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191-094
Regg, James B (DOA) 1-qi� From: Bixby, Brian D (DOA) Sent: Monday,June 20, 2016 8:00 AM t l � '7A I/k;To: Regg,James B (DOA) � Subject: Emailing: 160619 1R-29 Well photo 2jpg, 160619 1R-29 Well photo ljpg Attachments: 160619 1R-29 Well photo 2jpg; 160619 1R-29 Well photo 1 jpg Good Morning Jim, Attached are the photos I took yesterday to follow up on the piping issues on 1R-29. Photo 1 shows the spacer they added to move the pipe away from the "S" Riser and Photo 2 shows a good air gap between the piping. I'm comfortable ✓ with closing out the report. If you need anything else please let me know. Thanks, Brian Brian Bixby SCANNED DEC 1 2OL.S Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.Rov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433 or brian.bixbv@alaska.gov. • • V State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1R-29 Well Date: 4/17/2016 PTD: 1910940 Operator: Conoco Phillips Type Inspection: SVS Operator Rep: Darrell Humphrey Inspector: Brian Bixby Position: Production Engineering Specialist Op.Phone: 907-659-7535 Correct by(date): Op. Email: n1139@conocoohillips.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Gas Lift flowline is in a real bind with the"S"Riser and putting stress on a gate valve.Shut-In 4/18/2016 well relieve the strees from both the fiowlines,take pictures and then well is OK to beliitr \ brought back online.An inspector may stop by to look at it later. J `e Pe ,% Cd"jp i!eke(-{) e t't ,t t,u Ccn; +- C='/i z ht, , 14S (t 111,, — S WeF. c (6.114A, -cc .q,II_o P &leiiIto Goo 6,�3)x��� (P1'46,> 4 Pictures are attached to email. Attachments: Darrell Humphrey ,`,17. ,I_ Operator Rep Signatures: 't �P Brian Bixby AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • • KRU 1R-29 (PTD 1910940) Riser Repairs Photos by AOGCC Inspector B. Bixby 6/19/2016 0 k . m .,li . . lir , if .fr j , , 1,_:..• fi ST00 i..;t Y 1 • f • , .. ' i , tr .. ,... : , .. ,, ,, .. „ ,, ,, ,., . : ,_, 4 .g: ..... .....:.. ,• Y11161 :4: i.. flj,. Ai' :..; Ir,-,, _. .t.,i; if: 0 ; . i' 'i .1 . .f., J r ,� �• + i ....:14 0 ,, ti*.: :i . l' .,,,••,,,,„„0,,, tr. 44......ir5 ..., , , .. , .;!, . t- t� pi t f „. .„.... z • 1 I .'- ,/ 2016-0619_Deficiency_KRU_1 R-29_correctedphotos_bb.docx • Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Sunday,June 12, 2016 2:03 PM To: Bixby, Brian D (DOA); Regg,James B (DOA) Cc: NSK Fieldwide Operations Supt Subject: 1R-29 Deficiency Report Repairs Attachments: 1R-29 GL Riser repairs 06-08-16.pdf ) ConocoPhillips has made the requested repairs to the Gas Lift riser on 1R-29 to eliminate contact with the well's S riser as discussed during the AOGCC Inspector's site visit in May.The photo enclosed shows that there is space between the two risers after the repairs were made.This addresses the concerns of the 4/17/16 deficiency report for this well. Please let us know if any further action is necessary or if you would like to make a site inspection. Regards, Darrell Humphrey/ Bob Christensen Production Engineering Specialist Conocophillips Alaska Inc. n1139( conocophillips.com Office (907) 659-7535 Pager (907) 659-7000#924 1 t- •'''• , , (ift , te -• , .c.- ..... ,,, ,... • , .. .- t..., it. --,;;,•,., AK ,--) .-. - - . , .. . rj , ,. . ...,.., • „...... ,. 4 i . *, • • • •_ . . • • V • . I- ,,,,,,00 Ir, -:-• .,..- ott.• 40'.• - 4..... ., . . ......., ..,, . . ..... 0 .• .40 _ _ • • , - — / -••••,,it, Al ,-........t •,. r , -litykia.,-- - , . „..., _ ... , ...... .•••, . ... . 0. .. ..,,,,.... .Thi...,,,, . . ., ,,,,„ lit'l, • . - ”" '44 ' - /t ••,....... ....,•.--.,--- -... , 0-,:rii,....0.410:,• . —•-4,..,.41— - 1 — . — -.--. - - . ., . . i• . . . - ; - t----\ ----i), c; .., 4.... '''"' ..,_ ^ 0 C‘I ' . .. . 1- '' . . ‘,.....) . •- ›.. .-- . , • .,...._.. .. ......, -0---- .-- • , - ,.= 4.-•.0 = ty a. t:161 44 I cot o 0 •;... / •.= ‘....„,_ .....,,. . ,--- --------4—fj•,,NVcft. ; 'NI. , • , • . *. • 0 - u8 '.\ • . - - IMIII"MIIIIIIIMIIIIIMIIIIIIIIIIIIIMIII"Milli")IMraillail, • . ' v- • Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Thursday, May 12, 2016 7:24 PM To: Bixby, Brian D (DOA); Regg,James B (DOA) 44; Cc: NSK Fieldwide Operations Supt Subject: 1R-29 piping review site meeting This note is a follow up to our meeting 5/12/16 at 1R-29 to review the piping of the gas lift and S risers on the well. ConocoPhillips representatives met with AOGCC inspector Brian Bixby to review the well and his concerns over stressed piping.The gas lift riser is currently disconnected from the well as there is some TIFL work in progress. Mr. Bixby noted his concerns in regards to the two risers being in contact with each other.The determination of whether or not the piping was stressed could not be made in the wells current condition.The well will be re-evaluated after the gas lift piping is reconnected and ConocoPhillips will make any repairs deemed necessary and communicate these to AOGCC when complete. Regards, Darrell Humphrey/ Bob Christensen Production Engineering Specialist Conocophillips Alaska Inc. n1139@conocophillips.com Office (907) 659-7535 Pager(907) 659-7000#924 1 • • R ECF N STATE OF ALASKA ..UN 0 7 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill fl Perforate New Pool r Repair Well Fro Re-enter Susp Well r Other: Tubing patch p- 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fr, Exploratory r 191-094 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 5002-922-19500-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0025636 KRU 1 R-29 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Kuparuk River/Kuparuk River Oil 11. Present Well Condition Summary: Total Depth measured 11,331' feet Plugs(measured) None true vertical 6865' feet Junk(measured) None Effective Depth measured 11,144 feet Packer(measured) 8765, 10,572, 10,844 true vertical 6755' feet (true vertical) 5518, 6436, 6581 Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 123' 123' Surface 6000' 9 5/8" 6042 4119' Production 11,296' 7" 11331' 6865' SC64V..iV,PfC 9 7 201F, Perforation depth: Measured depth: 10746-10786, 10945-10955, 11000-11010, 11053-11076, 11092-11112 True Vertical Depth: 6528-6549, 6639-6644, 6670-6676,6701-6715, 6724-6740 Tubing(size,grade,MD, and TVD) 3.5", L-80, 10,867' MD, 6594'TVD 64' retrievable TTS Pargon patch from 8671'-8735' Packers&SSSV(type, MD,and TVD) Baker FHL 8765'&5518'TVD, Baker FB-1 10,572'MD&6436'TVD, Baker FB-1 10,844'MD&6581'TVD No SSSV 12. Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A • Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development Service r Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil 17, Gas r WDSPL Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG i 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: N/A Contact Brent Rogers/Kelly Lyons Email: N1617conocophillips.com C1 Printed Name Brent Rogers Title: Problem Well Supervisor ki4/..4- 2,ev. Signature Phone:659-7224 Date: June 05,2016 Form 10-404 Revised 5/2015 i/Ar(' -7-1�l)L RBDMS I,V +i(4, 7 Abmit Original Only • • ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 JUN 072016 AOGCC June 5, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU well 1R-29 (PTD 191-094). This report is for a 64' retrievable patch set to repair a tubing leaks above the top packer. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments • • ConocoPhillips, Alaska Date Event Summary 05/14/16 PULLED 2.81" CAT VALVE FROM 10832' RKB. PERFORMED SBHPS,MADE 30 MINUTE STOP @ 10830 RKB (bhp= & 15 MINUTE STOP @ 10640' RKB.B&F'D INTERVAL FROM 8700' SLM TO 8750' RKB. DRIFTED DOWN TO 8900' RKB W/25' X 2.74" PATCH DRIFT. SET 2.72" SOS LOWER PACKER (ser#cpp35069) @ 8735' RKB. 2.78" TTS TEST TOOL IN LOWER PACKER @ 8735' RKB.LRS NIGHT CREW LEFT IN CONTROL FOR PRESSURE TEST. C-MIT PASSED (2nd attempt). JOB IN PROGRESS. CMIT-TxIA pre T/I/O= 1100/800/360. Initial T/I/O= 2500/2200/360. 15 min T/I/O= 2475/2200/360. 30 min T/I/O= 2475/2200/360. 05/15/16 PULLED 2.78"TTS TEST TOOL FROM LOWER PACKER @ 8735' RKB. SET 2.2" SOS PIIP (ser#cpp35066) W/ 13.48' SPACER PIPE & SNAP LATCH (oal=18.84') @ 8717' RKB. SET 2.78" TTS TEST TOOL IN UPPER PACKER @ 8717' RKB.LRS ON LINE FOR MIT-T,33 BBLS AWAY& IA STARTED TO TRACK.EITHER TOP PACKER LEAKING OR LEAK ABOVE. WELL READY FOR SLICKLINE 05/16/16 PULLED 3 1/2"TTS TEST TOOL FROM 8676' SLM. IN PROGRESS. 05/17/16 PULLED UPPER PATCH ASSEMBLY @ 8717' RKB. SET 24' 11" UPPER PATCH 05/19/16 GOOD TBG TEST W/ HOLE FINDER @ 8668' SLM (EST 51" FROM TOP OF PATCH) TTS TEST (OAL 36") TOOL STILL IN TOP OF PATCH @ 8711' RKB. IN PROGRESS. 05/26/16 PULLED TTS TEST TOOL @ 8711' RKB; DEPLOYED CATCHER & PULLED OV @ 8700' RKB (POCKET LEFT OPEN); PULLED GLV& SET OV @ 7531' RKB; PULLED CATCHER & 24' UPPER SECTION OF PATCH @ 8711' RKB. LRS ON LOCATION DISPLACING IA. IN PROGRESS. 05/27/16 SET 38.84' UPPER PIIP (CPP35080)PATCH ASSEMBLY @ 8696' RKB; SET TTS TEST TOOL & FAILED TO P/T; RAN HOLE FINDERS &W/ PEAK HOLEFINDER DETERMINE LEAK POINT TO BE BETWEEN 8693'-8691' RKB. JOB SUSPENDED FOR PLAN FORWARD (TTS TEST TOOL STILL IN HOLE) 05/29/16 PULLED TTS TEST TOOL @ 8696' RKB; STACKED PIIP PATCH ASSEMBLY(24.86' OAL) @ 8671' RKB; RAN TTS TEST TOOL & OBTAINED PASSING MITT; PULL TEST TOOL. JOB COMPLETE. BEGIN MITT. INITIAL T/I/O = 1050/875/360/160 START = 2525/840/360/160 15 MINS = 2400/725/360/160 30 MINS = 2350/650/360/160 PASS. 06/05/16 (AC EVAL) ReTIFL post patch (PASS). Initial T/I/O = 200/1085/550 IA FL @ OV(7531') OA FL @ 66'. SI well @ WV double block lift gas @ manifold bldg. Stack T x IA with lift gas 75 minutes T/I/O = 950/1000/250 IA FL @ 7531' (OV). Bleed lift gas line to 250 psi. Bleed IA 60 minutes T/I/O = 940/510/230 IA FL @ same location. Bleed IA additional 10 minutes (70 minutes total) T/I/O = 940/420/230 IA FL same location. 15 min T/I/O = 940/420/230. 30 min T/I/O = 940/420/230 IA FL same location. 45 min T/I/O = 940/420/230. 60 min T/I/O = 940/420/230 IA FL same location. Final T/I/O = 940/420/230 Summary A 3 section 64' retrievable TTS Paragon patch was set from 8671' - 8735'. Each section was tested during installation. A passing TIFL was completed proving up patch and tubing integrity. KUP PROD 1R-29 ConocoPhillips g Well Attributes Max Angle&MD TD Alaska,Inc, Wel!bore APIIUWI Field Name Wellbore Status )not(°I MD(ftKB) Act Btm(ftKB) Conoca'tiepc Y 500292219500 KUPARUK RIVER UNIT PROD II 60.58 8,375.00 11,368.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-1R-29,5/31201612:42.29 PM SSSV:NIPPLE 80 7/31/2015 Last WO: 4/20/2001 42.99 8/16/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --- ----- ----- --- - Last Tag:SLM 11,144.0 11/3/2010 Rev Reason:H2S,GLV C/O,MILLED XN pproven 5/31/2016 NIPPLE,PATCHS HANGER'39.1 -,1E)i ,,,,,,,,,, ,.„..„„.am„„„,„„„m„a.. 1I Ali, " �t,aa.Casing Strings .1 Casing Description OD(i n) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 44.0 123.0 123.0 62.58 H-40 WELDED Casing Description OD(In) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.921 42.2 6,042.4 4,119.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(BOB) Set Depth(TVD)... WtlLen 0...Grade Top Thread ✓.WINDOW 8 7.000 11,000.0 11,010.5 6,676.5 CONDUCTOR;44.0-123.0-a I, Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 35.2 11,330.6 6,865.2 26.00 J-55 BTC-MOD NIPPLE;521.0 `W Tubing Strings GAS LIFT;3,403.6 t. TubingDescription I String Ma...I ID(in) I Top(ftKB) I Set Depth(ft...I Set Depth(ND)(...I Wt(lb/ft) I Grade I Top Connection GAS LIFT;3,403.6 r_ TUBING WO 31/2 2.992 39.2 10,867.411 6,594.3 9.301L-80 EUE8RDMOD I Completion Details Nominal ID Top(kKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;5,830.7 - 39.2 39.2 0.00 HANGER FMC GEN 4 TUBING HANGER 3.500 521.0 520.0 7.18 NIPPLE CAMCO DS LANDING NIPPLE W/NO GO PROFILE 2.875 8,750.0 5,510.9 59.79 SEAL ASSY BAKER SEAL ASSEMBLY 2.992 8,750.8 5,511.3 59.78 PBR BAKER PBR 4.000 SURFACE;42.2-6,042.4 8,764.5 5,518.2 59.60 PACKER BAKER FHL PACKER 2.937 10,570.4 6,4352 58.51 SEAL ASSY BAKER SEAL ASSEMBLY w/BAKER NO GO ID 3.0" 3.000 10,572.3 6,436.2 58.50 PACKER BAKER FB-1 PACKER 4.000 GAS LIFT;7,531.3 10,575.6 6,437.9 58.48 SBE BAKER SEAL BORE EXTENSION 4.000 10,731.8 6,520.0 58.10 BLAST RINGS CARBIDE BLAST RINGS(OAL=63') 3.500 PATCH;8,671.0 'IJ 10,832.1 6,574.5 56.19 SLEEVE-C 3.5"BAKER CMU SLIDING SLEEVE w/2.813"CAMCO 2.813 i DS PROFILE.(CLOSED 11/30/12) GAS LIFT;8,699.9 f` 10,842.2 6,580.1 55.96 SEAL ASSY BAKER SEAL ASSEMBLY w/BAKER NO GO ID 3.0" 3.000 PATCH;8,696.0 10,844.0 6,581.2 55.92 PACKER BAKER FB-1 PACKER 4.000 PACKER;8,735.0 k 10,847.3 6,583.0 55.87 SBE BAKER SEAL BORE EXTENSION 4.000 10,859.3 6,589.7 55.74 NIPPLE 3.5"XN NIPPLE w/2.813"Pkg bore x 2.75"NO GO 2.800 profile(MILLED to 2.80"12/4/2012) SEAL ASSY;8,750.0 PBR;8,750.8 10,866.7 6,593.9 55.66 WLEG WIRELINE ENTRY GUIDE 3.015 PACKER;8,764.5 - - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top not Top(ftKB) (kKB) r) Des Corn Run Date ID(in) 8,671.0 5,471.2 59.81 PATCH STACKED PIIP PATCH ASSEMBLY(24.86'OAL)@ 5/29/2016 1.650 PRODUCTION;8,811.4 '.I 8671'RKB --- 8,696.0 5,483.8 59.81 PATCH 38.84"UPPER PIIP(CPP35080)PATCH ASSEMBLY 5/27/2016 1.650 7"CSG HOLE;9,438.0 8696'RKB 8,735.0 5,503.4 59.90 PACKER 2.72"SOS PIIP(ser#cpp35069/oaI=3.97) 5/14/2016 1.650 9,438.0 5,861.0 59.55 7"CSG HOLE-Hole in 7"casing,see USIT log 4/15/01 4/20/2001 6.151 PRODUCTION;10,524.6 11,000.0 6,670.4 54.43 WHIPSTOCK THRU TUBING MECHANICAL WHIPSTOCK 12/7/2012 SEAL ASSY;10,570.4 - 11,166.0 6,767.8 53.79 FISH FISH 1.5"OV on RK from 9/22/01..See WSR 9/22/2001 0.000 PACKER;10.572.3 10/11/01 SBE;10,575.6 _ Perforations&Slots Shot Dens Top(ND) atm(ND) (shots/f PRODUCTION;10,623.2 Top(kKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 10,746.0 10,786.0 6,527.5 6,549.1 C-1,1R-29 12/31/1991 12.0 IPERF 4.5"Csg Gun;120 deg ph 10,945.0 10,955.0 6,638.5 6,644.3 A-3,1R-29 11/29/2012 6.0 IPERF 2.5"HSC Loaded, IPERF;10,746.0-10.7860- MIIIIniUm HMX DP Charges 11,000.0 11,010.0 6,670.4 6,676.2 UNIT B,10- 11/28/2012 6.0 IPERF 2.5"HSC Loaded, S 29 Millinium HMX DP SLEEVE-C;10.832.1 Charges SEAL ASSY;10,842.2 - 11,053.0 11,076.0 6,701.3 6,714.8 A-4,1R-29 12/31/1991 4.0 IPERF 4.5"Csg Gun;120 deg PACKER;10,844.0 ph SBE;10,847.3VI= 11,092.0 11,112.0 6,724.1 6,735.9 A-3,1R-29 12/31/1991 4.0 IPERF 4.5"Cog Gun;120 deg I 'I Ph I ai.} Stimulations&Treatments iMin Top Max atm __ Depth Depth Top(ND) Btm(ND) NIPPLE;10,859.3 (kKB) (ftKB) (ftKB) (808) Type Date Corn 1 11,053.0 11,076.0 6,701.3 6,714.8 FRAC 9/17/2001 A-SAND REFRAC,52,000#16/20&12/18 WLEG;10,866.7 E. CARBOLITE,5.3 ppa ON PERFS Mandrel Inserts IPERF;10045.0-10,955.0- -- St aft ,r. on Top(TVD) Valve Latch Port Size TRO Run IPERF;11,000.0-11,010.0 N Top(kKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com WHIPSTOCK:11,000.01 -- 1 3,403.6 2,600.6 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,343.0 1/9/2013 11:30 WINDOW;11,000.0-11,0105 + 2 5,830.7 3,996.8 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,323.0 4/25/2016 SLOTS;11,017.0-12,722.03 7,531.3 4,896.6 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 5/26/2016 Liner L1-03;10,856.6-15722.0 ice-- 4 8,699.9 5,485.8 CAMCO MMG 11/2 GAS LIFT OPEN 5/26/2016 IPERF;11,053.0-11,0760 5 8,811.4 5,542.0 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 4/20/2001 10:00 FRAC;11,053.0, I� �' 6 10,524.6 6,411.4 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 4/20/2001 7:30 !PERE;11,092.0-11,112,0-7_ 7 10,623.2 6,462.9 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 10/12/2001 5:00 FISH;11,166.0 41 Notes:General&Safety End Date Annotation 10/20/2010 NOTE:Mandrel @ 10623-1.25"JD w/Core Ext.for Equalizing Prong. 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUCTION;35.2-11,330.6 • 12/29/2012 NOTE:ADD LATERALS L1,L1-01,L1-02,L1-03 • C p ¢ v 0 E'o .- u v 0 N z CO - aJ O 6- rj 1 rCO < X (Ou Or9 OV Y 20 a L ° a Y_ a) o o I- 1 r, z LL C _) - Op > 0_ O z Y o V Ci.2 v �nCU E Y O 1 Q 4-' O O` O -O o vL O = ro T Q Q Q p 4-= C -0 rO 0 C, 0 ... to - ., ,, to m t O a) E t m V r r r a J >+ T T >+ 'w a) O y N N I- O tE CO CO R co r0 as '� L C C rO l'''' lL rL ro O_ N F- N O O r ot 1- C >' > N a N C „ a) O_ a) Z Q p o -0 E o >. • OC u u J--, cc H O a) '' co O ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0- CO a) (L,) - ' a J J J J J J J W W W W W W W 00p ro O O 0 F}- LL LL LL LL LL LL LL .vf a) E -a) o 0 Q J J J J J J J Q o a) Q Q Q a a a a C Q a) a Z z z z z z z .T v, -0 `" Y u p u M ❑ U.. 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M N (N 0 N 0 N d N N N N N N N n Q to O) to O) t) P') 0) 8 L Q N N N N N O N Q1 00 . . . — . - O O O OO O O u) v) u) N u') in It) �, 30 a) T co C_ 0. u C pE y > . da cd ... 4 8 a Ce v 'C ��t co ra fflh1 mom OA - N N fh to 0.1 cc rnY CA a a Q • • aut sz_Z, lciia Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.c m> Sent: Sunday, April 17, 2016 4:06 PMQ�J .' 