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Home My WebLink About182-090Reviewed By: P.I. Suprv Comm ________ :ZϬϴͬϭϲͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐϮϰϬϳϬϳϭϯϬϯϱϰ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϳͬϳͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƌŝĂŶŝǆďǇ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϯͬϰͬϮϬϭϭ η ϯϭϬͲϰϮϱ dƵďŝŶŐ͗ϭϬϬ /͗Ϭ K͗ϭϬ KƉĞƌĂƚŽƌ͗,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ͕>> KƉĞƌĂƚŽƌZĞƉ͗ZǇĂŶ,Žůƚ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϳͬϲͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ tĞůůEĂŵĞ͗WZh,KzhE/dϬϲͲϭϳ WĞƌŵŝƚEƵŵďĞƌ͗ϭϴϮϬϵϬϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ 'ŽŽĚ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ 'ŽŽĚ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ 'ŽŽĚ͘ůĞĂŶǁĂƚĞƌŝŶƚŚĞĐĞůůĂƌ͘ ŽŵŵĞŶƚƐ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚtŝƚŚƐͲƵŝůƚDĂƉ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ WŚŽƚŽƐ;ϰͿĂƚƚĂĐŚĞĚ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌǇ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ &ƌŝĚĂǇ͕ƵŐƵƐƚϭϲ͕ϮϬϮϰ 9 9 9 9 9 9 9 2024-0707_Suspend_PBU_06-17_photos_bb Page 1 of 2 Suspended Well Inspection – PBU 06-17 PTD 1820900 AOGCC Inspection Rpt # susBDB240707130354 Photos by AOGCC Inspector B. Bixby 7/7/2024 2024-0707_Suspend_PBU_06-17_photos_bb Page 2 of 2 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-17 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 182-090 50-029-20760-00-00 11500 Conductor Surface Intermediate Production Liner 9223 80 2466 10789 986 10081 20" 13-3/8" 9-5/8" 7" 8245 37 - 117 36 - 2502 34 - 10823 10504 - 11490 37 - 117 36 - 2502 34 - 8765 8549 - 9216 10776 470 2670 4760 7020 10081 1490 5380 6870 8160 10818 - 11202 5-1/2" 17# x 4-1/2" 12.6# L-80 x N-80 32 - 10536 8762 - 9018 Structural 5-1/2" Baker S-3 , 10320 , 8420 No SSSV 10320 , 10442 8420 , 8506 Bo York Operations Manager Ryan Holt Ryan.Holt@hilcorp.com (907) 659 - 5102 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028311 32 - 8571 0 0 6842 0 0 0 1994 0 -5 0 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB , 10442 , 8506 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:37 am, Aug 06, 2024 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Reason: I am approving this document. Date: 2024.08.06 08:43:37 -08'00' David Bjork (3888) DSR-8/12/24WCB 10-1-2024 RBDMS JSB 080824 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Prudhoe Bay UNIT 06-17 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 182090 API Number: Lease Wellbore Traverses: Expiration Date: Operator: Hilcorp Alaska LLC Date Suspended: 3/4/2011 Surface Location: Section: 11 Twsp: 10N Range: 14E Nearest active pad or road: DS-06 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Pad or location surface: Good Location cleanup needed: None Pits condition: Good Surrounding area condition: Good Water/fluids on pad: Good Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): 4 Wellhouse Well Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC wellhead / Tree Cellar description, condition, fluids: None Rat Hole: None Wellhouse or protective barriers: Wellhouse Well identification sign: Good Tubing Pressure (or casing if no tubing): 100 Annulus pressures: IA - 0 psi OA - 10 psi Wellhead Photos taken (# and description): Work Required: None Operator Rep (name and signature): Ryan Holt AOGCC Inspector: Brian Bixby Other Observers: Inspection Date: 7/7/2024 AOGCC Notice Date: 7/6/2024 Time of arrival: 10:15 AM Time of Departure: 10:30 AM Site access method: Drive 50029207600000 5 Year Digitally signed by Ryan Holt (4157) DN: cn=Ryan Holt (4157) Date: 2024.07.07 15:44:24 - 08'00' Ryan Holt (4157) ACTIVITYDATE SUMMARY 7/6/2024 T/I/O = 100/0/20. Temp = SI. WHPs (suspended well inspection) AL disconnected, spool is in back corner. Wellhouse and wellhead are clean. There is ~1 ft of what appears to be water in cellar (raining). There is piping and spool pieces behind the wellhouse that are delineated. Surface area around well is clean. Well ID sign on wellhouse. SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 11:00 7/7/2024 T/I/O = 100/0/10. Temp = SI. WHPs (Suspended well inspection). (Inspected by Brian Bixby). AL disconnected (spool in wellhouse). Piping and spool pieces behind wellhouse with deliniation Wellhead, cellar and around wellhouse tidy and free of drips/spills. Signs accurate and in place. SV, SSV = C. MV = LOTO. MV = O. 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7KHZHOOSUHVVXUHUHDGLQJVDUH7,2 SVL 5HTXHVW +LOFRUS1RUWK6ORSH//&UHTXHVWVDSSURYDOIRUUHQHZDORIWKHH[LVWLQJVXVSHQVLRQVWDWXVIRU $YDULDQFHWRWKHSURYLVLRQVRI$$&FLVDOVRUHTXHVWHGXQGHU$$&L WRDOORZWKHZHOOWRUHPDLQDVVXVSHQGHGLQLWVFXUUHQWFRQGLWLRQ$OOK\GURFDUERQLQWHUYDOVDUH LVRODWHGDQGWKHUHDUHQRXQGHUJURXQGVRXUFHVRIIUHVKZDWHULQWKLVDUHD a 'Fll STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i. Operations Performed Size: MD: i"'- " " !1J IJ Buret: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdmn Plugs Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ChangeApp P J 9223 Plug for Redrill ❑ Perforate Naw Pool ❑ Repair Well ❑ Reenter Susp Well ❑ Other: Susend Inspection 0 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work5. feet Permit to Drill Number: 182-090 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ 8245 feet Packer AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number. 50-029-20760-00-00 7. Property Designation (Lease Number): ADL 028311 WNme and Number: PBU 06-17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 10504 - 11490 8549-9216 8160 7020 Pertorabon Depth: PRUDHOE BAY, PRUDHOE OIL None feet 11. Present Well Condition Summary: Length: Size: MD: TVD: Buret: Collapse: Total Depth: measured 11500 feet Plugs measured 10081 feet true vertical 9223 feet Junk measured 10776 feet Effective Depth: measured 10081 feet Packer measured 10320,10442 feet true vertical 8245 feet Packer true vertical 8420.a506 feet Production Number or N/A if C.O. Exempt: Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Subsequent to operation: Conductor 80 20" 37-117 37-117 1490 470 Surface 2466 13-3/8" 36-2502 36-2502 5380 2670 Intermediate 10789 9-5/8" 34-10823 34-8765 68701 8150 4760/5080 Production Number or N/A if C.O. Exempt: WA Liner 986 7" 10504 - 11490 8549-9216 8160 7020 Pertorabon Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and twe vertical depth) 5-1/2" 17# L-80 / 13Cr80 x 4-1/2" 12.6# N-80 32-10536 32-8571 Packers and SSSV (Type, measured and 5-12" Baker S-3 Packer 10320 8420 true vertical depth) 5-12" Baker SAB Packer 10442 8506 12. Stimulation or cement squeeze summary Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14. Attachments: Iregmred per MMC 25.070.25.071, a 25.2831 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: ~pecialist, /\ , A Contact Email: Travis.Montgomeryabp.com Authorized Signature: / IY vvr�, p Date: �tOIf % Contact Phone: +1 907 564 4127 Form 10404 Revised 04/2017 M��" 6 r' ` �� RBDMSA4"jUL 312019 Submit Original Only T/I/O = 100/0/20. Temp = SI. Pre AOGCC SU well inspection. AL disconnected. Wellhouse and wellhead are clean. There is —1 ft of what appears to be water in cellar. There is piping and spool pieces behind the wellhouse that are delineated. Surface area around well is clean and dry. Well ID sign on wellhouse. 6/30/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 01:40 TWO = 100/0/20. Temp = SI. AOGCC SU well inspection (Inspected by Bob Noble) AL disconnected. Wellhouse and wellhead are clean. Al spool left in wellhouse. Well ID sign on wellhouse. Wellhead and surrounding area is clean and dry. 7/6/2019 ISV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 07:40 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 06-17' Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1820900 API Number: 50-029-20760-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 91 1� Surface Location: Section: 11 Twsp: 10N Range: 14E Nearest active pad or road: DS -06 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Lr, j "r, rav -1 Location cleanup needed: Pits condition: Surrounding area condition: Water/fluids on pad: Discoloration, Sheens on pa Samples taken: Photographs taken (# and Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/treelvalve description, condition: Cellar description, condition, fluids: int Rat Hole: N Wellhouse or protective'barriers: Ini Well identification sign: ,,((r< Tubing Pressure (or casing ifndtubing): ,(r^ Annulus pressures: 6 Wellhead Photos taken (# and description): Work Required: None _ Operator Rep (name and AOGCC Inspector: Inspection Date: Time of arrival: n. FF Site access AOGCC Notice Date Time of Departure: w •� �y�6t �t i j; Q Y 07-341P 07-20A 02.-02_- 4 02-41 ( I �- 0603A 05-03' `1 1404 _ Oe -02A 02-31 02-1 02- D A C, 7404A C 02-24A re 2A "06-02APBI f 0&01 (�02-11A U T L02-11 1403 01-08A C 140° 1433A Y 0&026 ` 0&24A — — 0&_48PB1 �: De -23A � C'�- BA 01 0&228P81 20 0&2 .. = 0&238;7106-23 0&03s C1r,-W-22 �, 3 2 14-33 02218 _•,'' 06-236PJR 1i 07-20G 1432 Y 0&248 ', 08 05 08.22A l _$ 4002-2 1 1434PB2 L 0618r F C 0&20A 4 118A -- � � L; 0& 10A — Q 140<..L1 14143 _ 21A 0&21A — 1434 '. ' R 08-08 D7-2 1 A ' - �R1 ID R01f1 RD a O4VDW- E - ;_ 0613 C 0&14 L D8 -14A d- 06-04- 0&088PB1 A 14071 05.q�06-08A 3,17 05-18 0C2� 10 z' 13-23A 0608 — 11 T12.18 12 01-241 a 1414 1337 1j 08-0 140 C M14B % 06- 88k1 G 061 13APB1 C 0&10A C 08- 08-10 14'8 ty,A 13-19 M-09 C, 13-02BL1 C 128 13 A 13-20 - O 14-26 14-30 0& 128L1 — 1324 1302,8,7^.1302- 105 -OCA 1302BP82.13-b; C: 1301 13-02PB1 '1 13-031 C 13-28 4 1430 1. - * 13-32A 13-2$ -4 1334 ' 13-22 C 1131413 1_6-' 1332 -14 13-25 ? ,^'' ;13-22P81 13-06AP81 DS 13 1304 12-06A 13-31- 13-3Q 1 l 1 �� 13-05 C PR131014 TREE = FMC GEN 3 10504' WELLHEAD = FMC DATE ACTUATOR= _ AXELSON SUSPENDED KB. ELEV = 74' 9-5/8" CSG, 47#, L-80 BTC XO TO SOO-95 BTC BF. ELEV = _ 39.64' 9-5/8' CSG, 47#, SOO-95 BTC, D = 8.681' KOP = _ 3150' 6 _Max AnA a =. __.. 50-@7100' 05/22/96 Daban MD = 109_88' 11046 - 11068 Datum TVD= 8800'SS 3-3/8' 4 13-3/8" CSG, 72#. L-80 BTC, D = 12.347" 2507 Minimum ID = 3.81" @ 10523' 4-1/2" CA DB -6 NIPPLE 5-12' TBG, 17#, 13CR NSCC, —I 10428' .0232 bpf, D = 4.892' 5-12" TBG, 17#. L-80,.0232 bpf, D = 4.892' 1044.2' PERFORATION SLIAM F?Y REF LOG: BHCS ON 07/01/82 ANGLE AT TOP PEW: 49 @ 10818' Note: Refer to Production DB for historical pert data 9S/8" X 7' BKR LNR HGR 10504' INTERVAL w/ TIEBACK SLV, ID =HG 2 DATE 3-3/8" 10536' 4-1/2" TBG, 12.68, N-80, .0152 bpf, D = 3.958" O 10736' 9-5/8" CSG, 47#, L-80 BTC XO TO SOO-95 BTC 6 10974 - 10944 9-5/8' CSG, 47#, SOO-95 BTC, D = 8.681' � 2 PERFORATION SLIAM F?Y REF LOG: BHCS ON 07/01/82 ANGLE AT TOP PEW: 49 @ 10818' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sq2 DATE 3-3/8" 4 10818 - 10848 O 04/15/95 3-3/8" 6 10974 - 10944 O 08/02/96 3-3/8" 6 10994- 11036 S 05/22/96 3-3/8" 4 11046 - 11068 S 05/22/96 3-3/8' 4 11090 - 11110 S 05/16/91 33/8" 4 11120 - 11140 S 05/16/91 33/8" 4 11150 - 11170 S 05/16/91 3318" 4 11182 - 11202 S 05/16/91 7- LNR 29#, L-80, .0371 bpf, D = 6.164' H 11490' SAFETY NOTES: WELD. 8/18)94 PREV K-VLV. 06-17 6-17 "`5-1 /2" CHROME TBG" 2170' H5-112- HES X NIP, D= GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH I PORT DATE '3789 10535' 3758 24 CA DMY T-2 16 0523/05 2 6471 5744 50 CA DMV T-2 16 0523/05 3 8131 6825 47 CA DMY T-2 16 0523/05 4 9209 7596 43 CA DMY T-2 28 0523/05 5 9981 8170 42 CA DMY T-2 0 07/14/00 10060' TOP OF CEMENT (0 10290' JEFCUT(1128/08) 1 10320' 1 1 10395' 1 = 4.75' 10428' 15-12'BKRPBRASSY,D=4.75' 10429' 5-12"MULESHOE,D=4.892' 10442' 9-5/8" X 5-12' BKR SAB PKR DATE w/ K-22 ANCHOR SEAL NP, I-)=4.75" 10448' 7- NLLOUT BKR EXTENSION, D = 6.00' 10455' 5-12" X 4-12" XO, D = 3.958' 10523' 4-12" GAM 08-6 NP, D = 3.81' 10535' 4-1/2' BKR SHEAROUT SUB 10536' 4-1/2' TBG TAL, D = 3.958' 1051T ELMD TT LOGGED 02/12/83 10969' —17- MARKER JOINT 11004' FISH - BKR BP & ELEMENT 1100T CEMENT CAP(0522/96) 11� 20/40 SANDBACK (05/05/9 DATE REV BY COMMENTB DATE REV BV COMMENTS 07/13/82 1 ORIGINAL COMPLETION 12/13/10 1 JRA/PJC I FISH CORRECTIONS (10/31/08) 07/08/00 LAST WORKOVER 0227/11 KSB/PJC P&A(01/30/11) 1121/08 JKD/rLH PLUG PULL4BP SET 11/01/08 0728!19 JNUJMD IADDED BE & SUSPENDED 12/04/08 DTR/PJC SLUGGITS (1126/08) 12/12/08 RRD/PJC JETCUT 1128/08 12/13/10 JRA/PJC CMTCAP/SAND CORRECTIONS PRUDHOE BAY UNFF WELL: 06-17 PERMrr No: 1820900 API No: 50-029-20760-00 )N, R14E, 2826.64' FEL & 5241 BP Exploration (Alaska) nded Well Inspection Review Report InspectNo: susRCN190708125654 Datelnspected: 7/6/2019 Inspector: Bob Noble Well Name: PRUDHOE BAY UNIT 06-17 Permit Number: 1820900 Suspension Approval: Sundry # 310-425 - Suspension Date: 3/4/2011 Location Verified? ❑� If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 7/5/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? Photos Taken? 0 Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: 0 - BPV Installed? ❑ OA: 20 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead looks to be in good condition. SSV is closed. Flowline is attached. AL line has been removed and blinded. Wellhead is protected with a wellhouse. Condition of Cellar Good clean dry gravel Surrounding Surface Condition Good clean gravel. Comments Location was verified with a pad map. - Supervisor Comments Photos(2)attached 'jR ajf1ir`i Monday, August 19, 2019 a • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing El Change Approved Program 0 Plug for Redrill CIPerforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspended Well 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number: 182-090 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-20760-00-00 7. Property Designation(Lease Number): ADL 0028311 8. Well Name and Number PBU 06-17 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL _ 11.Present Well Condition Summary: 4`d ' , 4,,,.:h Total Depth: measured 11500 feet Plugs measured 10081 feet 0 true vertical 9223 feet Junk measured 10776 feet ��1. ') Effective Depth: measured 10081 feet Packer measured 10326,10444 feet � true vertical 8245 feet Packer true vertical 8424.8508 feet A <, 'tom!C C Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 80 20"94#H-40 36-116 36-116 1530 520 Surface 2466 13-3/8"72#L-80 36-2502 36-2502 4930 2670 Intermediate 9743 9-5/8"47#L-80 32-9775 32-8016 8150 5080 Intermediate 1049 9-5/8"47#S00-95 9775-10824 8016-8766 8160 7020 Liner 995 7"29#L-80 10496-11491 8544-9217 8160 7020 Perforation Depth: Measured depth: See Attachment feet (AM True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"Baker S-3 10326 8424 true vertical depth) 5-1/2"Baker SAB 10444 8508 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 6842 0 1994 -5 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development�I I Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil($/IlYY I Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP Me N/A 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or �.N./'A if C.O.Exempt: N/A Contact Summerhays,Nita M(WIPRO Technolo.•-s) Email Nita.Summerhays@bp.com Printed Name Su. merhays, to M(WIPRO Tech . .gies) Title Petrotechnical Data Manager i Signatu = ' , / Phone +1 907 564-4035 Date 08/04/2015 g 10,-,moi✓///// � . 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Nrs. 4t N• y W CO - N - V N �? in a`o i, N c O) to o co .4- O O N CCo � I� OONO J N (3) • W W Q Q C O •C W w w toQctO c ZZ VOLL_ Z t W W W m m O D1; H Z O D U (/) Z _, H F- Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 06-17 Field/Pool: PRUDHOE BAY/PRUDHOE OIL Permit#(PTD): 182-090 API Number: 50029207600000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 3/4/2011 Surface Location: Section: 11 Twsp: 10N Range: 14E Nearest active pad or road: DRILL SITE 06 Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: clean active pad, old spools stored on edge of pad, cleaned and empty Pad or location surface: clean Location cleanup needed: none Pits condition: clean rain water Surrounding area condition: clean Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition: good Photographs taken(#and description): (3)flowline,wellhouse, well sign Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC wellhead, FMC tree, flowline connected, clean and functional Cellar description, condition, fluids: some old grease spots, steel encasement cellar Rat Hole: N/A Wellhouse or protective barriers: well house Well identification sign: yes, correct Tubing Pressure (or casing if no tubing): N/A SSV closed Annulus pressures: IA/OA=0/0 psi Wellhead Photos taken (#and description): (2)wellhead and tree Work Required: none Operator Rep(name and signature): Whitney Pettus 4/1116 AOGCC Inspector: Matt Herrera Other Ob Ryan Hayes Inspection Date: 7/12/2015 AOGCC Notice Date: 7/8/2015 Time of arrival: 8:20 AM Time of Departure: 8:25 AM Site access method: truck • . 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WELLHEAD= FMC 06-1ACTUATOR= AXELSON 7 .5-1/2"CHROME TBG""" KB.ELEV= 74' BF.ELEV= ? KOP= 3150' Max Angle= 50 @ 7100' Datum MD= 10988' Datum TVD= 8800'SS 2170' H5-1/2"HES X NIP,ID=4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,ID=12.347" — 2502' 1 3789 3758 24 CA DMY T-2 16 05/23/05 2 6471 5744 50 CA DMY T-2 16 05/23/05 3 8131 6825 47 CA DMY T-2 16 05/23/05 1114 9209 7596 43 CA DMY T-2 28 05/23/05 5 9981 8170 42 CA DMY T-2 0 07/14/00 ►•••• 10080' —ITOPOFCEMENT(01/30/11) I Minimum ID = 3.81" @ 10523' :•:':•i•:' 10290' —IJET CUT(11/28!08) •••%• ►•••• 4-1/2" CA DB-6 NIPPLE ►••••••••• 10320' —9-5/8"X 5-1/2"BKR S-3 PKR,ID=4.75" I ►••••••••• ►••••••••• ►••••••••• ►••••••4 10395' —5-1/2"HES X NIP,ID=4.562" ••••••••4• ►••••••••4 ►••••••••4 ►••••••••4 ►••••••••4 5-1/2"TBG, 17#, 13CR NSCC, —I 10428' 1••••••••, r••••'' —H 10428' —5-1/2"BKR PBR ASSY,ID=4.75" 1••••• .0232 bpf, ID=4.892" ►•••,"4I►•!• •�-•� '•14••-•;•;•; 10429' —I 5-1/2"MULESHOE,ID=4.892" 4 5-1/2"TBG, 17#, L-80, .0232 bpf, ID=4.892" — 10442' ••�•�••1 10442 —9-5/8"X 5-1/2"BKR SAB PKR 1•••• !••••••••••�\ w/K-22 ANCHOR SEAL NIP, ID=4.75" '`••�•�•�•• \\ll V..4 10448' I-7"MILLOUT BKR EXTENSION, ID=6.00" I �••••4 10455' —15-1/2"X 4-1/2"XO, ID=3.958" 9-5/8"X 7"BKR LNR HGR — 10504' I— ►i O ►•• w/TIEBACK SLV, ID=? •►•�•� 10523' —4-1/2"CAM DB-6 NIP,ID=3.81" 1••4 ►••••• 4 10535' —4-1/2"BKR SHEAROUT SUB 4-1/2"TBG, 12.6#, N-80,.0152 bpf,ID=3.958" — 10536' i••i • t ♦••••♦••••• 10536' —14-1/2"TBG TAIL,ID=3.958" ♦•••••� 9-5/8"CSG,47#,L-80 BTC XO TO S00-95 BTC 10736' •••••••••••Q ••••••••••••. 10517' — ELMD TT LOGGED 02/12/83 ••••••• 9-5/8"CSG,47#,SOO-95 BTC,ID=8.681" — 10823' ••••••••••••♦•••••• • •••••• •••••••••••••••••4 , ••••••. PERFORATION SUMMARY ••••••••••••• ••••••4 REF LOG: BHCS ON 07/01/82 ••••••••••••• ••••• •••••• ANGLE AT TOP PERF:49 @ 10818' •••••••••••••• •••••• ••••••, Note: Refer to Production DB for historical pert data •••••••••••! •••••• SIZE SPF INTERVAL Opn/Sqz DATE ••••••••••••c. ••••••/ 10969' —I 7"MARKER JOINT I 3-3/8" 4 10818- 10848 0 04/15/95 •••••••• ••••••• •••^•.•• •• •., 3-3/8" 6 10974- 10944 0 08/02/96 11004' —I FISH-BKR IBP&ELEMENT(10/31/08) I •• v v •••••••4• • 3-3/8" 6 10994- 11036 S 05/22/96 •-•••••_A_ _1 11007' --I CEMENT CAP(05/22/96) 3-3/8" 4 11046- 11068 S 05/22/96 "•"•"� 3-3/8" 4 11090- 11110 S 05/16/91 11032' 20/40 SANDBACK(05/05/96) 3-3/8" 4 11120- 11140 S 05/16/91 3-3/8" 4 11150- 11170 S 05/16/91 3-3/8" 4 11182- 11202 : S 05/16/91 PBTD — 11325' 1/111111111/1i1 7"LNR,29#,L-80, .0371 bpf, ID=6.184" —I 11490' 1111/1111111111] 1i1�1i1�1i1�1�1ig DATE REV BY" COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/13/82 ORIGINAL COMPLETION 12/13/10 JRA/PJC FISH CORRECTIONS(10/31/08) WELL: 06-17 07/08/00 LAST WORKOVER 02/27/11 KSB/PJC P&A(01/30/11) PERMIT No:`1820900 11/21/08 JKD/TLH PLUG PULL/IBP SET(11/01/08) API No: 50-029-20760-00 12/04/08 DTR/PJC SLUGGITS(11/26/08) SEC 11,T10N, R14E,2826.64'FEL&5240.09'FNL 12/12/08 RRD/PJC JETCUT(11/28/08) 12/13/10 JRA/PJC CMT CAP/SAND CORRECTIONS BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 07/12/15 Inspector: Matt Herrera Operator: BPXA Well Name: PBU 06-17 Oper.Rep: Ryan Hayes PTD No.: 1820900 Oper.Phone: 907-659-5766 Location Verified? Yes Oper.Email: ryan.haves( bp.com If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 03/04/11 Date AOGCC Notified: 07/08/15 • Sundry No.: 310-425 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A • Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: Good,Gauges operable g CANtiej Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around well house or in cellar area Follow Up Actions Needed: Monitor IA and OA pressure and visually inspection by Operator Comments: SSV was closed.Photos taken by operator rep Attachments: None - REVIEWED BY: Insp.Supry jet— t5ltt I lc Comm PLB 12/2014 2015-0712_Suspend_PBU_06-17_mh.xlsx • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 07/02/11 Inspector: Matt Herrera Operator: BPXA Well Name: PBU 06 -17 Oper. Rep: Jon Arend PTD No.: 1820900 Oper. Phone: 907- 659 -5766 Location Verified? Yes Oper. Email: areni2[Dbo com If Verified, How? LAT / LONG Onshore / Offshore: Onshore Suspension Date: 03/04/11 Date AOGCC Notified: 06/29/11 Sundry No.: 310 -425 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 105 ' Photos Taken? Yes IA 0 OA 0 ) F n U _ Condition of Wellhead: Good, no leaks. Water in cellar determined to be snow melt with no sheen. All gauges on tree operational. Condition of Surrounding Surface Location: Good, no subsidence and area around well house clean. Well sign on well house. Follow Up Actions Needed: Operations get regular annulus readings and perform regular visual inspections. Comments: None Attachments: Photos (2) REVIEWED BY: Insp. Supry 4 /11 //, Comm PLB 11/2011 2011- 0702_Suspend_PBU_06- 17_mh.x. Suspended Well PTD Inspection 1820900 — PBU 06 -17 Photo by AOGCC Inspector M. Herrera d n a '"t ' + s k a Inc • " RCS p �� gicnfi GomP � $iA>sidary of Alannc -17 Well No. 6 f : f Surf L ocation FEL 860 s Sec. 11,T10N, R14 , UM Bottom Hole Location : . . 39 " FS , 2457 " FWL i Sec. 11,T1ON R1 , UM ADL ■ No. 28311 DP No. 82 ' {�► • API: 50 - 029 - 20760 Air PBU 06 -17 Suspended Well Inspection 7 -2 -11 mh 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ei REPORT OF Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECTION Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ — 182 - 0900 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 20760 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028311 + PBU 06 -17 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11500 feet Plugs (measured) 10081 (TOC) feet true vertical 9222.79 feet Junk (measured) 11004 feet Effective Depth measured 10081 feet Packer (measured) 10320 10443 feet true vertical 8245.08 feet (true vertical) 8420 8507 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 94# H -40 30 - 110 30 - 110 1530 520 Surface 2473' 13 -3/8" 72# L -80 29 - 2502 29 - 2502 4930 2670 Production 10794' 9 -5/8" 47# L -80 28 - 10822 28 - 8765 6870 4760 Liner 986' 7" 29# L -80 10504 - 11490 8549 - 9216 8160 7020 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ - Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# 13Cr80 23 - 10428 23 - 8496 5 -1/2" 17# 13Cr80 10428 - 10455 8496 - 8515 4 -1/2" 12.6# 13Cr80 10455 - 10536 8515 - 8571 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker S -3 Packer 10320 8420 5 -1/2" Baker SAB Packer 10443 8507 12. Stimulation or cement squeeze summary: r t � Intervals treated (measured): �t E ii. !