½" tbg &lnd. BOPE, NU & tst tree. Displ well to crude. RECEIVED Set BPV, ND Alaska Oil & Gas C°ns.~'ommissi rl~, o The above is correct erin p eparatlon ~nd cllatri-bUtiqi~, For f r see Procedures Manual, Section 10,F Drilling, Pages 86 and 87. Date I Title 4/12/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable- has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District County or Parish Lease or Unit Tte IAccounting cost center code State Alaska Field Alaska Kuparuk River North Slope Borough ADL #25654 JWell no. 2C-9 Auth. or W.O. no. AFE 503355 Pool #102 Completion &PI 50-029-21237 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 3/26/85 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 1030 Hrs. Dale and depth as of 8:00 a.m. Complete record for each day reported 4/04/85 Old TD New TD Released rig 2100 Hrs. 7" @ 9619' 9509' PBTD, RR Crude/Diesel Tst SSSV. Set BPV. Classifications (oil, gas, etc.) Oil Producing method Date RR @ 2100 hfs, 4/3/85. PB Depth 9509 ' Kndofrg Rotary 4/03/85 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable ,~_ ~.,f.ec~ejda¥~ J. n corrected The above is correct I Date ITitle Si g n at u re ,~l#J~~,~~ 4/12/85 For form prepaSa~ion and'di(~'ibuti~,, - see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ~,, ~ bas Cons. Commission Drilling Superintev~0r~ae ARCO Oil and Gas Company,~," Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or wa~orkover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. Field Kuparuk River Auth. or W.O. no, AFE 503355 District I County, parish or borough I State Alaska I North Slope Borough I Lease or Unit I ADL 25654 I Title I Drill- Alaska Well no. 2C-9 Parker 191 Operator ARCO Alaska, Inc. API 50-029-21237 Spudded or W.O. begun IDate IH°ur Spudded 3/4/85 0030 hrs. Date and depth as of 8:00 a.m. 3/04/85 3/05/85 ·-:_ ::. 3/06/85 3/07~85 Complete record for each day reported 3~08~85 ARCO W.,. 56.24% Pr or status if a W.O. 16" @ 101' 500', (399'), DD Wt. 9.6, PV 17, YP 23, PH 9.5, WL 14, Sol 4 Accept ri~ @ 2000 hrs, 3/3/85. NU diverter sys. 3/4/85. Drl to 500'. Spud well @ 0030 hrs, 16" @ 101' 2644', (2144'), Drlg Wt. 9.6, PV 14, YP 19, PH 9.5, WL 14, Sol 6 Drl & surv 12¼" hole to 2644'. 474', Assumed vertical 618', 3.8°, N38.5E, 617.92 TVD, 4.77 VS, 3.74N, 2.97E 1065', 21.4°, N44.5E, 1051.85 TVD, 104.89 VS, 81.10N, 66.54E 1520', 35.3°, N39.5E, 1450.60 TVD, 321.05 VS, 238.57N, 215.81E 1743', 41.9°, N37.5E, 1624.88 TVD, 460.18 VS, 347.45N, 302.42E 16" @ 101' 4200', (1556'), RU to rn csg Wt. 9.9, PV 15, YP 12, PH 9.0, WL 12.5, Sol 8 Drl 2644'-4200', CBU, 20 std short trip, C&C, POH. 2628', 55.6°, N38.5E, 2174.17 TVD, 1151.08 VS, 886.84N, 734.18E 3557', 55.0°, N37.5E, 2705.07 TVD, 1912.47 VS, 1488.90N, 1200.36E 4047', 53.7°, N35.5E, 2990.66 TVD, 2310.39 VS, 1808.97N, 1437.20E 9-5/8" @ 4162' 4200', (0'), DO cmt Wt. 9.0, PV 5, YP 8, PH 9.5, WL 18, Sol 3 RU & rn 96 its, 36#, J-55 HF-ERW BTC csg w/FS @ 4162', FC @ 4073'. Cmt w/1000 sx AS III @ 12.2 ppg + 600 sx C1 "G" w/2% S-1 & .2% D-46 @ 15.8 ppg. Displ w/mud, bump plug w/1500 psi. CIP @ 1535 hrs, 3/6/85. ND diverter, NU csg head & BOPE. Tst same. PU BHA, GIH, tag FC @ 4074'. Tst csg to 1500 psi; OK. 9-5/8" @ 4162' 6640', (2440'), Drlg Wt. 9.4, PV 10, YP 17, PH 10.5, WL 13, Sol 6 DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 6640'. 4439', 56.2°, N35.5E, 3219 TVD, 2629 VS, 2068N, 1622E 5343', 57.2°, N39.5E, 3713 TVD, 3385 VS, 2656N, 2099E 5967', 56.5°, N40.5E, 4052 TVD, 3909 VS, 3071N, 2663E 6561', 56.2°, N36.5E, 4377 TVD, 4406 VS, 3463N, 2725E Alaska Oil & Gas Can.~ Commissfo. The above is correct S~gnature For form preparation and distribution, ~., ~..~ ~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 4/24/85 ITM Drilling Superintendent A ARCO Oil and Gas Company '~' ,~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheels until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less lrequentiy than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string unlii completion. District [County or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River J ADL 25654 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 3/09/85 thru 3/11/85 3/12/85 3/13/85 3/14/85 Alaska JWell no. 2C-9 9-5/8" @ 4162' 9636', (2996'), Prep to log Wt. 9.6+, PV 15, YP 12, PH 9.0, WL 8, Sol 8 Drl & surv 8½" hole to 9154', lost circ, mx & spot 60 bbls nut plug & 40 bbls LCM pill; regained circ. Drl to 9636', start losing mud @ 12 BPH. Made 20 std short trip, spot 115 bbls LCM, TOH, still losing mud @ 12 BPH. Prep to log. 6687', 55.5°, N39.5E, 4447.64 TVD, 4510.75 VS, 3544.74N, 2789.62E 7610', 7929', 8182', 9024', 9461', 9601', 58.9°, N38.5E, 4953.58 TVD, 5294.43 VS, 4151.71N, 3285.45E 56.6°, N37.5E, 5118.46 TVD, 5555.70 VS, 4357.62N, 3446.33E 55.2°, N35.5E, 5260.30 TVD, 5764.91VS, 4526.02N, 3570.94E 45.7°, N38.5E, 5788.16 TVD, 6418.86 VS, 5056.87N, 3953.87E 41.1°, N38.5E, 6105.59 TVD, 6719.04 VS, 5291.79N, 4140.74E 39.2°, N39.5E, 6212.59 TVD, 6809.29 VS, 5361.94N, 4197.55E 9-5/8" @ 4162' 9636', (0'), Prep to log Wt. 9.7, PV 13, YP 7, PH 9.5, WL 7, Sol 8 Att to rn triple combo; could not pass 8150', POOH, RD Schl. TIH, C&C well, spot LCM pill, TOH to log. No drag, still losing fluid @ 4 BPH. Total fluid lost to date = 918 bbls. 9-5/8" @ 4162' 9636', (0'), TIH Wt. 9.8, PV 16, YP 7, PH 9.5, WL 7.6, Sol 8 Log DIL/SFL/GR/SP f/9589'-4162', rn FDC/CNL f/9589'-8950', 7700'-7300', & 5400'-4800', RD loggers. TIH to cond hole, pmp pressure less than expected, TOH; lost bit blank. TIH. 9-5/8" @ 4162' 9660', (24'), Rn'g 7" csg Wt. 9.8, PV 15, YP 6, PH 9.0, WL 6.4, Sol 6 TIH, drl 8½" hole to 9660', C&C f/7" csg, TOH, LD DP. Chg rams to 7" & tst. RU & rn 7", 26#, J-55 BTC csg. The above is correct Signatu~_.~ , For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date 4/24/85 rTM Drilling Superintendent V,,.AY 2 8 1985 A!as~,a 0~ & Gas Cons. Commission Anchorage -ARco Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I County or Parish I State Alaska North Slope Borough / Alaska Field ILease or Unit IWell no. Kuparuk River APL25654 2C-9 Auth. or W.O. no. ITitle AFE 503355 I Drill Parker 191 API 50-029-21237 Operator I A.R.Co. W.l. ARCO Alaska, Inc. I 56.24% IDate 3/4/85 Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 3/15/85 Complete record for each day reported Iotal number of wells (active or inactive) on this pst center prio'r to plugging and I bandonment of this well I our I Prior status if a W.O. I 0030 hrs. 7" @ 9619' 9529' PBTD, 9660' TD, (0'), RR Wt. 9.8, PV 15, YP 6, PH 9.0, WL 6.4, Sol 6 Fin rn'g 231 its, 7", 26#, J-55 BTC csg w/FS @ 9619.85', FC @ 9529.90'. M&P 430 sx Cl "G" w/3% KCl, .8% D-60, .2% D-46 & 1/4#/sx Celloflake. Displ using rig pmps, bump plug. CIP @ 1340 hrs, 3/14/85. ND BOPE, set 7" slips & cut off csg. NU wellhead & tst pack-offs to 3000 psi. RR @ 2400 hrs, 3/14/85. Old TD Released rig 2400 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD Date 9660' (3/13/85) Ps Depth IKnd of rig 3/14/85 I IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 9529' Rotary Well no. Date Reservoir I Producing Interval Oil or gas Test time Production Oil on test Gas per day RECEiVF_ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective data corrected /iAV9 o IOO~ The above is correct t;~r~d UI ~x GaS G0rls, ~~ ~ Z~ C ~. 