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184-212
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2W-08 KUPARUK RIV UNIT 2W-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 2W-08 50-029-21228-00-00 184-212-0 W SPT 5734 1842120 1500 1300 1300 1300 1300 320 440 440 440 4YRTST P Sully Sullivan 5/2/2023 pt to 2300 for 500 psi dp, pt with 90 deg. Diesel 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2W-08 Inspection Date: Tubing OA Packer Depth 500 2300 2200 2170IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230503092452 BBL Pumped:2.2 BBL Returned:2.1 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 16:09:06 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Tim Regg <`� j DATE: Wednesday, June 17, 2020 /I/ P.I. Supervisor I�-wo q%'1'I2• 1'r? SUBJECT: Mechanical Integrity Tests 1 ConocoPhillips Alaska, Inc. 2W -O8 FROM: Adam Earl KUPARUK RIV UNIT 2W-08 Petroleum Inspector — 2W-06 -TypeInj Ste: Inspector W Reviewed By: 5734 ' P.I. Supry &jam NON -CONFIDENTIAL Comm Well Name KUPARUK RFV UNIT 2W-08 API Well Number 50-029-21228-00-00 Inspector Name: Adam Earl Permit Number: 184-212-0 Inspection Date: 6/14/2020 ✓ Insp Num: mitAGE200617114843 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well — 2W-06 -TypeInj W TVD 5734 ' Tubing 950 - 950 950 950 PTD 1842120 - Type Test SPT Test psi 1500 IA 400 800 - 710 - 1685 - BBL Pumped: 13 BBL Returned: 1.3 OA 135 140 140 140 - Interval 4YRTST Notes: MIT LA Wednesday, June 17, 2020 Page 1 of I 1��,• 2, �2 a.4111•1 t MAY 1 0 2d1u WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. May 6, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 v1�K/.t6ENDER RE: Injection Profile : 2W-08 Run Date: 11/18/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2W-08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21228-00 Injection Profile Log 1 Color Log 50-029-21228-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANNED "i1`r' Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' va `i L, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg _ P.I.Supervisor 9 DATE: Wednesday,October 28,2015 CI li i. 15 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2W-08 FROM: Jeff Jones KUPARUK RIV UNIT 2W-08 Petroleum Inspector SCMhNEa Src: Inspector Reviewed By: P.I.Supry 1� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2W-08 API Well Number 50-029-21228-00-00 Inspector Name: Jeff Jones Permit Number: 184-212-0 Inspection Date: 10/16/2015 Insp Num: mitJJ151017071035 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2W-08 Type Inj ' W 1TVD 5734 - Tubing j 2125 - 2125 - 2100 2125 1842120 SPT i 1500 920 2800- 2670 2640 PTD - Type Test Test psi IA Interval 4YRTST PAF P OA 325 390 = 390 390 Notes: 1 well inspected,no exceptions noted. Wednesday,October 28,2015 Page 1 of 1 tack 7W --Ce prb 164z t zo Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> 1\�4� {z15f is Sent: Monday, October 05, 2015 2:28 PM To: Regg, James B (DOA);Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk MIT forms and request for extension to 2W-08 (PTD 184-212) MIT Attachments: MIT KRU 1C-119 10-04-15.xls; MIT KRU 2W-08 10-04-15.xls; MIT KRU 3F-03 10-04-15.xls Attached are the MITs performed yesterday in Kuparuk on 1C-119, 2W-08 and 3F-03. All three were 4-year tests. They were shut in during their pad testing and recently returned to injection. Jim, 2W-08's (PTD 184-212) MIT, the test that was waived, needed to be called inconclusive. The day before the testing,the header at 2T needed to be shut in and major reallocation of water across the field commenced. We went forward with the MIT on 2W-08, expecting there not to be significant fluctuations to that particular well. Unfortunately this was not the case. While we expect the header issues to be sorted out shortly and stabilization to be reached within a few days on 2W-08, three other wells on 2W pad were returned to injection yesterday and will need to be witnessed-tested. As such, CPAI requests that we postpone 2W-08's retest until all wells on pad are stable and ready to be tested, in order to maximize everybody's time and resources. We did obtain a passing shut-in MITIA on 2W-08 in May of this year. The well has been online since 9/23/15. Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 SCANNED 1 • 41) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq@alaska.00v, AOGCC.Inspectorsa:alaska.00vs phoebe.brooksaalaska.aov chris.wallaceCrD.alaska.aov OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT/PAD: Kuparuk/KRU/2W DATE: 10/04/15 OPERATOR REP: PhillipsNanCamp AOGCC REP: Waived by Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. Well 2W-08 Type Inj. W TVD 5,744' Tubing 1,950 1,950 2,035 2,065 2,090 2,075 Interval 4 P.T.D. 1842120 Type test P I Test psi 1500 Casing 740 2,800 2,700 2,720 2,770 2,835 P/F Notes: Test considers ncone4bswe_due to OA 220 260 260 260 260 270 Injection rate and temperature fluctuations during test resulting in increases in IA pressure Injection temperature 110-121. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2W-08 10-04-15.xls • STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COM. .�SION REPORT OF SUNDRY WELL OPERATIONS 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 r Perforate New Pool r " Repair Well r Re-enter Susp Well r Other:Install Tubing Patch . I✓ 2 Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory r 184-212 3 Address: 6.API Number P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21228-00 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 25642 KRU 2W-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary. Total Depth measured 7833 feet Plugs(measured) none true vertical 6278 feet Junk(measured) 7560, 7601, 7603 Effective Depth measured 7725 feet Packer(measured) 7070, 7383 true vertical 6200 feet (true vertical) 5744, 5963 Casing Length Size MD J TVD Burst Collapse CONDUCTOR 64 16 95 95 SURFACE 3290 9 625 3320 3136 PRODUCTION 7786 7 7815 6265 RECEWED Perforation depth: Measured depth: 7163'-7308', 7314'-7336',7548'-7611' A U r 2 8 2015 G15 True Vertical Depth: 5809'-5910', 5914'-5930',6077'-6121' 1/ SCAOME AOGCC Tubing(size,grade,MD,and TVD) 3.5, J-55, 7403 MD, 5976 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEVABLE PACKER @ 7070 MD and 5744 ND PACKER-BAKER FB-1 PERMANENT PACKER @ 7383 MD and 5963 ND SSSV-BAKER'FVL' @ 1909 MD and 1908 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 _ shut-in Subsequent to operation shut-in 14.Attachments(required per 20 MC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development r Service Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: , Oil r Gas r WDSPL T Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG rri GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-227 Contact Tyson Wiese 263-4250 Email Tyson.M.Wiese(a�conocophillips.com Printed Name T -on Wiese Title Sr. Wells Engineer Signature \ Phone:263-4250 Date e6.....11 ._ oi5 viz_ C1/2//> RBDMS !ri 1 6 2015 Form 10-404 Revised 5/2015 Submit Original Only 2W-08 WELL WORK SUMMARY DATE SUMMARY 8/8/2015 BRSHED & FLUSHED W/2.64" CENT,3.5" BLB &2.25" GAUGE RING. DOWN TO 7400' RKB... JOB IN PROGRESS. 8/9/2015 DRIFT W/33' X 2.74" PATCH DUMMY DOWN TO 7310' SLM.SET 2.765" X 1.81" D-NIPPLE REDUCER © 7396' RKB.SET 1.81" CA-2 IN NIPPLE REDUCER © 7396' RKB.RAN LDL ABOVE CA-2 PLUG © 7396' RKB TO VERIFY REDUCER& PLUG HOLDING.SAW NO TEMP OR SPINNER MOVEMENT. PLUG HOLDING..JOB IN PROGRESS. 8/10/2015 SET 2.72" HES PERMANMENT PACKER W/ UPPER MID ELEMENT © 7122' RKB & LOWER MID ELEMENT @ 7143.6' RKB.LRS PERFORMED MIT-T,FAILED.RAN LDL TO TOP OF CA-2 PLUG @ 7396' RKB.PIN POINT LEAK BOTTOM OF PATCH © 7143.6' RKB.ATTEMPTED PULLING CA-2 PRONG FROM 7396' RKB,UNSUCCESSFUL... JOB IN PROGRESS. 8/12/2015 BAILED FILL OVER CA-2 PLUG @ 7,350' SLM PULLED CA-2 PLUG @ 7,350' SLM (7,397' RKB). JOB COMPLETE C3A Ne\A ' \1 hIe�0\(1 bele . UAM ,Vo��\ � , KUP INJ 2W-08 Y r3 ConocoPhillips I Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) anon,e4lrps 500292122800 KUPARUK RIVER UNIT INJ 51.03 3,800.00 7,833.0 ... -- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2W-08,8/17/201510:25-.20 AM SSSV:LOCKED OUT Last WO: 36.01 11/26/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 7,572.0 1/16/2015 Rev Reason:SET PATCH,GLV C/O lehallf 8/17/2015 _ Casing Strings HANGER;307 i(tI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread J CONDUCTOR 16 15.062 31.0 95.0 95.0 62.50 H-40 WELDED , = ., aaa,Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE95/8 8.921 30.2 3,320.0 3,1353 36.00 J-55 BTC Casing Description rOD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.0 7,815.0 6265.2 26.00 J-55 BUTT ���CONDUCTOR:31.0950• Tubing Strings Tubing Description (String Ma...IID(in) (Top(ftKB) (Set Depth(ft..1Set Depth(ND)(...I Wt(Iblft) (Grade (Top Connection TUBING 31/2 2.9921 92 3071! 74030 5,976.3 9.30 J-55 EUE 8RD SAFETY VLV;1.908.9 I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 30.7 30.7 0.14 HANGER FMC GEN 01 TUBING HANGER 3.500 GAS UFT;1,953.8 I 1,908.9 1,908.1 8.36 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 2 272006) 2.810 GAS LIFT,2,877.4 7,055.3 5,733.9 46.07 PBR BAKER PBR 3.000 7,069.5 5,743.7 46.04 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,150.6 5,800.0 45.93 BLAST RINGS BLAST RINGS(7) 2.992 SURFACE;30.23,320.0-4 _ 7,382.4 5,961.9 45.88 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.992 7,383.2 5,962.5 45.88 PACKER BAKER FB-1 PERMANENT PACKER 3.000 GAS LIFT;3,326.1-1! 7,385.7 5,964.3 45.90 SEAL ASSY BAKER SEAL ASSEMBLY RECEPTICLE 2.992 7,396.7 5,971.9' 45.96 NIPPLE CAMCO D NIPPLE NO GO;ADDED 2.761"x1.81"D- 2.750 GAS LIFT;4.057.3 '1 Nipple reducer 8/92015 7,402.2 5,975.7 45.98 SOS BAKER SHEAR OUT SUB 2.992 GAS UFT;4,758.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ' Top(TVD) Top Incl GAS LIFT;5,321.0 Top(ftKB) _ (ftKB) (°) Des Corn Run Date ID(in) 7,122.0 5,780.2 45.96 PATCH HES PERM PACKER 8/10/2015 2.250 GAS LIFT,5,893.0 7,560.0- 6,085.3 45.70 FISH GLV Body 8 Spring Lost Downhole 10/12/1992 0.000 7,601.0- 6,114.1 45.42 FISH 27 1/2'Strip Gun Left fish in hole;Reperfed only to 11/5/1991 0.000 7598' GAS LIFT;6,496.5 7,603.0 6,115.5 45.41 FISH 1"OV JUNK on DV in Pocket originally GLM#10; 12/25/1987 0.000 Fell to Rathole-replace DV 4/26/94 No Problem GAS LIFT;7,009.3 Perforations&Slots Shot Dens PBR;7,055.3 J Top(TVD) Btm(TVD) (shots/f Top(RKB) Btm(ftKB) (ftKB) (ftKB) Zone Dale t) Type Corn PACKER;7.069.5 7,163.0 7,308.0 5,808.7 5,910.0 C-4,C-3,C-1, 12/13/1984 12.0 IPERF 5.5"SOS,120 deg.pH 2W-08 INJECTION;7,090.9 7,314.0 7,336.0 5,914.2 5,929.6 C-1,2W-08 12/13/1984 12.0 (PERF 5.5"SOS,120 deg.pH J 7,548.0 7,549.0 6,077.0 6,077.7 A-4,2W-08 11/8/1991 4.0 RPERF 21/8"Dynastrip HLS,0 INJECTION;7,128.9 f. deg pH PATCH,7,122.0 ppy�o `, 7,549.0 7,573.0 6,077.7 6,094.4 A-4,A-3,2W- 11/8/1991 8.0 RPERF 2 1/8"Dynastrip HLS,0 xf Ii,"I Ic Z__ \ 08 deg pH �J J 7,573.0 7,582.0 6,094.4 6,100.7 A-3,2W-08 11/5/1991 4.0 RPERF 21/8"Dynastrip HLS,0 _ deg pH IPERF;7163.0.7,308.0 e - 7,582.0 7,598.0 6,100.7 6,112.0 A-3,2W-08 11/8/1991 8.0 RPERF 2 1/8"Dynastrip HLS,0 deg pH (PERF;7,314.0-7,336.0- 7,598.0 7,611.0 6,112.0 6,121.1 A-3,2W-08 12/13/1984 4.0 IPERF 4"SOS,90 deg pH Mandrel Inserts INJECTION;7,365.8 St an on Top(TVD) Valve Latch Port Size TRO Run SEAL ASSY;7,382.4N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PACKER;7,383.2 1' 1,963.8 1,962.2 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 SEAL ASSY;7,385.7 .1 2 2,877.4 2,782.1 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 3 3,326.1 3,140.4 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 NIPPLE;7,3%.7 4 4,057.3 3,647.8 MMH FMHO 1 GAS LIFT DMY I BK-2 0.000 0.0 12/13/1984 soy;7,402.2 ;'d 5 4,758.5 4,138.9 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 6 5,321.0 4,531.2 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 RPERF;7,548.0-7,549 0-- - 7 5,893.0 4,930.7 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 FISH;7.560.0 8 6,496.5 5,347.7 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 RPERF;7,549.5-7,573.0-� >, 9 7,009.3 5,701.9 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 1/5/1985 RPERF,7,573.0.7,582.0 .... - 1 7,090.9 5,758.6 MMH FMHO 1 INJ DMY BK 0.000 0.0 4/26/1994 0 RPERF;7,582.0-7.598.0 .-.. s 1 7,128.9 5,785.0 MMH FMHO 1 INJ CV BK 0.375 0.0 2/15/2015 - 1 -Y - 1 7,365.8 5,950.4 MMH FMHO 0.0 INJ DMY BTM 0.188 0.0 2/20/1997 2 FISH,7,603.0 Notes:General&Safety 7,598.0-7,611.0 End Date Annotation FISH;7,601.0 12/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/5/2012 NOTE:2 RIGS RKB DIFFERENCES ACCOUNT FOR PROD/TBG TOP OVERLAP PRODUCTION;29.0-7,815.0 K€(4 zw—ov forb 1S9zlz-o Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> S'i3j�'S Sent: Tuesday, May 12, 2015 7:56 PM c9 / To: Wallace, Chris D (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Senden, R. Tyler Subject: KRU MIT forms Attachments: MIT KRU 1G-05 05-8-15.xls; MIT KRU 1R PAD 05-08-15.xls; MIT KRU 2E-03 05-09-15.xls; MIT KRU 2M-14 05-09-15.xls; MIT KRU 2V-04 05-09-15.xls; MIT KRU 2W PAD 05-09-15.xls; MIT KRU 2W PAD SI 05-09-15.xls fL _ 2,1 J.., a w- 0 Attached are copies of the forms for the recent MIT's performed at Kuparuk. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. JUN Desk Phone (907) 659-7224 SCANNED f 82015 Pager (907) 659-7000 pgr. 909 AV:ELLS TEAM c lLps 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to jim.regqaalaska.gov• AOGCC.Inspectors@a alaska.gov• phoebe.brookscalaska.gov chris.w/allace@alaska.gov I� OPERATOR: ConocoPhillips Alaska,Inc. Oil �Tt7,IS FIELD I UNIT I PAD: Kuparuk/KRU/2W DATE: 05/09/15 OPERATOR REP: Manjarrez,Beck,Hollandsworth,Duffy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2W-04 Type Inj. N TVD 5,696' Tubing 640 640 640 640 Interval 4 P.T.D. 1850120 Type test P Test psi 1500. Casing 250 1,800 1,730 1,710 P/F P Notes: Non-witnessed OA 60 60 60 60 Inspector elected to not witness test on shut in well Well 2W-05 Type Inj. N TVD 5,690' Tubing 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 1841910 Type test P , Test psi 1500 Casing 350 2,320 2,220 2,200 P/F P Notes: Non-witnessed OA 175 175 175 175 Inspector elected to not witness test on shut in well /...... .. a\ Well 2W-08 Type Inj. N TVD 5,744'1 Tubing 250 250 250 250 Interval 4 P.T.D. 1842120 Type test P Test psi 1500 Casing 600 1,820 1,760 1,740 P/F P Notes: Non-witnessed OA 60 60 60 60 Inspector elected to not witness test on shut in well Well 2W-09 Type Inj. N TVD 5,686' Tubing 520 530 530 530 Interval 4 P.T.D. 1842190 Type test P Test psi 1500 Casing 520 1,800 1,740_ 1,720 P/F P • Notes: Non-witnessed OA 55 55 55 55 Inspector elected to not witness test on shut in well Well 2W-16 Type Inj. N TVD 5,745' Tubing 1,250 1,250 1,250 1,250 Interval 4 • P.T.D. 1842390 Type test P Test psi 1500 Casing 440 2,000 1,920 1,910 P/F P • Notes: Non-witnessed OA 80 80 80 80 Inspector elected to not witness test on shut in well _ Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F • Notes: OA Well Type Inj TVD Tubing Interval P T D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval _ P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2W PAD SI 05-09-15.xls i<OF s THE STATE Alaska Oil and Gas °fALASKA Conservation Commission ori-t==i-A 333 West Seventh Avenue 0�Tti / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 P Main: 907.279.1433 ALA`3* Fax 907.276 7542 www.aogcc.alaska.gov Jay Maguire SCONEL Wells Engineer f` 3 ConocoPhillips Alaska, Inc. g rl P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2W-08 Sundry Number: 315-227 Dear Mr. Maguire: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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 thisj 2 of April, 2015 Encl. STATE OF ALASKA AL .CA OIL AND GAS CONSERVATION COM. ,ION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ry 1.Type of Request: Abandon r Aug for Redrill r Perforate New Pool r Repair w ell Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:lnstall Tubing Patch .170 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.' Exploratory r Development r 184-212 • 3.Address. 