� ll 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: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGD GINJ ❑ - SUSP0 SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam= Lastu k A Title Petrotechnical Data Technologist Signatur 2 564 -4091 Date 7/11/2011 `f p Form 10 -404 Revised 10/2010 , p B tMS JUL 13 20114 L. ? /p''f( Sub ' Original Only Only /"cr 7/21/ / 06 -17 182 -090 _ PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06 -17 2/12/83 PER 11,090. 11,110. 8,942.49 8,955.96 06 -17 2/12/83 PER 11,120. 11,140. 8,962.7 8,976.19 06 -17 2/12/83 PER 11,150. 11,170. 8,982.95 8,996.48 06 -17 2/12/83 PER 11,182. 11,202. 9,004.6 9,018.16 06 -17 9/25/87 APF 10,818. 10,848. 8,762.09 8,781.89 06 -17 9/25/87 APF 11,018. 11,038. 8,894.24 8,907.61 06 -17 9/25/87 APF 11,048. 11,068. 8,914.3 8,927.71 06 -17 3/29/91 SQZ 11,188. 11,202. 9,008.67 9,018.16 06 -17 5/12/91 SQZ 11,151. 11,188. 8,983.62 9,008.67 06 -17 5/16/91 SPS 11,090. 11,151. 8,942.49 8,983.62 06 -17 5/20/91 APF 11,016. 11,038. 8,892.91 8,907.61 06 -17 5/20/91 APF 11,046. 11,068. 8,912.96 8,927.71 06 -17 4/25/93 APF 10,973. 10,993. 8,864.28 8,877.58 . 11 006. 8 864.28 8,886.24 9/4/93 APF 10 973 06-17 • 06 -17 4/15/95 RPF 10,818. 10,848. 8,762.09 8,781.89 06 -17 8/12/95 SPS 10,892. 11,068. 8,810.85 8,927.71 06 -17 9/2/95 SPR 10,892. 10,965. 8,810.85 8,858.98 06 -17 9/16/95 BPS 10,900. 11,057. 8,816.1 8,920.33 06 -17 10/4/95 BPP 10,900. 11,057. 8,816.1 8,920.33 06 -17 12/10/95 SPR 10,965. 11,068. 8,858.98 8,927.71 06 -17 2/6/96 RPF 10,973. 11,016. 8,864.28 8,892.91 06 -17 5/6/96 SPS 11,030. 11,068. 8,902.26 8,927.71 06 -17 5/22/96 SQZ 10,973. 11,032. 8,864.28 8,903.6 06 -17 8/2/96 APF 10,974. 10,994. 8,864.95 8,878.24 06 -17 5/15/04 BPS 10,370. 10,380. 8,455.32 8,462.42 06 -17 5/22/05 BPP 10,370. 10,380. 8,455.32 8,462.42 06 -17 6/23/05 BPS 10,376. 10,386. 8,459.58 8,466.68 06 -17 6/26/05 BPP 10,376. 10,386. 8,459.58 8,466.68 06 -17 6/27/05 BPS 10,385. 10,395. 8,465.97 8,473.05 06 -17 11/25/08 SPS 10,617. 10,818. 8,626.79 8,762.09 06 -17 1/30/11 SQZ 10,081. 10,818. 8,245.08 8,762.09 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • Suspended Well Site inspection Form Notify A0000 Inspectors at least 10 days prior to inspection to allow witness Well Name: DS6 -17 Field /Pool: Prudhoe Bay /PBU Permit # (PTD): 182 -090 API Number: 500292076000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 12/15/10 Surface Location: Section: 11 Twsp: 10N Range: 14E Nearest active pad or road: Drillsite 6 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: Good - Clean Surrounding area condition: Good - Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None _ Access road condition: Good Photographs taken (# and description): (2) Wellhouse front and surround, Wellhouse back and surrround Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree/valve description, condition: Good - OCT Wellhead, OCT Tree Cellar description, condition, fluids: 4" Meltwater - Clean Rat Hole: None Wellhouse or protective barriers: Wellhouse Well identification sign: Yes Tubing Pressure (or casing if no tubing): 105 psi Annulus pressures: IA - 0 psi. OA - 0 psi Wellhead Photos taken (# and description): (2) Wellhead, Tree Work Required: None Operator Rep (name and signature): Gerald Murphy � ` _ AOGCC Inspector: Matt Herrera Other Observers: rind Inspection Date: 7/2/2011 AOGCC Notice Date: 6/26/2011 Time of arrival: 9:10 AM Time of Departure: 10:00 AM Site access method: Truck • • Prudhoe Bay Unit Well 6 -17 PTD 182 -090 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of PBU 6 -17 on 7/2/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector Matt Herrera witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within 1/4 mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • PBU 6 -17 suspended on 12/15/2010 after several unsuccessful attempts to regain operable status. • PBU 6 -17 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with cement in the tubing. • The well is mechanically sound as proven by a MIT -T and MIT -IA tested to 2500 #. AWO 7/8/2011 TREE = FMC GEM 3 SAFETY : WELD. 8/18/94 PREY K -VLV. ACTUATOR = AXELSON WELLHEAD= FMC 06 -1 7 * * *5 -1/2" OMETBG* ** KB. ELEV = 74' BF. ELEV = ? KOP = 3150' Max Angle = 50 @ 7100' Datum MD = 10988' I 2170' H5-1/2" HES X NIP, ID = 4.562" I Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 113 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" H 2502' I--, 1 3789 3758 24 CA DMY T -2 16 05/23/05 2 6471 5744 50 CA DMY T -2 16 05/23/05 3 8131 6825 47 CA DMY T -2 16 05/23/05 4 9209 7596 43 CA DMY T -2 28 05/23/05 5 9981 8170 42 CA DMY T -2 0 _07/14/00 ∎ ■∎ ■∎ ■∎ ■∎ 10080' J - 1 TOP OF CEMENT (01/30/11) •••4 Minimum ID = 3.81" @ 10523' ► : 10290' — jJET CUT(11 /28/08) 4 -1/2" CA DB -6 NIPPLE ►�� j � ► =� 10320' I- 1 9 -5/8" X 5-1/2" BKR S 3 PKR, ID = 4.75" • ►••• 1 '• • � • � • 4 4 10395' —15-1/2" HES X NIP, ID = 4.562" I ►•iiii' . • ►•i• • •ii 4 5 -1/2" TBG, 17 #, 13CR NSCC, — 10428' jj • j� 10428' H5-1/2" BKR PBRASSY, ID = 4.75" I ►••••1 _ .0232 bpf, ID = 4.892" j ►• � • 10'.. •� • 10429' — 5 1 /2 "MULESHOE ID = 4.892" 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 10442' . ► • •• • • • • •• • ••� 10442' 9 -5/8" X 5 -1/2" BKRSAB PKR ��•••••••• w / K -22 ANCHOR SEAL NIP, ID = 4.75" t•••j•Si ► •j 4 10448' H7" MILLOUT BKR EXTENSION, ID = 6.00" I ►� 10455' H5-1/2" H5-1/2" X4-1/2'X0 , ID = 3.958" I 9 -5/8" X 7" BKR LNR HGR —I 10504' ► OOi ; , w / TIEBACK SLV, ID = ? ►�• 10523' 1 - 1 4 -1 /2" CAM DB -6 NIP, ID = 3.81" I I� ; 10535' I — I 4 -1/2" BKR SHEAROUT SUB I 4 -1/2" TBG, 12.6 #, N -80, .0152 bpf, ID = 3.958" 10536' ♦ •1 • * •4 10536' I TBG TAIL, ID = 3.958" I 19 -5/8" CSG, 47 #, L -80 BTC XO TO SOO -95 BTC I - 1_10736 ►•• , ► ••••••••••�, I 10517' I—I ELMD TT LOGGED 02/12/83 1 . • • 19 -5/8" CSG, 47 #, SOO -95 BTC, ID = 8.681" I 10823' o •• • • 4 ►• ■ PERFORATION SUMMARY • • REF LOG: BHCS ON 07/01/82 ► • • • • ••••• 4 • ANGLE AT TOP PERF: 49 @ 10818' ••••• Note: Refer to Production DB for historical perf data ►••••••••• SIZE SPF INTERVAL Opn /Sqz DATE • • 4 . ► iiiiii • � I 10969' I-I 7" MARKER JOINT I 3 -3/8" 4 10818 - 10848 O 04/15/95 ► • • • • •• • • 3 -3/8" 6 10974 - 10944 0 08/02/96 •• A•�� 4� • 11004' H FISH - BKR IBP & ELEMENT (10/31/08) I 3 -3/8" 6 10994 - 11036 S 05/22/96 •- •- •�• = I 11007' I--I CEMENT CAP (05/22/96) 1 3 -3/8" 4 11046 - 11068 S 05/22/96 40.4 3 -3/8" 4 11090 - 11110 S 05/16/91 11032' — 1 20/40 SANDBACK (05/05/96) I 3 -3/8" 4 11120 - 11140 S 05/16/91 3 -3/8" 4 11150 - 11170 S 05/16/91 3 -3/8" 4 11182 - 11202 S 05/16/91 PBTD H 1 1325' 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I 11490' ► ►i�i�iii ii i DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/13/82 ORIGINAL COMPLETION 12/13/10 JRA /PJC FISH CORRECTIONS (10/31/08) WELL: 06 -17 07/08/00 LAST WORKOVER I 02/27/11 KSB /PJC P&A (01/30/11) PERMIT No: `1820900 11/21/08 JKD/TLH PLUG PULL/IBP SET (11/01/08) API No: 50- 029 - 20760 -00 12/04/08 DTR/PJC SLUGGITS (11/26/08) 1 SEC 11, T10N, R14E, 2826.64' FEL & 5240.09' FNL 12/12/08 RRD/PJC JET CUT (11/28/08) 12/13/10 JRA /PJC CMT CAP /SAND CORRECTIONS' BP Exploration (Alaska) Ente xit R - � Z -.11- - J _ 1261' \ j �. It I i ° G / ! a V / - _;'\ \ 275' —J At 0 s 240' -..I 'r 1 • 0 r, A 24 1 \ D 1 I 23 • 111 1 l 16.* s 22 • 1g •..,__ a I ■ 3 \\ , 1dI ■ 1 21 ■ I 14■ L I 1 a 0 i { 20 • 13 • I; 1I . II s si I I ) 11 1s 12 I 11 a I 11 • t h 17 • r — ti +If 7 . 11I I I I 1 ) 11 I I mo_ ..,1 J I I 9 I I I 1 1 iiprt I II. — l ../ L -.......- r7,- _ . .: i 1 ',I I ■(.. 114 P O , i - k llj [ � I r' i j - -- 1 I Enter/ I 495 ❑ / � 1 / � j I 1 Exit `� r _ ❑ ❑ ass I d ! 0 ' �/ ! � / a, V el 1 1 fi, i _,-- ,,_, .4 _, [c .-(1 i (3 I I WELL PRODUCER • or ❑ WELL INJECTOR A DATE : 12/2/2010 SCALE : 1" = 275' MAP DATE : 2010 PBU - DS 6 WELL SLOT W /CONDUCTOR 0 bs14495.mxd • 6& fly 9, 2010 Pad 3 .,‘ lot _::: ...,...............,.. , _ Aimate S cale: 1" =300' 201 pprox 0- 19c -8 -1 AFRO- mfTRIC X . 1 1 -At -\, i I . t "., ., —'� } r f � S J A t C 1 � "` +� ° c am A AO_ . \\ ....... ,,,,,_._.41u, . \\ . ‘,. S, lF1w. ? ` we -:,'., r '-' -, ! ..... - ..1 10 . i,:‘„ i t . - �► -1600 , l { f ;:' (-\ ,.. .. 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' f s y ��rt *��t r ` � ' 4� r+ r ', M yy • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 12, 2011 TO: Jim Regg 4( 131 I( P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 06 -17 FROM: Lou Grimaldi PRUDHOE BAY UNIT 06 -17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 'JP-- NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 06 - 17 API Well Number: 50 029 - 20760 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110306095815 Permit Number: 182 - 090 - Inspection Date: 3/4/2011 - Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 06 -17 IType Inj. N TVD I 8419 IA 370 2520 2570 2560 - P.T.D 1820900 TypeTest I SPT Test psi 2104.75 OA 14 17 17 17 Interval OTHER p/F P - Tubing 400 660 685 690 Notes: Tubing reportedly cemented off (see mitLG110306094506), test of IA for future P &A work. 6.5 pumped and 6.1 returned, good test. A ._l) A-' 1 G`t Tuesday, April 12, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 12, 2011 TO: Jim Regg kICI /�i P.I. Supervisor y 13 ( ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 06 -17 FROM: Lou Grimaldi PRUDHOE BAY UNIT 06 -17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry �'r-- NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 06 -17 API Well Number: 50- 029 - 20760 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110306094506 Permit Number: 182 - 090 - Inspection Date: 3/4/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 06.1 `Type Inj. N -1 TVD 8419 IA 380 490 500 500 P.T.D 1820900 - TypeTest SPT Test psi 2104.75 OA 15 15 — 15 15 Interval OTHER -- pfj` P • Tubing 500 2520 -- 2450 2450 Notes: Tubing reportedly cemented off, test of plug in tubing for future P &A work. 2.75 pumped and returned, good test. Bleed down and rig over to IA for test of backside. - # s 41`'. Tuesday, April 12, 2011 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOP WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development El Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: BP EXPLORATION ALASKA, INC. Aband.: 3/4/2011 •182 -090 310 -425 3. Address: 6. Date Spudded: 13. API Number: PO BOX 196612 ANCHORAGE, AK 99519 -6612 6/17/1982 , 50- 029 - 20760 -00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 3' FNL, 860' FEL, SEC.11, T1ON, R14E, UM 6/30/1982 • PBU 06 -17 Top of Productive Horizon: 8. KB (ft above MSL): 74 15. Field /Pool(s): 4901' FNL, 2642' FEL, SEC.11, T1ON, R14E, UM GL (ft above MSL): PRUDHOE BAY FIELD/ Total Depth: 9. Plug Back Depth(MD +TVD): PRUDHOE BAY OIL POOL 5241' FNL, 2827 FEL, SEC.11, T1ON, R14E, UM 10081 8244 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 686137 y- 5940599 Zone- ASP4 11500 9223 ADL028311 TPI: x- 684480 y- 5935660 Zone- ASP4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 684304 y- 5935315 Zone- ASP4 NONE 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1900' APPROX 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: DIL / BHC / GR / SP, DIL / FDC / CNL / GR / CAL, CBL N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 SURFACE 81' SURFACE 81' 30" 2361# POLESET 13 -3/8" 92# L -80 SURFACE 2502' SURFACE 2502' 17 -1/2" 2032SX FONDU & 400SX PFC 9 -5/8" 47# L -80& SURFACE 10822' SURFACE 8765' 12 -1/4" 500SX CLASS G & 33 BBLS S00 -95 PERMAFROST C 7" 29# L -80 10511' 11490' 8554' 9216' 8 -1/2" 325SX CLASS G 24. Open to production or injection? Yes ❑ No ig If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 5-1/2" 17# L -80 10442 10320 / 8420 4 -1/2" 12.6# N -80 10442 - 10536 10442 / 8506 5$ APR Ks 3 2Oi' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10081' PLUGGED WITH 27 BBLS CLASS G (NEAT) ✓ AND 15 BBLS CLASS G W/ AGGREGATE 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NOT ON PRODUCTION N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate -1.- 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. CE1 ; 0.\ .: '�l RSD MS A P R 01 ,,,( tk 24 COW nso GORE ��"�`' a m Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 74 ...) 5/6 .f! itrnit only C • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 AAC 25.071. Permafrost - Base SADLEROCHIT 10972' 8864' Formation at total depth: 31. List of Attachments: SUMMARY OF DAILY OPERATIONS, WELLBORE SCHEMATIC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: JOE LASTUFKA Printed Na e: JO „ LAST .l Title: DATA MANAGER Signatur -• \ ill( Phone: 564 -4091 Date: 3/31/2011 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. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • • 06 -17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1/29/2011 T /I /O= 80/40/16 Load and Kill (P &A prep). Pumped 3 bbls neat meth and 500 bbls crude down the 1A. Pumped 2 bbls neat meth and 351 bbls crude down the TBG.Capped the TBG w/3 bbls neat meth. Established a TBG injection rate of 5 BPM I© 1350 psi. There was no fluid or leaks from the conductor throughout the job. I* *Wellhead valves left in the following positions: SV, WV & SSV =S /I. MV & IA left (open. DHD in control of OA upon departure. Tag hung. ** FWP's= 350/250/0 1/29/2011 IT /I /0= 80/40/16. Temp =SI. Monitor SC leak (P & A). ALP =Spool piece dropped. Bled OAP & maintained an open bleed throughout Tbg & IA load. No conductor lactivity was noted. Monitored 30 mins, OAP remained the same. 1 ** Job is Complete ** SLB in control of well upon departure. 1/29/2011 T /I /O = 60/0/0. P & A well. PJSM, MIRU, PT Lines. On line with 1% KCL. Pumped l 90 bbls. Continued on WSR dated 1/30/11. 1/30/2011 T /I /0= 60/0/0. Temp= SI. P & A Cellar Watch. AL disconnected. Monitor OAP during pumping operations bleeding as needed. No returns from conductor. Cement crew in charge of valves. 1/30/2011 T /I /O = 620/650/0 P & A Perfs. Continued from WSR dated 1/29/11. Continued pumping 1 % KCL. 360 bbls total. Switched to 10 bbls of Chem Wash, 5 bbls of neat 115.8 • • • class G cement, 15 bbls of 15.8 ppg cement w/15 • •b a• • and 22 bbls of neat 15.8 ppg cement. Flushed Ines with 2 bbls water. Opened up to launch foam ball and pumped 5 bbls of water. Ball launched, displaced with 196 bbls of diesel @ 5.0 bpm then slowed rate to 1 bpm. Pressures started increasing at —210 bbls of diesel away. Treating pressure increased to 840 psi at 225.5 bbls of diesel away. SD and monitored pressures for 20 min. Tubing pressure dropped to 400 psi in 10 min and maintained that pressure for an additional 10 min. Final WHP's = 430/270/0. 2/11/2011 °T /I /O = 800/710/10. Temp = SI. Assist Fullbore (cellar watch). AL is disconnected. 1 2" integral installed on IA. Spotted heater blowing in wellhouse. Bleed tank on location for job. 60" of void in 20" conductor (hard bottom, no fluid present). Job ' postponed. SV, WV = C. SSV, MV = 0.1A, OA = OTG. NOVP. r 2/16/2011 T /I /O = 880/680/20. Temp = SI. Assist Fullbore (cellar watch). AL is disconnected. 2" integral installed on IA. Spotted heater blowing in wellhouse. Bleed tank and Vac truck on location for job. 20" conductor (hard bottom, no fluid present). MIT -T to 2500 psi ** *PASSED" * *. MIT -IA to 2500 psi ** *PASSED * * *, see LRS log. No OAP increase or fluid to surface during wellwork. FWHP= 300/300/20 SV, WV, SSV = C. MV = 0.1A, OA = OTG. NOVP. • • 2/16/2011!T/1/0= 880/680/0 Temp= SI MIT -Tbg PASSED to 2500 psi, MIT -IA PASSED to 25001 s Fpsi (P &A) MIT -T: Pressured up Tbg with 1.8 bbls diesel. Tbg lost 80 psi in 1st 15 !mins and 40 psi in 2nd 15 mins for a total loss of 120 psi in 30 min test. Bled 'pressures back, bled —3.5 bbls diesel. MIT -IA: Pressured up IA with 5.1 bbls diesel. 'IA lost 40 psi in 1st 15 mins and 10 psi in 2nd 15 mins fora total loss of 50 psi in 30 'min test. Bled pressure back, bled aprox 7 bbls diesel. Final WHPs 250/300/0 ISV,WV,SSV= Shut MV,IA,OA= Open 2/21/2011 *WELL S/I ON ARRIVAL* ** DRIFT & TAG W/ 2.50" CENT & S.BLR, TAGGED CEMENT @ 10081' SLM, AOGCC WITNESSED BY J.CRISP RECOVERED GOOD SAMPLE OF CEMENT, RDMO [ ** *WELL S/I ON DEPARTURE * ** mm 3/4/2011' TWO= 500/380/15 Temp. =SI (AOGCC State Witnessed Lou Grimaldi) MIT T PASSED to 2500 psi. / MIT IA PASSED to 2500 psi. (MIT T) Pumped 2.75 bbls of neat meth to reach test pressure. Tubing lost 70 psi. in the 1st 15 min. and no loss l in the 2nd 15 min. for a total loss of 70 psi. in a 30 min. test. Bled back 2.75 bbls. to Istarting pressure. (MIT IA) Pumped 6.35 bbls of neat meth to reach test pressure. IA gained 50 psi. in the 1st 15 min. and lost 10 psi. in the 2nd 15 min. for a total gain of 40 psi. in a 30 min. test. Bled back 6.5 bbls to Final WHP= 420/230/17. 1SV,WV,SSV- closed , MV IA,OA -open. FLUIDS PUMPED BBLS 16 NEAT METH 851 CRUDE 234 DIESEL 360 1% KCL 10 CHEMICAL WASH 27 CLASS G CEMENT (NEAT) 15 CLASS G CEMENT W/ 15 AGG 1513 TOTAL TREE = FMC GEN 3 WELLHEAD = FMC ( SAFETY: WELD. 8 /18/94 PREY K -VLV. * * *5 -1/2" CHROME TBG* ** ACTUATOR = AXELSON 06-1 7 KB. ELEV 74' u k ^ n KOP= 3150' S�SP Max Angle = 50 @ 7100' Datum MD = 10988' I 2170' H 5 -1 /2" H ES X NIP, ID = 4.562" Datum TVD = 8800' SS GAS LIFT MA ST MD TV D EV TYPE VLV LAT PORT DATE 113 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" H 2502' 1 3789 3758 24 CA DMY T - 16 0 5/23/0 5 2 6471 5744 50 CA DMY T -2 16 05/23/05 3 8131 6825 47 CA DMY T -2 16 05/23/05 4 9209 7596 43 CA DMY T -2 28 05/23/05 11111 5 9981 8170 42 CA DMY T -2 0 07/14/00 ► L 10080' H TOP OF CEMENT (01/30/11) I •, ••♦ • Minimum ID = 3.81" @ 10523' . , 10290 -I JET CUT (11/28/08) 1 ►•••• 4-1/2" CA DB-6 NIPPLE _ ► ; • ; • ; • ; • ; 10320' — I9 -5/8" X 5 -1/2" BKR S -3 PKR, ID = 4.75" 1 ► mo t ► • • • • ►.t ••••• ■•••• ■•••• � •�• • 4 10395' 1-15-1/2" HES X NIP, D = 4.562" I 1 �• 5 -1/2" TBG, 17 #, 13CR NSCC, -1 10428' ► • • • • • • • • • I I ••• . 10428' H5 - 1/2" BKRPBRASSY, ID =4.75" .0232 bpf, ID = 4.892" j ► �•� . � � r i 10429' -I 5 -1/2 "MULESHOE, ID = 4.892" I 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 10442' ►••••••• 10442' - 9 -5/8" X 5 -1/2" BKR SAB PKR ►�/ ►•••••X ►mot I / K -22 ANCHOR SEAL NIP, ID = 4.75" 10448 --I" MILLOUT BKR EXTENSION, D = 6.00" i 10455' J-15-1/2" X 4-1/2" XO, ID = 3.958" I 9 -5/8" X 7" BKR LNR HGR 10504' ► • • • • i W/ TIEBACK SLV, ID = ? • ■•• 11 gi 10523' 4 -1/2" CAM DB -6 NIP, ID = 3.81" l ► •�• •1 10535' H4 -112" BKR SHEAROUT SUB I 14 -1 /2" TBG, 12.6 #, N-80, .0152 bpf, ID = 3.958" 1-1 10536' ► i ► 10536' -14 -1/2" TBG TAIL, ID = 3.958" I 1 9 -5/8" CSG, 47 #, L -80 BTC XO TO SOO-95 BTC H 10736 !••••••••••••• ►��, ' �, I 10517' H ELMD TT LOGGED 02/12/83 I ►•••••• 19 -5/8" CSG, 47 #, SOO-95 BTC, ID = 8.681" I 10823' ■ � • •• • • • • � • � • j ►•••••••••�••• PERFORATION SUMMARY ► REF LOG: BHCS ON 07/01/82 ••••••• ••• ►•••••••••••• ,- ANGLE AT TOP PERF: 49 @ 10818' ••••••• ••••••••••••• Note: Refer to Production DB for historical perf data •••••••••••• P • •••••• . SIZE SPF INTERVAL Opn /Sqz DATE ••••••• ••• ►•••••••�••• , I 10969' 1-17" M ARKER JOINT I 3 -3/8" 4 10818 - 10848 0 04/15/95 ••••••• ••• ••••••• 3 -3/8" 6 10974 - 10944 0 08/02/96 j•••4� v 11004' h FISH - BKR IBP & ELEMENT (10/31/08) 1 ►•. • •••` i i _ I 11007' H CEMENT CAP (05/22/96) 1 3 -3/8" 6 10994 - 11036 S 05/22/96 • • �_ 3 -3/8" 4 11046 - 11068 S 05/22/96 -•-•-•-•-•-• 3 -3/8" 4 11090 - 11110 S 05/16/91 Min 11032' -120/40 SANDBACK (05/05/96) 1 3 -3/8" 4 11120 - 11140 S 05/16/91 3 -3/8" 4 11150 - 11170 S 05/16/91 II 3 -3/8" 4 11182 - 11202 S 05/16/91 PBTD I-1 11325' I 11444144 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 11490' ► * � * � * 4 • ►�i�∎ •∎∎ ••�i •t •t. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/13/82 ORIGINAL COMPLETION 12/13/10 JRA /PJC FISH CORRECTIONS (10/31/08) WELL: 06 -17 07/08/00 LAST WORKOVER 02/27/11 KSB /PJC P&A (01/30/11) PERMIT No: '1820900 11/21/08 JKD/TLH PLUG PULL /IBP SET (11/01/08) API No: 50- 029 - 20760 -00 12/04/08 DTR/PJC SLUGGITS (11/26/08) SEC 11, T1ON, R14E, 2826.64' FEL & 5240.09' FNL 12/12/08 RRD /PJC JET CUT (11/28/08) 12/13/10 JRA /PJC CMT CAP /SAND CORRECTIONS BP Exploration (Alaska) WE D SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSI01V ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 ...EM (907) 276 -7542 Josh Alley Petroleum Engineer a 6Y BP Exploration (Alaska) Inc. P.O. Box 196612 UF. ti Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06 -17 Sundry Number: 310 -425 Dear Mr.Alley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 10 - 1/ Z Daniel T. Seamount, Jr. Chair DATED this fsday of December, 2010. Encl. STATE OF ALASKA (, 7 ALASKOL AND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVALS �v 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development [2]. Exploratory ❑ 182 -0900 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20760 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU 06 -17 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO - 028311 PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11500 - 9222.79 - 11444 9184.2 10385 11004 Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" SURFACE 81 SURFACE 81 1490 470 Surface 2502' 13 -3/8" 72# L -80 SURFACE 2502 SURFACE 2502 4930 2670 Intermediate Production 10822' 9-5/8" 47# L -80 SURFACE 10822 1 SURFACE 8765 6870 4760 Liner 979' 7" 10511 11490 8554 9216 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5 -1/2" 17# 13Cr80 23 10428 5 -1/2" 17# L -80 10428 10455 4 -1/2" 12.6# N -80 10455 10536 Packers and SSSV TVDe: 9 -5/8" X 5 -1/2" BAKER S -3 PKR Packers and SSSV MD and ND (ft): 10320 8420 9 -5/8" X 5 -1/2" BAKERr SAB PKR 10443 8506 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/28/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended - ❑� 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josh Alley Printed Name Josh Alley Title PE Signature Phone Date 564 -5732 12/14/2010 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O Plu Inta�d ]� BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ C 'V "D Other: DEC 1 4 2010 GaS Cons. C011M1NSSI L/ A nchorage Subsequent Form Required: / Q '— / APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: 2 S MS DEC 17 � - =�s�o ORIGI Form 10-403 Revised 1/2010 /" Submit in Duplicate i 06 -17 182 -090 PERF ATTACHMENT - Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06 -17 2/12/83 PER 11,090. 11,110. 8,942.49 8,955.96 06 -17 2/12/83 PER 11,120. 11,140. 8,962.7 8,976.19 06 -17 2/12/83 PER 11,150. 11,170. 8,982.95 8,996.48 06 -17 2/12/83 PER 11,182. 