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C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-09-25_22050_KRU_2A-17_LeakPointSurvey_Transmitttal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22050 KRU 2A-17 50-029-20193-00 LeakPoint Survey 25-Sep-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM . XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~-/Z/'/~ File Nu m ber of Well H ,sto ry File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs-of various kinds [] Other COMMENTS: Scanned by: Bevedy Diann~athan Lowell TO RE-SCAN Date:/,~ Is/ '~ Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: is~ • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 29, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2A -17 3—\ L� Run Date: 6/13/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 103 - 20193 -00 Production Profile Log 1 Color Log 50 -103- 20193 -00 ,.1 SEP 0 i ZO`! PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Oct /lDate: 2 2-011 / Signed: ai~r~~~~~~i~~i NO.4914 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1 L-23 - 12097405 SBHP SURVEY ( 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - JC © O L 09/10/08 1 1 3G-25X 12080437 LDL ~ - 3 ~((0 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE L.,, C ( 09/14/08 1 1 3M-13 12096541 LDL - (~C( I ~ 09/10/08 1 1 2Z-13A 12100446 LDL Q(o- (~ O ~U 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17!08 1 1 3C-14A 12080436 SCMT - 5-~ 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE -t p ~. ~/ 09/20/08 1 1 30-15 12100452 LDL ~I(- -~ 5Q 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE o ~ 09/23!08 1 1 iR-11 11966277 SBHP SURVEY - (~ 09/25/08 1 1 1R-35 11966279 SBHP SURVEY ~ _ p 09/25/08 1 1 i R-14 11966286 LDL - ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 1 R-34 12080444 _ GLS ojL „- 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .-' L ~~C/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~"~~ ( 10/06/08 1 1 1H-19 12096548 INJECTION PROFILE L~ 10/03/08 1 1 1 B-16 12097426 GLS Cj - =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT - 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - `~ 10/07/08 1 1 1B-04 12096552 INJECTION PROFILE - 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 16-16 12096554 PRODUCTION PROFILE q C' ..~ G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ('~C . 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~} ~'. '~ • • - c Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 ,K., . Mr. Tom Maunder ~{'= ~- ~ ' ~ ~ -- Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 ~- ` .. Anchorage, AK-99501 ~ - . ~~ rj ~ ~ 2~~if ~ r Dear Mr. Maunder: ~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The- cement was pumped September 24 & December 12 2007 and the corrosion inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • ~~~ ~~~~~~s Asa ~~a Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant i'op-off Report of Sundry Operations (10-404j Kuparuk Field Date 12/15/2007 VI/elf Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitorf sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12!14!2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.2 10" 9/24!2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 12/5/2007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14!2007 2A-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.75 12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 1212007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9124!2007 3 12/5/2007 2A-22 195-068. 39"' na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 10/13/06 Sc~luIIbepgel' OCT 1 6 2006 I\~(~I & (~(~m~" c(Wt9~~Wt c'..·. < .. ') f'!ì 5 tJ) 1 (...\...0 . ,,,,!r, ';rì ""('f.,¡',,,.,. ¡(=~., vV<i~\I~ -.,;:: ~~' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth fÎ93 -116 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well log Description Date Bl CD Color Job# 1J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T -39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1L-06 11415625 SBHP SURVEY 09f24f06 1 1F-07 11415629 LDL 09/27f06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434151 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06f06 1 2V-08A 11216321 USIT 09/21/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . f? f¥oo MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~'~'~' DATE: Commissioner THRU: TOm Maunder, ~ P. I. Supervisor January 4, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit _2A Pad .Thursday, January 4, 2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2A Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2A-12 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in gOod condition. Summary: I witnessed the semi annual SVS testing at 2A Pad in the Kuparuk River Field. KRU 2A Pad, 12 wells, 24 components, 1. failure 4.1% failure rate 21 wellhouse inspections Attachment: SVS KRU 2A Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS .doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 2A Pad Separator psi: LPS 96 HPS 1/4/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed CAS or CYCLE 2P~-01A 1840570 .. 2A-02 1840500i 2A-03 1840510 I 2A-04 1840530 i2A-05 1840670 2A-06 1840640~ 2A-07 1840650 2A-08 1852480 2A-09 1860010 96 - 70 50 P 15 OIL 2A-10 1860020! 96 70 55 P P OIL 2A-11 1860030 96 70 50 P P OIL 2~-12 1860040 96 70 70 P - 4 OIL 2A-13 1851440 96] 70 50 P P OIL ,. 2A-14 1851450 96 70 70 P P OIL 2A-15' 1851460! 96 70 70 P P OIL 2A-16 1851470! 96] 70 70 P P OIL 2A-17 1931400~ 961 70 50 P P OIL 2A-18 1950590 96 70 60 P P OIL ., 2A-19 19315201 ., 2A-20 . 1931510 2A-21 1931330 2A-22 1950680 96 70 '70 P P OIL 2A-24 1931440 96' 70 · 60P P OIL 2A-25 1960620 ~ , : Wells: 12 Components: 24 Failures: 1 Failure Rate:' 4.1% [390 oar Remarks: Surface Safe,ty on 2A-12 had slow leak, valve to be serviced and retested 1/0/01 Page 1 of 1 SVS KRU 2A Pad 1-4-01 CS.xls ON OR BEFORE C:LO~ILM-DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing Alter casing Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 133' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1347' FSL, 53' FEL, Sec 14, T11N, R8E, UM 2A-17 At fop of productive interval: 9. Permit number/approval number: 1318' FNL, 1269' FEL, Sec 15, T11N, R8E, UM 93-140 At effective depth: 10. APl number: 1235' FNL, 1505' FEL, Sec 15, T11N, R8E, UM 50-029-20193-00 At total depth: 11. Field/Pool: 1204' FNL, 1516' FEL, Sec 15, TllN, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 9934 feet Plugs (measured) None true vertical 6194 feet Effective Deptt measured 9827 feet Junk (measured) Possible washer on top of GLM @ 7338' true vertical 6111 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 200 Sx PFC 121' 121' Surface 4119' 9-5/8" 625 Sx AS III & 4161' 2913' 525 Sx Class G w/125 Sx AS I top job Production 9876' 7" 200 Sx Class G 9915' 6179' Liner Perforation Depth measured 9582'-9618', 9502'-9539' true vertical 5920'-5948', 5859'-5887' Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, J-55 @ 9417' Packers and SSSV (type and measured depth) Packer: Camco HRP-4-SP @ 9386'; SSSV: Camco TRDP-4A @ 1794' 13. Stimulation or cement squeeze summary Perforate "B & C" sands on 4/28/98. Intervals treated (measured) 9502'-9539' Treatment description including volumes used and final pressure Perforated using 2.5" HC guns w/DP charges at 6 spt, 60 deg phasing, no orientation, fp was 8800 psi. 