6.API Number: Stratigraphic r Service • P.O. Box 100360,Anchorage,Alaska 99510 50-029-21228-00 • 7.If perforating, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r ✓ KRU 2W-08 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25642 . 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): 7833 • 6278 • none 7560,7601,7603 Casing Length Size MD TVD Burst Collapse CONDUCTOR 64 16 95' 95' SURFACE 3290 9.625 3320' 3136' RECEIVED � PRODUCTION 7786 7 7815' 6265' CI V ,,,,D APR 14 2015 DGS $/ t 7 i is .AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade: Tubing MD(ft): 7163-7308,7314-7336,7548-7611 ' 5809-5910,5914-5930,6077-6121 3.5 J-55 7403 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL RETRIEVABLE PACKER MD=7070 TVD=5744 • PACKER-BAKER FB-1 PERMANENT PACKER MD=7383 TVD=5963 • SSSV-BAKER FVL SSSV MD=1909 TVD=1908 . 12 Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program IT BOP Sketch r Exploratory r Stratigraphic r Development r Service r• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/27/2015 Oil r Gas r WDSPL r Suspended E 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. Jay Maguire @ 263-4551 Email: Jay.C.Mcguire@conocophillips.com Printed Name Jay Maguire Title: Wells Engineer Signature fgar......._ Date Phone:263 4551 VI 3/)5 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 6-22:1 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No 12 Subsequent Form Required: /d — 4 U 4/-- J� APPROVED BY Approved by: T� COMMISSIONER THE COMMISSION Dat9: —(/ 7-1-) Approve pert int mo the troffm the date of approval. 4/..,/7.../5 Form 10-403(Revised 10/2012) 1� Il Submit Form and Attachmgnts in Duplicate V77— 41/7//S *y/1 /4— RBDM APR 2 0 2015 + r • RECEIVED APR 14 2015 ✓ Interoffice Aon r ConocoPhillips Communication Date: April 13th, 2015 File code: Well file 2W-08 Subject: 2W-08 Tubing Patch Installation From/Location: Jay Maguire /ATO-2039 Telephone: 263-4551/ 832-541-8091 To/Location: Central Wells Group, NSK-69 Network Number: 10379791 Activity: ZX64 2W-08 injector was drilled and completed in 1984 with 3.5", J-55 tubing and perforation intervals in the Kuparuk A & C-sands. On 1-16-15, the tubing was drifted with 2.67" to fill at 7577' SLM. On 2-15-2015 a hole finder was run to determine a leak from the injection mandrel @ 7129' RKB. A 20' permanent tubing patch will be set at 7,119' — 7,139' RKB. The estimated NOB for the patch job is 30 BOPD. Per this procedure, SL will brush and flush the tubing from 7,100' RKB- 7,300' RKB then run top of dummy patch drift (30' X 2.75")to 7300' RKB, then SL set a nipple reducer @ 7,396' MD (2.75 D nipple x 1.81 D nipple) and set a CA-2 plug in the 1.81 D nipple @ 7,396' MD. Next E-line will set a 20' OAL Perm Patch from 7,119' RKB-7,139' RKB. A MITT & MITIA will then be performed to verify patch integrity, and then 2W-08 will be returned to injection. cc: CPAI Wells Supt CPF2 Pad Engr— Mark Shulman CPF2 Production Engr CPF2 DS Lead Techs Charles Fitzpatrick, Eddie Zemba Steve Drake, Jake Fama Jim McAnelly Halliburton -Jeffery Mansavage, Bob Baker, Dan Brown Job Objective: Set a permanent tubing patch across an injection mandrel. Well Status: 2W-08 is currently online and injecting 4000 BWPD. Tie-In Reference: 2W-08 tubing detail Min ID in well: 2.75" at Camco D Nipple at 7,396' RKB Last Tag: 01-16-15 Tag @ 7577' SLM Design Envelope: Tubing: 3-1/2", 9.3#/ft, J-55. Production Casing: 7", 26#/ft, J-55. Wellhead: FMC Gen III, 3-1/8", 5000 psi. Procedure: The tubing will be brushed and flushed at the production mandrel. Next a 20' dummy patch drift will be drifted below the production mandrel. A nipple reducer must be installed in the 2.75" D nipple of 2W-08 with a plug. The nipple reducer will enable setting a plug to isolate the formation in event of a future rig workover. We will utilize a 2.75 D nipple x 1.81 D nipple reducer. Slickline: 1. Brush & Flush the 3.5" tubing at 7,100'—7,300' RKB. 2. Contact Y-Pad shop 907-659-7658, to verify that they have a (2.75 D nipple x 1.81 D nipple). 3. Run a dummy patch drift (33' X 2.75") below the production mandrel to 7,300 RKB. 4. RIH and set the nipple reducer @ 7,396' RKB (2.75 D nipple x 1.81 D nipple). 5. RIH setting a CA-2 plug in the 1.81 D nipple @ 7,396' RKB. E-line(or DSL): 6. Contact Halliburton, Jeffery Mansavage or Bob Baker, (907)-670-5953 office, or at (907)-943-1414 cell, to request 1 patch: one Special Clearance 2.715" OD x 20' OAL Owen X-Span Perm Patch for set in 2W-08. 7. RIH and set the 20' patch at 7,119'- 7,139' RKB across the mandrel, (referencing the attached 2W-08 tubing detail). Slickline: 4. Perform MITIA & MITT to 2500 psi. 5. RIH & pull the 1.81" Plug from the 1.81" D Nipple reducer at -7,396' RKB. Return 2W-08 to injection. i KUP INJ 2W-08 ConocoPhillips ; Well Attributes Max Angle&MD TD Wellbore APIIUWI Held Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) s Alaska,Inc Ce--‘ ii, 500292122800 KUPARUK RIVER UNIT INJ l 51.03 3,800.00 7,833.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2W'08,208/20151.46.11 PM SSSV:LOCKED OUT Last WO: 36.011 11/26/1984 Vertical schematic(actual) Annotation -Depth(ftKB) End Date Annotation Last Mod By End Date __ _....Last Tag:SLM 7,572.0 1/16/2015 Rev Reason:ADD MANDREL DETAILS,GLV hipshkf 2/18/2015 C/0 TE I Casing Strings l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread HANGER;30.7 I({' CONDUCTOR 16 15.062 31.0 95.0 95.0 62.50 H-40 WELDED }.®„ amb Casmg Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(1...Grade 'Top Thread SURFACE 95/8 8.921 30.2 3,320.0 3,135.7 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len p...Grade Top Thread PRODUCTION 7 6.276 29.0 7,815.0 6,265.2 26.00 J-55 BUTT .A.AA CONDUCTOR;310-950• Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection TUBING 31/2 2.992 30.7 7,403.0 5,976.3 9.30 3-55 EUE 8RD SAFETY VLV;1,908.9 Completion Details Nominal ID Top(ftKB) Top(TVD))ftKB) Top Incl(°) Item Des Corn (in) 30.7 30.7 0.14 HANGER FMC GEN III TUBING HANGER 3.500 GAS LIFT;1,963.8 1,908.9 1,908.1 8.36 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 2/27/2006) 2.810 GAS LIFT;2,877.4 .: 7,055.3 5,733.9 46.07 PBR BAKER PBR 3.000 7,069.5 5,743.7 46.04 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 I 7,150.6 5,800.0 45.93 BLAST RINGS BLAST RINGS(7) 2.992 - - 7,382.4 5,961.9 45.88 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.992 SURFACE;30.2-3,320.0-K d: 7,383.2 5,962.5 45.88 PACKER BAKER FB-1 PERMANENT PACKER 3.000 GAS LIFT;3,326.1 , .. 7,385.7 5,964.3 45.90 SEAL ASSY BAKER SEAL ASSEMBLY RECEPTICLE 2.992 7,396.7 5,971.9 45.96 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT;4,057.3 7,402.2 5,975.7 45.98 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;4,758.5 Top(ND) Top Incl li Top(ftKB) (ftKB) (°) Den Corn Run Date ID(in) 7,560.0 6,085.3 45.70 FISH GLV Body 8 Spring Lost Downhole 10/12/1992 0.000 GAS LIFT;5,321.0 7,601.0 6,114.1 45.42 FISH 27 1/2'Strip Gun Left fish in hole;Reperfed only to 11/5/1991 0.000 7598' GAS LIFT;5,893.0 I I, 7,603.0 6,115.5 45.41 FISH 1"OV JUNK on DV in Pocket originally GLM#10; 12/25/1987 0.000 Fell to Rathole-replace DV 4/26/94 No Problem GAS LIFT;6,496.5 Perforations&Slots Vii' ;. 1 Shot Dens l GAS LIFT;7,009.3 It I Top(TVD) Btm(TVD) (shotsk Top(ftKB) Btm(ftKB) (ftKB) )ftKB) Zone Date t) Type _ Com 7,163.0 7,308.0 5,808.7 5,910.0 C-44,08-3,C-1, 12/13/1984 12.0 (PERF 5.5"SOS,120 deg.pH PBR;7,055.3 7,314.0 7,336.0 5,914.2 5,929.6 C-1,2W-08 12/13/1984 12.0 IPERF 5.5"SOS,120 deg.pH PACKER;7,069.5 •" JI\ 4.4 7,548.0 7,549.0 6,077.0 6,077.7 A-4,2W-08 11/8/1991 4.0 RPERF 2 1/8"Dynastrip HLS,0 INJECTION;7,090.9 i; �J � deg pH ��"\ 7,549.0 7,573.0 6,077.7 6,094.4 A-4,A-3,2W- 11/8/1991 8.0 RPERF 2 1/8"Dynastrip HLS,0 08 deg pH INJECTION;7,128.9 IE (4 j 7,573.0 7,582.0 6,094.4 6,100.7 A-3,2W-08 '11/8/1991 4.0 RPERF 2 1/8"Dynastrip HLS,0 deg pH _ iiiii. 7,582.0 7,598.0 6,100.7 6,112.0 A-3,2W-08 11/8/1991 8.0 RPERF 2 1/8"Dynastrip HLS,0 IPERF;7.163.0.7,308.0 deg pH 7,598.0 7,611.06,112.0 6,121.1 A-3,2W-08 12/13/1984 4.0 IPERF 4"SOS,90 deg pH J (PERF;7,314.0-7,3360- I ['p Mandrel Inserts st IR f of INJECTION;7,365.8 - n Top)ND) Valve Latch Port Size TRO Run 4 N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Corn 1 1,963.8 1,962.2 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 SEAL ASSY;7,382.4 : II PACKER;7,383.2 •n"' 2 2,877.4 2,782.1 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 SEAL ASSY;7.385.7 3 3,326.1 3,140.4 MMH FMHO 1 GAS LIFT DMY ;BK-2 0.000 0.0 12/13/1984 4 4,057.3 3,647.8 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 NIPPLE,7.396.7 --. al 5 4,758.5 4,138.9 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 SOS;7,402.2 _ 6 5,321.0 4,531.2 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 7 5,893.0 4,930.7 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 RPERF;7,548.0-7,549.0- ---J. -. 8 6,496.5 5,347.7 MMH FMHO 1 GAS LIFT DMY BK-2 0.000 0.0 12/13/1984 FISH;7,560.0 r 9 7,009.3 5,701.9 MMH FMHO 1 GAS LIFT OV BK-2 0.438 0.0 12/13/1984 RPERF,7,549.0-7,573.0-- - -- 1 7,090.9 5,758.6 MMH FMHO 1 INJ DMY BK 0.000 0.0 4/26/1994 RPERF,7,573.0-7,582.0-__ 0 1 7,128.9 5,785.0 MMH FMHO 1 INJ CV BK - 0.375 0.0 2/15/2015 RPERF;7,582.0-7598.0 e_ 1 - 1 7,365.8 5,950.4 MMH FMHO 0.0 INJ DMY BTM 0.188 0.0 2/20/1997 Notes:General&Safety FISH;7,6 .0 End Date Annotation IPERF;7,598.0.7,61111.0 -- 12/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 FISH;7,601.0 ^ 10/5/2012 NOTE:2 RIGS RKB DIFFERENCES ACCOUNT FOR PROD/TBG TOP OVERLAP PRODUCTION;29.0-7,815.0 Ima ect Well History File' C( e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organizing(done) ~d IIIIIIIIlllllllllll D RescanNeeded IIIIIIIIIIIIIIIIIII RESCAN DIGITAL DATA OVERSIZED (Scannable) D Color items: [] Diskettes, No. [] Maps: [] Grayscale items: E] Other, No/Type [] Other items scannable by large scanner r- Poor Quality Originals: .~, OVERSIZED (Non-Scannable) [] Other: , NOTES: [] Logs of various kinds [] Other Project Proofing .. BY: BEVERLY B~ERYL MARIA LOWELl. Scanning Preparation ~/.-.:,,.- x 30 = .. Production Scanning ~ ~ ~ Stage I PAGE COUNT FROM SCANNED FILE: ~. ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: V/YES BY: BEVERLY BREN VINCENT SHERYL DWELL DATE: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: (SCANNING I~ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAY$CALE OR COLOR IMAGES) NO NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScan ned.wpd • MEMORANDUM State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, May 13, 2011 TO: Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2W-08 FROM: Bob Noble KUPARUK RIV UNIT 2W -08 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2W -08 API Well Number: 50- 029 - 21228 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN110511111942 Permit Number: 184 -212 -0 Inspection Date: 5/812011 Rel Insp Num: _ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 2w- 08 "Type Inj. W TVD 5734 IA 1440 3200 - 3100 3100 P.T.D1 1842120 lTypeTest SPT Test psi 3200 OA 580 760 760 760 Interval 4YRTST p/F P - Tubing 255o 2550 2550 2550 Notes: 1 *ATONED ; Au 1 2O Friday, May 13, 2011 Page 1 of 1 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~) }/,~/ ' ·"i::YC¡ DATE: Monday, May 21, 2007 SlIBJECT: Mechanical Integrity Tests CO'\OCOPHILLIPS ALASKA I'iC 2W-08 KUPARUK RlV UNIT 2W-08 C54-~JJ ~ \ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv:Jr?.f'- Comm Well Name: KUPARUK RN UNIT 2W-08 API Well Number: 50-029-21228-00-00 Inspector Name: John Crisp Insp Num: mitJCr07052 I 095958 Permit Number: [84-2 I 2-0 Inspection Date: 5/19/2007 ReI Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ---'T' 2W-08 !Type Inj. i W I TVD ! I M_____" I ! I Well 5736 IA 1450 I 2210 i 2140 2130 i ._~~-~.._-1.-----~.,~.-_.- .- - ------_.----- -------- P.T.DI 1842120 ,TypeTest i SPT I Test psi I i 1500 OA I 480 880 I 880 ! 880 I i , --+ -----~_.~-- Interval 4YRTST P/F ./f ':y;0ubing' 2700 r 2700 2700 27~ - .~._--~-_.._-.-- Notes: .5 bbI pumped for MIT. Operator was not requested to test above 1500 psi required by the State. IA test pressure was discussed & Operator did / not want to test IA above 3000 psi. Options were discussed & IA test pressure was moved over 500 psi on IA from pretest pressure for MIT. ./ Pass or fail win be decided by State Inspector Supervisor NON-CONFIDENTIAL aCANNED JUN 0 6 Z007 Monday, May 2 I, 2007 Page 1 of [ Œ 04/05/07 ScbllDlbePler RECEIVED NO. 4205 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR 0 6 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~\Jæka Oil & Gas ConS. Cornmission Anchorage sCANNED APR 1 0 2007 U:¡::-C- / ~L,I- (9 , d Field: Kuparuk Wel~ Color CD Job# Log Description Date BL 2M,12 11632681 PRODUCTION PROFILE 03/29/07 1 35-22 (REDiD) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GL5 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H-02' 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331' N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Reudrich Commissioner THRU' Jim Regg P.I. Supervisor FROM' Jeff Jones Petroleum Inspector NON- CONFIDENTIAL DATE: May 14, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 2W Pad 2W-04, 2W-08, 2W-14 KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. I I-r.v.D. I I Tub,r, II,nterva, I 4 J P.T.D.J 1850120 Type testJ P J TestpsiJ 1500 JCasingJ 1200 J 3000 J 2860 J 2860 J P/F J 13 I Notes: Test fluid: 2.3 bbls diesel. I WellJ 2W-08 JType,,j.J s J T.V.D. J5726 J TubingJ 2750 I=~0 JlntervalJ 4 I P.T.D.J 1842120 TypetestJ P JTestpsiJ 1500 JCasingJ 1500J 3500J 3410J 3375J P/F J _P I Notes: Test fluid: 2 bbls diesel. I Well J 2W-14 J Type Inj. ,/ P.T.D.J 1842370 Type test Notes: Test fluid: 1.5 bbls diesel. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details May 14, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPAI) Kuparuk River Field injection wells 2W-04, 2W08 and 2W-14, to witness 4 year MIT's. Jared Break was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with the three wells passing their MITs. I inspected three well houses and no exceptions were noted. Summary: I witnessed successful MIT's on cpAI's water injection wells 2W-04, 2W-08 and 2W-14 in the Kuparak River Field. Three well house inspections conducted. /.... M.I.T.'s performed: __3 Number of Failures: _0 Total Time during tests: 2 hrs. Attachments: Wellbore schematics (3) cc:. MIT report form 5/12/00 L.G. MIT KRU 2W-04,08,14 5-14-03 JJ.xls 5/20/2003 . ..~ ConocoPhillips Alaska, Inc. KRU 2W-04 2W-04 APl: 500292127500 Well Type: INJ Angle @ TS: 37 cleg@ 6973 L_~ SSSV Type: LOCKED OUT Orig 3/1/1985 Angle @ TD: 33 ~eg @ 7540 Completion: Annular Fluid: Last W/O: Rev Reason: Tag, GLV design ]~ ~ Reference Log: Ref Log Date: Last Update: 4/212003 Last Tag: 7229 TD: 17540 ftKB Last Tag Date: 3/11/2003 Max Hole Angle: 147 deg @ 4800 '~ [] Casing String - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16,000 0 90 90 62.50 H-40 SURFACE 9.625 0 3257 3106 36.00 J-55 I ~:=! .,,~. [] PRODUCTION 7.000 0 7518 6234 26.00 J-55 ] ~': ' Tubing String - TUBING 3.500 0 7109 5897 9.30 J-55 8RD EUE '~ [] perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 6978-7034 5793-5838 ;-3,C-2,C-1, 56 12 2/23/1985 IPERF 120deg. phasing, 5"DA B HD 7047-7057 5848-5856 UNITB 10 12 2/23/1985 IPERF 120deg. phasing, 5"DA 7178- 7190 5953- 5963 A-4 12 4 2/23/1985 IPERF 120 deg. phasing, 4" Dressier Atlas JJ 7201 - 7235 5971 - 5999 A-3 34 4 2/23/1985 IPERF 120 deg. phasing, 4" i~ i i::: Dressier Atlas JJ - - 120 deg. phasing, 4" [] 7300 7308 6052 6059 A-2 8 4 2/23/1985 IPERF DresslerAtlasJJ G:as :Lift: MandrelsN~lves I:: st MD TVD Man Man VMfr VType VOD Latch Port TRO Date VIv I [] Mfr Type Run Cmnt "= 1 2014 2013 Camco KBUG DMY 1.0 BK 0.000 0 4/7/1985 iii::; 2 3333 3160 Camco KBUG DMY 1.0 BK 0.000 0 8/24/1996 ~ 3 4298 3842 Camco KBUG DMY 1.0 BK 0.000 0 8/24/1996 l~l~ 4 4840 4222 Camco KBUG DMY 1,0 BK 0.000 0 8/24/1996 '; 5 5262 4521 Camco KBUG DMY 1,0 BK 0,000 0 4/7/1985 :i:.!: 6 5686 4821 Camco KBUG DMY 1.0 BK 0.000 0 4/7/1985 : ....... :' 7 6080 5115 Camco KBUG DMY 1.0 BK 0.000 0 4/7/1985 8 6473 5409 Camco KBUG DMY 1.0 BK 0.000 0 4/7/1985 9 6722 5594 Merle TPDX (WI DMY 1.5 RD-5 0.000 0 1/11/199( :~:? PKG) :;;:.i iilnjecti~h :Man;drel~lV~'lve~:: .: : . ::::: St MO TVD Man Man V Mfr V Type V OD Latch Port TeD Date Vlv Mfr Type Run Cmnt ..