19(((a� To: Bixby, Brian D (DOA) C Cc: Regg, James B (DOA) Subject: RE: Emailing: 160417 KRU1R-29 Well #4jpg, 160417 KRU1R-29 Well #3 jpg, 1604174 KRU 1R-29 Well Deficiency Report.xlsx, 160407 KRU 1R-29 Well #1.jpg, 160417 KRU 1R-29 Well #2jpg Thanks Brian, I have received your email and will distribute it to the appropriate groups to make the necessary repairs. Darrell Humphrey ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) Original Message From: Bixby, Brian D (DOA) [mailto:brian.bixby@alaska.gov] Sent: Sunday,April 17, 2016 3:58 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Cc: Regg,James B (DOA)<iim.regg@alaska.gov> Subject: [EXTERNAL]Emailing: 160417 KRU1R-29 Well#4.jpg, 160417 KRU1R-29 Well#3.jpg, 1604174 KRU 1R-29 Well Deficiency Report.xlsx, 160407 KRU 1R-29 Well#1.jpg, 160417 KRU 1R-29 Well#2.jpg Darrell, As per our discussion in your office here is the Deficiency Report for 1R-29 Well. Please reply to ALL to confirm you received this OK. Thanks, Brian NNE) DEC 1 4 2016 1 • • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1R-29 Well - Date: 4/17/2016 PTD: 1910940 Operator: Conoco Phillips Type Inspection: SVS• Operator Rep: Darrell Humphrey Inspector: Brian Bixby Position: Production Engineering Specialist Op. Phone: 907-659-7535 Correct by(date): Op. Email: n1139@conocophillips.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Gas Lift flowline is in a real bind with the"5" Riser and putting stress on a gate valve.Shut-In well relieve the strees from both the flowlines,take pictures and then well is OK to be brought back online.An inspector may stop by to look at it later. Attachments: 4 Pictures are attached to email. Darrell Humphrey Operator Rep Signatures: Brian Bixby AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • • Deficiency Report Photos-KRU 1R-29 (PTD 1910940) Photos by AOGCC Inspector B. Bixby 4/17/2016 - „,.....-- -,s,„4..1.,\......,,‘'`-‘,.....:‘....::,........... .."'44V-11"rrilll'i ,f ,.,, ;•. • h g. Tom. r c ,.010-4filit c c ■ a t 6 E f '14'.' ) .., . , .,, ... ,,,,„ i r . , , ,,,, .. . _ ,4$4.{ H • � 1 • .,-..t,..., ,, - : ,„„4,..--,--44".' t .. iiik \ , ' . i mil jIIMIMI il s , 2016-0419_De ficency_Photo s_KRU_1 R-29_bb.docx Page 1 of 2 0 • ,.: ., .i! / � A a oft, e i w • " ,:,- ' _.------ , ..,, #1 iii 14 F .' P% w .z id,,...___ ,.. 1 : i Ais Its mr 1 i . 4 4 ,i; .... •': - „:-...,-- ' . ' di ',..,!,:. , - -- ,-"i ' : - -- *11' ti.„,'--\,. 40: . - ,..i.c.-0.. • . . ,:t vf,ii : ,, i$,..,,„„L.,-,:i. - i a 2016-0419_Deficency_Photos_KRU_1 R-29_bb.docx Page 2 of 2 • • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1R-29 Well Date: 4/17/2016 PTD: 1910940 Operator: Conoco Phillips Type Inspection: SVS Operator Rep: Darrell Humphrey Inspector: Brian Bixby Position: Production Engineering Specialist Op.Phone: 907-659-7535 Correct by(date): Op. Email: n1139@conocophillios.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Gas Lift flowline is in a real bind with the"S"Riser and putting stress on a gate valve.Shut-In 4/18/2016 well relieve the strees from both the flowlines,take pictures and then well is OK to be brought back online.An inspector may stop by to look at it later. Attachments: 4 Pictures are attached to email. Darrell Humphrey /_ Operator Rep Signatures: �+1�� 1P Brian Bixby AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • • ConocoPhillips Alaska AOGCC EXCEPTION REPORT Location: 1R-29 Date: 04/17/16 AOGCC Inspector: Brian Bixby Instructions: All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered into the'Action Taken'section below. Note- Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: From AOGCC Inspector: Gas Lift flowline is in a real bind with the "S" Riser and putting stress on a gate valve. Shut-In well relieve the strees from both the flowlines,take pictures and then well is OK to be brought back online.An inspector may stop by to look at it later. \\S:\NSK\LongTerm\Groups\Wells Group\Problem Wells&Compliance(ADM040)\State Testing EXP200..EXP220 \AOGCC Exce tion Re orts\1 R Exceptions The above a- z)1.- 1-iTik is tote onoco i ips AOGCC 1R Exception folder.You will find photos and the AOGCC deficiency report located here. When the repairs are complete please place the required photos in this folder. Action Taken to Correct Problem: The valve handle has been removed to eliminate the stress on the Date: 04/18/16 Initials: TLA valve stem. Pipe wrap has been applied to eliminate the concern for abrasion Date: 04/18/16 Initials: TLA between the two pipes. After review with our Engineering discipline, we believe that the gas lift noted is not in a bind or under stresses that are detrimental to the integrity of the line. Photos of the current condition demonstrate Date: 04/18/16 Initials: TLA that the line is not deflected or bent. This well will continue to be on our field integrity surveys and corrective action will be made if the condition deteriorates to a level of concern. Date: Initials: Date: Initials: Date: Initials: Return completed form to Prod. Engr. Specialist: nil 39(@.conocophillips.com Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF1&2 Ops Supt CPF3 Ops & DOT Pipelines Supt NSK Fieldwide Operations Supt '' re,.,-irov I 4- 1 8-1 6 .1 R-29 Valve . ..4t .. ...,-.• ,a, * '1.-i. ,•,.;,: '0V'''''''. '.., -','-'' -#''''''T-•--41"-''- I ' p , . . , ....., „.. 1„.. . . , -- , ...,. , 0. , :•.,:, / , ..:,•,t..„•.. -• , .•. 1, \'‘....,,,,,. ' $ , • ,1. .' 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''•, , I 0 :1.- ‘....• i '',740•4!;'•;1,' ' ".•0:',.•,,.0.V°',.''''. -,. • :',.,) , ,..;*:)q,',•:,;7::'•.:::,..' .. ., , £1 I . . .. 1 Copyright '"' - Alaska, Inc •,i , rAllii AOGCC pi itsown use; 0 i, , any other. :i':,,y,,."4 , ny other part prohibited .„,„ ,.....1 :.1,.4iiirrif 1r sent of ......- , ,,,,.- ConocoPhil: l,' . 0 qIIIPPP, ' , , V; 4111 ::,...`t,,.,,...-.. - •--I. . .,,, 3,1'441.': • . , *1./,'''''... IN 1 tkr U 1 '1. ' r.' " ' 4..' ';'.:.1''r7), :r 1 R-29 Gas Lift Riser 4-18-1 F a� , I , . `‘., 11116 i • r t; � sYx � � t 'i �f ::"'i• �' o 1 ' k ,...„ .._: i_.... , ,,, ...,\., .._,., I. iti. r `x' - at i, • V 17..:.-.--•'!::. .... tft) sz . 5.. 1 ss ' 4 T19' ►Q16 Con. ,. Phillips Alaska, Inc. 1 04 "rmitt� € ? copy for its T own use;`any other u ' 1. ^opying by faw�y other party prohib�-d ‘'•�, vv ttv,rf:kit sop ca .ConocoP' '" �- 4• A -,,,,r...t, ,:--...._ • -.4 flc.,..,,,,.,-,,.,,. 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They are available in the original file and viewable by direct inspection. / ¢/ ~ 0~¢' File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] [] Diskettes, No. Other, No/Type OVERSIZED .~- Logs'of vadous kinds . n Other Complete COMMENTS: Scanned by: Dianna Vincent Nathan Lowell TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si • 6 9� \�� THE STATE Alaska Oil and Gas 1) - O f ALASK � Conservation Commission T h - GOVERNOR SEAN PARNELL 333 West Seventh Avenue QA' �. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 James Ohlinger Senior CTD Engineer Q ConocoPhillips Alaska, Inc. -• Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1R-29 Sundry Number: 312 -432 Dear Mr. Ohlinger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy ' . Foerster Chair DATED this 27 day of November, 2012. Encl. STATE OF ALASKA 'i/ ED • KA OIL AND GAS CONSERVATION COM ON "/ ` APPLICATION FOR SUNDRY APPROVALS .%1K 13 2012 • 20 AAC 25.280 , I'O( et S i I �'Q' 1 Z. 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool rr Repair w ell r CharAG &m r Suspend r Plug Perforations I� • Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate Alter casing g r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p . Exploratory r 191 - 094 3. Address: Stratigraphic r Service 6. API Number. P. 0. Box 100360, Anchorage, Alaska 99510 50 029 - 22195 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No I✓ 1R-29. 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25636 ' Kuparuk River Field / Kuparuk River 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): 11368 • 6887 . 11241' 6811' 11166' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 123' 123' SURFACE 6000 9.625" 6042' 4113' PRODUCTION 11295 7 11331' 6864' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 10746'- 10786', 11053'- 11076', 11092'- 11112' 6527'- 6548', 6700'- 6714', 6723' -6735' 3.5 L -80 10867 1 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 8764 TVD= 5518 PACKER - BAKER FB -1 PACKER MD= 10572 TVD= 6436 PACKER - BAKER FB -1 PACKER MD= 10844 TVD= 6581 SSSV - CAMCO DS NIPPLE MD =521 TVD =520 12. Attachments: Description Summary of Proposal f' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development I • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/16/2012 Oil r Gas r WDSPL r Suspended i✓ • 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 -1102 Email: James .J.Ohlinger @conocophillips.com Printed Name James Ohlin Title: Senior CTD Engineer Signature 5 ....fra :� ....e Phone: 265 -1102 Date / //0 / %Z Commission Use Only Sundry Number. 5(2,(/ Z Conditions of approval: Notify Commission so that a representative may witness ��(( Plug Integrity r BOP Test /Mechanical Integrity Test r Location Clearance r Other. Sa p i_tS f i._6, 4.0c 0 5 t Spacing Exception Required? Yes ❑ No [rj Subsequent Form Required: APPROVED / Approved by: COMMISSIONER THE COMMISSION Date: !/ 2-7 °/ RADMS r ��� �1 �.�• •ved application Form 10-403 (Revised 10/201 is valid foo 12 from the date of approval. 201 :4 A V i—F U K IGINAL Submit Form and Duplicate 'Y 11 / /2 achme is in /0 �∎ Ak • • KRU 1R -29 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well 1R - 29 is a Kuparuk A- sand /C -sand production well equipped with 3'h" tubing and 7" production casing. Four proposed A -sand CTD laterals will increase reservoir exposure in two adjoining fault blocks. Prior to drilling, the existing A -sand perfs in 1 R -29 will be squeezed with cement to provide a means to kick out of the 7" casing. This will permanently abandon only the Kuparuk A -sand. The C -sand perfs will still be accessible via the single selective. After plugging off the existing A -sand perfs with cement, a pilot hole will be drilled through the cement to 11,050' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 1R- 29L1 sidetrack will exit the 7" casing at 11,000' MD and will target the A4 sand west of the existing well with a 2900' lateral. The hole will be completed with a 2-%" slotted liner to the TD of 13,900' MD with an aluminum billet at 11,550' MD. The 1R- 29L1 -01 lateral will kick off from the aluminum billet at 11,550' MD and will target the A3 sand west of the existing well with a 2350' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,900' MD with an aluminum billet at 11,085' MD. The 1R- 29L1 -02 lateral will kick off from the aluminum billet at 11,085' MD and will target the A4 sand east of the existing well with a 1415' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,500' MD with an aluminum billet at 11,150' MD. The 1R- 29L1 -03 lateral will kick off from the aluminum billet at 11,150' MD and will target the A3 sand east of the existing well with a 1350' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,500' MD with the final liner top located inside the 3'h" tubing at 10,850' MD. 1 604 c -. well ,f frodvc,, left ri4., (00 190,1 (4 d- t'9 Cv7- ill7/0 woo(' '/( a4 .4 ryA/ 47-eapy q per ', e>cis1; C f r't/1* f . #0,6' kker4 fAeti l / rec o verfi 1"0 /-*)- CTD Drill and 1R -29 Laterals: November 2012 pr r/ 'oe , t - i44_ /Q/ Pre -CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs — T & IC. 3. MIT -IA 4. RU slickline. Tag fill. Get updated static BHP survey. 5. Pressure test tubing to confirm that the C sand straddle has integrity. 6. RU Eline: perforate tubing tail at 10,855' RKB 7. RU coil. Mill out XN- nipple at 10,859' RKB to 2.80" ID 8. RU coil. Plug all perfs with cement from PBTD @ — 11,141' MD up to the tubing tail perfs at 10,855' MD. RD coil. 9. RU slickline. Tag top of cement and pressure test. RD slickline. 10. Prep site for Nabors CDR2 -AC, including setting BPV Page 1 of 2 11/1/2012 r • • Rig W or k fa +DUops' !9A SVrac) ( (9 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7 -1/16" BOPS 3/2 2. 1R -29L1 Sidetrack (A4 sand, west) ,No/� �) OLyCG a. Drill 2.80" high -side pilot hole through cement to 11,050' MD. 2 4- h ✓.5 1 ►'� b. Drift pilot hole with whipstock dummy a d ✓e ii c c c. Set whipstock at 11,000' MD with high -side orientation. d. Mill 2.80" window at 11,000' MD. e. 1 ri . 1 x . i- center atera to Do ,• 1 1 D f. Run 2%" slotted liner with an aluminum billet from TD up to 11,550' MD 3. 1R- 29L1 -01 Lateral (A3 sand, west) a. Kick off of the aluminum billet at 11,500' MD b. Drill 2.70" x 3" bi- center lateral to TD of 13,900' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 11,085' MD PT 4. 1R- 29L1 -02 Lateral (A4 sand, east) a. Kick off of the aluminum billet at 11,085' MD ) b. Drill 2.70" x 3" bi- center lateral to TD of 12,500' MD c. Run 2%" slotted liner with an aluminum billet f r o m TD up to 11,150' MD 21 Z _ / 3 L/ 5. 1R- 29L1 -03 Lateral (A3 sand, east) 2i1-1q-5 a. Kick off of the aluminum billet at 11,150' MD b. Drill 2.70" x 3" bi- center lateral to TD of 12,500' MD Z 2 _ �� c. Run 2%" slotted liner from TD up to 10,850' MD, up inside the 3'/2" tubing tail 6. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Return to production Page 2 of 2 11/1/2012 1R-29 Proposed CTD Sidetrack 16" 62# H -40 shoe 3 -1/2" Camco DS nipple @ 521' RKB @ 123' RKB 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface 3 -1/2" gas lift mandrels @ 3403', 5830', 7531', 8700' RKB 9 -5/8" 36# J -55 shoe @ 6042' RKB �� Baker PBR @ 8750' RKB Baker FHL packer @ 8764' RKB (2.937" ID) 3 -1/2" MMG production mandrels @ 8811', 10524' RKB 7" casing leak @ • 9438' RKB '- Baker seal assembly /FB -1 packer @ 10572' RKB (3.0" ID) l -� I 3 -1/2" MMG production mandrel @ 10623' RKB .w....._ 3 -1/2" CMU sliding sleeve @ 10832' RKB C -sand perfs 10746' €€ - 10786' MD RKB - Baker seal assembly /FB -1 packer @ 10844' RKB (3.0" ID) 3 -1/2" HES XN landing nipple @ 10859' RKB (2.75" min ID, No -Go) 2 -3/8" liner top @ 10850' RKB l to be milled out to 2.80" pre -rig 3 -1/2" tubing tail @ 10867' RKB 3 -1/2" tbg circ holes @ I Mi f � 10855' RKB ■ ? ITop of Whipstock @ 11,000' MD A -sand perfs (sgz'd) 11053' - 11112' MD 1R -29L1 A4 (west) A lum billet Alum billet TD = 13,900' MD 1R-29L1-03 A3 (east) -- � @ 11,085' MD @ 11,550' MD Alum billet @ 11,550' MD TD = 12,500' MD ------------------------------ __ ,, -- ------::::::::-Z° 1 \ 1R-29L1-02 A4 (east) II 1 R- 29L1 -01 A3 (west) -' Alum billet TD = 13,900' MD TD = 12,500' MD 7" 26# J - shoe @ " ;; @ 11,150' MD Alum billet @ 11,085' MD Alum billet @ 11,150' MD 11330' RKB A KUP 1 R -29 • , a Conoc Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ft0B) e ,. 500292219500 KUPARUKRIVERUNIT PROD 60.37 8,100.00 11,368.0 • Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ""' NIPPLE 50 8/6 /2009 Last WO: 4/20/2001 42.99 8/16/1991 Well Config -1 8-29, 11128/2010 11:03:07 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 11,144.0 11/3/2010 Rev Reason: RESET PUMP Imosbor 11/28/2010 Casing Strings HANGER. 39 :, Casing Description String 0... String ID ... Top (ftKB) Set Depth (L. Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 44.0 123.0 123.0 62.58 H WELDED �.`.° r Casing Description String 0... String ID ... Top (1808) Set Depth (f... Set Depth (TVD) ... T String Wt... String ... String Top Thrd SURFACE 95/8 8.921 42.2 6,042.4 4,113.0 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (6... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 35.2 11,330.6 6,864.1 26.00 J -55 BTC -MOD Tubing Strings Tubing Description 1String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, TUBING 31/2 2.992 39.2 10,867.4 I 6,593.2 I 9.30 L -80 EUE8RDMOD 04-723 Completion Details NIPPLE. 521 A; Top Depth (TVD) Top Inc! Nomi... _........ Top (ftKB) (ftKB) ("1 Item Description Comment ID (In) 39.2 39.2 0.01 HANGER FMC GEN 4 TUBING HANGER 3.500 GAS LIFT, 3,404 - 521.0 520.1 7.32 NIPPLE CAMCO DS LANDING NIPPLE W/ NO GO PROFILE 2.875 8,750.0 5,507.2 59.69 SEAL ASSY BAKER SEAL ASSEMBLY 2.992 8,750.8 5,507.6 59.69 PBR BAKER PBR 4.000 GAB LIFT, 8,764.5 5,514.5 59.66 PACKER BAKER FHL PACKER 2.937 5,831 10,570.4 6,433.8 58.35 SEAL ASSY BAKER SEAL ASSEMBLY w/ BAKER NO GO ID 3.0" 3.000 10,572.3 6,434.8 58.34 PACKER BAKER FB-1 PACKER 4.000 10,575.6 6,436.6 58.34 SBE BAKER SEAL BORE EXTENSION 4.000 10,731.8 6,519.0 57.73 BLAST RINGS CARBIDE BLAST RINGS 3.500 SURFACE, ,■ ■ 42 -8,042 10,832.1 6,573.6 55.87 SLEEVE -O 3.5" BAKER CMU SLIDING SLEEVE w/ 2.813" CAMCO DS PROFILE. 