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1281 1635 324 667 300 Subsequent to operation 2111 4406 1046 847 269 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed..~~~/~ _ Title: Production Engineering Supervisor Date Form 10-404 Ret /88 SUBMIT IN DUPLICATE~ ARCO Alaska, Inc. ..KUPARUK RIVER UNIT .ELL SERVICE REPORT ,~' K1(2A-17(W4-6)) WELL JOB SCOPE JOB NUMBER 2A-17 PERFORATE, PERF SUPPORT 0423981652.2 DATE DAILY WORK UNIT NUMBER 04/28/98 PERFORATE - ADD C SANDS 2128 DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes (") NoI (~ Yes (~ No . SWS-JOHNSON JONES FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTI MATE KAWWR K 230 DS28AL $18,119 $20,975 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann ] Initial Outer Ann I Final Outer Ann 500 PSI 1600 PSI 750 PSI 1140 PSII 0 PSII 0 PSI DALLY SUMMARY SWS (JOHNSON & CREW) PERFORATED C SANDS FROM 9502' TO 9539' W/2.5" DP, 6 SPF, 60 DEG PHASE, NO ORIENT. FILL @ 9578' UNABLE TO CORR W/CCL. RUN GUN GR, OK. 2ND RUN GUN GR FAILED, RAN CCL. JOB COMPLETE. TIME LOG ENTRY 09:00 JOHNSON & CREW MIRU, HELD TGSM, PERFORATING SAFETY. 10:30 MU 20' 2.5" HC, DP, 6 SPF @ 60 DEG PHASE, NO ORIENT, CCL & 6' WT BAR. TEST LUBRICATOR TO 3000#. 11:30 RIH TO 9578', TAG FILL W/GUN, UNABLE TO TIE INTO SHORT 7" CSG JOINTS. 12:00 POH. CHANGE TOOL STRING TO GUN/GR. 13:30 RIH W! 20' GUN AS ABOVE W/GUN/OR/COL. 14:20 CORR. GUN TO GR/CET LOG 10-15-93 & PERF FROM 9519' TO 9539'. POH. 15:00 LAID DOWN GUN, ALL SHOTS FIRED. MU 20' GUN AS ABOVE W/3' BLANK ON TOP (17' LOADED) & RIH. 16:45 CORR. GUN TO ABOVE LOG & ATTEMPT TO PERF FROM 9502' TO 9519'. NO INDICATIONS OF A SHOT. POH. '." . 18:00 LAID DOWN GUN, DID NOT FIRE. SUSPECT GUN/GR. MU SAME GUN AS ABOVE W/COL ONLY & RIH. 19:45 CORR GUN TO:ABOVE LOG & PERF FROM 9502' TO 9519'. POH. 21:00 LAID DOWN GUN, ALL SHOTS FIRED. RIG DOWN & RELEASE SWS. DSO WILL RETURN TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $84.00 APC $950.00 $950.00 HALLIBURTON $0.00 $800.00 LITTLE RED $880.00 $1,772.00 SCHLUMBERGER $17,369.50 $17,369.50 TOTAL FIELD ESTIMATE $19,199.50 $20,975.50 " .... ' STATE OF ALASKA , AI_A~,,,A OIL AND GAS CONSERVATION COMMISb~JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1347' FSL, 53' FEL, Sec. 14, T11N, At top of productive interval 1318' FNL, 1269' FEL, Sec. 15, T11N, At effective depth 1235' FNL, 1505' FEL, Sec. 15, T11N, At total depth 1204' FNL, 1516' FEL, Sec. 15, T11N, 12. Present well condition summary Total Depth: measured 9 9 true vertical 61 Effective depth: measured 9 8 true vertical 61 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service R8E, UM 6. Datum elevation (DF or KB) RKB 133 7. Unit or Property name Kuparuk River Unit 8. Well number · 2A-17 9. Permit number/approval number feet R8E, UM R8E, UM R8E, UM 93-140 10. APl number $0-103-20193-00 11. Field/Pool Kuparuk River Field/Oil Pool 34 94 27 11 feet feet feet feet Plugs (measured) None Junk (measured) Norle Casing Structural Conductor Surface Intermediate Production Liner Perforation depth; Length 80' 4119' Size 16" 9-5/8" 9876' 7" measured 9582'-9417' true vertical 5920'-5948' Cemented Measured depth True vertical depth 200 Sx PFC 121 ' 625 Sx AS III & 41 61 ' 525 Sx Class G w/125 Sx AS I top job 200 Sx Class G 9 91 5' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 9415' Packers and SSSV (type and measured depth) Pkr: Camco HRP4SP @ 9386'; SSSV: Camco TRDP-4A @ 1794' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 9/2/97. Intervals treated (measured) 9582'-9618' Treatment description including volumes used and final pressure . Pumped 3.17.7' M lbs 20/40 and 12/18 ceramic proppant into formation, fp was 6200 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 121' 2913' 6179' Tubing Pressure Prior to well operation 1 1 3 6 1086 376 688 284 Subsequent to operation 1 9 04 2493 1108 695 3O5 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Rep~ort of Well Operations X Oil X Gas Suspended 17. I hereb~-c-~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~'~'~,~~~,~ Title Wells Superintendent Service .~;O Alaska, Inc. --~-'" KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(2A-17(W4-6)) WELL JOB SCE~PE JOB NUMBER 2A-17 FRAC, FRAC SUPPORT 0820970738.1 DATE DAILY WORK UNIT NUMBER 09/02/97 "A" SAND REFRAC DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 6 (~ Yes (-.) NoI (~ Yes O No DS-GALLEGOS CHANEY FIELD AFC¢ CC# DALLY COST ACCUM COST Signed -' ESTIMATE KD1456 230DS28AL $183,067 $263,057 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann J Initial Outer Ann J Final Outer Ann 1800 PSI 1800 PSI 200 PSI 500 PSIJ 50 PSIJ ,--"" 50 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETE. INJECTED 317723 LBS OF PROP IN THE FORMATION W/14.7# PPA OF #12/18 @ THE PERF'S. SCREENED OUT DURING FLUSH. UNABLE TO FREEZE PROTECT TBG. MAXIMUM PRESSURE 6200 PSI AND F.G. (.70). TIME LOG ENTRY 07:00 09:00 10:00 10:25 11'15 13:10 15:30 16:30 17:30 MIRU DOWELL FRAC EQUIP, APC TANKER, APC VAC TRUCK, AND LRS HOT OIL TRUCK. HELD SAFETY MEETING (17 ON LOCATION) PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9500 PSI. HAD A LEAK ON ONE OF THE HIGH PRESSURE PUMPS, DEPRESSURED THE SYSTEM AND REPAIRED LEAKING VALVE. RE-PRESSURE TEST HIGH PRESSURE LINES TO 10600 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW & HSFLA @ 29 BPM TO 15 BPM. VOLUME PUMPED 320 BBLS. USED 2053 LBS OF #20/40 PROP FOR CONDITIONING. MAXIMUM PRESSURE 5700 PSI AND ENDING PRESSURE 2800 PSI. S/D AND OBTAINED ISlP OF 1513 PSI W/F.G. @ (.70). STOOD-BY AND MONTORED WHTP. PULSED FOR CLOSURE. DETERMINED CLOSURE +-21 MINS @ 1166 PSI. PUMP DATAFRAC W/50# DELAYED XL GW & HSFLA @ 5 BPM TO 15 BPM. VOLUME PUMPED 200 BBLS. MAXIMUM PRESSURE 4900 PSI & ENDING PRESSURE 3000 PSI. S/D AND OBTAINED ISlP OF 1665 PSI W/F.G. @ (.72). STOOD-BY AND MONITORED WHTP FOR CLOSURE. DETERMINED CLOSURE TIME OF +-31 MINS @ 1291 PSI. PUMP FRAC W/50¢ DELAYED XL GW & HSFLA @ 5 BPM TO 15 BPM. SCREENED OUT 5 BBLS INTO THE FLUSH. VOLUME PUMPED 1652 BBLS. PUMPED 342940 LBS OF PROP (18623 LBS OF #20/40, 301513 LBS OF #12/18, & 23164 LBS OF PROP). INJECTED 317723 LBS OF PROP IN THE FORMATION W/14.7# PPA OF #12/18 @ THE PERF'S. LEFT 30670 LBS OF PROP IN THE WELLBORE. UNABLE TO FREEZE PROTECT TBG. STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRUCK. REMOVED TREESAVER (30% OF CUPS LOST). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIE DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL -- $0.00 $882.00 _APO $6,700.00 $18,900.00 _DIESEL $300.00 $1,100.00 _DOWELL $173,758.00 $225,777.00 .__HALLI BURTON $0.00 $7,688.00 .__Li FFLE RED $2,310.00 $8,710.00 ~TOTAL FIELD ESTIMATE $183,068.00 $263,057.00 PERMIT DATA 93-140 5957 93-140 407 93-140 DAILY WELL OP AOGCC Individual Well Geological Materials Inventory Page' 1 Date' 09/29/95 T DATA_PLUS ~T~020-9934, OH-CDR/CDN RUN DATE_RECVD 1 01/!8/1994 93-140 SURVEY ~/COMP DATE:10/22/93 R 09/24/93-10/22/93 ,.~DIRECTIO~IA~ DIRECTIONAL 12/03/1993 12/03/1993 11,/09,/1992 12/03/1993 93-140 CBT ~00-9792 01/01/1993 T~ ' ~4090-9900 I 01/18/1994 93-140 CDN-.3D/DC 9~-i40 CDR-E/LWD/DC 200-9910 i 01/18/1994 93-140 CDR-LWD/DC ~4100-9920 1 01/18/1994 93-140 CET "~8300-9820 01/01/1993 93-140 USIT(C&C) ~//100-3000 1 10/12/1993 Are dry ditch samples required? ~es q~And receiz~i?~ ye~ngL_~__:~ Was the well cored? yes ~__~r~alysis & description receiv~.--~~n_~o Are well tests requirad?/lyes ~~P~e~eive ?~_~~ no ~ Well is in compliance In~%ial COMMENTS ARCO Alaska, Inc. Date: January 14, 1994 Transmittal #: 8981 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following O.l~¢ole items. Please acknowledge receipt and return one signed copy of t'his transmittal. 