~:..£ _.~l~_~"~r~. 10 6842 5686 Merle TPDX HFCV 1.5 RM 0.000 0 3/31/2003 (RKFS) 11 6911 5740 Merle TPDX HFCV 1,5 RM 0.000 0 3/31/2003 12 7070 5866 Merle TPDX HFCV 1.5 RM 0.000 0 3/30/2003 ..1 'I Other· flugs, ·equiP., etc: - JEWELRY Depth TVD Type Description ID 1964 1963 SSSV Baker'FVL' (Locked Out 6/30/89) 2.810 : ii;?: 6792 5647 PBR Baker 2.992 .:~::: . 6806 5658 PKR Baker'FHL' 3.000 ;:i 7088 5881 PKR Baker'FB-l' 4.000 · 7101 5891 NO GO Camco'D' Nipple 2.750 :::: .: 7109 5897 SOS 2.992 '~r~.~ 7110 5898 TTL 2.992 (7101-7103, 0D:3.500) ARCO Alaska, Inc./ SSSV (1898-1899, -- OD:3.500) PBR (7044-7045, ~ OD:3.500) PKR (7058-7059, OD:6.151) TUBING (0-7403, OD:3.500, ID:2.992) Per[ (7163-7308) Per[ (7314-7336) PKR (7372-7373, -- 0D:6.151) NO GO (7385-7386, ~ 0D:3.500) Per[ (7548-7598) Per[ (7549-7573) Per[ (7582-7611) 271/2' Strip Gun ~ (7601-7629, 0D:1.500) KRU 2W-08 2W-08 APl: 500292122800 SSSV Type: Baker FVL Annular Fluid: Last Tag: 7497 Rev Reason: Depth corrections by mO Well Type: Orig 111/26/84 Completion:I Last W/O: Last Tag Date: 9/8/97 Last Update: 8/23/98 PBTD: 17833 ltKB TD: 7833 flKB Max Hole 51 de9 @ 3800 Angle:I Angle ~. TS: 146de~_ ~ 7164 Angle @ TD: 45deg @ 7833 Casing String - PRODUCTION Size I T°P I 7.000 0 Casing String - CONDUCTOR Size I T°P I 16.000 0 Bottom 7806 Bottom 95 Casing String - SURFACE Size I Top 9.625 0 Bottom 3320 rubing String - TUBING Size I Top 3.500 0 Bottom 74O3 Perforations Interval I 582_D5910 Zone 7163 - 73081 C-4,C-3,C-1 7314- 73361 5914- 59301 C-1 A-4,A-3 6077 - 6112 7548 - 7598 7549 - 7573 6078 - 6095 A-4rA-3 7582- 7611 6101 - 6121 A-3 TVD Wt Grade Thread 6259 26.00 J-55 TVD VVt Grade Thread 95 62.50 H-40 TVD VVt Grade Thread 3135 36.00 J-55 TVD VVt Grade Thread 5976 9.30 J-55 8RD EUE Feet ISPFI Date I Type 1451 1212/13/84151/2,,sos 22 12 12/13/84 5 1/2"SOS 50 4 11/8/91 2 1/8" Dynastrip HLS 24 4 12/13/84 4" SOS I 29l 4112/13/8414" SOS Comment 120 deg. phasing 120 deg. phasing zero deg. phasing; REPERF; 90 deg. phasing; 90 deg. phasing; Gas :Lift :MandrelS~alVes Stn I MD I TVD I Man Mfrl Man Type I VIv Mfr I VIv TyPe I VIv ODI Latch I Port I TRO Date Run I I 19521 19501McMurrayl FMHO ] I DMY I 1.0 I BK-2 {0.0001 0 12/13/84 I Hughes I I 2[ 2866 2773 McMurray FMHO DMY 1.o BK Io.oool 012,25,87 Hughes Hughes Hughes Hughes Hughes 7 [ 58821 4923 McMurrayI FMHOI I I.-lo.oool o Hughes Hughes Hughes Hughes 11 ] 71181 57771McMurrayI FM.O I I DMY I 1.0 I BK ]0.000t 0 0/0,97 Hughes 121 73551 59431MoMurreyl I I I Hughes I I I I I (BTM) I / :other (PlugS~ equiP.;; etc:)::, JEWELRY. Depth I TVD I Type 18981 18971 SSSV 70441 57261 PBR 70581 57361 PKR 73721 59551 PER 73851 59641 NO GO 7391 5968I 7392 5969 Fish ~ FISH Depth DeScriPtion 75601GLV Body & Sprin.q 7601127 1/2' Strip Gun 7603 1" OV. Baker 'FVL' Description ID 2.810 Baker 2.992 Baker 'FHL' 3.000 Baker 'FB-1° 3.000 Camco 2.750 SHEAR OUT Baker 2.992 TUBING TAIL 2.992 : Comment Lost Downhole Left fish in hole; Reperfed only to 7598' JUNK on DV in Pocket originally GLM #10; Fell to Rathole - replace DV 4/26/94 No Problem ARCO Alaska, Inc.A Kuparuk 2W-14 2W-14 APl: 500292125300 Well Type: INJ PBTD: 8,420 ftKB SSSV ~ SSSV Type: Baker FVL (Locked Out) grig Completion: 1/16/85 TD: 8,420 ftKB TUBING ~ Annular Fluid: Last W/O: Max Hole Angle: 1 51 de.q ~, 3000 Last Tag: 8215 Last Tag Date: 5/16/91 Angle ~ TS:I 33 deg ~ 7898 Rev Reason: New Schem Last Update: 319198 Angle ~ TD:1 29 de.q ~ 8420 Gas Lift ~ Eleva§ons Mandrel/Dummy Valve 1 Grd 158 ft I Original R g RKB 124 ff PROD. CASING Casing String - CONDUCTOR Item Btm Jnts Wt I Grd Thd Gas Lift 16.000 in CONDUCTOR 115 62.501 H-40 Mandrel/Dummy Valve 2 Casing String - SURFACE SUR. CASING Item Btm 3,938 Jnts Wt I OrdI Thd 9.625 in SUR. CASING 36.00 J-55 Gas Lift ~ Casing String - PRODUCTION Mandrel/Dummy Va~ 3 Item Btm 8,405 Jnts Wt I GrdI Thd Tubing String ' TUBING Gas Uft Item Top t Lan w3 II Thd MandreVDummy Valve 4 3.500 in TUBING 24 7,981 .30 J-55 8RD EUE Perforations Interval Zone Status Feet SPF Date Type Comment Gas Uft 7,902 - 7,952 C-4,C-3,C-I,UNIT B 50 12 2/27/85 5" DA HD 120 deg. phasing MandreVDumrny Valve 5 7,960 - 7,964 UNIT B 4 12 2/27/85 5" DA HD 120 deg.. phasing 8,074 - 8,126 A-4,A-3 52 4 2/27/85 4" DA JJ II 120 deg. phasing Gas' Eft Mandrels/Valv=es Gas Uft -- Stn MD TVD ManMfr Man'Type Mfr 'Type Latch Port TRO Run Mandrel/DummyValve6 I 2,054 1,947 Camco 3 1/2 X 1 KBUG DV BK-2 0.000 0.0 2/27/85 2 3,699 3~004 Camco 3 1/2 X 1 KBUG DV BK-2 0.000 0.0 2/27/85 3 4,505 4,942 3,804 3,516 Camco 3 1/2 X 1 KBUG DV BK-2 0.000 0.0 2/27/85 2/27/85 Gas Lift 4 Camco 3 1/2 X 1 KBUG . DV BK-2 0.000 0.0 Mandrel/Dummy Valve 7 5 5,412 4,116 Camco 3 1/2 X 1 KBUG , DV BK-2 0.000 0.0 2/27/85 6 5,851 4,409 Camco 3 1/2 X 1 KBUG DV BK-2 0.000 0.0 2/27/85 7 6,290 4,709 Camco 3 1/2 X 1 KBUG i DV BK-2 0.000 0.0 2/27/85 Gas Lift 8 6,732 5,012 Camco 31/2 X IKBUG i DV BK 0.000 0.0 11/25/89 Mandrel/DummyValve8 9 7,170 5,311 Camco 3 1/2 X 1 KBUG I DV BK-2 0.000 0.0 2/27/85 10 7,668 5~680 Maria 3 1/2 X 1 1/2 TPDX ~DV RO-5 0.000 0.0 12/15/94 11 7,764 5,757 Maria 3 1/2 X 1 1/2 TPDX i DV RO-5 0.000 0.0 3/6/95 12 7,835 5,816 Maria 3 1/2 X 1 1/2 TPDX OV RO-5 0.250 0.0 4/2/91 Gas Lift 13 7,961 5,921 Maria 3 1/2 X 1 1/2 TPDX I DV RO-5 0.000 0.0 4/2/91 UandreVDummyValve 9 Other(PlUgS~ equip, etc~)?JEWELRYi :: :: = Depth Type Description ID 1,876 SSSV Baker 'FVL' (Locked Out 12/14/94) (Pulled MCX INJ Valve on 3/6/95 - 2.812 Gas Lift ~ to be left out of hole) Mandrel/Dummy Valve 7,713 PBR Baker 2.992 10 7,726 PKR Baker 'FHL' 3.000 7,984 PKR Baker 'FB-I' 4.000 PBR NO GO Camco 'D' Nipple 2.750 7,998 8,004 SHEAR OUT Baker 2.992 8,005 TUBING TAIL 2.992 8,222 1 CV Dropped in rathole Ga U Mandrel/Dummy ~;~ Gas Lift Mandrel/Valve NO GO SHEAR OUT TUBING TAIL Perf 7 / sssv d,f. DV Or GLV -T Fluid Level -1 Found Ft KUPARUK FLUID LEVEL REPORT Well ~f/t/-d ¢' Date Il ]~2,~,.h /0 Fluid Level Shot Down: CC: DS Engr. NSK Files OP Engrg. Files Prod. Foreman Casing Tubing CSG Press During Shot = # TBG Press During Shot = Z~YO # Reason For Shooting FL: -- To Determine Operating Valve Well Status: Comments: On Continuous GL Operating CSG Press = __ GL Rate (If Available)= On Intermittent GL On Time=__ Min. Off Time = Hr. Min. , , Delta Time From End Of On Cycle No GL # MCFD Min. STATE OF ALASKA 0 ~ ALA~;~, OIL AND GAS CONSERVATION ~MI~ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1144' FNL, 535' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1255' FNL, 1329' FWL, Sec. 33, T12N, R9E, UM At effective depth 1255' FNL, 1329' FWL, Sec. 33, T12N, R9E, UM At total depth 1263' FNL, 853' FWL, Sec. 33, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 7725' feet Plugs (measured) 6200' feet 7708' feet Junk (measured) 61 8 8 feet None 6. Datum elevation (DF or KB) 95' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2W-08 9. Permit number/approval number 84-212 10. APl number 5o-02cJ-21228 11. Field/Pool Kuparuk River Oil Pool Casing Length Size Cemented Structural Conductor 95' 1 6" 260 Sx Cold Set II Surface 3320' 9 5/8' 875 Sx AS III & Intermediate 810 Sx Class G Production 780 6' 7" 500 Sx Class G & Liner 41 bbl AS I Perforation depth: measured 7163'-7336' 12 SPF @ 120 degree phasing 7549'-7611' 12 SPF @ 90 degree phasing true vertical 5808-5929°, 6077'-61 21' TVD Tubing (size, grade, and measured depth) 3.5" J-55 set at 7392' Packers and SSSV (type and measured depth) Baker FHL @ 7058', Baker FB-1 @ 7372'; Baker SSSV @ 1898' Measured depth True vertical depth 95' 95' 332O' 3135' 7806' 6258' RECE]V .D 13. Stimulation or cement squeeze summary Reperforate A Sands from 7548'-7598'@ 4 SPF @ 0° phasing Intervals treated (measured) Treatment description including volumes used and final pressure 14, Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 - - 0 - - 0 - 750 2344 Subsequent to operation 0 - - 0 - 2604 800 2548 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C.(.~. ~ Title 'Operations Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE WELL SERVICE REPORT ARCO Alaska, Inc. Subs~cliary of ~tlantic Richfielc~ Company WELL IPBDT "2_ vV-o8 ,TRACTOR Ilks' ~Jt l~'~,,, ~ REMARKS / IFIELD - DISTRICT- STATE , OPERATION AT F~EPORT TIME IDAYS 1 DATE //-~.. q/ ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~ ~Wind Vel. Weather ;Temp. ! Chill Factor i Visibility Report °F : °F ~ARCO Alaska, Inc. Subs~(:Jiary of Atlanhc R~chfield Company WELL TRACTOR REMARKS ~,~_ 0~(..~ iPBDT !7'-d& 7~o/ _l WELL SERVICE REPORT FIELD - DISTRICT- STATE OPERATION AT REPORT TIME i DAYS i DATE I ~L /~-~-~ I / 7~$ - · ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Report '~ Chill Factor Visibility Wind Vel. Signed °F °F! miles knots ~'",3,... STATE OF ALASKA ALASKa' OIL AND GAS CONSERVATION COMM,OSION REPORT OF SUNDRY WELL OPERATI( N S1 A Alter Casing -,~ Other 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3, Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1088' FNL, 512' FEL, Sec. 33, T12N, R9E, UM 5. Datum elevation (DF or KB) RKB 95 6. Unit or Property name Kuparuk River Unit 7. Well number 2W-8 Injector Feet At top of productive interval 1255' FNL, 1329' FWL, Sec. 33, T12N, At effective depth 1263' FNL, 853' FWL, Sec. 33, T12N, At total depth R9E, UM R9E, UM 8. Approval number g-4~g 9. APl number 5o-- 029-21228-00 10. Pool 1263' FNL, 853' FWL, Sec. 33, T12N, R9E, UM 11. Present well condition summary 7725' Total depth' measured true vertical 6200' feet Plugs (measured) feet Kuparuk River Oil Pool Effective depth' measured 7708' feet Junk (measured) true vertical 6188' feet Casing Length Size Cemented Structural Conductor 95' 16" Yes Surface 3320' 9-5/8" Yes Intermediate Production 7806' 7" Yes Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Measured depth 95' 3320' 7806' 7544'-7611' MD 5948'-6026' TVD 3 1/2", 9.3 lb/ft, J-55, 7.392' True Vertical depth 95' 3211' 6258' Packers and SSSV (types~~a~g,d~R' Baker FHL @ 7058' Baker FB-1 @ 7373' 12. Stimulation or cement squeeze sun~/f~y Intervals treated (measured) N/A Treatment description including volumes used and final pressure N,/A 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure (Both Zones ) 4300 1300 Prior to well operation A Sand 0nly) 700 0 2400 Subsequent to operation Tubing Pressure 2000 3800 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //?¢~/4 Form 10-404~ F~v. 12-~¢85 Date Submit in'Duplicate AR'CO Alaska, Inc. {) .. Drillsite Morning Report CPF Date O"'- ,,3 / - ,~ ~ Time ~ ~OO Drillsite ,~.//,/ Status Production Well status Gas ~ift Status Shut-In -- Well P.T. or TP Choke Temp!'Lasi H2S CSGP'ressurepsI'i' Gas Inj. Rate 1 s~nn # SI Zone PSI Bean °F WC% PPM 7" 10" Temp Meter..Total MSCFD ~Hrs ,Rea I .. .. I .. , Total 3~ ~ ~ Status Injection Well Status Shut-In Well Gl, PW Inject. Pressure PSI Temp Choke CSG Pressure PSI Meter Injection Rate # or SW Zone Allowable Actual °F Bean 7" 10" Total .BBLS/Day I MMSCFD Hrs. Reason ~ ,¢t.,) ~ /~,~x ~/,~ ~. ~ 3 / o ~-Ty- /7~- ~9~ i 7~o~~ ~o / Total ~H, qgq /~.,/~ SWI Total ,,2~,, Y' oa'V' PWI Total Drillsite Coil Temperature °F C0il Pr~'ssure Psi- Bath 'Blanket· Heater Prod t Test , , Prod Test Temp. ,GasPSI Run Time Chemicals Type I Gal/Day !fi, q/ca t Headers "Produc~tion Water Injecti.o.n.. - Gaslnjectiqn ' ' 'GasLift Drain Pressure ~o~ /~ 1-8: , , Temperature! ~'"/ 4"./ 9-16: Tank: Meoh/Diesel ..... Level Temp. Comments Operater's Signature. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMf-~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ' ' Operation Shutdown ~ i Re-enter suspended well [-3 Alter casing [] Time extension Change approved program L! Plugging ~ Stimulate-~ Pull tubing'' Amend order ,r~ Perforate E: Other 2. Name of Operator ARCO Alaska. Thc. 3. Address Po0. Box 100360, Anchoraqe, Alaska 995:].0 4. Location of well at surface 1088' FNL, 512' FEL, Sec. 33, T12N, R9E, UM 5. Datum elevation (DF or KB) q5 RKB 6, Unit or Property name Kuparuk River Unit 7. Well number 2W-08 feet At top of productive interval 1255' FNL, 1329' FWL, Sec. 33, T12N At effective depth 1263' FNL, 853' FWL, Sec. 33, T12N At total depth 1263' FNL, 853' FWL, Sec. 33. T12N 11. Present well condition summary 7725 Total depth: measured true vertical 6200 , R9E, UM , R9E, UM ? R9E, UM 8. Permit number 84-212 9. APl number 50-- 079-?122R 10. Pool Kuparuk River 0il Pool I feet Plugs (measured) I feet Effective depth: measured 7708' feet Junk (measured) true vertical 6188 ' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 95' 16" yes 95' 95' surface 3320' 9-5/8" yes 3320' 3211' Intermediate Production 7806' 7" .vas 7806 ' 6258' Liner Perforation depth: measured 7544'-7611' MD true vertical 5948'-6026' TVD Tubing (size, grade and measured depth) RECEIVED JUN 1 0 1988 3 1/2", 9.3 lb/ft, J-55,Al~13a~il& Gas C0ns. C0mmiss[0rl Packers and SSSV (type and measured depth) Anchorage qqqV @ 1RQR', Pk'P. Raker FHI ~ 705~,' R,u¢~ FR_I ~ 7q79' 12.Attachments --~escri~i~ summ'~'~y of-propos~l"~ -Detailed op~GiFEns'~ro6r~m '~' ~P sketch Convert water injection w~ll tn WAG inj~nf, inn w~ll. 13. Estimated date for commencing operation / Wo=k 14. ~osal was verbally approved ~0~ No. i~ ' ~ated~~~ Date approved Name of approver 15. I hereby certify that the foregoing is true and correct to the~ best of my knowledge Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No../~ [] Plug integrity [] BOP Test ~ Location clearancel c._~' / ORIGINAL SIGNED BY Approved by I ONNIE: C. SMITH ~pproved Copy Returned Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Well 2W-08 Application for Sundry Approval I · Propose conversion from water injector to alternating gas injector. 2, No BOP equipment will be required. 3, The estimated static BHP is 3100 psi at 6200' SS. 4, No workover fluids will be required. ATTACIIMENT PAGE I KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL NUMBER ><~2C-03 ,~2D-05 ""~2W-05 >~'~2w-o8 '><~2X-02 "~2x-o3 >~""2X-06 "'-?L3F.0~ APl NUMBER 50-029 20968 20973 21157 212O8 21228 20982 20987 20988 21h49 21~63 DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INJECTION SURVEY SURVEY ~URVEY 12/12/85 11/09/85 11/09/85 11/22/85 11/15/85 11/19/85 11/04/85 11/0~/85 05/0~/86 05/06/86 02/03/87 02/01/87 02/0h/87 03/05/87 03/06/87 02/07/887 03/02/87 03/0~/87 02/08/87 02/09/87 SPINNER SP NNER SP NNER SP NNER SP NNER SP NNER SP NNER SPINNER SPINNER SPINNER WELL COMPLETION FOLLOWUP A&C S FOLLOWUP A&C S FOLLOWUP A&C SS FOLLOWUP A&C SS FOLLOWUP A&C SS FOLLOWUP A&C SS FOLLOWUP A&C SS FOLLOWUP A&C SS INITIAL A&C SS INITIAL A&C SS ZONES TAKING WATER A&C ! A&C A&C A&C A&C A&C A&C A&C A&C A&C I NJ ECT I ON BWPD · Alaska Oil & Gas Cons. Commissiorl Anchorage ARCO Alaska, Inc. Post Office BO~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1987. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have anx questions concerning the information reported, please contact me at (907) 263-4262. Sincerely, Operations Engineer BBB/SPT'pg'O069 Attachments Alaska Oil & Gas Cons. Commissiorl ~chorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCornpany WELL CONTRACTOR ,vlARKS - ~ " "- I='~,"~ ~ ARCO Alaska, Inc ~ ,. ~.':.:~,/~/.,~ELL SERVICE R~T ..Subsidiary of Atlantic Richfield Company I PBDT ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Wind Vel. i Signed miles i kn°ts I Report Chill Factor I Visibility "F I CONTRACTOR ,,/lARKS ARCO Alaska, inc 't~' ,c,. Subsidiary of Atlantic Richfield Company JPB~ .,.5'-_.'t ..-,.":'-.~."~,ELL SERVICE REPORT iDATE ! i Signed knotsI REMARKS CONTINUED: OTiS sCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC coIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE DESCRIPTION DAILY ACCUM. TOTAL TOTAL FIELD ESTIMATE ARCO Alaska, Inc.. ~ Subsidiary of Atlantic Richfield Company SERVICE REPORT WELL "NTRACTOR n,;MARKS · IPBDT -7'~,d_~ PE>T~ 08ar~ - · ['-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp' 1 Chill Fact°r ' Visibility lWlnd Vel'Report 'F 'FI miles , knots Isigned ARCO Alaska, inc ...... ~, ~,. WELL SERVICE REPORT Subsidiary of Atlantic Richfield Company WELL ]PBDT FIELD.DISTRICT-STATE ~ 'DAYS I DATE~ ~NTRACTOR iOPERATION AT REPORT TIME 'nEMARKS KUPARUK OPERATIONS Er'.;G'~'~~~~~.,..~,~ I I Iii iI ~~ (;:)~Cx:) - ¢..IG UP .3u~r..C.u,,¢p., CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport tTemp' OF {I Chtll FactoroFII Visibility miles !lWind Vel. knots ttSigned REMARKS CONTINUED: I ACCUM. I DESCRIPTION DAILY TOTAL OTIS i SCHLUMBERGER [DRESSER-ATLAS I DOWELL !HALLIBURTON ARCTIC COIL TUBING :~ FRACMASTER B. J. HUGHES :Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting , AFE __ TOTAL FIELD ESTIMATE , I 2---<~"7. 5 __ __ ARCO Alaska, lnc~ O' Sub$idh~ry of Atlantic Richfield Compan,. WELL IPBDT . r'ONTRACTOR REMARKS FIELD- DISTRICT- STATE IOPERATION AT REPORT TIME WELL SERVICE REPORT IDAY~ 'iDATE 4:) >/ _._KUPARUK OPERATIONS [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots isigned REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO ' OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL ' ' HALLIBURTON ' " ' ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts / Diesel Methanol Supervision Pre-Job Safety Meeting TOTAL FIELD ESTIMATE Slg ned~,~, ARCO Alaska, Inc v' Sub$idi~3ry of Atlantic Richfield Compar . WELL PBDT ,~, /..,~- ~ 7~ z 7 ~'ONTRACTOR · L'or~ ~L-~d ~z~ · WELL SERVICE REPORT FIELD - DISTRICT- STATE IOPERATION AT REPORT TIME DAY~ JDATE KUPARUK OpERAT!ONS ENGINFFR.~NG jUi Y, i [--] CHECK THIS BLOCK If SUMMARY CONTINUED ON BACK Weather I Temp' 1 Chill Fact°r I Visibility IWlnd Vel'Report OF 'F miles knots ISigned STATE OF ALASKA ALASt,~.~' OIL AND GAS CONSERVATION COMi~.,-.¢SION REPORT OF SUNDRY WELL OPERATIONS Feet ' 1. Operations performed: Operation shutdown [] StimulateX[] Plugging ~ Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 95' 3. Address 6. Unit or Property. name PO Box 100360, Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 27' wJellw-t~ number 1088' FNL., 512' FEL, Sec. 33, T12N, R9E, UM At top of procfuctive interva! 1255' FNL, 1329' FWL, Sec. 33, T12N, R9E, UN At effective depth 1263' FNL, 853' FWL, Sec. 33 At total depth 1263' FNL, 853' FWL, Sec. 33 11. Present well condition summary Total depth: measured 7725 true vertical 6200 , T12N, R9E, UM ; T12N, R9E: UM feet feet 8. Approval number ' ~.',~'1:;i ~n 6'n~6e r~'- 50-- 029-21228-00 10. Pool Kuuaruk River Oil Pnnl , 12. Effective depth' measured 7708 feet true vertical 6188 feet Casing Structural Conductor Surface xxxl~mex~e Production xxxt~R~:rxxxxx Perforation depth: Length Size Plugs (measured) None Junk (measured) None Cemented 95' 16" Yes 3320' 9.625" Yes 1, 7806' measured Measured depth 95' MD 3320' MD Yes 7806' MD True Vertical depth 95' TVD 3211' TVD 6258' TVD 7544' - 7611' MD true vertical 5948' - 6026' TVD Tubing (size, grade and measured depth) 3.5", 9.3# J-55, 7392' Packers and SSSV (type and measured depth) Baker FHI and FR-1 Park~r~ - 7flRF~' a. nd 7372' Stimulation or cement squeeze summary 13. Intervals treated (measured) 7544' - 7611' Treatment description including volumes used and final pressure Gel 1 ed Diesel Hydraulic Fracture - 150 bbls 9elled diesel, 700# 100 MS Sand~ 16~000# 20/40 MS Sand, Final Pressure = 3730 p Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 1150 1500 400 1600 1400 Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Sr. Operations Engineer Signed ./,.-~, ¢~,4..,.~! Form 10-404 Rev. 1~1-85 Date si Submit in Duplicate ADDENDUM WELL: 5/19/S6 2W-8 B. J. Tital frac'd Kuparuk "A" sand perfs 7544'-7573' & 7582'-7611' in 8 stages per 5/13/86 procedure using diesel w/5% Musol, 2A gelled diesel, 100 mesh & 20/40 mesh sand. Press'd annulus to 1500 psi w/diesel. Tst ins to 7520 psi. Stage #1: Pmp'd 40 bbls diesel w/5% Inflow 40 Musol @ 4.7 BPM. Stage #2: 63 bbls gelled diesel spacer @ 19.5 BPM w/2450 psi-5070 psi. Stage #3: 7 bbls gelled diesel pad @ 10.5 BPM w/1500-3030 psi. Stage #4: 35 bbls gelled diesel w/.5 ppg 100 mesh @ 18.4 BPM, 3050-3460 psi. Stage #5: 31 bbls gelled diesel pad @ 19.5 BPM, 3460-3400 psi. Stage #6: 28 bbls gelled diesel w/3 ppg 20/40 mesh @ 20.2 BPM, 3460-3420 psi. Stage #7: 53 bbls gelled diesel w/8 ppg 20/40 mesh @ 2~ BPM, 3200-3610 psi. Stage #8: 69 bbls gelled diesel flush @ 20.4 BPM, w/final press of 3540 psi, final ann press of 1730 psi. Pmp'd 700# 100 mesh @ .5 ppg, 3326# 20/40 mesh @ 3 ppg & 12,410# 20/40 mesh @ 8 ppg in formation leaving ±250~ of 20/40 mesh @ 8 ppg sand in csg. Load to recover 208 bbls of diesel. Job complete @ 1211 hrs, 5/19/86. Well turned over to Production. Drilling Supervisor Date STATE OF ALASKA ALASr,~, OIL AND GAS CONSERVATION COMM~dSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~.. Suspend fq Operation Shutdown © Re-enter suspended well [] Alter casing [] Time extension _~ Change approved program [] Plugging [] Stimulate .~ Pull tu'bing ~ Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 95 RKB feet 3. Address 6. Unit or Property name Box 100360, Anchorage, Alaska 99510-360 Kuparuk River Unit 4. Location of well at surface 1088' FNL, 512' FEL, Sec. 33, T12N, R9E At top of productive interval 1255' FNL, 1329' F~CL, Sec. 33, T12N, R9E At effective depth 1263' FNL, 853' FWL, Sec. 33, T12N, R9E At total depth 1263' FNL, 853' FWL, Sec. 33, T12N, RgE 7. Well number 2W-8 8. Permitnumber 84-212 9. APInumber 50-- 029-21228-00 10. Pool Kuparuk River 11. Present well condition summary Total depth' measured 7725 true vertical 6200 feet Plugs (measured) feet Effective depth: measured 7708 feet true vertical 6188 feet Junk (measured) Casing Length Size Cemented Measured depth Structural Conductor 95 ~ 16'; Yes 95 ' Surface 3320 ' 9. 625r' Yes 3320 ' Intermediate Production 7806 ' 7" Yes 7806 ' Liner Perforation depth: measured 7544' - 7611' True Vertical depth 95' 3211' 6258' true vertical 5948' - 6026' MA~V Tubing (size, grade and measured depth) 3 5", q 3¢ J-55, 7392' ~a 0il & 6as ~'~ Packers and SSSV (type and measured depth) Baker FHL and FB-1 Packe=s - 7058~ and 7372' 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May 17, 1986 14. If proposal was verbally approved Name of approver Lonnie C. Smith Date approved May 14, 1986 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ..,:_/. i.? C.,:' L:'., Signed .( ¢ ~/,/,,.~ /.') . ;,~//,~/L.~..,.,~. .,, :/ Commission Use'Only Date Conditions of approval Notify commission so representative may witness I Approva' No. [] Plug integrity [] BOP Test [] Location clearance .,i::.:.::'-'-.::: -~::' ~} ·; . by order of Approved by Form 10-403 Rev 12-1-85 Submit in triplicate DESCRIPTION SUMMARY FRACTURE It is proposed that the A Sand in Kuparuk Well 2W-8 be hydraulically fractured and propped to improve injection. The treatment uses gelled diesel as the pad and carrying fluid and 20/40 mesh sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting the job. Fluid: 350 BBLS Proppant: 15,000 LBS Anticipated Start Date: May 17, 1986 ARCO Alaska, Inc. Post Office B ;00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- Wel I Action Date Performed on the 1L-1 Convers 1L-7 Convers 10-2 Convers 10-7 Convers 10-11 Convers 10-13 Convers 2B-5 Convers 2B-9 Convers 2C-1 Convers 2C-3 Convers 2C-6 Convers 2C-8 Convers 2D-2 Convers 2D-7 Convers 2D-11 Convers 2D-14 Convers 2F-1 Convers 2F-2 Convers 2F-13 Convers 2F-14 Convers 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-10 Convers 2~-12 Convers 2G-16 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-16 Convers 2W-2 Convers 2W-4 Convers on on on on on 11/18/85 11/18/85 11/17/85 11/17/85 11/17/85 11/17/85 11/23/85 11/23/85 11/19/85 11/19/85 11/19/85 11/19/85 11/20/85 11/20/85 11120185 11/20/85 11/21/85 11/21/85 11/2i/85 11/21/85 11/lq/85 11/14/85 11/14185 11/14/85 11/14/85 11/14/85 11/14/85 RECEIVED 11/16/85 ~.,. .11/16/85 JAN.8 11/16/85 1 1 / 1 5 / 8~ska OU & Gas ~ns. ~ts:~ion 11 / 22 / 85 k~chor~ ARCO Alaska, Inc. Is a Subsidiary ol AtlanticRichlieldCompany Mr. C. V. Chatterton, Well Action Chairman Date Performed Page 2W-5 Convers 2W-8 Convers 2W-1 0 Convers 2W-1 4 Convers 2W- 16 Convers 2X-2 Convers 2X-4 Convers 2X-5 Convers 2Z-9 Convers 2Z-11 Convers 2Z-1 4 Conver s 2Z-16 Convers on on on on on on on · on 11/22/85 11/15/85 11/15/85 11115/85 11/22/85 11118185 11118185 11118185 11117185 11117185 11117185 11117185 If you have any questions, please call . T. M. Drurnm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. STATE OF ALASKA ALASKA oI'L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL[] COMPLETED WELL[]X OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC, R4-212 3. Address 8. AP! Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 228 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION' 1088' FNL, 512' FEL, .Sec T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 95' (RKB) 6. Lease Designation and Serial No. ADL 25642, ALK 2573 10. Well Number 2W-8 11. Field and Pool KIJPARUK R!VER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 15, 1985 Kuparuk well 2W-8 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both "A" and "C" sands. the 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. /¢¢' ¢/--,/~ ~,_~- ,¢ ¥,~ ~--z~,~f,.~ Title KUPARUK The space below for Commission use OPERAT IONS COORD ! NATOR Date 1 ? / 1 R / R ~ Conditions of Approval, if any' Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In(' Post Office-.~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street ~ Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 · AnChorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK '~IL AND GAS CONSERVATION C MMISSION SUNDRY'NOTICES AND REPORT ON WELLS 1. DRILLING WELL[] COMPLETED WELL~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 10036©, Anchorage, Alaska 99510 4. Location of Well 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk Riger Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) t 6. Lease Designation and Serial No. Kuparuk Ri vet 0i l Pool N/A I see attached 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ['~ Repairs Made [] Other [] Pull Tubing [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of J^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. RECEiV.ED sEP 2 o !9" 5 Gas Cons. Commission knchoraOe 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed :~, ,/~ ~~'~r'J'~'~-~ Title Kuparuk Operations Coordinator Date 9/18/85 The space below for Commission use Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved COpy .Rotun'm:l / By Order of ¢_-~. ~:; ~' COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:009 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 8O 85 106 128 132 85- 6 7 2O 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 209 209 209 029-211 211 211 211 211 211 211 211 029-212 212 212 212 029-210 210 210 210 210 210 210 210 029-211 211 211 211 211 211 211 029-212 212 212 213 212 212 029-210 210 210 210 210 210 029-212 212 212 212 212 79 70 74 77 76 57 69 35 34 83 85 46 27 13 14 58 63 62 65 32 35 48 52 50 65 19 24 40 59 63 69 70 83 03 62 64 37 41 51 54 55 61 79 75 O8 28 35 25653 1! 25658 25658 25657 I! 25656 25644 25643 25655 25644 25655 25642 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " lO/15/85 2575 10/15/85 " 12/15/85 " 10/15./85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 ,' ~ _.~./15/85 E IV ARCO Alaska, Inc. ~1~'- Post Office Box~-00360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive. Anchorage, AK 99501 SLIBJECT: Conductor As-Built Location Plats - 2W Pad Wells 1-8, 9-16- Dear Elaine' Enclosed are as-built location plats for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer ,. JG/tw . GRU2/L93 Enclosures If ARCO Alask~a. Inc. is a Subsidiary of AllanticRichfieldCompany 'PHASE 3~ AS-BUILT WELLS ~ Thru 16 ~ (NSK 9. O5.223d 2) 27 34 PHASE T AS-BUILT WELLS I Thru 8 wELL ! Y - 5,gTg,J3g.o0 L~T. 70a2~'X~.gg05 ~ - 5~8,g09.~2 L~#6. PlO ELEV. 65.1 O.G. ELEV. 60.3 179 ~EL 1,226 ~NL SEC. 33 WELL 2 Y - 5,979.Z$3.39 LAT. X = $18,~87.&~ LONG. PAD ELEV. 55.3 0.5. ELEV. 202.~EL 1,279 FNL SEC. 33 ~ELL 3 Y - 5,979,227.80 LAT. X . 51a.a6~.a9 L0~G. t~g°50'~8.51~7w ~g !LEV. 55.3 0.G. ELEV. 60.7 225 F£L t,335 FNL $~¢. 33 WELL ~ ¥ - 5,g?g,17Z.0) L~T. X = 518.~&2.38 LONG. P~D ELEV. 55.2 3.G. EL~V. 2~8 ~EL 1,331 ~NL SEC. 33 WELL 5 Y · 5.979,307.27 LAT. 70021'1~.6873" X . 518,508.68 L~NG. PAD ELEV. 6~.7 O.G. EL~V. 581KEL 1,255 FNL SEC. 33 ~ELL 6 ¥ - 5,S79,36~.79 LAT. 70021'17.Z335'' X = St8,531.1~ LONG. PA0 ELEV. 6~.~ 0.G. ELEV. 59.3 558 FEL 'l,l~g FNL S~C. 33 WEL~ 7 Y = 5,979,~18.39 LAT. 70~21'17.7a01" X . 518,553.~7 LONG. P~D ELEV. 6~.~ 0.~. ELE¥. 535 ~EL I,I~A FNL SEC. 33 WELL 8 ¥ - 5,979,~73.39 ~T. 70°~'1~.325& X = $1~,57).15 LO~G. 512 ~EL I.G88 FNL SEC. 33 LOCATED IN PROTRACTED SECTIONS 33 &34 TOWNSHIP 12 N.~ RANGE 9 E.~ UMIAT MER. NO SCALE NOTE' BASIS OF POSITION IS MONUMENTATION AJask 2W NORTH AND 2.W SOUTH PER LHD & ASSOCIATES. '. ~,~.. ..~ .~,'~'~. L L ~ ~ ~. ~ D ~"~'"~T" )'' ~ -,, ~ .uas. uo,,s. Commissior, ,t:% .~.~.~~ ¢~ I HEREBY CERTIFY THAT 'I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT R~PRE$~NTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCTOBER 14, 1984. ARCO Alosko, Inc. KuPoruk Project North Slooe Drilling DRILL SITE 2W CONDUCTOR AS-BUILT LOCATIONS Oct. 23, 1984 I Scale: AS SHOWN ARCO Alaska, Ir Post Ofli(..~. ,Cox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-1 8-85 TRANSMITTAL NO: 5219 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ITTED tIER~,[ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE L/~ECEIPT AND RETURN ONE SIGNED COPY OF TItIS TRANSMITTAL. FINAL PRINTS/SCIIL CBL'S (ONE * OF EAClt) ./ 1E-15 ' 11-01-84 RUN #2 6994-7910 1L-16~'~ 11-05-84 RUN ~1 5693-7620 2D-2/ 11-03-84 RUN ¢.1 6760-7663 2D-4 --~' 11-04-84 RUN ¢rl 6987-8492 2U-1-/' 03-01-85 RUN ~1 4550-7316 2U-2 J 03-01-85 RUN #1 5850-8446 2U-13~ 02-05-85 RUN #1 4600-7786 2U-14 ~-~ 02-09-85 RUN Itl 4900-6991 2U-16 -~ 02-10-85 RUN ~1 4600-6070 2W-5 -- 11-25-84 RUN ~1 5750-8059 2r,~-7-'~ 11-27-84 RUN ~1 4530-6241 2W-8 /' 11-27-84 RUN ~1 5140-7702 2X-16 '~ 11-07-84 RUN ~1 7900-9568 RECEIPT ACKNO~LEDGED: BPAE B. CURRIER C HE VRON D & M DISTRIBUTION: DRILLING*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL DATE: ..... STATE OF A'LASKA*BL/ SOHIO SE UN I ON K.TULIN/VAULT'~F-~' STATE OF ALASKA ~-~ ALASKA OIL AND GAS CONSERVATION CO~IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of Well Classification of Service Well 1. OIL:~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Op. erator 7. Permit Number ARCO Alaska, Inc, 84-212 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21228 4. Location of well at surface 9. Unit or Lease Name 1088' FNL, 512' FEL, 5ec.33, T12N, R9E~ UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1255' FNL, 1329' FWL, Sec.33, T12N, R9E, UM 2W-8 At Total Depth 11. Field and Pool 1263' FNL_, 853' FWL, Sec.33, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i I Pool 95' RKBI APL 25642 ALK 2573 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. Nc. of Completions 11/18/84 11/23/84 1 2/13/84I N/A feet MSLI 1 17. TotalDepth(MD+TVD) :18. Plug Back Depth (MD+TVD)19. Direc;donalSurvey I 20. Depth where SSSV Set I 21.Thickness of Permafrost 7830'HD,6274'TVD 7725 ' MD ,6200 'TVD YES:~ NO [] 1909 feetMD 1450' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/FDC/CNL, D IL/SFL/GR/FDC/CNL/Ca], Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: 62.5# H-40 5urt 95' 24" 260 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3320' 12-1/4" 875 sx AS III & 810 sx dlass G 7" 26.0# J-55 Surf 7806' 8-1/2" 500 sx Class G & 41 bbl§ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7611' - 7582' w/4 spf, 90° phasing 3-1/2" 7403' 7383' & 7069' 7573' - 7549' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7336' - 7314' w/12 spf, 120° phasing See attached Adden(ium, dated 6/9/86, for frac summary. 