4/24/85 Drilling Superintendent I*'e Anchorage For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. April 8~ 1985 Directional Services Pressure Services Chemical Transmission Systems Mr. Randy Ruedrich ARCO Alaska, Inc. P. O. Box 560 Anchorage, Alaska ~9510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-50056 Well: 2C-~ (SEC 21TI1N ROgE) Field: Kuparuk Alaska Survey Date: March 17, 1985 Operator: J. Samec, M. Derison Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Survey on the above well. Thank you for giving us this opportunity to be of service. Si ncerel y, NL SPERRY-SUN~ INC. Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 RECEIVED Alaska Oil & Gas Con=. Comm!.3sien Anchor~,rja SPERRY-SON"W'E-LE'"~UR~E~iNG'COMPANY ANCHORAGE ALASKA ARCO ALASKA, INC. 2'C=~SEC21 Tll'N RO~E) COMPUTATION'-DATE KUPARUK MARCH 18, 1785 ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE 1 DATE OF SURVEY MARCH 17, 1785 BOSS GYROSCOPIC 'suR-~E9 ............ JOB NUMBER AK-BO-50036 KELLY BUSHING ELEV. = 125.00 FT. OPERATOR-.i', SAMEi_%' ..... H-~ ....... ~i~ER I'.qON ...................................... TRUE ............ SUB=SEA .... COURSE ....... COURSE 'DOG'LEG MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY DEPTH DEPTH DEPTH BEG MIN DEGREES BEG/lO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST . 0 0.00 -125.00 100 99.99 -25.01 ............................... 20'0 ........... I97~$8 ........ 7~;98 300 2??.?6 174.76 400 3??.?5 274.?5 ............................. 500 4~9'.'74 .... 374,94 600 5??.85 474.85 700 6?9.30 574.30 0 0 N O. 0 1 2 c. 11 19 ........ 0 ....... 57 ................ S 'I2,' 0 0 51 S 13.6? 0 4? S 22.3? 0" 56 ............ N "6d-'.'. 8..° 3 44 N 45. 0 8 3 N 41.89 ............................... 800 ~00 1000 I~00 1200 1300 .................. I400' 1500 1600 .................. 1700 1800 1700 ................ 2000 .... 2100 2200 .............. ~7.'77 894.81 989.98 ........ I083'-18 1174.04 1262.67 1'349.19 1432.78 1513.72 1591;50 -t665.81.., '672, 7.9 ........... 11 45 ............. i~I--' 39 ~'"I ? 74.9.81 864.98 958,"18 1049.04 1137.67 "1224.19' 1307.78 1388.72 1466.50 154(>.81 16 11 N 38.50 19 31 N 43.60 '"22' 57 ............. N 46'f-60 26 ~°'z' N 47.60 28 46 N 43.3? 31 '24 ........N'~2~'"I9' 34 43 N 40.10 37 33 N 39. 0 40 .... 17 ............ N--~8"~'8~'- 43 40 N 38.89 1736.75 1611.75 1'805;48 " '1680';48 1869.74 1744.74 1929.14 1804.14 E 0.00 W 1.04 W 0;09 ..... 45 47 52 54 W W E E E E" E E O. 10 0.13 1.'64 2.89 4.3:3 ..... 3.7'2 ' 4.44 3.68 E ......... 3;; 61 E 3.45 E 3. O? -'E .... 2.70 E 3.51 E 2. ?0 E ...... 2.76 E 3.35 36 N 37.30 E 1.76 51 ......... N' '39'. 39"E 2: 24'" ? N 39.:30.E 4.31 56 N 38.89 E 2.81 0.00 0.89 S 2.5? S 4.13 S 5.53 S 5.88 S 3.25 S 4.2:--: N 17.39'N 36.20 N 57.22 N 84.73 N 113.12 N 145.60 N 182.40 'N 223.50 N 268.99 N ' ' 317.86 N 36'.-?. ?3 N 424.44 N 480.74 N 53?. ?7 N 602.3? N 2400 2042.75 2500 2077.18 ..... 2600 ...... 2155,73 2700 2212.48 28£>0 2269.64 ......................... 2900 2327.14 'I'986,19 ....... 1'861';'I? .............. .55,---2~ ...... 1917.75 55 38 1~74.18 55 37 2030.73 .......... 55 30 2087.48 2144.64 54 55 2202';14 " 54 '51' N' ]38. 80-'E ............. -0.53 ...... 66;"-.-; 35 N N :3:$:. :30 E A. 4!5 7:--:0. '-'= ,=,._, N N 38.50 E 0.17 7?5.54 N N- 3:3, 6.9 'E '0'. 21 860. O0 N N 36:.50 E 0.22 ?24.35 N N 38.80 E 0.49 ?88.43 N "N'-38"f 50"-'"E ............ 0';"25 .... 1052.32 N 0. O0 0.18 W .... 0';'52 W' 0.87 W 1.3:3 W 0,85 W 2.21 E ?.20 E '20, 3:2 E :::5.45 E 55.65 E 81.:::5 E 111.74 E 144.8? E 178. ?4 E 214.81 E ..._, .-'. :34 E 2'.'? 1. :s:5 E 33:--:. 86 E 37:$:. 17 E 424.33 E 472.8? E 523.61 E 575.13 E 626. ~2 E 677.80 E 727.26 E 780.62 E 831.87 E 882. ?7 E VERTI C:P' :--;E C:T I ~. ').: O. 00 -0.81 -2.36 -.3.7'?~ -!5. 17 --5. 15 -1.20 ?. 04 26.22 50.35 :::0. '.-? :3 116. :-':/_-. 15:E:. 06 20:_--: '- "" = .-:7 ._~ 308 ...... :367. :2:4 4:30. 17 47'7.06 567. :30 640.08 716.65 797.07 877.19 961.66 1A44.21 1126.68 1209.01 1271.06 1372. :_--:7 ARCO ALASKA, INC. ..................... 2C=9(SEC2i ~TiiN~ROgE) KUPARUK ALASKA · =.FERRY-.:.EN WELL SURVEYING CGMPANY ANCHORAGE ALASKA ........... COMPUTATION 'DATE MARCH 18 VERTIC:AL SECTION . C:ALC:LILATED ALONG r:LnSLIRE ...... PAGE DATE OF SURVEY MARCH 17, 1985 BOSS'GYROSCOPIC SURVEY JOB NUMBER AK-BO-50036 KELLY BUSHING ELEV. = 125.00 FT. OPERATOR-J, SAMEC'; ....... MJ-"'DERISON .................................... TRUE MEASLIRED VERT I CAL DEPTH DEPTH ~UB-~EA nnllR~E ............. ~OIIR~ VERTICAL INC:LINATION DIRECTION DEPTH DEG MIN DEGREES lOG-LEO SEVER I TY D ElS / 1 C>0 TOTAL ..................... RECTANGLILAR COORDINATES NORTH/SOUTH EA._T/WE.=.T 3000 2384.67 3100 2442.28 ................................... 3200 ....... 2499;94 .... 3300 2557.21 3400 2614.04 ......................... 3500 .............. 267I'~"03 ..... 3600· 2728.43 3700 2786.10 3800 ............... 28~'3;"99 ......... 2718. 3900 2902.22 2777. 4000 2961.06 2836. ......................... ~I-00 .......... 3020',60 ...... 2895. 4200 3080.17 2955. 4300 3138.16 3013. ..................... zl:z~O0-' 3 I94" ~ ~,~ o06.. 4500 3250.52 3125. 4600 3306.46 3181 ~700 ..... 3362.16 3237 4800 3417.45, 3292 4900 3472.22 3347 5'000 ........ 3526.71 ' 34'0I 5100 3581.21 3456 5200 5300 5400 5500 .... 56'00 5700 5800 3635.79 3510 .......... 3690,27 3565 3744.69 3619 3799.19 .... 3~3;71 3908.13 3962.54 ...................... 5900 ...... 4017;~ 2259.67 54 54 N 38.39 E 0.09 2317.28 54 43 N 38. 0 E 0.37 2374';94 54 5'I ................. N'"37~89 'E 0.15"' 2432.21 55 16 N 37.80 E 0.43 2489.04 55 28 N 37.50 E 0.32 2546,'03 55 2 N-"'3'6"~ 80 'E .... O, 72 2603.43 54 53 N 36.69 E 0.16 2661.10 54 39 N 36.60 E 0.25 99 5~ ........ 36 ........... -N-36'.'39-"~ O~ 17 22 54 10 N 36.30 E 0.44 06 53 44 N 36. 0 E 0.49 60" 53 I0 ........... N-'~._~'80-'"E .................... 0,58' 17 53 41 N 35.50 E 0.57 16 55 23 N 35.60 E 1.70 '52 ..... 55 ....58 ........N'"3~]'.S"-~-'E ............. 1",'22 52 55 55 N 37.80 E 0.75 .46 56 3 N 38.60 E 0.68 ,1~ ........ 56 15 ........N-'"3B',-i'9-E .......... 0:39 .45 56 36 N 38.10 E 0.37 .22 56 58 N 38. 0 E 0.38 .71 ...... 56 '58 ....... N'-~7; 69 E .... 0.2~--._ .21 56 5:3 N 37.50 E 0.17 .79 56 52 N 37.30 E 0.20 .27 ..... 57 6 ..... N"36.89 E .............. 0.41 .69 56 56 N :36.80 E O. 18 3674.19 57 0 N 36.39 E 0.34 '37"28.71 ......... 56" 55 ...... N'"'35; 89-'~ ................. O. 43 3783.13 57 7 N 35.60 E 0.32 3837.54 56 57 N 35.10 E 0.45 3892~56 '56 '16 N'"-3~TI'..~-E ............. I,"I~ ..... 1116.38 1180.61 · 1245.04' 1309.77 1374.92 1440.4'1' 15(.')6. (])2 1571.56 '1637~ 1-'1'" 1702.59 1767.87 - 1832.96 ' 1898.23 1964.50 '2031 .' 10 2096.96 ~162. 10 2227. 19 2292.71 2358.60 - 2424.81 2491.23 2557.80 2624.68 2691. :::'2 2759.13 2826, 82 ' 2894.90 296.'3.34 3'031. 17 N 93:3.83 N 984.38 N 1034: '62' N 1084.92 N 1135.18 N" 1184.81 N 1233.80 N 12.'.=:2.57 N 1.:,.. I 07 N 17:79 o5 N 1426.95 N .... 1474.06 N 1520.88 N 1568.24 N' I617.08 N 1667.34 N 1718.60 N 1770.19 N 1821.65 N 1873.22 'N ' 1924.67 N 1975.8:3 N 2026.72 N 2077.31 N 2127.62 N 2177.61 N' "o.').'~7 06 a~. -' ." ¢. N 2276.07 N 2324.62 · ':'. ~ 7":. '7.. P. ~--- -----' m ~,. -- E E E E E E E E E E E 'E ' E E E' E E E E E E E E E E E E E E E VERT I CP' :--;ECTIL ,I 1454.67 .r.: .