11,202. 9,004.6 9,018.16 06 -17 9/25/87 APF 10,818. 10,848. 8,762.09 8,781.89 06 -17 9/25/87 APF 11,018. 11,038. 8,894.24 8,907.61 06 -17 9/25/87 APF 11,048. 11,068. 8,914.3 8,927.71 06 -17 3/29/91 SQZ 11,188. 11,202. 9,008.67 9,018.16 06 -17 5/12/91 SQZ 11,151. 11,188. 8,983.62 9,008.67 06 -17 5/16/91 SPS 11,090. 11,151. 8,942.49 8,983.62 06 -17 5/20/91 APF 11,016. 11,038. 8,892.91 8,907.61 06 -17 5/20/91 APF 11,046. 11,068. 8,912.96 8,927.71 06 -17 4/25/93 APF 10,973. 10,993. 8,864.28 8,877.58 • 06 -17 9/4/93 APF 10,973. 11,006. 8,864.28 8,886.24 06 -17 4/15/95 RPF 10,818. 10,848. 8,762.09 8,781.89 06 -17 8/12/95 SPS 10,892. 11,068. 8,810.85 8,927.71 06 -17 9/2/95 SPR 10,892. 10,965. 8,810.85 8,858.98 06 -17 9/16195 BPS 10,900. 11,057. 8,816.1 8,920.33 06 -17 10/4/95 BPP 10,900. 11,057. 8,816.1 8,920.33 06 -17 12/10/95 SPR 10,965. 11,068. 8,858.98 8,927.71 06 -17 2/6/96 RPF 10,973. 11,016. 8,864.28 8,892.91 06 -17 5/6/96 SPS 11,030. 11,068. 8,902.26 8,927.71 06 -17 5/22/96 SQZ 10,973. 11,032. 8,864.28 8,903.6 06 -17 8/2/96 APF 10,974. 10,994. 8,864.95 8,878.24 06 -17 5/15/04 BPS 10,370. 10,380. 8,455.32 8,462.42 06 -17 5/22/05 BPP 10,370. 10,380. 8,455.32 8,462.42 06 -17 6/23/05 BPS 10,376. 10,386. 8,459.58 8,466.68 06 -17 6/26/05 BPP 10,376. 10,386. 8,459.58 8,466.68 06 -17 6/27/05 BPS 10,385. 10,395. 8,465.97 8,473.05 06 -17 11/24/08 SPS 10,617. 10,818. 8,626.79 8,762.09 06 -17 11/25/08 SPS 10,617. 10,818. 8,626.79 8,762.09 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH IOPEN HOLE To: Alaska Oil & Gas Conservation Commission O b p From: Josh Allel y Wells Group Engineer BP Alaska Date: December 14, 2010 Re: PBU 06 -17 Sundry Approval Sundry approval to suspend well 06 -17 is requested. 06 -17 is a well that is exhibiting TxIAxOA communication with a potential surface casing leak. This well is currently not secured with a mechanical plug. It is our desire to secure the well with a more permanent cement plug. Our current plan is to cover the existing perforations with cement leaving the top of cement a minimum of 10666' ft MD to comply with our internal zonal isolation requirements. Given the volume of excess cement we are pumping, it is very likely that the cement top will be much higher, likely into the 5 -1/2" tubing. Further work with slickline and pumping operations will confirm the actual top, of cement and plug integrity. This work will place the well in a suspended state. Well Information Status: Non Operable Artificial Lift Producer Last Well Test 05/11/2004 Typical Production Rate: 6200 bfpd, 6.8 mmscfpd, 95% WC at 320 psi WHP and 174F WHT. Max Deviation: 50deg at 7100' and Perf Deviation: 49deg at 10818' md. Min. ID: 3.81" CAMCO DB -6 Nipple Last TD tag: 12/18/08: tag IBP[TD] with 3.125" cent and 2.5" LIB at 11004 slmd. Last Downhole Ops: 12/18/08: LDL and TD tag. SIBHP / SIBHT No survey since 1998. Assuming 3200 psi. Latest 1-12S level: 05/02/04: 30 ppm. Ann Comm Status: TxIAxOA x Surface Casing; Not Operable Die fio Flo COICA?'1101 pe 'r0 `✓lu �� yecv <t • • The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed cement plug is attached for reference. Planned Work: 1. FB F ll u bore cement job with minimum TOC at 10666 ' MD J 40 bbls of 15.8 ppg class G cement. 2. SL Drift and tag to confirm TOC. 3. FB Pressure test cement to 3000 psi. Pressure test casing to 3000 psi. Josh Allely Wells Group Engineer 564 -5732 (w) 350 -7362 (c) Dan Kara Wells Group Engineering Team Lead 564 -5667 (w) 240 -8047 (c) TREE= FMCGE 3 SAFETY NOTES: WELD. 8118194 PREY K -VLV. WELLH =_ _ FMC CAKYYtv1{ 5cl.cw1A i� 0 1 ** *5.112 "CHROMETSW ** ACTUATOR= AXELSON ■ KB. El-EV = 74' ws of IZ ly'to 10 BF. ELEV = ? KOP= 3150' Max Angle = 50 @ 7100' Dalum MD = 10988' 2170' -j 5-1/2" HES X NBA, ID Datum TVD = 8800' SS GAS LIFT MANDRELS — JA 13 -3/8" CSG, 72#, L -80 BTC, ID= 12.347" 2502' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3789 3758 24 CA DMY T -2 16 05/23/05 2 6471 5744 50 CA DMY T -2 16 05/23/05 3 8131 6825 47 CA DMY T -2 16 05/23/05 4 9209 7596 43 CA DMY T-2 28 05/23/05 5 9981 8170 42 CA DMY T 2 0 07/14!00 Minimum ID = 3.81" @ 10523' 10290' JET CUT (11/28/08) 4-1/2" CA DB-6 NIPPLE 10320' 9 -5/8' x 5-1/2^ BKR S 3 PKR D =4.75 10395' 5-112" HES X NB', � = 4.562" 5 - 112" TBG, 17#, 13CR NSCC, 10428 10428' 5 -112" BKR PBR ASSY, O = 4.75" I .0232 bpf, ® = 4.892" 10429' 5- 1/2"MLLESHOE, D= 4.892" 5 -1/2" TBG, 17 #, L-80-0232 bpf, ID = 4.892" H 16442' 10442' 9-518"X 5.1/2" BKR SAS PKR w 1 K -22 ANCHOR SEAL NIP ID = 4. 75" 10448' 7" MILLOUT BKR EXTENSION, O = 6.00" 10455' 5-1/2" X 4 -1/2" XO, 9-518" X 7` BKR LNR HGR 10504' w / TIEBACK SLV, ID = ? 10523 — �4 -1/2" CAM DB-6 NP ID = TT 4 -1/2" TBG, 12.5, N-80, .0152 bpf, Q = 3.958` 10536' 10535' 4 - 1/2" BKR SHEAROUT SUB 10536' 4 -112" TBG TAL, O = 3.958" 9 -518" CSG, 47 #, L-80 BTC XO TO SOO 95 BTC 10736' 1051 r ELMD rr LOGGED 02112/83, 9-516" CSG, 47 #, SOO-95 BTC, ID = 8.681" 10823' PERFORATION SUMMARY REF LOG: BRCS ON 07/01/82 ANGLE AT TOP PERF: 49 @ 10818' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3-318" 4 10818-10848 O 04/15195 10969' 7" MARKER JOIPIT 3-318" 6 10974 - 10944 O 08/02/96 11004' FISH- BKR B LEMENT (10131108) P& E 3-318" 6 10994 -11036 S 05/22196 11007' ETCE uENT CAP (05/22/96) 3-318" 4 11046-11068 S 05/22196 3-3/8" 4 11090 -11110 S 05/16/91 11032 20/40 SANDBACK (05105/96) 3-318" 4 11120 -11140 S 05/16/91 3-3/8" 4 11150 - 11170 S 05/16/91 3-3/8" 4 11182.11202 S 05116/91 PBTD 11325' 7" LNR, 29#, L -80, .0371 bpf, ID = 6.184 11490' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07M3/82 ORIGINAL COMPLETION 11/21/08 JKD/TLH PLUG PULLIBPSET(11101108) WELL: 06-17 07/08/00 LAST WORKOVER 12/04/08 DTR/PJC SLUGGITS(11/26108) PERMIT No: r 1820900 05!17105 MGS/PJC FISH CORRECTION 12112108 RRD/PJC JET CUT (11 /28108) API No: 50- 029 - 20760 -00 09123/05 MOR(ILH PX TTP SET (06/27105) 12113/10 JRA/PJC CMT CAP/SAND CORRECTIONS SEC 11, T10N, R14E, 2826.64' FEL & 5240.09' FNL 11/20/07 KSB/PJC GLV CIO (05/23/05) 12113110 JRA/PJC FISH CORRECTIONS (10/31108) 11/26/07 1 AMSIPJCI DRAWING CORRECTIONS BP Exploration (Alaska) Attachment 1. Current Wellbore Schematic as of 12114/2010 TREE = FMC GEN 3 SAFETY NOTES: WELD. 8118/94 PREY K -VLV. WELLHEAD= FMC �ropoeec� sctnewRd t 06-1 — 5-1/2" CHROME TB(r" ACTUATOR= AXELSON KB.ELEV = 74' BF. ELEV = ? KOP = 3150' Max Angle = 50 @ 7100' Datum MD = 10988' 2170' 5 112" HES X NIP, ID = 4.562" Datum TVD = 8800' SS GAS LIFT MANDRELS 13 -3/8" CSG, 72#, L -80 BTC, D = 12.347" 2502' ST MD TVD DEV TYPEI VLV LATCH PORT DATE 1 3789 3758 24 CA LDMY T -2 16 05/23/05 2 6471 5744 50 CA T -2 16 05/23/05 3 8131 6825 47 CA T -2 16 05123105 4 9209 7596 43 CA T -2 28 05123105 5 9981 8170 42 CA T -2 0 07/14/00 Minimum ID = 3.81" @ 10523' 10290' — [JET CUT (11 /28108) 4 -1/2" CA DB-6 NIPPLE 10320' 9 -5/8" x 5-1/2" BKR S-3 PKR, ID =4.75 10395 5-1/2' HES X NP, D = 4.562" 5- 112" TBG, 17 #, 13CR NSCC, 10428' A1042 5-1/2" BKR PBR ASSY, D = 4.75" .0232 bpf, ID = 4,892" 5 -112" TBG, 17 #, L -80, . PK 0232 bpf, 0 = 4.892" 10442' S- 1 /2 "MULESHOE, D = 4.892 ", 9-5/8" X 5 -1/2" BKR SAB R w / K -22 ANC SEAL N P, ID = 4.75" 7" MILLOUT BKR DCTENSION, ID = 6.00" 5- 112" X 4 -112" XO 9-5/8" X 7" BKR LNR HGR w / TIEBACK SLV, ID 4 -112" CAM DB-6 NP, D = 3.81" 4 -1 /2" TBG, 12.6#, N 80, .0152 bpf, D = 3.958" 36 105— I - 1/2" BKR SHEAROUT SUB 9 CSG, 47 #, L - 80 BTC XO TO SO O 95 BTC 10736' 10536' 4 - 1/2" TBG TAIL, D - 3.958" 1051 T EL T T LOGG® 02!12!83 9 -5/8" CSG, 47 #, S00695 BTC, D PERFORATION SUMMARY 1p6 M`h'►^ 4oP oR C E�+t Y1�' REF LOG: BRCS ON 07/01/82 ANGLE AT TOP PERF: 49 @ 10818' Note: Refer to Production DB for historical perf data r SIZE SPF INTERVAL Opn /Sqz DATE 3-3/8" 4 10818 - 10848 O 04/15/95 10969' 7" MARKER JOINT 3 -3/8" 6 10974 -10944 O 08/02196 11004 FISH - BKR IBP & ELEMENT (10/31108) 3-3/8" 6 10994- 11036 S 05/22/96 1100T CEMENT CAP (05122/96) 3-3/8" 4 11046 - 11068 S 05/22/96 3-318" 4 11090 -11110 S 05/16/91 11032 20140 SANDBACK (05/05/96) 3-318" 4 11120 -11140 S 05/16/91 3 -3 /8" 4 11150 -11170 S 05/16191 3 -318" 4 11182 -11202 S 05/16/91 PBTD 11325' 7" LNR, 29#, L-80_0371 bpf, ID = 6.184 11490' DATE REV BY COMMEMS DATE REV BY COMMENTS PRUDHOE SAY UNIT 07113/82 ORIGINAL COMPLETION 11/21/08 JKDIILH PLUG PULLIEP SET (11101108) WELL: 06-17 07/08/00 LAST WORKOVER 12104/08 DTR/PJC SLUGGITS (11/26/08) PERMIT No: x 1820900 05117105 MGS/PJC FISH CORRECTION 12/12/08 RRD/PJC JET CUT (11/28108) API No: 50- 029 - 20760 -00 09/23/05 MOR/TLH PX TTP SET (06127/05) 12/13/10 JRA /PJC CMT CAPISAND CORRECTIONS SEC 11, T10N, R14E, 2826.64' FEL & 5240.09'M 11/20/07 KSB /PJC GLV C/O (05123/05) 12/13/10 JRA/PJC FISH CORRECTIONS (10131108) rl — 1/2 - 6/0 - 77 — MSIPJC1 DRAWING CORRECTIONS 771 BP Exploration (Alaska) Attachment 2. Proposed Wellbore Schematic after pumping cement into existing perforations. • VV~~L ~~~ --_--° :, . ,. ProActive Diagnostic Services, Inc. To: ACC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 ~ (907) 793-1225 RE : Cased Hole/Open Hole/ Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907] 245-8952 .~~. ~. V ~c ~ fib- ~3C~ l x-33 ~ ~2 ~ t ~ 33 1) Leak Detection -WLD 18-Dec-08 06-17 2) Leak Detection -WLD 19-Dec-08 W-~4~2 Signed Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. IN7ERNATiONAL AIRPORT RD SUfTE C, ANCHORAGE, AK 99518 PHONE: (807)245-8951 FAX: (907)2458952 E-MAIL.: ~dsan~h®rac~e(~rr~erraory9og.~s~m WEBSITE : =,vw~v.rrfemorylo 1 Color Log / EDE 50-029-20760-00 1 Color Log / EDE 50-029-20533-00 Date : _ .' C:\Documeftt, azul Settings\OwnerlDesktop\Transmit_BP.docx 11 /04/08 ~~~I~mb~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wt±ll .Inh it ., ~. ~ ;,, tR rtn~~~ ~wiii~i~~~'i.~.ar/ ~'~' ~ 4 ~ t,{~iS1id r .... n..~.. ..•:..., N0.4952 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 D-29 12103692 USIT f 10/19/08 -- - iv. 1 13-16 12103694 INJECTION PROFILE (REVISED) / 10/20/08 1 1 13-19 12103695 INJECTION PROFILE -t 10/21/08 1 1 03-04 12031526 INJECTION PROFILE 10/22/08 1 1 J-08A 12031514 CBL p~_ ~2' ( 09/20/08 1 1 06-17 11970850 PRODUCTION LOG ~ f (p~ 10/30/OS 1 1 01-33 11999052 RST ~ 10/10/08 1 1 1-4510-26 12096920 LDL '-~-. ~ 10/10/08 1 1 3-05/0-29 12083416 MEM LDL ~ ~~. 10/24/08 1 1 L-116 11999055 USIT b- f ~ /' a 10/31/08 1 1 DI CACC A/~VAI/1\Illl C __. ___..~._.-~..~~~~.~..~~~.. r. v.~w.....M r+.~v ..r. v..,~..~v v.~C VVr1 GMIi II IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ,~,i: ?iji~~~; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99 03-283 ATTN: Beth Received by: ----~"" • • • • ~,...,.~ ~..! L.I ~J L.E ~. ~ ~~ r7k. i ~ ~~ ~~-~ ~~~ ~ ~~~~ ~~~~ ~~~ ~ ~~~ SARAH PAUN, GOVERNOR t~a,a.~c>.-7I~A OII, A1~TD GAS 1 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA`i`IO1~T COMhIISSIOI~T /// ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 David Reem f FAX (907) 276-7542 Engineering Team Leader BP Exploration Alaska Inc. ~,;~,.~~ ~~, ~ ,~;,, ~ ~. PO Box 196612 }```"~"'~`~' 4 `` ` ~` e ~~~ d Anchorage, AK 99519-6612 , ~a ~. Re: Prudhoe Bay Field, Prudhoe Bay Oil Fool, PBU 06-17 Sundry Number: 308-399 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ,-~ Daniel T. Seamount, Jr. Chair DATED this ~ ~" day of November, 2008 Encl. STATE OF ALASKA ~ i\ •,~ ~ ~ ~ Q~ ~~ A IL AND A N RVATI N M ION ~ ~ ~,b ~ O G S CO SE O CO i ~~ l APPLICATI N F N RY APPROVA l O OR SU D L ., 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing , ®Repair Well- ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 182-090 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20760-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 06-17 - Spacing Exception Required? ^ Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~3 ~ ~ ADL028311- 74' - Prudhoe Bay Field / Prudhoe Bay Pool 12- PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11500 - 9223' - 11325' 9102' 10395' 10795' in n iz D ur r ' rf / " 4 7 rm i Pr i ' L'n r 7" 4 1 1 7 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq 10818' - 10944' Below Pluq 8762' - 8845' 5-1/2", 17# x 41/2", 12.6# 13Cr / L-80 10536' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker S-3 Packer Packers and SSSV MD (ft): 10320' 9-5/8" x 5-1/2" Baker SAB Packer 10442' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: December 7, 2008 ®Oil - ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 564-5683 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number. Sondra Stewman, 564-4750 Signature Phone 564-5743 Date 1~ ;f tSg Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness c ^ Plug Integrity ~~.BOP Test ^ Mechanical Integrity Test ^ Location Clearance J ~ S /f ~ _~~ Other: ?~~~ ~S , ~® Subsequent Form Re wired: ~..,~'~ ~: APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised O~r12006 Submit In Duplicate `~ ~ ~ ~' I ~ A L ~~ ~~ ~~~~ ~ ~ zoos I ° [ t • by c,~,y 06-17 Expense Rig Workover Scope of Work: Pull 5-~/z" 13Cr-80 completion, cut and pull 9-5/8" casing, run and cement to 9-5/8" surface casing, test 9-5/8" casing, run 5-1/2" 13Cr80 "stacker-packer" completion. MASP: 2420 psi Well Type: Producer Estimated Start Date: Production Engineer: Intervention Engineer: December 07, 2008 James Dean David Bjork Pre-Rig Work Request: S 1 Drift tubing for 5-1/2" Power Jet cut. Pull 4.56" PX plug from 10395'. Drift wellbore for 3-3/8" IBP to 10,650' otential 3.37" restriction 10,471 . E 2 Set 3-3/8" IBP at 10,650' F 3 Fluid- ack wellbore and CMIT TxIA to 3500 si, record LLR as necessar . S 4 Dum 20' of Slu its on to of IBP at 10,650'. E 5 Power Jet cut 5-'/z" 13Cr-80 tubing at 10,290' MD, in the middle of the first full joint above the acker. Reference tubin tall dated 7/04/2000. F 6 Circulate well with 8.6 seawater and freeze rotect to 2000'. MIT-OA to 2000 si W 7 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 8 Set a BPV in the tubin han er. O 9 Verify that the well has a competent cellar. Add spray in liner for secondary containment. Remove the wellhouse & flow line. Level the ad as needed for the ri . Proaosed Procedure 1. MIRU. ND tree. NU BOPE with 3-'/z" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-'/z" tubing string to the cut. 3. Run USIT log to determine top of cement in 9 5/s" x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be changed to 9-5/8" as the well has two tested barriers (IBP and RBP) to the reservoir. 6. Run and fully cement new 9-5/8" casing to surface. 7. Retrieve bridge plug. 8. Run 5-'/z" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 10200' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test tubing and IA to 3500 psi. Freeze protect to 2000' MD. 11. Set BPV. ND BOPE. NU and test tree. RDMO. TREE _ FMC GEN 3 'WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = ? KOP = 3150' Max Angle = 50 @ 7100' Datum MD = 10988' Datum ND = 8800' SS O 6 ~ ~ 7 ~5-1 /2" CHROME g(~ $18/94 PREY K-VLV. i 2170' (~ 5-1 /2" HF~ X NIP, ID = 4.562" 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" I-I 2502' Minimum ID = 3.81" @ 10523' 4-112" CA DB-6 NIPPLE 10395' -{5-1/2" HF~ X NIP, ID = 4.562" 10395' 5-1/2" PX TTP (06/27/05) 5-1/2" TBG, 17#, 13CR NSCC, .0232 bpf, ID = 4.892" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 9-5/8" X 7" BKR LNR HGR - j 10504, w /TIEBACK SLV, ID - ~ 4-1/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 10536' 9-5/8" CSG, 47#, L-80 BTC XO TO SOO-95 BTC 10736' 9-5/8" CSG, 47#, SOO-95 BTC, ID = 8.681" x$23' PERFORATION SUMMARY REF LOG: BHCS ON 07/01/82 A NGLE AT TOP PERF: 49 @ 10818' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10818 - 10848 C 04/15/95 3-3/8" 6 10974 - 10944 C 08/02/96 3-3/8" 6 10994 - 11036 S 05/22/96 3-3/8" 4 11046 - 11068 S 05/22/96 3-3/8" 4 11090 - 11110 S 05/16/91 3-3/8" 4 11120 - 11140 S 05/16/91 3-3/8" 4 11150 - 11170 S 05/16/91 3-3/8" 4 11182 - 11202 S 05/16/91 GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3789 3758 24 CA DMY T-2 16 05/23/05 2 6471 5744 50 CA DMY T-2 16 05/23/05 3 8131 6825 47 CA DMY T-2 16 05/23/05 4 9209 7596 43 CA DMY T-2 28 05/23/05 5 9981 8170 42 CA DMY T-2 0 07/14/00 9-5/8" X 5-1 /2" BKR S-3 PKR, ID = 4.75" 10428' -~ 5-1 /2" BKR PBR ASSY, ID = 4.75" 10429' 5-1 /2"MULESHOE, ID = 4.892" 10442' 9-5/8" X 5-1/2" BKR SAB PKR w / K-22 ANCHOR SEAL NIP, ID = 4.75" 10448' 7" MILLOUT BKR IXTENSION, ID = 6.00" 10455' 5-1/2" X 4-1/2" XO, ID = 3.958" 10523' 4-1/2" CAM DB-6 NIP, ID = 3.81" 10535' 4-1/2"BKRSHEA ROUT SUB 10536' 4-1/2" TBG TAIL, ID = 3.958" 10517' ELMD TT LOGGED 02/12/83 10795' SLM I-I FISH - IBP ELEMENT 10969' I~ 7° MARKER JOINT I PBTD I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~-j 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/13/82 ORIGINAL COMPLETION 07/08/00 LAST WORKOVER 05/17/05 MGS/PJC FISH CORRECTION 09/23/05 MOR/TLH PX TTP SET (06127/05) 11/20/07 KSB/PJC GLV GO (05/23/05) 11/26/07 AMS/PJC DRAWING CORRECTIONS PRUDHOE BAY UNff WELL: 06-17 PERMff No: 1820900 API No: 50-029-20760-00 SEC 11, T10N, R14E, 2826.64' FEL & 5240.09' FNL BP Exploration (Alaska) TREE = FMC GEN 3 WELLHHAl7= FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = ~ KOP = 3150' Max An le = 50 7100' Datum MD = 10988' Datum TV D = 8800' SS ~6-17 NOTES: WELD. 8/18/94 PREYK-VLV. Proposed -1 /2" CHROME TBG** Surface OA Cemented to Surface 2000' S-1/2" HES X NIP, ID = 4.562" 9-5/8" x 13-3/8" CSG, ECP -2380' 9-5/8" Casing Patch 2400' / 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 2502' / Minimum ID = 3.81" @ 10523' 4-1 /2" CA DB-6 NIPPLE 5-1/2"TBG, 17#, 13CR VamTopHC, 10290' .0232 bpf, ID = 4.892" 5-1/2" TBG, 17#, 13CR NSCC, 10428' .0232 bpf, ID = 4.892" 9-5/8" X 7" BKR LNR HGR 10504' w /TIEBACK SLV, ID = ? 4-1/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 10536' 9-5/8" CSG, 47#, L-80 BTC XO TO SOO-95 BTC 10736' 9-5/8" CSG, 47#, SOO-95 BTC, ID = 8.681" 10823' PERFORATION SUMMARY REF LOG: BHCS ON 07/01 /82 ANGLE AT TOP PERF: 49 @ 10818' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3l8" 4 10818 - 10848 C 04/15/95 3-3/8" 6 10974 - 10944 C 08/02/96 3-3/8" 6 10994 - 11036 S 05/22/96 3-3/8" 4 11046 - 11068 S 05/22/96 3-3/8" 4 11090 - 11110 S 05/16/91 3-3/8" 4 11120 - 11140 S 05/16!91 3-3/8" 4 11150 - 11170 S 05/16/91 3-3/8" 4 11182 - 11202 S 05/16/91 /" LNK, Z9#, L-80, .0371 bpf, ID = 6.184" 11490' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3726 3699 23 MMG DCK 3 6791 5950 50 MMG DMY 2 8941 7399 43 MMG DMY 1 10135 8285 42 MMG DMY 10195' 5-1 /2" HES X NIP, ID = 4.562" / 10205' 9-5/8"x 5-1/2" BAKER S-3 PKR 10230' 10442' 9-5/8" X 5-1/2" BKR SAB PKR w/ K-22 ANCHOR SEAL NIP, ID = 4.75" 5-1/2" HES X NIP, ID = 4.562" 9-5/8" X 5-1/2" UNIQUE 10290' OVERSHOT 10320' 9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4.75" 10395' 5-1/2" HES X NIP, ID = 4.562" 10429' 5-1/2"MULESHOE, ID = 4.892" - 10428' S-1 /2" BKR PBR ASSY, ID = 4.75" 10448' 7" MILLOUT BKR EXTENSION, ID = 6.00" 10523' I~4-1/2" CAM DB-6 NIP, ID = 3.81" 10535' 4-1/2" BKR SHEAROUT SUB 10517' ELMD TT LOGGED 02/12/83 I FISH - IBP ELEMENT I PBTD 17" MARKERJOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 07/13/82 ORIGINAL COMPLETION 07/08/00 LAST WORKOVER 05/17/05 MGSlPJC FISH CORRECTION 09/23/05 MOR/TLH PX TTP SET (06/27/05) 11/20/07 KSB/PJC GLV GO (05/23!05) 11/26/07 AMS/PJC DRAWING CORRECTIONS PRUDHOE BAY UNff WELL: 06-17 PERMIT No: 1820900 API No: 50-029-20760-00 SEC 11, T10N, R14E, 2826.64' FEL & 5240.09' FNL BP Exploration (Alaska) 06-17 RWO (4ES) permit # 1820900 Maunder, Thomas E (DOA) From: Bjork, David (Northern Solutions) [David.Bjork@bp.comJ Sent: Monday, November 10, 2008 9:50 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C; Hubble, Terrie L Subject: 06-17 RWO (4ES) permit # 1820900 Mr. Maunder, The 3-3/8" IBP set at 10,650' MD will be pulled post RWO. Regards, Dave Page 1 of 1 11/10/2008 @1J"f8\1JfE ~ rE ® nm\ ~' cW;W· u: UVu Lf~L6u\JæJl AI4ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI. GOVERNOR Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27&7542 . ^¡"'°9° \<ßð Re: PBU 06-17 Sundry Number: 305-380 (;:ò{{' t:,\«.~¡¡,,~~r¡ ø\oi\1'",Ut;rt:c#. .' CJi. 1 (,:; -' Dear Ms. Julian: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, n Ch DATED thislå day of December, 2005 EncL 20 MC 25.280 ¡ aSKa UH Û! bas Com; Cnmnù 1. Type of Request: Abandon U Suspend D Operational shutdown U Perforate U WaiverQ Anchorag~ther U Alter casing D Repair well [] Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developm ent ø / Exploratory 0 182-0900 ,/ 3. Address: P.O. Box 196612 Stratig raphic 0 Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-20760-00-00 / 7. KB Elevation (ft): 9, Well Name and Number: 74 KB 06-17 / 8. Property Designation: 10, Field/Pools(s): ADL-028311 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): ¡Effective Depth MD (ft): Effective Depth TVD (ft): I Plugs (measured): \JUnk (measured): 11500 9222.79 11444 9184.2 10395 IT 10776 Casing Length Size MD / TVD Burst Collapse Structural Conductor 80 20" 94# H-40 30 110 30 110 1530 520 Surface 2473 13-3/8" 72# L -80 29 2502 29 2502 4930 2670 Intermediate Production 10794 9-5/8" 47# L -80 28 10822 28 8765 6870 4760 Liner 986 7" 29# L-80 10504 11490 8549.11 9216 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10818 - 10944 Closed 8762.09-8845.08 Closed 5-1/2" 17# 13cr80/L -80 23 - 10455 10994-11202 Sqz'd 8878,24-9018.16 Sqz'd 4-1/2" 12.6# N-80 10455 - 10536 Packers and SSSV Type: 5-1/2" Baker S-3 Packer Packers and SSSV MD (ft): 10320 5-1/2" Baker SAB Packer 10443 / 12. Attachments: Descrictive Summary of Proposal 0 13, Well Class after proposed work: Detailed Operations Program ø BOP Sketch 0 Exploratory 0 Development ø / Service 0 14. Estimated Date for 12/flo05 15, Well Status after proposed work: Commencing Operations: Oil ø Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: V>(. Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Prepared by Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Jennifer Julian Printed N~a() Jennife;...¡ uliqlil Title Wells Engineer Signature . J... I 1) '--- Phone 564-5663 Date 12/9/2005 U V U COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: ðJS - (2.0..() Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: R8DMS 8Ft DEC 1 4 2005 :::~ðA~40+' APPROVED BY Date: j" ,. /t>, OJ _ . II C'(MMISSIONER THE COMMISSION \",;'" ~~( \.$1 G1\\JAL Form 10-403 Revis /2005 Submit in Duplicate STATE OF ALASKA CP:f 1Z,,;Ji-ð5''Wf!:tET,,gf)Ð\ ALASKA OIL AND GAS CONSERVATION COMMISSION ~h I <,'1 ~t:..c,t: .1 2 2005 APPLICATION FOR SUNDRY APPROVAL G/Ô I ssion bp ... ,\1'.'''. -....~ ~..- ~..,- ~..,- ".'\: -F.... .J'.'_\- ". To: J. Bixby/D. Cismoski, GPB Well Ops TL NSU, ADW Well Operations Supervisor Date: Janua.O~~05 !;/7 -. From: Jennifer Julian, Design Engineer Subject: 06-17 Packer SQueeze AFE PBJD09020 Est. Cost: $250 M lOR: 300 BOPD Please perform the attached packer squeeze procedure. This procedure includes the following steps: Step Type Procedure 1 S Pull TTP. DGL V's. Caliper. Drift for tubing punch/Fas Drill plug 2 C Shoot circ holes, Set Fas Drill plug. Perform packer squeeze. 