7308' - 7163' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I 'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-oILRATIO TEST PERIOD OIL-BBL GAS-MCF WATER-BBE OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE "~" 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit c i NONE JUN25 1986 Ai~k,~ 0ii ~, Gas Cons. Commission . . Form 10-407 WC1/069 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · - . ,,...z ..... .,~., GEOLOGICMARI~[='Rs .... ' ' ,'v - :_ ~- .... .- - . ' " : ..'-ir -'. FORMATION TESTS' ; ' * "' - .: ~ .~ - - .:: - -i .- ., ; ,. . ,. :_. .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7163' 5807' N/A · Base Upper Sand 7339' 5930' Top Lower Sand 7527' 6061' . Base Lower Sand 7734' 6206' · 31. LIST OF ATTACHMENTS Addendum (dated 6/9/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/~/7~J~/ ~L/~ Associ a~:e Lng~, neer ~.~.~ Signed ~,.. _ - Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~407 ALA$ffA OIL MiD ~A$ · SOOt POItCUPIHE DRIVE TEL EPHONE Itc Ii ~l~r. 1433 REs yet: received tile following required ftems on ehe subject well ~l,tcl, our record~ indicated wa. completed_ / Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. · · Chairman lc~C.024 ARCO Alaska, Inc. Post Office bc,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TRP, N,S'iiT.'f'T¢,I... i;,!O".i~l '57 R E.'T U F:; N 'f' [! · F:' ]] N :'.";~ !._ F'R Z ii) F-'.ii] N H,..'E.)L. E ,% C 1--I I... [..1 i"i D I]!; R 2b'--8 i i .... 24-,94 F:.:UN:,~ I i i '" .'2.4 -'-E~ 4 F: I...IN -,,.'"' i i i "-24"-84 F;:UN :,~:t t I .... 24.-.~i!4 RUN :,",:t i i .--'2 .a, .-. ~.".: 4 I;.' I .... ~i',! .,,-'"' I i I .... 24--.~34 RUN ~:t f i .... 2. 4 .... (ii: 4 F;.: U N :,~: t R U N I:;,' U N RUN Fi: U N R U iq. R l..J i'.4 F,'.' U i".! ,, F;: E [] r=.- 'r F:' '1- ~ C !'( ?.-.I .:."il,,,' ~ i!" f; F.; I= p · i.- ..s. ..._ L.. ,.; .. ,.. ................. :I; ,!;: 'r u T'!I! i!!!, i;:i':; ........................ Z-.' F' ~':':~ ii;: l't, '"' ','l , 'r i',! [-:- ."':' E',' I... I.,..! 1" :'" '"~" ~:: ':" .- :%..:. *.. i.., ,!. ... ' I"1 ~.':' I t I,~.I-'". · C U F:; F:. '~ ........ " .............. ..,. i., ;.~: I ........ I[.,, ~ r.'.,:.:. ! t.)N ~F. X X [) N , u', .. '.,,~r;,,. r'~..,, ..~,.! H [I 'f::.:.., ]~ ~ (:: o Alaska, Inc. is a Subsidiary of A U 1~ I~[ ~[i $,1i~ [I; E,~,~'p a,~'~ ][ I... ,..-.: '"l'" '"' ~ '~" ';";~:' t · fi ~(' I;~, L. N ,~? K C I.. u:. '", i-( ':,:' I'.", [ .... J., :-,.. ~'-.'~ ~ r-~,~, ,--. '.- .... :,,:- I¢L. ARCO Alaska, Inc. Post Office ~o~' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-8 Dear Mr. Chatterton' Enclosed is a copy of the 2W-8 Well History to include with the Well Completion Report, dated 02/13/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L64 Enclosure Alaska 0it & ~as Cons. Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office b,.,x 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 Harch 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-8 Dear Mr. Chatterton: Enclosed is a copy of the 2W-8 Well History (Completion Details) to include with the Well Completion Report, dated 02/13/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L19 Enclosure xc: 2W-8 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Anchorage ARCO Alaska, Inc poStoffice(~ ~360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 2/20/85 Transmittal No: 5057 RETURN TO: ARCO ALASKA, INC. ATTN:. Records Clerk ATO-1115B oo3 o J Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OPEN HOLE LIS TAPE: Ref #70023 Run #1&2 1-25-85 2C-13'~ Ref #70041 Run #2 2-1-85 2C-14J Ref #69972 2U-1/ Ref #70050 Run #1 2-5-85 2U-136/ Ref #69971 2U-15~,/ Ref #70007 2U-16 ~/ Ref #70030 Run #1&2 1-30-85 2W-1~' Ref #70053 -Run #1 2~6-85 DISTRIBUTION ~ece~2~ ~c~aow~easea~ Date ~ ........... ~ ~as,,,,~. Cummission Anchorage :B. Currier Drillin~ W. Pasher BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Drill Clerk J. Rathmell Well Files ARCO Alaska. Inc. ~s a subsidiary of AllanlicRichfi~.ldCompany ARCO Alaska, Inc. .~¢,s'i: (¢ffi,;o ~ .... i.00380 '/elei4ir~ne 9OY 270 12'i5 February 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2W-8 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the 2W-8 Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L148 Enclosures iVED Alaska 0ii & Gas ~¢un~, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantJcRichfieldCompany '" ' STATE OF ALASKA .. ALASK, ,._._.. ,ND GAS CONSERVATION ( ~ .... ...SSION WELL COMPLETI , OR RECOMPLETIOh .', PORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-212 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21228 4. Location of well at surface ~ ....... ~_ 9. Unit or Lease Name 1088' FNL, 512' FEL, 5ec.33, T12N, R9E, UN !I,OC~.?i,'.,-??,.Si Kuparuk River Unit At Top Producing Interval~¢ ~ ; 10. Well Number 1255' FNL, 1329' FWL, Sec.33, T12N, R9E, UM isui';-'"~ ~- 2W-8 At Total Depth ~ ~---~ 11. Field and Pool 1263' FNL, 853' FWL, Sec.33, T12N, R9E, UM Kuparuk River Field 5, Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 95' RKB~ ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore ~ 16. No. of Completions 11/18/84 11/23/84 12/13/84~ N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (M~D) 19. DirectionaISurvey 20. Depth where SSSV set ~ 21. Thickness of Permafrost 7830'MD,6274'TVD 7725'MD,6200'TVD YES ~ NO ~ 1909 feet MDI 1450' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/FDC/CNL, D IL/SFL/GR/FDC/CNL/Cal, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5¢ H-40 Surf 95' 24" 260 sx Cold Set II 9-5/8" 36.0¢ J-55 Surf 3320' 12-1/4" 875 sx AS Ill & 810 sx Class G 7" 26.0¢ J-55 Surf' 7806' 8-1/2" 500 sx Class G & 41 bbls AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7611' - 7582' w/4 spf, 90° phasing 3-1/2" 7403' 7383' & 7069' 7573' - 7549' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 7336' - 7314' w/12 spf, 120~ phasing N/A 7308' - 7163' -- 27. N/A PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.} DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. COP E DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 GRU3/WC45 Submit in duplicate Rev. 7-1180 CONTINUED ON REVERSE SIDE ':"' '" ' ' 5 ::? '. '!.¢_--- .. 29. ~":-"'-~.. .. ; .... . .; 30.. :. ;- ...:' :,-,;.- - ~ "" ..... " -:GEOLOGIC'MAR-' ': ~''' ' ";"-,ERS"':' -.:; "'. ""':' ,' "':: -:~'~ ' ~:~' ~¢:¢ ~: ........ ~'' ';: ::'-' ? ~: '-¥ :''~'~:~ M~'T O ' "'R'---i' N,~T~-~ .... .. ' " . ";: :,. ' - ' , '- .. - NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7163~ 5807~ N/A Base Upper Sand 73~9~ 5930~ Top Lower Sand 7527~ 6061~ Base Lower Sand 77~~ 6206~ . . . 31. LIST OF ATTACHMENTS 32. I hereby certity that the toregoing is true and correct to the best of my knowledge Signed ~ ~ ~~ Title Assoo~8~e E.g~.ee. Date d - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air. injection, salt water disposal, water supply for injection, observation, injection for in-situ Combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/25/84 11/28/84 2W-8 Arctic Pak w/41 bbls AS I, followed by 55 bbls Arctic Pak. Rn CBL w/JB & 6.125" gage ring f/7702'-5140'. Rn GCT gyro f/7650'-surf. Drillin~Superint endent Date ARCO Oil and Gas Company Well History - Initial Report- Daily InlttUCflOnl: Prepare and submit the "Initial Rel~ort" on the ;l~t Wednesday attar a well is spudded or workover oC>erations are staJ~ad. Dally wort< prior to SPudding should be summarized on the form giving inclusive dates only. District Field I County, par~st~ or borough State Alaska North Slope Borough Alaska I Lease or Unit Well no. Kuparuk River ADL 25642 2W-8 ITitle Drill, Complete & Perforate Auth. or W.O. no. AFE 203611 Parker 141 API 50-029-21228 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date IHour Prior status if a W.O. Spudded 11/18/84 J 1030 Hrs. Date and depth as of 8:00a.m. 11/18/84 11/19/84 11/20/84 11/21/84 11/22/84 Complete record for each day reported Accept ri~ @ 0600 hrs, 11/18/84. NU diverter sys. 16" @ 95' 2471', (2376'), POH Wt. 9.4, PV 9, YP 9, PH 8.5, WL 14.8, Sol 8 Spud well @ 1030 hfs, 11/18/84. Drl, DD & surv 12¼" hole to 2471'. 1824', 5.4°, S77.5W, 1824 TVD, 6 VS, iS, 6W 2134', 17.2°, S86W, 2127 TVD, 66 VS, 7S, 66W 2416', 27.3°, S84W, 2388 TVD, 173 VS, 17S, 173W 9-5/8" @ 3320' 3335', (864'), NU BOPE Wt. 9.8+, PV 17, YP 16, PH 8.5, WL 8.2, Sol 11 Drl & surv 12¼" hole to 3335', CBU, 15 std short trip, POH. RU & rn 83 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3320', FC @ 3238.59'. Cmt w/875 sx AS III w/ 1/2#/sx cellophane flake, followed by 810 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. Full rtns thruout job. ND diverter sys. NU BOPE. 2773', 33.1°, S84.5W, 2696 TVD, 352 VS, 35S, 351W 3290', 38.1°, S87W, 3113 TVD, 657 VS, 56S, 655W 9-5/8" @ 3320' 4324', (989'), Surv'g Wt. 9.0+, PV 11, YP 11, PH i1, W-L 12.6, Sol 5 Tst BOPE. RIH w/BRA to 3234', tst csg to 1500 psi. DO flt equip, cmt + 10' new formation to 3345'. Conduct leak-off tst to 12.5 ppg EMW. Drl 8½" hole to 3753', turbine drl to 4324'. 3497', 43.1°, S84.5W, 3269 TVD, 793 VS, 66S, 790W 3937', 45.1°, S87W, 3570 TVD, 1114 VS, 94S, lll0W 9-5/8" @ 3320' 6538', (2214'), Drlg Wt. 9.6~ PV 13, YP 6, PH 9.0, WL 8.1, Sol 9.9 Drl & surv 8½" hole to 6538'. 4249' 4935' 5840' 6340' , 44.9°, S89W, 3790.58 TVD, 1334.64, 101.22S, 1330.87W , 45.7°, S88.5W, 4272.54 TVD, 1822.53, 117.10S, 1818.98W , 45.20, S86.5W, 4907.28 TVD, 2467.17, 137.61S, 2463.48W , 46.3°, S86W, 5256.18 TVD, 2825.32, 161.03S, 2820.86W The above is correct Signature p For form 13rel3lretlon end/~atrtb-tlon, see Procedures Manual, ~ctlon 10, Drilling, Pagal 86 and 87. Date Title 3/19/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inslruclion$: This form ~s used dumng dmlling or workover ocerations. If testing, comng, or perforating, show formation name in descmbing work performed. Number ail drill stem tests se~3uentJaJly. Attach 0escriptlon ut all cores. Work performed by Producing Section will be reported on "lnferim" sneers unit[ final comple.on. Report official or representa.ve test on "Final" form. t} Submit "Interim" sheets when filled out but not less frequently than every 30 dayS. or (2) on WeQnesQay of the week in which oil string ~s set. Submit weekly for workovers and following setting of od strinG until completion. District Field Alaska County or Parish I State North Slope Borough I Alaska Lease or Unit Weil no. ADL 25642 2W-8 Kuparuk River Date and dePttl as of 8:00 a.m. 11/23/84 11/24/84 11/25/85 Complete record tot each day while drilling or workover in progress 9-5/8" @ 3320' 7582', (1044'), C&C f/logs Wt. 10.i, PV 13, YP 5, PH 8.5, WL 6.8, Sol 10 Drl 8½" hole to 7267', POH, chg BHA. RIH, wsh & rm 7200'-7267', drl on junk 7267'-7270', drl 8½" hole to 7582', C&C. 6837', 46.1°, S88.5W, 5600.18 TVD, 3183.98 V$, 178.24S, 3179.16W 7192', 45.7°, S86W, 5847.21TVD, 3438.87 V$, 190.47S, 3433.80W 9-5/8" @ 3320' 7830', (248'), RD Schl Wt. 10.0+, PV 14, YP 12, PH 8, ~% 6.8, Sol 10 Circ, spot pill on btm, POH. RU Schl, rn DIL/SFL/GR/FDC/CNL f/7576'-6950', POH & RD Schl. Drl 8½" hole f/7582'-7830', POH. RU Schl, rn DIL/SFL/GR/FDC/CNL/CAL f/7833'-6900', RD Schl. 7770', 44-1/4°, S87W, 6256.10 TVD, 3844.54 VS, 194.04S, 3842.31W 7830', 44-1/4°, S87W, 6299.08 TVD, 3886.11VS, 191.85S, 3884.12W 7" @ 7806' 7830', (0'), Set 7" csg slips Wt. 10.2, PV 14, YP 8, PH 8.0, W% 7.9, Sol 11 RIH & cond f/7". RU & rn 197 jts, 7", 26#, J-55 BTC csg w/FC @ 7727', FS @ 7806'. M&P 500 sx C1 "G" w/3% KC1, .8% D-60 & .2% D-46. Displ w/296 bbls 10.2 ppg brine, bump plug. Reci~p pipe thruout job. ND BOPE, set 7" csg slips. Arctic Pak w/41 bbls AS I, followed by 55 bbls Arctic Pak. The above is correct Signature For form preparation and I~stribut~on see Procedures Manual Se"CtlOn 10. Drilling, Pages 86 and 87 Date 3/19/85 Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report instructions: Prepare and submit the "Finsl Report" on the first Wednesday atter allowable has Peen assigned or ',veil ,s P~ugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefimte or aporec!able !ength of time. On workovers when an official test is not required upon completion, repod completion and representative ',est data in blocks 0rovided. The "Final Report" form may be used for reporting the entire operation ~f space ~s avadaOle. District Alaska county or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. T tie AFE 203611 Parker 141 North Slope Borough Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 11/26/85 Oate and depth as of 8:00 a.m. AR.Co. W.I. 56.24% Date 11/18/84 Complete record for each day reported ADL 25642 Drill, Complete & Perforate IAccounting cost center Code State Alaska API 50-029-21228 ~otal number of wells (active or inactive) on this cost center prior to plugging and abandonment of this well Hour I Prior status if a W.O. I 1030 Hrs. IWeil no. 2W-8 7" @ 7806' 7806' PBTD, RR 10.2 ppg Brine NU wellhead & tst to 3000 psi. RR @ 0900 hfs, 11/25/~. Old TD New TD 7830' (11/24/85) Released r,g Date 0900 Hrs. Classdicadons (oil, gas. etc.) Oil Producing method Flowing PB Oepth 7806 ' 11/25/85 Kind of rig Rotary IType completion (single, dual. etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data .. Well no. ;Date Rese~.,oir Producing Interval Oil or gas Test time ProduCtion O~t on test Gas per day Pump S~ze',' SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature /~ see Procedures Manual, Section 10. Oril{ing, Pages 86 and 87. Date ITitle 3/19/85 Drilling Superintendent AtlanticRichfieldCompany -,- Daily Well -Ristory-lnitial Report Inetructlons: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prlor to spudding should be summarized on the form giving inclusive dates only. IState Alaska Well no. 2W-8 District I County or Parish Alaska I North Slope Borough Field ILease or Unit Kuparuk River I ADL 25642 Auth. or W.O. no, ITitle AFE 203611 I Completion Roll'N 4 API 50-029-21228 Operator ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate IHour Complete 12/9/84 1000 Hrs. Date and depth as of 8:00 a.m. 12/10/84 12/11/84 12/12/84 12/13/84 Complete record for each day reporled A.R.Co's W.I. Pr or status f a W,O, Accept rig @ 1000 hrs, 12/9/84. Wait on weather· 7" @ 7806' 7725' PBTD, Tst'g BOPE 10.2 NaC1/NaBr NU BOPE, tst rams. w/5-1/2" gun, 12 w/5-1/2" gun, 12 7308'-7288'. Rn 7288'-7263'. Rn Perfd 7263'-7243' Perfd 7243'-7223' Perfd 7233'-7203' Perfd 7203'-7183' 7" @ 7806' 7725' PBTD, TIH w/WL Pkr 10.2 NaCl/NaBr Rn #1 w/4" gun, 4 SPF @ 90° phasing. Perfd 7611'-7582'. Rn #2 w/4" gun, 4 SPF @ 90° phasing. Perfd 7573'-7549'. Rn #3 SPF @ 120° phasing. Perfd 7336'-7316'. Rn #4 SPF @ 120° phasing. Perfd 7316'-7314' & #5 w/5-1/2" gun, 12 SPF @ 120° phasing. Perfd #6 w/5-1/2" gun, 12 SPF,= @ 120° phasing. · Rn #7 w/5-1/2" gun, 12 SPF @ 120° phasing. . Rn #8 w/5-1/2" gun, 12 SPF @ 120° phasing. . Rn #9 w/5-1/2" gun, 12 SPF @ 120° phasing. · Rn #10 w/5-1/2" gun, 12 SPF @ 120° phasing. Perfd 7183'-7163'. TIH w/6.125" gage ring & jnk bskt. TIH w/Bkr 7" FB-1WL, set pkr. 7" @ 7806' 7725' PBTD, TIH w/WL Pkr 10.2 NaC1/NaBr, Prep to Shear out f/PBR Fin TIH w/Bkr FB-1WL pkr & tailpipe assy & set same @ 7372' WLM. POOH & RD SOS. RIH w/3-1/2" 9.3# J-55 IPC 8RD EUE tbg compl string. PU & MU Bkr FVL SSSV & tst t/5000 psi, ok. RIH w/a total of 221 jts 3-1/2" tbg & sting into SBR, press up to 300 psi to verify stab in position. PU & circ dwn ann & clean debris f/hole. Space out, PU & MU FMC Gen III tbg hgr, lnd tbg, drop ball, press tbg t/2500 psi & set pkr, tst top of pkr w/2500 psi, ok & prep to shear out PBR. Anchorage The above is correct Signature For form preparation a~d dist~i~-u~on, see Procedures Manual, Section Drilling, Pages 88 and 87. ,[ Date Title 12/28/84 Drilling gnpmr~nt~nd~nt ARCO Oil and Gas Company Daily weiCHistory- Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon cornpietion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation ~f space ~s avatlaPle. DistrictAlaska County or Parish Field Lease or Unit Kuparuk River Auth. or w.O.AFmnO. T t e North Slope Borough Accounting cost center code State Alaska. APL 25642 Well no. 2W-8 Completion Parker 141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth Complete record for each day reported as of 8:00 a.m. Old TD 12/14/84 API 50-029-21228 A.R.Co. W.I. [Total number of wells (active or inactive) on this [cost center prior to plugging and I 56.24% ]abandonment of this well I Date I Prior status if a W.O, Hour 12/9/84 | 1000 Ers. 7" @ 7806' 7725' PBTD, 7830' TD, RR 10.2 NaCl/NaBr Shear PBR, set BPV, ND stack, NU tree, tst FMC Gen III tree t/5000 psi; ok, w/35 bbl diesel ahead. Displ well w/200 bbl crude. SITP = 0, Press ann, shut SSSV & tst same; ok. Open SSSV press tbg orifice vlv; ok. Shear out ball catcher sub w/3500 psi, good indication of shear, bleed off press. well. Rig Released @ 1430 hrs 12/13/84. New TD 7830' TD Released rig Date 1430 Hrs. 12/13/84 Secure Classifications (oil, gas, etc.) Oil I PB Oepth 7725' PBTD Kind of rig Rotary Producing method Flowing Type completion (single, dual. etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct S i g n a t u r ~j~ p...,~....