~ -"~ 1~o6 4(:) 161'",:,. 10 1700.0,=,- '-' · ?,q.-, .q/. %< . 5'2 1 ,:, :,4 1946. :38 2028.05 109, 57 '::.' 1 '..'?0.83 2271.64 2351.93 24.'---:2. 18 '.-'.'513.56 2596. 2678. ';, ._,' 2761.84 2:5:44. 2928.21 3011.8 3095.73 ..5 :3179 ._ 7 3263. :36 :3347.20 34:31.08 :2:514.90 3598.69 :36:--:2.51 3766..:. · 384'P. 75 ARCO ALASKA, INC. 2C=gXSEC21--TI1N--ROgE) KUPARUK ALASKA .=.F ERR Y-.=..EII~fJEL L' 'SLIRVEVI NG" i-:OMPANY ANCHORAGE ALASKA .......... C'OMPLITATION DATE ..... MARCH 18, 1'-''~=yo,_, VERTICAL SECTION CALCULATED ALONG C:LOSI_IRE ............. F'AGE :3 DATE OF '.E;URVEY MARF:H 17, 1985 BO::GYRO:COP I E!~ "S;UR'V~? ._lOB NUMBER AK-BO-50036 KELLY BUSHING ELEV. = 125.00 FT. OPERAT(]R-.J, SAMEC'; ....... Pi.'-' ......... ]EiER'I '.SON .............................................. TRUE'" MEASURED VERTICAL DEPTH DEPTH 6000 4073.04 6100 4128.37 ............................... 6200 4I"83.36 6300 4238.02 6400 4292.38 ......... '~ ........ l~I L'--ILR'~E ' o-l:~-oEA ......... COf3RSE .................... VERTICAL INCLINATION DIRECTION DEPTH BEG MIN DEGREES 3948.04 56 19 N 36.19 E 4003.37 56 29 N 36.1~ E ........... 4058;'3~ ........... 5~ ....... 47 .............. N"'38;'30-'E' 4113.02 56 56 N 36.19 E 4167.38 57 12 N 36. 0 E DOG'LEG SEVER I"rY DEG/100 0.05 0.17 ...... 0.31 0.17' 0. :32 TdTAL ................................... REC:TANGI.ILAR C:00RD I NATES VERT I (::A~ ' / NORTH/:--;OUTH EAST/WEST oEuT I 0,. - 30'?`'8.33 N 2422· 42 E 3'.:~32.90 :::165.~ . 40 6. 6 ._4 N 2471 61 E _1 1 ':"-"'~'~' 90 N .~._ ~ 1 ',' 0'0"-E: 40'.;~9 64 3300.4::: N 2570.52 E 418:3.34 ::436,c:. 25 N 2619.97 E 4267.2.'_--: ..................... 6~0'0 ............ 43'47.0'7 42'22;'07 ...... 6600 4402.68 4277.68 6700 4459.15 4334.15 ...................... 6800 .......... 4~1'5'-'87 .......~3~0';87 6900 4572.00 4447'00 7000 4627.54 4502.54 TI'O0 .............. 4682, 53 455_,7.'53 ' 7200 4737.06 4612.06 7300 47'P 1.24 4666.24 ................... 74'00 4844.87 ' 471~'; 87 7500 4897.81 4772.81 7600 4949.90 4824.90 7700 5002.36 4877.36 7800 5055.91,-, 4~30.~1 7~00 5110.20 4~85.20 ................ 8000 ...... 5165.54 5040;54 8100 5221.84 5096.84 ~ ....... J 5153.95 ~00- ...... 5336,'79 .......... 5211 ;"79 ' " 8400 5395.62 5270.62 8500 5455.80 5330.80 .................... 8~00 ..... 5517.47 53?2.47 8700 5580.74 5455.74 8800 5645.55 5520.55 ..................... ~00_ .. 57I°~ . ~ ~87'~__ ~.~ 55 57 N 38. 19 E 1.05 55 16 N 39.69 E 1.41 55 36 .............. N- 37'; 80"E ...... 0'. '34 56 5 N 39.80 E 0.48 56 26 N 39.80 E 0.35 56''50 ......... N--39'J30' 'E ....... 0',58 57 4 N :::'.:`'. 1'.:.? E 0.24 3435.50 3501.30 3565.48 3628.80 3692.38 3756.27 3820.68 3885.5~ 57 18 N :3':?. 30 E 57 47 ................ }I'- 38 ;,"'SS.~'"'E .......... 58 15 N 38.69 E 58 56 N 38.19 E 57'46 ........... N"-'37;30-'E"' 57 2:3 N 36.:--:'?, E 0.25 3950.67 0'.61 "4016.17 0.47 4082.29 0.81 4149.14 1.4i" 4216~45 0.45 4283.80 N N N N N N N · _,6 46 N 37 19 E 0.7:3 4o._,3.83 N 56 1 .... N 36%89'"E" 0,80 4417.30 N 55 26 N 37.30 E 0.67 4483.21 N 54 54 N 37.30 E 0.53 4548.52 N '54 ....25 .........N" 37'; '-O"E ...............U: 55 461-3,54 N ' 5:3 29 N :::7. 0 E O.'P;7: 4678. 11 N 52 30 N 36.50 E 1.06 4742.10 N 51 ' '20 ...... N'-36~ 89'--E ................... 1] 21 4805.21' N 50 9 N ;7:7.80 E 1.:37 4866.77 N 49 2 N 37.39 E 1. 16 4927. 10 N 47 1'.9 ......... N"38.--5_.O-ET ..................... I';"~'l ................. 4985.86 N 2669.6:2 E ..... 4:350. 'P 1 2720 Pi""' .... ~ E 44 :--:4.02 2772.4../:. E 4516.5:3 '-":"~'~' 1 "> 'E 4598 '-'~' .' i_~.,:.._ . .,_ · ~_-%.J 2:::78. A9 E 4681.57 2931.33 E 47/_'.4./z. 9 2984 ' 51' E 4:5:48 18 30:B7.54 E 4931.78 3090.72 E 5016.01 3143 95 E '5100.;7' 3197 11 E F.I,..._ '-' . .- . 3250.19 E 527A.5 3:--:02 31 E F,'"5= ...... - .... ,. 71 · -.. c. ~.-:, 25 E 5440 15 · _~ ._; ._ ,_! · , 340 :'-':. 85 E F,'-"-' '~ ..... · ---~. 12 o4._4 0:3 E 5/-_.07.40 :::50:'::. :E:8 E 5690.0:3 '-'-'-";-=;':' 6:3 E 5772 11 · "*.-- --- .-! m m 3/_"'02. :;:9 E 5:_--:5:3.68 L'::/-,.~,i 55 E 5':'.,':'::4 '="-' -- -- . · ._l ~ 3699. :_'-: 3 E 6014. :36 3746.37' E 6093.05 :::793.35 E 6170.48 :'s:837.81 E 6246.6',2: '-"-"-'= 6::: E /_-.:~21 14 ._-, ,-, ,-, .j = · ............ SPERRY'SUN'"'WELE'"'SURVEYING"COMPANY ANCHORAGE ALASKA ....... COMPUTA'TIONDATE" MARCH 18, 1985 ARCO ALASKA~ INC. ................ 2LD.=?'(SISC2! 'T1 I'N' ROgE) ................................ KUPARUK ALA~'-';KA VERTICAL SECTION CALCULATED ALONG CLOSLIRE PAGE 4 DATE OF SURVEY MARCH 17~ 1985 'BOSS GYROSCOPIC SURVEY ......... dOB NUMBER AK-BO-50036 KELLY BUSHING ELEV. = 125.00 FT. OPERATOR-J. SAMEC; ........ M"; .... DERISON' MEASURED DEPTH 9000 ~100 9'20'0 9300 9400 ........ TRUE VERTICAL DEPTH ........... ~UB'~EA ' COLIRS~ .......... COURSE DOG-LEG ..... TOTAL .............................. VERT I CAL I NC:L I NAT I ON D I RECT I ON SEVER I "FY REC:TANGLILAR COORD I NATES; VER]' I DEPTH DEG H I N DEGREES DEG/100 NORTH/'.SOUTH EAST / WE'.E:T 'SECT 5781.05 5656.05 45 40 N 40.10 E 2.02 .:;,:,.=, 1. :=: 0 "~l '7.=,/- .8 0 4 4 1 ._, = N 4. 0 .8 A E1 .4. 9 '5..'~23, 87 .... 57'.~8';'87 ...... 43' ' 31 ............. N '3:-'-.~; 30 K ...... 1.28 5997. O0 5872. O0 42 29 N :_~:'.~. 1 '.:.~ E 1.03 6071.21 5946.21 41 40 N :38.60 E 0.90 5041. '.:.)S) N 3931.55 E 6:393.64 50S~5.76 N 3977.39 E 6464.24 5148,82 N 4022.00 B" 6533.51 5201.64 N 4065.15 E 6601.70 5253.79 N 4107.24 E 6668.71 ........................ 9461 ......... 6117-;"06 5992;'0~. 40 51 ................. N '38;'19" E ........ 1.41 5285.32 'N ' 4132.23 E ~.708.95 9500 6146.55 /_-.021.55 40 51 N :=:8.1 ?) E 0.00 5:=:05.37 N 4148.01 E 67:'::4.46 9600 6222. 1 'P 60S>7.1 '.~ 40 51 N :--:8.1 'P E 0. O0 5356.7'.:) N 4188.46 E /=.7'.;~'.-.-~. 88 ..~;'60 ................. 6;267';'..~ ............ 6"I42,57 40 51 ...... N"-38'; I~"-E" ............ 0'~0'0 5387. '63 N 4212,"74"F' '683.'¢~ 13 HORIZONTAL DISPLACEMENT = 683'F¢. 1:3 FEET AT NORTH 38 DEG. 1 MIN. EAST AT MD = THE CALCULATION PROCEDURES ARE BAS;ED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. AR~z.'o ALASKA ~ I NC:. ................ 2'P.='a ( .=,EC..' 1 TI I N ROgE) .................................. I~,UPAF~Uk .:.F ERRY-o LIN -'WELL.' 'S'UR'VEY I NG r':~nMF'ANY ANCHORAGE ALASKA ......... COPIPCITAT iON" D'AI'E ' ' MARCH 1.':::, 1 '.-.'~85 F'AGE 5 DATE OF SURVFY MARCH 17., 1'.~:::5 ._lOB NUMBER AK-BO-50036 KELLY BUSHING ELEV = lz._ 00 FT OPERA TOR'd !-q A ME C I NTERF'OLATED VALL.IE.S; FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE .:.UB-c..EA TO"FAL MEA:E;I_IRE/I VERT I CAL VERT I C:AL REL. TAN_,I_ILAR COORD I NATES MD-TVB .............. DI='PTH DEF'TH DEPTH NORTH / SOLITH ....... EAL:;T / WE".--;T D I FFERENF:E VERT I C:AL CORREC:T I ON 0 O. O0 -125. O0 O. 00 O. 00 .................................. 1000 .... 789. '~8 86'4'; ..~8 ...... 59.22 "N ........ 55.'/_-,5 E 2000 1805.48 1680.48 480.74 N 424.33 E 3000 2384.67 225'~. 67 1116.38 N '~33.83 E 4'000 2'..~61.06' 2836;06 1767'::'...q--7'-'N ........ 1'426,"95 E 5000 :3.526.71 :3401.71 2424. :--: 1 N 1924.67 E 6000 4073.04 3'.-}48.04 30'78.33 N 2422.42 E ......................... ]'000 ..... 462'7, 54 ..... 4502' 54 375,_.'2 27' 'N .............. 2~31.33 E 8000 5165.54 5040.54 4417.30 N 3454.03 E '..~000 5781.05 5656.05 5041.9.'.-~ N 3931.55 .................. 