3 S WOC 2 days. MIT IA. Slick line drift. Run LGLV 4 C Mill cement & plug. 5 S Run DGLV. MIT-IA. Run generic GL V design Max Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: 50 @ 7100' 3.81" @ 10523' 4-1/2" nipple 1 0839' on 7/18/00 LDL 11/11/04 30 ppm on 5/2/04 The primary purpose of this packer squeeze is to repair a confirmed production casing leak near the production packer (LDL run 11/11/04). Perfs will be protected with a Halliburton composite Fas Drill plug in the tailpipe. A cement plug will be left in the tubing to prevent possible U-tubing of cement back into the well bore. After WOC the cement and composite plug will be milled up, the IA will be pressure tested, and the well will be brought back on line. If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W)564-5663, (H)274-0929, (Cell)240-8037. cc: w/a: Well File A. Yancey J. Julian North Slope Distribution w/o: S. Rossberg Page 1 of 9 6-17 Packer Squeeze 5-1/2" tubing TOC at -10100' Shoot Circ holes at 10290-10295' DD packerat10320'DD PBR w/o seals packerat10443'DD 5-1/2" x 4-1/2" crossover a 10455' DD 4.5" XN Nipple at 10523' DD 4.5" TT at 10536' DD 7" liner - LEAK in production casing Fas Drill Composite Plug set @ 10530' DD Cement Volume in Tubina (10455-10100') * .0232=8.2 (10530-10455') * .0152=1.1 9.3 bbls Cement Volume in Annulus (10320-10100') * .0438= 9.6 9.6 bbls Total Cement to Pump 9.3 + 9.6 = 19 bbls total 2 6-17 Packer Squeeze SQueeze Taraet Place cement in the tubing by IA annulus to repair confirmed leak in 9-5/8" PC near packer. LLR through leak in 9-5/8" PC near packer is at .4 bpm at 3000# during LOL on 11/10/04 (with TTP in hole) MIT-T passed on 5/15/04 / MIT-OA passed 7/14/04 IA volume to packer is 452 bbls Tubing volume to composite plug to be set at 10530'00 is 243 bbls Pre-SQueeze Slickline 1. RU SL. Pull TTP. 2. C/O GLV's to OGLV's 3. Drift tbg for Halliburton Fas Drill plug and tubing punch (Fas Drill to be set at 10530' DO. 4. Run caliper (this will ensure that tailpipe is in good enough condition to set Halliburton Fas Drill plug. 5. Shoot fluid levels on IA and tubing. CTU Tie in/Set Fas Drill plua/Shoot Circ holes/SQueeze NOTE: Prior to rigging up, contact WOE to verify plug setting depth based on caliper results from above. It is important that the IA is liquid packed with crude during the squeeze. Shortly before the squeeze, shoot a fluid level on the IA to see if the annulus is liquid packed. If a significant gas bubble is present, it may be necessary to load. 6. RU CT and squeeze equipment. NOTE: Rig up surface equipment to allow returns from both the 9-5/8" and the CTlTbg annulus. 7. PT & RIH with Memory Gamma Ray, flag pipe and correct to tubing tally- attached. POOH. 8. Pick up Halliburton 4-1/2" Fas Drill plug (or Weatherford Fracguard Plug) and set at 10530'. POOH. 3 6-17 Packer Squeeze 9. RIH wI CT conveyed perf gun. Per G. Elmore, use pump-through swivel above the firing head and a bowspring on bottom of gun. Tag Fas Drill plug. Correct depth. 10. Shoot squeeze holes from 10290' - 10295' (reference driller's depths) wI tubing ;/' puncher, 4 SPF, 0 degree phasing, Orient to shoot highside. Tubing to perforate is5Yz",17#. 11. Pump down tubing and up IA to confirm circulation through circ holes by opening up returns from the lA, holding 100-200# backpressure. Confirm 1-for-1 returns to a 40 bbl open-top tank. Perform CMIT-TxIA to 2000 psi. It is likely that the CMIT will fail and this will confirm that the well has a production casing leak at - ./ 10320'. If the CMIT passes, this indicates that the packer at 10320' is leaking (the well had a failed CMIT when the TTP was set at 10395). There will be no change in the cement procedure below for either case. SD CT pump. SI IA. POOH. 12. RIH with cementing nozzle (no checks). Tag Fas Drill plug. Pick-up until full string weight is observed. Correct depth to top of Fas Drill plug. PUH 10' and flag pipe. PUH & park coil at 10100'. 13. Batch mix 19 pumpable bbls LARC cement to meet the following specifications. / (Use current BP liner blend, per Dowell Lab) Volume to Pump Cement Type Filter Cake Thickening Time Fluid Loss Target Acceptable Range Rheology 19 bbls total Neat Liquid Latex Acid Resistant w/B-82, 3% BWOC .85" firm cake ± 0.15" in lab 3-5 hours at 185°F SBHT 75 cc/30-minutes at 170°F BHCT 50 - 90 cc/30-minutes at 170°F BHCT YP>5 with no settling or gelation in fluid loss cell. . Catch a sample of the cement for QC testing. Once the blend is approved, conduct 2nd Job Scope meeting to ensure that participants know the upcoming job sequence. Line up cementers to the coil. · Ensure all gas is out of the system. Do not proceed with squeeze unless the tubinq is liquid packed and qas free. · First step will be to lay in all cement in tubing. Then IA will be opened and cement will be circulated into IA as detailed in steps below. 14. RIH to flag. Line out cementers to the CT. Pump the following down the coil: 4 6-17 Packer Squeeze · 10 bbls spacer water / · 19 bbls neat LARC cement · One coil volume of spacer water · 1.5# biozan gel for cement clean-out SI in IA and take returns up the backside (tubing x CT annulus) while pumping water spacer. Switch to LARC while continuing to take returns up the backside. Maintain 100-200 psi backpressure. Pump 1 bbls LARC out the nozzle (75' of cement above nozzle) and then lay-in 1: 1 while PUH (This step is to ensure that /' you don't dilute cement as you pull up). Strap returns in the 40 bbls tank. . · Monitor IA pressure while laying in cement in tubing to account for cement U- tube. · Water flush volume is critical, so use the internal 1 0 bbls tanks in the pump van to gauge flush volume. SAFETY: 19 barrels of cement would extend up the tubing to 9683' DD if no cement is placed in the annulus (assuming Fas Drill plug at 10530' DD). 15. With the nozzle at safety, SO pumping, SI backside (tubing x CT annulus). Compare pump volume to return volume in the 40 bbl tank. 16. Open IA to returns to the 40 bbl tank. Begin pumping at minimum rate down the CT. Circulate 9.5 bbls through the circ holes and up the IA. SI IA and gauge volume of returns. Monitor the IA and tubing pressures at equilibrium. NOTE: With Fas Drill plug at 10530' DD, the final cement top in the tubing and annulus should be -10100' -200' above the circ holes 17.0pen the choke on the backside and begin pumping biozan down the CT for clean out. Launch ball and begin jetting with biozan down maximum depth of 10050' MD. 18. Switch to friction reduced water. Make 3 down passes and 2 up passes at 80% from 10050' to -9500. Take barrel count to ensure 1: 1 returns. Jet uphole at 80% running speed and max CT pressure, washing all jewelry thoroughly. Replace voidage trying to maintain a balanced well bore. This step is critical to the success of this job-particularlv on this job which has very little cement in the annulus. 19. Freeze protect the top 2,500' of the well bore while POOH. Continue to closelv monitor the chanaes in wellhead pressure to maintain a balanced well bore. 5 6-17 Packer Squeeze 20. Leave tubing pressure so the well bore will be balanced between the tubing and I casing at the packer. Post-SQueeze DHD 21.After 2 days WOC, MIT the IA to 3,000 psi. Establish LLR if MIT fails. ,r-' Post-SQueeze SL 22. RU slickline unit. Tag cement top. 23. Pull DGL V and run LGL V to station #1 (this will allow freeze protect fluid to be circulated around via this open GLM in case CT gets stuck during milling job as was the case in the recent 11-6 post scab liner milling). Post-SQueeze CT Mill Cement Pluç 24. RU CTU and RIH with mill and motor to mill through the -430' cement and Fas Drill plug. POOH at 80%. Post-Millout SL& Fullbore 25. RU slickline unit, pump and fluids. Run DGL V to station #1 26. MIT IA to 3000 psi. 27.lf MIT-IA passes, run generic kickoff design. / 28. Put well on production 6 TREE = WELLHEAD = A CTUA TOR KB, ELEV = BF, ELEV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN 3 FMC AXELSON 74' ? 3150' 50 @ 7100' 10988' 8800' SS 06-17 / SAFETY NOTES: WELD. 8/18/94 PREV K-VLV. ***5-1/2" CHROME TBG*** Minimum 10 = 3.81" @ 4-1/2" CA 08-6 NIPPLE . . 2170' H5-1I2" HES X NIP, 10 - 4562" I 2502' µ ~ GAS LIFT MANDRELS l ST MD TVD DEV TYPE VLV LA TCH PORT DATE 1 3789 3758 1 CA DOME T-2 16 07/14/00 10523' 2 6470 5744 50 CA DOME T-2 16 07/14/00 3 8131 6825 47 CA DOME T-2 16 07/14/00 4 9209 7596 43 CA S/O T-2 28 04/25/03 5 9981 8170 41 CA DMY T-2 0 07/14/00 :8: "'"""" 1 0320' 1-19-5/8" X 5-1/2" BKR S-3 PKR, 10 - 4,75" I ""-" 1 0395' - 5-1 /2" HES X NIP, ID = 4,562" I 2" H 10428' I -- 10395' -5-1/2" PXTTP(06/27/05) I 10428' - 5-112" BKR PBR ASSY I BGH 10428' I l ~ :8: k::-::> 10443' - 9-5/8" X 5-1/2" BKR SAB PKR 2" H 10455' I I"'-" pcH 10455' I \ J I 10455' H5-1/2" x 4-1/2" XO I NR I 10504' l- II -4-1/2" CAM DB-6 NIP, ID - 381" I I I I 10523' v-I 10535' H4-1/2" BKR S/O SUB I 8" - I- 10536' I -4-1/2" TBG TAIL I I 10536' 1" I 10822' 1---4 .. 10517' H ELMO TT LOGGED 02/12/83 I Y .. 10795' SLM 11 FISH - IBP ELEMENT I 1/82 r J 10818' orical perf data /Sqz DATE 04/15/95 08/02/96 OS/22/96 OS/22/96 05/16/91 05/16/91 II 05/16/91 05/16/91 o I 11444' I " I 11490' I I 113-3/8" CSG, 72#, L-80. 10 = 12,347" I 15-1/2"TBG, 17#, 13-CR-80, ,0232bpf, 10=4,89 I TOP OF 5-1/2" T 15-1/2" TBG. 17#, L-80, ,0232 bpf, 10 = 4,89 I TOP OF 4-1/2" TBG- TOPOF 7" L 14-1/2" TBG, 12,6#. N-80, ,0152 bpf, 10 = 3,95 I 9-5/8" CSG, 47#, L-80, ID = 8,68 PERFORA TION SUMMAR REF LOG: BHCS ON 07/0 ANGLE AT TOP PERF: 49 @ Note: Refer to Production DB for his! SIZE SPF INTERVAL Opn 3-3/8" 4 10818 - 10848 C 3-3/8" 6 10974 - 10944 C 3-3/8" 6 10994 - 11 036 S 3-3/8" 4 11046 - 11068 S 3-3/8" 4 11090 - 11110 S 3-3/8" 411120-11140 S 3-3/8" 4 11150 - 11170 S 3-3/8" 4 11182 - 11202 S I PBT 17" LNR, 29#, L-80, ,0371 bpf, ID = 6,184 DATE 07/13/82 07/08/00 09/13/01 03/22/03 04/25/03 09/20/03 RN/TP JMP/KK JrvtlTP KJB/KK COMMENTS ORIGINAL COM PLETION LAST WORKOV ER CORRECTIONS DELETE WAIVER SAFETY NOT GLV C/O PERF CORRECTIONS DATE 05/13/04 05/17/05 09/23/05 REV BY COMMENTS KB/KAK CORRECTIONS MGS/PJC FISH CORRECTION MOR/TLH PX TTP SET (06/27/05) PRUDHOE BA Y UNIT WELL: 06-17 PERMIT No: "1820900 API No: 50-029-20760-00 SEC 11, T10N, R14E, 2826,64' FEL & 5240,09' FNL REV BY BP Exploration (Alaska) PBU 6-17 ') Subject: PBU 6-17 From: Chuck Scheve <chuck - scheve@admin.state.ak.us> Date: Mon, 15 Nov 2004 10:06:02 -0900 To; }imR~g~,<jim_n~gg@admin~state.alcus>, Hi Jim Ç) -. l B7.. - (J1'C) ,~ '1.1-15--0ðr I received a call friday evening 11/12/04 notifying me of an incident on well 6-17. A plug had been set in the tubing tail and the well loaded with dead crude. Wire line was rigging up to run a leak detect log when the crane winch free spooled dropping the lubricator striking the well house then the well head. Some time after the incident a very small leak was noticed between the master valve and tubing head adapter. The tubing was depressured and the leak stopped. Currently BP is waiting for winds to lessen to rig up a lubricator and set a back pressure valve to effect repairs on the tree. Chuck SCl~NNE[', 1 of 1 \i 2 3 2004 11/15/2004 9:40 AM MEMORANDUM TO: Camille O. Taylor Chair THRU: Tom Maunder P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL DATE: May 16, 2002 SUBJECT: Mechanical Integrity Tests BPX \,,~'~' DS 13 13-20 Prudhoe Bay Field Prudhoe Bay Unit Packer Depth Pretest Initial 15 Min. 30 Min. / Well] 13-20 I Type,nj.I s I T.V.D. [8227 I Tubingl 800 I 800 I 800 I 800 [Intervall I~ P.T.D.I 1820090ITYpetesq P I TestpsiI 2200 I CasingI 1100I 2280I 228oI 2280 I P/F I P/ Notes: Converted from producer to injector. we"I I Type Inj. P.T.D.] ]Type test Notes: '" Well] [Type Inj. P.T.D.I I Type test Notes: P.T.D. I Type test Notes: WellI I Type Inj. P.T.D. I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G --' GAS INJ. 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 D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Tesrs Details I traveled to BPX's Prudhoe Bay field to witness the initia MIT on 13-20. This well was converted from producer to injector. The 4" bull plug on the well head for te IA was leaking freeze protect. The BP was found loose & will be tightened alter test pressure is bled off. M.I.T.'s performed: l_ Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. CC: MIT report form 5/12/00 L.G. MIT PBU DS 13 05-16-02jc.xls 5/17/02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor DATE: July 29, 2000 FROM: JohnPetroleum I CrisP, ~or-~,'~ /~ "h'sPectr SUBJECT: Safety Valve Tests Prudhoe Bay Unit DS 6-17 DS 7-37 DS 15-42 July 29~ 2000: I traveled to Prudhoe Bay Field to witness misc. Safety Valve System tests. Operator Rep. Kurt Horst contacted AOGCC inspector to witness misc. SVS tests on wells that were missed during regular test cycle. No failures were witnessed. The AOGCC test reports are attached for reference. SUMMARY: I witnessed misc. SVS tests on DS 6-17, DS 7-37 & DS 15-42 in the PBU. 3 wellS, 6 components tested. No failures witnessed. Attachments: Misc. SVS PBU DS 6-17 7-29-00jc Misc. SVS PBU DS 7-37 7-29-00jc Misc. SVS PBU DS 15-42 7-29-00jc cc; NON-CONFIDENTIAL Misc. SVS PBU DS 6, DS 7, DS 15 7-29-00jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Kurt Horst AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU DS 6-17 Separator psi: LPS 168 Date: 7/29/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 06-01 1750490 06-02 1770780 06-03A 1951520 06-04 1750620 06-05 1780200 06-06A 1960820 06-07 1780210 06-08A 1951950 06-09 1790730 06-10A 1981960 06-11 1791100 06-12A 1920640 06-13 1800300 06-14A 1920570 06-15 1800320 06-16 1800330 ~ :1~820900: 168 150 125 P P OIL 06-18 1820990 06-19 1821140~ 06-20 1821240' 06-21 1821270: , 06-22A 1930570 06-23A 2000370 06-24 1821470 Wells: 1 Components: 2 Failures: 0 Failure Rate: 0.0% ~3 9o var Remarks: 8/1/00 Page 1 of 1 Misc. SVS PBU DS 6-17 7-29-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Kurt Horst AOGCC Rep: John Crisp Submitted By: John Crsp Field/Uni~ad: PBU DS 7-37 Separator psi: LPS 168 Date: 7/29/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 07-0lA 1971530! 07-02A 1960880! 07-03A 1950620! 07-04A 1920670 07-05 1780130 07-06A 1951970 07-07A 1830130 07-08A 1982440 07-09 1780760 07-10A 1980160 07-1lA 1971560 07-12. 1780790i '~7-13A 1941030: 07-14A 1980720 07-15A 1981120! 07-16 18218201 · 07-17 1822000! 07-18 1822090 07-19A 1980290 07-20A 1951290! , , ,,, 07-21 1830190~ , 07-22 1830390 07-23A 19808901 07-24 1830630 07-25 1830560 07226 1830480 07-28A 19712901 07-29A 1982270 07-30 1880190 07-32A 1990690 07-33A 1981440 , 07-34A 2000130 07-35 1971770 , 07-36 1971690 8/1/00 Page 1 of 2 Misc..SVS PBU DS 7-37 7-29-00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 07-37 1971760 168 150 125 P P O~L Wells: 1 Components: 2 Failures: 0 Failure Rate: 0.0% ~] oo Day Remarks: 8/1/00 Page 2 of 2 Misc, SVS PBU DS 7-37 7-29-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Kurt Horst AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU DS 15-42 Separator psi: LPS 168 Date: 7/29/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLt 15-0lA 1982220 15-02A 1961630 15-03 1820300 15-04 1820370 15-05A 1950340 15-06A 1982540 15-07A 1940110 i's-68U 1971820 15-09A. 1931380 15-10A 1880850 15-1lA 1982480 15-12.. 1811460 15-13A 1991240 15-14 1811700 15-15A 1982410 , 15-16 1840740 15-17 1840890 , 15-18 1920600 ,,, 15-19A 1990990 ,, 15-20A 1990480 15-21A 1990290 15-22 1800970 ,, 15'23 1911350 15-24 1911280 15-25A 1990860 15-26A 1970170 , 15.27 1920060 15-28 1920150 15-29 1920350 15-30 1920780 , 15-31 1920870 ,, 15-32 1940470 15-33A 1990600 15-34' 1'940630 8/1/00 Page 1 of 2 Misc. SVS PBU DS 15-42 7-29-00jc.xls 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 CYCL~ II I 15-35 1940880 15-36 1940720 15-37 1940790 15-38 1941040 , 15-39 1941150 15-40A 1980980 15-41 1940940 15-42 195'1850 168 150] 130 P P 0IL 15-43 1960830 15-44 1961100 15-45 1960690 15-46 1960610 15-47 1951740 15-48 19520801 15-49 1960340! Wells: 1 Components: 2 Failures: 0 Failure Rate: 0.0% [] 9o Day Remarks: 8/1/00 Page 2 of 2 Misc. SVS PBU DS 15-42 7-29-00jc.xls STATE OF ALASKA ALASK,~-- '_ AND GAS CONSERVATION COMI~~ '~ION RE~ORT OF SUNDRY WELL OPERATIOI~ 1. Operations performed: r-I Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development RKB = 74' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3' SNL, 860' WEL, SEC. 11 T10N, R14E, UM At top of productive interval 9. Permit Number / Approval No. 378' NSL, 2641' WEL, SEC. 11, T10N, R14E, UM 182-090 ,~: ,,-, (:.~,'~;~"... 10. APl Number At effective depth /--',O ~; ~ c) ~ ..... ,~ u' 50- 029-20760-00 355' NSL, 2654' WEL, SEC. 11, T10N, R14E, UM ,~,~,~!.,,,,~ 01,; .~ ~a~: ~6~$,,.~'.~..~mmi,~i:~r~ 11 Field and Pool At total depth A~Ch0r~~ Prudhoe Bay Field / Prudhoe Bay 38' NSL, 2826' WEL, SEC. 11, T10N, R14E, UM Pool 12. Present well condition summary Total depth: measured 11500 feet Plugs (measured) Tagged PBTD at 11007' (11/98) true vertical 9223 feet Effective depth: measured 11007 feet Junk (measured) true vertical 8887 feet Casing Length Size Cemented MD TVD Structural Conductor 81' 20" 2361# Poleset 81' 81' Surface 2428' 13-3/8" 2032 sx Fondu, 400 sx PF 'C' 2502' 2502' Intermediate Production 10748' 9-5/8" 500 sx Class 'G', 33 Bbls PF 'C' 10822' 8765' Liner 986' 7" 325 sx Class 'G' 10511' - 11490' 8554' - 9216' Perforation depth: measured Open: 10818'-11062' (nine intervals) ORIGINAL Sqzd: 11090' - 11202' (four intervals) true vertical Open: 8762' - 8924' Sqzd: 8942' - 9018' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13Cr80 to 10429'; 5-1/2" x 4-1/2" to 10536' Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" Baker 'SAB' packer at 10443'; 9-5/8" Baker 'S-3' Hydro-set packer at 10320'; 5-1/2" HES 'X' nipple at 2170' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the fore, going is t~ct to the best of my knowledge Signed Terrie Hubble '"~~'"/ ~ Title Technical Assistant Date 0~;)',,~1~' ~) Prepared By Name/Number: Terrie Hubble, 564-4628 'i~orm 10-404 Rev. 06/15/88 Submit In Duplicate..~ Legal Well Name: BP AMOCO OperatiOns Summary Report 06-17 page 1 of I Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/20/2000 06-17 WORKOVER NABORS NABORS7ES From-To 00:00 - 00:30 00:30 - Ol :00 01:0o - Ol :30 01:30 - 03:30 03:30 - 04:30 04:30 - 06:00 06:00 - 08:30 08:30 ~ 09:30 09:30- 12:30 12:30- 15:30 15:30- 16:30 16:30- 17:30 17:30 - 19:30 19:30 - 20:30 20:30 - 22:30 22:30 - 00:00 0.501 FISH 0.50 FISH 0.50 FISH FISH FISH FISH Spud Date: 6/17/2000 Start: 6/15/2000 End: Rig Release: -Group: DRK1 Rig Number: 7es Phase DeScription of oPerations DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Finished rigging up to lay down 5 1/2 inch tubing fish. Laid down 13 jts. and 4.98 ft. cut joint of 5 1/2 inch tubing. Rigged down tubing handling equipment and cleared floor. Make up FBHA #2. RIH w/outside cutter on 3 jts. 8 1/8" washpipe. RIH picking up drill pipe to 1150 ft. Had false H2S alarm. CWl and evacuated rig. Located faulty H2S sensor and repaired. Finished GIH with outside cutter on 8 1/8" washpipe to 6092 ft. Circulated hi vis sweep surface to surface. Worked over top of fish and lowered outside cutter to 6192 ft. Rotated cutter up hole, engaged tubing collar at 6186 ft. and cut tubing at 6191 ft. While POOH, pipe binding in interval 5200-4900 ft. requiring 10K lbs. overpull. Pipe hung in interval 4900-4790 ft. requiring 50K lbs. overpull. Last overpull to 50K executed with shoe of cutter at 4790 ft. Finished POOH with FBHA #2. Left two joints washpipe, outside cutter and 5 1/2" tubing fish in hole. Pin on top joint of washpipe broke of completely due to old pre existing crack. Made up FBHA #3 consisting of 8 1/8" overshot with 5 1/2" grapple, oil and bumper jars and 9 - 6 1/2" drill collars. RIH w/overshot on drill pipe. Tagged top of fish at 4757 ft. indicating fish fell down hole 33 ft. after pin broke with shoe at 4790 ft. Worked overshot at top of fish with no indication of catching fish. POOH w/FBHA #3 and recovered 5 1/2" tubing fish consisting of 34.3 ft. stub, 39.4 ft. joint and 2.5 ft. stub. Laid down 5 1/2" tubing fish by cutting with torch. Found complete tubing packoff across collar of tubing. Cleared floor and laid down tools. r- ¢EiVE© Printed: 8/10/2000 11:20:05 AM BP AMOCO Page 2 of 1 1 OPerations Summary Repo ska Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Sta~: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es r D ro ACtVi~ C°d ~ ~ ateF m.To Hours i Phase Description of Operatic I :: I 6/15/20~ 09:00 - 17:00 8.00 ~ MOVE ~ PRE ~D floor Top Drive Lower Pipe chute, Blow down Pits & Unhook. ' PJSM, Lower Mast, Move Camp, Pits, Shop ~ I ~ ~ PRE ~ Move Sub Base Of well :~17:00- 17:30 0.50 MOVE i ,17:30 - 18:00 0.50 MOVE SKID . PRE ~3 Hyd Motor Tripped, Troubleshoot same 18:00 - 18:30 ~ 0.50 MOVE PRE Move Subbase to West Beach Rd. 18:30 21:30 ~ 3.00 MOVE [PERS PRE Waited on Security and Electricians (Two Rig Moves) 21:30 00:00 2.50 MOVE PRE Move Towards DS 6 via Oxbow 6/16/2000 00:00 - 02:00 2.00 MOVE PRE Move sub Base/Derrick from DS 2 to Little Putt River Culve~ Via Oxbow Rd. 02:00 - 15:30 13.50 MOVE OTHR PRE Road Gave Way Under Rig Wheels Stbrd Strn, River High & Rising, Filled and Plaid in Hole; 2100 sand bags, Placed Pl~ood & Mats on Sandbags, Drove Rig UP on Mats Past Culve~s 15:30 - 00:~ 8.50 MOVE PRE Lay mats ahead of rig. Distance to DS6 is 7/10 mile 6/18/2000 00:00 - 03:00 3.00 WHSUR DECOMP N/D Tree & ADP Flange, Function All LDS on TBG Spool, OK 03:00 - 05:00 2.00 BOPSUF~, DECOMP N/U BOP 05:00 - 08:00 3.00 BOPSUR DECOMP Test BOP, 250 Iow, 3500 High, AOGCC Waived Witness 08:00 - 09:30 1.50 BOPSUR DECOMP Pull Blanking Plug, ~U Lubricator, Pull BPV 09:30 - 10:00 0.50 CLEAN DECOMP ~U To Circ & Take Returns to Cuttings Tank Outside 10:00 - 12:30 2.50 CLEAN DECOMP Circ ~ 4 BPM No gas Detectable, Loss Rate 4 BPH 12:30 - 13:30 1.00 FISH DECOMP Back Out LDS, Screw Into HGR 13:30 - 14:00 0.50 FISH DECOMP Pull 95000 ~ TBG Moving 14:00 - 16:30 2.50 FISH DECOMP POH, UD, Spool Up SSSV Control Lines, Recovered 25 Clamps, 4 SS Bands & 5 1/2" 17 ~ L80 EUE 8rd Tbg, Parafin Present on Exterior of TBG 16:30 - 17:00 0.50 FISH DECOMP Clear & Clean Floor of Spooling Unit 17:00 - 20:30 3.50 FISH DECOMP Finish POH W~BG, Recovered Total 2 GLMs & Pups Plus 140 Jts 5 1/2 TBG. Jt ~ 136 Had Chemical Cut That Didn' Sever TBG, Top of Joint g 140 Has Internal Yielded (Burst) From Collar To 5' Below. The Pin on g 140 Has Jumped the Box & Split the TBG. Top of Fish is Collar; TOF 5595 20:30 - 21:00 0.50 FISH DECOMP Clean Rig Floor of Parafin, asphaltines from Exterior of TBG 21:00 - 23:00 2.00 WHSUR DECOMP P/U & Run 9 Jts 6 1/4 DC, M/U R~S & Storm Valve, Set ~ 30 ff RKB, Test to ~000 psi, OK 23:00 - 00:00 1.00 WHSUR DECOMP N/D BOP & TBG Spool, Prep to Pull Packoff 6/19/2000 00:00 - 00:30 0.50 WHSUR DECOMP Finish N/D BOP & TBG Spool 00:30 - 03:00 2.50 WHSUR DECOMP Pull 9 5/8 Packoff, Pulled with 35K After Heating Wellhead & Cycling Tension On R&R Tool 03:00 - 04:00 1.00 WHSUR DECOMP Change Out Packoff, UD R&R Tool 04:00 - 04:30 0.50 WHSUR DECOMP N/U TBG Spool, Test Packoff & Flange Fa~ to 5000 OK 04:30 - 05:30 1.00 WHSUR DECOMP N/U BOP & 2nd Annular Valve 05:30 - 06:00 0.50 WHSUR DECOMP Test Lower Pipe Ram, Da~, Flange to 250 Iow, 3500 Hi 06:00 - 07:30 1.50 WHSUR DECOMP Set Wear Bushing, Screw into Storm Valve, Release & Recover R~S 07:30 - 08:30 1.00 WHSUR DECOMP Pull & Std Back DC 08:30 - 09:30 1.00 WHSUR DECOMP Se~i~ Top Drive 09:30 - 11:00 1.50 FISH I DECOMP P/U DP Work String 11:00 - 15:00 4.00 FISH ~ DECOMP PJSM, Chemical Cu~ing, ~U SWS, RIH with Chemical Cutter, Cut TBG ~ 6112 WLM, POH & ~D SWS 15:00 - 16:00 1.00 FISH DECOMP M/U FTA ~1, RIH with Spear 16:00 - 20:00 4.00 FISH DECOMP RIH W/FTA ~1, Picking Up DP Work String, Spear Fish ~ 5595, Gained 15K Wt, Fish Free 20:00- 23:00 3.00 FISH DECOMP POH 23:00 - 00:00 1.00~ FISH DECOMP Release Spear & UD 13 Jts 5 1/2 17~ L80 EUE R3 TBG plus 7' Stub I Printed: 8/10/2000 11:20:05 AM BP AMoco Page 3 of 1 OPerations summary Report Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Start: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es !i Date From-To HOurs Activity COde Phase DescriPtion of Operations ' i , 6/19/2000 .23:00- 00:00 i 1.001 FISH i i DECOMP With Chemical Cut in Tube, New TOF 6112', L/D Fish 6/21/2000 i00:00 - 01:00 ~ 1.001 FISH I I DECOMP Service top drive. ' 01:00 - 02:00 1.00 FISH DECOMP Made up FBHA #4 consisting of 5 3/4" spear with 7.182" grapple, 8 3/8" i [ stop ring, bumper and oil jars, 9 - 6 1/2" DC. 02:00 - 03:30 1.50 FISH DECOMP RIH with spear to top of fish at 4765 ft. Caught fish and set grapple ! with 15K lbs. pull. 03:30 - 06:00 2.501 FISH DECOMP Jarred fish downhole from 4765 ft. to 4834 ft. 06:00 - 07:00 1.00~ FISH ~ DECOMP Circulated hi vis sweep surface to surface with no recovery. 