1Y-31 Dual Compensated Neutron /(CNTG) CDN LWD/Depth Corrected ¢"CDRLWD/Depth Corrected ',./CDR Enhancement . LWD/Depth Corrected ¢CDN LWD/Depth Corrected -./CDRLWD/Depth Corrected vCDR Enhancement LWD/Depth Corrected ','CDN LWD/Depth Corrected ,cE;DR LWD/Depth Corrected -¢CDR Enhancement LWD/Depth Corrected ,/'CDN LWD/Depth Corrected C... ~t:k ~ LWD/Depth Corrected ~Z;DR Enhancement LWD/Depth Corrected ,-"CDR LWD/Depth Corrected ,-dSDN LWD/Depth Corrected ,/' CDR Very-Enhanced Resistivity LWD/Depth Corrected Acknowledged: ?'-'-~.' -~ '~-' ..' ~ /2A-21 ~:~1'~" '~} (,, 2A-21 '",2A-21 ,/2A-17 ,~.5_. Ikk:) '~2A-17 '~2.A-17 ,/2A-23 ' \2A-23 72A-24 ~¢-,/- i~q ~ 2A-24 2A-24 ¢.' 2A-20 ?.,... !~\ ~ 2A-20 ~-" 2A-20 DISTRIBUTION' 09-08-93 ';:..\ 6450-7689 09-17-21-93 09-17-21-93 09-17-21-93 ¢~14650.11800 6,\4700-11800 ~t 11100-11800 09-26-28-93 09-26-28-93 09-26-28-93 ~\4090-9900 ,, 4100-9920 9200-9910 10-04-08-93 10-04-08-93 10-04-08-93 10-12-15-93 10-12-15-93 10-12-15-93 4300-11650 4300-11660 ..i. 11000-11660 ~_~' 3400-9800 ¢,- ~,-¢¢-~ a 3400-9800 ¢,' ~-'~ 3400-9630 ¢',0cm'9° 5'" 10-19-23-93 10-19-23-93 10-19-23-93 Date' 4100-11530 4100-11530 10400-11 51 ARCO Alaska, Inc. Date' January 14, 1994 Transmittal #: 8980 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. ~'~ ,~:...~-:~z'~ 1Y-27 ..::., .... , Ll_LS~T_ape__.and Listing: ;.:.;.::C;'~'~'"10-28-93 93426 *;' ?>;- Cas_e~d_H_ole-TEhT-P~ passes and average ¢'iZ~.~¢ '"'*' - 1Y-18 ?:~:~_ LIS Tape and Listing' 10-28-93 93423 Please acknowledge receipt 1Y-23 5o~ ;S~ LIS Tape and Listing: 10-28-93 93425 C~--CNTG Main and repeat passes, t~tcok-9-5~% P,\ c1~¢I0 1Y-31 ~3o~5~ LIS Tape and Listing' 10-04-93 93429 ~~CNTG e/~-i~'~ 2A-21 5~5~o LIS Tape and Listing' ~.I*-CDR/CDN, 2 Bit Runs 2A-17 ¢¢~5~ LIS Tape and Listing' -CDR/CDN, 2 Bit Runs cl.~lq~ 2A-23 ~'~ LIS Tape and Listing' O~--CDR/CDN, 2 Bit Runs 12-07-93 with QRO Processing 12-07-93 with QRO Processing 12-07-93 with QRO Processing ~.lq~ 2A-24 5~ 5~ LIS Tape and Listing: 12-19-93 o~-CDR/CDN, 1 Bit Runs with QRO Processing 2A-20 5q6;0 LIS Tape and Listing: 12-20-93 ¢J~ic~ I ~-. CDR/CDN, 2 Bit, ns with QRO Proces.sing Receipt Acknowledged' _/-/ //L~_./_..~,.:5 _~.~¢~ ~/~ DISTRIBUTION' Bob Ocanas 93452 H~¢-¢-~ t~ 93474 93470 93480 93497 Date' State of Alaska STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS:51ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well C~assification of Service Well · · .,- , , OIL ~] GAS E~ SUSPENDED E~ ABANDONED [] SERVICE E~] 2 Nameof Operator 7 Permit Number ARCO Alaska, Inc 93-140 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20193 4 Location of well at sudace 9 Unit or Lease Name 1347' FSL, 53' FEL, SEC 14, T 11N, R8E, UM ~ ~';~;~ ::~ ~:¢~?~_ -~ . , '~OCA~-[ KUPARUK RIVER AtTop Producing Inte~al ~.~~.~'~ '~ ~',,~( ~ '~.,~-- -V~[~~ i[ 10 Wel12A_17Number 1318' FNL, 1269' FEL, SEC 15, T 11N, R 8E, UM ~ ?t:~?;¢¢ ~ ~ ~_. ....... 11' At Total Dep~ ~.._~_.-. ~. ~ ~ Field and Pool 1204' FNL, 1516' FEL, SEC 15, T 11N, R 8E, UM'' '-* *" ............ ; KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease Designation and Serial No. RKB 133', PAD 92' GL~ ADL 25571 ALK 2669 ~ 2 Date Spudded 13 Date T;D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore ~16 No. of Completions 23-Sep-93 29-Sep-93 ~Comp) ~~ NA feet MSLI 1 Directional Su~ey ' ' J20 Dep~ where SSSV set 17 Total Dep~ (MD+TVD) 18 Plug Back Depth (MD+~D) 19 21 Thickness of permafrost 9934' MD, 6194' TVD 9827' MD, 61i 1' ~D YES--~ NO ~ 1794' feet MD~ 1600' APPROX ~ Type Electric or O~er Logs Run CDR, CDN,C~,CBT, GR,CCL, GCT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE C~~ 16" 62.5~ H-40 SURF 121' 24" 200 SX PFC CMT 9.625" 47¢/36¢ L-80/J-55 SURF 4161' 12.25" 625 SX ASlII , 525 SX C~SS G CMT 125 SX ASl TOP JOB 7" 26~ L-80 SURF 9915' 8.5" 200 SX CLASS G CMT 24 Pedorations open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SlZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.3~ J-55 9417' 9386' 4.5" CSG GUN ~ 4 SPF 9582'-9618' MD 5920'-5948' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production ~Me~ of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR ~TE ~ 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA REEEIVED DEC - ~ Nas~ Oit & Gas Oons. Commission ~chorago Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, alt fluids recovered and gravity, ME_AS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 9499' 5856' NA BASE OF KUPARUK C 9538' 5894' TOP OF KUPARUK A 9546' 5892' BASE OF KUPARUK A 9700' 6011 ' 31. LIST OF A'FTACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY(GCT) 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2A-17 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25571 ALK 2669 50-103-20193 93-140 ACCEPT: 09/23/93 06:00 SPUD: 09/23/93 10:00 RELEASE: 10/21/93 03:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 09/24/93 (1) PARKER 245 TD: 3485'( o) 09/25/93 (2) PARKER 245 TD: 4175'( 690) o) 09/26/93 (3) PARKER 245 TD: 4175'( 09/27/93 (4) PARKER 245 TD: 7575'(3400) 09/28/93 (5) PARKER 245 TD: ~9450' (1875) 09/29/93 (6) PARKER 245 TD: 9678' ( 228) DRILLING 16"@ 121' MW:10.0 VIS: 54 NU 20" DIVERTER SYSTEM. FUNCTION TEST DIVERTER-WITNESSED BY JERRY HERRING W/AOGCC. MU BHA, ORIENT & TEST MWD. SPUD & DRILL 8.5" HOLE F/121'-2322'. CBU. SHORT TRIP TO HWDP. HAD TO WASH & REAM F/1750'-1470'. DRILL F/2322'-3485'. RUNNING CSG 16"@ 121' MW:10.3 VIS: 55 DRILL 8.5" HOLE F/3485'-4175'. CBU. SHORT TRIP-TIGHT F/1700'-1375'. FIN POOH, LD MWD & MOTOR. PU HOLE OPENER & STABS. TIH. WASH & REAM F/1400'-1800'. CBU. INCREASE MUD TO 10.2 PPG. POOH. TIGHT. BACK REAMED F/2053'-1395'. TIH TO 2200'. POOH. PMP OUT OF HOLE F/2200'-1300' LD STABS & HOLE OPENER. RU CSG EQUIP & HOLD SAFETY ME~TING. RUN 9-5/8" CSG. CUT DRILL LINE 9-5/8"@ 4160' MW: 8.9 VIS: 30 FIN RUNNING 9-5/8" CSG. SHOE @ 4161'. CIRC & COND MUD @ 8 BPM @ 500 PSI. DOWELL CMT'D W/625 SX AS III LEAD CMT AND 525 SX CLASS G CMT. RD CMT HEAD, NU BOPE. TEST ALL EQUIPMENT TO 300/3000 PSI. RD TEST EQUIP. SLIP & CUT DRILL LINE. DRILLING 9-5/8"@ 4160' MW: 9.1 VIS: 33 FIN DRILL LINE. MU BHA #3, ORIENT & TEST MWD. TIH. TEST CSG TO 2000 PSI. DRILL FC, CMT, FS & 10 FT NEW FORM. CBU. RUN FIT. DRILL 8.5" HOLE W/4185.'-7575'. DRILLING 9-5/8"@ 4160' MW:ll.2 VIS: 39 DRILL F/7575'-9208'. CIRC & WT UP TO 11.2 PPG. ADDED 10.0 PPB LCM. DRILL F/9208'-9302'. SHORT TRIP 20 STDS. NO FILL. DRILL F/9302'-9450' DRILLING 9-5/8"@ 4160' MW:ll.2 VIS: 44 DRILL 8.5" HOLE F/9450'-9528'. CBU. SLUG DP. POH W/BIT #3. LD LWD TOOLS, MWD, & TURBINE. BIT WAS WORE OUT. RU SCHLUMBERGER WL TRUCK. RAN USI LOG IN 9-5/8" 47# L-80 CSG F/3000'-100'. NO METAL LOSS IN CSG. RD SCHLUMBERGER. PU ROTARY BHA, LWD TOOLS, LOAD RA SOURCE, & TIH. RE-LOG HOLE F/9400' TO BTM. DRILL 8.5" HOLE F/9528'-9678'. RECEIVED DEC -;5 1995 Oil & Gas Cons. Commission Anchorage WELL: 2A-17 API: 50-103-20193 PERMIT: 93-140 PAGE: 2 09/30/93 (7) PARKER 245 TD: 9934' ( 256) 10/01/93 (8) PARKER 245 TD: 9934'( o) 10/17/93 (11) DOWELL TD: 9934 RU CASERS 9-5/8"@ 4160' MW:ll.2 VIS: 43 DRILL 8.5" HOLE F/9678'-9934' TD. CIRC & COND @ 9934' . MADE 20 STD SHORT TRIP. HOLE TIGHT & SWABBING. CBU. NO TRIP GAS. POOH W/TUBOSCOPE CHECKING HARD BAND. LD 72 JTS. RETRIEVED SURV. REMOVED RA SOURCE. LD LWD TOOLS. PULLED WEAR BUSHING. RU CASERS. RIG RELEASED 9-5/8"@ 4160' MW:ll.2 VIS: 44 RU CASERS. HOLD SAFETY MEETING. RUN 232 JTS 26# L-80 CSG. CIRC. MAKE UP CMT HEAD. CIRC & COND MUD. SHAKE OUT LCM. CIRC @ 6 BPM-700 PSI. TEST LINES TO 4000 PSI. CMT'D 7" W/200 SX CLASS G CMT. RECIP PIPE W/FULL RETURNS THROUGHOUT JOB. SHOE @ 9915' & FC @ 9826' PLUG DOWN & JC @ 21:45 HRS 09/30/30. TEST 7" CSG TO 3~00 PSI-HELD. PU STACK, LANDED 7" W/150,000# ON SLIPS, CUT OFF, & LD CSG TOOLS. ND BOP'S. MADE FINAL CUT, NU TBG HEAD & TREE-TEST SAME TO 3000 PSI. FREEZE PROTECT 9-5/8" X 7" ANN W/125 BBLS WATER & 80 BBLS DIESEL. BROKE @ 900 PSI-FINAL PRESS 700 PSI. 37.3' RT TO TBG SPOOL. RELEASED RIG @ 0430 HRS 10/01/93. MOVE RIG F/2A-17 TO 2A-23. 