2.813 OPEN 11/3/2010 10,842.2 6,579.2 55.79 SEAL ASSY BAKER SEAL ASSEMBLY w/ BAKER NO GO ID 3.0" 3.000 GAS LIFT, - 10,844.0 6,580.2 55.77 PACKER BAKER FB -1 PACKER 4.000 7.531 - 10,847.3 6,582.0 55.74 SBE BAKER SEAL BORE EXTENSION 4.000 MI 10,859.3 6,588.7 55.64 NIPPLE 3.5" XN NIPPLE w/ 2.813" Pkg bore x 2.75" NO GO profile 2.750 GAS LIFT 10,866.71 6,592.8 55.58 WLEG WIRELINE ENTRY GUIDE 3.015 e,700 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) IIII Top Depth (TVD) Top Intl Top (18(B) (ftKB) (°) Description Comment Run Date ID (in) SEAL ASSY 9,438.0 5,857.9 59.42 7" CSG HOLE Hole in 7" casing, see USIT log 4/15/01 4/20/2001 6.151 8,750 - -- P8R, 8,751 10,832.0 6,573.5 55.88 PUMP 3" RC JET PUMP ON 2.813" CS LOCK (56" OAL "), 11/14/2010 1.500 PACKER, 8,784 SN #PH -1113 W/ 9-B RATIO; #9 NOZZLE; #10 THROAT ' 11,166.0 6,766.7 53.79 FISH FISH 1.5" OV on RK from 9/22/01..See WSR 10/11/01 9/22/2001 0.000 Perforations & Slots PRODUCTION, Shot 8,817 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh... Type Comment 10,746.0 10,786.0 6,526.7 6,548.1 C -1, 1R -29 12/31/1991 12.0 IPERF 4.5" Csg Gun; 120 deg ph 7 " CSG HOLE. 1 11,053.0 11,0 76.0 6,700.2 6,713.6 A-4, 1R -29 12/31/1991 4.0 IPERF 4.5 "Cs Gun; 120 de h e.43e 9 9 P 11,092.0 11,112.0 6,723.0 6,734.8 A -3, 1R -29 12/31/1991 4.0 IPERF 4.5" Csg Gun; 120 deg ph PRODUCTION, I Stimulations & Treatments 10,525 .. Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) SEAL ASSY,_ (11013) (ftKB) (ftKB) (ftKB) Type Date Comment igER. 11,053.0 11,076.0 6,700.2 6,713.6 FRAC 9/17/2001 A-SAND REFRAC, 52,000# 16/20 & 12/18 PACKER, CARBOLITE, 5.3 ppa ON PERFS SBE, 10,578 ti14 Notes: General & Safety End Date Annotation 10/20/2010 NOTE: Mandrel @ 10623 - 1.25" JD w/ Core Ext. for Equalizing Prong. PRODUCTION. 10/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 10,623 IPERF, 10,746- 10.786 11 1 t PUMP, 10,832 � K/ I- ig t 10,832 SEAL ASSY, n ,/ 10,842 _ -- P .e r PACKER, 10,844 SBE, 10,847 l / NIPPLE. 10,859 ' Mandrel Details Top Depth Top Port WLEG, 10.867 V: I (TVD) Inc! OD Valve Latch Size TRO Run V Stn Top (ftKB) (ftKB) (o) Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 1 3,403.6 2,595.7 58.34 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,299.0 9/21/2008 2 5,830.7 3,993.3 56.45 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,297.0 9/21/2008 IPERF, 11,053 - 11.078 t 3 7,531.3 4,891.7 59.01 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,290.09/21/2008 FRAC, 11,053 4 8,699.9 5,481.9 59.80 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 9/20/2008 11,092 - 71.1 12 F, 5 8,811.4 5,538.5 59.59 CAMCO MMG 1 1/2 PROD DMY RK 0.000 0.0 4/20/2001 6 10,524.6 6,409.8 58.43 CAMCO MMG 1 1/2 PROD DMY RK 0.000 0.0 4/20/2001 FISH, 11.186 $ 7 10,623.2 6,462.8 59.31 CAMCO MMG 1 1/2 PROD RKED RK 0.000 0.0 10/12/2001 PRODUCTION. 35- 11.331 * It. 11,388 • • Page l of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS ( IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). r 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill" 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F : \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, November 24, 2012 5:41 PM To: Ohlinger, James J Subject: Re: 1R-29 CTD sundry request /f/ — D77' You have verbal approval to proceed with the pre -CTD plugging of well 1R -29 as proposed in the submitted sundry. ( per Commissioner Foerster) Regards, Guy Schwartz Sent from my iPhone On Nov 24, 2012, at 4:03 PM, "Ohlinger, James J" < James .J.Ohlinger @conocophillips.com> wrote: » Thank you for working over the holidays. I would like to request a verbal approval on the 1R -29 sundry to cement the current A -sand perforations. Current operations are to perf the tubing tail and mill the XN nipple followed by cement plug early this week. » A valid approval will allow us to put the operation in motion and mobilize the coil unit. » Again, thank you. > James Ohlinger > 907 - 854 -2414 > <1R -29 CTD Summary for Plugging Sundry.pdf> SCANNED APR 17 2013 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 3, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT): 1R-29 SCANNED FEB 2 5 2013 Run Date: 9/28/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -29 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22195 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: l 0 'l-G t `2,. Signed: !� .� • C0110 / ~ ~ coPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 _~,~ ~ "~,~ t..` _ ~ 4 . 't ~ '~ ~ ~.. ~w,~ . .a'+Z&w ,. ~ ~.~~~.. Dear Mr. Maunder: ~~ p~'~ 1 °~ - a~~ l~~ 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 August 15~' and 23rd 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. The attached spreaasheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, / ~~ MJ Loveland • ~~~ ~~~ ~ ~ ~~P ~ ~ 2009 ~I~~~~ ~il ~ C~s C~n~a.~a~r~s~~i~t~ ~~Ch~F~~ ConocoPhillips Well Integrity Projects Supervisor , . -..z ~ . _-, .. • ~ +.~~ ~ V1 ~~~~ ~ ~ '.. ~r_ . `_.~, .~... ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (10-404) Kuparuk Field Dat~ 8/29/09 ~ o o e n Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls R al 1 R-01 B 50029214040200 _ 2001560 13'7" 2.0 26" S/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1 R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28l2009 1R-08 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 S/28/2009 1 R-10 50029213510000 1850960 32' S.40 22" 8/15l2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8/28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009 1R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N!A 16" NIA 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8l15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1 R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009 1 R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 ') ConocJP'hillips Alaska ) P,O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ,......01...",.,.....'.lt ill"", O' . .\ \ ,,",\":il:--.". Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RECEIVED DEC ~ 12004 Alaskl OU & Gas Cons. commilsion Anchorage December 17, 2004 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. welllR-29. The Sundry regards the completing a Braidenhead weld and subsequent passing OA pressure test. Please call Brad Gathman or me at 659-7224 if you have any questions. Sincerely, /~/~~ MJ Loveland Problem Well Supervisor Attachments SCANNED DEC 2 7 2004 ) ) RECEIVED ALASKA OIL AND ~r:;~g~S~L:~:;;ON COMMISSION DEC 2 I 2004 REPORT OF SUNDRY WELL OPERATIONSAlaska Oil & Gas Cons. Commiss'on Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other Ariöorage Alter Casing 0 Pull Tubing 0 Perforate New Pool D Waiver 0 Time Extension D Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: i ConocoPhillips Alaska, Inc. Development - 0 Exploratory 0 ¡qmf"{J~ ~ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-029-22195-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 88' 1 R-29 '1. Operations Performed: 8. Property Designation: Kuparuk River Unit 11, Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: 10. Field/Pool(s): Kuparuk Oil Pool measured 11368' feet true vertical 6886' feet measured feet true vertical 6276' feet Length Size MD 123' 16" 123' 5954' 9-5/8" 6042' 11243' 7" 11331' Plugs (measured) Junk (measured) Burst Collapse TVD 123' 4114' 6864' Measured depth: 10746-10786', 11053-11076', 11092-11112' true vertical depth: 6527-6548',6700-6714',6723-6735' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10866' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' PACKER; BAKER 'FB-1' PACKER; BAKER 'FB-1' PACKER pkr= 8764'; 10572'; 10844' sssv= NIP sssv= 521' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 87 349 95 387 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 Gas 0 WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil-Bbl 234 256 Casinq Pressure 1291 1309 TubinQ Pressure 247 223 WDSPLD Contact Brad Gathman/MJ Loveland @ 659-7224 Printed Name MJ .L~land / /' Tifle Problem Wells Supervisor Signature ~/ /~f i Phone 907-659-7224 Date /7 D~c 1s?L~ / ' KtSUM~ t5J-L DEC 2 1 2004 Form 10-404 Revised 04/2004 Submit Original Only 1 R-29 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1211212004IPurge N2 for BH weld. T/I/O = 0/0/0 Welded 3 pass seal weld on Brayden Head adapter. 12113/2004 State witnessed MIT-OA to 1800 psi passed, post BH weld. T/I/O = 0/0/0. Initial OA FL NS. Pumped 1.5 bbls of diesel down OA to pressure up to 1810 psi, OA pressure @ 15 minutes = 1700 psi, @ 30 minutes = 1650 psi. Pressured OA back to 1800 psi. Pressure @ 15 minutes = 1730 psi, @ 15 minutes = 1700 psi. Bled OA back down to 0 psi, BH weld did not show any signs of leaking. Final pressures; 0/0/0 uø ~,~~\:\\ . , . '. '-~'~ ~..... '-.'. ~~,~. .... .................~ ., "."tt-S"..... ", . " . -, .~, MEMORANDUM ) State of Alaska ') Alaska Oil and Gas Conservation Commission TO: Jim Regg 'V I ZI16(C4- P.I. Supervisor '\er:f, DATE: Tuesday, December 14,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC lR-29 KUPARUK RIV UNIT lR-29 b'f,...o1lf FROM: JCr Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv ~ Comm Well Name: KUPARUK RIV UNIT lR-29 Insp Num: mitJCr041213184858 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-22195-00-00 Permit Number: 191-094-0 Inspector Name: JCr Inspection Date: 12/13/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lR-29 Type Inj. TVD 5508 IA 0 1800 1730 1700 P.T. 1910940 TypeTest SPT Test psi 1377 OA 0 0 0 0 Interval OTHER PIF P Tubing 0 0 0 0 Notes: Wellhead welding repair. This producer had waiver for leak from wellhead to conductor. OA pressure test passed wi no problems witnessed. This was screw on braiden head Kuparuk Gen 4. Surface casing shoe @4114 TVD. SCANNED DEC ~!. 200¿¡ Tuesday, December 14,2004 Page 1 of 1 P , ,.LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 9, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1R-29 (191-094) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation treatment on the KRU well 1R-29. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 88 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 451' FNL, 5142' FEL, Sec. 20, T12N, R10E, UM (asp's 539830, 5990750) 1 R-29 At top of productive interval 9. Permit number / approval number 831' FSL, 1720' FWL, Sec. 21, T12N, R10E, UM 191-094/ At effective depth 10. APl number 50-029-22195 At total depth 11. Field / Pool 4725' FNL, 3042' FEL, Sec. 21, T12N, R10E, UM (asp's 547246, 5986521) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 1 1368 feet Plugs (measured) true vertical 6886 feet Effective depth: measured 11166 feet Junk (measured) fish @ 1512' true vertical 6767 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 123' 16" 230 sx AS I 123' 123' SURFACE 5954' 9-5/8" 1320 sx Type E cmt, 560 sx CIG 6042' 4114' PRODUCTION 11243' 7" 250 sx Class G 11331' 6864' Perforation depth: measured 10746'-10786', 11053'-11076', 11092'-11112' ' i ~"~'~"'C~/V~j,%. true vertical 6527'-6548', 6700'-6714', 6723'-6735' "~//~$kO~? .~~85~~'/' ~'4200/~ "~' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 10866' MD. Packers & SSSV (type & measured depth) BAKER 'FHL' PACKER @ 8764' MD; BAKER 'FB-I' PACKER @ 10572' MD; BAKER 'FB-I' PACKER @ 10844' MD; CAMCO 'DS' LANDING NIPPLE W/NO GO PROFILE @ 521' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 24 639 2 - 166 Subsequent to operation 67 528 178 - 246 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Signed ..;'.~.~, -.'.'~..¢~_~'_~,~ .~.~.~~.~/ Title Wells Team Leader Date ,,/ /' Michael Mooney ~ ' ~'~/ ~.-~"/ Prepared by Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 1 R-29 Event History 09/14/01 09/15/01 09/16/01 TAGGED FILL @ 11,066'RKB. PULLED 1" GLV @ 7531'RKB, MADED SEVERAL ATTEMPTS TO PULL GLV @ 5831'RKB UNSUCCESSFUL, PRE- FRAC SLICKLINE IN PROGRESS. [PT TBG-CSG] PULLED 1" GLV'S @ 3404',5831'RKB. SET 1" DV'S @ 3404',5831',7531'RKB. PRE-FRAC SLICKLINE IN PROGRESS [PT TBG-CSG] PUMPED 180 BBLS SEAWATER INTO CASING, SET 1.5" DV @ 8700'RKB, PT BOTH TUBING & CASING TO 3500# HELD GOOD, PULLED 2.81" XN PLUG @ 10,859'RKB, READY TO FRAC. [PT TBG-CSG] TREATING PRESSURE DUE TO MANDREL IN CASING LEAK STRADDLE - PRESSURE TOO HIGH DURING PAD ON FIRST FRAC ATTEMPT W/50# XL GEL- FLUSH JOB AWAY - REDESIGN JOB FOR 40# XL GEL AND 3 09/18/01 UNIT DOWN TO RE-WELD COILED TUBING [FCO, MAINTENANCE] 09/19/01 CLEANED FILL TO 11,180' CTM W/SLICK SEAWATER AND FLO-PRO GEL (EST. 80' OF RATHOLE) USING 1-3/4" JET-SWIRL NOZZLE. WASH PASSES MADE ACROSS GLM'S. WELL FREEZE PROTECTED TO 2500'+ W/DIESEL. [FCO] 09/21/01 BRUSH AND FLUSH TBG W/3" BRUSH, REMOVE FRAC SAND, DSPL 40 BBL DEISEL, PULLED 1.5" DV F/ 8710' RKB IN PROGRESS. [GLV] 09/22/01 INSTALLED NEW G/L DESIGN, SET 1" GLV'S @ 3385', 5815', 7529', 1.5" OV W/3/16" ORIFICE, @ 8700' RKB, IN PROGRESS. [GLV] 09/23/01 TAGGED FILL IN @ 11166' RKB EST. 54' RAT HOLE, COMPLETE. [TAG] Page 1 of I 10/8/01 PH.',-LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 May 24, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1R-29 (91-94 / 301-050) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on KRU well 1 R-29. If there are any questions, please contact me at 265-6434 or Pat Reilly at 265-6048. Sincerely, J. Trantham Drilling Engineering Supervisor Phillips Drilling JT/skad ORIOiNAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _X Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 88 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 451' FNL, 5142' FEL, Sec. 20, T12N, R10E, UM (asp's 539830, 5990750) 1 R-29 At top of productive interval 9. Permit number / approval number 831' FSL, 1720' FWL, Sec. 21, T12N, R10E, UM 91-94/301-050/ At effective depth 10. APl number 50-029-22195-00 At total depth 11. Field / Pool 4725' FNL, 3042' FEL, Sec. 21, T12N, R10E, UM (asp's 547246, 5986521) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 11368 feet Plugs (measured) true vertical 6886 feet Effective depth: measured 11241 feet Junk (measured) true vertical 6811 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 230 sx AS ~ 123' 123' SURFACE 4899' 9-5/8" 1320 Sx Type E cmt, 560 Sx 6042' 41 14' Class G PRODUCTION 8484' 7" 250 sx Class G 11331' 6864' Perforation depth: measured 10746'-10786', 11053'-11076', 11092'-11112' ' true vertical 6527'-6548', 6700'-6714', 6723'-6735' ~.: ! '~ : ' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 10867' Packers & SSSV (type & measured depth) Baker FHL 7"x4" pkr @ 8764', Baker FB-1 permanent pkr @ 10572', Baker FB-1 permanent pkr @ 10844' No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut - In Subsequent to operation 62 553 324 - 205 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __X Gas __ Suspended _ Service 17. I hereby ~ ertify that the foregoing is true and correct to the best of my knowledge. Questions? Call Pat Reilly265-6048 Signed n~arnC,-~(.,/~,~..~'~'--C_~f~..~¢4,' Title Drilling Engineering Supervisor Date O~~£~] '-~,~ James Tra ~ Prepared by Sharon AIIskp-Drake 26.,~-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~~ Rpt Date April 4, 2001 April 5, 2001 April 6, 2001 April 7, 2001 Operations Summary 1 R-29 Comments Trun key rig move. Wait on Nabors 19E to pass lB pad till 0230 hrs. Clean up around 1B-14 well site. Move out with rig @ 0230 hrs 6 mile move F/1B to 1R pad. Spot over well 1R-29 Berm up spot tanks. Accept rig @ 0830 hrs 4/4/2001. Pull VR plug. Had trouble pulling BPV. L/D down lubricator. R/U circulating lines. SICP 1440 psi SITP 1300 psi. PJSM w/Hot oil- APC truck drivers- Pad operator- Rig crew & Mud man on well kill Hot oil pumped 15 bbl's 170 deg Diesel down flow line to flow tank & 1R-05 flow line. Test line 250-2000 psi. Pump 140 deg diesel down tbg taking returns to 1R-05 flow line 120 bbls followed by 15 bbl sweep followed by 450 bbl's 100 deg 8.5 ppg sea water. Freeze protect flowline w/25 bbl's diesel. Continue pumping 10.3 ppg mud taking returns to rig tanks. After 10.4 mud back to surface Shut in well monitor pressures. SITP 110 SICP 140. Weight up pits to 10.8 ppg and continue circulating for kill. POOH L/D 3 1/2" tbg. Camco spooled up control line. Recovered 31 of 32 control line SS bands. Continue POOH L/D tbg. BOLDS Pull 3 1/2" tubing hanger to rig floor up weight 104k. Circulate bottoms up. 75 spm @ 950 psi. Test BOP's Rams & Manifold to 250-4000 psi Hydril 250-3000 psi. Pull BPV. N/U 11" 5M triple gate BOPE. Function test rams. Set test plug. Monitor well & pump dry job. Monitor well Dead. R/R circulating lines. Displace well w/10.8 ppg mud @ 3 bpm 520 psi Continue to build 100 bbl's volume & increase mud weigth f/10.4 to 10.8 ppg Wait on FMC 1/2 hr Install BPV. N/D Tree. POOH w/fish Work over top of fish @ 10573' work overshot over 3 1/2" tbg stub 4' to 10577'. Soft trip Jars & straight pull up to 165k seal assy came free work up hole. Pressure up to 400 psi saw seals come out of PBR Circulate bottoms up and pump dry job. Circulate bottoms up @ 3.5 bpm 920 psi. On bottoms up fine sand over shakers. Slip and cut drilling line while circulating. P/U & M/U Fishing BHA #1 overshot & jars. RIH on 3 1/2" Dp off rack. to 10568' Circulate last two singles down. Up Wt 135k Dn Wt 85k Set test plug. Test lowed pipe rams 250-4000 psi. Pull test plug Install wear ring Drift 6.375". Off load tubing & Jewelry. Clean up rig floor. Continue POOH I_/D 3 1/2" 9.3# J-55 Eue Tbg. Total of 336 joints + 16.48" cut off. 1 SSSV- 6 3 1/2" X 1" KBUG GLM's- 2 3 1/2" X 1 1/2" Otis 'LB' GLM's w/pups. FMC Gen IV tbg hanger. Tubing f/jr# 287 covered in scale w/corrision of collars on Iow side. Load 50 jts 3 1/2" DP + 12 4 3/4" Dc's & Fishing tool. Strap and rabbit same. Clear floor- Strap & tally BHA #2 to Fish Baker PBR & 'HB' pkr. RIH to 10567'. up Wt 145k Dn Wt 80k. POOH No fish Released spear. CBU No gas cut mud P/U Jt #216 ingauge fish @ 10594' Soft trip jars. Straight pull to 245k work pipe w/o jaring. Packer not releasing. Started jaring @ 50k over string weight and worked up to 100k over. Packer did not release. Started torqueing string up to 10000 fi/lb and Continue POOH w/Fish #1 I cut off 3 1/2" tbg 15.10' + 6' pup & Baker 4" Seal assy 12.80' ORIGtN, L Operations Summary 1 R-29 April 8, 2001 April 9, 2001 April 10, 2001 April 11, 2001 April 12, 2001 Redress spear. Load pipeshed w/2 4 3/4" Dc's 15 jts 3 1/2" HWDP & accelerator jar. P/U Same Monitor well. Blow down top drive. POOH w/o dry job. Hole fill good. Continue POOH w/Fish #1 on 3-1/2" DP to 9116'. Improper hole fill. Service rig. Raise mud weight f/10.8 ppg to 11.1 ppg 3.5 bpm 590 psi RIH to 10560' Working fish up & down-attempting to break loose-work from 10K over to 20 K over- Circ. while working fish. RIH w/Fishing tools-Tag fish @ 10710 DPM-latch fish. Change crews-service top drive & rig. Lay down fish-recoveredBaker PBR-HB Packer-2 its. 3 1/2" tbg.