07:00 - 08:30 1.50 FISH DECOMP Worked pipe up hole thru tight spot from 4820 ft. to 4750 ft. Fish pulled free. 08:30 - 10:30 2.00 FISH i DECOMP POOH with DP to BHA. 10:30 - 13:00 2.50 FISH i DECOMP Pulled BHA and laid down 1 joint of 8 1/8" washpipe fish. Left 1 joint 8 iI 1/8" washpipe and 8 1/8" outside cutter in hole. Washpipe apparently I jumped box. Cleared floor. Removed spear from washpipe and 0.50 , redressed spear with new 7.182" grapple. 13:00 - 13:30 FISH ' DECOMP Made up FBHA #5 consisting of 5 3/4" spear with 7.182" grapple, oil and bumper jars, 9 - 6 1/2" DC. 13:30 - 16:30 3.00 FISH DECOMP RIH with spear and tagged fish at 6142 ft. (Fish top should have been at 6155 ft. if fish resting on 5 1/2" tubing) 16:30 - 17:00 0.50 FISH DECOMP Worked pipe and tagged fish w/15K wt. Had no weight increase or drag. Tagged fish second time w/15K weight. Picked up with no increase in weight or drag. 17:00 - 20:00 3.00 FISH DECOMP POOH to 5000 ft. Pulled slowly from 5000 - 4700 ft. with 10K lbs. drag. POOH from 4700 ft. with no drag. 20:00 - 21:30 1.50 FISH DECOMP Did not recover fish. Changed out 5 3/4" spear and installed new 7.182" grapple. Ran 3.2 ft. extension between spear and stop ring. 21:30 - 00:00 2.50 FISH DECOMP RIH with FBHA #6 to 4600 ft. and took up and down weights. RIH to 4790 ft. and took up and down weights. Had 7K lbs drag down and 4K lbs drag up in interval 4760 - 4990 ft. Drag disappeared at 5000 ft. 6/22/2000 00:00 - 00:30 0.50 FISH DECOMP RIH to top of 5.5" stub @ 6192'. 00:30 - 01:00 0.50 FISH DECOMP POH wet to 4700'. 01:00 - 02:30 1.50 FISH DECOMP Pump dry job. POH to 321' 02:30- 03:00 0.50 FISH DECOMP LD BHA #6. 03:00 - 03:30 0.50 FISH DECOMP PJSM w/SWS. 03:30 - 09:00 5.50 FISH DECOMP RU SWS. RIH w/4 7/16" chemical cutter. Worked into 5.5" tbg 6192'. RIH to 10,425' WLM (PBR). Logged up w/CCL to 6900'. Tie in. Cut 5.5" tbg @ 6967'. POH. RD SWS. 09:00 - 09:30 0.50 FISH DECOMP MU BHA #7 (8 1/8" x 5.5" overshot). 09:30 - 11:00 1.50 FISH DECOMP Cut drlg line & service top drive. 11:00 - 13:30 2.50 FISH DECOMP RIH with overshot to 6192 ft. Tagged fish and swallowed 6 ft. Picked up with 10K overpull. 13:30 - 16:00 2.50 FISH DECOMP POOH with DP to 1000 ft. 16:20 - 17:00 0.67 FISH DECOMP Finished POOH to 100 ft. 17:00- 17:30 0.50 FISH DECOMP Rig up tubing handling equipment. 17:30 - 18:30 1.00 FISH i DECOMP Broke down BHA and overshot. Cut fish at end of overshot 18:30 - 19:30 1.00 FISH DECOMP Laid down 19 full joints and 2 - cut joints tubing (total length - 775 ft.) New Top Of Fish @ 6967 ft. 19:30 - 20:00 0.50 FISH DECOMP Rig down tubing handling equipment. 20:00 - 21:30 1.50 FISH DECOMP Made up FBH^ #8 with Tri State spear. 21:30-23:30 2.00 FISH IDECOMP RIHwith DP by stands to 6235 ft. A~¢horage AU(~ 2_. 9 ,~.~.~,~,.,.,¥, BP AMOCO page4 of 11 ~as~ oii ~ ~ c~. c~iss~on Operations Summary Report Anc~or~e Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Start: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: N^BORS 7ES Rig Number: 7es , Date ; ,;Fr°m~To HOUrs,ActivitY Code Descrip!ion of oPerationsI 6~22~2000 ~21:30 - 23:30 i 2.00[ FISH ~ ~DECOMP ! 23:30 - 00:00 I 0.50[ FISH ~ i DECOMP i RIH to 6952 ft. by singles. 6/23/2000 00:00 - 01:00 i 1.00[ FISH I , DECOMP i Finished GIH w/TriState spear. Tagged TOF at 6945 ft. Ran spear i~ ' DECOMP into fish to 6953 ft and actuated sips P cked up wth 10K overpull. I ! Overpull dropped immediatey to 2-4K. 01:00 - 05:30 4.50 FISH POOH w/FBHA #8. Had 40K lbs. overpull at 4779 ft. Held D-1 drill - response time 1 min. 05:30 - 06:30 1.00 FISH DECOMP Stood back DC, broke down jars and laid out BHA. 06:30 - 07:30 1.00' FISH DECOMP Recovered and laid down 1 joint 8 1/8" washpipe and outside cutter. ~ Two knives broken out of cutter; otherwise no significant markings on fish. 07:30- 08:00 0.50 FISH DECOMP Service top drive. 08:00 - 09:00 1.00 FISH DECOMP Rigged up SWS with chemical cutter. PJSM re chemical cutter. 09:00 - 12:00 3.00 FISH DECOMP Ran 4 7/16" chemical cutter. Could not get into top of 5 1/2" tubing stub at 6967 ft. POOH and found centralizers bent and one bow missing. Removed centralizer from tool. 12:00 - 15:30 3.50 FISH DECOMP Ran second chemical cutter with no centralizer on tools. Could not stab into tubing stub at 6967 ft. POOH w/cutter. 15:30 - 20:00 4.50 FISH DECOMP Ran 8 7/16" impression block on electric line. Tools sat down at 4798 ft. Could not work past. POOH. Had no impression on block. Tools apparently sitting down in dogleg in casing. 20:00 - 21:00 1.00 FISH DECOMP Rig down SWS. 21:00 - 21:30 0.50 FISH DECOMP Cleared floor of fishing tools, etc. 21:30 - 00:00 2.50 FISH DECOMP Move 5 1/2" tubing workstring into pipe shed. Drift and tally pipe. Rig up tubing handling equipment. 6/24/2000 00:00 - 02:30 2.50 FISH DECOMP Loaded 5 1/2" tubing and casing in pipe shed. Drifted and measured pipe. Finished rigging up tuibng handling equipment. 02:30 - 03:00 0.50 FISH DECOMP Made up 8 1/8" overshot with 5 1/2" grapple. 03:00 - 10:00 7.00 FISH DECOMP RIH with overshot picking up 112 joints 5 1/2" 17# L-80 casing and 68 joints 5 1/2" 17# L-80 & J-55 tubing. 10:00 - 11:00 1.00 FISH DECOMP Circulate hole volume with seawater workover fluid. 11:00 - 13:00 2.00 FISH DECOMP Space out overshot at 6967 ft. and install pup joints. Lower overshot and latch 5 1/2" tubing fish at 6973 ft. tubing measure. 13:00- 14:00 1.00 FISH DECOMP RU Schlumberger. 14:00 - 14:10 0.17 FISH DECOMP Held PJSM re chemical cutting operation. 14:10 - 18:30 4.33 FISH DECOMP Ran 4 7/16" chemical cutter. Sat down at 6967 ft. Cutter stuck. Vvorked free and POOH. Lost 1 bow from centralizer and severly damaged second bow. RD Schlumberger. 18:30 - 19:30 1.00 FISH DECOMP !Serviced rig and top drive while waiting on HES slickline unit. 19:30 - 20:10 0.67 FISH DECOMP Rigged up HES slickline unit. 20:10 - 20:30 0.33 FISH DECOMP Held PJSM re wireline operations. 20:30 - 22:00 1.50 FISH DECOMP Ran 4.5" OD lead impression block. Impression of top of chemical cut fish crimped inward on one side by 1 1/2" with Schlumberger centralizer i bow hung on one side of crimp. 22:00 - 23:30 1.50 FISH DECOMP Ran 3.6" OD tubing gauge on wireline to TOF at 6958 ft. WL depth. Jarred down on gauge for 15 mins. with no sticking or progress. POOH and found gauge heavily marked with metal scars on opposite sides of bottom ring. 23:30 - 00:00 0.50 FISH DECOMP Ran 3.6" tubing swage on wireline to TOF at 6958 ft. VVL depth. Jarred down on fish for 8 mins. with swage sticking slightly. Had to jar up to free swage. 6/25/2000 00:00 - 01:00 1.00 FISH DECOMP RIH with 3.48" OD tubing swage. Jarred down on top of fish with drift sticking. Could not jar drift into top of fish. POOH I Printed: 8/10/2000 11:20:05 AM BP AMOCO ,, ~. ~. Page 5 of 11 ALJG 29 L0u0 Operations Summary Re po.. ka 0 ,i cons, ~nmissk~a AnC 0rage Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Start: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es ; Date; ;;FrOm.To ;Hours ActiVityt;COde:t Phase : ; :DescriPtion of oPerations; ! 6/25/2000 i01:00 - 01:30 0.50~ FISH j i DECOMP i RIH with 2.75" OD tubing gauge. Sat down at top of fish. Jarred down i I and entered top of fish to 6975 ft. Pulled tools out of fish and POOH. i01:30 - 02:30 1.00 FISH I , DECOMP RIH with 3" OD lead impression block. Confirmed top of fish crimped ~ on Iow side of hole. POOH. 02:30 - 03:00 0.50 FISH DECOMP Rigged down HES wireline. 03:00- 03:30 0.50 FISH I DECOMP Released overshot from fish. ,03:30 - 04:30 1.00 FISH DECOMP Laid down space out pups, safety valve, etc. Rig up tubing handling equipment. 04:30 - 09:30 5.00 FISH DECOMP POOH with 5 1/2" tubing work string laying down in singles in pipe shed. 09:30- 09:32 0.03 FISH DECOMP Conducted D-1 kick drill. 09:32 - 10:30 0.97 FISH i DECOMP Finished POOH laying down 5 1/2" tubing workstring. 10:30 - 11:130 0.50 FISH i DECOMP Broke out overshot, rigged down tubing handling tools and cleared floor. 11:00 - 11:30 0.50 FISH I DECOMP Pull wear ring. 11:30 - 14:00 2.50 FISH I DECOMP Set test plug and tested pipe rams, blind rams, annular preventer, : choke manifold, safety valve, dart valve, rotary hose and top drive to 250 psi Iow and 3500 psi high pressure. Test witnessed by Leu Grimaldi with AOGCC. 14:00 - 15:30 1.50 FISH DECOMP Pulled BOP test plug and ran wear ring. Laid down test joint and broke out top sub. Cleared floor. 15:30 - 17:00 1.50 FISH DECOMP Made up FBHA #10. RIH to 1000 ft. 17:00 - 18:00 1.00 FISH DECOMP POOH and stood back BHA. 18:00 - 19:00 1.00 FISH DECOMP Cut 3 X 1/2" circulating holes in skirt of skirted mill. 19:00 - 20:00 1.00 FISH DECOMP RIH with 4 3~4" skirted mill to TOF at 6967 ft. 20:05 - 22:15 2.17 FISH DECOMP Broke circulation and took parameters. Rotated over fish at 6967.7 ft. and milled on top offish to 6974 ft. end of cut lip giude on 8 1/8" OD mill skirt. Depth of mill inside fish - 6970.5 ft. or 2.8 ft. below TOF at 6967.7 ft. 22:15 - 23:15 1.00 FISH DECOMP Circulated hi vis sweep surface to surface at 12 BPM. 23:15-00:00 0.75 FISH DECOMP Began POOHwith FBHA#10. 612612000 00:00 - 02:00 2.00 FISH DECOMP Finished POOH with drill pipe and FBHA #10. 02:00 - 03:00 1.00 FISH DECOMP Broke out FBHA #10. Tapered mill showed marking evident of being inside top of fish. Markings on stop sub confirmed being inside top of fish by 2.8 ft. 03:00 - 03:10 0.17 FISH DECOMP PJSM with slickline wireline crew. 03:10 - 04:30 1.33 FISH DECOMP Rig up HES slickline wireline unit. 04:30 - 05:30 1.00 FISH DECOMP RIH with 4.5" OD tapered tubing swage. Could not get below 6974 ft. WL depth. POOH. 05:30 - 07:00 1.50 FISH DECOMP RIH with 4.5"OD lead impression block. 07:00 - 08:30 1.50 FISH DECOMP RIH with 3.0" OD lead impression block. Combination of impressions ! indicated tagging top of fish in area of crimp, but fish on high side of ~ hole. POOH. 08:30 - 09:00 0.50 FISH DECOMP Rigged down HES slickline. 09:00 - 10:00 1.00 FISH DECOMP Serviced top drive. 10:00 - 11:00 1.00 FISH DECOMP Begin make up FBHA #11. 11:00 - 12:30 1.50 FISH DECOMP Participated in 1 hour Safety Stand Down drill and meeting. 12:30 - 13:00 0.50 FISH DECOMP Rig up 5 1/2" tubing handling equipment. 13:00- 13:30 0.50 FISH DECOMP Finish making up FBHA#11. 13:30-18:30 5.00 FISH :DECOMP RIHwithFBHA#11 picking up 51/2" tubing work string. 18:30 - 19:00 0.50 FISH DECOMP Circulate bottoms up at TOF. 19:00 - 20:00 1.00 FISH DECOMP Rotate pipe and work over top of fish from 6967 ft. to 6972 ft. 20:00 - 20:05 0.08 FISH DECOMP PJSM with HES wireline crew. Printed: 8/10/2000 11:20:05 AM ~'-~' ~ BP AMOCO ' ~ '~'~ ~='-TM~ - Page~6 of 11 OPeratiOns SUmma Repo Legal Well Name: 06-17 Common Well Name: 06-17 ~pud Date: 6/17/2000 Event Name: WORKOVER Sta~: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es Date From:To HoUrs Activi~ Code~ Phase DescriPtion of oPerations 6/26/2000 ~20:05 - 21:00 0.92 FISH ~ DECOMP R gged up HES slickline wire ine un t. 21:00 - 22:15 1.25~ FISH ~ ~ DECOMP RIH with 4.5" OD tapered tub ng swage. Had to bump thru TOF and ~ ] ran to boffom of 5 1/2" tubing at 10,455 ff. Had to bump back thru TOF. 22:15- 23:00 0.75 FISH DECOMP RD HES wireline unit. 23:00 - 23:10 0.17 FISH ~ j DECOMP PJSM with Schlumberger m chemical cuffer. 23:10 - 00:00 0.83 FISH DECOMP Rig up SWS for chemical cut. 6/27/2000 00:00- 00:30 0.50 FISH DECOMP Finished rigging up Schlumberger. 00:30 - 00:40 0.17 FISH DECOMP Held PJSM m chemical cuffer operation. 00:40 - 03:00 2.33 FISH DECOMP Worked 4 7/16" chemical cuEer thru TOF at 6967 ff. and cut tubing at 10,413 ff. leaving 9 ff. stub, pup joint, PBR seals and packer seal K-latch below cut. 03:00- 04:00 1.00 FISH DECOMP Make up second 4 7/16" chemical cutter. 04:00 - 06:00 2.00 FISH DECOMP Worked 4 7/16" chemical cutter thru TOF at 6067 ff. and cut tubing at 9744 ff. 06:00 - 06:30 0.50 FISH DECOMP Rigged down Schlumberger. 06:30 - 07:30 1.00 FISH DECOMP Rig up Nabom tubing handling equipment. Lay down pup joints from top of work string and clear floor. 07:30 - 12:30 5.00 FISH DECOMP POOH laying down 5 1/2" work string. 12:30 - 13:00 0.50 FISH DECOMP Broke out FBHA ~12 and laid down overshot. 13:00 - 14:00 1.00 FISH DECOMP Rigged down Nabors tubing handling equipment and cleared floor. 14:00-16:00 2.00 FISH DECOMP MadeupFBHA~12. RIH to 317 ff. 16:00 - 17:00 1.00 FISH DECOMP Se~iced top drive. Slip and cut drill line. 17:00 - 19:00 2.00 FISH DECOMP RIH with overshot to TOF at 6967 ff. 19:00 - 19:30 0.50 FISH DECOMP Worked overshot onto fish. Latched fish and pulled free with 36K overpull. 19:30 - 20:30 1.00 FISH DECOMP Circulated bottoms up at 12 BPM. 20:30 - 23:30 3.00 FISH DECOMP POOH with 5 1/2" tubing fish to BHA. 23:30 - 00:00 0.50 FISH DECOMP Stood back BHA. Prop. to release ovemhot from fish. 6/28/2000 00:00- 00:30 0.50 FISH DECOMP RU Nabors tubing handling equipment. 00:30 - 01:30 1.00 FISH DECOMP Release overshot from fish. Found top of fish scalloped on in orientation with flat side of gas lift mandrel. Scallop was 2 1/2" long along circumference and 1 1/2" deep. 01:30 - 04:00 2.50 FISH DECOMP Lay down 2777 ff. of 5 1/2" fish including 2 cut joints, 65 full joints, 6 gas lift mandrels and 12 pup joints. 04:00 - 04:30 0.50 FISH DECOMP Break down ovemhot and change grapple. Rig down tubing handling equipment. 04:30 - 05:00 0.50 FISH DECOMP Make up FBHA ~14 same as FBHA ~13. 05:00 - 08:30 3.50 FISH DECOMP Pick up 120 joints 4" drill pipe. 08:30 - 10:30 2.00 FISH DECOMP RIH with 61 stands of drill pipe from derrick. 10:30 - 11:00 0.50 FISH DECOMP Obtained parametem and latched fish at 9744 ff. Worked fish free with 75K overpull. 11:00 - 12:30 1.50 FISH DECOMP Cimulate hole with hi vis sweep at 12 BPM. Pump d~ job. 12:30- 15:30 3.00 FISH DECOMP POOH to BHA. 15:30- 16:00 0.50 FISH DECOMP Stand back BHA. 16:00 - 18:00 2.00 FISH DECOMP Rigged up tubing handling equipment. Laid down 668 ff. of 5 1/2" tubing fish including 2 cut joints, 12 full joints, 4 gas lift mandrels and 8 pup joints. 18:00 - 18:30 0.50 FISH DECOMP Rig down tubing handling equipment and clear floor. 18:30 - 19:00 0.50~ FISH DECOMP I Made up FBHA ~14 same as FBHA ~13. 19:00 - 21:30 2.50j FISH DECOMP RIH with overshot to 10,400 ff. 21:30 - 22:30 1.00[ FISH DECOMP ]Worked pipe. Took parameters. Had to roam and circulate overshot 0.50 down 8 ff. to latch fish. 22:30 - 23:00 FISH DECOMP Attempted to release K-Latch from packer with torque up to 8500 ft-lbs. Printed: 8/10/2000 11:20:05 AM BP AMOCO Page 7 of 11 £.L." ~:'J operations Summary Report Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Sta~: 6/15/2~0 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es Date From,:To~ ~ ~ ~ ~Hours Activi~ Code Pha~ : Description of Operations ' : I ' I 6/28/2000 22:30 - 23:00 0.50 FISH ~ DECOMP ~and pulls in range of 20K-50K. 23:00 - 23:30 [ 0.50~ FISH ~ ~ DECOMP Jarred on fish with maximum 90K jar stroke. Fish came free. ~23:30 - 00:00 ~ 0.50' FISH ~ DECOMP i Pulled overshot uphole 30 ff. with 5K additional weight. Began POOH. 6/29/2000 00:00 - 04:30 4.50 FISH . DECOMP POOH with OS BHA ~14. 04:30 05:30 1.00 FISH DECOMP ~Lay down 5 1/2" tubing stub, pup joint and PBR seals. ) . . 05:30 - 06:00 0.50 FISH DECOMP Sew~ce top drive. 06:00 07:30 1.50 FISH DECOMP Made up FBHA ~15 with tanden Bowen spears with 6.22" nominal catch grapples. 07:30 - 10:30 3.00 FISH DECOMP RIH to TOF at 10,428 ff. 10:30 - 11:00 0.50 FISH DECOMP Worked pipe and obtained operating parameters. Latched fish while ~ circulating at 120 gpm. Set grapples with 50K overpull. , 11:00 - 11:30 ~ 0.50 FISH J DECOMP Attempted to release K-latch anchor from packer. Torqued pipe in 1000 fi-lbs, increments from 5000 ft-lbs, to 10,000 fi-lbs while working overpull at fish thru range of 15K to 50 K lbs. K-latch began to rotate. Rotated latch 100 turns with 18K-25K up strain. Anchor did not release. 11:30 - 11:45 0.25 FISH DECOMP Jarred on fish to maximum overpull of 100K. Spear grapples packed off to circulation while jarring. 11:45 - 12:00 0.25 FISH DECOMP ;Worked pipe thru overpull range of 15K to 50K lbs. while rotating at 11 RPM. 12:00 - 12:10 0.17 FISH DECOMP ~Jarred down to release spears and regained circulation. Released spears from PBR. 12:10 - 13:30 1.33 FISH DECOMP Circulate bottoms up at 12 BPM and pump d~ job. 13:30 - 16:30 3.00 FISH DECOMP POOH with tandem spear BHA. 16:30 - 18:00 1.50 FISH DECOMP Broke down BHA. Changed out oil jars and laid out spears. Cleared floor of tools. 18:00 - 19:00 1.00 FISH DECOMP Made upwashover FBHA~16. 19:00 - 19:30 0.50 FISH DECOMP Sewice top drive. 19:30 - 20:30 1.00 FISH DECOMP Slip and cut drill line. 20:30 - 22:00 1.50 FISH DECOMP RIH with 8 1/2" rota~ shoe on 8 1/8" washpipe to 4800 ff. 22:00 - 23:00 1.00 FISH DECOMP Washpipe sat down in suspected dogleg at 4795 ff. with 25K weight. Worked WP 15 ff. into dogleg. Had to overpull 75 K to free washpipe. 23:00 - 00:00 1.00 FISH DECOMP POOH with rota~ shoe and washpipe BHA. 6/30/2000 00:00 - 00:30 0.50 FISH DECOMP Finished POOH to BHA. 00:30 - 01:30 1.00 FISH DECOMP Laid down washpipe and rota~ shoe BHA. 01:30-02:30 1.00 FISH DECOMP Made up single spear FBHA ~16. 02:30 - 04:30 2.00 FISH DECOMP RIH to top of PBR fish at 10,424 04:30 - 05:30 1.00 FISH DECOMP Broke circulation and took operating parameters. Engaged PBR with spear. 05:30 - 12:00 6.50 FISH DECOMP Jarred on PBR and K anchor fish to maximum overpull or 175K lbs. without result. 12:00 - 12:30 0.50 FISH DECOMP Released spear and pulled to 10,400 ff. ~ 12:30 - 13:00 0.50 FISH DECOMP Pressure tested 9 5/8" casing to 3000 psi. Had 584 psi bleed off in 30 mins. indicating ve~ small leak - probably collar. 13:00- 13:30 0.50 FISH DECOMP Inspected derrick after jarring operation. 13:30 - 13:40 0.17 FISH DECOMP PJSM - cutting drill line. 13:40 - 15:00 1.33 FISH DECOMP ~Cut 150 ff. off frayed drill line. 15:00 - 19:00 4.00 FISH DECOMP POOH to BHA. t9:00 - 19:30 0.50 FISH DECOMP Broke out and laid down spear BHA. 19:30 - 21:00 1.50 FISH DECOMP Made up Hole Opening BHA consisting of 8 1/2" string mill, etc. 21:00 - 22:30 1.50 FISH DECOMP RIH with string mill to 4790 ff. 22:30 - 00:00 1.50 FISH DECOMP Kelly up and circulate. Tag tire spot in casing at 4800 ff. Took 20K Printed: 8/10/2000 11:20:05 AM BP AMOCO Page8 of 11 Operations Summary RepOrt &i~k~ Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Start: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es ;Date From,TO ;H°urslACtivity;Code Phase : ]:, Descripti°n °f oPerati°ns 6/30/2000 22:30 - 00:00 1.50; FISH i ~; DECOMP i weight. Worked thru bottom of tire spot at 4807 ft. Travel completely i,I i I ' threefree beloWtimes.4813 ft. Reamed with mill thru tite interval 4800-4807 ft. I 0.50 ! DECOMP Rotated 8 1/2" string mill thru dogleg interval 4800-4807 ft. up and down 7/1/2000 ~00:00 - 00:30 i FISH ~ ' I with 1300 ft-lbs overtorque. Stopped rotary and lowered mill thru I dogleg taking 8K weght. Pulled mill thru dogleg with 10K overpull. 00:30 - 01:30 1.00 FISH I DECOMP Circulated around with hi vis sweep at 4887'. 01:30 - 02:00 0.50 FISH DECOMP Lowered mill to 5166 ft. to check for other possible tite spots. 02:00- 03:30 ' 1.50 FISH DECOMP POOH with BHA. 03:30 - 05:00 1.50 FISH DECOMP ;Broke down and laidout string mill BHA. Cleared floor. 05:00 - 06:00 1.00 FISH DECOMP i Make up casing scraper BHA. 08:00-09:00 3.00 FISH DECOMP ~RIH with casing scraper to 10,114 ft. Scraper took 10Kweight in !dogleg at 4800 ft. 09:00 - 09:30 0.50 FISH DECOMP !Washed with casing scraper from 10,114 ft. to 10,424 ft. 09:30 - 11:30 ! 2.00 FISH DECOMP Circulate around with hi vis sweep at 10,424 ft. and pump dry job. 11:30 - 15:30 4.00 FISH DECOMP POOh with drill pipe to BHA. 15:30 - 16:30 1.00 FISH DECOMP Broke down casing scraper BHA and laid out scraper and jars. 16:30 - 17:30 1.00 FISH DECOMP Made up RTTS packer BHA. 17:30-20:00 2.501 FISH DECOMP RIHwith RTTS packer and set at4725 ft. 20:00 - 21:00 1.00 FISH DECOMP Tested 9 5/8" casing from wellhead to 4775 ft. to 3000 psi for 30 mins. with no bleed. 21:00 - 21:30 0.50 FISH DECOMP RIH with RTTS packer and set at 7480 ft. 21:30 - 22:00 0.50 FISH DECOMP Pressured 9 5/8" casing interval 7480 - 10,442 ft. top of Baker packer to 3000 psi and lost 200 psi in 5 mins. indicating casing leak below 7480 ft. 22:00 - 00:00 2.00 FISH DECOMP RIH and set RTTS packer at 9000 ft. 7/2/2000 00:00 - 01:30 1.50 FISH DECOMP With RTTS packer set at 9000 ft., tested 9 5/8" annulus to 3000 psi for 30 mins. - no bleed. Tested 9 5/8" casing below RTTS to 3000 psi for 30 mins. - no bleed. 01:30 - 02:00 0.50 FISH DECOMP RIH and set RTTS packer at 10,407 ft. 02:00 - 03:00 1.00 FISH DECOMP Tested 9 5/8" casing from surface to 10,407 ft. to 3000 psi for 30 mins with no bleed. Tested Baker packer and 9 5/8" casing bleow 10,407 ft. to 3000 psi for 30 mins with no bleed. 03:00- 07:00 4.00 FISH DECOMP POOH to BHA. 07:00 - 08:00 1.00 FISH DECOMP Stand back BHA and lay down RTTS. Stand back BHA and lay down RTTS. 08:00 - 08:30 0.50 FISH DECOMP Lay down RTTS and clear floor. 08:30 - 09:00 0.50 FISH DECOMP Rig up Schlumberger electric line truck. 