9-5/8"@ 4160' DO ARCTIC PACK 10/21/93 (9) NORDIC 1 TD: 9934 PB: 9826 RUN COMP ASSY 9-5/8"@ 4160' MW: 0.0 ACCEPT RIG @ 0830 HRS 10/20/93. CHECK WELL F/PRESS. 7" SICP=0 PSI, 9-5/8" ANN 0 PSI. ND DRY HOLE TREE. SET TEST PLUG. NU BOP. TEST BOPE. RU SCHLUMBERGER. TEST LUB TO 1000 PSI. PERF/9598'-9618' & 9582'-9598' @ 4 SPF. RD SCHLUMBERGER. FLUID LOSS TO FORM 0 BBLS. NU FLOW LINE. CONT TO LOAD TBG. RU & RUN 3-1/2" COMP ASSY W/SHEAR OUT SUB, CAMCO 2.75" D NIPPLE, HRP-4SP PKR, PBR & GLM'S. RECEIVED DEC -. Alaska Oit & Gas Cons. Commission Anchorage WELL: 2A-17 API: 50-103-20193 PERMIT: 93-140 PAGE: 3 10/22/93 (10) NORDIC 1 TD: 9934 PB: 9826 FINAL REPORT 9-5/8"@ 4160' MW: 0.0 CONT RIH W/3-1/2" COMP ASSY. MU CAMCO TRDP-4A SSSV & 1/4" CONTROL LINE . MU TBG HGR & ATTACHED CONTROL LINE. LANDED HGR & RILDS. DROPPED BALL & ALLOWED TO FALL TO SHEAR OUT SUB. PRESS TBG TO 2500 PSI TO SET PKR. HELD 2500 PSI ON TBG & MONITORED-OK. BLED PRESS OFF TBG. PRESS ANN & TBG TO 1000 PSI VIA ANN. CLOSED SSSV & BLED OFF TBG PRESS TO 500 PSI & MONITORED SSSV. SSSV HOLDING. EQUALIZED TBG & ANN. OPENED SSSV. BLED OFF TBG & ANN. BOLDS. PU & SHEARED PBR @ 43K# OVER PU WT. RELANDED TBG & RILDS. TESTED ANN & TBG TO 2500 PSI. PRESS TBG TO 3600 PSI & SHEARED OUT BALL. BLED OFF PRESS & CLOSED SSSV. BO LANDING JT. SET BPV. ND BOP. NU TREE. TEST SAME TO 250/5000 PSI. OPENED SSSV. FREEZE PROTECT ANN & TBG W/DIESEL. SI FOR PRESS TO BLEED OFF. SET BPV. MOVE RIG TO 2A-23. RIG RELEASED 1530 HRS 10/21/93. SIGNATURE: dri~~ntenden~ DATE: RECEIVED DEC 199] Alaska Oil & Gas Cons. Commission Anchorage SUB. SURFACE DIRECTIONAL ~URVEY [~]UIDANCE ~]ONTINUOUS ~_JOOL Company Well Name ARCO ALASKA, INC. ZA-17 (134,7'FSL,, 53'FEL, .SEC.14,. T11N,, R8E, [Itl)' Field/Location KUPARUK, NORTH SLOPE, Al( i Job Reference No. 93481 Logaed By;. G. JOHNSON RECEIVED DEC -~ 199~ Alaska .Oil & Gas Cons. Commission Anchorage Date , 10/15/93 Computed By: R. SZNES SCHLUMBERGER GCT DIRECTIONAL SURVEY cUsTOMER LISTING FOR ARCO A~SKa, INC. 2A - 17 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 15-0CT-1993 ENGINEER' O. JOHNSON METHODS OF COMPUTATION TOOL LOCATION- MINIMUM CURVATURE INTERPOLATION' LINEAR VERTICAL SECTION- HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 68 DEG 14 MIN WEST COMPUTATION DATE' 26-0CT-93 PAGE I ARCO ALASKA, INC. 2A - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 15-0CT-1993 KELLY BUSHING ELEVATION' 133.00 FT ENGINEER' G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/100 FEET FEET FEET DEG ~IN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -133.00 100 O0 200 O0 300 O0 399 88 499 51 598 69 696 80 793 35 887 56 0 0 N 0 0 E -33.00 0 11 S 34 33 E 67.00 0 13 S 42 34 E 167.00 0 41 N 60 58 W 266.88 3 59 N 51 25 W 366.51 5 51 N 50 28 W 465.69 9 4 N 52 13 W 563.80 12 55 N 56 10 W 660.35 17 24 N 59 27 W 754.56 21 16 N 62 45 W 0 O0 0 O0 -0 34 -0 35 4 O4 12 17 ,24.28 42.94 68.48 101.67 0 O0 0 O0 0 32 4 25 1 97 2 89 3 78 3 87 4 84 2 4O 0,00 N 0.00 S O.33 S 0.45 S 2 38 N 7 78 N 15 74 N 26 94 N 40 78 N 56 86 N 0 O0 E 0 O0 E 0 24 E 0 20 E 3 40W 10 O0 W 19 86 W 35 48 W 57 46 W 86 0 O0 N 0 OE 0 0 0 4 12 25 44 70 77 W I03 O0 S 27 36 E 40 S 35 56 E 49 S 23 48 E 15 N 55 4 W 67 N 52 8 W 34 N 51 36 W 55 N 52 48 W 46 N 54 38 W 75 N 56 46 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 979.86 O0 1069.92 936 O0 1158.51 1025 O0 1245.67 1112 O0 1330.44 1197 O0 1412.85 1279 O0 1491.88 1358 O0 1567.32 1434 O0 1636.90 1503 O0 1700.25 1567 846 86 24 5 92 26 51 51 28 18 67 3O 40 44 33 14 85 36 22 88 39 0 32 43 23 9O 48 3O 25 52 49 N 63 57 W N 65 38 W N 66 43 W N 67 8 W N 66 20 W N 66 23 W N 65 43 W N 65 18 W N 64 52 W N 65 52 W 139.99 183 36 229 72 278 70 331 70 388 30 449 51 515 03 586 69 663 92 4 31 1 77 1 24 2 89 1 46 4 65 3 51 5 41 4 87 2 89 74 05 N 121 18 W 142.01 N 58 34 W 92 111 130 151 174 198 226 256 288 52 N 160 21N 202 34 N 248 34 N 296 10 N 348 86 N 404 17 N 464 45 N 529 78 N 599 50 W 185.26 N 60 2 W 95 W 231.42 N 61 17 W 06 W 280 22 N 62 17 W 74 W 333 11 N 62 59 W 59 W 389 65 N 63 28 W 63 W 450 85 N 63 50 W 27 W 516 43 N 64 2 W 33 W 588 18 N 64 9 W 58 W 665 50 N 64 17 W 2000 O0 1758 42 1625.42 55 56 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1814 O0 1867 O0 1918 O0 1970 O0 2022 O0 2074 O0 2127 O0 2180 O0 2233 15 1681.15 56 19 57 1734.57 59 5 84 1785.84 59 8 24 1837.24 58 57 14 1889.14 58 33 44 1941.44 58 24 04 1994.04 58 5 16 2047.16 57 43 £3 2100.90 57 25 N 66 41W N 66 34 W 828 N 66 43 W 912 N 67 5 W 998 N 70 6 W 1084 N 70 8 W 1169 N 70 10 W 1254 N 70 17 W 1339 N 70 24 W 1424 N 70 25 W 1508 745 19 19 68 5O 27 69 88 88 55 82 1 26 1 09 1 21 1 72 0 48 0 17 0 14 0 27 0 40 0 56 321 46 N 674 05 W 746 78 N 64 30 W 354 387 421 452 481 510 539 568 596 39 N 750 95 N 827 82 N 906 90 N 986 93 N 1067 89 N 1147 70 N 1227 23 N 1307 48 N 1386 27 W 829 84 W 914 74 W 1000 67 W 1085 O7 W 1170 23 W 1255 25 W 1340 03 W 1425 49 W 1509 76 N 64 43 W 24 N 64 53 W 05 N 65 3 W 65 N 65 21W 85 N 65 42 W 85 N 66 0 W 68 N 66 16 W 20 N 66 30 W 35 N 66 43 W 3000 00. 2287 62 2154 62 57 30 3100 O0 2341 3200 O0 2395 3300 O0 2450 3400 O0 .2503 3500 oo 2557 3600 O0 2611 3700 O0 2666 38OO.OO 2722 3900.O0 2776 61 2208 61 57 7 94 2262 94 56 58 27 2317 27 57 30 65 2370 65 57 42 42 2424 42 57 14 81 2478 81 56 51 78 2533.78 56 28 28 2589.28 56 17 08 2643.08 58 38 N 70 15 W 1593 11 N 70 17 W 1677 N 70 21W 1761 N 68 49 W 1845 N 67 23 W 1929 N 67 39 W 2013 N 67 52 W 2097 N 68 10 W 2181 N 68 18 W 2264 N 68 7 W 2348 23 13 04 60 91 82 35 53 82 0 07 0 13 0 28 3 28 0 70 0 44 0 32 0 5O 1 04 1 O5 624 89 N 1465 91 W 1593 54 N 66 55 W 653 681 710 742 774 806 837 868 899 33 N 1545 61N 1624 42 N 1703 41N 1781 67 N 1859 45 N 1936 73 N 2014 55 N 2091 86 N 2169 13 W 1677 18 W 1761 03 W 1845 30 W 1929 20 W 2014 86 W 2098 32 W 2181 58 W 2264 83 W 2349 58 N 67 5 W 41 N 67 14 W 26 N 67 21W 82 N 67 22 W 13 N 67 23 W 05 N 67 24 W 58 N 67 25 W 75 N 67 27 W 03 N 67 29 W COMPUTATION DATE' 26-0CT-93 PAGE 2 ARCO ALASKA, INC. 2a - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 15-0CT-1993 KELLY BUSHING ELEVATION' 133.00 FT ENGINEER' G. JOHNSON INTERPOLATED V/U_UES FOR EVEN 1OO FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2828 O0 2695.00 58 33 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2880 O0 2933 O0 2986 O0 3039 O0 3092 O0 3144 O0 3196 O0 3248 O0 3300 45 2747 45 58 10 60 2800 99 2853 82 2906 15 2959 25 3011 22 3063 30 3115 65 3167 60 57 34 99 57 58 82 58 17 15 58 36 25 58 39 22 58 42 30 58 30 65 58 23 N 68 26 W 2434.29 N 68 51 W 2519.42 N 69 11 W 2604.12 N 69 17 W 2688.66 N 69 32 W 2773.55 N 69 32 W 2858.74 N 69 26 W 2944.08 N 69 34 W 3029.50 N 69 31W 3114.84 N 69 28 W 3200.02 0 66 0 42 0 66 0 24 0 34 0 26 0 18 0 30 0 35 0 14 931 56 N 2249 21 W 2434 49 N 67 30 W 962 992 1022 1052 1082 1112 1142 1172 1202 58 N 2328 93 N 2407 93 N 2486 78 N 2566 56 N 2645 50 N 2725 44 N 2805 27 N 2885 13 N 