-2 3 1/2" pups-1 GLM- 1 cut jt. of tbg. Break circ.-engage fish & jar on same-Fish loose. RIH w/fishing tools. Load-strap-pickup & make up BHA-Service top drive. CBU-monitor well-Break down top drive. Pump dry job & poh w/fish slow. Make up bha & rih to 10806'. POH w/fish. Slip & cut drlg. line. CBU-recovered lots of sand & gas cut mud on bottoms up. Circ over fish-latch same @ 10808' & work free. Finish poh w/fish. Change crews & service rig. POH w/fish. CBU-some sand on bottoms up. Working fish from 20k to 50k-slight jarring while bleeding down jars-fish come loose @ 50k over. Lay down fish-recovered 2 cut off jts-2 blast ring jts. & pup. Pump dry job-poh w/milling assembly. Slip & cut drlg. line. Pull 5 stands & monitor well. CBU @ 6 BPM-clean up hole. Break circ.-tag packer @ 10998' dpm & mill same & push to 11013 top of packer.. Crew change & service rig. Make up bha for packer mill. Lay down fish-recovered I cut jt. 3 1/2" tbg.-5 jts. 3 1/2" 9.3# tbg.-2 3 1/2" pups-AVA nipple-& seal assembly. POH w/fish. RIH to 10951' Make up bha #8. Circ.-drop ball & work reverse basket. 2400#-1.5 times-pump pill. POH w/fish. RIH to 11029'. Break circ.-tag fish @ 11019'-catch same & pull 20k over string wt.-fish came loose- pull up 90'. Lay down milling assembly & pick up spear assembly. CBU & pump dry job. RIH w/spear to 11013'. Make up junk baskets & reverse basket & rih. Operations Summary 1 R-29 April 13, 2001 April 14, 2001 April 15, 2001 April 16, 2001 April 17, 2001 April 18, 2001 Break down bha-clean junk baskets & reverse basket-recovered large pieces of packer slips. Pump pill & poh. Lower boot failure on riser-Repair same. Retrieve storm packer & lay down same. Nipple up bope. Set test plug & weekly bope test 250-3500#-pull test plug & set wear ring. Nipple down bope. Slip & cut drlg. line. Set storm packer 40' below rotary & test same to 1000#. POH 40 stands w/reverse basket & bha. Circ. @ 90 spm 5' off bottom. Remove & replace primary & secondary well head packoff,s & tbg. spool-test to 2400#. PJSM-Rig up sws-make up Baker FB-1 permanent packer & rih on 'E' line-set same @ 10844'. Poh & rig down sws. Make up retrieve 'a' matic Baker packer & rih to 10670'. Lay down bha-clean junk baskets-recovered 3 small pieces junk. Circ. & work reverse basket-pump pill. RIH w/reverse basket to 10990'. POH w/reverse basket. Make up retrievable bridge plug & retriev-a-matic test packer & rih. POH for retrievable bridge plug. Inspect retriev 'a' matic packer & send to baker for redress-cut & slip drlg. line-service rig & crown-fire drill-unload baker tools. Set packer @ 10670'-test csg. moving packer up hole-found leak in csg. @ 9410' to 9440'. RIH w/packer to 10670'. CBU-sevice rig & top drive. PJSM-rig up sws & run USlT log from 10820' to 8000'. Finish trip in hole w/retrievable bridge plug & retrieve 'a'-matic packers to 10720'. Set RBP @ 10720' & test csg. for leaks by moving packers-test from 10720 to 9400'. Found leaks @ 10615' & 9438'. Circ.-condition mud after testing-pump dry job. POH & lay down packers. Sting in to packer & no-go @ 10844-space out 1' & drop ball to set packer. Rig up handling tools-make up FB-1 7" X 3.5" packer w/completion & run in hole on 3.5" dp. Finish running USlT log. (12820' to 8000'.) Evaluating logs for completion. RIH w/3 1/2" Completion tbg and jewelry Total of 337 jts of 3 1/2" 9.3# L-80 Eue 8rd tbg Change out lifting and turning equipment to run 3 1/2" completion. Continue to L/D 3 1/2" DP and HWDP. Tag lower pkr @ 10859' Space out to set 'FHL' Pkr @ 8764' & Iowwer seal assy 1' from fully inserted. Set packer w/2500 psi and 30 min Csg test. O.K. POOH L/D 3 1/2" DP. CBU and Pump dry job. Continue to Set Baker 7" X 3 1/2" 'FB-I' Pkr @ 10572'. Release from Pkr. Service rig and top drive. RIH w/1 1/2" Kickover tool to pull Circulating shear valve @ 8700' Operations Summary 1 R-29 April 19, 2001 April 20, 2001 Due to 7" casing wear. R/U Howco wireline unit to pull I 1/2" casing to tubing shear valve @ 8700'. Pull BPV install test plug. Test tree 250-5000 psi O.K. N/U Tree. Test 250-5000 psi Bleed off pressure after 2500 psi csg test to 0 psi. Increased annulus pressure to 3100 psi to shear circulating valve @ 8700'. Did not shear. Pull 25k over string weight shear out PBR @ 8751'. Space out w/10 pup and install tbg hanger. Land in tbg spool N/D BOPE. Shiped 250 bbls to mud plant for next well. 120 bbls on vac truck waiting for displacement of well bore. Reland tbg hgr. Full BOPE Test. 250-4000 psi Pull out PBR @ 8751' Up Wt 80k. Circulate and worm well bore. Mud returns 38 deg @ 3 bpm 630 psi. Pull BPV. Shell test BOPE. 250-4000 psi Set BPV. N/D tree. N/U 11" 5M triple gate BOPs. Wireline RIH 1" kickover tool to pull DV @ 7530'. Two trips unable to latch on to valve. R/D wireline. R/U Circulating lines. Pressure up on 7"X 3 1/2" Annulus to 3100 psi w/tbg open. Still unable to shear valve out. Continue Running Howco wireline trying to pull RP valve @ 8700' total of 5 runs. Unable to latch on to valve. R/U Pump down tbg & pressure up to 3500 psi w/annulus open. Chear valve did not open. Checking that Camco had not installed wrong type chear valve. N/U Tree. Pull BPV install Test plug. Test packoff 250-5000 psi. Test tree to 250- 5000. Pull test plug. Set BPV. N/D BOP Stab into Baker PBR @ 8750'. Test tbg to 2500 psi for 15 min. Pressure tbg up to 3150 psi Shear out DCR valve tbg to annulus. Land hanger RILDS. Circulate pipe volume 80 bbl's 4 bpm @ 750 psi Check space out O.K. M/U space out pup - tbg hanger w/Landing jt.. Continue to stand back 3 1/2" tbg. Change seals on Baker Seal assy. Service rig & top drive. POOH and stand back 3 1/2" tbg L/D all GLM's. Slip and cut drilling line. Check crow-o-matic. Continue weekly BOPE test 250-4000 psi. Displace Mud f/well bore @ 8700' 82 spm 1750 psi w/Sea water by pumping down annulus taking returns f/Tbg. Followed by 90 bbls of diesel for freeze protection and 'U-tube to ballance @ 2570'. SITP 10 psi SICP 10 psi RIH w/3 1/2" 9.3# L-80 Eue tbg out of derrick and pick up new GLM's Install BPV. R/D circulating lines. Move off well. Clean up around well head and location. Release rig for turn key rig move to 2A pad. @ 0000 hrs 4/20/2001. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Variance _ Pedorate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 454' FNL, 136' FWL, Sec. 20, T12N, R10E, UM At top of productive interval 831' FSL, 1720' FWL, Sec. 21, T12N, R10E, UM At effective depth At total depth 557' FSL, 2241' FWL, Sec. 21, T12N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB feet) RKB 88 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 R-29 9. Permit numb. e~/approval number 91-94 10. APl number 50-029-22195-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary TOtal depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4899' Production 8484' Liner 11368 feet Plugs (measured) 6886 ~'/ feet 11241 feet Junk (measured) 11211' 6811 feet Size Cemented Measured Depth True vertical Depth 16" 230 sx AS ~ 123' 123' 9.625" 132o sx Type E & 560 sx Class G 6042' 41 14' 7" 250 sx Class G 11331' 6864' RECEiv :D Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 10746'-10786', 11053'-11076', 11092'-11112' ~R 0 8 2001 6527'-6548', 6700'-6714', 6723'-6735' Alaska 0il & Gas Cons. Commission Anchorage 3.5", 9.3#, J-55 @ 10626' MD, 3.5", 9.3#, L-80 from 10626'-11025', 2.875", 6.5#, J-55 @ 11038' Baker HB packer @ 10626', Baker 'D' Perm. Pkr @ 11017', Camco 'TRDP-4A' SSSV @ 1807' 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch __ Schematic __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic -- 14. Estimated date for commencing operation March 20, 2001 16. If proposal was verbally approved Name of.approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended __ Service __ 17. I hereby c~¢rtify that the foregoing is true and correct to the best of my knowledge. Signed ,_~ ~ ~/~uc.t~ Title: Drilling Engineering Supervisor Questions? Call Pat Reilly 265-6048 Date 09 ~ '~¢--~t Prepared by Sharon AIIsup-Drake ~ FOR COMMISSION USE ONLY ~,, ~.~!~,,..~ Conditions of apProval: Notify Commission so representative may witness .~(:;)~b ~, ~;:~'~'~-~ ~\~r~ Approval no ~ Plug integrity __ BOP Test ~, Mechanical Integrity Test __ Approved by order of the Commission Location clearance__ Subsequent form required 10- ~"~'~ Commissioner Form 10-403 Rev 06/15/88 · Date SUBMIT IN TRIPLICATE 1 R-29 Workover Schematic 9-5/8" 36¢ J-55 @ 6,042' 3ol/2" 5M FMC Gen IV tubing hanger with 3.5" L-80 9.3# EUE 8rd Mod pin down. ( or existing 4" DSS-HTC 3' pup w / XO to 3-1/2", L-80, 9.3~ EUE 8rd Mod Tubing- contingency) XO 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing / 4" DSS-HTC (contingency) 3-1/2", L-80, 9.3ff EUE 8rd Mod Tubing to the tubing hanger. 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. 3-1/2", L-80, 9.3~ EUE 8rd Mod Tubing to the 'DS' Nipple with 3-1/2" x 1" Camco 'KBUG' GLM's w/DV's spaced out as follows. GLM # M__.~D TVD I TBD TBD 2 TBD TBD 3 TBD TBD 4 TBD TBD 5 TBD TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. 3-1/2" x 1-1/2" 'MMG' GLM w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. I Joint 3-1/2", L-80, 9.3~ EUE 8rd Mod Tubing. C1 Sand Perfs 10,746'-10,786' MD 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'FHL' Retrievable Packer @ 10,626'. Minimum ID through the packer 3.00". 3-1/2", L-80, 9.3ff EUE 8rd Mod Tubing to Packer. 3-1/2" x 1-1/2" 'MMG' GLM w/ 6' L-80 handling pups installed on top and bottom of mandrel. 3-1/2", L-80, 9.3~ EUE 8rd Mod Tubing to GLM. 3-1/2, L-80, Special Clearance BTC Mod Tubing w/Rickert Blast Rings. XO coupling to 3-1/2" EUE 8rd on top joint. +/- 50' of Blast Rings to cover all C-Sand Perfs w/at least 5' ovedap above & below perfs. 3-1/2", L-80, 9.3# EUE 8rd Mod Pup Joints as required to begin blast rings 5' below bottom C-Sand Perforations (XO coupling to 3-1/2" BTC Mod on top). Baker Sliding Sleeve with Camco 2.81" DS Profile @ 11,007' ( Lock has 2.856" NO-GO dng). 6' Pup Joint 3-1/2", L-80, 9.3~ EUE 8rd Mod Tubing. Baker 'GBH-22' Locator Seal Assembly (5' seals w/Iocator). A4, A3 Sand Perfs ~ 11,053' - 11,112'~ MD 7" 26# J-55 @ 11,331' Fill Baker 'FB-I' Hydraulic Set Permanent Packer w/5' Seal Bore Extension @ 11,017' (4" ID through SBE - 2.985" rain bore through seals). 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Halliburton XN Nipple @11,032' w/2.75" No-Go Profile 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" Shear Out Sub w/ WL Re-entry Guide. Tubing tail @ 11,038' MD. PBTD @ 11,067'- Fill tagged on 8/26/97 RECEIVED PBTD @ 11,241' - Actual 7" casing PBTD to FC. TD @ 11,368' MAR 0 8 2001 Alaska 0il & Gas Cons. C0mmissic Anchorage 3/7/01 PJR KRU 1R-29 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: ~ ~,~ 1. Get separate bottom hole pressure readings for the C and A sands. 2. RU Slick Line Unit. RIH and tag bottom. Dummy off all GLM's. 3. Place sand plug across A sand perfs. 4. RU Slick Line, RIH pull GLM valve @ 10,527' and leave open. RU E-line and chemical cut the tubing above and below the blast ring section, and in the center of the first full joint above the top seals. 6. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with seawater. Displace tubing and annulus with seawater. SI well and monitor pressure to determine kill weight. 3. Load pits with kill weight mud. Displace tubing and annulus with kill weight mud through open bottom GLM. SI well and monitor pressure to ensure well is dead. Set BPV. 4. ND / NU and test B OPE. 5. Screw in landing joint. POOH laying down 3.5" tubing and spooling up SSSV control line. Lay down SSSV and continue POOH laying down 3.5" tubing and jewelry. 6. Load, strap and drift 3-1/2" drill pipe. 7. RIH and fish top seals. 8. RIH and fish retrievable packer 9. RIH and fish blast ring section. 10. RIH and fish bottom seals. 11. RIH and mill up Baker D permanent packer and push it to bottom. 12. RIH and fish packer. 13. RIH with cleanout assembly. 14. Cleanout to below bottom of C sand perforation, and POOH laying down 3-1/2" drill pipe. 15. RIH with bottom packer assembly on E-line and set packer. 16. Load, strap and drift 3.5" tubing. 17. RIH with 3.5" selective completion assembly as per schematic. 18. Spaceout with tubing pups and land tubing hanger. 19. Pressure test tubing and annulus. 20. ND / NU and test tree. 21. Displace well to seawater and freeze protect with diesel to +\- 2000' TVD. P JR 7-Mar-01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 E E PL E W M A TE R IA L U N D E THIS MARKER R AOGCC Geological PERMIT DATA T 91-094 CBT L 91-094 CBT-POST SQZ L 91-094 CDN L 9i-094 CDR L 91-094 CET L 91-094 CET-POST SQZ L 91-094 407 R 91-094 DAILY WELL OP R 91-094 SURVEY R 91-094 5127 T Individual Well Materials Inventory DATA_PLUS Page: 1 Date: 12/16/93 SCALE DATE_RECVD R1,10000-11178 5 R2,9990-11133 5 R1,6042-11368 2/5 R1,6042-11368 2/5 R1,10000-11198 5 R2,9990-11156 5 COMP DATE: 01/03/92 08/09/91-01/03/92 SS DIRECTIONAL OH-CDR/CDN,5939-11368 09/16/1991 09/16/1991 09/13/1991 09/13/1991 09/16/1991 09/16/1991 02/25/1992 02/25/1992 02/25/1993 11/27/1991 Are dry ditch samples required? yes 0~ And received?~s no yes /~o~ Ananlysis & description rec.~. Was the well cored? Are well tests required?~ yes Well ±s in compliance Comments yes ~o ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ¢/--,'~-K' ,)'2. -~- Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-03 LIS Tape and Listing 1 - 2 7- 9 2 92095 3 R- 1 2 D LIS Tape and Listing 2 - 4 - 9 2 9 21 1 5 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY - RECEIVED WITH THIS ONE. THANK YOU. 1R-17 I R-20 1 R-21 I R-22 I R-23 1R-24 1 R-26 1R-27 I R-29 Receipt LIS Tape and Listing 9 - 1 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 9 - 9 - 9 1 9 2 0 26 LIS Tape and Listing I 0 - 6 - 9 1 9 2 0 26 LIS Tape and Listing 9 - 2 4 - 9 1 9 2 0 26 LIS Tape and Listing 1 0 - 2 2 - 91 9 2 0 26 LIS Tape and Listing 7 - 3 0 - 9 1 9 20 26 LIS Tape and Listing 7 - 1 8 - 91 9 2 0 26 LIS Tape and Listing 8 - 3 1 - 9 1 9 2 0 26 LIS Tape and Listing 8 - 1 4 - 9 1 9 20 2 6 LIS Tape and Listing 6 - 1 9 - 9 1 9 2 0 26 LIS Tape and Listing 1 I - 1 1 - 91 9 20 26 LIS Tape and Listing 1 I - 1 7 - 91 9 20 26 LIS Tape and Listing 5 - 9 - 9 1 9 2 0 26 LIS Tape and Listing 5 - 1 9 - 91 9 20 26 LIS Tape and Listing 5 - 2 6 - 9 1 9 20 26 LIS Tape and Listing 6 - 3 - 9 1 9 2 0 26 Acknowledged' -- Date' R-E-6E--I-V E D FEB 2 8 1992. DISTRIBUTION: Lynn Goettinger A~aska 0il & Gas Cons. Commission Anchorage State of Alaska /; ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed.copy of this transmittal. ~//'-'1'~/~ 3Q 03 v// ' LIS Tase and Listing ¢'~ '- ~ 3 R-' 1 2 O v/'' LIS Ta~e and ~isting ql-t,~Y' I R-1 7 LIS Ta2e and Listing ¢ / -"/°°¢ 1 R - 2 0 LIS Ta ¢/i_~1.3 1R-21 LISTa ¢//...-/~, ~' 1 R - 2 2 LIS Ta ¢/'1..-.~ ¢ ! 1 R 2 3 ,./' LIS Ta g/-' ~3 1 R- 2 4 LIS Ta ..., ,~ 1 R-26 LIS Ta ,¢/Y~.~ ~~- 1 R-27 LIS Ta 'i/-.-¢¢, 1 R-2 LIS Ta ¢¢~ USTa ¢'/-I~.I' 2M-21 LIS Ta ?/-- / 32- 2 M- 1 9 LIS Ta~ 'f I--~.