09:00 - 09:10 0.17 FISH DECOMP PJSM rel logging operations. 09:10 - 14:30 5.33 FISH DECOMP Ran Schlumberger USIT casing inspection log 10,200 - 0 ft. 14:30- 15:00 0.50 FISH DECOMP Rig down Schlumberger. 15:00 - 18:00 3.00 FISH DECOMP Pulled wear bushing. Tested BOPE, pipe rams, blind rams, annular preventer, choke manifold and valves, safety valve, dart valve, top drive and hose to 250/3500 psi. Witness of test waived by John Spaulding with AOGCC. 18:00- 18:30 0.50 FISH DECOMP Install wear bushing. 18:30 - 19:30 1.00 FISH DECOMP Serviced top drive equiipment. 19:30 - 20:30 1.00 FISH DECOMP Made up cleanout BHA #17. 4 1/2" Muleshoe, 4 1/2" collar, 4 1/2" x 5 1/2" Xover, 5 1/2" collar, Baker PBR Seal assembly with top seal unit, 5 1/2" casing pup joint, Xover, 9 drill collars, Xover. 20:30 - 00:00 3.50 FISH DECOMP RIH with muleshoe cleanout BHA to top of PBR at 10,428 ft. 7/3/2000 00:00 - 00:30 0.50 FISH DECOMP Obtained operating parameters. Tagged top of PBR at 10,425.36 ft. Printed: 8110/2000 11:20:05 AM BP AMOCO Page 9 of 11 OperatiOns Summa Report Legal Well Name: 0~-17 Commo~ Well Name: 05-17 Spud Date: $/17/2000 I=¥ent Name: WORKOVER Start: $/15/2000 Fnd: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es : Date From-TO HoUrs ACtivitY:code Phase Description:of OPeratiOns 7/3/2000 i00:00 - 00:30 i 0.50 FISH ! i DECOMP drill pipe measure. Worked pipe with pump on and tagged PBR several ~ ! I times. Rotated pipe and inserted muleshoe into PBR. i00:00 01:00 - 1.00 FISH I DECOMP Lowered muleshoe rite PBR .0 ft with pump on. Stopped pump and I I/ ~lowered additional 3.0 ft. Took 15K weight. Picked up and muleshoe / stuck. Pulled to 350K, pressured to 2000 psi and torqued to 6K ft-lbs. , 01:00 - 06:00 5.00 FISH[ DECOMP Worked pipe to maximum 400K pull, 6K torque and 3000 psi. Lost ! pressure and began to lose fluid. Inflatable bridge plug in tailpipe failed. !06:00- 06:45 0.75 FISH DECOMP Rigged up Schlumberger. 06:45 - 07:00 0.25 FISH DECOMP PJSM re backoff operations. 07:00 - 10:00 3.00 FISH DECOMP RIH with string shot and backed off pipe in tubing collar at top of muleshoe cleanout assembly. 10:00 - 14:00 4.00 FISH DECOMP Attempted to circulate and losing fluid at rate of 600 bbl/hr. Mixed and spotted 45 bbls of 50 ppb LCM pill. Lossed decreased to 180 bbl/hr. Mixed second 45 bbl LCM pill and regained full circulation while spotting pill. Cleared pill from drill pipe and pumped dry job. 14:00- 17:30 3.50 FISH DECOMP POOH to BHA. 17:30 - 18:00 0.50 FISH DECOMP Stood back drill collars. Pipe backed off in 4 1/2" IF box at bottom of drill collars leaving 4 1/2" IF X 5 1/2" LT&C Xover, 51/2" 17#/ft pup jt., PBR seal assembly, 5 1/2" casing collar turned down to 5 15/16", 5 1/2" LTC X 4 1/2" LTC Xover, 4 1/2" casing collar and 4 1/2" muleshoed pup joint in hole. Total length - 33.94 ft. 18:00 - 19:00 1.00 FISH DECOMP Slip and cut drill line. 19:00 - 20:00 1.00 FISH DECOMP Made up FBHA #18:8 1/8" OS w/6 3/8" grapple, jars, drill collars and circulating sub. 20:00 - 00:00 4.00 FISH DECOMP Began GIH tightening each connection of drill string. 7/4/2000 00:00- 02:30 2.50 FISH DECOMP RIH To 10008, Checking Torque On Each Conn. 02:30 - 03:30 1.00 FISH DECOMP Circ, Wash f/10008-10403 03:30- 04:30 1.00 FISH DECOMP CBU 04:30 - 05:00 0.50 FISH DECOMP Engage Fish, Jar Free w/125 Overpull 05:00 - 06:00 1.00 FISH DECOMP CBU @ 10400' 06:00- 10:00 4.00 FISH DECOMP POH to 350' 10:00 - 12:00 2.00 FISH DECOMP Handle BHA, Break Out & L/D Fish (recovered 33.94') 12:00 - 13:30 1.50 FISH DECOMP M/U BHA # 22 (Muleshoe, XO, Bump, eli Jar, 9 DC), RIH to 310', Fluid 13:30 - Lost 58 BBLS 16:30 3.00 FISH DECOMP RIH w/4" DP to 10394 i16:30- 17:00 0.50 FISH DECOMP Circ 17:00 - 19:30 2.50 FISH DECOMP Pump Hi Vis Sweep, Sand in Returns, Sting Into PBR BBL, Had to Rotate to Get In PBR, Lost 11 BBL 19:30 - 20:00 0.50 FISH DECOMP Space Out With Stinger In PBR BBL, No Trouble Getting In 20:00 - 20:30 0.50 FISH DECOMP PJSM, PJU HES W/L 20:30 - 00:00 3.50i FISH DECOMP Make Tag Run to 10452 w/2", Run 1.75" LIB, Inconculsive, Some Sand on Outside No Marks in the center, Tagged @ 10450-10452 7/5/2000 00:00 - 03:00 3.00 FISH DECOMP M/U & Run 1.75" Pump Bailer, Tag @ 10449, Work to 10452, POH w/Bailer, Bailer Full of Frac Sand, M/U & Run 2" Pump Bailer, Tag @ 10448, Work to 10450, Pull Bailer, Recovered Sand, R/D HES 03:00 - 04:00 1.00 CLEAN COMP P/U Out of PBR, CBU W/Sweep ~04:00 - 07:00 3.00 CLEAN COMP Displace Dirty Seawater w/Clean @ 5 BPM, PJSM 07:00 - 15:00 8.00 CLEAN COMP POH, L/D 4" DP, Hole Static 15:00 - 15:30 0.50 CLEAN COMP L/D BHA 15:30 - 16:00 0.50 WHSUR COMP Pull Wear Bushing 16:00 - 18:00 2.00 RUNCO~i COMP R/U to Run 5 1/2" 13 Cr Completion 18:00 - 18:30 0.50 RUNCOk COMP PJSM, On Running Completion 18:30 - 00:00 5.50 RUNCOk COMP Run 5 1/2" Completion, Had To L/D One Joint & One GLM Pup Printed: 8/10/2000 11:20:05 AM ,,, BP AMOCO Page 10 of 11 Operations Summary Report Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Start: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 7ES Rig Number: 7es Date I From~To HOURS ActiVitYlCOde! Phase DescriPtiOn Of oPerationS 7/5/2000 118:30 - 00:00 I 5.50 RUNCOM i COMP VV/NSCC Connection, Slow Due To Having to Buff wickers & Burrs Out I i [~! i Of Boxes 7/6/2000 00:00 - 17:00 17.00 RUNCOM COMP i Finish Run 260 Jts + Pups & Jewlery, 5 1/2 13CR NSCC R3 Class B RUNCO'!'M I ~TBG to 10429 17'00. 17:30 0.50 COMP ITag Up, Locate, Space Out, Up 195, Down 130K ~ 17:30 - 19:30 2.00 RUNCOI~I~ COMP M/U Pups, Hgr, L J, & Land TBG, RILDS 1 9:30 23:30 4.00 RUNCOM COMP Reverse Circ Clean Seawater w/Corr Inhib 23:30 - 00:00 0.50 RUNCOM COMP Drop Ball & Rod, Let Fall 7/7/2000 00:00 - 01:30 1.50 RUNCOI~ COMP Set PKR W/3500, Hold Pressure for 30 Min. for TBG Test, OK, Bleed ~ TBG to 2000 psi, Test Annulus to 3000 for 30 min. OK, Shear RP Valve , i 01:30 - 02:00 0.50 RUNCOri COMP BackOut Landing Joint, Galled Thread on XO 02:00 - 02:30 0.50 RUNCOI~I COMP Set BPV, Test to 500 psi 02:30 - 03:00 0.50 RUNCOkl COMP PJD & BlowDown Lines 03:00 - 04:00 1.00 BOPSUR COMP Nipple Down BOP 04:00 - 05:30 1.50 VVHSUR COMP Nipple Up Tree, Hanger Threads Damaged 05:30 - 07:00 1.50 VVHSUR COMP Pull BPV, Install Test Plug W/Lubricator, Test Tree to 5000 OK 07:00 - 07:30 0.50 VVHSUR COMP Pull Tree Test Plug :07:30 - 10:00 2.50 VVHSUR COMP PJU to Tree, Freeze Protect w/155 BBL Diesel 10:00 - 12:00 2.00 RIGD COMP Set BPV, Prep to Move, Rig Released 1200 Hrs 7/7/2000 Ancho~e Printed: 8/10/2000 11:20:05AM BP AMOCO Page 11 of 11 Operations Summa Report ..... Legal Well Name: 06-17 Common Well Name: 06-17 Spud Date: 6/17/2000 Event Name: WORKOVER Start: 6/15/2000 End: Contractor Name: NABORS Rig Release: Group: Rig Name: NABORS 7ES Rig Number: 7es Date From- HOurs ACtiVitY Code phase DesCription of OPerations: :: 22:30 - 00:00 i 1.501WHSUR DECOMP Held Rig Wide PJSM With Both Crews & Review Pre Spud Check List, ; Annu us on Vac, Check Under BPV, TBG Dead, N/D Tree, Accepted i' i ! I Rig 2230 Hrs 6/17/00 6/22/2000 ~ 16:00 - 16:20 i 0.33 FISH DECOMP Held D-1 drill. Crew response good - 11/2 mins. 6/25/2000 20:00 20:05 ~ 0.08 FISH DECOMP Held fire drill. Response time 1' 10". i AUG 29 2000 Printed: 8/10/2000 11:20:05AM MEMORANDUM TO: Dan Seamount Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector NON- CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 25, 2000 Nabors 7ES '- Phillips Petroleum Co. DS 6-17 182-090 Operator Rep.: Tom An,qlin Contractor Rep.: Charlie Henley Op. phone: 659-4103 Rig phone: 659-4144 Op. E-Mail: Rig E-Mail: PBURig7estp@BP.com Test Pressures Rams: 250/3500 Annular: 250/3500 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location P Hazard: P ' Standing Order: P "' BOP STACK: Quantity Size P/F Annular Preventer 1 P Pipe Rams 1 P Lower Pipe Rams 1 P Blind Rams 1 P Choke Ln. Valves 1 P HCR Valves 2 P Kill Line Valves 1 P Check Valve N/A P Choke: 250~3500 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm Quantity P/F Trip Tank P P Upper Kelly 1 P Pit Level Indicators P P Lower Kelly 1 P Flow Indicator P P Ball Type 1 P Meth Gas Detector P P" Inside BOP I P H2S Gas Detector P P ,. ACCUMULATOR SYSTEM: CHOKE MANIFOLD: Time/Psi · P/F Quantity P/F System Pressure 3000 P No. Valves 14 P After Closure 1600 P Man. Chokes 1 P 200 psi Attained 32 P Hyd. Chokes 1 P Full Pressure 2 P Blind Covers (All Stations): P N2 Bottles (avg): 6@2200 psi Test's Details The rig was ready to test when I arrived. All BOP equipment was tested and passed its function/pressure test. This is normal for this rig which makes it a pleasure to visit. The hands seemed well versed in their test procedure of which is written out and a copy on hand to refer to if needed. The rig and its surrounding area were very clean and orderly. This rig maintains the highest standards of operation. TotaI Test Time: 2 hours Number of failures: NONE Attatchments: None cc: Ted Sta_~.q (Shared Services drilling) BOP Nabors 7ES 6-25-00 LG 6/28/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X (patch) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2' FNL, 859' FEL, Sec. 11, T10N, R14E, UM At top of productive interval 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, UM At effective depth At total depth 5240' FNL, 2827' FEL, Sec. 11, T10N, R14E, UM 5. Type of Well: Develepment__X Explorato~__ Stratigraphic__ 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-17 9. Permit number / approval number 82-90 10. APl number 50-029-20760 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical 11500 feet 9223 feet Plugs (measured) Tagged PBTD @ 11007' MD (11/26/1998) Effective depth: measured 11007 feet true vertical 8887 feet Junk (measured) Casing Length Size Conductor 81' 20" Surface 2428' 13-3/8" Production 10748' 9-5/8" Liner 986' 7" Cemented Measured Depth True vertical Depth 2361# Poleset 81' 81' 2032 Sx Fondu & 400 Sx PFC 2502' 2502' 500 Sx Class G & 33 bbls PFC 10822' 8765' 325 Sx Class G 1 1490' 9216' Perforation depth: measured 10818'-10848'; 10974'-10994'. true vertical 8761' - 8781'; 8864' - 8877'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 5-1/2", 17#, L-80 PCT @ 10455' MD; 4-1/2", 12.6#, N-80 PCT @ 10536' MD. 9-5/8" X 5-1/2" BAKER SAB PACKER @ 10444' MD. 5-1/2" CAMCO BAL-O SSSV @ 2025' MD. RECEIVED, JUL 15 1999 ~laska 0il & Gas Corm. Anchorage ORIGINAL 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation (shut in) Subsequent to operation 412 Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 2341 5532 Casing Pressure Tubing Pressure 267 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas _ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ .~ ~ Title Arco Wells Group Supervisor Erin Oba~.. '.~ Service Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-17 DESCRIPTION OF WORK COMPLETED SET PATCH Date Event Summary 10122/1998: 11/26/1998: 2/16/1999: 2/19/1999: 2/21/1999: Pulled IBP - element intact. RIH & tagged PBTD @ 11007' MD. Set DWP lower patch section w/element @ 6164' MD. Ran 4.52" x 5.53" drift to 6143' MD. MIRU CTU. Tested BOPE. RIH &tagged lower patch @ 6160' MD. Set 5-1/2" DWP patch assembly @ 6140' MD. FP'd well. POOH. RD. Returned well to production & obtained a valid welltest. ALASKA ,- AND GAS CONSERVATION C :MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing ~ Alter casing -..,- Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 3' FNL, 860' FEL, Sec 11, T10N, R14E, UM. At top of productive interval 379' FSL, 2638' FEL, Sec 11, T10N, R14E, UM. At effective depth 75' FSL, 2477' FWL, Sec 11, T1 ON, R14E, UM. At total depth 39' FSL, 2457' FWL, Sec 11, T10N, R14E, UM. 5. Type of Well Development X~ Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-17 9. Permit number/approval number 82-90 10. APl number 50 - 029-20760 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11500 feet 9222 feet Plugs(measured) PBTD Tagged @ 11018' MD (9/1/96). Effective depth: measured true vertical Casing Length Conductor 81' Surface 2428' Production 10748' Liner 986' 11018 feet 8893 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 2361# Poleset 81' 81' 13-3/8" 2032 Sx Fondu & 400 Sx PFC 2502' 2502' 9-5/8" 500 Sx CIG & 33 bbls PFC 10822' 8765' 7" 325 Sx CIG 11490' 9216' Perforation depth: measured 10818 - 10848'; 10974 - 10994' ORIGINAL true vertical 8761 - 8781'; 8864 - 8877' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10455' MD; 4-1/2", 12.6#, N-80, PCT @ 10536' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 10443' MD; Camco BaI-O SSSV @ 2024' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data JAN 211997 Alaska 0il & Gas Cons. Commission Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 1050 4257 5827 829 4152 584O Casing Pressure .. Tubing Pressure 325 332 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~"~ '~13. '~"~ Title Engineering Supervisor Date /- /~ '? '7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 6-17 DESCRIPTION OF WORK COMPLETED CEMENT PLUGBACK FOR WATER SHUTOFF 4/24/96: RIH & tagged PBTD at 11119' MD. 5/5/96: MIRU CTU & PT equipment. RIH w/CT & pumped gelled sand slurry containing 2200 lbs of 20/40 mesh sand to spot an isolation sand plug across the lower open perforation interval at: 11048 - 11062' MD (Z4) Ref Log: BHCS 7/1/82. POOH w/CT leaving an estimated sand plug top at 11030' MD. 5/7/96: RIH & tagged top of sand plug at 11046' MD. Rigged down. 5/1 7/96: RIH w/dump bailer & tagged top of sand plug at 11010' MD. 5/1 8/96: RIH & retagged top of sand plug at 11032' MD. 5/22/96: RIH w/cement bailer & spotted 1.5 bbls of Latex Acid Resistive cement on the sand plug (above). POOH w/bailer. RD. 5/24/96: RIH & tagged top of cement cap at 10976' MD, indicating isolation of the open perforation intervals located at: 10976 - 11016' MD (Z4) 11018 - 11038' MD (Z4) Ref Log: BHCS 7/1/82. 5/27/96: RIH & retagged top of cement cap at 10976' MD. 7/1 5/96: RIH w/underreamer & reamed through cement to 11003' MD w/biozan. POOH w/UR. RD. 8/2/96: RIH w/perforation gun & shot 20' of perforations as follows: Added Perforations: 10974 - 10976' MD (Z4) Reperforated: Ref Log: BHCS 7/1/82. 10976 - 10994' MD (Z4) Ref Log: BHCS 7/1/82. Used a 3-3/8" carrier & shot the perfs at 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. STATE OF ALASKA ALASKA ( AND GAS CONSERVATION CC~' llSSION REPORT-OF SUNDRY WELL OPEHATIONS 1. Operations performed: operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 3' FNL, 860' FEL, Sec 11, T10N, R14E, UM. At top of productive interval 379' FSL, 2638' FEL, Sec 11, T10N, R14E, UM. At effective depth 75' FSL, 2477' FWL, Sec 11, T10N, R14E, UM. At total depth 39' FSL, 2457' FWL, Sec 11, T1 ON, R14E, UM. 5. Type of Well Development Exploratory Stratigraphic Service ORIGINAL 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-17 9. Permit number/approval number 82-90 10. APl number 50 - 029-20760 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth' measured true vertical 11500 feet 9222 feet Plugs(measured) PBTD Tagged @ 11125' MD (2/6/96) Effective depth: measured 11125 feet true vertical 8965 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 2361# Poleset 81' 81' Surface 2428' 13-3/8" 2032 Sx Fondu & 400 Sx PFC 2502' 2502' Production 10748' 9-5/8" 500 Sx CIG & 33 bbls PFC 10822' 8765' Liner 986' 7" 325 Sx CIG 11490' 9216' Perforation depth: measured 10818 - 10848'; 10976 - 11016'; 11018 - 11038'; 11048 - 11062' true vertical 8761 - 8781'; 8865 - 8892'; 8893 - 8907'; 8914 - 8923' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10455' MD; 4-1/2", 12.6#, N-80, PCT @ 10536' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 10443' MD; Camco BaI-O SSSV @ 2024' MD 13. Stimulation or cement squeeze summary i ~i,,,,~,,,~i.--i 14. Intervals treated(measured) see Attached Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation FEB 21 Representative Daily Average Production or Injection Data ~" ~-~'-~'~ Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1053 4106 5390 -- 282 1184 4276 5526 -- 289 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _,~.~ ~ , ~,-.~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE_._.~ 6-17 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/6/96: MIRU & PT equipment. 20' of perforations as follows: Reperforated: 10996 - 11006' MD (Z4) Added perforations: RIH w/perforating gun & tagged PBTD at 11125' MD, then PU & shot Ref. Log' BHCS 7/1/82. 11006 - 11016' MD (Z4) Ref. Log'BHCS 7/1/82. Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gaslift & obtained a valid welltest. FEB 21 1~6 Oil & Ga~ .cons,, il GeoQuest ~00 W. International Airport Road I:ii !!? ~,nchorage,. AK 99518-1199 il ATT'N: Sherrie · Well Job # Log Description 2/5/96 NO. 1O025 · Company: Alaska Oil & Gas Cons Comm Attn:! Larry 'Grant 3001 :.PorcuPine Drive Anchorage, :AK 99501 Field: Prudhoe Bay ~' , · Floppy Date BL RF Sepia DIR MWD Disk :. ..D..~..S. 4'30 'sT1 ~'~" <~' ~' PROD. PROFILE 960104 1 1 D..S. 5-25 ~,c/.. ! ~ / PROD. PROFILE 960101 1 D.S. 6-17 .. ~,o~, -' c/O PROD. PROFILE 960117 I 1 D.S. 6-17 ~o~ o ~ O DIG.ENTRY & FLUID IMAGING TOOL 960117 I 1' .,-, ,,D.S. 7-6A__ ,, _<~-~: //<~7 TDT-P ;960106 I I "' D.S. 7-15 ~" !,,..,'7' 3 LEAK DETECTION LOG 960115 I 1 D.S. 9:35A _~g -'.:~ / STATIC BHP SURVEY 960102 I 1 D.S. 9-45 ~ (~ -'_/,./~'~ ~TATIC BHP SURVEY 9601 04 I I .... D.S. 9-46 _~_.-/,~27 PROD. PROFILE 960105 1 1 'D.s:'J11-16 ST1 _ _~:'_'~.~ ~ DETEcTION LOG .... '~960111 1 I .... D.S. '!1-1I~ _<~-'/{ ~,'COMP. NEUTRON LOG 960117 1 1 ' D.S. 15-1 ;~ - (~ TDT-P BORAX 960116 I 1 D.S. '15-39 ~ ?__:/-~/~ LEAK DETECTION LOG 960112 I I ...... ~ , · , S I G N E D: _ DATE: R, ECL:!VED FEB Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA(~" , AND GAS CONSERVATION C~'''~'' 41SSION REPORT bt: SUNDRY WELL OPEr'I:ATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development X 74 RKB feet ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3' FNL, 860' FEL, Sec. 11, T10N, R14E, UM 6-17 At top of productive interval 9. Permit number/approval number 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, UM O IGIN L 82-90 At effective depth 10. APl number 75' FSL, 2477' FWL, Sec. 11, T10N, R14E, UM 50 -029-20760 At total depth 11. Field/Pool 39' FSL, 2457' FWL, Sec. 11, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11500 feet Plugs(measured) PBTD Tagged @ 11057' MD (9/15/95) true vertical 9222 feet Effective depth: measured 11057 feet true vertical 8920 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 2361# Poleset 81' 81' Sudace 2428' 13-3/8" 2032 sx Fondu & 400 sx PFC 2502' 2502' Production 10748' 9-5/8" 500 sx CIG & 33 bbls PFC 10822' 8765' Liner 986' 7" 325 sx CIG 11490' 9216' Perforation depth: measured 10818-10848'; 10976-11006'; 11018-11038'; 11048-11062' true vertical 8761-8781 '; 8865-8885'; 8893-8907'; 8914-8923' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10455' MD; 4-1/2", 12.6#, N-80, PCT Tail @ 10536' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 10443' MD; Camco BaI-O SSSV @ 2024' MD 13. Stimulation or cement squeeze summary ~.~ "' J- t · ~ Intervals treated(measured) See Attached 0CT 2 '7 1995 Treatment description including volumes used and final pressure ~aS_k~_ .0il ,& Gas Cons. Commission 14. Representative Daily Average Production or Injection Data ......... o- OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 971 3433 4896 -- 299 Subsequent to operation 1273 3158 6510 -- 311 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations x Oil~ Gas ....-- Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~v~ ~"~, ~ Title Engineering Supervisor Date /O/,~7/'~ ~' Form 10-404~Rev 06/15/88 SUBMIT IN DI~PLICATE GSS cc: KZ, JWP ~ 6-17 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF SAG RIVER 8/1 I/9 5: MIRU & PT equipment to 4000 psi. RIH w/CT to tag bottom at 11067' MD, then PU & pumped gelled sand slurry containing 4100 lbs of sand to place an isolation sand plug over the open perforation intervals located at: 10976 - 11006' MD (Z4) Ref. Log: BHCS 7/1/82. 11018 - 11038' MD (Z4) 11048 - 11062' MD (Z4) POOH w/CT. Rigged down. 8/12/95: RIH & tagged top of the sand plug at 10892' MD. 8/1 5/95: MIRU & PT equipment to 9000 psi. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the open perforations located above the sand plug at: 10818 - 10848' MD (Sag) Ref. Log: BHCS 7/1/82. Pumped: a) 400 bbls 20# Pre Pad Gel @ 30 bpm, followed by b) Shutdown. ISIP @ 1940. Resumed pumping: c) 550 bbls 40# Crosslinked Pad @ 30 bpm, followed by d) 890 bbls Crosslinked Slurry w/proppant stages @ 1 - 8 ppg, followed by e) 225 bbls 20# Gelled Flush, followed by f) Shutdown. Rigged down. Placed 90,600 lbs of proppant into the formation at an average treating pressure of 3800 psi. 8/1 6/95: Performed a CT proppant/sand plug fill cleanout to 10843' MD. Returned the well to production w/lift gas & obtained a valid welltest. OCT Nast~ Oil & Gas Cons. C0rnmissi0n Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9756 Company: 9/26/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description Date BL Prudhoe Bay Floppy RF Sepia DIR MWD Disk D'S.' 1-11 "'~.'"~ {37~ q PRODUCTION PROFILE 950914 1 1 D.S. 1-13~'~,,. O,~"'-q PRODUCTION PROFILE 950916 I 1 D.S. 6-19 ~ ~}~ L~K D~ECTION LOG 95091 5 I 1 D.S. 15-12 ~ ~ }~ TUBING PATCH S~ RECORD 950913 I I SIGNED: .... .~ ____~_-L~z. Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. REC VED ^laska Oil & ~as Co'ns. Gommission Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9683 Company: 8/31/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1..-10 ..' -7 ~-- /-'/:.~,.~ CNTG 950818 I 1 D.S. 01-33'~_.~ I ?---"~-...-- LEAK DETECTION 95 0 8 0 8 I 1 ,, D.S. 6-8 BAKER INFLATABLE BRIDGE PLUG 95 0 812 1 1 D.S. 6-17 ~'~-~ ~t '/~ LEAK DETECTION LOG 950807 1 1 D.S. 9-4A~ ~' CraG 95081 9 I 1 D.S. 9;41 . ~ ~ pRoDuc~oN PROFILE 95 0 810 1 1 D.S. 11-25 ~ ~ [ ~ i CNTD 95081 1 1 1 D.S. 13-34 ~' I ~ ~ PRODUCTION pROFILE 950801 I 1 D.S. 14-18 -~/ ~ STATIC BHP SURVEY 95081 2 I 1 D.S. 15-12 ~ ~ ~ ~ ~ BRIDGE PLUG S~ RECORD 9 5 0 S 0 5 1 1 -, .... Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. R C IVF_.D · · $£P 0 1 19 5 DATE: Alaska Oit & ~s C,o~s. Commission Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9596 CompanY: 7/27/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 2-13A ~'?""t~.i ,~.~.~ ~RODUCTION PROFILE 950701 I 1 D.S. 2-34 G I I q C~ DUAL BURST TDT-P 950702 I 1 D.S. 5-10A ~q ~ ~ PRODUC~ONPROFILE 950703 1 ~ ' 1 D.S. 6-17 ~ '~ , PRODUC~ON PROFILE 950706 1 1 D.S. 7-13A q ~ I ~ DUAL BURST TDT-P 950704 I - i ~ D.S. 7-16 ~' ~ I ~~NJEC~ONPROFILE 950704 I I ~ D.S. 7-33 ~~ ~~- :INJEC~ONPROFILE 950702 1 1 D.S. 7-33 STA~C PRESSURE SURVEY 950 702 I 1 D.S. 7-34 ~ ~ ~ ~ TDT-P aOR~ 950702 I 1 D.S. 7-34~ ~ ~MPERA~RE SURVEY 950 7 02 I 1 9.s. 1~-3~ ,.