2965 ,49 W 2519 57 W 2604 63 W 2688 11W 2773 95 W 2858 89 W 2944 90 W 3029 89 W 3114 69 W 32OO 61 N 67 32 W 29 N 67 35 W 81 N 67 38 W 68 N 67 42 W 85 N 67 45 W 17 N 67 48 W 57 N 67 51W 90 N 67 54 W 07 N 67 56 W 5000 O0 3352.99 3219.99 58 28 5100 5200 5300 5400 5500 5600 5700 5800.00 3765 5900.00 3816 O0 3405.23 3272.23 58 35 O0 3457.26 3324.26 58 46 O0 3508 99 3375.99 58 55 O0 3560 50 3427 50 59 6 O0 3611 77 3478 77 59 11 O0 3662 98 3529 98 59 11 O0 3714 23 3581 23 59 10 53 3632 53 59 8 95 3683 95 59 0 N 69 21W 3285.21 N 69 18 W 3370.47 N 69 21W 3455.85 N 69 25 W 3541 41 N 69 33 W 3627 11 N 69 46 W 3712 94 N 69 41 W 3798 80 N 69 36 W 3884 65 N 69 45 W 3970 46 N 69 50 W 4056 20 0 12 0 18 1262 0 32 1292 0 10 1322 0 41 1352 0 10 1382 0 17 1412 0 11 1442 0 02 1471 0 O0 1501 1232 13 N 3045 44 W 3285.25 N 67 58 W 26 N 3125 42 N 32O5 55 N 3285 64 N 3365 46 N 3445 20 N 3526 12 N 3607 96 N 3687 61N 3768 21W 3370.50 N 68 0 W 11 W 3455.87 N 68 2 W 21 W 3541.43 N 68 4 W 46 W 3627.12 N 68 6 W. 98 W 3712.95 N 68 8 W 56 W 3798.81 N 68 11 W 05 W 3884.65 N 68 12 W 53 W 3970.46 N 68 14 W 01 W 4056.20 N 68 16 W 6000.00 3868 51 3735.51 58 56 6100 O0 3920 06 3787.06 58 57 6200 6300 6400 6500 6600 6700 6800 6900 O0 3971 66 3838.66 58 57 O0 4023 21 3890.21 58 56 O0 4074 99 3941.99 58 44 O0 4127 O0 3994.00 58 33 O0 4179 30 4046.30 58 21 O0 4231.87 4098.87 58 17 O0 4284.15 4151.15 58 43 O0 4335.85 4202.85 58 56 N 68 29 W 4141 85 N 67 3 W 4227 N 67 11W 4313 N 67 30 W 4398 N 67 40 W 4484 N 67 53 W 4569 N 67 55 W 4655 N 68 1W 4740 N 68 8 W 4825 N 68 14 W 4910 53 18 85 39 81 O4 10 35 94 3 75 0 12 0 25 0 44 0 23 0 56 0 31 0 17 0 50 0 O0 1531 58 N 3848 28 W 4141 85 N 68 18 W 1564 1597 1630 1663 1695 1727 1759 1791 1823 55 N 3927 88 N 4006 90 N 4085 54 N 4164 85 N 4243 91N 4322 83 N 4401 64 N 4480 45 N 4559 36 W 4227 53 N 68 17 W 28 W 4313 18 N 68 15 W 35 W 4398 85 N 68 14 W 42 W 4484 39 N 68 14 W 49 W 4569 81 N 68 13 W 46 W 4655 04 N 68 13 W 31 W 4740 10 N 68 12 W 40 W 4825.35 N 68 12 W 87 W 4910.94 N 68 12 W 7000 O0 4387 54 4254 54 58 51 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 4439 36 4306 36 58 46 O0 4492 05 4359 05 57 4 O0 4547 23 4414 23 56 16 O0 4602 46 4469 46 56 42 O0 4557 18 4524 18 57 1 O0 4711.29 4578 29 57 14 O0 4766.47 4633.47 55 59 O0 4822.87 4689.87 55 10 O0 4879.72 4746.72 56 11 N 68 14 W 4996.55 N 68 12 W 5082.08 N 66 37 W 5167.06 N 65 47 W 5250 38 N 66 0 W 5333 67 N 66 29 W 5417 32 N 66 57 W 5501 39 N 67 6 W 5584 76 N 68 23 W 5667 33 N 68 17 W 5749 60 0.27 0.27 3.51 0.26 0.25 O. 80 1.47 O. 83 1 . 06 1.85 1855 20 N 4639 37 W 4996.55 n 68 12 W 1886 1919 1953 1987 2020 2054 2086 2118 2148 97 N 4718 09 N 4797 14 N 4873 20 N 4949 96 N 5026 15 N 5103 82 N 5180 14 N 5256 44 N 5333 77 W 5082 08 N 68 12 W 46 W 5167 06 N 68 12 W 58 W 5250 38 N 68 10 W 67 W 5333 68 N 68 8 W 26 W 5417 34 N 68 6 W 53 W 5501 42 N 68 5 W 26 W 5584 79 N 68 4 W 66 W 5667.36 N 68 3 W 14 W 5749.63 N 68 3 W COMPUTATION DATE: 26-0CT-93 PAGE 3 ARCO ALASKA, INC. 2a - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 15-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH ~I~UE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTI~ DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERI3~f NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEO 8000 O0 4935 39 4802 39 55 47 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 4991 O0 5047 O0 5100 O0 5152 O0 5204 O0 5255 O0 5308 O0 5366 O0 5426 89 4858 84 4914 69 4967 43 5019 03 5071 06 5122 88 5175 05 5233 69 5293 89 55 29 84 56 54 69 58 40 43 58 56 03 59 7 06 59 12 88 56 19 05 54 6 69 51 35 N 68 31W 5832 67 N 68 54 W 5915 N 68 51W 5998 N 68 16 W 6082 n 68 22 W 6168 N 68 31W 6254 N 69 I W 63,40 N 69 3 W 6424 N 69 31W 6506 N 69 43 W 6585 17 O5 94 51 17 16 42 45 93 1 08 0 30 3 39 0 28 0 21 0 66 2 50 1 85 2 68 2 25 2179 11 N 5410 35 W 5832 70 N 68 4 W 2209 2238 2269 2301 2333 2364 2394 2423 2451 02 N 5487 78 N 5564 98 N 5643 60 N 5723 10 N 5802 31N 5882 54 N 5961 60 N 6038 43 N 6112 24 W 5915 60 W 5998 54 W 6082 06 W 6168 71W 6254 85 W 6340 51W 6424 23 W 6506 70 W 6585 20 N 68 4 W 07 N 68 5 W 96 N 68 5 W 53 N 68 6 W 19 N 68 6 W 18 N 68 6 W 44 N 68 7 W 46 N 68 8 W 94 N 68 9 W 9000 O0 5491 19 5358 19 48 26 9100 920O 9300 9400 9500 9600 9700 9800 9900 O0 5559 O0 5631 O0 5704 O0 5779 O0 5856 O0 5933 O0 6011 O0 6089 O0 6167 50 5426 15 5498 29 5571 68 5646 75 5723 93 5800 39 5878 55 5956 62 6034 50 45 17 15 43 13 29 42 39 68 39 53 75 39 24 93 39 29 39 38 50 55 38 38 62 38 38 N 68 53 W 6662 31 N 66 1W 6735 30 N 66 16 W 6805 O1 N 66 4 W 6873 16 N 67 51W 6938 82 N 66 46 W 7002 53 N 66 27 W 7066 08 N 65 14 W 7129.28 N 62 12 W 7191.47 N 62 11 W 7253.47 1 58 1 11 0 81 1 82 0 71 0 56 0 46 1 46 2 53 0 O0 2478 30 N 6184 21W 6662 32 N 68 10 W 25O6 2534 2561 2587 2612 2637 2663 2690 10 N 6251 27 N 6315 81N 6377 41N 6438 05 N 6497 23 N 6555 04 N 6613 44 N 6669 2719.47 N 6724 71W 6735 52 W 6805 90 W 6873 38 W 6938 15 W 7002 53 W 7066 27 W 7129 30 W 7191 46 W 7253 31 N 68 9 W 02 N 68 8 W 17 N 68 7 W 84 N 68 6 W 55 N 68 6 W 11 N 68 5 W 31 N 68 4 W 52 N 68 2 W 54 N 67 59 W 9934.00 6194.16 6061.16 38 38 n 62 11 W 7274.59 0.00 2729.38 n 6743.25 W 7274.68 N 67 58 W COMPUTATION DATE: 26-0CT-93 PAGE 4 ARCO ALASKA, INC. 2A - 17' KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 15-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 1000.00 979.86 846 2000.00 1758.42 1625 3000.00 2287.62 2154 4000.00 2828.00 2695 5000.00 3352.99 3219 6000.00 3868.51 3735 7000.00 4387.54 4254 8000.00 4935.39 4802 9000.00 5491.19 5358 0.00 -133 O0 0 0 86 24 5 42 55 56 62 57 30 O0 58 33 99 58 2B 51 58 56 54 58 51 39 55 47 19 48 26 N 0 0 E N 63 57 W 139 N 66 41W 745 N 70 15 W 1593 N 68 26 W 2434 N 69 21W 3285 N 68 29 W 4141 N 68 14 W 4996 N 68 31W 5832 N 68 53 W 6662 0 O0 99 19 11 29 21 85 55 67 31 0 O0 4 31 I 26 0 07 0 66 0 3 0 .1 1 12 75 27 08 58 0 O0 N 74 321 624 931 1232 1531 1855 2179 2478 05 N 121 46 N 674 89 N 1465 56 N 2249 13 N 3045 58 N 3848 20 N 4639 11N 5410 0 O0 E 0.00 N 0 0 E 18 W 142.01 N 58 34 W 05 W 746.78 N 64 30 W ' 91 W 1593.54 N 66 55 W 21 W 2434.49 N 67 30 W 44 W 3285.25 N 67 58 W 28 W 4141.85 N 68 18 W 37 W 4996.55 N 68 12 W 35 W 5832.70 N 68 4 W 30 N 6184.21 W 6662.32 N 68 10 W 9934.00 6194.16 6061.16 38 38 N 62 11 W 7274.59 0.00 2729.38 N 6743.25 W 7274.68 N 67 58 W COMPUTATION DATE: 26-0CT-93 PAGE 5 ARCO ALASKA, INC. 2a - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 15-0CT-1993 KELLY BUSHING ELEVATION' 133.00 FT ENGINEER' G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 133 O0 233 O0 333 O1 433 22 533 69 634 82 737 25 841 78 948 97 0.00 -133.00 0 0 133.00 0.00 0 14 233.00 100.00 0 7 333.00 200.00 2 8 433.00 300 O0 4 38 533.00 400 O0 6 42 633.00 500 O0 10 34 733.00 600 O0 14 24 833.00 700 O0 19 18 933.00 800 O0 22 33 N 0 0 E S 32 0 E S 31 18 E N 52 18 W N 50 43 W N 50 40 W N 53 40 W N 57 18 W N 60 53 W N 63 35 W 0.00 -0.10 -0.42 0.44 6 43 15 67 $o oo 51 56 81 49 119 87 0 O0 0 O0 0 O0 4 39 0 67 3 32 4 03 3 93 3 53 2 84 0 O0 N 0 11S 0 40 S 0 03 N 3 95 N 10 11N 19 32 N 31 76 N 47 31N 65 0 O0 E o 0 0 5 12 24 42 68 09 N 103 O6 E 29 E 47 W 35 W 84 W 59 W 84 W 86 W 0.00 N 0 0 E 0.12 S 31 4 E O.49 S 36 34 E 0.47 N 86 5O W 6 65 N 53 31W 16 34 N 51 46 W 31 28 N 51 51W 53 33 N 53 27 W 83 55 N 55 3O W 08 W 121 91 N 57 44 W 1058.72 1033.00 1171.08 1133 O0 1000 1285 30 1233 1403 05 1333 1525 19 1433 1653 64 1533 1794 14 1633 1955 37 1733 2134 35 1833 2327 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 900 O0 26 11 O0 27 58 O0 