~ 1 L- 2 3 LIS Ta ~1-6~ 1 L-24 LIS Ta~ ~/_?o~, 1 L- 25 LIS Ta~ ¢/-~ ~ ? LISTa se and Listing se and Listing ~e and Listing 2e and Listing 2e and Listing 2e and Listing ~e and Listing ~e and Listing ~e and Listing ~e and Listing ~e and Listing 2e and Listing ~e and Listing )e and Listing ~e and Listing Receipt Acknowledged: Please acknowledge receipt and return 1 -27-92 92O95 2-4-92 92115 9- 1 9- 91 92026 9-9-91 92026 1 0-6-91 92026 9-24-91 92026 1 0-22-91 92026 7-30-91 92026 7-1 8-91 92026 8-31 -91 92026 8-1 4-91 92026 6-1 9-91 92026 11-11-91 92026 1 1 -1 7-91 .92026 5-9-91 92026 5- 1 9- 91 92026 5-26-91 92026 6-3-91 92026 Date' ...RECEIVED FEB 2 5 1992_ DISTRIBUTION: Alaska 0118, Gas Cons. Commission Ancherage Lynn Goettinger State of Alaska ,~"~'--~ STATE OF ALASKA '--' 0 ~ I ~~ ~ t AU~UKA OIL AND GAS CONSERVATION coMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~] GAS [--] SUSPENDED [~] ABANDONED [~] SERVICE r'--] 2 Name of Operator ARCO Alaska, Inc 3 Address P.O. Box 100360, Anchora~, AK ~510-0~0 4 Location of well at surface 454' FNL' 136' FWL' SEC 20' T12N'R10E' UM ! ~/~_.~___2..=i At Top Producing Interval 831' FSL, 1720' FWL, SEC 21, T12N, RIOE, UMW: At Total Del~h 557' FSL, 2241' FWL, SEC 21, T12N, RIOE, UM 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 88', PAD 45' GL I ADL 25636, ALK 2569 12 Date Spudded 08/08/91. 17 Total Depth (MD+TVD) 11,368' MD, 6886' TVD 22 Type Electric or Other Logs Run Permit Number 91-94 8 APl Number 50-029-~2195 9 Unit or Lease Name KUPARUK RIVER 10 Well Number 1 R-29 11 Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 16 No. of Completions 08/14/91. I 01/03/92. I NA feet MSL 1 18 Plug Back Depth (MD+TVD) 119 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 1,241'MD. 6811'TV JE~inhoieell,211'(W~.M) YES [~ NO r-] I 1807, feetMD 1700' APPROX CDN/CD F:VG R/CET/CBT/GYRO 23 CASING SIZE WT. PER FT. 16' 62.5# H-40 9-5/8" 36fl J-55 I GRADE 7" 26fl J-55 24 Perforations o 25 CASING, LINER AND CEMENTING RECORD SE"I-I'ING DEPTH MD TOP BOTI'OM HOLE SIZE OEMENTING RECORD SURF 123' 24' 230 SX ASI SURF 6042' 12-1/4' 1320 SX TYPE E, 560 SX CLASS SURF 11,331' 8-1/2' 250 SX CLASS G ~en to Production (MD+TVD of Top and Bottom and interval, size and number) 10,746'-10,786' W/4-1/2' CSG GUN @ 12 SPF MD 6526'- 6548' TVD 6700'- 6713' TVD 6722'-6734' TVD 11,053'-11,076' W/4-1/2' CSG GUN @ 4 SPF MD 11,092-'11,112' W/4-1/2" CSG GUN @ 4 SPF MD AMOUNT PULLED TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2' 9.3#, 2-7/8" 6.5# 11,016', 11,038' 10,626', 11,017' !26 ACID, FRACTURE,* CEMENT SQUEEZE, ETC iDEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED '11,104'-11,112 I 14 BBLS CMT CLASS G '10,992'-11,000' 9 BBLS CMT CLASS G '10,950'-10,952' 17 BBLS CMT CLASS G * 10,630-10,632' 27.5 BBLS CMT CLASS G 27 Date First Production Date of Test Hours Tested Casing Pressure Flow Tubing Press. PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR OIL-BBL GAS-MCF TEST PERIOD CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE WATER-BBL WATER-BBL CHOKE SIZE / GAS-OIL RATIO 28 CORE DATA Brief description o~ lithology, porosity, fractures, apparent dips and pmsenca of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CCNTINUED ON REVERSE SIDE Submit in duplicate ~CGIC ~ . FORMATE)N TESTS I NAME I Include interval tested, pressure data, all fluids recoverd and gravity, Ivr:As. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 10,640' 6470' NA KUPARUK C BOTTOM 10787' 6548' KUPARUK A TOP 11024' 6683' KUPARUK A BO-FI'OM 11167' 6767' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed .... .~, X' ~ Tit I e AREA DRELI',~ 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 leve', (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: 1R-29 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25636 ALK 2569 API: 50-029-22195 PERMIT 91-94 APPROVAL: ACCEPT: 08/08/91 SPUD: 08/08/91 RELEASE: 08/16/91 OPERATION: DRILLING RIG: POOL 7 AFE: AK5971 WI: 55.252072 08/09/91 (1) TD: 1350' (1350) SUPV:KKL 08/10/91 (2) TD: 5000' (3650) SUPV:KKL 08/11/91 (3) TD: 6065'(1065) SUPV:KKL 08/12/91 ( 4) TD: 6065'( SUPV:KKL o) 08/13/91 ( 5) TD: 8875' (2810) SUPV:KKL 08/14/91 ( 6) TD:10760' (1885) SUPV:KKL 08/15/91 ( 7) TD:11368' ( 608) SUPV:KKL DRLG AT 1350' MW: 9.1 VIS: 72' MVE RIG FROM 1R-24 TO 1R-29. ACCEPT RIG AT 1100 ON 8/8/91. NU DIVERTER & FUNCTION TEST. PU BHA. ORIENT MWD. DRLD 123'-266'. KICK OFF AND DRILL TO 1350' ADT 8.75 HRS. DAILY:S73,251 CUM:$73,251 ETD:S73,251 EFC:$1,840,000 DRLG 12-1/4" HOLE AT 5000' MW: 9.3 VIS: 49 DRLD 1350'-2586'. ADT 5 HR. CBU. POH. CHANGE BIT AND BHA. DRLD 2586'-5000'. ADT 9.75 HR. DAILY:S65,917 CUM:$139,168 ETD:S139,168 EFC:$1,840,000 POH FOR 9-5/8" CSG MW: 9.7 VIS: 48 DRLD 5000'-6065'~ ADT 8.5 HR. CBU. POH TO HWDP. HOLE SWABBING FROM 2066'-1616' RIH. TIGHT SPOT FROM 1650'-1900'. WASH & REAM THRU TIGHT SPOT. RIH TO 6065'. CIRC & COND MUD. POH TO RUN 9-5/8" CSG. DAILY:S56,172 CUM:$195,340 ETD:S195,340 EFC:$1,840,000 TESTING BOP MW: 9.6' VIS: 41 POH. RAN 142 JTS 9-5/8" 36# J55 BTC CSG. FS @ 6042' CMTD W/1320 SX PERMAFROST E W/ 1/4# FLOCELE AND 560 SX CL G W/ 1/4# FLOCELE AND 2% CACL. RECIP CSG. 90 BBL CMT BACK TO SURF. BUMPED PLUG W/2000 PSI. ND DIVERTER. NU 11-3/4" BTC X 11" 3M BRADENHEAD. NU BOP & FUNCTION TEST. DAILY:S230,426 CUM:$425,766 ETD:S425,766 EFC:$1,840,000 DRLG AT 8875' MW: 9.3 VIS: 36 TEST BOP. PU BHA, TEST LWD TOOLS. RIH. TAG CMT STRINGERS AT 5930'. DRLD FC, SOFT CMT. TEST CSG TO 2000 PSI. DRLD FS & 10' NEW HOLE. CIRC. TEST FORM TO 12.5 PPG EMW. DRLD 6075' TP 6342'. ADT 2 HRS. WORK ON TOP DRIVE. DRLD 6342'- 8875'. ADT 8.5 HR. DAILY:S52,879 CUM:$478,645 ETD:S478,645 EFC:$1,840,000 DRLG AT 10760' MW:10.2 VIS: 38 DRLD 8875'-10367'. ADT 9 HR. CBU. SHORT TRIP TO 9-5/8" CSG SHOE. NO PROBLEMS OR TIGHT SPOTS. RIH. DRLD 10367'-10760' ADT 7.25 HR. DAILY:S61,325 CUM:$539,970 ETD:S539,970 EFC:$1,840,000 CIRC & COND MUD MW:10.2 VIS: 38 DRLD 10760'-11368'. ADT 13.5 HR. CIRC BU. SHORT TRIP. CIRC FOR 7" CSG. TOH. HOLE TIGHT AND SWABBING. TIH. CIRC & COND MUD. DAILY:S57,481 CUM:$597,451 ETD:S597,451 EFC:$1,840,000 WELL: 1R-29 OPERATION: DRILLING RIG: POOL 7 08/16/91 (8) TD:l1241' ( 0) SUPV:JRR 08/17/91 ( 9) TD:l1241' ( SUPV:JRR o) PAGE: 2 BUMP PLUG 7" CMT JOB 7"@11330' MW:10.4 VIS: 39 CIRC & COND MUD. TOH. RAN 126 JTS 7" 26# J-55 BTC CSG + MARKER JT + 143 JTS 7" 26# J-55 BTC-MOD CSG. FS @ 11331' CIRC @ SHOE W/ FULL RETNS. PMP 10 BBL ARCO PREFLUSH, 35 BBL SPACER, 250 SX (54 BBL) CLASS G CMT W/ 3% CFR3, 0.23% HR5 0.5% BENTONITE, 3% CAL SEAL, 0.6% LAP-i, 0.02 GPS 434B @ 15.5 PPG (1.23 YLD) DISPL W/ 429.5 BBL 10.2 PPB NACL/NABR BRINE. BUMPED PLUG. RECIP TIL PACKED OFF W/ CMT AT SHOE. HAD NO RETNS BUT PRESS INCREASE INDICATED CMT IN CSG ANN. FLOATS HELD. CIP 0600 8/16/91. DAILY:S345,369 CUM:$942,820 ETD:S942,820 EFC:$1,840,000 RIG RELEASED-MOVE TO 1R-27 7"@11330' MW: 0.0 VIS: 0 START ND BOP. ANNULUS FLOWING BACK MUD-200 PSI. SI & MONITOR PRESS. BLEED MUD OFF BACKSIDE. (LOST CIRC ZONE FLWG MUD BACK). ND BOP. SET SLIPS. NU TBG HEAD. TEST PACKOFF TO 3000 PSI. FREEZE PROTECT ANNULUS W/ 80 BBL DIESEL. RIG RELEASED 1900 8/16/91. DAILY:S29,416 CUM:$972,236 ETD:S972,236 EFC:$1,840,00 SIGNATURE: ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: 1R-29 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25636 ALK 2569 API: 50-029-22195 PERMIT 91-94 APPROVAL: ACCEPT: 12/21/91 SPUD: RELEASE: 01/03/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK5971 WI: 55.252072 12/22/91 (10) TD:l1241 PB:11242 SUPV:SS/GB 12/23/91 (11) TD:l1241 PB:11242 SUPV:SS/GB 12/24/91 (12) TD:l1241 PB:11242 SUPV:SS/GB 12/25/91 (13) TD:l1241 PB:11242 SUPV:SS/GB 12/26/91 (14) TD:l1241 PB:11242 SUPV:SS/GB 12/27/91 (15) TD:l1241 PB:11242 SUPV:DB/SW RD SWS 7"@11330' MW:ll.2 NaCl/Br ACCEPT RIG @ 1400 HRS 12-21-91· Nil AND TEST BOPE. RU SWS AND SHOOT SQUEEZE PERFS F/11104'-11112' AND 10992'-11000". MADE GAGE RING AND JUNK BASKET RUN. SET BP @ 11122'. GIH W/ RETAINER. HUNG UP AT 5550'. COULD NOT WORK LOOSE. SET SAME. POH W/ WL. PREPARE TO GIH W/ BIT. DAILY:S32,765 CUM:S1,005,001 ETD:SO EFC:$2,845,001 PREPARE TO GIH W/ SCRAPER. 7"@11330' MW:ll.2 NaC1/Br GIH W/ 6-1/8" BIT. TAG RETAINER @ 5572'. DRILLED UP RETAINER AND PUSH TO BOTTOM. POH. RU SWS AND MAKE GAGE RING JUNK BASKET RUN. COULD NOT GET PAST 9850' SUSPECT RUBBER FROM RETAINER. POH. RD SWS. PREPARE TO MAKE BIT AND SCRAPER RUN. DAILY:S61,388 CUM:$1,066,389 ETD:SO EFC:$2,906,389 GIH W/ STINGER ON DP 7"@11330' MW:ll.2 NaCl/Br MADE BIT AND SCRAPER RUN. RU SWS AND MADE GAGE RING JUNK BASKET RUN. SET DOWN AT 10700'. WORKED JB F/ 11100-10000' SEVERAL TIMES. POH. JB CLEAN. PU EZSV AND SET SAME AT 11090' WLM. POH AND RD SWS. MU STINGER AND GIH ON 3-1/2" DP. DAILY:S44,858 CUM:$1,111,247 ETD:SO EFC:$2,951,247 POH 7"@11330' MW:10.3 NaCl/Br RIH WITH STINGER AND TAG EZSV @ 11081'· ATTEMPT TO BREAK CIRCULATION BEHIND CASING AND OUT UPPER SQZ PERFS W/O SUCCESS. ESTABLISH INJECTION RATE AND SQZ 75 SX 'G' CEMENT BELOW EZSV. UNSTING F/ EZSV AND REVERS OUT. SPOT 16 BBS 'G' CMT ON TOP EZSV AND SQZ UPPER SET OF PERFS. WOC 8 HRS. PRESSURE BLED F/ 1800 PSI TO 350 PSI· POH W/ STINGER. DAILY:S109,713 CUM:$1,220,960 ETD:SO EFC:$3,060,960 WOC 7"@11330' MW:10.3 NaCl/Br FPOH W/ STINGER· RU SWS AND MADE GAGE RING RUN TO TOC = 10730' SET EZSV @ 10650' WLM. SHOOT SQZ HOLES F/ 10630-~2' @ 4 SPF. RD SWS. GIH W/ OE DP. CBU. RU HOWCO AND ESTABLISH INJECTION RATE. MIX AND SPOT 32 BBLS 'G' CMT ON EZSV. PU ABOVE CMT AND SQZ 27.5 BBLS CMT INTO PERFS. HOLD PRESSURE ON CMT AND WOC. DAILY:S83,025 CUM:$1,303,985 ETD:SO EFC:$3,143,985 DRILLING CEMENT 7"@11330' MW:10.3 NaC1/Br FIN WOC. FINAL PRESSURE = 1450 PSI. POH AND PU BIT AND BHA. GIH AND TAG CMT STRINGERS @ 9974' DRILLED CMT TO 10571'. TEST CSG TO 1500 PSI FOR 15 MIN. LOST 75 PSI. DRLD STRINGERS TO 10615'. DRLD HARD CMT TO CIBP @ 10640' RETEST CSG TO 1500 PSI. LOST 25 PSI IN 15 MIN. DRLD UP CIBP. GIH TO TAG CMT STRINGERS @ 10755'. DRLD STRINGERS TO 10960'. DRLD HARD CMT TO 10988' · DAILY:S28,147 CUM:$1,332,132 ETD:SO EFC:$3,172,132 WELL: 1R-29 OPERATION: COMPLETION RIG: NORDIC PAGE: 2 12/28/91 (16) TD:l1241 PB:11242 SUPV:DB/SW 12/29/91 (17) TD:l1241 PB:11242 SUPV:DB/SW RUNNING BOND LOGS 7"@11330' MW:10.2 NaC1/Br DRLD HARD CMT TO 11079' CBU. TEST CSG TO 1500 PSI. LOST 190 PSI IN 30 MIN. DRLD JUNK AND EZSV. DRLD CMT OT 11109' CBU. RE-TEST CSG TO 1500 PSI. LOST 290 PSI IN 30 MIN. DR~D CIBP AND PUSHED JUNK TO BOTTOM, 11204' DPM. POH. RU SWS. GIH W/ CET-CBT. DAILY:S33,982 CUM:$1,366,114 ETD:SO EFC:$3,206,114 SQUEEZING CEMENT 7"@11330' MW:10.2 NaC1/Br MADE CET-CBT RUN W/ 1500 PSI PRESSURE. MADE GAGE RING RUN TO 11170'. HAD TO WORK PAST SEVERAL TIGHT SPOTS. SET CIBP @ 11010' WLM. PERF 10950'-52' @ 4 SPF. SET EZSV @ 10930' WLM. RD SWS. PU STINGER FOR EZSV AND GIH ON DP. STING INTO EZSV AND ESTABLISH INJECTION RATE @ 1 BPM AND 2600 PSI. MIX 100 SX 'G' CMT FOR SQUEEZE JOB. DAILY:S96,801 CUM:$1,462,915 ETD:SO EFC:$3,302,915 12/30/91 (18) TD:l1241 PB:11242 SUPV:DB/SW 12/31/91 (19) TD:l1241 PB:11242 SUPV:DB/SW 01/01/92 (20) TD:l1241 PB:11242 SUPV:DB/SW 01/02/92 (21) TD:l1241 PB:11242 SUPV:DB/SW POH 7"@11330' MW:10.2 NaC1/Br STING INTO RETAINER AND SQUEEZE AWAY 17 BBLS CMT INTO FORMATION. SD. SIP = 2400 PSI. UNSTING AND POH 6 SINGLES. REV OUT. REC'D 1.5 BBL CMT. TRIP FOR BIT. TAG TOC @ 10906'. TEST CSG TO 1500 PSI. LOST 30 PSI IN 30 MIN. DRLD FIRM CMT TO 10920' DPM. DRLD CMT RETAINER AND CMT TO 10970' DPM. TEST CSG TO 1500 PSI. LOST 60 PSI IN 30 MIN. DRILLED OUT CMT TO 11000' AND TAGGED CIBP. TESTED CASING TO 1500 PSI. LOST 210 PSI IN 30 MIN. DRLD CIBP AND PUSHED ALL JUNK TO BOTTOM @ 11198' DPM. CBU AND START TRIP FOR BIT AND SCRAPER RUN. DAILY:S54,698 CUM:$1,517,613 ETD:SO EFC:$3,357,613 POH 7"@11330' MW:10.2 NaC1/Br FPOH. TEST BOPE. MADE BIT AND SCRAPER RUN. FILTER BRINE WHILE ON BOTTOM. POH FOR PERFORATING. DAILY:S31,437 CUM:$1,549,050 ETD:SO EFC: $3,389,050 MAKING GAGE RING RUN 7"@11330' MW:10.2 NaC1/Br FPOH. RU SWS AND PERFORATE WELL WITH 4 GUN RUNS. MADE GAGE-RING AND JUNK BASKET RUN AND RECOVERED +/- 1/2 GALLON OF JUNK. MAKE SECOND RUN AT RPT TIME. DAILY:S36,355 CUM:$1,585,405 ETD:SO EFC:$3,425,405 MU TBG HGR 7"@11330' MW:10.2 NaC1/Br RE-RRUN GAGE-RING AND JUNK BASKET. SET PERMANENT PACKER AND 2-7/8" TAIL PIPE @ 11,005' WLM. TBG TAIL @ 11,026' WLM. RUN 3-1/2" X 2-7/8" COMPLETION ASS'Y. STAB INTO PERMANENT PKR. APPEARS THAT CIRCULATING CHECK VALVE IS LEAKING. SPACE OUT. MU TBG HGR. CALL OUT SLICKLINE UNIT. DAILY:S83,109 CUM:S1,668,514 ETD:SO EFC:$3,508,514 WELL: 1R-29 OPERATION: COMPLETION RIG: NORDIC PAGE: 3 01/03/92 (22) TD:l1241 PB:11242 SUPV:DB/SW RR @ 0100 HRS 1-3-92 7"@11330' MW:10.2 NaC1/Br MU LANDING JT AND CONTROL LINE TO HANGER. RU SLICKLINE. INSTALL DV IN GI24 #1. PRESSURE UP TO SET PACKER. SOS SHEARED EARLY @ 2500 PSI. TEST ANNULUS TO 1500 PSI. OK. SHEARED PBR. TEST ANNULUS TO 2500 PSI. OK. SET BPV. ND ,BOP'S AND NU TREE. TEST TREE. OK. PULL DV F/ GLM #8. FREEZE PROTECT. RE-INSTALL DV IN GLM #8. RD SLICKLINE. TEST TUBING. OK. RR @ 0100 HRS, 1-3-92. SITP=700 PSI, ANNULUS PRESSURE=0 PSI, SICP=0 PSI. DAILY:S262,722 CUM:$1,931,236 ETD:SO EFC:$3,771,236 DATE: .<' · 2 /'/ '? Z ORIGINAL SUB- SURFACE DIRECTIONAL SURVEY UIDANCE ONTINUOUS l-~ OOL RECEIVED FEB 2 5 t992 ¢iJ .& Gas Cons. Commission ;Anchorage Company ARCO ALASKA~ [NC. Well Name 1R-29 (454' FNL,. 136' FWL,SEC 20,T12N,R10E) Field/Location KUPARUK~ NORTH SLOPEr ALASKA Job Reference No. 75074 Looclecl By: Date 27-Aug-9! Computed By: FORMICA KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUS't OMER LISTING FOR ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 27-AUG-1991 ENGINEER: JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: j INTERPOLATION: VERTICAL SECTION: TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 59 DEG 45 MIN EAST COMPUTATION DATE: 6-NOV-91 PAGE 1 ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA DATE Of SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ SECTION SEVERITY NORTH/SOUT~ EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -88 O0 0 0 N 0 0 E 100 O0 100.00 12 O0 0 4 S 82 3 E 2O0 3OO 400 5O0 6O0 70O 8O0 9O0 O0 200.00 112 O0 0 10 N 55 31 E O0 299.99 211 99 1 47 S 74 11 E O0 399.74 311 74 5 16 S 68 4 E O0 499.13 411 13 7 3 S 65 29 E O0 598.25 510 25 8 20 S 63 29 E O0 696.88 608.88 10 51 S 62 46 E O0 794.62 706,62 13 41 $ 61 59 E O0 891.03 803,03 17 8 S 60 49 E 0 O0 0 06 0 2O 1 11 7 9t 18 74 48 37 69 a~ 95 9~ 0.00 0.18 0.17 5.47 2.47 0.92 1 .6~ 2,14 3.56 3.66 0.00 N 0085 0 0 02 N 0 0 12 S 1 2 55 S 7 6 85, $ 17 1 2 54 S 29 29 79 5 63 42 47 S 86 0 O0 E 02 E 0 24 E 0 21 E 1 67 E 8 70 E 18 66 E 32 32 E 48 02 E 69 0 O0 N 0 0 E 08 S 15 40 E 24 N 84 34 E 22 S 84 11 E 08 S 71 35 E 98 5 68 5t E 20 S 67 E E 63 S 65 ~1 E 70 S 6~ 42 E 26 E 96.15 S 63 47 E 1000.00 985.71 897.71 20 19 S 61 6 E 128 05 1100.00 1078.39 990.39 23 42 S 61 20 E 165 1200.00 1169.07 1081.07 26 10 S 59 18 E 207 1300.00 1257.74 1169.74 29 3 S 58 4 E 253 1400.00 1343.92 1255.92 31 43 S 58 37 E 304 1500.00 1427.74 1339.74 34 26 S 59 18 E 359 1600.00 1508.85 1420.85 37 6 S 59 38 E 417 1700.00 1587.19 1499.19 39 39 S 59 7 E 479 1800.00 1663.28 1575.28 41 26 5 58 50 E 544 1900.00 1736.83 1648.83 43 52 S 58 15 E 612 54 67 87 56 O8 54 68 55 28 3.34 3.28 2 O8 3 24 2 36 2 84 2 66 1 81 301 2 67 58 07 S 114.37 E 128 27 S 63 5 E 76 96 120 147 175 205 237 270 305 11 S 147.25 E 165 88 S 183.91 E 207 99 S 223.33 E 254 64 S 266.46 E 304 73 S 313.19 E 359 40 S 363.57 E 4t7 04 S 417.05 E 479 44 S 472.67 E 544 80 S 530.46 E 612 75 S 62 40 E 87 S 62 13 E O0 S 61 33 E 63 S 61 1 E 13 S 60 42 E 58 S 60 32 E 71 S 60 23 E 57 S 60 13 E 29 S 60 2 E 2000.00 1807.14 t719.14 46 37 S 57 48 E 683.34 2100.00 1874.30 1786.30 48 57 S 57 44 E 757.37 2200.00 1938.50 1850.50 '51 7 S 57 52 E 833.98 2300.00 2000.26 1912.26 52 41 S 58 35 E 912.60 2400.00 2059.51 1971.51 54 36 S 59 3 E 993.14 2500.00 2116.11 2028.11 56 25 S 59 37 E 1075.57 2600,00 2170.40 2082.40 57 42 S 59 32 E 1159.55 2700.00 2223.17 2135.17 58 27 S 59 1 E 1244.48 2800.00 2275.96 2187.96 57 51 S 58 39 E 1329.41 2900.00 2329.24 2241.24 57 43 S 57 57 E 1414.00 2.67 2.23 1 .76 2.24 1 .81 1 .65 1 .18 0.59 0.42 0.49 343.56 S 590.69 E 683.34 S 59 49 E 383.06 S 653.35 E 757.37 S 59 37 E 423.97 S 718 19 E 834.00 S 59 27 E 465 43 S 785 02 E 912.62 S 59 20 E 507 15 S 853 92 E 993.17 S 59 18 E 549 17 S 924 85 E 1075.61 S 59 t8 E 591 63 S 997 30 E 1159.58 S 59 19 E 635 07 S 1070 29 E 1244.52 S 59 19 E 679 02 S 1142 96 E 1329.45 S 59 17 E 723 51 S 1214.95 E 1414.06 S 59 14 E 3000.00 2382.75 2294.75 57 38 S 57 26 E 1498.43 3100.00 2436.07 2348.07 58 4 S 57 2 E 1582.94 3200.00 2488.53 2400.53 58 31 S 57 3 E 1667.98 3300.00 2540.88 2452.88 58 19 S 56 23 E 1753.06 3400.00 2593.42 2505.42 58 22 5 56 10 E 1837 98 3500.00 2646.05 2558.05 58 7 S 59 24 E 1922 93 3600.00 2699.00 2611.00 57 54 S 59 25 E 2007 77 3700.00 2751.74 2663.74 58 30 S 58 57 E 2092 72 3800.00 2803.66 2715.66 58 48 S 58 26 E 2178 17 3900.00 2855.39 2767.39 58 51 S 57 54 E 2263 72 0.47 768.68 $ 1286,34 E 1498,51 S 59 8 E 0.86 814.54 S 1357.42 E 1583.06 S 59 2 E 0,46 860.87 S 1428.85 E 1668.15 S 58 56 E 0.78 907.59 5 1500 10 E 1753.29 5 58 50 E 0.86 955.00 5 1570 75 E 1838.29 5 58 42 E 1.61 1000.47 S 1642 58 E 1923.28 S 58 39 E 0.62 1043.40 S 1715 75 E 2008,11 5 58 42 E 0.80 1086.94 5 1788 71 E 2093.06 S 58 43 E 0.54 1131.38 S 1861 72 E 2178.53 S 58 43 E 0.87 1176.51 S 1934 42 E 2264.10 S 58 42 E COMPUTATION DATE: 6-NOV-91 PAGE 2 ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MIN 4000,00 2907,42 2819,42 58 30 4100,00 2960 10 2872,10 57 49 4200.00 3014 4300.00 3073 4400.00 3133 4500.00 3194 4600.00 3255 4700.00 3315 4800.00 3374 4900.00 3434 82 2926,82 55 34 lB 2985 18 53 21 27 3045 27 52 55 31 3106 31 51 54 35 3167 35 53 3 06 3227 Ot 53 25 95 3286 95 52 59 70 3346 70 54 11 S 57 21 E 2349.06 S 57 18 E 2433,97 S 61 38 E 2517.63 S 61 14 E 2598 78 S 60 40 E 2678 70 S 60 2 E 2757 90 S 60 58 E 2837 l0 S 61 ? E 2937 29 S 60 50 E 2997 36 S 62 ~ E 3077 52 0,68 2.16 1268 3,59 1310 1.13 1349 0.92 1388 0.8t 1427 1.16 1466 0.46 1505 0.67 1544 2,90 1583 1222 22 S 2006 56 E 2349 49 S 58 39 E 37 5 2077 81 S 2150 51 S 2221 32 S 2291 56 S 2360 70 S 2428 51 S 2499 38 S 2569 02 S 2639 94 E 2434 O3 E 2518 41 E 2599 29 E 2679 09 E 2758 95 E 2837 ~5 E 29i7 ~7 E 2997 43 E 3077 46 S 58 36 E 11 S 58 38 E 20 S 58 43 E 08 S 58 47 E 25 S 58 5O E 43 S 58 52' = 59 S 58 5E ~ 62 S 58 5g' [ 75 S 5~ 3 E 5000,00 3493.03 3405 03 54 5 5100,00 3552.19 3464 5200,00 3611.99 3523 5300,00 3672,39 3584. 