~,,~ ..~.~_~,~,.~ j 12/28/84 Drilling Superintendent For form prepar-atio~"a~J ~istributi~3n7 see Procedures Manual, Section 10, Drilling, Pages 86 and 87. $ UB-$ URFA CE DIRECTIONAL SURVEY F~ UIDANCE F~-] ONTINUOUS ~-] O0 L Company Well Name Field/Location ,, ,.ATLANTIC RICHFIELD COMPANY 2W-8 (10P.8' FI'IL.. 512' FFI. _q~: T'I?N~ P9E. KUPARUK. NORTH SLOPE._ALASKA . Job Reference No. 69864 D. BARBA Date DEC-18-84 Computed By; STEVENS GCT ~)IRECTIONAL SURVFY CUSTOMER LISTING FIR ARCO ACASKAt I~C. KUPARU~ NORTH SLOPE, ALASKA SURVEY DA'TX: 27-NOV-84 ENGINEER: D. BARSA ~ETHODS OF COMPUTATIDN TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 86 DES 13 MIN W~S'T SCHLUMBER©ER ARCO ALASKA, INC. 2W-8 KUPARUK NORTH SLOPE, ALASKA NOVEMBER 2'7, 1984 TVW PLOT FROM OCT DATA RECeivED FFB20 '" Alaska Oil & Gas Cons. Commission Anchorage JOB REFERENCE 69864 WELL' 2W-8 SURFACE LOCATION' 1088' FNL, 512' FEL, S33, T12N,'~R9E, UM VERTICAL PROJECTION -4000 ...; ............. L ....... ~_...~-L:..~-L..: ......... t-..Z_Z._z.IL.~.±~....__._..;-.~-.,L;_.: .......... 'L..: ............. ~..~..:...: ....... J......:...- ....... i .................. J.......: ......... ~ .............. j ............. i .......... -..; ......... .r~.~-.w-'.z-r-..-?.+.-~.~.~: .+..4-?f-.-~--~-~f--p-? ~ .~.~.f-.~...k-?-'h-~ .......................... ~ ................. t ................. ?-', ......... ~---f--.--...~ ......... .~ ................ .~ ................ 4 ................. .J ....... · .-4. .............. -~ ........... .;,.-.~ .......... ~ ........... ~. ............ ~. ........... ~. ................... j.....; ...... ~.......~....?..~ ........... ~_? .............. : ............ . .~ .......... j... ~.. , ' : J ....... ".. ,". ............. ~ . {t:' ....... ................. ? , ........... ................... ~ ................ , ............................................................................. -..J...;--.~...~...~, ...... ,; , ; ; 1-~ ; ......i : L , ' ;. . ~ : : ~ : ; . · ' - ' ~ .......... T .............. t ............. t"T ................. t ................ J 'fi ........... ~'-f"'?"t'-?"""~'"~ ........... ,; ......... ~"~'"f"-"?'~ ....... t ....... ~ ........... t ................... f ....... :'"~ ....... t ......... : ...... t ....... ~"-f ....... ;---: ........ ~---,-~ ........... ~ ............................... ~ .......... ~ ........... J";'; ...... 7'i";'"~ ....... T .............. ;'"~"~ ....... ~ ...... 7? ............... 77T-'~ .......... t .................. T ....... 7'~ ...... ~'~-'~, ............... i ............. ~ ............... t ..... ~ ...... t ......... :'" ! ......... :.! ....... t ........ : t': ............................... ! ............... ~ ............... ! .................. i- ................ ~- ................. t~----:--.~.--? ................ ~ ............ L.~..:...'. .......... i ................... '.- '- ............. ~ ........... ~..~ ...... ~-.- ~ [;;77.;.:.===================================================== ;:;;-~:::: ~Z;Y;;;';y;;~::;: .'..-.f: :;: ZJ;:;:;~';:;'~ .......... =~'"?"--~ ...... :-4 ......... :--'--4 ....... ? ......... f ............. ~--t ..................................... · ' ' ' : ' ' ' J" ? 'F ~"l -t ................... f ................................ ? "t ................................... .,' ................. ? ................ 1 J ................. i ................. ' ' ..................................... ' ' ' " .................. i~ ................. . i, .................. -~ ................... j .................. ~ ' -.,...-. ....... ~---.,..:...-.-.._. '""'"~-'"' ...............: . . l, ..... .~..'.: ................. '' ' !, ................ ............ ?' t ............ J ............... :'"~ .......... f ................ ~ ....... ~ ..... t ..... ?' ~ ...... t ........................ : ...... :'",; ............................... ~ ................ f ...... ? .............. ~ ........ ~ --~ .............. ; ............. ' ": ..... ~, .......... j ..........~ ........... ~ ............... ~ ................ ~ ................. +"~ .............................. t +..-.--..--...-..+..-~-.41Z~,.q. ....... ~ ................... ~ ...... ~ ...... ; ........... ; ............ ......... ' ............... ' ......... ~ ........ ~ .................. ; ................ ;.-.- .............. ; .......................... ~...:. 4 ........................ -~ 1 ...... : .......... 1 ....... i ...... l--:":' ;' :::::::::::::::::::::::::::::::::: :-: ::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: J ............................ I ............. ; .................. i .................. ; ................. ; ................. ~ .............................. ; ........... ~ ....... ! .................. ; ................... ~ ...... ..._.T~.. ;......._' .......... ~ f ..... ,, . ~._ ~;j~'.- ........................... -'~000 -2000 - ]000 0 0 !000 2000 3000 4000 SN ...................... ! ............... ~ ............ t ............... t .................. · ................... ~ ...... - - ~ ....... ; .....................; ......................... ~ .................. 1 ............................... ~ :. ~ '"~ WO~......; ?.::..::' :'...::' ;.: :::.:.:.:'..:.:.!::.:. :'.':'::;::.!:::::. :.::::::::' i:..:::::--:::::: ::::::::::::::::::::: :::::::::::::::::::::::::::::::::: ::::::::::::::::::::::: ::::::::: :::::::::::::::::: ":::::.:. ::::::::::::::::::::::: ..::' ! ' ' ' ' ' ' ' : ;'-~ ..... ; ..... ' .............. i _ - ~ ' --- i - . '. ~ ! ......................... + ................... : ................ t ...................................... ~ ................. %'-',¢'-~ ........................................ ; ................... ~ ................................ Z.: Zi..Z.Z;i;.;.Z;._'-:::::::::::::::::::::: PROJECTION ON VERTICAL PLANE 0F AZIMUTH 266 SCP4. ED IN vERTICAL OEPTH$ HORIZ SCALE = 1/lO00 IN/FT WELL' 2W-8 SURFACE LOCATION' 1088' FNL, 512' FEL, S33, T12N,-R9E, UM HORIZONTAL PROJECTION NO~TH ! 000 0 -1000 -2000 -3000 -4000 -S000 -6000 SOUTH -7000 -7000 WEST ..................................... t ........ + ........ ~"'~' .......... i .............. l ................................................... ! .... ~ ................ -S000 -SO00 -4000 -3000 -2000 -!000 0 ]000 EAST COMPUTATION DATF: 17-~EC-&4. PAC.,E I ARC3 ALASKA, KUPARUK NDRTH SLOPE, INC. ALAS iCA INTERPOLATEO VALUES FQR EVEN I00 FEE 9EASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA COURSE VERT VERTICAL DEVIATION AZIMU[H SEC DEPTH OEG MIN DEG MIN F lO0.O0 ZOO.DO 300o00 ¢00.00 500.00 500.00 700.~0 aO0.DO 900.00 0.00 100.00 200.00 299.9~ 399.99 439.9'7 599.99 699.99 799.99 839.99 lO00.O0 1100.00 1ZO0.O0 1308.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 999.98 1099.98 1199.98 1299.97 1399.97 1439.97 1599.97 ~6}9.9~ 1799.87 1899.27 '90~.~8 0 21 S ~1 55 ~ 100~.98 0 2~ $ 61 4~ W 110~.98 0 31 S 59 5l W 1ZO~.~7 0 23 S 58 3 W 130~.37 0 24 S 67 4~ W 1404.37 0 23 S 38 0 W 150~.97 0 27 $ 43 2S W 1601.96 0 46 S W~ 47 W 1704.87 4 13 S 74 ~ W 180~.27 8 0 S 81 32 W 2000.00 2100.i)0 2200. D0 2300.00 2~00.00 2500.00 2600.00 2700.00 2800.00 2900.00 1997.73 Z094.81 2190.16 2283.27 2373.85 2451.87 25~8.~5 2633.77 Z717.76 2800.29 1902.73 12 2 S B7 23 W 1999.dl 15 4.2 S $8 IL) w 2095.16 19 27 S 86 7 W 2188.27 23 13 S d6 I W 22_78.55 26 46 S 85 52_ W 2366.87 29 23 S 86 0 W 2~53.¢5 30 ~,1 S 85 57 W 2538.77 32 lO S 85 53 W 2622.76 33 35 S 56 3 W 2705.29 34 59 S 86 Z W ICAL DOG TION SEV EET DE~ 3000.00 3100o00 32.00. O0 3300.~)0 3600.00 3500.00 3600.00 3700.00 3800.00 3900.00 Z881.73 2_962.05 304.1.42 3119.73 3136.91 3271.02 33~1.6~ 3408.~6 3472.61 ]536.70 2786..73 36 0 S .~6 1Z d 2867.05 3'7 2 S ~6 26 W 2945o~'2 37 56 S 86 3:~ W 3026.73 38 52 S 86 51 W 3101.91 ~0 37 S 87 D W 317&.02 43 38 S ~7 2k W 324~.69 46 19 S 87 38 W 3313.d6 49 16 S 88 3 W 3377.61 51 2 S 88 Z W 3~41.70 47 19 S 88 17 W O.O0 -0.05 -0.21 -0.25 -O.i8 -0.03 0.15 0.37 0.62 0.94 1.37 1.96 2.71 3.47 6.55 5.12 ~.73 9.33 20.00 3 6 9 12 17 21 26 31 37 4.3 DATE OF SURVEY: 27-N3V-8z, KELLY 3USHIN& ELEVATION: ENGINEER: ~. 8ARBA T OF MEASURED D~PTH 35.0~ FT LEG RZCTANGULAR ERITY NORTH/SOUTH /100 FEET 0.00 0-00 0.60 0.28 0.77 1.00 0.80 1.63 0.50 2.16 0.59 2.70 1.04 3.18 0.68 3.54 0.65 3.92 0.64. 4.27 0.62 4.70 0.70 5.12 0.68 5.53 0.51 5.92 0.58 6.21 0.74 6.60 0.74 7.14 1.11 7.7a 3.62 9.29 4.04 11.3.1 C3DRDINATES H3RIZ. DEPARTURE EAST/WEST DIST. AZINUT~ FEET FEET DEG MIN 7.34 3.05 12.6i 1.25 3.~7 13.55 1.31 3.85 14.88 7.74 3.81 17.60 0.07 3.37 20.42 7.50 1.32 23.80 7.5~ 1.53 27.32 ~.70 1.68 31.01 3.97 1.86 34.81 0.~2 1.01 36.7~ 0.00 ~ 0.00 0.05 E 0.27 0.28 E 1.04 0.36 E 1.67 0.33 E 2.19 0.20 E 2.71 0.07 f 3.18 0.1¢ W 3.5¢ 0.37 W 3.93 0.66 W 4.32 N 0 0 E S IZ 59 f S 15 2'~ E S'IZ 30 E S 8 33 E S 4 19 E S 1 10 E S 2 11 W S 5 20 W S @ 48 W 5a8.02 O. 95 46.5i ~08.85 1.20 ~0.22 571.05 0.82 53.73 73~. 61 3.0 9 57.13 801.72 3.16 60.45 372.45 2.79 63.57 946.68 2.88 66.31 1023.4.7 0.40 58.87 1100.17 8.0l 71.48 1.07 W 4.82 1.62 W 5.37 2.35 w 6.01 3.08 W 6.68 3.69 W 7.22 4.22 W 7.83 4.6.% W 8.52 5.23 w 9.37 8.7~ W 12.75 13.3~ { 22.36 S 12 4.8 W S 17 34 W S 23 3 W S 27 29 W S 30 42 W S 32 36 W S 33 6 W S 33 54 W S 43 14 W S 59 37 W 36.59 W 38.73 60.46 W 61.92 90.53 W 91.74 12.6.86 W 128.07 159.09 W 170.32. 216.40 W 217.71 266.31 W 267.71 318.34. W 319.85 3?1.4~ d 374.11 4Z8.80 W 430.55 S 70 51 W S 77 22 W S 80 39 W S 82 6 W S 83 6 W S 83 43 W S 8½ 8 W S 8¢ 26 W S B~ 39 W S 84 50 W 636.70 W 688.57 54.6.1 4 W 548.12 606.8& W 608.9~, 668.96 W 671.11 732.4% W 734.6b 799.~Z W 801.76 870.15 W 87Z.41 9~4.16 W 946.49 i021.1b W 1023.4~ 1097.8~ ~ 1100.17 COMPUTATI3N DATE: 1Z-DEC-B4. PAGE ARCO ALASKA, INC. 2W-8 KUPARdK NORTH SLOPE, ALASKA OATE OF SURVEY: 27-NDV-8½ KELLY aUSH/NG eLEVATION: ENGINEER: D. 8ARSA 95.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUROO D~PTH TRUE SUB-SEA COURSE ~EASURED VERTICAL ~ERTICAL DEVIATION AZIMUTH DEPT~ DEPTH DEPTH DEG MIN DEG MIN VERTICAL 80GLEG RECTANGULAR COORDINATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZ,ZNUI~ FEET OEG/IO0 FEET FEET FEET D'EG WIN 4800.00 3606.58 3511.58 4.5 23 4100.00 3676.83 3581.~3 45 25 ~200.00 374.6.98 3651.98 Z, 5 21 4300.00 3817.30 3722.30 45 26 4~00.00 3887.38 3792.38 4.5 30 4500.00 3957.~3 3862.~3 45 33 4500.30 ~027.34 3932.3~ 45 39 ~700.00 ~097.17 4002.17 ~5 46 4~00.00 ~156.8~ 407I.a6 45 48 ~900.00 ~236.64 4141.64 45 44 S B8 25 W 1171.64 S 58 Z} W 124.2.75 S 88 19 W 1313.97 S 88 15 W 1385.02 S ,58 7 d 14.56.31 S 87 55 W 1527.64 S 87 ~5 w 1599.11 S 87 42 W 1670.~7 S 87 4Z W 1742.37 S 87 45 W 1813.96 0.45 0.2~ 0.77 0.40 0.27 0.16 0.36 0.25 O.Z1 0.50 73.36 S 1169.34 W 1171.6~ S '186 24 W 75.35 S 12½0.4~ W 12~2.71 S"'86 31 W 77.4.~. S 1311.72 W 1314.00 S, ~6 37 W 79.49 S 1382.79 m 1385.07 S 8 ~m ~ ~ W 81.71 S 14S~.09 W i~56.38 S 86 47 W 84.1~ S 1525.41 w X52).)3 S ~ 50 W 86.84 S 1596.86 W 1599.22 S 86 53 W 89.63 S 1668.39 W 16~0.79 S 86 55 W 92.50 S 17~0.0~ W 1742.51 S 85 57 W 95.36 S 1811.67 W 1814.13 S 86 59 W 5000.00 ~.306.4,~ 4Y. 11.~,4 45 47 5{.00.00 ½376.13 4281.13 4,5 4.3 5 ZOO. ~lO ~.445.77 4.350.77 ~5 57 5300.00 ~515.41 4~20.41 ~5 4b 5~O0.DO ~585.23 4490.23 ~5 40 5500.00 ~654.99 4559.99 ~5 46 5600.00 ~724.62 4529.02 45 57 5~00.00 ~T~.3Z 4699.32 45 36 5800.00 ~864.3~ 4~69.37 ~5 27 5gOO.D0 ~934.47 4839.47 ~5 37 S 67 53 W 1885.55 S 87 4.1 W 1957.23 .S 87 2a W 2028.98 S 87 17 W 2100.73 S 87 3 W 2172.31 S 87 1 W 2243.95 S 87 21 W 2315.71 S a7 35 W 2387.40 S 87 40 W 2458.7~, S 87 3B W 2530.0~ 0.42 0.39 0.47 0.3,3 0.10 0.40 0 0.68 0.31 0 98.00 S 1883.18 W 1885.73 S 81 1 W 100.76 S 1954.8~ wi 1957.44 S 87 2. W 103.82 S 2026.55 d 2029.21 S 87 4 W 107.08 S 2098.2½ W 2100.9'7 S 87 4 W 110.56 S 2169.74 W 2172.56 S 87 4 W 114.31 S 22~1.2~ W 2244.20 S B7 4 W 11).80 S 2312.98 W 2315.9~ S 8~ 5 W 120.93 S 2384.62 W 238~.68 S 8) 5 W 123.81 S 2455.9] ~ 2459.05 S 8) 6 W 126.~6 S 252~.18 W 2530.3b S 8) ~ W 6000.00 5004.11 4909.11 '5 47 6100.00 5013.37 4978.37 46 26 6200.00 5142.29 5047.29 46 26 6300.00 5211.0~ 5/1b.04 46 40 6400.00 5279.67 5184.67 4.6 32 6500.00 534.8.60 5253.50 46 29 6500.00 5417.56 5322.$4 46 20 6700.00 5486.50 5391..50 4.6 26 6~]00o00 5555.46 54.60 . 4.6 46 17 6900.00 5624.75 5529.75 4.6 T S 87 38 W 260L.78 S 87 36, W 2673.89 S 87 4~, W 2746.32 S a7 31 W 2815.92 S ~7 24. W 2891.6,4 S 87 Z5 w 296~*.07 S 87 2~ ~ 303~.~9 S 87 Z~ W 3~08.90 S 37 12 W 3181.30 S 87 .13 W 3253.39 0.37 0.37 0.32 1.51 0.87 0. 0 0.72 0.19 129.6~ S 2598.8') W 2602.12 S 87 8 W 132.67 S 2670.95 m 2674.25 S 87 9 W 135.65 S 27~3.35 W 274.6.70 S 87 lO W 138.66 S 28/5.9t W 2819.32 S 8]' I0 W 1~1.88 S 28~8.5'1 W 2892.05 S 87 11 W 145.13 S 2960.9~ W 2964.50 S 87 11 W 1~8.40 S 3033.3E W 3036.93 S 87 11 W 151.67 S 3105.66 W 3109.36 S 87 12 W ', 155.18 S 3177.99 W 5181.78 S 81 1Z W 158.68 S 3250.00 W 3253.87 S 87 12 W 7000.00 5696.00 5599.00 4.6 11 7100.00 5763.19 5668.19 45 59 7200.00 5832.7'~ 5737.79 45 53 7300.00 5902.71 5a07.'?1 4.5 2~ 7400.00 5972.54. 5~77.54 '~5 59 7500.00 6041.83 5946.33 ~6 8 7600.00 6,111.75 6016.75 ~5 25 7700°00 5182.29 6087.29 ,44 58 7800.00 $253.02 6158.02 44 58 7830.00 b274.Za 6179.24 44 58 S 87 18 W 3325.52 S 87 25 W 3397.71 S 87 Z W 34.69.,~9 S 87 29 W 35~,0.98 S 88 13 W 3,512.53 S 89 Il W 368~.57 N i39 2~ W 3755.90 N 89 1~ W 3826.58 N 89 1~ W 3893.05 ~ 89 17 W 3918.19 0 0.90 0 0.69 0.86 1 0.00 0.00 0.00 152.07 S 3322.07 , 3326.02 S 8]' 12 W 165.41 S 3394.19 W 3398.22 S 87 12 W 168.80 S 3465.91 W 5470.02 S 87 12 W 172.37 S 3537.32 W 354.1.5,1 S 87 12 W 175.13 S 3608.84 W 36i3.09 S 87 13 W 176.8/+ S 3680.92 W 3685.16 S 8~ 14 W 176.83 S 3752.41 W 3756.57 S 87 18 W 176.07 S 3823.29 w ~827.34 S 87 21 W 175.20 S 3893.97 W 3897.91 S 87 25 W 174.93 S 3915.18 a 3919.09 S 87 26 W ARCS ALASKA, INC. 2W-8 KL)PARL~K NORTH SLOPE, ALASKA C~MPUTATIJN DATE: I?