30 15 O0 33 18 O0 37 14 O0 41 0 O0 48 11 O0 54 39 O0 57 7 59 1933 O0 1800.00 59 7 N 65 0 W N 66 28 W N 67 12 W N 66 19 W N 66 23 W N 65 20 W N 64 51W N 66 23 W N 66 33 W N 68 0 W 1022 164 93 216 O9 271 24 333 36 403 41 483 91 582 32 708 52 856 89 18 1 92 1 19 3 O2 1 33 2 65 4 47 5 37 4 O0 3 66 3 82 84.82 N 143.73 W 166 89 N 59 27 W 105.80 N 190.44 W 217 127.44 N 241.18 W 272 152 O1 N 298 27 W 334 180 16 N 362 45 W 404 213 15 N 435 95 W 485 254 59 N 525 37 W 583 306 85 N 640 40 W 710 365 81 N 776 61 W 858 430 85 N 928 63 W 1023 85 N 60 57 W 78 N 62 9 W 77 N 63 0 W 75 N 63 34 W 27 N 63 57 W 81 N 64 9 W 12 N 64 24 W 46 N 64 47 W 71 N 65 7 W 2520 80 2033 O0 1900.00 58 31 2711 2898 3084 3268 3454 3638 3819 4009 4198 26 2133 33 2233 12 2333 03 2433 74 2533 68 2633 37 2733 58 2833 88 2933 O0 2000.00 58 3 O0 2100.00 57 24 O0 2200,00 57 9 O0 2300 O0 57 8 O0 2400 O0 57 28 O0 2500 O0 56 42 O0 2600 O0 56 34 O0 2700 O0 58 30 O0 2800 O0 57 34 N 70 7 W 1187.42 N 70 18 W 1349.43 N 70 25 W 1507.41 N 70 16 W 1663 90 N 69 50 W 1818 14 N 67 31W 1975 80 N 67 58 W 2130 17 N 68 16 W 2280 67 N 68 28 W 2442 46 N 69 11 W 2603 18 0.01 0.24 O. 55 0.40 2.48 O. 68 0.72 1.91 0.57 O. 67 487.96 N 1083 75 W 1188.54 N 65 46 W 542.92 N 1236 596..01 N 1385 648.83 N 1532 700.92 N 1677 760.14 N 1823 818.62 N 1966 874.52 N 2106 934.56 N 2256 992.60 N 2406 25 W 1350.21 N 66 17 W 16 W 1507.94 N 66 43 W 57 W 1664.26 N 67 3 W 85 W 1818.37 N 67 20 W 97 W 1976,03 N 67 23 W 84 W 2130.40 N 67 24 W 57 W 2280.89 N 67 27 W 81 W 2442.66 N 67 30 W 69 W 2603.35 N 67 35 W 4387.04 3033.00 2900 O0 58 14 4578.40 3133.00 3000 4770.69 3233.00 3100 4961.76 3333.00 3200 5153.30 3433.00 3300 5346.54 3533.00 3400 5541.46 3633.00 3500 5736.60 3733.00 3600 5931.16 3833.00 3700 6125.08 3933.00 3800 oo 58 35 O0 58 35 O0 58 28 O0 58 38 O0 58 59 oo 59 13 O0 59 8 O0 58 59 O0 58 56 N 69 31W 2762 53 N 69 27 W 2925 N 69 33 W 3089 N 69 22 W 3252 N 69 20 W 3415 N 69 26 W 3581 N 69 47 W 3748 N 69 38 W 3916 N 69 51W 4O82 N 67 5 W 4249 64 84 63 96 28 54 O6 89 O1 0 37 0 33 0 19 0 19 0 28 0 27 0 2o 0 21 0 20 0 21 1048 93 N 2555 78 W 2762 66 N 67 41 W 1106 1163 1220 1278 1336 1394 1453 1510 1572 02 N 2708 52 N 2862 64 N 3014 33 N 3167 56 N 3322 77 N 3479 07 N 3636 81N 3793 93 N 3947 62 W 2925 47 W 3089 94 W 3252 77 W 3415 53 W 3581 39 W 3748 50 W 3916 08 W 4082 15 W 4249 73 N 67 47 W 90 N 67 53 W 66 N 67 58 W 98 N 68 1W 29 N 68 5 W 54 N 68 9 W O6 N 68 13 W 89 N 68 17 W O1 N 68 16 W COMPUTATION DATE: 26-0CT-93 PAGE 6 ARCO ALASKA, INC. 2A - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 15-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG 6318 95 4033 O0 3900 O0 58 52 6511 6702 6894 7087 7274 7455 7639 7817 7995 50 4133 15 4233 47 4333 74 4433 36 4533 70 4633 BO 4733 70 4833 75 4933 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 58 32 O0 58 17 O0 58 56 O0 58 45 O0 56 17 O0 56 49 O0 56 35 O0 55 2 O0 55 49 N 67 32 W 4415 07 N 67 54 W 4579 N 68 2 W 4741 N 68 14 W 4906, N 68 11W 5071 N 65 42 W 5229 N 66 15 W 53,80 N 66 54 W 5534 N 68 28 W 5681 N 68 29 W 5829 61 93 21 59 O8 23 73 85 15 0 39 0 39 0 19 0 O0 0 26 0 37 0 54 1 72 0 80 1 10 1637 11 N 4100 33 W 4415 07 N 68 14 W 1699 1760 1821 1883 1944 2006 2067 2123 2177 55 N 4252 52 N 4403 69 N 4555 08 N 4709 38 N 4854 07 N 4992 22 N 5134 48 N 5270 82 N 5407 58 W 4579 61 N 68 13 W 01 W 4741 93 N 68 12 W 47 W 4906 21 N 68 12 W 04 W 5071 59 N 68 12 W 14 W 5229 08 N 68 10 W 26 W 5380 24 N 68 6 W 21 W 5534 76 N 68 4 W 16 W 5681.88 N 68 3 W 07 W 5829.18 N 68 4 W 8173 07 5033 O0 4900 O0 56 12 8362 8556 8742 8910 9061 9202 9338 9469 9598 35 5133 69 5233 95 5333 10 5433 95 5533 54 5633 66 5733 27 5833 79 5933 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 58 55 O0 59 26 O0 55 9 O0 51 17 O0 46 24 O0 43 12 O0 41 23 O0 39 24 O0 39 30 N 69 1W 5975 58 N 68 20 W 6136 N 68 44 W 6302 N 69 12 W 6459 N 69 44 W 6593 N 67 11W 6708 N 66 16 W 6806 N 66 48 W 6899 N 66 59 W 6983 N 66 28 W 7065 26 9O 95 82 O1 74 O2 O3 32 2 02 0 25 0 67 3 40 3 18 5 83 0 71 5 14 0 94 0 45 2230 70 N 5543 63 W 5975.61 N 68 5 W 2289 2350 2407 2454 2495 2534 2572 2604 2636 70 N 5693 87 N 5848 21N 5994 16 N 6120 26 N 6226 97 N 6317 1TN 6401 38 N 6479 93 N 6554 09 W 6136 28 N 68 5 W 10 W 6302 71W 6459 10 W 6593 66 W 6708 11W 68O6 62 W 6899 21W 6983 82 W 7065 92 N 68 6 W 97 N 68 7 W 83 N 68 9 W 02 N 68 10 W 76 N 68 8 W O4 N 68 7 W 05 N 68 6 W 34 N 68 5 W 9727.69 6033.00 5900.00 38 35 9855.66 6133.00 6000.00 38 38 9934.00 6194.16 6061.16 38 38 N 64 40 W 7146.57 N 62 11 W 7225.92 N 62 11 W 7274.59 I . 74 O. O0 0. O0 2670.37 N 6628.96 W 7146.61 N 68 4 W 2706.54 N 6699.96 W 7225.98 N 68 0 W 2729.38 N 6743.25 W 7274.68 N 67 58 W COMPUTATION DATE: 26-0CT-93 PAGE 7 ARCO ALASKA, INC. 2A - 17' KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 15-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR CHOSEN HORIZONS MARKER 9 5/8" CASING GCT LAST READING PBTD 7" CASING TD SURFACE LOCATION = 1347' FSL A 63' FEL, SEC14 TllN R8E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4161.00 2912.74 2779.74 9800.00 6089.55 5956.55 9827,00 6110.62 5977.62 9915.00 6179.33 6046.33 9934.00 6194.16 6061.16 981.19 N 2376.78 W 2690.44 N 6669.30 W 2698.18 N 6684.12 W 2723.84 N 6732.75 W 2729.38 N 6743.25 W ARCO ALASKA, INC. 2A - 17 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER PBTD TD COMPUTATION DATE: 26-0CT-93 PAGE 8 DATE OF SURVEY: 15-0CT-1993 KELLY BUSHING ELEVATION: 133.00 FT ENGINEER: Q. JOHNSON ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1347' FSL & SB' FEL, SEC14 TllN R8E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 9827.00 6110.62 5977.62 2698.18 N 6684.12 W 9934.00 6194.16 6061.16 2729.38 N 6743.25 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9934.00 6194.16 6061.16 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7274.68 N 67 58 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL 2A - 17 COUNTRY usA RUN I DATE LOGGED -15 - OCT - 93 DEPTH UNIT FEET REFERENCE 93481 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not. except In the c&se of gross or wiffull negligence on our part. be liable or responsible for any loss. costs, damages or exp~,,~ses incurred or sustained by anyone rasultinQ from any interpretation made by any of our offlcer~, agents or employees. These Interpretations are also subject to our General Terms and Conditions as set out In our current price Schedule. IdELL- 2A-17 ~ (1347'FSL, 53'FEL, SEC.14~ liN, R8E, U~) i0RIZONTAL PROJECTION NOR'T~ FIEF 934.81 SCALE = I / 2000 IN/FT ..................... , !.!.: ~ ::: :::: :::: !~!! :.:. :.:: ;::: :::: :::: ~::. .:~: :~.: .... · !-i!-'!---!---,---i--! ...... !-~--i-i--!---!---i-'-i .... ~'i-'i-'! ...... i--i-'!--!---!'--~-'-!--! .... i---~---i'--i'--!---!---i--i 'i-'~'-i---i ...... !"-!'i-! ...... i--'!'"i-'~ ...... '~'-~--i ':::' :'': :':: :::: '::: ;::: :-:' :::: :::: :::: :'-: ::;. ::.: !i!'~''!F"~"! .... F"~'F'!"'F"!'F"~ "!"~"~"~'~F'!"~'"!'!':'~''!!'"i'! .... :''~"F'! '~'!'! .... :'!'!'"~''F"F!"! :~': .... 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'!'--!-'~'!' ii'i'"!":'}"i-'i'}'"i!:~ ~i~': i'i: ' · --~ i i--~ .... i.--i-?~i .... i--i-i-~ .... i-i i-! ii-i---i- i-i-i--i- i.!--i--i .-i--i-i i-.I.i-i-i..!., i-i..i--i --i.i · ~ ~ i.i-- i.i i : : .... 5[..5.~ i.i.i..i .... i..i..i...L.l..i.[i.[ i:i!. ~i.i.[ i[iS..i..:.~i.l.:i..i. 5'i.i:.i i.:i: .:.[[~.: ..... ii.i-.!--i.-i-i-i---!---i--i--i .... i..-i...i.i iii--i¢-i---i--i:.-i--i--i--i.-i---!-i-i--ii-.!...i i-.i..-!--.i !;-.; .... :.!..i..i ~i.i~ ..... 