5400,00 3734,30 3646. 5500,00 3797,36 3709 5600,00 3860,46 3772 5700,00 3917,91 3829 5800,00 3974,21 3886 5900,00 4031,35 3943 19 53 17 99 53 14 39 52 18 30 51 13 36 50 35 46 52 18 91 56 14 21 55 12 35 55 30 S 62 32 E 3158.65 S 62 3 E 3239,19 S 61 57 E 3319,28 S 61 54 E 3398.92 S 61 56 E 3477.40 S 62 0 E 3554,95 S 62 25 E 3632.45 5 61 36 E 3714,21 S 61 25 E 3796.82 S 61 20 E 3878.85 0.72 0,55 0,52 1 ,05 0,72 0,74 5.89 1 ,33 1 ,34 0,85 1620.57 S 271~ 45 E 3158.83 S 59 8 E 1658.08 S 2782 1695.74 S 2853 1733.27 S 2923 1770.27 S 2993 1806.79 S 3061 1842,97 5 3130 1881,38 S 3202 1920.94 S 3275 1960.20 S 3347 82 E 3239,33 S 59 13 E 57 E 3319,40 S 59 17 E 87 E 3399.01 S 59 20 E 14 E 3477,46 S 59 24 E 62 E 3555.00 S 59 27 E 24 E 3632.49 S 59 31 E 48 E 3714,23 S 59 34 E 04 E 3796,83 S 59 36 E 11 E 3878,86 S 59 39 E 6000,00 4088.68 4000.68 54 7 6100,00 4148,44 4060,44 53 32 6200,00 4205,81 4117,81 55 48 6300,00 4260,88 4172,B8 58 6 6400,00 4311,89 4223.89 59 49 6500,00 4362,26 4274,26 59 44 6600,00 4412.80 4324,80 59 32 6700,00 4463,69 4375,69 59 20 6800,00 4514,89 4426,89 59 7 6900,00 4566,38 4478,38 58 55 S 61 0 E 3960,76 S 60 34 E 4040,91 S 59 41 E 4122,81 S 58 39 E 4206,27 S 57 39 E 4292,23 5 57 43 E 4378.56 5 57 56 E 4464,80 S 57 59 E 4550,84 5 58 11 E 4636,70 S 58 25 E 4722.40 1 86 4 31 0 35 4 28 0 23 031 0 41 0 26 0 43 0 10 1999,79 S 3418 84 E 3960,76 S 59 41 E 2038,69 S 3488 95 E 4040,92 S 59 42 E 2079,78 S 3559 79 E 4122.81 S 59 42 E 2122,32 S 3631 59 E 4206.27 S 59 42 E 2167.96 S 3704 49 E 4292,24 S 59 40 E 2214,18 S 3777 48 E 4378,57 S 59 37 E 2260.14 S 3850 50 E 4464,82 S 59 35 E 2305,82 S 3923 46 E 4550,87 S 59 33 E 2351,26 S 3996,36 E 4636,73 S 59 32 E 2396,29 S 4069,30 E 4722,44 S 59 30 E 7000,00 4618,14 4530.14 58 52 7100,00 4669,84 4581,84 58 53 7200,00 4721,37 4633,37 59 3 7300,00 4772,65 4684,65 59 10 7400,00 4824,03 4736,03 59 5 7500.00 4875.45 4787.45 59 2 7600.00 4926.94 4838.94 58 58 7700.00 4978.59 4890.59 58 54 7800.00 5030.27 4942.27 58 50 7900,00 5082,02 4994,02 58 50 S 58 41 E 4807,94 S 59 2 E 4893 S 59 15 E 4979 S 59 17 E 5065 S 59 32 E 5150 S 60 9 E 5236 S 60 29 E 5322 S 60 51 E 5407 S 61 6 E 5493 S 61 13 E 5579 53 23 07 86 63 35 97 56 10 0.32 0.29 O. 28 0.27 0.73 0.28 0.49 0.37 0.18 0.17 2440.97 S 4142.27 E 4807.99 S 59 29 E 2485.24 S 4215.54 E 4893.59 S 59 29 E 2529.18 S 4289.12 E 4979.28 S 59 28 E 2573.06 S 4362.90 E 5065.13 S 59 28 E 2616.82 S 4436.70 E 5150.93 S 59 28 E 2659.88 S 4510.87 E 5236.69 S 59 28 E 2702.36 S 4585.33 E 5322.41 S 59 29 E 2744.30 S 4659.98 E 5408.02 S 59 30 E 2785.83 S 4734.85 E 5493.60 S 59 32 E 2827,10 S 4809.81 E 5579.13 S 59 33 E COMPUTATION DATE: 6-NOV-91 PAGE 3 ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000 O0 5133.30 5045 30 59 55 8100 8200 8300 8400 8500 8600 6700 8800 8900 O0 5182.84 5094 O0 5232.34 5144 O0 5281.96 5193 O0 5331.62 5243 O0 5381.49 5293 O0 5431.60 5343 O0 5481.87 5393 O0 5532.28 5444 O0 5583,16 5495 84 60 22 34 60 15 96 60 12 62 6O 13 49 59 59 60 59 52 87 59 48 28 59 35 16 59 17 S 60 19 E 5664.92 S 59 56 E 5751.79 S 60 28 E 5838.67 S 60 57 E 5925.49 S 61 23 E 6012.26 S 61 39 E 6098.90 S 61 56 E 6185.38 S 62 !9 E 6271.75 S 62 8 E 6358.0? S 60 lO E 6444.09 3.49 0.26 2912 0.47 2955 0.67 2997 0.31 3039 O.23 3081 0.42 3122 0.50 3162 1.9~ 3202 0.32 3244 2868 66 S 4884 92 E 5664 95 $ 59 35 E 22 S 4960 39 S 5035 90 S 5tli 74 S 5187 09 S 5263 02 S 5339 47 S 5416 52 S 5492 52 S 5567 08 E 5751 48 E 5838 18 E 5925 23 E 6012 42 E 6098 66 E 6185 06 E 6271 57 E 6358 72 E 6444 82 S 59 35 E 7O S 59 35 E 51 S 59 36 E 27 S 59 38 E 91 S 59 39 E 38 S 59 41 E 75 S 59 43 E 02 S 59 45 E O9 S 59 46 E 9000.00 5634.48 5546 48 58 57 9100.00 5686.15 5598 9200.00 5737.30 5649 9300.00 5788.04 5700 9400.00 5838.64 5750 9500.00 5889.37 5801 9600.00 5939.78 5851 9700,00 5990.06 5902 9800.00 6040.26 5952 9900.00 6090.37 6002 15 58 54 3O 59 28 04 59 34 64 59 38 37 59 34 78 59 48 06 59 53 26 59 53 37 59 5O S 60 23 E 6529 92 S 60 37 E 6615 S 58 51E 6701 S 59 1 E 6787 S 59 27 E 6873 S 59 13 E 6960 S 57 47 E 7046 S 58 21 E 7132 S 58 57 E 7219 S 59 31E 7305 53 45 61 86 03 37 77 24 78 0.13 0.54 0.89 0.67 0.41 1 .71 0.34 0.50 0.56 0.52 3287 06 S 5642 26 E 6529 92 S 59 47 E 3329 17 S 5716 3372 37 S 5791 3416 94 S 5864 3461 05 S 5938 3504 79 S 6013 3550 15 S 6086 3595 90 S 6160 3640.92 5 6233 3685.21 S 6308 80 E 6615 07 E 6701 83 E 6787 95 E 6873 20 E 6960 69 E 7046 03 E 7132 87 E 7219 22 E 7305 53 S 59 47 E 45 S 59 47 E 6t S 59 46 E 86 S 59 46 E 03 S 59 46 E 37 S 59 45 E 77 S 59 44 E 24 S 59 43 E 78 S 59 42 E 10000,00 6140 85 6052.85 59 36 10100.00 6191 10200.00 6242 10300.00 6293 10400.00 6344 10500.00 6396 10600.00 6449 10700.00 6501 10800.00 6555 10900.00 6611 48 6103.48 59 31 37 6154.37 59 24 33 6205.33 59 15 74 6256.74 58 49 94 6308.94 58 28 28 6361.28 58 18 86 6413.86 58 12 37 6467.37 56 44 27 6523.27 55 17 S 59 56 E 7392.10 S 60 29 E 7478.33 S 60 55 E 7564.40 S 61 9 E 7650.42 S 61 23 E 7736.16 S 61 10 E 7821.43 S 61 9 E 7906.61 S 61 15 E 7991.65 S 61 57 E 8076.08 5 62 32 E 8158.91 0.58 0.64 0.46 0 47 0 78 0 42 0 28 0 72 2 38 2 87 3728.73 S 6382 77 E 7392.10 S 59 42 E 3771 58 S 6457 3813 66 S 6532 3855 35 S 6607 3896 56 S 6683 3937 56 S 6757 3978 73 S 6832 4019 79 S 6907 4060.05 S 6981 60 E 7478.33 5 59 43 E 70 E 7564.40 S 59 43 E 96 E 7650.42 S 59 44 E 18 E 7736.16 S 59 45 E 98 E 7821.43 S 59 46 E 58 E 7906.61 5 59 47 E 08 E 7991.65 S 59 48 E 34 E 8076.09 S 59 49 E 4098.64 S 7054.73 E 8158.92 S 59 51 E 11000.00 6669.02 6581.02 54 26 11100.00 6727,46 6639.46 53 58 11200.00 6786.60 6698.60 53 42 11300.00 6845.81 6757,81 53 42 11368.00 6886.07 6798.07 53 42 S 63 8 E 8240.44 S 63 23 E 8321.43 S 63 21 E 8401.81 S 63 21 E 8482.24 S 63 21 E 8536.93 0.91 2.09 0.00 0,00 0.00 4135.98 5 7127.33 E 8240,46 $ 59 52 E 4172.49 S 7199.79 E 8321.46 S 59 54 E 4208.52 S 7271,84 E 8401.86 S 59 56 E 4244,67 S 7343.86 E 8482,30 S 59 58 E 4269.25 S 7392.83 E 8537.01 S 60 0 E COMPUTATION DATE: 6-NOV-91 PAGE ARCO ALASKA, [NC. 1R-29 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 1000.00 985.71 897 2000.00 1807.14 1719 3000.00 2382.75 2294 4000.00 2907.42 2819 5000.00 3493,03 3405 6000.00 4088,68 4000 7000.00 4618.14 4530 8000.00 5133.30 5045 9000.00 5634.45 5546 0.00 -88 O0 0 0 71 20 19 14 46 37 75 57 38 42 58 3O O3 54 5 68 54 7 14 58 52 3O 59 55 48 58 57 N 0 0 E S 61 6 E 128 S 57 48 E 683 S 57 26 E 1498 S 57 21 E 2349 S 62 32 E 3158 S 61 0 E 396O S 58 ,41 E 4807 S 60 !9 E 5664 S 60 23 E 6529 0 O0 05 3,4 43 06 65 76 94 92 92 0 O0 3 34 2 67 0 47 0 68 0 72 1 86 0 32 3 49 0 13 0 O0 N 58 343 768 1222 1620 1999 2440 2868 3287 0 O0 E 07 S 114 56 S 590 68 S 1286 22 S 2006 57 S 2711 79 S 3418 97 S 4!42 66 S 4884 06 S 5642 0.00 N 0 0 E 37 E 128.27 S 63 5 E 69 E 683.34 S 59 49 E 34 E 1498.51 S 59 8 E 56 E 23,49.49 S 58 39 E 45 E 3158.83 S 59 8 E 84 E 3960.76 S 59 4~ E 27 E 4807.99 S 59 29 E 92 E 5664.95 S 59 35 E 26 E 6529.92 S 59 47 E 10000.00 6140.85 6052.85 59 36 11000.00 6669.02 6581.02 54 26 11368.00 6886.07 6798.07 53 42 S 59 56 E 7392.10 S 63 8 E 8240.44 S 63 21 E 8536.93 0,58 0.91 0.00 3728.73 S 6382.77 E 7392.10 5 59 42 E 4135.98 S 7127.33 E 8240.46 S 59 52 E 4269.25 S 7392.83 E 8537.01 S 60 0 E ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 6-NOV-91 PAGE 5 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0 O0 88 O0 88 188 O0 188 288 O0 288 388 22 388 488 78 488 589 64 588 690.97 688 793.19 788 896.83 888 0 O0 -88.00 0 0 N 0 0 E O0 0.00 0 3 S 81 51 E O0 100.00 0 10 N 51 34 E O0 200.00 1 13 S 76 41 E O0 300.00 4 59 S 68 21 E O0 400.00 6 56 S 65 47 E O0 500.00 8 9 $ 63 46 E O0 600.00 10 38 S 62 50 E O0 700.00 13 26 S 62 1 E O0 800.00 17 1 S 60 49 E 0 O0 0 04 0 18 0 79 6 87 ;7 38 3O 45 4~ 7C 67 85 94 97 0 O0 019 0 05 4 O0 2 21 2 11 2 34 3 7,:; 6 2_© 42 0.00 N 0075 0 0 O0 N 0 0 04 S 0 2 16 S 6 29 S 16 87 ~. 26 2E ~ 42 O4 S 6~, Ol S 85 01 E 0 21 E 0 90 E 0 69 E 7 46 E 17 33 E 30 83 E 46 60 E 68 44 E 95 0 O0 E 0 O0 N 0 0 E 07 S 6 19 E 21 N 89 33 E 90 $ 87 44 E 03 S 72 6 E 71 S 67 '~6 E 96 S 65 ~E -~ ~,l S 64 46 E 2~ S 63 49 E 1002.44 988.00 900 O0 20 23 S 61 7 E 128 90 1110.50 1088.00 1000 1221.13 1188.00 1100 1334.79 1288.00 1200 1452.17 1388.00 1300 1573.96 1488.00 1400 1701.05 1588.00 1500 1833.18 1688.00 1600 1972.33 1788.00 1700 2120.91 1888.00 1800 O0 23 59 S 61 15 E 169 78 O0 26 40 S 58 59 E 217 06 O0 30 3 S 58 9 E 271 03 O0 33 5 S 59 3 E 332 45 O0 36 26 $ 59 37 E 401 95 O0 39 41 S 59 7 E 480 35 O0 42 17 S 58 37 E 566.68 O0 45 56 S 57 48 E 663.36 O0 49 25 S 57 43 E 773.15 3 39 2 38 3 03 2 48 2 63 2 47 1 76 221 2 36 2 15 58.48 S 115 11 E 129.11 S 63 4 E 78.15 S 150 101.70 S 191 130.06 S 237 162.09 S 290 197.51S 350 237.38 S 417 281.93 S 491 332.91 5 573 391.50 S 666 97 E 170.00 S 62 38 E 97 E 217.25 S 62 5 E 90 E 271.13 S 61 20 E 33 E 332.51 S 60 50 E 12 E 401.99 S 60 34 E 63 E 480.38 S 60 23 E 59 E 566.69 S 60 10 E 78 E 663.37 S 59 53 E 71 E 773.16 S 59 35 E 2279.87 1988.00 1900 O0 52 17 S 58 26 E 896.63 2449.79 2088.00 2000 O0 55 31 $ 59 23 E 1033.97 2633.10 2188.00 2100 O0 58 2 S 59 20 E 1187.58 2822,63 2288 O0 2200 O0 57 51 S 58 30 E 1348.56 3009.81 2388 O0 2300 O0 57 37 S 57 22 E 1506.70 3198.99 2488 O0 2400 00 58'31 S 57 3 E 1667.11 3389.68 2588 O0 2500.00 58 22 S 56 2 E 1829.21 3579.29 2688 O0 2600.00 57 56 S 59 34 E 1990.22 3769.77 2788 O0 2700,00 58 49 S 58 36 E 2152.32 3962,79 2888 O0 2800.00 58 35 S 57 36 E 2317.34 1 79 1 98 528.05 S 889 1 08 605,89 S 1021 0 65 689 02 S 1159 0 54 773 15 S 1293 0 46 860 40 S 1428 0 41 950 12 S 1563 0 71 1034 50 S 1700 0.45 1117 86 S 1839 0.55 1205 15 S 1979 457.08 S 771 40 E 896 65 S 59 21 E O0 E 1034 43 E 1187 31 E 1348 32 E 1506 13 E 1667 45 E 1829 63 E 1990 66 E 2152 79 E 2317 O0 S 59 17 E 61 S 59 19 E 61 S 59 17 E 79 S 59 8 E 28 S 58 56 E 51 S 58 43 E 56 S 58 41 E 67 S 58 43 E 75 S 58 40 E 4151.81 2988.00 2900.00 56 51 S 59 42 E 2477.60 4324.75 3088.00 3000.00 53 8 5 61 6 E 2618.60 4489.77 3188.00 3100.00 51 56 S 60 4 E 2749.84 4654.57 3288.00 3200.00 53 25 S 61 7 E 2880.82 4821.67 3388.00 3300.00 52 57 S 60 50 E 3014.65 4991.43 3488.00 3400.00 54 7 S 62 36 E 3151.72 5159.89 3588.00 3500.00 53 19 S 61 58 E 3287.16 5325.44 3688.00 3600.00 52 1 S 61 53 E 3419.00 5485.26 3788.00 3700.00 50 42 S 61 59 E 3543.57 5646.72 3888.00 3800.00 55 7 S 62 4 E 3670.15 6.30 1291.32 $ 2115 06 E 2478.10 S 58 36 E 0.83 1359.08 5 2238 1.10 1423.54 S 2353 0.65 1487.86 S 2467 0.91 1552.81 5 2584 0.72 1617.37 S 2705 0.28 1680.63 S 2825 1.08 1742.74 S 2941 0.86 1801.44 S 3051 5.05 1860.55 S 3163 78 E 2619 01 S 58 44 E 11E 2750 22 E 2881 27 E 3014 29 E 3151 19 E 3287 59 E 3419 57 E 3543 63 E 3670 20 S 58 50 E 13 S 58 54 E 91 S 59 0 E 90 S 59 8 E 28 S 59 15 E 08 S 59 21 E 62 S 59 27 E 18 S 59 32 E ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 6-NOV-91 PAGE 6 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORM[CA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5824.11 3988.00 3900.00 55 0 5998.83 4088.00 4000.00 54 9 6168.39 4188.00 4100 O0 55 36 6352 61 4288 O0 4200 O0 59 36 6551 01 4388 O0 4300 O0 59 39 6747 57 4488 O0 4400 O0 59 12 6941 81 4588 00 4500 O0 58 48 7135 19 4688 O0 4600 O0 58 57 7329 90 4788 O0 4700 O0 59 5 7524 39 4888 O0 4800 O0 59 S 61 28 E 3816.59 S 61 0 E 3959.81 S 59 37 E 4096.69 S 57 49 E 4251 33 S 57 49 E 4422 57 S 58 4 E 459~ 7~ S 58 30 E 4758 ~? S 59 9 E 4923 67 S 59 18 E 5090 7~ S 60 13 E 5257 54 1.03 1.89 1999 1.32 2066 1.54 2146 0.20 2237 0.20 2327 0.79 2415 0.49 250C' 0.46 258E 0.25 2670 1930 40 S 3292 41 E 3816.60 S 59 37 E 33 S 3418 58 S 3537 09 S 3669 67 S 3814 49 S 3958 02 S 409[~ 73 S 42~! 28 S 4529 01E 3959.81 5 59 40 E 25 E 4096.69 $ 59 42 E 89 E 4251.33 S 59 41 E 73 E 4422 59 $ 59 36 E 14 E 4591 74 S 59 33 E 80 E 4758 22 S 59 30 E 40 E 4923 72 S 59 29 E 97 E 5090 80 S 59 28 E 02 E 5257 60 S 59 29 E 7718.22 4988 O0 4900.00 58 55 7911.55 5088 O0 5000.00 58 50 8110.43 5188 O0 5100.00 60 22 8312.15 5288 O0 5200.00 60 11 8513.02 5388 O0 5300.00 59 58 8712.18 5488 O0 5400.00 59 48 8909.47 5588 O0 5500.00 59 17 9103.59 5688.00 5600.00 58 55 9299.92 5788.00 5700.00 59 34 9497.29 5888.00 5800.00 59 33 S 60 55 E 5423.57 S 61 14 E 5588.98 S 59 59 E 5760.86 S 61 1 E 5936.03 S 61 41 E 6110.17 S 62 21 E 6282.27 S 60 12 E 6452.24 S 60 36 E 6618.60 S 59 1 E 6787,54 S 59 15 E 6957.70 0 32 0 22 0 43 0 76 0 21 0 46 0 23 0 65 0 67 1 62 2751.89 S 4673 61 E 5423.6~ S 59 31 E 2831.86 S 4818 2916.76 S 4967 3003.02 S 5120 3086.45 S 5273 3167.36 S 5425 3248.57 S 5574 3330.68 S 5719 3416.90 S 5864 3503.60 S 6011 47 E 5589.0t S 59 33 E 93 E 5760.89 S 59 35 E 40 E 5936.05 S 59 37 E 34 E 6110.17 S 59 40 E 39 E 6282.27 S 59 43 E 78 E 6452.24 S 59 46 E 48 E 6618.60 S 59 47 E 76 E 6787.54 S 59 46 E 19 E 6957.70 S 59 46 E 9695.90 5988 O0 5900.00 59 53 9895.28 6088 10093.14 6188 10289.57 6288 10482.91 6388 10673.68 6488 10858.77 6588 11032.57 6688 11202.37 6788 11368.00 6886 O0 6000.00 59 51 O0 6100.00 59 32 O0 6200.00 59 17 O0 6300 O0 58 26 O0 6400 O0 58 16 O0 6500 O0 55 54 O0 6600 O0 54 16 O0 6700 O0 53 42 07 6798 07 53 42 S 58 19 E 7129 23 S 59 29 E 7301 70 S 60 27 E 7472 42 S 61 7 E 7641 46 S 61 11 E 7806 86 S 61 7 E 7969 28 S 62 22 E 8124 91 S 63 16 E 8266 86 S 63 21 E 8403 72 S 63 21 E 8536.93 0.51 0.51 0.50 0.45 0.27 0.48 1 .36 1.05 0.00 0.00 3594.03 S 6157.02 E 7129.23 5 59 44 E 3683.14 S 6304.71 E 7301.70 S 59 42 E 3768 67 5 6452.46 E 7472.42 S 59 43 E 3851 03 S 6600.11 E 7641.46 S 59 44 E 3930 53 S 6745.22 E 7806.86 S 59 46 E 4009 01 S 6887.48 E 7969.28 S 59 48 E 4082 90 S 7024.55 E 8124.92 5 59 50 E 4147 92 S 7150.95 E 8266.88 S 59 53 E 4209 37 S 7273,54 E 8403,76 S 59 56 E 4269.25 S 7392.83 E 8537.01 $ 60 0 E ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA MARKER PAD RKB 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A LAST READING GC~ BASE KUPARU~ A PBTD 7" CASING COMPUTATION DATE: 6-NOV-91 PAGE 7 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 454' FNL & 138' FWL, SEC20 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 44.00 88.00 6042.00 10640.00 10787 O0 11024 OO 11155 10 11167 O0 11241 O0 11331 O0 44 O0 88 O0 4113 59 6470 30 654B 25 6683 O0 6760 O~ 6767 06 68t0 87 6864 17 -44 O0 0 O0 4O25 59 6382 3O 6460 25 6595 O0 6672 O1 6679 06 6722 87 6776 17 0 04 S 0 07 S 2016 16 S 3995 16 S 4054 93 S 4144 78 S 4192 29 S 4196 59 S 4223 34 S 4255 87 S 0 02 W 0 01 E 3448 43 E 6862 39 E 6971 75 E 7144 7~ E 7239 50 E 7248 O7 E 730~ 37 ~ 7366 t9 E TD 11368.00 6886.07 6798.07 4269.25 S 7392.83 E COMPUTATION DATE: 6-NOV-91 PAGE 8 ARCO ALASKA, INC. 1R-29 KUPARUK NORTH SLOPE, ALASKA MARKER PAD RKB 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A LAST READING GCT BASE KUPARUK A PBTD 7" CASING TD DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA SURFACE LOCATION = 454' FNL & 138' FWL, SEC20 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 44.00 88.00 6042.00 t0640.00 10787.00 11024.00 11155.10 11167.00 11241.00 11331.00 44 O0 88 O0 4113 59 6470 3O 6548 25 6683 O0 6760 O; 6767 O6 6810 87 6864 17 -44 O0 0 O0 4025 59 6382 30 6460 25 6595 O0 6672 01 6679 06 6722 87 6776 17 0 04 0 07 2016 16 3995 16 4054 93 4144 78 4192 29 4196.59 4223,34 4255.87 0 0 3448 6862 6971 7144 7239 7248 7301 7366 02 W 01 E 43 E 39 E 75 E 74 E 50 E 07 E 37 E 19 E 11368.00 6886.07 6798,07 4269.25 S 7392.83 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11368.00 6886.07 6798.07 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8537.01 S 60 0 E DIRECTIONAL SURVEY COMPANY FIELD WELL COUNTRY RUN DATE~ DEPTH UNIT AFICO ALA8KA, INC. 