-OEC-8~ DATE OF SURVEY: 27-N3V-86 KELLY 5USHZN~ ELEYAI[QN: ENGINEER: D. BARSA INTERPOLATED VALUES FOR EVE~ lOOO FEET 3F MEASUREO OEPT TRUE SUB-SEA C~URS£ MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MiN ~5.00 F! 0.00 0.00 -95.00 0 0 1000.00 999.98 '~04. g8 0 21 2000.30 1997.73 1902.73 12 2 3000.00 ZBdl.73 2.786.73 36 0 ~000.00 3606.58 3511.$~ ~5 23 5OO0.O0 ~306.~,¥ 4211.~4 ~5 ~7 6000.00 500~.11 ~30~.11 ~5 ~7 7000.00 569~.00 5599.0D ~6 11 7830.D0 627~.2+ 617'~. Z~ ~4 58 VERTICAL DOGLEG RECTANGULAR COORDINATES H2RIZ. OEPARTJRE S2CTiON SEVERITY N~RTH/SDUTH EAST/WEST DIST. AZIMUTr~ FEET DE~/IO0 FEET FE2T FEET DEG N 0 O 6 0.00 S 41 5~ W 1.37 S ~7 23 W 3)'.34 S 88 25 W 1171.04 S 87 53 W 1885.55 S 87 3~ W 2601.78 S ST 18 W 3325.52 N a9 ll W 3913.19 0.00 0 3 1.27 0 0 0.37 0 O.OO £OMPUTATI,3N DATE: 17-0EC-84 PAGE ARCO ~LASKA, INC. 2W-8 K~PARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 27-N~)¥-8½ KELLY BUSHIN~ ELEVATION: ENGIN':ER: D. ~ARBA 95.00 FT INTERPOLATED VALU~_S FOR EVE,~ IOO FE6T OF $U~-SEA DEPTH TRUE SUS-SEA COURSE 4EASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPT~ DEPTH DEPTH DEG MIN DEG MiN. VERTICAL DOGLEG RECTAhiGULAR C3020[NATES HDRIZ. DEPARTJRE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTN FEET DEG/iO0 FEET FEET FEET BEG 0.00 0.00 -93.00 0 0 hi 0 0 E 95.00 95.00 0.00 0 28 S 11 38 E 195.'~0 195.00 100.00 0 28 S 11 23 E 295.01 295.00 200.00 0 20 S 12 3~ E 395.01 395.00 300.00 0 20 S 19 10 W 695.01 4~35.00 600.00 0 22 S lB 33 W 595.01 595.00 500.00 0 14 S 6 t W 695.~1 695.00 600.00 0 15 S 63 3 W 795o01 795.00 700.00 0 15 S 20 0 Wi 895.01 895.00 ~00.00 0 1'~ S 50 53 W 0.00 0.00 0.00 ~ 0.00 -0.06 0.36 0.26 S 0.06 -O.ZO 0.8~ 0.90 S 0.2~ -0.25 0.86 1.61 ~ 0.3b -O.i9 0.5~ 2.13 S 0.36 -0.04 0.49 2.61 5 0.22 3.15 1.05 3.16 S 0.06 0.35 0.66 3.52 S 0.12 ~.62 0.77 3.90 S 0.36 0.92 0.68 4.25 S 0.6~ 0.00 N 0 0 E 0.25 S -13 31 f 1.00 ,$ ~"17 E 1.6~ S 12 29 E 2.16 S 8 56 E 2.68 $ ~ 36 E 3.16 S ! 8 E 3.52 S [ 53 W 3.9~ S 5 17 W 4.30 S 8 31 W 995.02 995.00 900.00 1095.02 t095.00 1200.00 1195.02 1195.00 1100.00 1295.03 1295.00 1200.00 1395.03 1.395.00 1300.00 1695.03 1495.00 1,~00. O0 1595.03 1595.00 1500.00 1595.04 16'95.00 1600.00 1795.12 1795.00 1700.00 1895.69 {.895.00 1800.00 t.35 0.5t 4.67 S 1.05 .I 1.92 0.5') 5.10 S 1.5') W 2.67 0.55 5.51 S 2.31 W 3.64 0.61 5.90 S 3.05 W ~,.06 0.6'7 6.20 S 3.65 W 6.62 0.75 6.57 S 4.20 W 5.09 0.75 7.11 S 4.63 W 5.68 1.07 7.73 S 5.18 W 9.00 3.65 9.19 S 8.41 W 19.61 3.90 11.22 S 18.71 d 4.79 S IZ 39 W 5.35 S 17 17 W 5.97 S 22 46 W 6.65 S 27 21 W 7.1'9 S 30 32 W 7.80 S 32 34 W 8.49 S 33 3 W 9.31 S 33 49 W 12.4~ S 42 2~ W 21.81 S 5'9 3 W 1997.Z1 1995.00 1900.00 11 57 2100.20 ;'095.00 2000.00 15 42. 2205.15 Z195.00 2100.00 19 3':) 2312.19 2295.0D 2200.00 23 41 2r, 23.77 2395.00 2300.00 27 35 2.538.10 2495.00 2~+00. O0 29 51 2654.38 2595.00 2500.00 31 30 2772.76 2695.0.0 2000.00 33 J 2893.54 Z735.00 2700.00 3~, 5.5 301 6o 6/, 2895.00 2800.00 36 11 S 87 2{3 W 35.76 2.93 S 88 10 W 61.30 3.45 S 86 Z W 93.06 3.89 S 86 `) W 132.85 3.73 S 85 50 W 180.93 3.56 S ~5 57 W 236.33 1.20 S 85 55 W 295.64 1.27 S 85 5~ W 358.~9 1.32 S 86 Z W 426.13 ~.06 S 8b 15 W 498.15 1.12 12.67 S 36.00 W 38.16 S 70 36 W 13.55 S 60.54, W 62.04 S 77 23 W 15.01 S 92.27 d 93.49 S 80 45 W 17.94 S 131.95 W 133.16 S 82 15 W 21.22 $ 179.92 W 181.17 S 83 16 W 25.11 S 235.1'`) w 236.53 S 83 54 W Z9.31 S 294.35 W 295.81 S 84 18 W 53.77 S 357.56 W 359.1'~ S 8~ 36 W 38.~9 S ~25.1~ W ~26.85 S 86 ~9 W ~3.33 S ~96.3~ W 498.2~ S 8~ 0 W 3141.37 2995.00 2900.00 37 22 3268.31 3095.00 3000.00 38 37 3397.~9 31'95.00 3100.00 ~,0 3,5 3533.39 3295.00 3200.00 44 38 367@.~6 3395.00 330D.00 48 39 3835°$4 34'95.00 3400.00 50 58 3983.51 3595.00 3500.00 65 27 4125.89 3695.00 3600.00 45 26 4268.24 3795.00 3700.00 ,~5 21 4410. ~38 3895.00 3800.00 45 30 S 86 28 W ,573.04 S 86 48 W 651.22 S 87 3 W 732.98 S 87 25 W 826.96 S 87 5'~ W 930.53 S 88 I W 1051.19 S 88 25 W 1159.91 $ 88 1`) W 1261.18 S 88 20 W 1362.~2 S 88 b W 1464.06 0.74 3.10 2.68 3.1,~ 0.89 0.60 0.21 0.41 0.20 ~.8.06 S 571.11 Wi 573.1,3 S 85 11 W 52.64 S 6%9.16 W 651.29 S 85 21 W 57.06 S 730.81 W 733.03 S 83 32 W 61.51 S 822.69 W 824.99 S 85 43 W 65.76 S 928.21 W 930.54 S 85 56 W 69.83 S 10~8.87 W {.051.19 S 86 11 W 73.03 S 1157.61 W 1~59.91 S 85 23 W 35.89 S 1258.92 W 1261.20 S 8~ 33 W ~8.83 ~ 1360.I3 W 13~2.46 S 86 40 W 81.96 S 14&1.8~ W 1464.14 S 86 47 W CONPUTATI3N DAT£: 17-DEC-84 PAGE ARCO kLAS~A, [NC. KUPARgK NgRTH SLOPEm ALASKA DATE OF SURVEY: ZT-N3V-84 KELLY 5USH[N& ELEVATION: ENGINEER: D. 8ARi3A '~5. O0 FT INTERPOLATED VALUES FOR EVEN ID0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA C,qURSf EASURED VERTICAL ~ERTICAL DEVIATION AZIMUTH 3EPT:~ DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES H3RIZ. DEPARTLJRE SECTISN SEVERITY NORTH/SOUTH EAS//dEST DIST. FEET DE~/IO0 FEET FEET FEET 4553.69 39'~5. O0 3900.00 45 40 4596.59 ~0~5.00 4000.00 45 45 4840.38 ~,195. O0 4100.00 ½5 45 4983.~0 ~ZgS.O0 4200.00 45 45 5127.02 ~,395. O0 4300.00 ~,5 46 5Z70.. 70 ~495.00 4~,00.00 45 51 5413. ~8 ~,5 :JS. O0 4500.00 45 41 5557°38 4695.00 4500.00 45 52. 5700.97 ~7~5o00 4700.00 ~5 36 5843.~7 ~895.00 4500.00 ~5 ;..7 S 37 50 ~ 1565.98 S 37 42 ~ 1668.44 S 57 ~2 ~ 177L.31 S 37 5% ~ 1573.80 S 87 35 ~ 197b.57 S 37 2O ~ 2079.72 S 87 I ~ 2182.31 S 87 1~ W 2285.08 S 57 35 . 2388.~0 0.38 0 .Z1 0.5) 0.35 0.60 0.59 0 0.5,) 0 85.57 S 1563.7~ W 1566.08 S 86 52 Id 89.5~, S 16~6.16 ii 1668.56 S 86' 55 il 93.65 S 1758.9~ ~ ~771.46 S 86' ,58 ~ 97.57 S 1871.4~ ~ 18?3.98 S 81 ~0 W 101.55 S 191~.17 ~ 1976.~8 S 81 3 W 106.0~ S 2077.25 ~ 20?9.95 S 87 4 W lil.O/ S 2119.73 W 2182.56 S 87 4 ~ 116.3~ S Z282.38 W ZZ~5.3~ S 8~ 4 W 120.96 S 2385.31 , 2388.38 S 8I 5 ~ 125.10 S 2~l. OZ ~ 2~90.11 S 81 7 W 5986.94 ~995.00 4900.00 e'5 48 6131.~1 ~095.00 5000.00 46 Z8 6276.51 5195.00 5100.00 ~6 39 6422. Z3 5295.00 5200.00 46 27 6567.38 5395.00 5300.00 ~6 19 6712.34 5495.00 5400.00 46 26 6857.~6 5595.00 5~00.00 7O01o~5 5695.00 5600.00 ~6 lI 7145.$9 5795.00 5'700.00 ~5 52 7289.03 58~5.00 5800.00 45 Z1 S 87 39 ~ Z59Z.~3 S 87 3~ W Z696.~6 S 37 33 W 250t.91 S 87 2~ W 2901.72 S 87 13 W 301Z.91 S ~7 1~ ii 3122.~3 S 87 1~ ~ 3320.57 S 87 2~ i 3~30.50 S 87 2~ ~ 3533.18 0.59 O.lZ 0.32 0.76 0.51 0 0 0.4l 129.3i S 2589.54 m 2592.71 S 87 8 W 133.63 S 16-J3.71 W 2.697.03 S 8T 9 W 137.92 S 2798.90 W 2802.30 S 87 10 W 1~2.59 S 2.904.64 ~I 2908.1~ S 87 Il ~ 1~7.33 S 3009.75 W 3013.36 S 87 11 W 152.09 S 3114.59 W 3118.30 S 87 12 W 157.17 S 3219.07 W 3222.91 S 81 12 W lb6.88 ~ 3416.96 W 3431.0l S 81 ll W 172.02 S 3529.52 w 3533.~1 S 87 12 W 7~,3Z. 34 5995.00 5900.00 46 ~ 7576.13 $095.00 6000.00 ~5 22 7717.98 6195.00 6100.00 ~ 58 7830.00 5274.Z~ 6179.14 ~ 58 S 88 25 W 3635.79 N 39 33 W 3738.94 N 89 17 W 3839.24 N 59 17 ~, 3918.19 0.54 0.7,Z 0.00 O.OO 175.78 S 3632.10 W 3636.3b S 87 13 W 176.98 S 3735.40 W 3739.59 S 81 17 W 175.91 S 3836.00 W 3840.03 S 87 2.2 W 174.93 S 3915.18 W 3919.09 S 87 Z6 W C~MPUTiTI~N DiTE: I~-DE~-B~ ~ ARCO ALASKA, INC. KLJPAEJK NORTH $LOPE~ ALASKA TOP UPPER SAND BASE LJPPER SAND TOP LOWER SAND PBTD BASE LONER SAND TOTAL DEPTH INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM K5 ~RIGiN: TVD PA~E DATE OF SURVEY: ZT-N~V-8~ KELLY BUSHING ELEVATION: ENGINEER: D. &ARBA 95. O0 FT SUB-SEA 7163.00 5807.05 571Z.05 1339.00 5330.03 5835.03 7527.00 6060.$5 59~5.55 7725.00 6199.97 5104.91 7734.00 6i06.33 7830.00 6274.2~ 6179.24 FNL, SURFACE LOCATION 512' FEL, SEC 33, T12N, R~E, RECTANGULAR C00ROI#~?ES NORTH/SOUTrt EAST/WEST 167.~7 S 3~,39.3~ 173.53 S 3565.1;2 177.04 S 3100.31 175.85 S 3840.96 17S.7~ S 38~1-32 /74.93 S 3915.[B JM CgMPUTATI3N DATE: 17-DEC-84 PAG~ ? ARCO ALASKA, lNg. KUPARdK NORTH SLOPE, ALASKA MARKER TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND P~TD BASE LOdER SAND TDT~,L DEPTH MEASURED DEPTH 8ELO~ KB 7163.00 7339.00 7527.00 I725.00 773&.00 7830.00 DATE OF SURVEY: 27-N,"1V-8~, KELLY '8, USHINS ELEVATION: ENGZNEER: O. 6ARBA ORIGIN: 1088' FNL, 512' TVD REC FRgM KB SUB-SEA NO SURFACE LOCAIION AT FEL~ SEC 33, TJZ~, R}E, TANGULAR COORDINI'T E S RTH/SOUTrl E~$XJWEST 5807.05 5712.05 5~30.03 5835.03 6060.55 · 5965.55 6199.~7 510~,.97 6205.33 6111.33 627~.Z4 b179.2,~ X67.,~7 S 3439.3"J' kl L73.53 S 3565-I2 177.04 S 3700°37 17.5.85 S 3840.96 iQ ~75.7]' S 3847.32 174.93 S 3 915..,18 FINAL MEASURED DEPTH 7830.0D ~ELL L3CATZON TRUE VERTICAL DEPTH 627~.Z4 AT TO: Su~-S~A VERTICAL DEPTH 5179.2q, .HORIZONTAL D~PARTURE DISTANCE AZIMUTH FE2T D~G MZN 3919.D9 S 87 25 · ' Date . Required Date Received Remarks · · . · · We11 Hi ' ' Yes j. . S~les . , ,, - ' ~~ ' ~'~ ~ ~~pl ...... · ~ /~ , , , ,, ,. , · ~ ~ .. ., ~ ' ~ / '". " ' ' ' v ' ' ' ' '' - ~ ....... Registered S~ " ' ' ...... ~ ~~ .V~, ~--o/-~.. ~ , , - ~ . Drill St~ Test Re~s ~~ ,.,, _ , .. . ....... . .. ,, , .' _ ~ ARCO Alaska, Inc. Post Offic ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/30/85 Transmittal No: 5013 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B T~~a~~.O. Box 100360 chorage, AK 99510 itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. BHP REPORTS & .SEQUENCE QF EVENTS _ 1G-4 9/30/84 9/04/84 "BHP" 1G-1 :, 11/24/8_4 11/24/84 "SBHP" 1L-8 10/05/84 1L-7 10/19/8'4 1L-6 10/18/84 1L-5 10/18/84 1L-4 10/19/84 2W-7~' 1/07/85 2W-6 1/07/85 2W-5 1/07/85 2W-8~ 1/08/85 1E-5 11/ 5/84 · . .1/07/84 1/07/84 1/07/84 1/08/84 11/26/84 "SBHP" "Initial" "SBHP" "Initial" "SBHP" · "Initial" "S BH~P" "Initial" "SBHP" /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M Date DISTRIBUTION Drilling W. Pasher State of AK Geology -' G. Phillips Sohio Mobil Phillips Oil Union NSK Ops. J. Rathmell Well Files ARCO A/aska. Inc. iS a subsidiary of AllanticRichfieldCornpan¥ ARCO Alaska, Inc. Post Office x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B p.0.~j~"100360 ~o~orage, AK 99510 · . ~ /T~nsmitted herewith are the following items. Please acknowledge receipt '~and return one signed copy of this transmittal. OTIS PBU SURVEYS 2w-s~'' 1/08/85 1B-7 ' 12/14/84 2F-12 1/06/85 2F-5 1/02/85 2W-§ ". 1/07/85 ~w-6 - 1/07/85 12W-7 - 1/07/85 i lA-l' 12/31/84 lA-1 12/15/84 lA-1 12/23/84 lG-5 12/25/84 2F-3 '12/31/84 2V-8A'- 12/16/84 2B-10 '~ 12/17/84 1Y-9--~ 12/20/84 ., .lC-~~ 12/10/84 2F-2~ 12/29./84 2F-15 1/05/85 2F-14 - 1/04/85 2F-9~ 1/02/85 2F-8~ 1/01/85 API 02 9-21228 ~029-2D616 029-21097 029-21073 -- 029-~'1220' -- 029-059O0 029-20908 029-21178. 029-21084 029-20935 029-21 063 029-21048 029-2~ 090 029-21077 CAMCO PBU SURVEYS 1E-12 · 12/14, 16/84 /cat Receipt Acknowledged: Date:Na~ka 0il & Anchora98 DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rat~nell Well Files ARCO Aleska, Inc. ~t a subsidiary ol AtlanticRichfieldCompa.y ARCO Alaska, I' Post Offi~e~Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 11, 1984 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are the November monthly reports for the following wells- 2D-14 2W-5 2X-11 2D-15 2W-6 2X-12 2D-16 2W-7 2X-13 2E-14 2W-8 15-9 2E-15 2W-9 Also enclosed is a Well Completion Report for 2B-14. any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer If you have JG/tw GRU3/L03 Enclosures RECEIVED Alaska Oil & Gas Cons. Commission Anchorago ARCO Alaska, Inc. Is a Subsidiary of Allantic~ichfieldCompany STATE OF ALASKA ALASKA O-~=AN D GAS CONSERVATION COk~_,lSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well I~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-212 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21228 9. Unit or Lease Name 1088' FNL, 512' FEL, Sec.33, T12N, R9E, UN Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) 95' RKB, PAD 65' I 6. Lease Designation and Serial No. ADL 25642 10. Well No. 2W-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1030 hfs, 11/18/84. Drld 12-1/4" hole to 3335'. 8-1/2" hole to 7830'TD, as of 11/23/84. Ran OH logs. Ran Secured well & RR ~ 0900 hrs, 11/26/84. Ran 9-5/8" csg. 7" csg. PBTD = Drld 7725'. 13. Casing or liner ryn and quantities of cement, results of pressure tests 9-5/8" 36.0#/ft, J-55, HF-ERW BTC csg w/FS 8 3320'. Cmtd w/875 sx AS III & 810 sx Class "O" cmt. 7" 26.0#/ft, J-55, HF-ERW BTC csg w/FS ~ 7806'. Cmtd w/500 sx Class "G" cmt and 41 AS I & 55 bbls Arctic pack. bbls 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/GR/FDC/CNL f/7576' - 6950' DIL/SFL/GR/FDC/CNL/Cal f/7833' - 6900' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED_ _ ~-J:.~' TITLE Associate Enoin~.~.r~ DATE i2~7-¢4 NOTE--Repor~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/MR81 Rev. 7-1-80 Submit in duplicate MEMORANDUM State'of AlaSka ALASKA OIL AND GAS CONSERVATIO~ CO}R.%ISSION /F/j~'½ C. V/~,a~t'er t on Chai~..r~ .-' TO: THRU: Lonnie C Smith Commissioner FROM: Ben LeNorman Petroleum Inspector DATE: November 21, 1984 FILE NO: Do lI. 41 TELEPHONE NO: .... ~. ~.~V t SUBJECT: Witness BOPE Test on ARCO' s Kuparuk 2W-8, Sec. 33, T!2N,R9E,L~--,:, Kuparuk River Unit. sOVember,16, 1984: I departed my home at 5:45 am for a h°wup a{i'~ ~7::i~' ~m departure via Alaska Airlines, Fit. #55 for Deadhorse arriving at 9:45 am. Weather: -1A°F. , clear, blowing snow. BOPE tests on ARCO's Kuparuk 2X-12 were completed, the subject of a separate report. Saturday, November 17, 1984: Standing by on DS 11-12. Sunday,_ November 18, 1984: BOPE test on AB. CO' s DS 11-12 ~Dega~,-~ at I0:45 pm . . . 1,'Ionday, November 19, 1984: . . . and were completed at 12:30 ~-he"Subject o~ a separate report. Tuesday, November 20, 1984: BOPE tests on ARCO's Kuparuk 2W-8 ~egan aE 9-~'20 am and were completed at 10:20 am. BOPE inspection report is attached. I departed Deadhorse at 5:40 pm via Alaska Airlines, Flt. #56, arriving in Anchorage at 7:20 pm and at my home at 7:50 pm. in s~ary, I witnessed successful ~-OPE test on ARCO's Kuparuk 2W-8. At t achment 02-00 ¢ A(F~ev. 10/79) O&G tt4 5/~4 Inspector Z ~~~ ~q~ Operator ~~ Location: Sec _~ T/A~~---M g7/~ STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date /~//~~,~ Representative Permit # ~- ~,~ f ~- ~%'sing Set @ ~ ~P ft. Drilling Contractor '/-~~k~_ Location, General ~/~ Well Sign~/~ General Housekeeping ~/~Rig ~/~ Reserve Pit /~~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Test Pressure Rig #/~/ Representative ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: N~ ~..~o0! D..~..~"~ ~~,~'~ ~l~psig Controls: Master Z~P/z~ Remote~/~ Blinds switch cover~.~ psig ~~ psig ~.,~ ~ rain ~%-sec. ~ mind, sec. Kelly and Floor Safety Valves Upper Kelly Test Pressure Lower Kelly Test Pressure Ball Type Test Pressure Inside BOP Test Pressure Choke Manifold Test Pressure No. Valves ~ No. flanges ,~ Check Valve ~~__~ Adjustable Chokes Hydrauically operated choke / Test Results: Failures / Test Time / hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector l~oven'~Der 14, 1984 ~fr. Jeffrey B. Kewin Area Drill' ~ · n~ Enginee~ ARCO Alagka, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2W-8 AKCO Alaska, Inc. Permit Ilo. 84-212 Sur. Loc. 1088' F~, 512' FEL, Sec. 33, T12i~, RgE, UI~. Btmhole Loc. 1336' FNL, t0!0' ~, Sec. 33, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one co~ic inch chip from each foot of recovered core is required. Samples of well cuttings and a n~ad log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs ±or copying except experimental logs, velocity su~zeys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa~ing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to con~mencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code,.Chapter 70) and by the Federal Water Pollution Control Act, ao amended. Prior to ce~encing operations you may be contacted by a repres-~ ~ ~ ~ the Department of Environmental Conservation. To aid us in scheduling field work, please notify this ofzmce ~ hours prior to commencing installation of the blowout prevention Hr. Jeffrey B. Kewin Kuparuk River Unit 2W-8 l~ovember 14, !984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~rhere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission n~y witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very tru.l' / C. V. Chatterton Chaiman of Alaska Oil and Gas Conservation Co~ission BY OgDER OF TIIE COI.