292.00 II PROJECTION ON VERTICAL PLANE 112.00 292.00 SCALED IN VERT1CAL DEPTHS HORIZ .~,CALE = 1 / 2000 IN/FT ARCO Alaska, Inc. Date: November 5, 1993 Transmittal #: 8916 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed copy of this transmittal. Please acknowledge receipt and 2A-17 2A-21 2A-23 Directional Survey Directional Survey Directional Survey 10-15-93 93481 10-14-93 93483 10-15-93 93482 Receipt Acknowledged: DISTRIBUTION: Date: D&M State of Alaska (2 copies) ARCO Alaska, Inc. Date: O~'tober 29, 1993 Transmittal #: 8907 RETURN TO: ARCO Alaska, Inc. A'I-i'N: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following~ items. receipt and return one signed copy of this transmittal. - Please acknowledge q 5.. ~,$$ ~2A-21 Cement Evaluation Log CET ",2A-21 Cement Bond Log CBT,--' ~2A-17 Cement Evaluation Log CET~ q~5- ~qo ~2A-17 Cement Bond Log CBTf /2A-23 Cement Evaluation Log CET ~'~ X,2A-23 Cement Bond Log CBT 10-14-93 10-14-93 10-15-93 10-15-93 10-15-93 10-15-93 9900-11718 9900-11690 8300-9820 8300-9792 0500-11533 0500-11505 Acknowled_e' __ _ _ , Drilling NSK Date: ARCO Alaska, Inc. Date' October 8, 1993 Transmittal #: 8888 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 2A-17 Ultrasonic Imager-GR 9-28-93 (Cement & Corrosion) Acknowledge: Please acknowledge 100-3000 ¢,\ ~' Drilling state' of Alaska(+sepia) NSK MEMORANDUM--,, Stat~'..Sf Alaska Alaska Oil and Gas Conservation Commission TO: David John, DATE: Chairman ~ THRU: Blair Wondzell, ~j~¢~ e l~-~ FlEE NO: P. I. Supervisor FROM: Jerry Herring, tI~ SUBJECT: Petroleum Inspector September 28, 1993 Ebxkiwac.doc Diverter Test- Parker 245 ARCO, KRU, 2A-17 Kuparuk River Field PTD # 93-140 Thursday,. September 23, 1993: I traveled to Kuparuk's 2A pad and witnessed the function test of Parker 245's diverter system. The rig had just moved on hole from 2A-16. The Diverter Systems Inspection Report is attached for reference. The function test began at 11:00 a.m. and went well. I found the rig to be in excellent condition. All components functioned properly and no problems were found. There were two separate 10" ball valves off of the 20" hydrill diverter. The controls were such that either the starboard 10" ball valve or the port side 10" ball valve would open (not together) when the hydrill closed depending on prevailing wind conditions. The 10" lines had 3 targeted tee's each and were vented sufficiently far enough away from ignition sources. I found the layout acceptable for the situation. Summary: A successful diverter test was witnessed on Parker 245, drilling well 2A-17 for ARCO, Kuparuk River Field. Attachment ALASKA OIL AND GAS CONSERVATION CO~IMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 21, 1993 A W McBride, Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2A-17 ARCO Alaska Inc 93-140 1347'FSL, 53'FEL, Sec 14, T11N, R8E, UM 1227'FNL, 1553'FEL, Sec 15, T11N, R8E, UM Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the Nodh Slope pager at 659-3607. , ,w David ~ohnston ~ - Chairm~ BY ORDER OF THE COMMISSION c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl r~'~.~ pf hied on rr,~:y(-IpH papr, r b y C. Fl. STATE OF ALASKA ALAL:., ~ OIL AND GAS CONSERVATION COMMISSi,..,, PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-] lb Type of Well Exploratory ['-] Stratigraphic Test [] Development Oil X Re-Entry E] Deepen [--~ Service [] Development Gas E] Single Zone X Multiple Zone 2., Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 133', Pad 92' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25571, ALK 2669 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1347' FSL, 53' FEL, SEC. 14, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1319' FNL, 1322' FEL, Sec. 15, TllN, R8E, UM 2A-17 #U-630610 At total depth 9. Approximate spud date Amount 1227' FNL, 1553' FEL, Sec. 15, T11N, R8E, UM 9/21/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2A-1 0 9934' MD 1227' ~ TD feet 20' ~ 300' MD feet 2560 6140' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 58.66° Maxirnumsurlace 1707 psig At total depth (TVD) 3288 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD -I-VD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 47.0# L-80 BTC 2959' 41' 41' 3000' 2318' 450 Sx Arcticset III & HF-ERW 550 Sx Class G 12.25" 9.625" 36.0# J-55 BTC 1085' 3000' 2318' 4085' 2883' HF-ERW 8.5" 7" 26.0# L~80 BTCMOE 9893' 41' 41' 9934' 6140' 160 Sx ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth i Conductor ~"t ~.~-.. Surface Intermediate Production Liner ~:~ ,r,. i:) '~ Perforation depth: measured Aia$!{.5~. 0il & Gas '-'_,0,:$. true vertical ,Al'ich01'a~g P~ 20. Attachments Filing fee X Property plat E] BoP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _ ~./~~ Title Area Drilling Engineer Date Commission Use Only ,~'~--~-/~"~ 50- //0,..~.- ~ (-~ //,~'~,. ' other requirements Conditions of approval Samples required FI Yes ~ No Mud log required r-] Yes .~] No Hydrogen sulfide measures ~ Yes ~' No Directional survey required ,~ Yes [] No Required working pressure for BOPE BI 2M ~] 3M [-'] 5M D 10M E] 15M Other: Origina.! Signed By David W. dohnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolic;[ o , o 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2A-17 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4085')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9934') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. Anchorage DRILLING FLUID PROGRAM Well 2A-17 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1707 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2A-17 is 2A-10. As designed, the minimum distance between the two wells would be 20' @ 300' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. iCreated by · jones For: M ELLIS !Date plotted ' 13-Sep-93 i : iPIot Reference is 17 Version #2. iCoordinotes are in feet reference slot #17. !True Vertical Depths (]re reference wellheed. --- Baker Hughes INTEQ 7200 TD LOCATION: I 1227' FNL, 1554' FEL SEC. 15, T11N. R8E 6800 6400 6000 ,5600 I t I I I I I ARCO ALASKA, ITARGET LOCATION: 1519' FNL, 1522' FEL SEC. 15, T11N, R8E I I V Structure : Pod 2A Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska: <-- West 5200 4800 4400 40'305600 3200 2800 2400 2000 16001200 I I I I I I I I I I I I I I I I I I I I I I Scale 1 : 200.00 800 400 0 400 TARGEq~ TVD=5845 '"'" TMD=9546 DEP=7051 550 _ 700 _ _ 10~_ _ 1400_ _ 17~_ _ 2100_ _ 2450_ _ 2800_ _ _ 5500_ _ 3850_ _ 4200 _ _ 45~ _ _ 4900_ _ 52~_ _ 5600_ _ 5950_ _ 5~ 0 350 Scale I : 175.00 N 68.24 DEG w ?0St' (TO TARC ,T) NORTH 2614 WEST 6549 RKB ELEVATION: 133' KOP TVD=500 TMD=300 DEP=O 3.00 9.00 15 O0 ~ 1 21 BULD 3 DE(:; / 00' ~%. 