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"')'"~"'~"') ...... ~"'k"~"'~ ...... )'"k"k"~ ...... ~'"F"~"-~-""'-~-'-~---}-'-~ ....... ~'-P'~'"k" "i-'~-~'-~-~ 'i-'~-k"~ ...... ~"'~---~"-~ ...... ~-"~'-~-'-~ ..... ~'"k-'~-'-~ ...... ~'--k"k"~ ....... k"~"-~-"~ ..... k-!.-'F--~ ...... ~."~...~.--~ ...... }...}-'-~.--~ ,..~--~---h--~ ..... h.-h..h--h-, ,.~---h--~--.~ ...... h-.h--h--~ ...... h--h..~---h- .-~.--h--~---~ ...... ~.'.h-.h-~ ...... ~-..~--h.-~--..--~-.-~--h--~ ...... h..h-~...~ ...... h'.~.-.~-..~ ....... h--~.--~-,-~ ...... ~--.~-,.~..-~ ..... h..h..h-q ...... ~-.-~...h-.~ ..... ~...~.--:..-h,. .... h.i--+--~ ...... )'"~"+".'"~"i ...... ~'".'" '"~"i"'k". ...... ~'"."'~'"~ ...... ~'"~"i'"~ ...... k'!"'k-~ ...... ~"'k"k"~""'.'".'"."i ...... ~"i'"~ ....... ~"'V"~ ...................... ~"i ...... ~"i ............ = ..... ~ '= = i = '"F'!"'F"~ ..... F"F"F"~ ...... F'F"F"[ ...... F!'"F-~ ..... F"F"r"~ ...... F"F'T"F ..... F"F"~ ........ ["'~TF"'F ....... ~'"i"'~'"F ..... F"~'"~"'~ ...... ~"'r"F"i ...... F"~ ...... ~ ...... ~ ...... ~ ............ ~ ...... ~ ...... ~ ..... ~'"~"~"~"'~ ...... ~'" "'~'!"i"i'"['-F"F'!-F""~-~"i'"F" '"~"'F"F'i ..... F"F"F"T ...... F"F"F'i ..... ~"'~"'r"( ...... F"F"F"~ ....... F"F"F"~ ..... F"F'F"~ ...... F"T'"~'"T ....... F"F"F'T"~"i'?'~"'{ ...... ?'-?'"~ ....... ~..'~"i-'.~"?-k" '"E'?'?"? ~"?"i'"i'"~ ...... i"?"i"?" ~'"?'?"?i ..... ??"?'i ...... ?'i"'!'"~ ..... ??"?'i ...... ?'??"~ ...... ?"?'?"~ ..... ?'??"~ ...... ?'?"?"( ...... ??'?' 7") AOGCC GEOLOGICAL MATERIAL9 INVENTORY LIST PERMIT// ? ! - COMPLETION DATE CO. CONTACT & NO./~ ~,~ form received received date comments 407 yes no completion report 403 yes no sund~ application 4~i4 yes no .......... repmt of sundq~ application Open required reCeiv-~d Cased required received Productior required received hole log hole Io. 9 , ,, log MUD " GCT I'EMP DII]S~-E" CNL ' 'PROD ........ DLL CU-['" ~ ~ .j' PRESS B'~CISL "' CET ~ ~ ~ SPINNER BHC/AC Em OTHER DATA tss ...... PEnF storey 'J ,, ,sss .-, mOCKER 'Di§ital '" Data ,,, FDC' ...... Well CNL Tests '"FDC " RWD required 'received SAMPLEs 'required received MWD L0r/cNL ' ' ' d ,,0, ~ ~, .~ dR/ditch,, yes no "-" IdL dD ~ / core yes no , , , . , CYBER ' core yes no .LOOK, , , Analysis ..... , , NGT ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return o. ne signed copy of this transmittal. Please acknowledge receipt ~J' ,~,~,~I2M-10 Litho-Density & Casing Neutron 11-29-91 7000-7756.,~~ -- Porosity Data & 12-29-91 7000 7669 2M-1 0 Litho-Density & Casing Neutron I 1-29-91 7000 7756 Raw Data & t2-29-91 7000-7669 I ~3Q-04 CCN ~' 1-12-16-92 4517.7-7720 d 4t~,-~1:>-i,oQ;04 CI~ ,, 1-12-16,92 4517.7-7720 i,.13,,~'~3Q.03 CDR ~ 1-24-27-92 5090-9640 .~THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUESTED · ..THANKTHAT YOUyou.THROW OUT THE. PREVIOUS (UNCORRECT) COPY OF THIS LOG. .,~ {[-(,"~ 1L-2~'~'~j"-.7'"~ ~N ' ' ~~~ --- 5237-104~-(~:,-% ?1..-~ 1L-26(.~q-,~)"/~]~i ' ' 6-3-6-91 5225-10065 } ~t-l'~ 2M-19~/ CD~ 11-17-'91 · 3835-9250 ! /, ,~-q 2M'21.v// CEN 11-1 1-91 3914-10599 ~'' .., 1R-17;, CEN 9-15-19-91 5698-10345 '---~ - ~' -r ,n-,~/ Ct~ 6-19-23-91 . 5390-9841 /~ - ~][ "~ ~r 1R-20~/ ~ 9-9-91 5568-10080 ~lt"~ :. ~ 1R-21 ~/.. C[::N 10-6-11-91 5070-10180 /\ 9--24-29-91 ~{"/,';'~ 1R - 22 ,~{ ~ 6001-10813 ..~,,tlR-23'/ . CCN 10-22-91 6330-12188 ~ 7-18-21-91 5591-10218 ~,..~/~ 1R;29 -~ C[3q/~ 8-31-91 6547-9250 8- 1 4-91 ..-6042-11368 ~/~ 1L-24-~' CON ,/ 5-19-22-91 5081-9241 _~,1L-25 ~-~ CCN ,/ 5-26-29-91 4978 9352 / RECEIVED Alaska 0il & Gas Gens. Commission A~chorage ARCO Alaska, Inc. Date' January 10, 1992 Transmittal #: 8328 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one/signed copy of this transmittal. .~I RR!22(~ 2, ~ ~ n~ r~tt EB°vnadl uLa t°(i3o nP~)(~jSqueeze Post Squeeze 2 M- 1 3 Ultrasonic Imager Receipt Drilling Please acknowledge receipt and 12-28-91 12-28-91 1 -1 -92 Acknowledge' --~--~ Date: 999O-11133 999O-11156 10200-12010 RECEIVED" JAN, 1 ,:7) 1992 Alaska Oil& Gas Cons. Commission ,.? Anchorage ARCO Alaska, Inc. Date: November 22, 1991 Transmittal #: 8288 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box- 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. Receipt Acknowledged: Please acknowledge receipt and return Sub-Surface Directional 8 - 2 7- 9 1 Survey .................. Date: 75074 D&M State of Alaska RECEIVED NOV 2 7 1991 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' November 22, 1991 Transmittal #: 8290 RETURN TO: ARCO Alaska, Inco Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed c0py of this transmittal. · 9/../o~ I R - 2 7 ,.~ LIS Tape and Usting -~ ~'/'"~,'~ 8- 3 1 - 91 ~'/" ? ~' I R-2 9 / LIS Tape and Hsting~,5-/~ ? 8- 1 4- 9 1 ~/"/°'~ I R- 2 0 .. ~ LIS Tape and Usting ~ 5"/~f,," 9 - 9 - 9 1 ,e/._//~ I R- 1 7 ~'/ '. LIS Tape and Usting .~. j-/..-,--&' 9- 1 9- 91 ?/,,j,~, I R-23 ~ ....... LIS Tape and Usting ~..c-/.~J" .... 1 0-22-91' Please acknowledge receipt and return 74904 74854 74922 74934 75103 Receipt Acknowledged: - -- Date' Lynn Goettinger RECEIVED State of Alaska N0V 2 7 1991 DISTRIBUTION: Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: September 13, 1991 Transmittal #: 8223 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. -.. 1A-23k/ 1A-23< 1A-23~ 1A - 23~.,'- lA lA lA (~t,~ .,-1RiR -23'~' -23 - -23 23~ -23~-2:3'~,-26--' - 26---- Tracerscan 7- 1 Pulsed Spectral Gamma Log 5 - 1 Pulsed Spectral Gamma Log 5 - 1 Cased Hole Extra Long Spaced 5- 1 Fullwave Log Cased Hole Spectra Gamma Log 5 - 1 Cased Hole Fullwave Acoustic Log 5- 1 Tracercheck Log 7- 1 Tracercheck Log 7- 1 PSGT..~:~.~ 5 - 1 PSGT 5-1 Cement Bond Log 8 - 2 Cement Evaluation Log 8 - 2 1R-29.-~ "1 R-29--- 2M-25-- 2M-25--- Receipt -.Cement Evaluation Log 8- 2 Cement Bond Log 8 - 2 Cement Evaluation Log 8- 2 Cement Bond Log ,~ 8 - 2 Acknowledge: -- Please acknowledge receipt and 6-91 5-91 5-91 5-91 5-91 5-91 6-91 9-91 5-91 5-91 7-91 7-91 7-91 7-91 8-91 8-91 Date' 6900-7300 6800-7350 6800-7350 6800-7350 6800-7350 6800-7350 6900-7300 6900-7300 6900-7300 6900-7300 '8500-10092 8500-10113 10000-111988~ 10000-1117 5990-7334 5990-7314 Drilling State of Alaska(+sepia) NSK RECEIVED SEP 1 6 1991 Alaska 0~1 & Gas Cons. Commiss~o, AnChorage ARCO Alaska, Inc. Date' September 6, 1991 Transmittal #: 8219 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. Please acknowledge receipt 1 R-29 CDR 8- 1 4-91 6042-11 368 1 R-29 CDN 8-1 4-91 6042-11368 Receipt Acknowledged' - ............................ Date' - ......... DI,.qTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) TO: THRU: FROM: MEMORANUUM State of Alaska. ALASKA OIL AND GAS CONSE'RVATION COMMISSION Lonnie Co Sm' %~'~ ~" DATE: August 14, 1991 Commissioner ',~'-~'~ ~ ~- FILE NO: LG814 TELEPHONE NO: SUBJECT: Diverter Inspection RIG/BOPE Inspection ARCO Well KRU 1-R-29 Kuparuk Rv Unit Permit No. 91-94 Louis R. Grimaldi Petroleum Inspector AUgust 8. _1991: I travelled to CPF #1 R-pad in the Kuparuk RiVer unit to witness a diverter test on Pool Rig #7 preparing to drill well #1R-29. The diverter test went well with no problems. I also made a RIG/BOPE inspection while there and found no problems. Gary Goerlich, Pool's toOlpusher, strives to supply the rig and its hands with all that is needed to correctly operate the rig. Although cosmetic, the rig is undergoing a paint job and is shaping up toad,be a fine looking rig. In summary~ The diverter and RIG/BOPE inspection on Pool #7 went well and no non-compliances were found. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERAT I ON: Wkvr U 1C Operator Permit # Location: Sec Drlg contr ~~ ~C~/C~~ Rig~~ Location (gen'l) ~ N COMPL Ye~ nj 9/a A. D)VERTER ~.~) () 3.(~ () (I 5.(,~ () 6. () 7. (~ ( ) 8.() '() 9.() () ~o.() () ~.() () ~2.() () 13. ( ) ( ) ~4.() () ~s.() () ~6.() () 17. ( ) ( ) 18.() () 19.() () 2o.() () 21. ( ) ( ) 22.() () 23. (~ ( ) 2~, t~¢' () 25. (~, ( ) 26. ~ ( ) 27. ( ) 28. (~ ( ) 29. ~d~ () 3o. tx~ () · 31. ~) () 32. ( ) STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMISS BOPE Walk-Thru Inspection Report Representative , Representative ~A~ REMARKS: ( ) line sz & length ( ) line conn& anchored ( ) bifurcated & dwn wind ( ) 90° targeted turns ( ) vlvs: auto & simultaneous ( ) annular pack-off { ) condition B. BOP STACK (?) wellhead flg wkg press (~) stack wkg press ()) annular preventer ( pipe rams ( blind rams ( stack anchored ( chke/kill line sz IN COMPLIANCE; yes no n~a' 33.~ () 34. ( ) 3s.p~ () 37. 38. (~ 39. (~) 40. ~) 42. (~X~} 43. (/ ( (J) HCR vivs (chke & kill) ( ) manual vlvs (chke & kill) ( ) connections (flgd, whd, clmpd) ( ) drl spool ( ) flow nipple ( ) flow monitor ( ) control lines fire protected C. CLOSING UNITS ( ) wkg press ( ) fluid level ( ) oprtg press ( ) press gauges ( ) sufficient vlvs ( ) regulator bypass ( ) 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel ~x~ remote control panel ( ) firewall ( ) nitrogen power source (back-up) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM ( ) ( ) pit level floats installed ( ) ( ) flow rate sensors ( ) ( ) mud gas separator 44. (k~) () ( ) ( ) degasser ( ) ( ) separator bypass ( ) ( ) gas sensor ( ) ( ) chke In corm ( ) ( ) trip tank E. RIG FLOOR ( ) kelly cocks (upper,lower, IBOP) 45. ~ ( ) ( ) floor vlvs (dart vlv, ball vlv) ) 90° turns targeted (chke & kill ln) 46. ~-~) ( ) ( ) kelly & floor vlv wrenches 47. ~ ( ) ( ) driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) ( ) ~/~ kill sheet up-to-date 49. ~} ( } ( ) gas ~etection monitors (H-S & methane) so.() () 5~,() () 52.() () 53.() () 54.() () ss. bi () s6. /)0 () 57.,(/~ () sa.A<~ () (~<~ hydr chke panel chke manifold F. MISC EQUIPMENT (~Td~ flare/vent 1.ine (-/z~ 90° turns targeted (dwn strm choke lns) (~ reserve pit tankage ( ) personnel protective equip avail ( ) all drl site suprvs trained for procedures ( ) H2S probes ( ) rig housekeeping RECORDS: ~/~~~. Date of last BOP inspection:_~ Resulting non-compliance: Date of last BOP test: Non-compliances not corrected & why: Date corrections will be completed: BOP test & results properly entered on daily record? ~ Kill sheet current?~ Inspecto - C.0013 (rev 04/29/91 ) ALASKA OIL AND GAS CONSERVATION COMMISSION July 19, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1R-29 ARCO Alaska, Inc. Permit No. 91-94 Sur. Loc. 454'FNL, 136'FWL, Sec. 20, T12N, R10E, UM Btmhole Loc. 557'FSL, 2176'FWL, Sec. 21, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. Sincerely, }rman,D~a_v_i,d_~ax~aWui ervation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill [] Redrill D I lb. Type of Well Exploratory D Stratigraphic Tesl [] Development Oil [] Re-Entry ri Deepen r-~I Service ri Development Gas ri Single Zone [] Multiple Zone D 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB 88'r Pad 45' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25636, ALK 2569 4. Location of well at surlace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 454' FNL, 136' FWL, Sec. 20, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 945' FSL, 1510' FWL, Sec. 21, T12N, R10E, UM 1R-29 #UG30610 At total depth 9. Approximate spud date Amount 557' FSL, 2176' FWL, Sec. 21~ T12N, R10E, UM 7/30/91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 1 R-26 11,269' MD 557'@ TD feet 60' ~ Surface feet 2560 6,844' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 57° Maximum sM,ace 2438 psig At total depth (TVD) 3300 psig 18. Casing program Settinc~ Depth size Specifications Top Bottom Quantify/ of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD 'rVD {include stage dataI 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' d:200 CF 12.25" 9.625" 36.0# J-55 BTC 6224' 43' 43' 6,267' 4,118' 1280 Sx Permafrost E & HF-ERW 560 Sx Class G 8.5" 7" 26.0# J-55 BTC 11226 43' 43' 11~269' 6~844' 250SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Presenl well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured deplh True Vertical depth !'°in;d~Utc~tr°al RECEIVED Intermediate Production d U L - 8 t991 Liner Perforation depth: measured Alaska 0ii & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee r~ Property plat D BOP Skelch r~ Diverter Sketch [] Drilling program I~ Drilling fluid program ~ Time vs depth plot ri Refraction analysis ri Seabed report D 20 AAC 25.050 requirements ~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~J~~ Title Area Drilling Engineer Date "'~/~/ '"' - / ~ Commission Use Only m Permit Number IAPlnumber [Approval date IEee cover letter for .?/'- .~:~ ~Z/ 50- ~ ~- 'ff --' ~-- Z / ~.b'" ~) ~'~ '"" -/~ -- ~' /' other recluirements Conditions of approval Samples required D Yes ~ No Mud log required I~] Yes ~ No Hydrogen sulfide measures ri Yes ,,~ No Directional survey required ,~ Yes D No Required working pressure for BOPE Fl 2M 3M r'l 5M D 10M D 15M Other: ~ ('-"~. ' by order of Appro _ _ _ Commissioner the commission Date..~' ../ DRILLING FLUID PROGRAM (1R-29) Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 8.6-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% _+ Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2438 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1 R-29 is 1 R-26. As designed, the minimum distance between the two wells would be 60' @ Surface. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or Kuparuk Field well with open annulus used for disposal. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. ARCO ALASKA, Structure' Pod 1R Well ' 29 Field · Kuparuk River Unit Location · North Slope, Alaska o.oo E a s f 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6;0006500 7000 7500 I I I I I I I I I I I I I I I I SURFACE LOCATION: ~;~ ~ 454' FNL, 136' FWL I 0 v~ ,SEC. 20, T12N, RIOE, ~'reated by i jones For: FITZPATRICK ~ 1000 )Gte plotted ; 29-Jun-91 ~ _ Plot Reference is 29 Version ~5. ~ ~ TARG~ LOCATION. I Coordinat ..... in feet ret ....... Io~ ,29. ~ ISEC. 21. T12N. RIOE~ _ True Vertical Depths are reference wellhead, EASTMAN 7J~CHRISTENSEN ~ ~%~ -~o~o ~:~o - -- ~ ~ SOUTH 3881 ~T 6654 - 7703' (TO TARGET) ~00 - - ~ - -40~ ' ' - I KOP ~O=300 TMD=300 DEP=O -4500 ~ 500- ~ ~.00 e ~ 9.00 - ~ - ~ 15.00 ~ ~5~- ~ 39.00 ~ ~45.00 8/ PERMAFROST ~D=1653 TMD=1804 0EP=562 ~ ~1~0 EOC ~D=1901 TMD=2199 DEP=869 3000- ~ 3500- ~ 1/ W S~K S~Bg ~D=3483 1~D~5102 D[P~3303 ~ 4000 B/ w SAK SNDS WD~918 T~=590~EP=3972 ,I SAGO- AVERAGE ANGLE ~ v _ 57 OEO Anc~om~ 6000_ TAROET_ ,~p=6~4~ TMD=IO~50 DEP=770~ 6500- - B/ KUP SNDS ~D=67~5 TMD=llO69 7000 TO/ LOOOINO PT ~D=BB~4 TMD=11269 i i i I i i i i i i i i i i I i i i i i i i i i 1 I i i i i i I t i i i i i 500 0 500 1000 1500 20~ 25~ 5000 3500 4000 4500 5000 5500 60~ 65~ 7000 7500 8000 85~ 9000 Scele 1 ' 250.00 VeHicel Section on 120,25 ezimufh with reference 0,00 N, 0,00 E from slot ~29 1,50 _ 200 . 250 30O 350 _ 400 _ 450 . 500 _ 55O 50 100 150 200 250 300 350 400 450 500 550 I I ! I I I I I i, ! I _ 150 / , ,, I . 200 I i J 300 I , _ j 350 I J 400 ~ " '- -'" -'" -'" '-'-rSe°- -' -' -' -' '- -' -- -- - _. 450 ~ ? ~oo I ~ I I I I I I I I 50 100 150 200 250 300 350 400 450 500 550 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1 R-29 , , , . . 1 . . 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,267') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (11,269') according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED Alaska Oil & Gas Cons. Anchorage ,6 , 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUMC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3(X)0 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLI~DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)0 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)O PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3(XX) PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED J U L ~ 8 ~99~, Alaska OiJ & Gas Cons. Comm[ssio~ Anchorage KJPARUK RIVER UNEI 20" DIVERTER SCHEMATIC I I 6 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 5 HCR 4 5 HCR MAINTENANCE & OPERATION 3 I I. . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) REC[IV[D 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 117' OUTLETS. 5. d U L ~. 8 ]993 ,Alaska Oil & ~as Cons. ~ommissio[~ Anchorage 117' HCR BALL VALVES WITH 117' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ITEM (1) Fee (2) Loc 2. 3. 4. 5. 6. 7. . / 8. (3) Admi. [9 thru 1'3]'z , 10. [10 g 153 12. [Lq ~hru 22] LS. (5) BOPE [23 thru 28] (6) Other (6) Addl ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE D T [~[2~hrU ~h) thru '3 :[ ] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company Is permit fee attached ............................................... Is well to be located in a defined pool ............................... Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is 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 ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ?;~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Add i t i ona 1 requ i rements ............................................. Lease & Well YES NO REMARKS // geology: eng i neer i ng~ DW . B EW.,~L RAD dH,.- rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. * ALASKA COMPOTIMG CENTER * ****************************** *------- SCHLUMBERGER ****************************** COMPANY NAME : ARCO ALASKa, INC, FIELD NAM~ ! KUPARUK RIVER BOROUGH : NORTH SLOPE STATE t ALASKA API NUMBER : 50-029-22195 RECEIVED FEB 2 5 1992 Alaska 0il & Gas Cons. Commission Anchorage ~IS Tape Verification Llstim<~ ~chlUmber~er AlasKa.. ComputinQ Center 04:20 PAGE{ SF, RV!CE i'~4E : EDIT O~I~Ih) ~ FLOC REEY.: ~A~E : 74~54 CO~,;~IMUATION ~ PREVIOUS REEL CO~t~E~T : ARCO ALASK~ I~,~C., 1R-29, KUPARUK {~IVER, 50-029-22~95-00 SEN¥ICE ~4A~E : EDiT DATE : 92/01/2i O~IGiN : FI,IC T~PE NA~E : 74854 CONTIN(.I~TIO~ ~ : 1 PPEVIDUS TAPE : CO~MENT ~ At~CO ALASKA 3liNC., 1R-29, KUP&RUK RIVE~, 50-029-22195-00 FILE NA~E : EDIT ,00! SERVICE : FLIC VERSION : 00iA06 DATE ~× BEC SIZE : ~024 FID~ TYPE L~ST FILE ****************************************************************************** FILE - EDIT,00~ ARCO ALASKA INC. KUPARUK RTVER 1R-29 50-029-~2195 PASS LWD LOG DATA DENSITY OATA PRESENTED ON THIS LIBRAPY TAPE IS FROM 'RHO8 MAX' D~TA SA~PI.,ED EVEPY -.5000 FEET DATA I~CL~DFD 'COOL ~XTCNS~O~ TYPE USED CDP .L~O CD~ .bwO TOO.% bOGGI~G ~;,~!4. ILE ORIbbIt,~G RESISTIVITY/GR 6042' TO 11304' bOG~I~G '¢~,~.f. bE DRILLINC, N~TUTRON/OENSITY 6042' TO I~240' ~IS Taoe Verification Listing ~chlumberqeralaska Comoutinq Center 2J-JAN-lq92 04:20 COMPUTING CENTER RE~ARK$ (20-JAN-92): THIS LIBRARY TAPE HAS BEEN REVISED TO iNCLUDE RECAL!BRATED CDN DENSITY DAT~, DATA PRESENTED IS FROq 'RHOB MAX'. PAGE: TABLE TYPE : C0~$ TUNI VALU OEFI TYPE ''''''''''' ...... ''' ............ R' .... ' .... -R'''~''' ...... '''''''''''m~anyNam ..... ''''''''''''''''''''''''''''''' CN A CO ALASKA NC Co e FN KUPARUK RIVE Field Name ~T ~T MT FT FT FT FT CP F3 OH~N OEGF FL SECT TOWN COUS STAT N~TI LATI WITN PD~T L~F a~D EDF TDL DFT DFD DFP~ DFV DFL ~T ~FST ~CSW TCS IR-29 50-02g-22195 454' FNL & !38' FWL 2O 12N NORTH SLOPE ALASKA 548122 MSL 1,1368. Ii368, 6042. 10.2 9 6.40000~ 3.72 75. 07:00 15-AUG-gl DEGF 45. DEGF 1454. Well Name AP1 Serial, Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness' Name Service Order Number Permanent datum Elevation o~ Perm, Da Loq ~easured From A~OVE PERMANENT DATUN Elevat$on of Kell Bu Elevation o~ Dorr~ck Elevation of Ground t, Total Depth - Driller Total DePth - Logger Bottom Log Interval Top Log Interval _ D~llling Fluid Drilling Fluid Densit Drllllnd Fluid Ph Drilling Fluid ¥iscos Drilling Fluid Loss Resistivity of ~ud Sa ~ud. SamPle Temperatur Resistivity of mud fi ZONE ~.ud. Filtrafe SamPle T ZONE Resistivity of ~ud Ca ZONE ~ud Cake Sample Tempe ZOnE Time Circulation Stop Surface Temperature Bottom Hole Temperatu verification 15istinq ~cblumberqer AlasKa ComPutinq Center 21-JAN-1992 04:20 TYPE TABLE TYPE I CURV DEP~e~T Depth C ann. 1 Name ROS~ SS2 RHO Dems~,t¥ - bDT R~O~ Bulk Densltv DPMO Delta PMF Photoelectric Factor DCAL Differential Caliper DPI{I Density Porosity DPO~ Density Porosity Output from an Application Program T~P~ Thermal Meutron Porosity ATR ~GS BHC ATTENUATION RESISTIVITY PSP RGS BBC P)!ASE SHIFT RESISTIVITY DER DIELECTRIC RESISTIVITY FROM RGS ROPE RATE OF DRILLING P.~ETRATION GR Gamma Rav .. ** DITA FORMAT SPECIFICATION RECORD ** ** SET TYPE 64 B ** .....TYPE'''''''''''''~'REPR COD .... ;;~' ! 66 0 2 66 0 3 73 56 4 6~ 5 66 6 73 7 65 8 6~ 0 5 1~ 66 12 13 66 0 !4 65 FT lq 66 68 !6 66 0 66 0 ~IS Tape Verification 5istinq ~cblu.m. berqer AlasKa Computing Center 21-jAN-t992 04:20 PAGE: 4 LE N[JM~ UMB SI CLASS ~OD NUmB SA,~D EDEM CODE (HEX) DEP? FT 548122 00 000 RO$~ DWD G/C3 5q8122 OD 000 RHO~ L~D G/C3 548122 00 000 PPHn bWD G/C3 548122 O0 000 P~F L~D 549122 00 000 DC~I, [,~D IN 54~122 00 000 DPHI L~D PU 548122 00 000 DPOR LWD PU 54~122 00 000 ?~DH L~D PU 54~.22 00 000 ATR b~O OHaM 549122 O0 000 PSR h~D OHH~ S4~122 00 000 DER L~D OHH~ 54~122 00 000 RflP~ LWP ~/HR 548122 00 000 G9 LwD GAPI 5q8t22 00 0o0 O0 0 1 I 1 4 68 0000000000 O0 0 ~ I i 4 68 0000000000 O0 0 1 1 1 4 6@ 0000000000 O0 0 I t 1 4 68 0000000000 O0 0 1 t, !, 4 6~ 0000000000 O0 O 1. 1 1 4 68 0000000000 O0 0 I 1 1 4 6~ 0000000000 O0 0 1 i 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 I 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 I t ! 4 68 0000000000 O0 0 i 1 1 4 6~ 0000000000 O0 0 1 1 I 4 68 0000000000 DATA DEPT. 11368,500 RO$2 LWD -999 TNPH ~ bwg -999,250 ATR. L,~.D- -999 ROP~. I,%~D 72, t45 GR, LWD -999 DFPT. 11300,000 ROS2.LWD -999 DEF,I,~D -999,250 DCAL,bwD -999 TNDH.L~D -999,~5<) ATR,LWD 3 D~P~'LwO 84,1.16 GR.LwD -999 DEPT. 11200.000 RO$2,bwD 2 DEF.L~D 3.493 DCAb.bWD 0 TEPH.LWD 46.000 ATR L~D 2 RODF.[,~ 49,452 GR~I~WD 82 DFDT. lllO0.O00 ROS2,LWD 2 DE~,[,~D 2.722 DCAb,LWD O TND~.LWD 33 500 ATR.bWD 9 ROPW.L~9 25:5~2 G~.LWD 52 D~DT. 11000,000 ROS2.bw9 2 PEF,LWO 3.009 DCAb. I, WD 0 T~PH,[,'~ 31.50(? ATR.L~D 3 10900.00~ ROS2.t.wD 2 2.865 DC~h.bwD 1 36.000 A'I'R,bWb 5 26.799 GR,bWD 68 .250 ~HOB.bwD 999,250 DRHO,LWD ,250 DPHI,b'~D ~999,250 DPOR,bWD 250 PSR,LwD -999.250 DER,LWD '250 . .250 RHOB,hWD -999.250 DRHO,LWD ,250 DPHI,bWD -999 250 DPOR,bWD ,003 PSR,[~WD 3~580 DER.LWD .250 ,426 RHOB.%WD 2.426 DRHO LWD .359 DPHI,hWD 13.600 DPOR:SWD .758 PSR,bWO 3.144 DER,LWD .563 ,378 RHOS,hWD 2.378 DRHO.LWD ,1.10 DPHI,LWO 16,500 DPOR.,LWD ,893 pSR,LWD 11.648 DER,LWD ,333 .461. RHO8,LWO 2.461 DRHO.LWD .414 OPHI.bWO 11.400 DPOR,LWD .92! PSR.Lwo 4.247 DER,LWD .150 .355 RNO~.bwO 2 355 DRMO.LWD .376 DPHI.hWD 17~900 DPOR LWD ,376 PSR.'Gw9 5. 349 DER:LwD ,170 '999,250 -9 , 2S0 -999:250 -999 50 : 009 0 o'ooe 1 0 015 11:400 4,128 i0,011 ,900 ,358 ~IS Tane Verlficat~on Listlnq ;chlumberQer AlasKa ComDut~.n.q Center DF. pT. 1..0800,,000 T~PH. b~b 36. 200 D~PT. 10700.000 T~.~PH, L~D 33,800 DE'PT 10600 · ~ PEF L~P 3,9~5 T~P~, LWf? 34 DFiPT 10500.O00 ROS2.LWD PEF'[,~O 3.316 DCAL.LwD T~P~ ~ L~D 37,900 ~TR; b~O ROPE, LWD 97. 299 GR'. LWD 0,000 R O $ 2. b W'D 3'590 DCAL.LWD 50,400 ~TR. bWD I. 558 GR, LWD DEPT 10300,000 ~OS2.bwO 'PE~'LWD. 3,331 OC~b,LwO ..... '-~ LWD TNp~ b~r) 50,100 ATR, ~ ROPE.L~D 1{2,649 GR,LWD DMPT, 10200,000 pEP.LWD 3,492 DCAh. LWD T~P)"~, LwD · 52.1 O0 ~TR, LWD ROpF, LWD 114,895 GR, DFPT, 10000.000 ROS2,LWD mEP.L~D 3.967 OCAb. LWD PPPP.I. YO 219.655 GR.LWO DFPT. 9900.000 ROS2.LWD PEP,LWD 3,243 OCAL,LwD TMp.n. [,,~>~D 45. 300 ATR. ROPF. [,,Wm 2g 1,341 !)EP?' 9800 00() ROS2 L~D r~RF' LFD 3:349 OCli,' ' ~, r'~ T~;Pn [,,~n 50,000 ATR, L~,'O RoP~'. t,., w b 171,561 GR. hWO 2~-jA!~-1992 04:20 1. 0 12 2,409 1.037 DPHI,b~D 5.915 PSR.L~D 65.763 ~,493 R).!OB,I~WD 0,919 DPN!,b~D 3.691 73.504 2.63~ RHOB,SWD 0.533 DPHI.LWD 3,~59 PSR,LWD 93, 2.567 RHOB.LWD 0.691 OPHI,bWO 2.824 PSR,bWO 5,i41 2.44:8 RHOB,LWO 0.543 OPHI,bWO 1,955 PSR.LwD 94,546 2,380 RHOB,LWD 0.058 OPHI,BWD 1.776 PSR.LWD 97.307 2,437 RHOB.LWO 0,202 DPHI,LMD 2.001 PSR.LWD 7.396 2.366 R. HOS.LWD 0,195 DPHI,L~O 3 059 PSR.LWD 2:756 2,394 RHOB.LWD 0.~5 DP~I,bWO 2, 7 PSR.LWD !3~,453 2 313 RHOB, 5~wO 0:091 DPW!.LWO 2 379 PSR.LWD 9o:g6 2.41~ 0,185 DPHI,LWD 3.22J. PS.R.b~O 2.409 14 600 6:593 2.493 9.50O 3.634 2.631 .200 .775 2 567 5i000 3 388 2.448 633 2.380 16,400 2.493 2.437 12.900 2.384 2.366 17.200 3.928 2.394 15.500 3.240 2.313 400 2.418 14.000 4.024 DRHO.bWD DPOR.bWD DER.LWD DRHO LWD DPOR:LWD DER,LWD DRHO DPOR!LWD DER LWD DRNO..LWD DPOR,LWD DER,LwD DRHO,LWD DPOR,LWD OER,LWD DRHO.LWD DPOR.bWD DER.bWD DRHO,LWD DPOR,LWD DER.LWD DRHO.LWD DPOR,bWD DER.LWD DRHO.LWD DPORLWD DMR:LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.I. WD DPOR.hWD PAGE~ 0.012 I~,600 0.027 ~,500 ,653 o'o2 1,200 3,511 0,009 5,000 3'i40 "0,008 2' 300 2,279 -0.,0~2 099 ~0,010 2 06 -0,004 l:i°° I 26 '0,012 .500 I :999 -0 034 20:400 2,921 0,008 ;4:osoo ] 66 ,IS Tape Verlf~lcatlon Listing 21-JAN-1992 04:20 ;chlumber~er AlasKa Comp,Jting Center PAGE: DFPT, 9700.000 Re. IS2, bWO 2.503 RHOB.bWD 2,503 PE;F, I..~O 4.035 DCAb, Lwl} 0,il. 3 DP~!,~D 8,900 T~p~. L¢3~ 40.000 hTR. L~,~O 3,457 PSR. bi, qD 4.083 ~OPE. [,WP ~ 53. 323 GR. LWD 97,589 DEPT, 9600,000 ROS2.LwD 2.393 R}4OB. bWD 2 393 PEW bwD 2.93~ F)CA b.t.~D 0.214 DP~!,LwD 15:600 TNFN ~ L'wD 41.50~ ATR. Lt'.~D I .964 PSR. LWD 1.858 ROpF. L~wD 10~, 909 GR. [,wD 68,372 DFPT 9500,000 ROS2 L~{O 2.371 RHOS,LWD ~.371 vEF[LWD 2,9~4 DCAL:L, WD 0,007 DPNI.,LWD 16,900 TNP~,LWD 35.600 ATR.bWD 2,402 PSR.LWD 2,593 ROP~.LWD 138,612 GR.LWD 9~ ,679 D~PT. 9400.000 ROS2,LwD 2.411 R}~OB, hWD 2.411 PEF*LWD 2,997 DCAL,LWD 0.103 DP~I,LWD 14.500 T~P~.LWD 38,100 ATR.BWD 2,148 PSR,B~D ~.272 ' , .,. . 6 78.270 ROPF L:~D 244 4~,7 GR.LWD [)EPT 9300,000 ROS2,LWD 2,358 R~OB,hWD 2.368 "PEF[L¢~D 3,063 DCAL,LWD 0,028 DPHI,~WD 17,100 TNP{~. L¢~D 40,500 ATR.LWQ 1.964 PSR,LWD 2.13t, ~op~', t.,~O 188,439 GR.. 5WD 73,552 DEPT 9200'000 ROS2,LWD 2 360 RHOB,LWD 2 360 peg' ' ' T~pH,LWD 3,068 DCAL, LWD 0,036 DP~I.. 5W{) 17~600 .LWD 39,800 ATR,LWD 2,000 PSR,B~D 2.122 ROPE. LwD 294. 675 GR,bWD 76,609 DFPT. 91.00,000 ROS2,LwD 2,323 RHOB,[~WD 2,323 P~;F [, W [;, 2,998 DCAL,LWD 0.112 DPH!,LWO 19.800 TNP~'~'L~,.~D 38 200 ATR LWD 2.202 PSR.LWD 2 294 Ro'pF. L~D 304. 201 GR,LWD 75,754 DEPT, 9000,000 ROS2,LWD 2.3i0 RHO~5.LWD 2.310 PEF.LWD 2.7~1 9CAb. LWD 0.000 DPHI.LWD 20.600 TNPM,LWD 36.300 ATR.LWD 3.388 PSR.hWD 3.84~ ROPF, hwp 242,148 GR, LWD 82. 667 DEPT. 8900.000 ROS2.LWD 2.369 RHOB.LWD 2.369 000 PEF. Lk~D 3.200 DCA~. h~D 0,053 DP~I. hud i :058 T~/P~. L~',~ 36,300 ATR.LWD 3,514 PSR,LWD ROPP. L~O 327,019 gR. LWD 82. 932 DFPT ~800.000 ROS2 hw'~ 2.350 RHO~.LWD 2.350 PEV~L~D 2,823 DC~L~I, Wb 0.022 DP~I,bWD 1~.200 T~p~. L,,,~.. 46.900. ATR.LWD. 2,!87 PSR. DWD 2.493 Rr3pE. L~,~[) 305,962 GR, LWD 9 !. 654 DEPT. 8700.000 ROS2.L~O 2.385 REOB,LWD 2.385 P?F.LWD 3,149 DC~h,LWD 0,000 DPHI,LND 16.100 T~Pg. L~r~ 38,100 AT~.L~b 3,~i9 PS~, [.~qD 3,275 pOp~. L;{D 329,875 GR. LWO 85. 200 DRMO.LWD DPOR.bWD DER,LWD DRHO.LWD DPOR.LWD DER.LWD DRMD,LWD DPOR.bWD DER*LWD DRH0,bWD DPOR,L~D DER,LWD DRHO.LWD DPOR,bWD DER,LWD DR~O.LWD DPOR LWD DER~LWD DRHO,hWD DPOR,LwD DER.LwD DRHO LWD DPOR!LWD DER LWD DRHO.LWD DPOR,LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD LWD DRHO, ~ DPOR.LWD DE~.LWD ,900 .824 0,000 15,600 t,896 , 14, 2.~22 -0,003 17,!00 2,061 [o,oo 7,600 2,072 -0.022 20,600 3,660 '0,0%3 17,000 3,838 ~0 021 8~200 2,360 ,100 3,217 !IS Tape verification l.fstincl 21-JA.N-~992 04:20 PAGEI 7 ;chlur~berqer AlasKa Computlnq Center DEPT. 8600.000 RO$2.LWD 2,409 RHOB.LN0 2 409 DRHO,b~D -0,033 PEW.bwD 2,888 DCAL.LWO 0.16~ DPN~,LWD 14:600 DPOR.LWD I~,600 TNP~ LW~ 30 300 ATR,T..~..D 3,621 P~R L~D 4 7~1 DER LWD 2~1 ROpm, L'~ 191 , 659 G~ . LWD 76.6~'1 8500 O0) ROS2 LWD 2.438 2.99] DCAL LWD 0,I08 37,800 ATR' hWD ]. 347 321,207 GR ~ bWD ~8,890 DEPT.L~[) 8400.000 RDO$2..bwo 2.400 PEF,,., .~ 3.068 .. CAS.LWD 0.116 !'NP~. LWD 38,000 ATR.L, WD 3,182 ROP~.G"~D,~., 3~1,366 GR.LWO 87,02I DFPT. 8300,000 ROS2.LWD 2,396 PEF,L~O 2,947 DCAL.bwD 0.157 T~PH.LWD 37,900 ATR,LWD 2,791 ROP~.LwD 2!5,7~2 GR.LWD 87,293 QEPT, 8200.000 ROS2,LWD 2,365 PEF.LWD 3,070 OCAL.LWg 0,01~ TNP~.LWD 38,800 ATR.LWD 2,850 ~OPE.L~D 224,524 ~R.LWD 89,421. DEPT 8100.000 ROS2.bwD 2.381 PEF:LWD 2.992 DCAb,LWD 0.144 ?NPH,LWD i]7,300 ~TR.LMO 3,517 Op~,L~D 289,19~ GR,LI~D 9!,934 [)EDT. 8000.000 ROS2.LWD 2.404 PEV.LWt) 3,096 DCAL,LWD 0.219 TNpH,L~D 40,600 ~TR.LWD 3,551 ROPW,L~D 75,771 GR.L~D 84.833 DEPT. 7900.000 RO$2.LWD 2.330 ~ ~ 'EF. L~tO 2,887 DCAb,LWD 0.000 TNPN.LW~ 35.300 ATR.LWD 3 550 ROPE,LW~ 362,196 GR. LWD 76:297 RHOO.LWD 2 438 DRHO LWD DPHI,bWD 12:800 OPOR!LWD li:800 PSR,LWD 3,429 DER LWD ' 400 RHOB,LWD 2.400 DRHO.LWD -0':0~4 ~PHI,LWD 15,200 DPOR~LWD ~5,200 PSR,LWD 3,341 DER,LWD 3,282 RHOB.bWO 2.396 DRMO.LWD -0,004 DPHI.hWO 15,400 DPOR.LWD t5,400 PSR,LWD 2,797 DER,LWD 2,794 DPHI'LWD 17:200 DPOR,LWD ~7. PS",LWD ~.~40 DER.LWD 2:907z~v RHOB,LWO 2,404 DRHO,LWD 0,004 DPHI.LWD 14.gO0 DPOR,LWD 14,900 PSR,LWD 3,490 DER,LWD 3'510 DEr"~. 7800.000 PO$2.hWD 2.390 RHOB,LWO 2 390 DRHO.5WD -0,009 .... ~F L~O -3.044 DC~L.LWD 0.035 ~PHI,hWD 151800 DPOR.LWD *~,000 TNP~: L v:~ 35,200 ~TR. L~O 4,199 PSR, LWD 4. 077 DER, LWD., .115 ROP~,LW~ 415,593 GR,LWO 85,119 DFPT, 7700.000 ROS2,LWi) 2.353 TNP~, bW~'> 38,600 ~TR, bWD 3,121 pOp~ bWD 51i.415 ~R.L~ ~ 400 DFpT. 7600,000 ROS2.bWO ?.279 PEF,b~9 9,743 DC~L.GWD 0,036 T~PH.I,!~n 39.400 ATR.LWD 3.064 ROPF.L~ 394,319 GR.Lw~ 77,293 ~HOB.bWD 2.353 DRHO.LWD -0,014 DPHI.bWD 18 000 DPOR.LWD 18,000 PSR.L~D 3:108 DER.LWD 3,112 RHO!:3. bY; O 2. 279 DRHO.LWD ~0.011 DPHI.LWO 22.500DPOR.LWD ]:500 PS.~.L~O 2.822 DER.LWD : B99 :iS Tare Verification Listlna :cblumberqer ~!as<a Computing Center 21-JAN-1992 04:20 PAGE: DEPT. 7500,000 ROS2,LkiD TNpH, LWD ]8,400 ~TR ROPE. L ~D 516. 093 GR. bWD D~PT, 7400,000 ~0$2.LW~D PEF.UWD 3,055 DCAh. LWD TNDg. LWD 38,200 ROPE,LWD 286,667 G~,hWD DFPT. 7300,000 RO$2.LWD PEF.LND 3,4~I DCgL.LWD TNPH,UWD 44,000 A. TR,LWD ROPE.L~D 44~,68I DFPT, 7200,000 ROS2,L~D PEF.L~D 3,256 DC~L. LWD T~P~ L~D 44,700 ATR.L~O ROPE~L~D 256,515 GR.LWD DEPT. 7100.000 ~OS2,L~U PEF.LWD 2.888 DCA~.LWD , ~r) 45.600 ATR,LI~O RODF.L~dD 361.562 GR.L~Q ~EPT 7000.000 TNPH.LWD 42.700 ATR.LWD RO~W.LWD 463.0qO DEPT. 6900.000 ros2.bw~ PEF.LWD 2,881 DCAI,,LWD T~IPH L~D 44.100 ATR.bWD ROp~'bwn. _, 569,492 DEPT, 6800°000 aos2,bwu PEF,I.,~D 3,120 DC~L,L~D T~PgoL~D 47,100 ATR,b~D ROPF.L~D 484.453 GR.L~:D DEPT. 6700.000 ROS2.LWD PEF.LWD 3.047 OCAL.LWD TNP~.I.WD 50.000 ATR.LWD ROPM.LMn 491.833 GR.LWO DEPT 6600 on() PEF:LwD 3.100 OCAL.LWO T~PH.bwr~~. _ 41.400. ATR.' ROpE.L~D 3!9,229 Dfi'PT. 6500.000 ROS2.LWD ~]F, L~D 3.042 DCAL. b~O TNPg. [..~D 43. 700 ATR. LwD R~PE. L;~D 598.743 GR. L.;,~D 2.345 RHOa,LWD 0.100 DPHI,L~D 2,966 81.866 2.367 RHOB,bWD 0.069 DPHI.LWD S~. 2,774 88.223 2.379 RHOB.LWD 0.!31 DP~I.G~D 3.749 PSR.LWD 81.687 2,357 RHOB.LWD 0.058 DPHI.LWD 3.435 PSR.L~D 83.365 2.377 RHOB.DWD 0.000 DPHI.LWD 2,911 PSR.LWD 88.580 2,349 RHOB,LWD 0,]14 2.748 PSR,L~D 86,i19 2,301 RHOB.LWD 0,068 DPHI.LWD 2,691 PSR.LWD 90.245 2,307 REOB.LWD 0.000 DPHI.LWD 3.183 PSR.LW~ 75,528 2.270 RHOB,LWD 0,000 DPHI,bWD 3.148 PSR.LWD 80.056 2.30g RHO~.LWD 0.000 DPHI.~WD 3,726 PS~.L~D 76,095 2.324 0.000 DPHI,LWD 3.367 80,315 2.345 18.500 2.936 2 367 17:2oo 2.790 2.379 16.400 4.156 ~.357 8OO 13'493 . 2,377 16.600 3.094 2.349 !8.300 2.868 2 ~0! 2 : oo 2.810 2.307 2O 8OO 2.270 23.100 3'428 2.309 20.700 3.~69 2.324 19.700 3.6O4 DRHOLWD DPORiLWD DER LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO'.LWD DPOR,LWD DER,LWD DRHO,LWD DPOR.LWD DER,LWD DRHO LWD DPOR~LWD DER.LWD DRHO LWD DPOR:LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRMO.LWD DPOR.LwD DER.LWD DRHO LwD DPOR:LWD DER.L~D ~,008 ,500 2'946 OO6 '0,003 16'400 4,001 o'oo ~7,800 3,473 822 o'oo ~,200 2,764 2 ~00 46 -0'019 23,100 3.319 3,8!8 000 3,515 ,IS Taee Verification Listing 21-JAN-1992 04:20 PAGE: 9 ;chlumber~er AlasKa Computin~ Center DEPT, 6400.000 ROS2,LWD 2.377 RNOO,bWD 2,377 PEF,LWD 3,2~3 DCAb L,.D 0 000 DP~{I.[~WD I .500 T~P~.LWD 44.000 ATR.GWD 3~518 DSR,LWD ~.761 ROD~.LWD 609.943 GR.LWD 79' 021 DE'PT. 6300.000 ROS2,hWD 2.285 RHOB.bWO~ 2.285 D~F [,,~ D ~,057 DC~.L. BWD 0.162 DPHI,G~D 22,100 TNP}'~: L~AD 47.000 ATR.LWD 3,089 PSR,LWD 3.103 . .. W GR LWD O, ROP~.b 'D 177..43g ' 8 653 DEPT, 6200,000 ROS~,LWO 2,263 RMOB.LWD PEF,LWD 3,003 DCAL.,LWD 0.023 DPHI,bWD TNPH.LWD 43,800 ~TR,LWD 3.9~2 PS~,LWD ROPF.LWD 6~7.142' GR.LWD 71.725 DEPT. 6100.000 ROS2 bWD 2.247 RHOB.~WD PEF.LWD 2.970 DCAb.:LWD 0,086 DP~I,bWD T~PM,LWD 43'200 ATR.LWD 2,875 PSR,LWD RODE.LWD 240.878 GR.LWD 75,149 PEF'LWD 24~51~ DCAL.LWD 0, 7 DPHI,LWD TNPH~LW~ 56.t00 ATR.I. WD -999,~50 PSR.,bWD ROP?, I.,~D -999,250 GR. LWD 44,351 QFPT, 5939.500 ROS~.LWD -999 250 RMOB,bWD PEF,LWD -999.25!) DCAL,LWD -999 250 DPHI,bWD T~PM,LWD -999'250 ATR,LWD -999 250 PSR,LWQ ROPF.I.,WD -999.250 G~,LWD -g99 250 ** END OF DATA ** 2 263 23 500 4 018 2.247 24.400 2.963 2.297 92~, 400 "9 9.250 -999.250 -999.250 -999.250 DRMOobWD 0'010 DER.bWD 6'72 DRMO LWD -0.025 DPOR:bWD 22,100 DER.bWD ~,'098 DRHO.LWD 0,022 DPOR,LWD ~3,500 ' DE bWD 4,009 DRMO.LWD DPOR,LWD ~4,400 DER.bWD 2,9~0 DRHO.,LWD "0,484 DPOR*LWD , 21~400 DER.LWD .999,~50 DRHO LWD' -999~0 DPOR:bWD -999,~50 DER,LWD -999'250 **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION ~ 00lA06 DATF : 92/0~/21 ~AX REC SIZE : 1024 F?LF TYPE : LO LAST FILM : **** TAPE TRAII.ER **** SF~VICg ~!AMK : EDIT OPI~IN : FLIC T~P~ MA~ : 74854 CO~JTINUATIO~ ~ : ~ PREVIOUS TAPE : Cn~KNT : ARCO ALASKA TNC., KUPARUK RIVER, 50-029-22195-00 :IS Ta~e Ver~.flcation bistln<~ Chlumber~er Atas~a Computlnc~ Center 21-J&N-!99~ 04:~0 PAGE{ 1,0 **** REEL TRAILER **** $~R¥ICE NAME : ~DIT DATE : 92/01/2! OPIG!N : FbIC REEY, N~E ~ 74854 C~!iTINOATION # : PRE¥IOUS RE~L : C~M~T : ARCO ALASKA INC., ~R-29, KUPARUK RIVER, 50-029-22195-00