9660 ...... 6267'.~._'3.7 6142.57 5387.63--'A1 ............-42 I"2"~-"7z[~ 615. .... 1038. 1473. 1726. 2372' 2834. O. 00 10.02 10.02 194.52 184.50 · ~,.-~ .-, -) 4.-.-L. 81 '.~4 423.60 '::"~> 4 :':: 4 ":'.=, ?6 453.67 46 ' 445.50 46 462.00 ,::;, .,=;, .-,,-, . · _ ,:,,=,4 48 43~ 17:3.49 THE CALC:LILATION F'ROREDURE8 ARE BA.SED ON THE U'.E;E OF THREE D IMEN'.E;IONAL RADIUS riF C:LIRVATURE METHOD. ARCh ALA'.:;KA, I NC. ................ 2C=.~. ( ,-'-,-.---", · =,r_,_.-' ! ..... T I 1N 'RO'9~ ) KUPARUK ALA~.KA · :,PERRY-.:,EN WELE-"SURVEYING"COMPANY FAEE 6 ANCHORAGE ALASKA DATE OF '.:;URVEY MAIRCH 17, 19:s:5 .......... COMF'UTAT'I ON ' DA TiE' AK B_ -.~,00.~6 MARCH 1:.~, 1'.'.~85 ,_IDB NUMBER ."- 'n =' ' '~ KELLY BUSHING ELEV. = 125.00 FT. OP~RATOR-d';' '"'.:,AMF't"_. ......, -M-. I~R I SON MEA._,L RED ................ -DEPTH 0 ....................... ~1:25 225 :2:25 I NTERF'OLATED VALUES FOR EVEN 100 FEE'T' FiF SUB-'.=';EA DEF'TH I'RUE SUB-SEA TO TAL -' -' ' -°l ' -' - - ~' VERTICAL VERTICAL REL. 1 ANL~ JLAR C. ULfRr' INATES MD-TVD VE:RTI CAL DEPTH DEPTH NORTH/SOUT'H .............. EAST / WE'E;T D I FFERENCE C:ORREE:T I t-fN (:). 0 CT - 1.."-'._, = . 00 (") .0 (:) 0 .00 1'25'00. 0 ;;00 .,.'~". "-':?,~'" '~..,~ ._ 0 ,'26'' 'W ' · :":'5 00 100 00 :=:. 0C) S 0 61 W .mt..',... ~ , i. ~ ', :=-:25.00 200.00 4.5A S 0.96 W' O. O0 0, O1 ...... 0'~ 0'1 ................ O. 0:3 O. 01 0.04 0.01 .......................... 42~ ..... 425.00 525 525.00 / .-,~ .-,~ :,~._ 6~._. 00 /25 .................. 725 ;' O0 827 825.00 300;00 ...... 5',87-"S ............... 1;47 W .... 0,05 400.00 5.58 S 0.36 W 0.07 500.00 1.88 S :3.54 E 0.22 ........... ~00%"00 ?; ~"~-I~I- ...................... I'I'.';"7"Y ' '~ .......................... 1 '00 700.00 22.05 N 24.11 E 2.:37 ':.~:31 .925.00 800.00 1'037 ........... I 0.'._. O0 .................. ..~00';-00 114.5 11 s' 5.00 1000.00 1257 1225.00 1100.00 .................. 1~I ............. 13~ O0 ...... 1200. O0 1470 14~ 00 1300.00 ~ 5 00 400 1614 1~2 . i .00 I744 ...... 1625.00 -- I500~00 1882 t 725.00, 1600.00 '-"-'5 00 17<30 00 202'~ 1 o~ ..... 43.21 N 41 .23 E ' 6. ~?,'='._, 'F~7.32 N 74.80 E 20.70 1 :E: I. 10 N 1 :E:O. 77 E :]':2.2:3 ..... 17'I'. 'b-.S-- ~ ............. I-6.~ ;-IS-E- ................. 4~; ,"78 ....... - :~ zl'.:~.._4 N 211.27 E 65. :3:2: 275.80 N 257. ,-,._':'P; E 89.28 415.00 N 370.44 E 157.'72 497. :33 N 4:3:=:. 36 E 204.49 0 .' 01 0.02 0. 16 '0'; 77 .......... 1.87 3.67 ~;'78' 8. :E:,.~ 11.53 14155 18.55 23. "= ;! 30. 18 38.4/_-. 4/_-.. 58 ANC~HORAGE ALASKA ARF.'FI ALA.:.KA ? I NC. 2C=..~(SEC21 ...... TI IN RO~E)'"'= 'CO'MPOT~TIiDN DATE I<LIPARLII< MARCH 18 ALASKA 'SPERRY:S~-iI~'-"'W'ELE' SORVEYING C:OMF'AN'~ ........... PAGE 7 DATE OF SURVEY MARCH 17, 1'.-?:::5 JOB NLIMBER -' F =' "~" AK-B J-._,O0o6 KELLY BU.'E;HING ELEV. = 1~.-,,00 FT, OPERATOR:;,I. SAMEL":';-"I'~': ..... DE'R I :-:;ON I NTERF'OLATED VALLIES FOR EVEN 100 FEET OF SLIB-'.:;EA DEF'TH TRLIE SUB-.'_:~EA TOTAL MEASLIRED VERT I (:AL VERT I CAL RECTANGLILAR E:OORD I NATES MD-TVD VERT I E:AL ............... -D~F'TH .............. DEPTH D~'PTH NORTH/SOUTFI' ............. E'A.STTWEST DI FFERENC'E ..... CORRECTI ON ' 2'1 ':.~2 1 '- '-'= ._ ._, N - - .~ ..- ._, 00 1 ::: 00 00 ~':~ 7. '-:: =' = '- :.._, E 2/:,-/. :a -- . . · ,"1,_1 .............................. 2:~. t:: 8 2025; '00 ........... 1":.~ 00';-00 71.0 ,' 'z;'7" '-N ...................... ~:; I '0 ='zF3" E .................... 343"~' 55 7 5, '70 2545 2125. O0 2000. O0 :.-':25.06 N 701.30 E 420.72 77.17 2722 2225. O0 2100. O0 938.52 N 791.90 E 497.02 76. :30 ._.. ....... ._ ...... ' - ' ._ 71...'-7 74-'-'= ................................... · %~.76 ..... .-.:~.~':,5 -' 0A 2200; O0 ........... 10'Z~f.~, '..~z~--N- .................. ~8'I' ;'0'7' ' i= ?, '-,' . ...._, :2:070 2425. O0 2:2:00. O0 11 ~ I. 36 N 969. :2::2: E /:.45.07 73. :--:24:2: 2525. O0 2400. O0 1273.14 N 1056.50 E 71 :=:. 55 7:3. 5'4A"~ .............. ..- 6-'2._' -.~,. ........................ O0 .......... 2500-;'00 1 ~,~.~-;"-~- .... o~,~-~-: .......................... N I IZl:~. 8...-° ..................... 'E 794, .>z; 75 35:~4 '"' ""~ '=C"-' · - 7z.... O0 2600, O0 1 .., .,~. 11 N 1230 ,'::'=' . ,= ,:, E :369.0:3 74. 3767 2825. O0 2700. O0 1615.61 N 1315.2'2 E :742.22 73. ................ ---~._-~G.: ............ er'~= ........ ~.~ · .- ....- ._,. O0 .... ..'._ O0, O0 '1728-.'.0T-N-- ..... -I3..~7 ;'9~._.''-E I 013:"91 ........... 7'I. ....... ~' '-"-' 34 /:.8. 4107 :::02.=; 00 2900 O0 1837.72 N 1477 50 E 1 .~.:..--. 4276 '-' '-'5. . ?]=-' . 69. · :,1..'._ O0 :3000 O0 194:::.99 N 1 .... ,/.1::: E 1151 8:2: "4454 "3'ZZS,'O0" ._ I00. O0 2'0/:;7. IZl· q'~ IS~zIT. ~._, E 1..-.-'9.4_, ' .......... 77:'63- 7.:,,-, · 7 :_"3 E 1 '-' ')':' · _-,t o. 20 7:-3 75 463:3 '-"-"-'~ 21 · :,.:,..'... O0 3200. O0 83.63 N I "'= - 4813 '-, '-'.~ ""-~'0 · :,4-.'~-. 00 :=::~00 O0 1388 71 80 5 · ---o_1.72 N 1~28.72 E . . · 47...~t:.' .......... 3525'.-00 ...... 3400; 0'0 2'422'=-7'2--N------I'92~.-OT_-:-'E-- .............. 147I"'~ :B/:.' ........... :=:3 ."'1S" 5180 .~o.-"-" '-'.=; ...... 00, :'q500. O0 .-'._ 44'-'.~ .64 N 2016.70 E 1.=;=is. ';'5 83. '::'-?._. .--. .-, ,~ -- - - . · 5:36:=: .:,7.-'._. O0 .36C)0.0C) 26/:,7.5:=: N ',-'10'..-?. 4'2 E 1638. :::9 :=:::-: 64 .................................................... .................................... 48 7'.-5' .......................... 69 69 4:_:: 4::: ARCO ALASKA, INC. 2C=?. (SEC21 'TI I'N '"RO..~E) ALA:SKA ........ SPERRY-SUN'WELU-'SURVEYING'COMPANY .................................................. PAGE 8 ANCHORAGE ALASKA COMPUTATION'DATE ........ MARCH 18. 1985 DATE OF SURVEY MARCH 17, 1985' dOB NUMBER AK-BO-50036 KELLY BUSHING ELEV. = 125.00 FT. OPERA'TOR=J'~ SAME~'-M';--tnERISON INTERPOLATED VALUES FOR EVEN 100 FEE]' OF SLIB-SEA DEPTH ]'RUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL. ............... DEPTH DEPTH DEPTH NORYH/SOUTH EAST/WEST'DIFFERENCE 'CORRECTION · J._,47._,,_.-._':'°':'5.00 3700.00 .................................... 573't .......... 3925-00 3800;00 5913 4025.00 3900.00 60~3 4125.00 4000.00 - .............................. 6276 ..... 422~.00 .... 4'100,00 6460 4325.00 4200.00 6639 4425.00 4300.00 ~8I'~ ....... 4~25,'00 .............. 4'400;'0'0 .... 6995 4625.00 4500.00 7177 4725.00 4600.00 73._.6~ ........... 4'8~._,';00 ....... 4700;'00 7551 4925.00 4800.00 7742 ._~e'-'=., ~ ._,. 00 4900. c~0. .... 7~27 .............. 5'I~'. 00 ............~O(~r, O0 8105 5225.00 5100.00 8279 5325.00 5200.00 ,_S~ ...........5425',"00 ...... 5300":00 8612 ~525.0(~, 5400.00 8768 5625.00 5500.00 2791.12 N 2201.16 E 2.~ 16';'22 "N ........ 22$~ 1', 26-' 'E ..... 3040.19 N 2:379.87 E :3161.4:'-: N 2468.60 E .... 3284;"28""N ........ 2558',70 E" :3408. 'P3 N 2649.72 E 3527.27 N 2741.02 E 3753.33 N 2928.88 E 2370. 3871.16 N 3025.78 E , 2452. ................ 3..~9. 'I', '._~'-'N- ........... 3~24";' I'I'""E ............. :' 2537; 4116.73 N 3224.64 E 2626. 48 34 48 24 1722.38 83. 1806,07 83; 1888.41 82. 1968.89 80. 2051.12 82. 21':'~ A4 8:3 ._1._ · . . 2214.87 79.84 '17 ............. 7~"29 .... 41 79.24 82 82.42 68 ...... 84.86 80 89.13 4245.01 N 3324.06 E 2717.45 90.64 43'6._~r,. ~-~-~-'lq--- .... o-3z~: ._~72-~ ............. 2802 .' 02 ................... 84-. '58 ................ 