27.00 ~ ,5.5.00 '%, 39.00 B/ PERMAFROST ~/D=1505 TMD=1601 DEP=427 '~ 45 O0 T/ UGNU SNDS TVD=1585 T~D=1707 DEP=495 '"-% 51,00 EOC TVD=1951 TMD=2255 DEP=917 SAJ< SNDS 7VD=2283 1MD=2932 D[F':1494 ~/ W SAK SNDS TVD=2~83 1MD=3701 DF~=2151 9 5/8," CSG Pl TVD=2B83 TMD=4085 DEP=24~O ~ ~ K--la TVD=2973 1MD=4259 D£P=262~ MAXIMUM ANGLE ~ 58.66 DEG TARGET ANGLE 40 DEG ISURFACE LOCATION: 1347' FSL, 55' FEL SEC. 14, IllN. RSE 5200 _ _2800 - _2400 - A _2000 I _ _1600 _ _1200Z 0 800 400 0 .. % ii_ F" t ,5 199;5 Alaska Oil & Gas Cons. Anchorage ] 1VD=4313 Ti,ID=6855 DEP=4828 --... . . BEGIN ANGLE DROPTVD=5238 TMD=8613 0EP=6347 ~ 58.00 '~,,,54.00 ~ 50.00 DROP 2 DEO/ 100' '%"46.00 x% 42.00 TARGET - (gOD) TVD=5843 TMD=9546 DEP=7051 ~ B// KUP St'IDS ~¢0=5987 TMD=9734 DEP=717~~' XN,k,,xx% TD - 7" CSG PT TVD:6140 TMD=9934 DEP=7301 I I I I I I I I I t I t I i I I I i I I I I 45150 I I I 52150 I I I I i I I I I I I 1 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4-900 5600 5950 6300 6650 7000 7350 Vertical Section on 291,76 azimuth with reference 0.00 N, 0.00 E from sial //17 45O 4OO 35O 3OO <- West 250 200 150 lO0 Scale 1 5O 0 : 50.00 5O 1500 1500 .4task.,~. , - (,~it & Gas Cons, Corn,toss,on' , ' ' ,Anchorage 1100 ARC 0 ALASKA, Structure : Pad 2A Field : Kuparuk River Unit Well : 17 Location : North Slope, Alaska 900 1900 2900 0 1900 '~' O0 200 150 100 5O 5O I_._ 100 i150 /X I I Casing Design / Cement Calculations 14-Sep-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressu re: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2A-17 4,085 ft 2,883 ft 9,934 ft 6,140 ft 2,931 ft 9,546 ft 5,843 ft 3288 psi ~~~~~~~~~~~.~~~~.~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~.~~~~~~~~':::::::::::?::::::::::::::::?::::::::::::::¢::::::::::::::::::::::::::?::::::::?:::?::::::?:::::?:::::::::::::?:::::?:::?:::::::::::::::?:?:?::::::?::::::::::::¢: See P 4 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe = {(13.5'0.052)-0.11}*TVDshoe =[ Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 2,883 ft 1,707 psiJ 3,288 psi 5,843 ft 150 psi 11.3 ppgJ Design lead bottom 500 ft above the Top of West Sak = 2,431 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 761 cf Excess factor = 15% Cement volume required = 876 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 450 sxJ Surface tail: TM D shoe = 4,085 ft (surface TD - 500' above West Sak) * (Annulus area) = 518 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4110 cf/If Cmt required in casing = 33 cf Total cmt = 551 cf Excess factor = 15% Cement volume required = 634 cf Yield for Class G cmt = 1.15 Cement volume required =[ 550 sxJ Anchorage Casing Design / Cement Calculations Production tail- 14-Sep-93 TM D = 9,934 ft Top of Target, TMD = 9,546 ft Want T©C 500' above top of target = 9,046 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 155 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 172 cf Excess factor = 15% Cement volume required = 198 cf Yield for Class G cmt = 1.23 Cement volume required =1 160 sxJ TENSION - Minimum Design Factors are' T(pb)=1.5 and T(js)=1.8 Surface (Pipe Body)' Casing Rated For: Tension (Pipe Body) -- Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy - Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production (Pipe Body): Tension (Pipe Body): Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy -- Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 Production (Joint Strength): Tension (Pipe Body): Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy - Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft): Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 ..... 1993 Anchorsge 1086000 lb 4,085 ft 47.00 Ib/ft 191995.0 lb 32587.7 lb 159407.3 lb 1161000 lb 4,085 ft 47.00 Ib/ft 191995.0 lb 32587.7 lb 1594O7.3 lb 7.31 604000 lb 9,934 ft 26.OO Ib/ft 258284.O lb 44O78.4 lb 214205.6 lb 2.81 667000 lb 9,934 ft 26.00 Ib/ft 258284.0 lb 44078.4 lb 2142O5.6 lb 3,11 Casing Design / Cement Calculations BURST- Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure - Pressure inside-Pressure outside Design Factor - Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE- Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 14-Sep-93 6870 psi 1706.7 psi 4.01 7240 psi 7113 psi 2842 psi 4271 psi 1.71 4750 psi 0.588 Ib/ft 760 psi 6.21 5410 psi 0.588 Ib/ft 3613 psi 1.51 Gas Co;is. C(lr~'¢issio',: A,qchorr-~ge Casing Design / Cement Calculations 14-Sep-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section 1 9.625 8.681 47 L-80 13.5724 SCl. in. 2 9.625 8.835 40 L-80 11.4538 sq. in, 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength Body Strength Collapse Burst 1161000 lb 1086000 lb 4750 psi 6870 psi 979000 lb 91 6000 lb 3090 psi 5750 psi 639000 lb 564000 lb 2020 psi 3520 psi 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb Body Strength Collapse Burst 604000 lb 5410 psi 7240 psi " 4 UPARUK RIVER UNiT 20" DIVERTER SCHEMATIC 6 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . . UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENTTHAT AN INFLUX OF WELI.~ORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SUP-ON WELD STARTING HEAD 3. DIVER'I'ER ~BLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE 4. 20" -2000 PSI DRILUNG SPOOLWn'H TWO 10' OUTLETS. 5. . Gas Oons. Corm'nissi(m Anchora.qe 10" HCR BALL VALVES WITH 10' DIVERTER UNES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROl ! ;:n TO ACHIEVE DOWNWIND DIVERSION 20' - 2(XX) PSI ANNULAR PREVENTER 7 6 5 4 2 13 5/8" 500( °SI BOP STACK ACCUMULATOR CAPACrTY TEST 1. CHECK AND FILL ~ULATOR RESERVOIR TO PI=lOPER LEVEL WiTH HYDRAUUC FLUID. ~. ASSURE THAT ~ULATOR PRESSURE IS 3000 PSI WITH n OBSERVE TIMF, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE BOP STACK TEb~ 1. FIE. BOP STACK AND MANIFOLD WITH WATER. ~- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. ~ CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(Xl0 PSI AND HOLD FOR 10 MINUTES. _mm=n TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE MNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3(XX) PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WiTH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING PosmVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOI'FOM PIPE RAMS. TEST BoI'rOM RANIS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING PosmoN. 1~_ TEST iCFL[y COCKS AND INSIDE BOP TO 3000 PSI WTFH KOOMEY PUMP. 1~ RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2000 PSI STARTING HEAD 11' - 3000 P~ CASING HEAD 11' - 3{X)0 PSI X 13~/~ - 5000 PSI SPACER SPOOL 5. 13-5/8' - ~__~Jn_o__ PSI DFE.G SPOOL W/ CHOKE AND KILL UNES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ 7. '1:3-.5/8' - 5000 PSI ANNU~ ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DAIE (3) Admin, [9~thru i3~ [10 & 13] [14 thru 22] (5) BOPE ~~ ~/'! ~-~ ? [23 thru"28] - Company ..... /~(__.~o, , Lease & Well 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4.' Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13. 14. 15. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nL[nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons .... ................. Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel lbore separation proposed ............................. Is a d iverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rat ing -- test to _ZLO[2~ps i g ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES NO REMARKS L2~--t h ru' 31'3 (7) Contact /~("_ ~.~/,~.,,~ ' L32] ' ( 8 ) Ad d l ,~~ ~/'¢ ~/~3 29. 30. 31. 32. 33. geo 1 ogy' en9 i nee r i ng: DWJ~IL---~ MTM ~ RAD~ f1-2--~ R P ~//r,/-' B EW ~.J2.~.T. d DH .? ~l!!!,,, ""--' TAB ~ ~ft..S- rev 6~93 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE /-o,/ /I/c Additional remarks' ,/ / / MERIDIAN' UM ~ SM WELL TYPE' Exp/~ Redri 11 Inj Rev O -t'Z ~-~O 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. ,IS Tape Ver!f.~cat~op 7-DEC-~ 993 _! ~ :~8 : ~,KCL', ALA.¢K~, IU¢'..,r, tlr,.hPbK Pl. VEP ~k;IT, ,?.A-17,50-130-20193-00 ~. S ? S T R I ,*J, (; 93474 J..4 1347 1:3 3.00 1. 3 3' 0 n 02.00 I,~ ~a.,>e Verification .f, iSt~.nq 7-fhtr;C-!gq3 1!.:38 at'5 'J'O P!T: ~:.~5.4.4 ~T Dri',' .[t'~ BI~: 133.17 FT I)~If.,LBD INTERVA!..; ~16! - qb?S PT RVS. Ti) t~I]' !.¢.n! 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