~flSSiOI-~ lc Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Doug L. Lowery Environmental Supervisor Pouch 1601 Fairbanks, Alaska 99707 w/o enci. ARCO Alaska, Inc. Post Office b,.,-x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 .November 6, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2W-8 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2W-8, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o Proximity plat o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on November 16, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ]B ,~_rely' i'ng Engineer JBK/JG/[:w GRU2/L66 Attachments RECEIVED ,NOV 0 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION CO%~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL []X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC MULT L 9. unit or lease name 10. Well number 2. Name of operator ARCO Alaska, Irc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1088' FNL, 512' FEL, 5ec.33, T12N, PgE, UN At top of proposed producing interval 1306' FNL, 1#72' FWL, 5ec.33, T12N, PgE, UN At total depth 1336' FNL, 1010' FWL, 5ec.33, T12N, R9E, UH 5. Elevation in feet (indicate KB, DF etc.) RKB 95', PAD 65' 6. Lease designation and serial no. ADL 25642 ALK 2573 2W-8 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Beadhorse miles 1010~ @ TB feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7749' MD, 6255' TVD fec. t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICKOFF POINT 1753 feet. MAXIMUM HOLEANGLE 45 Ol(see2OAAC25.035 (c) (2) 15. Distance to nearest drilling or completed 2W-7 wel~-~,60' 8 surface feet I 18. Ap~r~xim'~te spud date .kfl 1'/56184 2766 psig@ 80°F Surface 3104 psig@ 6!!5 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT _ _ , Hole I Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOMTVD (include stage data) 24" 16"- 62.5# H-40 Weld 80' 29' I 29' 109' 109' ± 200 cf 12-1/4" 9-5/8" 36 0# J-55 BTC 3241' 29' I 29' 3270'I 3115' 870 sx AS III & · I HF-ERW I ] 790 sx Class G 8-1/2" I 7" 26.0# J-55 BTC 7721' 28' II 28' 7749'1 6255' 400 sx Class G blend I T HF-ERW I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 77#9' MD (6255' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing wi]] be set through the West Sak sands at approximately 3270' MD(3115~ TVB). A 13-5/8", 5000 psi, RSRRA DOPE stack will be instal]ed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2766 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated w~th an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover r~g with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annu]i through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certify~at the foregoing is true and correct to the best of my knowledge // SIGNED / ~_~~4,¢~(,~,~,~ TITLE Area Drilling Engineer ~h~e sp~ece ~el~/for O~:)nff~ion use CONDITIONS OF APPROVAL DATE Samples required F1YES Z~-NO Permit number APPROVED BY GRU2/PD22 Mud log required ! Directional Survey required I APl number [~YES ~[~] NO I-~YES I~NO I 50-- ~ 'L,. '~ - "L. / -L,Z, ~ Approval te i 'Pr°.~714/84 , SEE COVER LETTER FOR OTHER REQUIREMENTS //,/~ ~ A I // Form 10401 Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL 2W-8 installed and tested upon completion of the job. 2W-8 will be 60' away from 2W-7 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 6100'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED NOV 0 9 Alaska Oil & Gas Cons. Commission Anchorage K__.U~..._~f:UKLF;[EL~, -HOR'rH:-~~, -ALASKA ..... : _ ~ ......... __ _.. ~ t -~P-O ..... i ~nnn ~' '1t~ ~ ~ .,V~gSO T ~, ~"10 ...... ~ ..... ' .... I "' ~ ~nnn ~, :.: .. :: ...... :; :~. :_: ......... : ...... ~__.~4~.~s.._,_~.~~-s~~"'~-~=~':''~ ,j .................. .... .. ~ ...+_ __.~_~'? .... = ~ ~ ~-~. ~~~ --4~,.-~-+~ -~--~~ ~;~~ m¢~--~~- ............ , ,, ..... , :i ,~,, ,,,~ ~ ~ ~ :~ ~ ~ ........ ,~, , , i~ :~ ~ ........ ] ........ ~ ..... ; ...; .... L ....... . ........ . ........... , Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify Ghat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 1 6" Conductor IANNUI..~ 9 ' PIPE 8 f BLIND ' ~ ) s I i-m z DIAGRAM fl 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FiLL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREJ~M OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITIq CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND '~'ALV]~S UPS~L1VI OF C~-IC)I<ES. DON-*T TEST AGAINST CLOSED CHO~S. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR i0 8. ~]~[I~'PRESSUI~ DOWNST. REAM OF CHO~ ISOLATION '~AL'VES, TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSi UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PI PE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE t~ANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET iN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSi. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WiTH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLE'FE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. REC ' V D Alaska OJi& Gas Cons. Commission Lease & Well No. /,i. /i, f,7 "!, 'L,J--~? CHECK LIST FOR 'NEW WELL PERMITS Company / 7 ;'"~-.-9 ITEM APPROVE DATE YES NO REMARKS (1) Fee ~ / ..... . .~-"~. ! ,. (2) Loc ; .......... / ....,, .' (2 thru 8) (3) Admin ~')'~. ) ' '~ i:t"'~ 9. (9' thru 12) 10. /!-/~ -~ 11. '('16 and 12) 12. (13 thru 21) 13. 14. 15. 16. 17. 18. 19. 20. 21. 1. Is the permit fee attached .......................................... 2 Is well to be located in a defined pool 3. Is well located proper distance from property line .................. 4. I$ well located proper distance ~rom other wells .. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7 Is operator the only affected party · eeeleeleeeee®eeeeeeeeeeeeeeeeee~· 8. Can permit be approved before ten-day wait ................... · Does operator have a bond in force eeeee.eeeeeeeeeeeeeee·~eeeeeee·ee· ~_.,,~..__ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ (5) BOPE j~7~7~,4" ~ '~' (22 thru 26) 22. 23. 24. 25. 26. 27. Is a diverter system required ................................... Are necessary diagrams of diverter and ~'equipment attached .. Does BOPE have sufficient pressure rating - Test to .~"~-'79 psig .. Does the choke manifold comply w/A?I R?-53 (¥eb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ,,~.f::,: ~- o ,..9 Geo logy: _~gngineer lng: H= _<_ JAL :9[ MTn/ ...... ' ~ev: 10J29/8~ 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS TAPE V~.R~'FICATION LISTING LVP f~lO.~O? VEDIFICA~'iON LTS'rJNG PAGE ** FT&E HEADER ~* FIDE ~A~F :EDTT .0Ol VEPS!O~ # DA~E ; MAXI~ ~,ENGTH : 1024 ** I.NFORNATION RECORDS ~N~M OONT~NT~ UNIT TYPE CATE SIZE CODE ~ANG~ m.ARUK 000 000 008 065 o ' 000 000 002 065 TOWN~ ~,2~ 000 000 004 065 SECT~ 33 O00 000 002 065 C[)~ ~ ~.SI, OP~ 000 000 012 065 8T~T~ ALASKA 000 00.0 OOb 065 CTPY: I~S~ 000 000 003 065 , $CttT, U~B~RGER LVD nle.!!O~ VEP,[F'iCAT'In~ L1SmING * ALASKA CO~PUTING CFNTEP ************************************************************************************* CO,PAulY = ATLANTIC ~WICHFIML~ WELb = F, IFbr~ : KI~P~RIIK COUNTY : NORT~ S~,OPE ~OR~UGH JOB ~!.~?.MR AT ACC: 69"18~ RUM ~tj.~*C, DATE bO(;G~]D: 2a-NOV-~q4 VISCOUS] TY PH FL!~In I,OSS 9,625" 0 36.00' - PIT SIZE = 8,5" TO 7830' POLY~FR lO,O LB/6 RM : 3,670 @ 61,0 DF 36.0 S RMP = 4.300 ~ 61,0 DF ~.5 ~MC : 3,120 ~ 61.0 DF 7.4 C3 RM AT BHT = 1.641 ~ 145.0 DF LVP Oln.~':O? VE~IFICATI,n?~ LTSTING PAGE 3 * $CHLI~mEPGE{q LOGS I{'~CL,{iOFL~, mlT{4 THIS MAGNETIC TAPE: * 9UAL INDUC~I{3~i SPHF,~!CAb[~ FOCI!~SED LOG (DIL) * ~(]~g~TlOl' DE~$][TY CG~PF. NSATED l,Og (FDN) , , , * , * , , , , , , , * , , , , , , , , , , , , , , * DATUM oPE~IFICATION BLOCKS O' R v T MN~'~ Slain!Vi ,E, SM .1CE UNT APl API APl API ~I[,E SIZE 1{') O~DER # LOG TYPF CLASS MOD NO. DEPT VT O0 nO0 O0 0 0 4 SFI,,U D1L r~H~ O0 220 o~ 0 0 4 YbP nil OH~ O0 1. 20 4b 0 '0 4 IL~ PI[, OH~M O0 120 44 0 0 4 SP Pti, oV rio 010 O1 0 0 4 GR PIt, Gk, PI O0 310 Ol 0 O 4 ~A,I,I m~"~ ~ TN O0 280 Ol 0 0 4 RNOS FD~ ~/C3 00 350 02 0 0 4 DEMO FD~,T GlO3 O0 356 Ol 0 0 4' MR~T r'r) ~ OD 420 Ol 0 0 a RN~A F{:, ~' O0 o00 O0 0 0 4 N~{I FON PU O0 ~90 O0 0 0 4 F~NL ~0~ CPS 00 330 30 0 o 4 PROCESS CODE 1 68 00000000000000 I 68 O0000000OO0000 1 68 00000000000000 1 68 O0000000OO0000 ~ 68 00000000000000 I 68 00000000000000 I 6S 000000000O0000 1 6~ 00~00'000000'0000 I 68 00000000000000 ~ 68 00000000000000 1 68 00000000000000 I 68 00000000000000 i 68 00000000000000 1 68 00000000000000 I 68 00000,000000000 LVP 03 r,.N02 v'E'~IFIrAI'Inr,~ LTSTING DEPl '7~57.00n0 SF'LU 3.4023 TLD ~P -11 gO31. GR 46.46R8 mR NPNI 47.~656 NCL}~ BO3.0gOo PCNL '1~'3~n3 GR 100.0625 ~R 1~o67 DRuG 0.1460 NRAT 46.4844 ~CNlo ~011.0000 FCN~ DEPT 'l~O0.OO00 SFI,U 7.2344 Sp -19 ~2~1 GR 8R 0000 OR RH~F 2~3~ql DRHO n:0532 ~:RAT Np~! 33.3008 %iC~L 242).0000 DEPT 7~0o.000o SFT.~ 16.7344 ILD SP 22.3750 ~R 7~.5000 CR RHoB 2 3262 DRNO 0.05~1 NRAT NPUI 30:7129 NCNb 2~80.0000 FCNL OB ~ 7~00.0000 SFLU 6.4727 ISn 'P -23.42~~ GR 9,..0625 ~R RHOB 2. OR~O O. I 099 NRAT ~PHI 33.~379 ~CNh 2236.0000 FCNL OEPT 7400,0000 SFI,U 9 0547 ThO SP -3~,9062 CR 8119500 ~R RH@B ~,45~i DRHO 0 0435 NRA~' ~PN,I 3~.5195 NCN~ 2522:0000 FCNL )EPT 7100 0000 SPLU 1.9902 5P 14:5938 ~R' 1,15.~125 GR qPHI 43~965 NC~5 1730.n298 0 NRAT 000 mCNL )EPT 700n.O000 ,,~I,U 2.4648 ILO ,~P -18.2344 C~R 121.6875 ~R ~PfnB , 2 3496 ORHO 0,0117 ,. ~ ~P~I ~5:6055 "'~u"~,b 1.785.0000 N~c~LRAT )EPT 6qO0.O000 ,-~[.,U,~' 2. 6465 TLr) 2.63~8 46.4688 CALl ~.7227 ~NPA 19¢.3750 2.7734 100.~625 CALl ],6797 457,~5~0 6.9492 IG~ 88.0000 CABI 2.9609 RNRA 701.~000 15,0391 IL~ 78 5~8g1 812.0000 5 .'2266 91 '0625 CALl 2 '9902 RNRA 689.0000 7 4727 IG~ 81 .~:5oo CALI 2 9102 ~NPA 806 5000 68.8750 CALl 918,0000 87.::B625 60.7188 CALI RNRA 125 CALl RNRA 2 ~734 lb~ t21:875 CALl 3.6328 RN~A 462.7500 2.7461 2.83ol 8.5000 4.0469 6 164 4.0000 6.7305 9,4297 3.4512 14.3359 9.7500 3.0527 5,4258 3, 41 172 3.1270 9.~219 2'~.727 88,0000 10,0078 3,34~8 1.8760 i0,2656 4,2930 2,3379 10.1094 3,S555 2.7500 SP -25.7500 CR NPHI 45.~.I¢8 NC~L DEDT 6600.0000 SFLU SP -29.7969 GR RHnb ~.~8a8 DR~O NPgI 3~.9902 NCNb OEPT 6500.0000 SFI, U Sp -27.5'781 GR RHO6 9.4609 DR~O NPMI 37,9883 ~CNb OEPT 6400.0000 SFbO SP -29.328i GR NpMI 35,791.0 NCWb DEPT ~300 0000 SFt, U 8P -32~9375 GR ~HOB ~.4b09 DRMO NpHt 36,~328 NCNb DEPT 6:00.0000 SFLU SP 2~,1094 GR RHOB ,3906 DRHO ~PHI 38,37~9 MCteL DEPT 6100,0000 $ FI.,U : 66'5 DRH'O NPHI 48 3~B ~ICNL -34.7188 141,3750 ER 0.0~32 ~RAT I~62.O000 FCNL ~.9316 rLD 0 0542 NR~T 1~37~0000 3 7676 170i1250 o O,147 1RI0.O000 FCNL 4.7~4~ TLD ]33.7500 0.01.37 2~66.00~0 FCNL 4.78~3 ILl) ]~4.8750 0.0703 1949.0000 FCNL 5 2227 98~3750 0.0635 sRAT 2578.0000 FC~L 4.]945 109,0000 2300.0000 FCNL 1.9922'~ <: "~ '''~ =":~"=' ': ' ' ~09,~250 0.~493 ~984;Ao00 2.6680 IbD 14~,1250 ~R .0'308 ~RAT 1079.0000 FC~L 4..0b75 IbD 122 3125 ~RA.' 0~0640 uR ~ 205~.n000 FCNb 141.3750 3.4727 503.2500 ~.5527 168.1250 3.6016 ~74.0000 3,~949 170.,250 3.609q 447.5000 4.3U86 ~33.7500 3.3262 610.5000 3.9687 ~14.8750 3,2148 609,0000 5.0469 9~.3750 3.0957 765'.5000 4.26~7 !09,0000 ~,1152 640,O000 2 ~ 0 ! , : 0 ' , 9 525. 0 4.2773 103.9375 '~6~7 60:5'000 4.2891 122.3~25 3.5586 549.0000 CALl RNRA CALl ~N~A CA£,I RNRA CAbI ~NRA CA6I ~NRA fA5I RNRA fAbI RNRA fASI RNRA ~:NRA C A L I CALI RNRA 10 3828 2.7188 10.3203 3.R750 3,3535 i0,7891 4,0430 4 4102 11:0391 3.5469 3.9590 10.9922 3.1.992 4 9219 10~8984 3.3672 4,2109 11,4.922 3.5938 2,6309 .76'76 4,2383 11,4063 3,4961 4,~422 078 DEPT SP NPNI Ri~D SP RHOb NPHi OEPT RHnb DEPT NPMI DEPT NPH1 DEPT 8P R'HOB NPHI niP.H02 VEPlFIC'ATtON 2.4082 97.4609 5700.0000 SFLU -23.0675 ~R 2.4,043 mRHO 40.2344 ~CWL 560~. ~000 SFLU -14 ~04~ ~R 5n. 3906 ~CNL -14.7734 ~R 2.3574 42.2852 NCNL 5 00, 0 15, , 1 43.6035 5~00.0000 SFr,U -125,5313 GR 3262 DRHO 502:0 NCNL ;3 36. i 3,~ 8 ~.7266 !bD ~27.0UOG CR 0.0464 ~RAT 1846.{~000 FCNL 3.3203 TLD 177.1250 CR 0.0596 NRAT 1777.nOnO FCML 0 0396 NRAT 1791:0000 rCNb ~39.2500 CR 0.n337 HRAT 2o41.n000 FCMD 2. 0977 TLD 229 NRAT 2! 7R.O000 PCNL 2.2617 ILD 74.O000 ~R 0.0225 ~RAT 2400.0000 FCN5 SFLU 2,[7~3 II~D 5 ~R ORHO 0.0444 NR~T ~CNb 2058,0000 FC' N,L RHOB 2,3789 DRHO 0.0391 NRAT NPHI 38. 3301 ~:CML, 2~ 6o.0000 FCNL ~P' 420 000 Fl,b ~31.6 IbD S'P 14.:4297 ~R 8].2500 ~R NPWI 38. 184 NCNb 2050,0000 FCNb D£PT 4800 0000 SFLU 2.5215 IhD SP -15]78~3 CR ~4,1875 CR RHOB 2.31.25 DR~O o,r~l~2 NR~T NP,1 39.1b02 NCNL ]085.0000 FCNb 4.2617 127.0U00 3.7J44 416.7500 2.8477 177.1250 3.3]98 529,0000 2 ~1~3 156~ 750 3.8926 447.7500 2.0391 ~39,2500 3.4512 618,5000 2.]027 86 2500 3:5234 590'0000 2.5586 74 )000 3 ~88 676 ~000 2,6641 84 5 o 6O9 60'q:,:~'O00 IbM CALl RNRA CALX RNRA IbM CAt,! RNRA CALi RNRA CA[,I RNRA CA L I PNRA IbM CALl RNRA 2 .,ALI 3 2 RNRA 62'5 .:0'~ ~0 85 2,5 3 ~34~ o925ooo 2 402 83 5O0 3.;2617 615,:0000 2 8262 84~1875 3.2793 60S.0000 CALl RNRA CALI RNRA CALI PAGE 4 6 875 4,4258 2.8555 10 2891 3:3574 2,1367 9.7500 4.0000 2.0391 9 9609 3~2988 ~,2793 10,7422 3,6914 2.~863 ]0, 688 3.5469 2,6348 10,6406 ],4844 2.7852 lO.4688 3.29J0 2,8105 ln,.4922 3,5430 2,6250 10.2266 3.3320 2,7266 3 793 LVF Ot~.HCi? VLPlFI('ATinN [,TS'T'I~;<; PAGE: 7 S~ RH~B SP D~PT ~EPT SP RHOB NpHI SP RHOb NpHI SP DEPT SP DEPT SP NPHI RHea{ NPH, i DE~T SP SP -t6.17~9 40.9668 4600.0000 -20.9531 2.3262 40.6738 4500.0000 SFLO -20.9062 ~R 2.3418 DkHO 37.7441 ~!CMC 4400.o0n0 ~FI,U -21.1094 GR 2.3164 DRanO 4~.R477 ~C~L 4]00.0000 ~[~242 D~HO 45.~496 MCteL 4900. 0000 SFT,,U -21. J 406 ~R 4~0430 MCNL 4IO0.OO00 SFT,U ,,tO 375 C,,R 50 3n I HCNL 4000,0000 SFLU 49'9705 O~HO .2168 UCNL 3900 . 0000 2.0820 53.5045 3~00 . OO00 10.1719 CR 3 g 6 25 ~' C ~? 3VOO.~O00 S?T~U 2.4277 0.0532 2.4141 76.0000 0.0203 2J, 4,?.0000 2.90~3 95.6875 0.0273 2!56.n000 ?.a453 9~.~125 0.n254 2062.n000 2.5703 ~{ 0.0000 0 ~3ql 2047:0000 3.4902 97.5625 0.0718 1004.0000 3.0488 97 0 10~7 00() ].826291.8125 0.0063 2200.0000 1.4746 ~ ]5.250O 0.0137 2130.0000 ].5'547 o.n7 3 1786.0000 2.5840 ~.7500 0.08~9 FCNL TLD ¢CNL ThD MR~T FCNL TLD ~C~L TGD mRAT ~'CMG CR ~RAT FCNL CR FCNL ¢CNL TLD ~R NR~T FCNL TLD GR NRAT WCNL ,,,RAT 2.60{6 86.8750 ].3789 549.5000 2 9570 v6.'Oooo 3.3613 574.0000 ].1055 95.6875 3.2031 610.5000 2 3 195 3.5371 486.5000 2.6602 80.0000 ].6445 492.7500 3.7285 97 5625 3:5469 495,0000 ].2266 97.2500 3.9570 93.81~5 3:~7207 540.0000 2.~445 135.~500 4.0666 426.0000 4,0039 115,3175 3.2734 54t.5000 3 , 1270 98.7500 3.6641, Cal,I RNRA CALl CALl R l~ R A I L~,T CALl RNRA CALI RNRA IBM CALl D NRA ~ALI RNR. A Ibm CAbI RNRA RNRA CALl RNRA CALl 2.5273 10.1875 3.7598 2.~066 10,]750 3.73O5 2.9629 9.9766 3.5313 2.6504 10.5859 4.2383 2.6348 I0.6563 4,1523 3.~434 11,4922 3.8457 3.03~3 10.3984 4,0781 3,4961 9.7344 4.0703 1,9590 5. O0 3.8223 3.28 ....2 2,8848 1~,4766 ,8691 46.t. 914 ~'~CNb 175f~.0000 FCML 454.2500 DEDT 3KO0.OO00 S~'LU 4.0977 TLD 4.1992 IL~ 3.q258 SP -18.4844 qR 97.9375 ~R 97.9375 CALl 19.0156 RHO~ ~.73~3 ~R~O 0.0264 N~T 3,4414 RNRA 3.7578 NpWl 49.13~7 ~ICNb 1807.0000 FC~[, 480.7500 DEPT 3400.0000 SFLU 4.3047 ThO 5.0000 IbM 4 5469 RHOB 2.9'115 qRHO 0.6815 ~RAT 3.9727 RNRA 4.4492 NPHI 5~..8555 ~CNL 178n.6000 FCNL 400.0000 DEP~ 3~13.0000 SF[,I~ 3~.56~5 Tbn 24.56?5 TLM 2000.0000 SP -31.00n0 ~R 58.5625 CR 58.5625 CALI 8.83~9 RHOb ~.~012 DRHO -0.4082 NRAT 3.8'750 ~NRA 4,4766 NP~I 50.0q88 qCNb 146R.0000 ~'CNL 327.7500 FILE NANE :EOTT .001 VERST()~ # DATE : ~AXI~UM ~ENGTH : 102a FI[.,E TYP~ NEXT EOF ~*~******* ** APE .... RAILER ** TCM M A:~{ E :EDIT ORTGTN :OoO0 TAPE i'~ A ~4 ~ :OTa~ CONTI~UATION ~ NEXT !,'APE ~A~E ;