4486.86 N :3506.66 E 2:3:--:0.57 78.54 4600.38 N ~_.'~592. c~-° E..._. ~.~_'~. ~-=,~ .75 74 .18 '4707. ;-7~I--N .........~3'~._,.'33-1S ............ 3024,' 27 ...... 67'. 52 4812.7:3 N 13752.02 E :_--:087.05 62.79 4908:30 N '::'-"-'= ._,c, . ._ o..-._,. 44 E :3143.66 =' . 61 ARCO ALASKA, INC. ............. 2C=9"(SEC21 TI 1N ROgE) ............................. I<UPARUK ALASKA SPERRY-"S1JN-'gIELE."'"!::;URVEYI NG F:'OMF'ANY .......... ANCHORAGE ALASI<A L. OMP JTAT ION' DATE MARCH 18 F'AGE DATE:. OF '.::;URVEY MARCH 17, 1''' '-' '=;¢,=, ._, dOB NUMBER AI<-BO-50036 KELLY BLISHING ELEV. = 1'':'='.,:.._,. 00 FT. OPERATOR',,I ' :'-":AMEC;"-PI'~--]EdER I S'ON INTERPOLATED VALLIES FOR EVEN 10(] FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VER]' ' ' I' r"_.AL ..................... ~ -~ ' ' .1~'~_~. - KI~FTH DF'PTH 'DEPTH NORTH/SOUTH ...... E~A.:.T ?WE.:,T D IFFERENr:E .... RORREE:T I ON 8'.-.? 18 5725. O0 5600. O0 4996. '71 N 3894.26 E 319:::. 85 7.~0~2 .............. 5Er.7.'5 ;'00 ............ ~;700:"00 5075';"...q-xc/-N 3'..~60'~'32"'E 3237, 57 S.~201 5'~25. O0 5800. O0 514'Ft. 65 N 4022.6:3 E :_'-:276.56 :.~337 6025. O0 5900. O0 5221.52 N 4081.36 E :3312. '.~8 ':~71 ............... 6125,'00 ........ 600'0";"00 .5270', 72-'-~ ...........4'1"36,48 "E .... 3346.50 '.~60:'-': 6225.00 6100. O0 5358.70 N 418'.-?. ':~7 E :_--:378.72 '.~660 6267.57 6142.57 5387.63 N 4212.74 E 3392.43 50. :20 '43','72 ......................... 38.98 36.42 '33,'52 :32.22 1:3.71 THE CALCULATION PROCEDURES LI.SE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF L. L RVATURE) icl I NT._~ ...............................................................· :,F"-''ERRY.-.:I1]N' ' ....'~' ................ NEE[ .:,~I. IRVEY' I N~-r~ ....................................... COMF'ANY F'AGE 10 ANCHORAGE ALASKA ARCO ALASKA, INC. ~C=9~(SEC2i Ti1N.ROgE) KUPARUK ALASKA DATE OF SURVEY MARCH 17, 1985 .......................... COMF'UTA'TI ON 'DATE ........................................................................... MARCH. 1,:,, 1':?:::?] ...lOB NUMBER AK-B_~-._,OO._-~6 KELLY BUSHING ELEV, = 125.00. FT. OPERATOR~;£I;, .... SAMECT-TT; .... ~RISON INTERF'OLATED VALLIES FOR .:,FEL. IAL S;LIRVEY F'OINI'S ] R JE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL REC:TANGULAR COORD I NATES; ................. DEPTH DEPTH DEPTH ...... NORTH/._cYL"'ItPrH EA.:,T~"/WE.:,T~ 'MARKI~R =q . = . . :3'i.~8'.~ 70 E UPPER SAND 9127 ...,,~71 14 ..,746 14 5110 03 N . TOF' ............................. ~,?' ! 2 =~'~"~ ~-" ....... ~ ~"'"~ ................... · - ~'...-~. -.,~ .......5807;'5~ ..... .. 1 .. c, · ~I N 40~7. ~.z. E BASE~' LIF'PER SAND ~.=,c, 7 60:39.09 5914.09 ~'~'~ .... =,1.4..., N 4089.40 E TOP LOWER SAND 94/-. 1 6117 06 ~992 06 ~]'="-'~ ....' '-'~ ' ~ ~ c, ~,. ¢: z N 41 '~'; .....' ........... ~.=. E ;=..IRVEY DEPTH .......... ~9524 6164-,'7I ............. 6039, 7I ._,._ 17 71-"~ ........... 4157';~72 E BASE LOWER c. AND '~ ~ 29 61 q 4 '~ 49 ~] '-"-' ' ~ .... 604:3 ~'- ...=,zu ';'9 N 41 74 E F'LUGBACK TD 9660 6267.._7 6142 57 ~,o,:,7 63 N 4212.'74 E TOTAL DEPTH DRILLER ARCO ALASKA, INR. 2C-'.~? ( .SEC21 T 11N Rr~'.:.~E ) "'~';=TRA; ..... F I I:] R~F' '" '"Fi I -'~"l .... '"1:, JMMARY"~ DERIVED U~:;ING DIL DEPTHS AND SPERRY SUN SURVEY DATA ..,. COORD INA T E'.--; MARKER ....... MEASURED DEPTH TVD THI~ ...... ""'-' . _.I-...NE.:,..:, W I TH REF TO WELLHEAD BKB BKB SUB-SEA VERT I CAL ( OR I O I N- 1115FNL 78FEL ) SEC.."" 1 "i ..... ?~i-"~'F~ ....... RCx-}E.. TOP UPPER SAND 9127 5871.14 5746.14 5110. O:'-:N 398'.:.). '7¢.. ) ................... ERASE '"UPPER--' SAND .... .92 I~ ............................................ 59'3'2',"57 ............ 5"_--:0'7 ~'57 51"55, 2i N 4027.2:3E TOP LOWER SAND 9357 60:_'-:'.~. 09 5914.09 52:2:1.45N 40:--:'.-.'~. 40E BASE LOWER SAND 9524 6164.71 6039.71 5317.71N 4157.72E ........................ ~lz'LtGBACK' TD .9~?. 6'I"~.B,'-4'¥] ............ 6043.4S)' ~]L'-i20]' 2'~.~N' ........... 4159'~ 74E TOTAL DEPTH DRILLER .9660 6267.57 6142.57 5._'-::37.6:'::N 4212.74E 1) FROM LINEA,R EXTRAPOLATION BELOW DEEPEST STATION. 2) C:OMPUTER PR~]GRAM"'- SPERRY SUN THREE DIMENSIONAL RADILI:S OF CURVATURE. ..... DATA-' CAT_CUE-AT ION" AND'"'I NTERPO L-AT ION" BY-" RAD'lrF. IS'~'OF'--CORV~TI_IRE ................................ ................................................... DATE-OF'-SEIRT~Ey ' MARCH' "17, 1985 ' " COMPUTATION DATE MARCH 18, 1985 JOB NUMBER AK-BO-500:36 KELL-Y-B[X. SHI NG EL'EV. = 125.00 FT. i'~ T RuF NI~RTH SCRLE :- i !NCH TO i500.00 / ~500.0 KUPRSUR qqco qL95KR, iNC. 2C-9[5EC2~ TiIN R08El HqSCH i'7. ~985 qK-8O-500~8 -4500.00 -3000.00 ~/ -,soo. /o. oo ./ ' 150~.00 9660 --1500. O0 HOR!ZONTflL 0.00 1500.00 4500,00 6000.00 5CRLE ;- i INCH TO i500.00 / i500.0 KUPRRUK qRoo qLq3KR. 2C-9[3EC2i TilN RogE) HRPCH ;7. qK-80-50036 YERTtCFIL :~EC?IQN 15 6839. 13 ¢ILONG I:IZ. 0.:90 ~ -9660 7500.00 I i500. O0 30bO. O0 4500. O0 6000. O0 7560.00 VER-.,_TCflL PB,3JECTfON Suggested form to be inserted in each "Active" Well folder to check for timely compliance with our regulations. OPE TOR, WELL bl~-Al~lE AND NUMBER Reports and Materials to be received by: ~-- /._~ "~, ~ Required Date Received Remarks Completion Report Samples Core Chips Core Description Registered Survey Plat ~_~ Inclination Survey Drill Stem Test Reports ~--- ~ ~... ~-p - Digit i'~'~d Dat a Y ARCO Alaska, Inc.~.. · Post Offic/ ~ 100360 _ Anchorage, Alaska 99510-0360 - - Telephone 907 276 1215 ;:;:I-': TURN TO' 'f',.'":' A NSH 1 I"T E D RECEIPT AND !;'E:qUENCE OF DATE' AF:RIL t9, TRANSMITTAl_ NO' ARCO ALA,'.'.:."I<A, INC, ATTN- RECORDS CLERI< A'FO-i i i F'.O,. BOX t ANCHORAGE, AK 99": .,, t ,3, I-IEREWITI-I ARE.TI-IF FOLI_.r~WING ITEMS. 'PLEASr: RE'TURN ONE ~IGNED COPY OF T!-IZ£ TRAN~H.T. TTAI_, EVFNTS · · FLLIID ID F'LIHF' GELLED WATER F'BU ' FLUID ID STATIC BHP F'BU G/I.. SURVEY FLOWING 'BI.-1F' BATCH FRAC 4/2/85 4/i4/85 4/6-]*'/85 416/85 4/6/85 4/J-5/85 4/5/85 4/2/85 9,.'::',5 i 4'7 - . F:' A [.; I:"' 2 OF 2 A r...'. K N 0 W I... E D G E ;..'ECE l PT ACKNOWLEDGED- "-', F'A E i-: CURR .[ ,ir'. '"HEVRON & M pi,. ,.,- ._.~.TR.zBUTION ' DRILLINL, W., F'ASHER ~ ~nux~'TON EXXON ~__ & ...~1 :...*. 11 ~ ~.....' HOBv~-.- F'H II_L.T. PS . OIL . 1; NSK CLEF-:,, J. RATFIHELL RECEIVED APR 2 5 .7985 AlAska Oil & ~as Cons. Commission .a. - I) ~ l' E Anchora¢o {,F 1 A I_'E Or.: A :.A ,S'OH 1'0 U i'-410 i'.4 K 'I'L4L I · ' T · 1.l/VAUI.. ARCO Alaska, Inc. is a Subsidiary of AtlanticR. ichfieldCompany , ARCO Alaska, inc~.---x Post OffiC' x 100360 Anchorage=, Alaska 99510-0360 Telephone 907 276 1215 '!E'I" J 17 N T O · E ~;!~JENC.'E Of=' A F:,' E: O A I_~ A,i.-.'I-( A, A--',"f'N' RECORD,.? C. LEF.:!( ~':'-", ']" C) .-- i i I .5-- r-..' F'., 0 ,. f.) 0 X -I ,.'} (:." 3,5 ;.;'.' A N (': .......... 1--I fi I--,' A .C.,. IF, A l( '-':':.-..;. _-. 1 ¢'"' ':"- ,.Il=r: r.'~ , ...... ,~,...,..,. -f'H ARE THE"' F.: I'.:: 'f' L.I F..' N 0 i'"-.! E I) A T E: ' fi l::' !:,'. ]; L. i '?, TRAi'-!£H I'¥"f'AI... NO · .FI...U Z D ii) F'LIHF'-G E L I... r..:'D F' !-.", L! FLUID ID 2'TAT]:C BI-.IF' F'BU ;~ ,;' L £URVEY. · -. r.,~ F' FLOI,4 Z NG -";,"1 WATER I"-,'i.~TCI-I FF,'AC z~t//''''~ C) '"' 4/6-7/85 ~. / A Ir',,-- :. ~..~ .,=..~,.2 .¢.. / A / o , .....t.., 4/'3-~/8-~ 4 /5: / 0r: 4 /";/8'~ %' / ~. . ,:T~::,"r, , ACi(!