~ ~~ PERFO~NGRECORD ~S0707 ~ ~ D.S. 11-32 ~ C[ t ~'t PERFO~NGRECORD 950707 I 1 D.S. 14-3 ~' ~' ~~ INF~TABLE BRIDGE PLUG 95 07 05 I 1 D.S. 18-1eA '~,~ ~;~ PRODUC~ONPROFILE 950706 I 1 D.S. 18-18A / ~ ~ ~5~47 TDT-P 950707 I SIGNED _~~ Please sign and return one copy 'of this transmittal to Sherrie at the above address. Thank you. DATE'Ye STATE OF ALASKA ALASKA[' .AND GAS CONSERVATION C(~"~ IlSSION REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well O~er 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 9951O-O36O 4. Location of well at surface 3' FNL, 860' FEL, Sec. 11, T10N, R14E, UM At top of productive interval 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, UM At effective depth 75' FSL, 2477' FWL, Sec. 11, T10N, R14E, UM At total depth 39' FSL, 2457' FWL, Sec. 11, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 11500 feet 9222 feet 5. Type of Well Development X Exploratory ,,, Stral~graphic 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-17 R£C£iV D Gas Cons, C0mmissi0~ Anch0r~' ? feet 9. Permit number/approval number 82-90 10. APl number 50 - 029-20760 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 11070 feet true vertical 8928 feet Plugs(measured) PBTD Tagged @ 11070' MD (4/13/95) OEIGt aAL Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 2361# Poleset 81' 81' Surface 2428' 13-3/8" 2032 sx Fondu & 400 sx PFC 2502' 2502' Production 10748' 9-5/8" 500 sx CIG & 33 bbls PFC 10822' 8765' Liner 986' 7" 325 sx Cl G 11490' 9216' Perforation depth: measured 10818-10848'; 10976-11006'; 11018-11038'; 11048-11062' true vertical 8761-8781'; 8865-8885'; 8893-8907'; 8914-8923'; Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10455' MD; 4-1/2", 12.6//, N-80, PCT Tail @ 10536' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 10443' MD; Camco BaI-O SSSV @ 2024' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 928 3633 4855 - 1 o59 4o84 5161 Tubing Pressure 517 376 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended .. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 cc: KZ, JWP Title Engineering Supervisor Date SUBMIT IN DUPLICATE 6-17 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 4/13/95: RIH & tagged PBTD at 11070' MD. 4/1 5195: MIRU & PT equipment. Reperforated: 10818 - 10848' MD (Sag) Ref. Log: BHCS 7/1/82. Used a 3-3/8" carrier & shot 4 spf at 180 degree phasing at underbalanced pressure. POOH w/perf guns. Noted all shots fired. Rigged down. RIH w/perforating guns & shot 30' of reperforations as follows: Returned the well to production w/gas lift & obtained a valid welltest. Anchor~ ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operati0'ns performed: Operation shutdown Stimulate Plugging Perforate x Pull tubing Alter casing Repair well .... Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 810'SNL, 1735' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 298' NSL, 2394' EWL, SEC. 15, T11N, R13E, UPM At effective depth 326'NSL, 2626' EWL, SEC. 15, T11N, R13E, UPM At total depth 328'NSL, 2648'EWL, SEC. 15, T11N, R13E, UPM 5. Type of Well: Development × Exploratory Stratigraphic .. Sewice 6. Datum elevation (DF or KB) KBE = 79.94 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-17(34-15-11-13) PBU 9. Permit number/approval number 82-190 / 10. APl number 50- 029-20862 11. Field/Pool Prudhoe Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 110 2667 99491 .. ~1292 Tubing (size, grade, and measured depth) 10901 feet Plugs (measured) BKB 9317 feet 10821 feet Junk (measured) BKB 9237 feet fill at 10821'MD (07/88) Size Cemented Measured depth 20x30 8 c.y. 148 13 3/8 3720 c.f. 2705 9 5/8 1559 c.f. 9987 7 391 c.f. 9602-10894 measured 10540'- 2', 10552'- 66',(two interval), 10570~-622'(four interval) Sqzed: 10431-98(eight interval), 10520'-40', 10542-52' (three interval) true vertiCal subsea 8892'-4', 8903'-16'(two interval),8920'-69'(four interval) Sqzed:8790'-852'(eight interval), 8873'-92'~8894'-903'(three interval) 5 1/2" L-80 to 9561' with 4 1/2" tailpipe to 9695' True vertical depth BKB 148 2705 8473 8163-9311 Packers and SSSV (type and.measured depth) 9 5/8" BOTpacker at 9561'; 5 1/2" SSSV at 2151' 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injectior~ Data OiI-Bbl Gas-Mcf Water'Bbl Casing Pressure 1014 10063 111 0 1398 15526 528 0 Tubing Pressure 2103 870 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foreg,eh'~l is true and correct to the best of my knowledge. Signed c~//~ ( // x'~VI~ Title Senior Technical Assistantll Form 10-404'Rev 06/15/88 ~ Date 5'/5'" 9,5' SUBMIT IN DUPLICATE 3/01/94 WELL H-1704-15-11-13) Reperf/NRWO Operation The following interval were reperforated using 3 3/8" guns, 4 SPF, random orientation and 6001120° phasing. 10431' - 10447' MD 03/06/94 03-07-94 A NRWO GSO Maraseal Gel was performed using the following fluids below: 1. RIH AND TIED-IN WITH PERF RECORD/GR/CCL OF 12/29/84, USING TT, XN AND X NIPPLES. GOOD TIE-IN. 2. SANDED BACK WITH 20/40 CL FROM 10,787 TO 10,503 FT BKB IN 3 STAGES. PLACED 100 LBS OF 100 MESH SAND IN LAST 3 BBLS OF SLURRY TO REDUCE PERM. 3. PERFORMED INJECTIVITY TEST AT 1.5 BPM (WHP=1920, CTP=3510). INC. RATE TO 1.6 BPM (WHP=1920,CTP=3730). TAGGED SAND AGAIN, 1 FT DEEPER AT 10,503 FT BKB. OK. FLAG CT AT 10,493 FT. ORDER 180 BBL OF 5% MARASEAL (MI MIX TANK LIMIT IS 120 BBL, SO 180 BBL REQUIRES TWO TANK LOADS SO TWICE THE MIX TIME.) 4. LOAD 5.5" TUBING WITH 94 BBLS OF DIESEL TO PROVIDE 4000 FT OF DIESEL CAP IN TUBING. COOL DOWN PUMPING 140 BBL 73 DEG. SW (FROM ARCO-WSW IS DOWN FOR THE COUNT). 5. PUMPED 176 BBL OF5% MARASSEAL WEIGHTED TO 9 PPG WITH NACL. PLACED 160 BBL BEHIND PIPE. 5% MARASEAL IS HARD TO PUMP AND FULLY CROSSLINKED IN THE 150 DEG CUP IN 27 MIN. TREATING PRESS WAS HIGH DUE TO THE LARGE AMOUNT OF FRICTION AND LARGE NEAR WELL FRICTION. (WATER INJECTIVITY=1920 PSI) 6: WELL JUG TIGHT AFTER GEL SET ON BTM FOR 20 MIN. HELD 3000 PSI, FROM TOP OF GEL AT 10,200 FT. POOH HOLDING 500 PSI WHP WITH PUMP. LEAVE WELL SHUT IN WITH 540 PSI WHP. TUBING FRZ PROTECTED W/DIESEL. 7~ LEAVE WELL SHUTIN FOR 3 DAYS TO LET MARASEAL FIRM UP. FLUIDS PUMPED 590 BLLS SEAWATER 65 BBLS MEDH 94 BBLS DIESEL 63 BBLS 4 PPG 20/40 CL IN 40# GEL SLURRY 18 BBLS 40# GEL SPACERS 176 BBLS 5% MARASEAL WEIGHTED TO 9.0 PPG WITH NACL. 1006 BBLS TOTAL 06~2~4 7/19/94 Page 2 WELL H-17(34-15-11-13) A NRWO Maraseal Gel was performed using the following fluids below: $UMMARY KILL WELL WITH 306 BBLS FSW DOWN BACKSIDE. RIH AND TIED INTO PROFILES. COOLED DN AND SET PKR. DROPPED 5/8" BALL AND OPENED CIR SUB. PERFORMED INJECTION TEST: 1300 PSI @ 1.0 BPM AND 1920 PSI @ 1.7 BPM. PUMPED 115 BBLS OF DIESEL DN BS. COOLED DN WEL WITH 180 BBLS OF 93°F FSW PUMPED DN CT. PUMPED 117 BBLS OF MARASEAL GEL AND PLACED 114 BBLS. LEFT 3 BBLS IN LINER ABOVE PKR. STROKED PKR TO EQUALIZE, AND STROKED TO RELEASE. PKR WILL NOT RELEASE. WORK TO RELEASE. NO LUCK. DROP 7/8" BALL AND TAKE RETRUNS TO BLEED TRAILER TO KEEP FROM OVERDISPLACING MARASEAL INTO FORMATION. DISCONNECT FROM TEL, CIRC SUB AND PKR.. POOH. WILL LEAVE PKR IN WELL FOR 3 DAYS AND THEN WILL ATTEMPT TO PUNCTURE RELEASE PKR. LEAVE WELL SI FOR THREE DAYS FOR GEL TO SET. 15 FLUIDS PUMPED BBLS. 306 100 o F FSW DOWN BACKSIDE TO KILL WELL 44 FSW TO SET PKR 70 FSW FOR INJECTIVITY TEST 115 DIESEL ON BS TO BALANCE BHP 180 50° F FSW DOWN WELL FOR COOL DOWN 117 4 % MARASEAL GEL 34 FSW DISPLACEMENT FSW TO PUMP DISCONNECT BAI~I~ OVER GOOSE NECK . , , The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10570'-10590'MD 10600'-10616'MD R£CEI rcD Oil & Gas Cons. Commission Anchora, ~ GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'i-TN: Sherrie NO. 9443 Company: 5/3/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 3-27 ~-(e,,1,. TBG. PACKER RECORD 041295 1 1 D.S. 4-12 '~-I~ TBG. PUNCHER RECORD 032695 1 1 D.S. 6-17 --" ~ ~~- ~'- ~ PERF. RECORD 041 5 95 1 1 D.S. 14-3 - ~ [ - 3 ~ ~EAK DETECTION 041 095i 1 1 D.S. 16-2 ~ ~0- lEO PERF. RECORD 041195 1 1 D.S. 16-3 -- ~ 1 ~ / / PERF. RECORD 041 0 95 I 1 D.S. 16-14 ~ ~ ~ -~~RI~EPLUGRECORD 041395 1 1 o.s. ~.-~s - ~7'~8 C.E~cn~cu~E. _ 0.~s ~ ~ D.S. 2-24 95154 CNT-D 040695 ,_[ 1 D.S. 18-02A 95159 ~ 041 895 ~ 1 D.S. 15-17 95155 C~ 040595 ~ I MAY O ~ i995 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED Alaska 011 & 6u Cons. C0mmbsbn Anchorage Drill Site: COMMENTS: 6 Well: 17 Mon May 30 19:59:59 1994 K-VALVE DESIGN DOME SET PRESSURE: 310 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 290 PSIG K-VALVE CLASS (A,B,C): A K-valve is designed to dump in-situ when tested. Well will have to be choked to operate under normal conditions. (WITH ATTACHMENTS) J,C. ~SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) FS 3 DS Supervisor PRB 13 (COVER ONLY) L.A. Boughton ATO 1569 (WITHOUT ATTACHMENTS DESIGNED BY: A.W. Brooks~ Drill Site: 6 Well: 17 K-VALVE DESIGN Wed Jan 26 16:53:25 1994 DO~ SET PRESSURE: 280 PSIG @ 60 DEG F FTP @-CLOSE (PSIG): 240 PSiG K-VAL~ CLASS (A,B,C):. B CO~.~NTS: Well operates smooothly and needs higher dome due to changes in well performance Wel.i should dump by opening drain system to common line pressure CC: ENGINEERING FILE / COORDINATOR 'Pm 24 (WITH ATTACHMENTS) J.C. SI~IART / M.G. SHOE~ PRB 20 (WITHOUT ATTACHMENTS) J.E. FAUSETT / C.W. SHU~.fWAY PRB 13 L. A. Boughton (WiTHOUT ATTACH~NTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: Ko L. Martin Printing contents of current screen - wait for message, to clear STATE OF ALASKA ALASKA[ _ AND GAS CONSERVATION O~" AISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown Stimulate X Plugging Perforate X , , Pull tubing ~. Alter casing . Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 3' FNL, 860' FEL, Sec. 11, T10N, R14E, UM At top of productive interval 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, UM At effective depth 75' FSL, 2477' FWL, Sec. 11, T10N, R14E, UM At total depth 39' FSL, 2457' FWL, Sec. 11, T10N, R14E, UM 5. Type of Well Development X Exploratory StralJgraphic Service 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-17 9. Permit number/approval number 82-90 10. APl number 50 - 029-20760 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11500 feet 9222 feet Plugs(measured) Fill @ 11140' MD (9/22/93) Effective depth: measured 11140 feet true vertical 8974 feet Junk(measured) Casing Length Size Cemented Measured depth TrUe vertical depth Conductor 81' 20" 2361# Poleset 81' 81' Surface 2428' 13-3/8" 2032 sx Fondu & 400 sx PFC 2502' 2502' Production 10748' 9-5/8" 500 sx Cl G & 33 bbls PFC 10822' 8765' Liner 986' 7" 325 sx Cl G 11490' 9216' Perforation depth: measured 10832-10834'; 10976-11006'; 11018-11038'; 11048-11062' true vertical 8771-8772'; 8865-8885'; 8893-8907'; 8914-8923' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10455' MD; 4-1/2", 12.6~, N-80, PCT Tail @ 10536' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 10443' MD; Camco BaI-O SSSV @ 2024' MD RE""iV"" 13. Stimulation or cement squeeze summary ~ ~ ~ L) Intervals treated(measured) See attached. Treatment description including volumes used and final pressure NOV 2 3 ]99 Alaska 0il & Gas Cons. Commission 14. Representative Daily Average PrQd~JCtion or Injection Data Anchorage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1855 3478 5362 -- 310 / Subsequent to operation 3149 / 7450 7254 -- 384 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x. Gas_... Suspended_._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FSIogrn;~0-40;4 Rev o6/15L"~88 1066/6 DTK cc: SW, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE ~:~ 6-17 DESCRIPTION OF WORK COMPLETED HYDRAULIC REFRACTURE TREATMENT OF ZONE 4 9/2/93: RIH & tagged bottom at 11063' MD. 9/4/93: Reperforated: 10986 - 10996' MD (Z4) Added perforations: 10996 - 11006' MD (Z4) 9/9/93: Ref. Log: BHCS 7/1/82. Ref. Log: BHCS 7/1/82. MIRU & PT equipment to 4000 psi. RIH w/CT to tag bottom, then pumped gelled sand slurry containing 20/40 mesh sand to place an isolation sand plug over the open perforation intervals located at: 11018 - 11038' MD (Z4) Ref. Log: BHCS 7/1/82. 11048 - 11062' MD (Z4) Made a final top of sand plug tag at 10990' MD. POOH w/CT. Rigged down. 9/13/93: Made bailer runs & bailed out sand to adjust the top of the sand plug to 11005' MD. 9/14/93: MIRU & PT equipment to 8000 psi. Pumped a fullbore tubing/perforation acid wash followed by a Hydraulic Refracture Treatment using 12/18 mesh proppant, through the perforation intervals located above the sand plug at: 10832 - 10834' MD (Sag) 10976 - 10986' MD (Z4) 10986 - 11006' MD (Z4) Ref. Log: BHCS 7/1/82. Pumped 50 bbls 7.5% HCI Preflush @ 5 bpm, to pickle the tubing & clean the perforations, then proceeded pumping the Hydraulic Refracture Treatment consisting of: a) 250 bbls 20# Linear Pre-Pad Gel @ 5 bpm, followed by b) 200 bbls 20# Linear Pre-Pad Gel @ 40 bpm, followed by c) Shutdown. ISIP @ 1560. Resumed RECEIVED NOV 2 3 pumping: hmska Oil & Gas Cons. Commission d) 325 bbls 40# Crosslinked Pad @ 40 bpm, followed by Anchorage e) 482 bbls Crosslinked Slurry w/proppant stages @ 1 - 10 ppg, followed by g) 28 bbls 20# Gelled Flush, followed by h) Shutdown. Placed a total of 33,000 lbs of proppant into the formation. Rigged down. 9/1 9/93 & 9/22/93: Performed CT proppant/sandplug fill cleanouts to uncover open perforation intervals (above), and reached a final bottom cleanout depth of 11140' MD. Returned the well to production w/gaslift & obtained a valid welltest. ~~Alaska,~c. ~O2~x100360 ~orage, Alaska~lO DATE: 10-8-93 77~ ~'7 1-11 _?___.~~_~_ ~4-14i~ 76--~'~.4-15 -17 ~~-21 -21 2~ v~-[~-7.8 7~ ** 9-9 1-25 1-28 8~-ql 14-24 e~ls-~o ~a-75 16-31 17- 1 8-29-93 8-29-93 8-29-93 9-7-93 9-7-93 9-3-93 9-8-93 9-3-93 9-4-93 9-4-93 9-10-93 8-31-93 8-31-93 9-2-93 9-10-93 8-29-93 9-5-93 9-12-93 8-30-93 9-10-93 9-3-93 9-5-93 9-7-93 9-4-93 Prod Proflle/f~~~e~ Run 1, 5" lost0-~ch Prod Proflle/~aa{~~ Run 1, 5" ~u00-u~0Sch Prod ~offie (~lw~~s R~ L 5" ~a~ ~Sch ~j ~offie & S~flc/~O~~~ 5" ~e~Sch ~j ~o~e · S~flc]~'o)~~~ 5"~o~~ch ~ Brat T~P ~~R -- 5" Sch mj ~ome ~ S~c l~'~l~~~- svm-~ ~ Sch ~ B~t T~P R,m 1, 5"~-~eo Sch Perf Record ~-1~o~ Perf Record ~-~~ Production~l~J~-~ USIT (Cement) Color USIT (Corrosion) Color Dual Burst TDTP Run Prod Proffie/Seal?~Tr~ Run Prod Proffiel~i~~ Run · CNL l~co ~ ~:~ Run ~P ~%~ R~ ~ ~tect~l~ R~ Pe~ Record ~zz~a-~$~ R~ GR/CCL (TCP ~e-~) R~ Pe~ Record %~a~o R~ Please sign and return the attached copy as receipt of data. RECEIVED BY_~~~ Have A Nice Dayl : Sonya WsllSCe ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL Run 1, 5" Sch Run 1, 5" Sch Run 1, l"&5" ~ Schq~=~ Run 1, 5"~ tz~-~Sch~ Run 1, 5"lzq~-l~q Sch 1, 5" ~ ~-- Schq%~ 1, 5'~:~'~ Sch ~o~- ~s~ 1, 5" ~e~ Sch ~~ 1, 5" Sch 2, 5" Sch 1, 2" l ~o- ~ Sch 1, 5" Sch 1, l"&5" ~- Sch ~t ~5 1, l"&5" Sch 1, 5" Sch Ap p R 0 VE D__~~__d~'~ d/?d Trans# 93109 # PHH. LIPS PB WELL FH, F~ # BPX # STATE OF ALASKA The correct top logged interval for this log is 12,900 feet. The correct top logged interval for this log is 10,400 feet. ARCO Alaslu~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5'! Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" REFERENCE: ARCO CASED HOLE FINALS ~ ~,~ 1-24A 2-7-93 GRICCLIJewelryiTemp *~ ~1/~ I~ 3-20 4-6-93 Tub!n2 Cutter ~,~~0A 4-13-93 SBT/GR/CCL ~'-~20A 4-28-93 Perf Record 47 ~i~ 4-28-93 Jeweh'y/OR/CCL, Tle-l~' .~ 4-23-93 CNL[OR Color 4-23-93 USIT/GR Color ~ ~ 3-30 ~ ~/-~ 1-29-93 Leak Detect 4-22-93 Static Press/Temp 3-33 6_ 4-16 ~-f~ 4-18-93 Leak Detect Run 1, -10 ??~ ?y~ 1-2-93 Prod Profile Run 1, 5" - 16 ?~'~ ~ 4-20-93 Production Log Run 1, 5" -12A c~ ~ c/4-19-93 Pressure Build-Up Run 1,. .~-6-12A ~ · / 4-24-93 Press/Temp Run 1, 5" ~.~_6-17{;~ 4-35-93 Perf Record Run 1, 5" ~,,~7-4A~:2~ ~ ? 4,23-93 Production Log Run 1, r'&5'.' ~"/7-7A ~$~- 4-21,93 Dual Burst TDTP (Borax) Run 1, 5" a~ .~9-27 ~r ~'~z~' 4-20-93 Perf Record · Run 1, ~9-31A ~-3~ 4-19-93 PFC/GR (Packer 8et) Run 1, 5" 0 , ~. ~.~~-40 ~_! i ~ 1-1-93 ~nJ Profile Run 1, /~./~.~e~~~2'13 ~!~V 2' 1-2-93 Leak Detect Run 1, 5" ~/2-148T F/ /$14-27-93 Leak Detect Run 1, 5" ~'.,~13-20~2-o~ 4-25-93 Leak Detect Run 1, 5" ~.~13-25/~2-c// 12-26-93 InJ Profile Run 1, ~'~-43 ~9-/d~ 1-3-93 Prod Profile Run 1, ~,~g6-27. ~'~. ~i 12-27-92 Prod Profile Run 1, ~'&5" ~,~17-13 ~c/~;?~ 4.18.93 Leak Detect Run I, 2"&5" ~,.~AGI-9~.~:~/ 4-11-93 8BT/GR/CCL Run 1, 2"&5" Please sign and retu~[~e atta~h, gd cd~.y as rec~ of data. RECEIVED ~.~. (~' Have A Nice * ~.. , ~TO-I # CENTRAL FILES # CHEVRON PB WELL FILES. # CLINT CHAPMAN # BPX # EXXON # STATE OF ALAS~ # MOBIL Camco Atlas Atlas 8ch 8ch $ch The correct wen name for thh log is 1-24~ The correct APl# for ~20~ is 50-029-209804)1. The correct APl# for 12-148T is 50~2~5~. Camco 8ch Sch Camco Sch 8ch 8ch 8ch 8ch 8ch Atlas Camco Camco 8ch 8ch Camco Camco Camco 8ch Atlas 6 Well= 17 E-VALVE DE.SION mmmmmmmmmmmmmmmmmmmmmmmmmm .Sat May 01 09=01.'.0! 199_3 COMMENTS: FTP @ CLOSE .(PBIG)= 110 P8I¢ K-VALVE CLASS iA, B, C.) = C mmmmmmmmmmmmmmmmmmmmmmm, will have to be bench tested, Design permits i~cre~sing gas lift r~es, t~creasing w~er cut decreasing post-adperf R,J, I~EINT.8 ATO 1560 .(..WITHOUT ATTAINTS ) o~.) DEBIG~FED BY= A,W, RECEIVED MAY 0 6 199~ ~RCO. ALA~K~ r~.Lmmo~ nAV. OMNIFAX TRANSMITTAL. COVER. SE.ND TO AO0CC ,'-./~ Z~__?mie s~a!~', RM & BLDO..__ .......... PRONF~ ....... PLEASE NUMBI~JI~ AI.I. pAGEg AND U~E IH..~~~h_.O~ PLEASE XEROX COPIF.~ FOR~ REMARKS: () () () () () () ANC ANC OP['I~A.TION$ ENGR - 15~ PR~I, IOi~ O~TIOI~ PURClt~INO- ~RD FL{ ANC KUPARUI~ OPElUkT{O~ KUPARUK HELt~. (~$X) LOS ANO~.~_m ~SAOE CBW PASADENA (ARCO/PARSONS) PLATO - (PRO ~Px. (AIVC) BlOi -0~-~) AOGCC 276-7542 SENT BY ~ OMNIFAX (~)07)65g-$273/~;283 PRUDIIOE BAY M~SSAGE CENTEI~ (9(Y/~59-5128 T1ELEX 09-35335 IF_..~~_NOT,,.REC . , . · K-VALVE Pti ,Jul 03 15:29:05 1992 CLOSE (P$IG)I 190 K-VALV~ CLA~8 (A,B,C)~ ~ : "~:Ln~,..tng cont;ent~s of current, screen Drill Site: 6 Well: 17 K-VALVE DESIGN Fri Jul 03 15:29:05 1992 DOME SET PRESSURE: 235 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 190 PSIG K-VALVE CLASS (A, B, C ): c COMMENTS: Re-run valve after required State bench test · J.C. SMART / M.G. SHOEMAKE J.E. FAUSETT / C.W. SHUMWAY ENGINEERING WELL FILE PRB 24 R.J. REINTS ATO 1551 PRB 20 (COVER) PRB 13 DESIGNED BY: JMS Printing contents of current screen - wait for message to clear RECEIVED JUL 1 7) 1992 Alaska Oil & Gas Cons. Commission Anchorage Drill Site: 6 Well: 17 Fri Jul 03 15:25~40 K-VALVE DESIGN SSSV DEPTH (MEAS): 2024 FTP @ CLOSE (PSIG): 190 PRESS ADJUSTMENT: 95 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR 89 2025 279 2197 67.4 1404 CONDITIONS AT CLOSURE: 89 2025 190 2350 67.4 1404 WELL TEST TEMPERATURE @ SSSV: 183 PRESSURE @ SSSV: 494 GLR LIQ PWF 756 6757 1784 SEP COML PI TEMP PRES DATE SEL 3.67 174 0 06/25/92 Y 736 7229 1634 3.67 174 @CLOSE 183 398 DOME SET PRESSURE: 235 PRIOR DESIGNS: DATE: 12/03/90 o1/o1/81 Ol/Ol/81 SET PRESSURE: 265 FTP @ CLOSURE: 218 0 0 0 0 TEMP: LINEAR NA NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..55086e-5 N= 1.298486 NEW C= ..60245e-5 ENTERED N= 1.298486 Printing contents of current screen - wait for message to clear Drill Site: 6 Well: 17 CK LGR FTP OIL %WTR WELL TEST DATA GOR GLR LIQ 89 2025 279 2197 67.4 1404 84 2016 288 2203 68.7 1439 88 2029 285 2221 66.1 1367 89 3003 298 2437 64.8 1439 89 3047 298 2479 64.7 1441 88 2533' 283 2476 64.4 1469 88 2519 279 2458 64.7 1452 88 2023 276 2635 62.9 1283 -88 2015 280 2377 64.9 1426 89 1532 270 2435 63.8 1273 89 2524 287 2418 65.4 1454 86 2036 278 2460 66.5 1423 756 6757 735 7052 772 6557 940 6926 941 7029 885 6971 873 6969 760 7105 796 6787 688 6729 864 6990 752 7354 Fri Jul 03 15:25:44 1992 PWF PI SEPARATOR DATE SEL TEMP PRES 1784 3.67 174 236 06/25/92 Y 0 0.00 175 245 06/19/92 0 0.00 173 240 06/04/92 0 0.00 172 232 05/24/92 0 0.00 172 234 05/23/92 0 0.00 173 223 05/19/92 0 0.00 172 217 05/18/92 0 0.00 173 223 05/14/92 0 0.00 173 230 05/13/92 0 0.00 174 228 05/09/92 0 0.00 172 226 05/05/92 0 0.00 175 226 04/23/92 ESC=EXIT; Fl=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 2024 FTP @ CLOSE (PSIG): 190 PRESS ADJUSTMENT: 95 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI WPS C= ..55086e-5 N= 1.298486 NEW C= ..60245e-5 ENTERED N= 1.298486 Printing contents of current screen - wait for message to clear ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 1-15 3-7 ?~-~ ? ~ ~ 4-7ST 4-78T 4-9 ~g'3 ~ 4-15 4-42 5-12 ~?-/~/ 2-11-92 66:13~°'~ 22-13-92 17 ~g-~o -11-92 2-9-92 2-27-92 3-1-92 3-13-92 3-15-92 3-1-92 3-1-92 ~?~- ~f/I7-1 2-18-92 7-1 2-18-92 ?~ ~g 9-1 2-28-92 ¢oz~,,'~ 9-2 2-8-92 ?~- ~? 9-18 3-14-92 ~s-~ 9-27 2-7-92 ~ ~---~ ~ / 9-31 2-8-92 Prod Prof Run 1, 5" Camco InJ Profile Run 1, 5" Camco Jewelry R-- 1, 5" Camco Prod Prof Run 1, 5" Camco InJ Prof Run 1, 5" Camco InJ Prof Run 1, 5" Camco PITS Run 1, 5" Camco Prod Prof Run 1, 5" Camco Jewelry Run 1, 5" Camco Prod Prof R,_,_~ 1, 5"Camco GR/CCL/Jewelry Run 1, 5" Camco Prod Prof Run 1, 5" Camco Prod Prof Run 1, 5" Camco Prod Prof R,m 1, 5" Camco I~ Prof Run 1, 5" Camco Prod Prof Run 1, 5" Camco Prod Prof Run 1, 5" Camco RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 Please sign and return the attached copy as receipt of data. AP P R OV EBl~sk~~'~~ Cons. commission Trans# 9207~-T # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO The correct well name for this log is 4-7ST. D~ill Si~e: 6 Well: 17 Sun Jul 21 20:16:06 1991 K-VALVE DESIGN DOME SET PRESSURE: FTP @ CLOSE (PSIG): K-VALVE CLASS (A, B, C ): 315 PSIG @ 60 DEG F 245 PSIG B COMMENTS: K-VALVE SHOULD DUMP IF THE WELL IS FLOWED TO A DE- PRESSURIZED SEPARATOR OR CAN BE BENCH TESTED IF THE FLOW RATE IS TOO HIGH. CC: C.P. FARMER / W.D. COOPER K.M. KENNEDY / W.S. WILDER B.G. HARRIS / T.J. BRASSFIELD ENGINEERING WELL FILE PRB 24 PRB 20 PRB 13 i54 DESIGNED BY: W. H. SMALSTIG Well: Reason for k-valve redesign (recent wellwork performed?)", ARCO Alaska, Inc. Prudhoe Bay Operations~. Engineering K-Valve Design 'CheCklist Date: W- ~ '~ - q I R~cent well test data is accurate and shakeout data confirms watercut? ',/E_ .5 Subject well is producing into the high or Iow pressure commonline? LOu-3 Past 7 day average commonline pressure [ci'O and Iow pressure Subject well's past 7 day average surface flowir~g tubing pressure? '~. ~ O Past 7 da~, IoV~ FTP? ': ~ '7~ Reason' k-):o ~ Is the FTP swinging or spiking? S,.o,',-,a How much?~ % lO 9~ Does the FTP versus CML pressure indicate a choke restriction or' undersized choke? Current Choke setting is at CFR or high limit (wide 'open)? Subject Well is gas lifted? k.) O Gas lift is operating smoothly? ~//~ Any recent gas lift valve changes have been entered into the WPS 'Wellbore Hydraulics Data' Summarize sensitivity analysis below: /WC -_ STATE OF ALASKA ~ 0 ~ ' ~ ALASKA[r`' LAND GAS CONSERVATION C{r MISSION -- ~6 I j~ .~ ~'~ REPORT' F SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X ~'~ Pull tubing Alter casing Repair well ... 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 3' FNL, 860' FEL, Sec. 11, T10N, R14E, UM At top of productive interval 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, UM At effective depth 75' FSL, 2477' FWL, Sec. 11, T10N, R14E, UM At total depth 39' FSL, 2457' FWL, Sec. 11, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic O~er X,,. 