-.j. ObJi_EDGEr~. '"' U F: F.: ]; E F,' '; F' ri i"~ n-r., .... .~ L..~...,. NG !J , F'A,)"'r-! E.R'" ~-- -' %.''.-"? t11.'- . L-~ ,. ..~,.~-. ~,~... Hr;t:"rL F'I-!]:!..I IP~ nil I . '.: &.- .l ....... N.S:K CLEF:K ,J, F:ATI-IHFI..L ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldOompany !) A ]" E: · ARCO Alask.a; Inc . . Post Olfice Box 100360 Anchorage, Alaska 99510-0360 Te!eph'one 907 276 1215 r, ARCO AI_r~2KA, INC., -'ATTN'" RECOI:i:D,S' CLERI< ¢lT(]-i t' t DB F:'.O~ BOX t00~6(-) 6NL]I.-IORACE, t..~K 995 H[::R I]: H ]: :1-.I ¢.~ R E 1'1-.i E: 1::' [)1... I_ E) 1.4 ]: N [; RIETUi.',:N ONE SICNE:!) COF'Y 01'--'rl-.l:[,t,' ..! CPL '~': : -'i f~"- 7.. 02; ..... J. 0""F35; .... i:;:UH '"".,,-, . ..;-'::'"'.'> t 6-'7977 -"i.O,:'g~.:. n':; .... t" '~'::' F<LIN :Il: t '"""'~70-"7~,i0 ~:..~:~;:_-:~ :::- ..... . ,..,, .... ,:,..: . ..,.,.., , ,~. (~ :'_~ -.- t,.,'"- .... ,.:": ..;':"' F;: t.I N -,,-'"' i 7 ? 5:0 -- ? 4 9 ~l 2C i0 05 .... I" '"':" ,:.:, "' c, ..,' ........ I::: t. I i'd "" t ,'5 0 0 (';' "" 8 t 8 t , . '."11' ""1 I'"' ... 5 "''') ' "'" "y:' ¢',("~ I::' . . . ',:,' ,:: '"' t," 5';' '"' ,:., ..,, '- I:;: L.I i"-~ -I,':- t ~ ,..)"' c:":' '..:,"'" .~":" '-' (.,'~ ',',"" 7 i ~...-.. *.,..- ~ 2 {..J '"' '" ":"' ~'"' '''q © -" c:, ,..- · '. : ........ .' "", ', ,", -.' ....... ,.., ,:: ..; ' F< t..IN-,,- .... t b-',9 t.,' v" <::,; (::, c, ~ 2 !,J--- 3 0 E, -.- 0 {!? "'- {ii 15 R U N -II: i ,5 7 0 0 --- [} t 6 '? , · :,,~',,.-r-.:-.' ''x~1 ,. ' .'_T(:l-iL. Ur--ll:.,.:.r,,t.,gF;: 'F'].r,~i-:,,_ F'F;:TN'f'S CON[:' ')':' OF' E;B' ' 3' .,. I'"¢ U H.. ~",: t . ..75,6.5; ~? .... '7 6 2 4 'F:UN-,,.'"' t ~ '" " ' · .; i(::, 0-- ;-'906 K:' · I') I::' C:' F;: t.J N ',,""' t <5 0 .,' 0 "" ,.....-' ..; 0 ir': U N "" " · ,,-1 7'-' o 00 "- 90 .,-: d .. , ,:., o ',?'-' l:;:! Ii'4 · .~: .t '~'"~ '"" ":' ' RUN ":,": t /,',';-',On ...., ~'/ .... .RUN -~:1 ,5'5'00 .... · . o 'l' 1:;: ¢, H $ H ]: '¥ 'f ¢~ l... , . · -. I-:: l::: (."- '" .T. F"!' ,,'\ C I"; i': (? -'2 l... ::: l'::' (:; F:: D ': ' ' ' " ' ~'" :1: .? "[' l:;: 'r ~'.'., j ,':' 'r "'l "' · ' ...... .,~,. .I..L,' :.1 I ,I. ',., i '~ · · ~; ,r'. ;~;, [..:' ........x-i::, F:.: I ,._ L. ][N r:-~ ':.'t --...F' !... ~. H ~ ,.r,, :-,, r-,".,., ,..~ -.. -. · . }]: C' '"""" "' ~-"F' ' i r~t,,".lq' r; "':;', ..... , .. ,... ~'.-. r~ ........... .I .~,-,,, ,., T,., N' [....':~ ,', t., ~'~ r'~.~r"::r:..fl;.', ~,..... ,,.,.. ,:~ h:)b.I. 1..':" "" I:"H Z~ ~ ]] i:',? (IT' ._, i,..i ..... '11: t 4 ,.'~ ;~ & il ">"<"' '" '"" ', ,.1:'--~:[ ) ,- ~',.(.-~ i'il:'~L.l... .... . .............., b L:::.""t:.~' .... ..' ..... ' ^.:,=:"" .......... ',~,-.,.m...I r',.. T I"l ARCO Alaska, Inc.~',. Post Office B . J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the March monthly reports for the following wells' 1Q-3 2U-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/LI06 Enclosures RECEIVED , PR 6 985 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanlicRIchfleldCompany ~"-. STATE OF ALASKA '~"-, ~4/ ALASKA C._ AND GAS CONSERVATION CO~,. _,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION · Drilling well)~][ -R-~-i ~-~ ~ ~ ~ .... 8~221 8. A~I ~umber ~51 0 50- 020-21 237 2: Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, ^nchorage, AK 9. Unit or Lease Name 4. Location of Well atsurface 1115' FNL, 78' FEL, Sec.21, T11N, ReE, UM 6. Lease Designation and Serial No. ADL 25654 ^LK For the Month of. Narch ,19 85 5. Elevation in feet (indicate KB, DF, etc.) 125,7' RKB Kuparuk River Unit 10. Well No. 2C-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0030 hrs, 03/04/85· Drld 12-1/4" hole to 4200'. Ran, cmtd, and 9-5/8" csg. Drld 8-1/2" hole to 9660'TD (03/13/85). Ran logs. Ran & cmtd 7" csg. = 9529'. Secured well & RR @ 2400 hrs, 03/14/85. tstd PBTD 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 101' Cmtd w/250 sx CS II 9-5/8", 36.0#/ft, J-55, BTC csg w/FS ~ 4162'. Cmtd w/lO00 sx AS Ill 7" 26 O#/ft, J-55, BTC csg w/FS ~ 9620' Cmtd w/430 sx Class "G" & 600 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/GR/SP f/9589' - 4162' FDC/CNL f/9589' - 8950' 7700' - 7300' 5400'-4800' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Reporto~this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ..... ~,,~,~ ,. Submit in duplicate "'-'-'-- STATE OF ALASKA ALASKA L,._ AND GAS CONSERVATION CO.,,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc, 84-221 8. APl Number 99510 50-- 029-21237 3. Address P, 0, Box 100360, Anchorage, Al< 4. Location of Well at surface 1115' FNL, 78' FEL, Sec.21, T11N, R9E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 125.7' RKB I6. LeaseDesignationandSerialNo. ADL 25654 ALK 2580 ,9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2C-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of Ma rch ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0030 hfs, 03/04/85, Drld 12-1/4" hole to 4200", Ran, cmtd, and 9-5/8" csg. Drld 8-1/2" hole to 9636'TD (03/10/85). Ran logs. Ran & cmtd 7" csg. = 9529'. Secured well & RR @ 2400 hrs, 03/14/85. tstd PBTD 13. Casing or liner rgn and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 101' Cmtd w/250 sx ES II 9-5/8", 36.0#/ft, J-SS, BTC csg w/FS ~ 4162' . Cmtd w/lO00 sx AS III 7" 26 O#/ft, J-55, BTC csg w/FS ~ 9620' Cmtd w/430 sx Class "G" & 600 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/GR/SP f/9589' - 4162' FDC/CNL f/9589' - 8950' 7700' - 7300' 5400'-4800' RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data N/A Alaska 0il & Gr~s COns. Commission AnChorage 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repo~ 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 TEMP/MR1 ~, Submit in duplicate ARCO Alaska, Incx- Post Office. .,.x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 F.:::TUF:.'-: T.q- ,:'-'R~n P, Lt.;2.1,..'.fi: ~!'-~C ~;T'T?-~ ' --r,' ~ :' :'-i ~" !:, :7 r'.! .~:' :;'::: _ ' r:, ?'i ! ~-.' :-i ~' ............ i 0 c:., ¥ 6 C.~ - -~- :~; '~ t : '--' ~~- '- /TM >.:.~ /--~r- ~ ~ 'l" '--: ~"-: : :, ~ W. o "r ~...: "- l",t-:L'l' -. F~."' I U:-.,r,:01-,.:::~ ~ ~..:-r,:Izt .... Y: December 4, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2C-9 ARCO Alaska, inc. Permit No. 84-221 Sur. Loc. 1115' F1CL, 78' FEL, Sec. 21, TllN, R9E, Btmhoie Loc. 1027' FNL, 1087' FEL, Sec. 15, TllN, R9E, U~-l. Dear }{r. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying 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 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of ar~y waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing o.perations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Jeffrey B. Kewim Kuparuk River Unit 2C-9 -2- December 4, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. in the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Harry W. Kugler Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COP~ISSION iC Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Doug L. Lowery ARCO Alaska, Inc ..... Post Office ,~ .100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 7, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 2C-9 Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Kuparuk 2C-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore We es any q A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment.~.~ timate spudding this well on February 9, 1985. If you have uestions, please call me at 263-4970. .S~~~rely, Area Dril ling Engineer JBK/JG/tw GRU2/L77 Attachments Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION CUMMISSlON PERMIT TO DRILL 2O AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS ~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. BOX 100360· Anchorage, Alaska 99510 SERVICE [] STRATIGRAPHIC b_~ SINGLE ZONE J~[ MULTIPLE ZONE [] P,,ECEiVkD 4. Location of well at surface 1115' FNL, 78' FEL, Sec.21, T11N, RgE, UH At top of proposed producing interval 1484' FNL, 1451' FEL, Sec.15, TllN, R9E, UM At total depth 1027' FNL· 1087' FEL, $ec.15, T11N, RgE· UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 125.7' PAD 88.7' ADL 25654 ALK 2580 · 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Uni~e_a_se,n~rrm ~ · Ka ~41["& Gas.Cons Commission KuparUK I~lver unll; ' Anchorag~ 10. Well number 2C-9 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth(MD & TVD) 9681' MD, 6240' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 14. Distance to nearest property or lease line miles 1027 feet 17. Number of acres i~ lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 55 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 2C-10well 58' ~ surface feet 18. Approximate spud date 02/09/85 2747 psig@ 80°F Surface 3154 _psig@ 6126 ft. TD (TVD) Hole 12-1/4" 8-1/2" SIZE Casing Weight Grade 16" 62.5# H-40 9-5/8" 36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER Coupling We l dI SETTING DEPTH Length 80' 36' I 36' 4043' 35' I 35' I MD TOP TVD I I 34' 34' ~ 9647' MD BOTTOM TVD 116' I 116' 4078' 13056' I 9681' I 6240' I QUANTITY OF CEMENT (include stage data) + 200 cf 900 sx Arcticset III & 600 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Fi eld development well to approximately 9681'MD (6240' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA ROPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2747 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2C-9 will be 58' away from 2C-10 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) 23. I herebv certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Drilling Engineer The space (~'l~ov~r ~'o/~issio, us[~ .... ~ Samples required I--lYES ~NO Permit number Mud Icg required ~YES .~O Approval date DATE CONDITIONS OF APPROVAL Directional Survey required I APl number [~.YES E]NO I 50- 0L~'- %/~37 //04//84 SEE COVER LETTER FOR OTHER REQUIREMENTS 2 APPROVED BY Form 10-401 GRU2/PD27 / ,COMMISSIONER by order of the Commission DATE December 4, 1984 Submit in triplicate Permit to Drill 2C-9 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED Nov I 91984 Alaska --,2? ....... ! _ _: .... ~ ..... 1 ........ i ......... .1 ...... ~. ..... .... ' - TOP' UON~ 'SNDS ' 'TVD~I 986 2203 ~EP=~IO ................ ' ............ f ...... ~ ........t ........i .... , .... : ..... ~ ' ;- '- .... ZLf]~TZZ;[ ..... -K-1'2 - -T~D-2856--TH~3726 DEP-~ 960 ~ - - - ~ · ' ' ......... , · ' ~ .... t : ' ' t ~ I , : : , ~ ..... ; .... . ...................; ....... i ''-f .... 1 . . i.. -: ..............55' DEG-'22'-HT N *': ......... s, .......... ,- ~ ~ K 5 TVD 4756 TMD=7070 ,D~ 4712 ,- - ~nnnJ ---~ ~- :'~- [ TOP ~i suR L~Nn~ [ 'T_vn~:_ m~n~.$O~E~456_ , - HOR',-'--7:ONTAL FROJECT] lin i <UPARUK-FII[LD.--I SLOPE:..ALASKA - i i ' ' ..... 50O . . ..... i : ........ · ~ ........... i.:_:; ;~ i , , 1~$1' ...... t .... i 1 ??8 ..... ..... ~ ....... ~ ......... ~ ...... ..... ; ..... ~ ..... ; ..... .... ,, - . ~ ' ...... ~ ............ ~ .-t .... ...... , .... [ ...... ..... ~ I~C.. :'" : : -T-T-T'Y'~ ..... :-JTPAD 20L}WLL. NO,'g~lO-11-12: PROPOSED ~~.~-- ... _ ___. ..... ~ ;iX_2 '' NO~E*-'~ELL'PATHS~EXTEND BETOND '' 6oo I . · . i i i lankco ~u~ck connect ~s~). b~ll velves~ hyor~ulicaliy ectuateO~ ./lO" lines - , o~ure ~f annular preventer. 2000 psi enn~i~r preyed:er. bell nipple. 7 Alaska 0il & Gas Cons. Anchorage PIPE , 7. !Z-5/E' - SO00 ~i pipz r~ ] t SL!k~ ~ ~ SPOOL F ~ P !PE ~- 'C"' ......... CaPKC.m' ,"r ~.. ~':~F. ~D9 PE~ UPST~,EAe DF 7AL','[ AK~ ~E~C. ;5' lO. )~CE~E P~E!SU~E TO !0OD ~5' AND HOLD FO~ i!. O~E~ BO~, 'S~ OF PIPE ~. ~A~K OFF ~UNN]NG JOINT AKD PULL O~ DF HOLE r, n~: :~ ~NC; ~k~ PSi. 12. DPE.~ ~L]ND ~J ~D ~ECDYE~, 7[~7 PLU2. ~KE SL;~E ~NiFDLD AND L)NSS ARE FULL OF ~C7:[ ~'~ir~ ALL '" rt Alask~ ~s. Commission, ARCO Alaska, IrK'-''~'~''' Post Offic~ Jo^ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mrs. Elaine Johnson State of A1 aska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 2C Pad Wel 1 s 9-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU2/L92 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~--~, I$~.~ I§ ~-~ 2 !~t~ 22 W~L 9 Y = 5,958,330.583 LAT. 70017'50.3495" X = 519~109.2~ LON~. 149050' 42. 924" PAD EL~. 88.3 O.G. EL~. 84.0 FNL 1115 FEL 78. SEC. ~ I0 Y = 5,958,272.562 LAT. 70° 17' 49.7786" X = 519,124.643 LONG. 149°50'.42.~80" PAD ELEV. 88.1 O.G. ELEV. 84. I FNL 1175 FEL 65 SEC. 21 ~E~ II y = 5,958,ZI4.485 LAT. 70017'49.2069'' X = 519~140.045 LONG. 149050'42. 035" PAD ELEV. 88.0 0.G. [LEV. 84.1 FNL 1231, FEL ~ SEC. 21 ~ WELL 12 Y= 5,958,156.537 LA~ 70017'48.63~" · ~ , X= 519,155.470 LONG. 149°50'41. 590" ~ , 70°17',47.7357 FNL 1289. FEL ~Z. SEC. 89 ~ WELL 13 Y =5 958,064.0~ LAT. " ~ X = 518, 807.527 LONG. 149°~ 51. 740" P~ ELEV. 87.9 O.G. ELEV. 84.0 ~ t5e ~ ~e~ ' FNL 1381. EEL 381 SEC. 21 ~ ~ELL ~4 Y = 5, 958 , ~ 22.046 LAT. 70°17'48.306~" X : 518,792.,27 LONG. 149°50'5[185' ~D ELEV. 88.3 0.~. ELEV. 84.0 FNL 1~23 FEL 396 SEC. 21 ~LL 15 Y : 5,958,180J~ ~T. 700 F'48. 8780'' X = 518,776.~2 LONG. 149050'52. 631" PAD EL~. 88.4 0.6. ELEV. 84.0 FNL 1265. FEL 411. ~ELL 16 Y : 5,958,238.038 LAT. 7~ 17'49.~4~" X : 518,761.261 L~G. 149°50'53..._, " PAD ELEV. 88.1 O.G. ELE~ 840 ~L 1207 FEL 426. SEC. 21 TOWNSHIP i I N , RANGE 9 E., UMIAT MER. ', ..... ~. M~c~,,~ S. ZC MIDDLE ~ 2C SOUTH PER LHD 8 ASSOC. ~ .... I LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF . 14 ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE ~ UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS' U ~ ARE CORRECT AS OF NOVEMBER 5 1984. ;/c~ ~~ ;m ~ CONDUCTOR AS- BUl LT LOCATIONS Date' NOV. 5 1984 Sca~e: t"= 400' Dra~n By: MC D~g. ~. ~SKg,~d3 .mCK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee / (2) Loc {2 thru 8) Aam n / 9. (9 thru 12) 10. (10 and 12) 12. { 4 ) C a s ~; //zf-ff 7/-/~ - ~' ~/ (13 thru 21) (5) BOPE (22 thru 26) YES NO 1. Is the permit fee attached .......................................... · 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line ....... 4. Is well located proper distance from other wells .. ~ ~,~.~ 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated and is wellbore plat included ................,,, 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait ........................... 13. 14. 15. 16. 17. 18. 19. 20.' 21. 22. 23. 24. 25. 26. (6) Add: //17'// /1-i~-~'9 27. REMARKS Does operator have a bond in force I~eeeeeeleeeeeeeeeee~eeeeeeeeeee~e ,., £. I~ a conservation order needed ...................................... I~ administrative approval needed ................................... Is the lease number appropriate ..................................... 'v Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. :~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~v~/ Are necessary diagrams of diverter and BOP equipment attached ....... ffZ~ Does BOPE have sufficient pressure rating - Test to ~f~z~ psig .. ~zT~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. ,,, Is the presence of H2S gas probable ........................... ~ ...... __ Additional requirements ............................................. .... ~zf~ Additional Remarks: ~o mm rev: 10/29/84 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF 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. LZS T~P~ V.ER.iFICAT,iGN LiS'TZN:Z~ = VE~IF~ ATiGN ~I$'TiNa PA,:~ ~x R:=ZE,_ HEADER SE~'¥:'C=' NA~4E :,iOlT gATE :~5/03/Z4 ~RZGZN : RCEL~ N,~M~ ' CONTZNJATi3N .~ PREVZG~S REEL &OANENTS : SERVICL NA,~IE : V,ERSZgN m : OAT2 : MAXIMUM LENG'TH ' FI LE TYPE : i 02+ ¢~ iNFORMATION Ri~C3R~S ~ ;MNEM CON'T;EN TS CN : .ARCO ALASKA NN : .ZC -9 PN : KUPA2UK :RANG: 9E ~=~T. i CO~N' N. SL'gPE STAT: AL~S~ ~ 'T :~ 'Y ~ u S :~ £NC UNIT J N I T TYPE 000 000 000 OOO TYPE 000 ,CATE 000 00:0 000 OOO 000 000 CATE 00 O S I Z E 0 i 5 0 ,O 4 Og7 0 ,'3 3 002 007 O03 SIZE 0 6.5 0:6 5 065 L~? Ji~ H,02 V~.,RI$1C4T!"N LISTT<~G ,R~g~ ALASKA DIVISION CDM'PUTING C,ENTER TAPE D~NSITY : 800 8Pi JO'5 ~" '* .- 7019~ SASE L~Gr.~ DiL , RUN ;~ 1 ~DATE L2G~E!3 :12 M4R 65 BOTTOM LDG INTER¥.~ = 953,~ FT. TOP uC'3 INTERVAL = ~162 F'T. CASING-LSGGER : g.6Z~ .iN. @ ~.I6Z FT. 5IT SiZE :: o.~OO IN. TYP~ HOLE FLUID = LJ~ SOLIDS ~.V? 010.HOZ VERIF.ZC~TIGN LISTING ~2,S~ 3 6~, F 64 F 1,29 F ,ENTRY ~L3CKS TYP~ SILE .Z i 8 4, 9 4 1 DA YUM SPE MN ,~2 M S!£RV ID CIFIC.~'TION IS~ S,ERvI2E ORDER m :5L~C~S UNIT AP1 AP1 LOG TYP~ FT OD $HMM OO 3MMM O0 120 ~¥ O0 JA~i O0 310 ~A'?Z SO 3.10 IN O0 280 G/C3 DO 3/C,3 O0 355 OD O0 3~PS O0 33O %~S O0 330 CDD~ 6.~ '73 ENTRY 0 I .lin 1 0 R~PR PR2C£SS COD~ (OCTAL) 6,B 68 00000000000000 68 00000000000002 6~ O00.OOOO0000000 58 O00000000000O~ 68 O00OO00000000~ ~ O~O00000OO000O 68 O0000OO000000O 68 O000000000000o 6~ OOO00OO000000S o6 O000000OO0000O ~ O00000000000O~ 65 ODO00OOOOO000~ ~600000OO00DO000 ~8, OJOOOOOOOOOOOD fO~' PT 9 bZ ) SP -:5.3.43 ]'5 g'R NP4I 19.1¢06 NCNL OEPT 9500.0000 SPLO SF -54.187;5 GR NPSi 19.0916 NCNL DEFT '9500.0000 SFuU i~i P H I ;53. ~ 0 ~ 6 N C N L DEFT 9~O0oO00O SFLU RHb2 2.2930 gR~O NPHi 31.3955 NCNL DEPT 9.300.0000 SFuU SP -1!5.,t8'7D GR NPHI 29.1932 NCNL OEPT 9ZO0.O000 SF~U SP -95.15'75 jR RHO6 2.7324 ORHC NPHI 31.~'9.~1 NCNL SP -,~.~727 GR RHgB 2.3555 DRHO NP~i 45.3125 NCNL DE,PT 9000.0000 ,SFLU SP -16.58'15 GR RH~B ,Z.3984 DRHO NP'Hi 4,~o?0.12 .NCNL OEPT 8~00.0000 SFLU SP 3oZ87! GR RHO8 -999.2500 DRMO NP~I -999.Z500 NCNL OEP'T 8800.00§0 SFLU NPH2 -~99.~500 NCN.L 3.1055 65.g625 JR -0.6255 ~ZO.O000 FCNL 3.1035 IL~ ,53 . 0625 '3 R -0.0255 NR~T 1~20.3000 FCNL '.g£.3~ 95.2500 GR g.!80k NR~T 173.$..0000 FCNL 2D.3438 6,~.250C O.O?Z3 NR&T £93:~,.0000 ~CtL 2.0459 83.3750 0.0981 NRA'T 2~BO.O000 FC~L Z2.~688 iL3 74.6875 GR 0,.066~ NR&T ~650.0000 FCNL 1.'3619 134.Z500 ~R 0.0869 NR~T 1887.000.0 FCNL ]2.9766 ILD 135.5250 GR 0.0903 NR~T ZO6,Z.gOOO ~C~L ~.~926 iLO ,153-6Z50 GR -999.2500 NR~T -999.2500 P.CNL 180. Z500 GR .-999.2500 NRAT .-99'9. '~_.500 ,=CNL 3.05o0 68.D6.25 Z.J156 Z.T73e 6J. OS.Z5 2.0156 547.5000 .¢. 07 J i 95.2500 393..5000 6~.Z500 2.9180 83.3750 98.2-4 ?50 O 7930 .Z 50'0 625 0 6738 5.31.5000 3.%199 I5.3.6g50 ,-999.Z500 25O 0 -999. ~.~00 RNRA ILM CALl RNRA CALl CALl RNRA fiLM CALi RNRA iLM RNRA I L'M RNR A iL:M CALl R NRA ~.LM C A L I RN R.A ,i J.,. M CALI R.NR A 5.5000 2.1914 2.9902 3.53!3 2.19i4 10.23'91 '9. '$2 3 4 ~ ,4 ',5 '9 968'7 Z2. ~I5,0 9., ~.9 Z£ 3. ~ 8 3 6 ,Z. g 6 ,'J .~, I0.,67 19 ~+..,L 172 3.87:8'9 i 0,. O938 '-!} 9':~. :bOO i0.. ! 3 ,Z,o LVP OIO.HO,?. VE,~I:FIf__.ATZ3N Li.%T!NG PAS~ 5 DEPT 8700.3000 SFLU 5P -!20..2500 3R RH3~ -~99.150C 3RnO NPnl -999.Z500 NCNL OEPT ~$0'0.0000 SFLU SP -152.37,50 3R RH3B -79~.25'00 OReO NPni -99g.iSOg NCNL &~ -160.6250 SR NP~i -~9~.2300 NCNL -161.52.50 ~R -999.2500 OR~G -~99.,2500 NCN~ 06PT S~C3..OO00 S~LU SP -161.~750 GR Rm~B -99'9.2500 ~RHG NP~i -~99.2~00' NCNL O~'T 8ZO0.O000 SFLU SP -152.3750 &R RH~B -999. Z500 CR~ NPH.I -999.2~00 NCNL G~:PT 8100.0000 SFLU SP -'~ 4'? 2500 D~PT 8~00.0000 SFLU SP -161.5000 SR RMO6 -999.2590 ORHG NP~2 -999.2500 NCNL OE~T 7~00.~030 5~LU SP -!59.87.50: GN RHg5 -~99..2500 3R~O NP~I -999.2500 NCNL O~PT 7800.0000 SFLU S.P -18'a'ZSO0 ,SR RMJ6 -999'2:500 ORHC NPHI )99.2500 NCN~ D~?T 7700.0000 S~LU SP '-180. i,Z50 GR RHg~ Z.385'? 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Z 500 3.31 ,,* 5 14-~. 1250 -999. ;i500 -~99. 2500 7500 2500 g. 33.£0 165.."5:00'0 -999. i5'00 -999 . 2500 ~. 0586 137.37'50 -999. 21500 -999. 2500 ~.~3'7~ -999,.2500 -999.2,500 -999.2500 4,11'72 -999.2500 ,-9'99.2500 5.679'7 .16'7.1250 3.4395 505..~000 GAL1 RNRA C AL1 ,RNRA Z L M CA-Z RNRA C~Li RNRA i LM GALI RN~IA .'ZLM CALl RNRA ILM gAL I RNRA iLM RNRA CALI ~. i 7 '58 lO. i~06 -999. 2500 ~.,i305 -999.2500 4.~781 10.7031 -~99,Z500 5.0731 i,~.21,~7 -999.2.500 ,:) 3, 0 '9 2500 10.5625 2.2910 -992.,Z500 ,,. 1836 -99'9.25g;0 -99~.,Z500 ,~. 2109 -999. '2500 3.8203 ~,.0625 LV? Oi~.aO~ V~i:?'_T&ATI,2N LISTING PA~6 6 GERT 7500.0000 SFLU NPHi 36.96.>_'9 NCNL OEPI 7500.0000 SFLO SP -154.3750 ~R RHD~ 2.5.516 DRHD NFH? 45 7031 NCNL OEPT 7300.0000 SFLU SR -162.0000 GR RHG6 2.3633 ORHO NFHi 41.5039 NCNL DERT ?3OO,.OOOO SFLO SP ,-16.3.7500 SR NPMi 40.0879 NCNL DEPT 7200.0000 SF~U SP -146.1250 3R R~C6 ,-~99.2500 3RHO NPHI -~9~.!50~ NCNL O~PT 7100.9000 SFLU SP -150.1250 GR RHDB -999.2500 SRHS NPHi -999..150C NCNL OEPT 7000.0000 SFLU SP -.ZTZ..7500 ~R RHO6 .-99:9,2:500 3RHg NPdi -999.2500 NCN~ OEPT 5900.0000 SFLU SP -1~9~.1250 ~R RHOB -~9~.Z500 DRHG NPMi -999.2500 NCNL OEPT b$OO.O0-O0 SFLU .SP '-18,~.1500 GR RhJ6 -D99 25,00 ORdO NP~I -99~,.Z500 ~CNL OEP'T 670g. 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ZE,JO ORiiC NPml -'399. 2500 NCNL D~PT 6~OO.O00g SFLU SP '-151.$750 SR RH36 -):99.2500 GRHO NPHi -999.Z500 NCNL 2k~T 630g..OOOg SF=u SP -I58.7500 $R NP~i -999.£500 NCNL DEFT 6ZOO. 0000 SFLU SP -165..5000 RHOB -'~99. 2500 NP~~'.,. -999 o .~5~0 NCNL DEFT 5~00.~000 SF~U SP -iT~.6ZEO GR RH3B -999.Z500 ORH'Q NPMI -999.2500 NCNL @EPT 6,800.3000 SFuU RH06 -'D9D.ZEOO gRmO iiPnI -)99°2500 NCNL SP -[85..5250 GR NPHZ -999. t500 NCNL DEFT 580:0.0000 SFLU SP -172.7500 ~SR R~ig5 -999. 2500 DRHO NPmi -99 ~,., ES00 NCNL DE. P'T 9lOg.gOO0 SFLU SP - 167. ZEgO SR Rm~8 --99.~.25g0 3R,tO NPM.I -999. £500 NCNL DEFT 5~O0.gOOO SFCd aP -i63.5090 JR NPHi -999.2500 NCNc SP -150. 3750 GR -999. ) 590 FC NL Z.673B ILO -999.25~0 :CNL 2.5625 .i13.9375 GR -999.2500 NR~T -~9~.ZEOO FCNL 2.8672 IL3 -999.2500 NR&T -999.2500 FC~L 3.0352 IL3 .i10.31,25 SR -999.2500 NRAT -999.2500 ~C~L ,Z.gZ,S8 8~.5000 GR -99~.lSgO -9'9'9.2500 ~CNL !.36%1 .1,2,3.5000 -999.2500 NR~T .-9'99.2590 Z. 5566 ZLD '-999.£530 NR.~T -999.,Z500 FCNL 3.0977 l L D 94.. 312.5 ~SR -999. 2500 NRAT -99'9.2500 FCi~L Z.95'TO -999.Z500 .NR~T -~99.Z500 ~CNL Z.gg58 iLO 9,~.. !)'50 6R -999.25D0 NRAT -99'9.2.500 mCNL ~. 9 8 6:.~ 'rL~J i 0 3 . 06. 2,5 &,R Z.5340 iLM -999.Z500 CALi -999.Z500 RNRA -999.Z500 .775q. - '9 '99.2. 50 O R N R .a · - :~99. Z,500 3.2422 lL~ -~99. Z500 CALi -99}.Z500 RNRA -'999.Z500 2.99~1 -999.25~0 CALi -9'9'9.2.500 RNRA -:~99.Z500 .Z.~OO6 -999.2500 CALl -99~..gSDO RNRA -999.2500 3.1016 ZLM -999.2500 CALl -999. 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