6. Datum of elevation(DF or' KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-17 9. Permit number/approval number 82-90 10. APl number 50 - 029-20760 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11500 feet 9222 feet Plugs(measured) 11144' MD; 8979' TVD Effective depth: measured 11144 feet true vertical 8979 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 2361# Poleset 81' 81' Sudace 2428' 13-3/8" 2032 sx Fondu & 400 sx PFC 2502' 2502' Production 10748' 9-5/8" 500 sx Cl 'G' & 33 bbls PFC 10822' 8765' Liner 986' 7" 325 sx Cl 'G' 11490' 9216' Perforation depth: measured 10832-10834'; 11018-11038'; 11048-11062' true vertical 8771-8772'; 8893-8907'; 8914-8923' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10455' MD; 4-1/2", 12.6~, N-80, PCT tail @ 10536' MD Packers and SSSV (type and measured depth)Baker SAB packer @ 10443' MD; Camco 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure L 1 ? 1 91 Gas Cons. Commissi0~ 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2137 3619 5305 4582 '// 7634 4010 Tubing Pressure 252 552 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .. 16. Status of well classification as: Oil X... Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 725 LBL c: D. Warner, ATO-1479 SW JWP SUBMIT IN DUPLICATE DS 6-17 (' .... DESCRIPTION OF WORK COMPLETED CEMENT PLUG, CTU CEMENT SQUEEZE & FRACTURE TREATMENT 3130/91: A Cement Plug was placed in the wellbore for water shutoff as follows: MIRU & PT equipment. RIH w/CT & loaded wellbore w/seawater. Tagged bottom w CT, then pumped 7.5 bbls of cement w/aggregate, laying in a cement plug to 11144' MD (top). Perforations covered by the cement plug were: 11150 - 11170' MD (Z4) Ref. Log: BHCS 7/1/82. 11182 - 11202' MD (Z4) 411/gl: RIH & tagged the top of the cement plug at 11188' MD. Placed well back on production (4/3/91) and determined that a CTU squeeze for water shutoff was required. 5/1 2/91: A CTU Cement Squeeze for Water Shutoff was performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/Seawater, then RIH w/CT & pumped 5 bbls of unaggregated cement, followed by 45 bbls of cement w/aggregate, squeezing perforations at: 10818 - 10848' MD (Sag) 11018 - 11038' MD (Z4) 11048 - 11068' M D (Z4) 11090 - 11100' MD (Z4) 11120 - 11140' MD (Z4) 11150 - 11170' MD (Z4) 11182 - 11202' M D (Z4) Ref. Log: BHCS 7/1/82. An estimated 36 - 41 bbls of cement was placed behind pipe. Could not sustain squeeze pressure over 1000 psi during the squeeze. Contaminated cement & jetted contaminated cement from the wellbore. Mixed another batch of cement & RIH w/CT & pumped 5 bbls of unaggregated cement, followed by 45 bbls of cement w/aggregate, to resqueeze the perforations (listed above). Placed an additional 4 bbls of cement behind pipe, at 3500 psi squeeze pressure held for one hour. Contaminated cement & jetted contaminated cement from the wellbore. POOH. Rigged down. 5/1 6/91: MIRU CT & PT Equipment. RIH w/CT & pumped 14 bbls of gelled sand slurry containing a total of 1900# of 20/40 sand, for prefrac sand placement, to 11072' MD. POOH w/CT. Rigged down. 5/20/91: Reperforated: 10832 - 10834' MD (Sag) 11018 - 11038' MD (Z4) 11048 - 11062' MD (Z4) Ref. Log: BHCS 7/1/82. 6/7/91: MIRU & PT equipment. Pumped a Propped Fracture Treatment through perfs (listed above). Pumped: a) 300 bbls 50# Pre Pad Gel, ~ 40 bpm, followed by b) Shutdown. ISlP @ 1860. Resumed pumping: c) 258 bbls Crosslinked Pad, @ 40 bpm, followed by d) 600 bbls 50# Cross Linked Slurry, @ 2 - 12 ppg proppant concentrations, followed by e) 70 bbls Flush, followed by Shutdown. Placed a total of 64,700 lbs of proppant into the formation. Rigged down. 6/9/91: Performed a sand / proppant fill cleanout to 10831' MD. Returned the well to production & obtained a valid production test. UL t 7 t991 & Gas Cons. Commissi',.~ Anchorage ARCO ALASKA, !NC. F'.O. BOX ~0036~-_ ......... '~-- ANCHORAGE, ALASKA 99510 .. DATE' 6-i ~)-9i .. '- REFERENCE' ARCO CASED HOLE FINAL5' .3,~_' ...... 5=~:9. i'_ .... _TUSING.._CUTTER--~ ........... ~..~~ .... : .... ~ ..... RUN .i..,._.5.~. .............. Olt;5~ ~-~ .... 5-24-9i'",-" CBT - -- ~/~-- ' RUN t, 5' - SCH.-.' ~-Si ~-24-et ;"': CET / ~, ~~ RUN ~,_.5~.-_._:..~._.SCN ..... . ~ ........ ~ .... ~ ........................ "~%~ ...................... ~ %"J~ ' 6-t ';5-24-9t PFC (RETAINER) "~i¢i/_ Z ¢~ RUN t, 5 ." . ATLA2 ~-~ ' '~/2~"o~'/9i' ~EF'T!L06 ' ~_ ~z RU~t~. ,5," :.,' _ '" .... ATL.A~_. ';'~'~'~ .............. ~L2;~;'t ".-'.":'~O~'LAR/p~'R~: ................ ~%"]-' "':"-.'' RUN t ,-'5T ~ :.: ' -. ',--- ." ATLAS ... ~f7 . 5,2.e~9t .~ COLLAR/PERE .............. ~e~'~Z~ ...... 'RUN t_, _.5~ ............ ATLAZ 9-t8 . 5-2e-9t - COLLAR/PERF . ~ RUN t, 5' ATLAS ....... .~t 8.__:_: .... 5:~. :~J~ ........... COLLAR.. (.RETAINER) ............................ RUN l..,.. 5" ,ATLAS t--' ,.. ..... .. AL AS --t' 8-t t.."~.-,:'5,2~'9t ~:~'~Y':TF'FC .:'..~'.t'..:':/::..:~' ':.~::/?': -.~.: ~-?'~'.~L.'"' .RUN ~. , ..5 ,--,~.-.::.:. ~....,' . ...,. , . F'LE~,SE ZZGN.AND .RETURN THE ATTACHED COPY ~S RECEZF'T OF D~TA, -'", .... . . : , · . _... . ..... . .,.....<..:?,., :~.. .... .,.',;, ..:....' :...:?., ..~,...- ' :~/' .:. ~ ........... ~.~ '.5 .... ~,~:.;.; ..... : ................... , ,'-. · ,...' - ~ · , ~' ¢-,. , ,., . .v ..... ¢, ,.' · .;:¢;- ,,.~ -. - , ,' i., '.'. ...... ;'.('t.:' .:}~-:':.',".:~,~: . :, -,..... · · ._ .... .- ..~AVE ...... "' ........ ' .... .... -* . . ~ '~.' .. ., SONY~ ~ALLACE '. ...... :..~[ ........... : ..... :.;='* ........... ~P¢:ROVED'.' . .........' :....: ....... :. ..... ~TO-t 529 -.' :-..: . .....:-._:: .,..,:. TR~NZ~ .9 79 ,,:';_,.::~;:,,,::.; :: ............ .r ~.. .., : . :.:.?':::.:.,:~,?,. ~.. '.t-..~ ?.~,.~.,.'..:.:: ..g ISTRIBUTION '. :,-:? :'. ~.':. "::. :'.~::t '.:~../: ? .... "." .' :". ?;".:'?;'LL~' "'.:~;-.,; 2.: ........ :._.'2~;]j;;:j.;Z~:]~.~.~L-]:'~_:2;::._/Z/..~ ............... : ....... -i"":~-~E'~'~'~'~'[-'~'i~--'7~: ................ ~ PHILLIPS' · ."C':.~':':~.r:.., .:',~::':':.' :' ' ':"":_ ............ = ...... CHEVRO .......................... EB...W LL..FILE~ ........ - D & M R & D ......................... ~ ..... .EXZ ENSI.O ~..E X F'.L 0 R A.T_I 0 N ............ ~... ~ EXXON ~ STATE OF ALAS'KA .::.-... .......................... MAR.A THO. N ............................... ]'E.~CO ..................... ~ ....... = ......... ' ......... ~ .................... ~ MOBIL · ..................................... . PRUDHOE BAY FIELD K-VALVE DOME-PRESSURE-SETTING DATA SHEET Drillsite-Well:i 6-1 7 I Date:l 7/42/90 i Comments:l: Unable to dump to depressurized separator. K-valve is redesigned with a higher dome. Previous Settings: Dome Pres. (PSIG) Closure FTP (PSIG) 260 210 Date 1/26/90 240 180 12/26/89 305 240 3/11/89 Production Data: ROR= 2200 BOPD CFR= BOPD Swing Well (very high or Iow GOR): No @ 88H Deg choke @ Deg choke Choke Priority Well: No Design Rates for Hydraulics Program PH2: Test Date 7 / 11 / 90 Oil Rate 2274 STBO/D Watercut 69 % Formation GOR 1816 SCF/STB Gas Lift Gas Rate 1964 MSCF/D Total GLR 836 SCF/STB Flowing Tbg. Pressure 292 PSIG :low. Wellhead Temp. 174 Deg F Choke Setting 87 Deg Calc. Dome Set Pres. RECEIVED JUL 2;t 1990 Alaska Oil & Gas Cons. uommis$ioa Anchorage Conditions at Valve: Temp. @ SSSV 185 Deg F Pres. @ SSSV 514 PSIG Pres. Adjustment @ SSSV 34 PSIG Notice: This adjustment is at the valver not surface. 286.0 PSlG ~ 60 Deg F JActual Dome Set pres. FTP at K-valve Closure K-valve Type 28 S PSIG ~ 60 Del F 2 6 0 PSIG ~ Surface B (A~ 8~ or C) cc: Ferguson / Farmer,, ~'"CC Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Eng: M.M. Maguire D.S. Supv: Winters/Shumway Prep. by: M.O. Johnson ATO- 1554 PRB-13 PRB-24 L_ G i::;:F T 1:::; O i L.. ..'-.~ i.4 T R (ii; i"-i i:;; G L F: L. i C P i.,,iF F: i C:Si];i::; ]3A ]" E :.E; E L. E C'T' L. ]' F T' GAS i i'-.iJ'EE T i Oi".J P L.O T t II I · ,..;_'. ~ jj .... i.F..' ............... t ............................ !71 ';'" ! T V I) 2 0 2 4 1~..:.: A ::3 I) E F"T' I---I 2 0 :T..:'.'.l. ]" i_t ~:E I::' F;i E S S 4 8 (:I C l:::l :E; E F' F;: E :'.E;:E; :i. 6 ';::",i~) I:::' t-,J. F I Gl_ R ::::: 2 ::::: !D UT44, 6-17,12 07-12-90 2~0x ~ WELL TEST . . TESTED RATES ........................ EXPECTED .... AUG AUG AUG TOTAL LIFT FORM TOTAL TEST FGRI~ T T ~ F ORIFC WELL DATE TIME CHOKE SEP FI'P SEP OIL WTR GAS CAS Z CDR GLR L~GTH OIL NO. Cl]iIP POS TEMP TEST PRES STOl) BFq) MSCFD MSCFD WTR SCF?B SCF/B HOURS STBO SCF/B WTR T P L C INCHES 06-17 07-04 0231 86 175l 2~0 221 2246l 60971 17731 1837l 852 8.0 2206 1806 67 M i Y C 3.50 06--17 06-17 0436 8? 174l -293 . 228 2210! 4887 5%01 17701 6? 18051 840 8.1 2232 16~ 69 i R N G 4.00 0~-17 05-16 2251 83 174 :283 232 2282 5059 6221 2445 69 1655 847 7.9 2296 1544 69 N R H C 3.75 06-17 05-03 1236 83 175 266 229 2286 5043 5474+ 1946 69 1543 747 10.3 2242 1967 68 E R ~ C 4.00 06-17 04-15 0611 88 176 261 224 2251 4850 5038 1962 68 1366 709 8.0 2479 1401 69 M ~ t C 3.50 06~t7 04-!1 0226 88 177 265 227 2474 5398 5424 1958 69 140~ 689 8.0 2352 1389 68 H R ~ G 3.75 06-~7 03-~4 1316 88 ~77 267 229 2349 5103 5207 ~946 68 1388 699 7.9 2435 i461 68 H R H ~ 3.75 06-17 03-04 0~16 86 176 275 236 2424 5177 5496 1955 68 1461 723 7.8 2389 1401 67 N ~ ~ C 9.75 06-17 02-12 1726 88 174 268 230 2448 4868 5873 2443 67 1401 803 7.9 2569 1540 68 H R N C 4.00 06-17 01-30 0706 88 175 285 247 2551 5340 6386+ 2456 68 1540 809 8.0 2398 1357 67 E ~ ~ ~ 3.75 06--~7 01-18 0726 88 174 254 210 2447 4996 5784 2464 67 1357 777 8.1 2375 1438 68 ~ R H C 3.50 WELL SHAkE-OUT DATA ~IELL ENTRY PERCEHT PERCE~T H2S PER [.DC SA~PLE ND. NO. DATE TIME WATER. SOLIDS MILLION EHTERED E:Y TAkE~ FROM 06-'17 12 07-11-90 1400 70.00 0.00 7.0 PRODUCTION SEPARATOR 1! 05-16-~0 1700 42.0 PRD~UCTIDN SEPARATOR i0 04-I0-~0 1630 70.00 %0 PRODUCTION HEADER 9 12-22-89 0320 70.00 0.00 8.0 PRODUCTION SEPARATOR 8 12-11-89 1930 7.0 PRODUCTION SEPARATOR 7 I1-~0-89 2200 59.00 0.00 PRODUCTION HEADER 6 11-29-89 0030 50.00 0.00 12.0 PRODUCTION SEPARATOR ~ 08-21-89 2318 66.00 8.0 FRODUCTIOR SEPARATOR 4 06-28-89 2040 68.00 O. O0 8.0 PRODUCTION SEPARATOR 3 06-03-89 1215 64.00 0.00 5.0 PRO~JCTION HEADER 2 05-16-89 2330 ' 8.0 PROI)UCTION ~EPARATOR 1 05-14-89 2300 44.00 0.00 6.0 PRODUCTION SEPARATOR ARCO ALASKA: INC~ P.O. BOX ~¢';336(3 ANCHORAGE, ALA~KA~ ~'i,,_, '"'~ DATE - 5-8-90 RECEIVED Alaska 0il & Gas Cons. Commission Anchorage REFERENCE' ARCO CASED HOLE FINAL£ 6-i7 - 4 7-i6 i-i ii-3 ti-J2 t - 23 i 2-i F3 2-2~] i3-26 4-25 iS-i iS-ii i5-i5 5-2£:, i6--8 i6-t9 4--i 6-90 4-9-9~3 4-23-90 4-2J-90 4-o3-90.. 4 -2°-90~ 4-'t8-90 4- 'i 7-9~.-} 4-23-9¢~ 4.-i '5-9(3 4- i 5-- 90 PRODUCTION PROFILE PIT2 F'RODLICTION F:'ROFI LE INJECTION PROFILE INJECTION PROFILE F'RODUCTION PROi"-ILE F'RODUCT]:ON F'RC1FI LE F'RODUCTION PROFILE GA2 LIFT SURVEY PRODUCTION F'ROFILE INJECTION F'ROFILE 4/2(:')-2i/9,>} TEMF' SURVEY 4- i i -9,3, 4- i i -9(~ 4-22-90 4-i 4-9~3 4- i i 4- i 4-'i 5-90 LEAK I)ETFCTION 2URVEY PRODUCTION PROFILE TEMP 2URVEY PRODUCTION PROFILE F'RODLJCTION PROFILE LEAK DE'I'ECTION 2URVEY LEAK DETECTION SURVEY RUN i, i'&5' F:UN i RUN i, _,~'" RUN t , 5" RUN i, 5" F:UN RUN i , 5 ' RUN RUN RUN RUN RUN RUN i , RUN i , ~" RUN i , 5' RUN t, 5" RiJN i , .5" RUN t , 5' RUN i 5 F'LEA2E ~IGN AND F..'ETURN THE ATTACHED COPY A2 RECEIPT OF DATA. RECEIVED BY ............ HAVE A NICE DAY! £ALLY HOFFECKER A't'O- t 529 CAMCO C A M C 0 CAMCO CAFiCO CAMCO C A Fi C 0 CAMCO CAMCO CAMCO CAMCO CAMCO ~.AMbO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO C A M C 0 DISTRIBIJTION · ~:~' CENTRAL FILES · ..'"' CHEVRON D & M -~: EXTEN2ION EXPLORATION ¢ EXXON MARATHON ~ MOBIL · ~'"' F' F! I L L I F' $ F'B WELL FILES R & D ~ ~_"~ FI X ' .,FAFE OF ALASKA TEXACO * THE CORRECTED AF'I~ FOR i5-20 12 50-029-2it33. D A 'f' E · 2 -'i 6 - 9 ('~ I::'1... lii;r:':'~:ii: E :~' 16; N ~'::'~ N :() R E"[' LJ I:;.: N "f" 1.'1 Iii; ¢.'~"i"f' (:'~ C H Iii: D C 0 t::' Y r:':~ ;?;: I:;.:l!i: C iii; I F'"[' 0 F' D A T A ,, · ,,. C E d"l" R A L.. F' :1: L. E ~." · '" C H Iii: V R 0 · ,. E >,:' T E N,S' I 0 N E X I::' I... 0 I:;: A T I fi N :~ Ii:' X X ('~ i",!. i'4 ¢'~ "'" I,..~-.i T HON "# H (] B I L DATE~ ~-~-88 REFERENCE: ARCO PRE£$URE DATA i -i t 0-24-88 i-J9 i 0-20-88 2-4 i 0-24-88 4-i 7 i ~-i 2-88 4-St . 9-2i -88 4-S2 9-2i -88 5-i i t ~-i 9-88 5-t3 t'3-t9-88 5-i 5 I 0-t 9-88 6-t 7 J ~-'J 8-88 7-2 J ~}-9--88 7-8 ~ ~-9-88 9-5 J ~-'.~-88 9-29 8-28-88 9-~S 8-28-88 ~ 2-3 ~ 0-~ 4-88 ~2-6 ~ ~-~ S-88 ~2-'J 8 J 0-'~ 2-88 J 2-2~ ~ ~'-J 9-88 J S-~ ~ J 8-6'-88 ~ ~-26 J ~-6-88 ~ J-28 J ~-6-88 J 4-J r3 7'-J ~}-88 J 4--~ ~ 6-~-88 ~ 4-J 7 J G-2()-_o ~ 4-'~ 8 ~ 4-32 ~ ~-7'-88 ~ 5-7 J ~-8-88 ~ 5-J~ ~ ~"9-88 ~ 5-~ 5 ~ 8-8-88 ~ 5-J 9 J ~-8-88 t 5-'~2 t 0-t t 5-25 t 0-20-88 t6-7 tO ~ PWDW~'-t t0-t~-88 BHP--$TATIC GRADIENT BHF'--$TATIC GRADIEN'[ BHP--$TATIC GRADIENT BHP--F'RE$~'URE FALL-OFF BHP--$TATIC GRADIENT BHP--$TATIC GRADIENT BHP--$TA'[ IC GRADIENT BHP--$TATIC GRADIENT BHP--~'TATIC GRADIENT BHF .... S'TATIC GRADIENT BHP--~TATIC GRAD I EN'I' BHP--$TATIC GRADIENT BHP--FLOWING GRADIENT BHP--$TATIC ~_~RADIENT BHP--$TATIC GRADIENT BHP--FLOWING GRADIENT BHP--FLOWING GRADIENT BHP--.F'LOW ING GRAD I EEN'I' BHP--$TA'¥IC GRADIENT BHP--~'TATIC GRADIENT BHP--$TATIC GRADIENT BHP--$TATIC GRADIENT BHF .... FLOWING GRADIENT BHP-.-$TATIC GRADIENT L'Jt"t F'-- $ t' A'i" l C GI~.:AD t ENT BHF .... STATIC GRADIENT BHF .... STATIC GRADIENT BI'ii:: ..... S'TA'F I C GRADIENT BHP--,"~'TAT I C GRADIENT BHF .... ,~'TAT IC GR'ADIENT BHP--$TATIC GRADIENT BHP--S'T. AT I C GRADIENT BHF .... STATIC GRADIENT BHF'--FLOWING GRADIENT BHP--$TATIC GRADIENT PL['"A~;E J~'IGN AND RETURN THE ATTACHED COPY AS' RECEIF'T OF' DISTRIBUTION CEN'f'RAL F ILEE,iS' ~ !::'l--t]]t...L. ~- D & M :~ H..' m. D FX'T'EN,? I Oi'~ EXPLORA'i"i ON ~ Z,'A F' C ~- EXXON. ~ '~"I'A"I'E OF AI_A;,.,'KA MARA'i'HON ~ TEXACO · ~ MOBIL CAMCO CAMCO CAMCO CAMCO OTIS OTI~ CAhCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DATA~ ANCHORAGE~ AI.ASKA 995t¢ DATE: REFERENCE' ARCO 6A2ED HOLE FINAl... 3-5 5-R 6-S 6-8 6-t3 6-22 6-2S 9-.5 9-~4 9.27-1:1t:1 ~ ~-2-87 ~ g-~ -87 9-24-87 ~ 0-25-87 - COI..LAR/PERFORAT !rlN CAI.. I.. AR/PFRFgRAT T ON COI. I...AR/F'ERFORAT l F!N COt.. !...AR/PFRFF1RAT T ON COI...L..AR/PERFORAT I ON C gl... L. AR/F'ERFORAT I ON C OI..I...AR/PERFORAT I ON COl... I... A R/P .F. RFF1RAT T ON C OL..!...AR / F'ERFORAT I ON COL I...AR/PERFORAT IgN COI...I...AR / PERFO. F;:AT T. ON 'COt. [..~R/PERFrlRAT.TON O-g-g? P..OI...!... AR./F'ERFORAT I ON RI.IN t , 5 · RUN t: c;· RI.IN .t: =; · RI. IN ~ .. c~· RI. IN ~., ~., · RI.IN t, 5 · RI. IN .'i. ~ · RI.IN t: 5 · RI. IN 'i.. ~' Fd..IN .t; 5" RUN 'i. 5' RI. JN t: .5' 'l., ,t e-24-s'7 e.,n ;.-. ¢./PE 5FO O RUN F't EAXE XII..T,N AND 'TAF~¢S~P'F nH- DATA. HAVE A NI~Fj' D~Y' ... F EGL,. f BENNETT A T or t ..,,,..9 ,;'.i:i:i:: TRAN..~: Sg.P,'l 6g APPROVED DI2TRISI. ITTgN A'TIAR ATI...AR ATI...&R ATI..A~ ATI..AR ~TIAR ATI...AR ATIA~ ATI_.A~ ATI...A~ ~TLA~ ~'TI...A~ ATI. A~ · ,,.'"- CENTRAl-.. .. FTI...E ~ ,,. · ,,.'"' CHE",/Rf.IN D & M ~ EXTENSION EXPLORATION ~ EXXON MARATHON · ,,.'"' MOBIl- PH I I...I...'[. $ F'lr-4, WEL. I:.. FTFI. · ,,. 2TATE OF . AI...A2KA ~'"' TEXAC..O ARCO ALAXKA, INC, P~o. BOX t~0360 ANCHORAGE, ALASKA 995i 0 DATE: ~2-22-87 REFERENCE: ARCO CASED HOLE FINAl.. 2-t t -87 2-t 2-'87 2-t t -87 PRODUCTION L. OG/Spinner-TempRIJN t, 5' NOISE/TEMPERATURE LOG RUN t, 2' NO.T.,~E/TEMF'ERATURE LOG RtlN ~ , 2' PI...EA..~E .~IGN AND RE".~II~~I~~[;~Y AS RECEIPT OF DATA. HAVE; A N I (.;ES DAY f.,~sI,',a Oil & Gas Cons. Commissio~ Anchorage PEGGY BENNETT ATO- t 529 TRAN£ ~87697,~ APPROVED DISTRIBUTION ~CH ..~CH $CH CENTRAl... FILES CHEVRON D & M EXTENSION EXF'I..ORATION EXXON MARATHON MOBIL. ..-""PHI I...l.. I P,.~' F'B WELl. FILE,.~' .-'~ SAPC ..-'"S'TATE OF ALASKA:' ,~ TEXACO ARCO Alaska, In~ Prudhoe B~,x Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 15, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- DS 6-17 Approval Number' 7-540 DS 6-18 Approval Number: 7-539 Enclosed are the Reports of Sundry Well Operations and Well Completion Reports detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/SAD' sd Enclosures CC' Standard Alaska Production Company File' PI(DS 6-17)W1-3 PI(DS 6-18)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-(~ A{ STATE OF ALASKA i~~ AL ..A OIL AND GAS CONSERVATION CO ..,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. -- 3. Address Post Office Box 1'00360, Anchorage, AK 99510 4. Location of well at surface 3' FNL, 860' FEL, Sec. 11, TION, R14E, UM At top of productive interval 379'FSL, 2638'FEL, Sec. 11, TION, R14E, UN At effective depth 75'FSL, 2477'FWL, Sec. 11, TION, R14E, UN At total depth 39'FSL, 2457'FWL, Sec. 11, TION, R14E, UN 5. Datum elevation (DF or KB) 74' EKD _ Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 6-17 8. Approval number 7-540 9. APl number 50-- 029-20760 10. Pool Prudhoe Ba~, Oil Pool 11. Present well condition summary Total depth: measured true vertical 11500 feet 9222 feet Effective depth: measured 11444 feet true vertical 9183 feet Plugs (measured) Junk(measured) Casing Length Size Cemented Measured depth True Vertical depth Conductor 20" Surface 2502' 13-3/8" Production 10822' 9-5/8" Liner 986' 7" Perforation depth: measured 10818-10848', 11120-11140', true vertical 8762-9018' 2361# Poleset 81' 81' 2032 sx Fondu & 2502' 2502' 400 sx PFC 500 sx Class G 10822' 8765' & 33 bbls PFC 325 sx Class G 11490' 9216' 11018-11038' 11048-11068' 11090-11110' 11150-11170', 11182-11202' Tubing (size, grade and measured depth) 5½", 17#, L-80 plastic coated @ 10428, 4½", 12.6# N-80 @ 10536' Packers and SSSV (type and measured depth) Baker SAB Packer @ 10443'MD, Camco Bal-O SSSV @ 2024'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes Used and final pressure 13. Prior to well operation Subsequent to operation RE£E VED /~laska 0ii & Gas Cons. O0mm~.~ AnCh0ra~JU Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2393 3875 3281 -- 367 4594 3795 2908 -- 349 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 Title Operations Engineering Manager Form 10-404 Rev. 12-1-85 Date ,/7'~,~ Submit in Duplicate STAT16/SN 6-17 S. K. Allsup-Drake (263-4244) Began perforating operation on 9/25/87. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 11048-11068'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 11018-11038'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 10828-10848'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #4, shot interval 10818-10828'MD (6 spf), flowed well to cleanup. Shut-in well, POOH, all shots fi red. Secured well. R.D. Ref: BHCS 7/1/82 " K~AO' STATE OF ALASKA [~ ALAS L AND GAS CONSERVATION MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator ..... 7. Permit Number ARCO Alaska, Inc. 82-90 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20760 ,,, 4. Location of well at surface 9. Unit or Lease Name 3' FNL, 860' FEL, Sec. 11, TION, RitE, UM Prudhoe Bay Unit At Top Producing Interval 10". Well Number 379'FSL, 2638'FEL, Sec. 11, TION, RitE, UM 6-17 At Total Depth 11. Field and Pool 39'FSL, 2~57'FWL, Sec. 11, T10N, RI~E, UM Prudhoe Bay Field , ,, 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 74' RKB ADL 28311 12. Date Spudded 13. Date T,D. Reached 14, Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. o~"Completions 6/17/82 6/30/82 7/13/82I N/A feet MSL'1 1 17. Total Depth (MD+TVD) 18.Plug I~ack'D'epth'(MD+TVI~) 19. Directional Survey I 20. D~pth where SSSV set I 21. Thickness of Permafrost ll500'MD, 9222'TVD 11444'MD, 9183'TVD YES~ NO []I nipple @2024 feet MD I 1900' (Approx.) , ., 22. Type Electric Or Other Logs Run DIL/BHC/GR/SP, DIL/FDC/CNL/GR/Cal, CBL 231 ,...., · ..... CASING,.LINERr AN,,D ~cEME,.NTING RECORD ....... ' ....... ' .' .. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ' 20" ' 9i.'5~' H-40 Surf. 81' ...... 3.0'.! ..... ~361~..,Poleset 13-3/8"~ .. 72.0~ . L,80 Surf. 2502' . !7~" 2032 sx Fondu & 400 sx ! ermafrost C 9-5/8" 47.0~ L-80 Surf. 10822' 12~" ] 500 sx Class. G & 33 bb].~ Permmfrn.~y SOO-95, . . , r .29'.'//,.'....'0 L,80, 10511', 11~90'. ..8~" I . . I · 7','.. .... 325 sx Class G 24. PerforatiOns open to PrOduction (MD+TVD of Top and Bottom and 25. TUBING RECORD ,, interval, size and number) S!.Z.E DEPTH SET (MD) PACKER SET (MD) 10818-10848'MD 6 spf 5%/4%" 10~6 I , ~n4a~ 11018-11038 'MD " 110/+8-11068'MD " 26. ' ...... ~CID, FRAcTuRE, cEMENT SQUEEZE, E"~C. ' ll090-11110'MD 4 spf DEP?,H 'INTERVAL r(Iv~O! AMOUN'~' ~ ~,IN6'oF M'ATERI'AL USED 11120-11140 'MD " 11150-11170 'MD " ...... N/A 11182-11202'MD ,, .......... ,.8762~9018'TVD Ref: BHCS 7./1/a?~ ................ ., 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 2/11/'83II Flowing , ........ Date of Test Hours TeSted ' ' ' PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE IGAS-OILRATIO ..10/&/87 ,:]:...0 ,, TEST PERIOD i~ 191/, .... l~il~.l 3919 Flow Tubing Casing P. ressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cOrr) Press, 3/+9 EI/A 24-HOUR RATE I~ /+59/+ 3795 2908 26./+ '28. ' .......... CORE D~TA ' ' BHe'f'~lescriP'ti~n of lithol~gy, poro'sity, fractures', apparent dips and 'presence 'of 'oil, gas 'orrwate'r.r Submit c'ore 'chips, '" ' . .... 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, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad lerochit 10972 ' 8863' N/A O/W Contact 11350 9119 Base Sadlerochit Not Reac[ ed 31. LIST OF ATTACHMENTS , __ 32. I hereby certify that the foregoing is true and correct to'the best of my knowledge Signed _ Title ODer. Engr. Mgr. 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. ~ · ~i .'~'~ Item 16 and 24: If thi~ 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. AL ~ OIL AND ~A$ CONSERVATION ~O ,,1551ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate I~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P_ N. Rn× 1NN~fiN_ Anchnrnnc,_ AK QqR1N 4. Location of well at surface 3' FNL, 860'FEL, Sec. 11, TION, R14E, UM At top of productive interval 379'FSL, 2638'FEL, Sec. 11, TION, R14E, UM At effective depth At total depth 39'FSL, 2457'FWL, Sec. 11, TION, R14E, UM 5. Datum elevation (DF or KB) 74' RKB 6. Unit or Property name PrlidhnP Ray Iinit 7. Well 8. Approval number 461 9. APl number 50- 029-20760 10. Pool Feet Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11500 feet 9222 feet Plugs (measured) Effective depth: measured true vertical 11444 feet 9183 feet Junk (measured) 12. 13. Casing Length Structural Conductor 20" Surface 13-3/8" Intermediate Production 9-5/8" Liner 7" Size Cemented Measured depth 81' 2502' 2361# Poleset 2032 Sx Fondu & 400 SX PFC True Vertical depth 500 Sx Class G & 33 bbls PFC 325 Sx Class G Perforation depth: measured 11090-11110', 11120-11140', 11150-11170', 11182-11202' true vertical 8868-8943' Tubing (size, grade and measured depth) 5~" 17#, L-80 PC @'10428'MD; 4½" 12.6#, N-80 @ 10536' Packers and SSSV (type and measured depth) Baker packer @ 10443'MD Camco Bal-O SSSV @ 2024'MD 10822' 11490' Stimulation or cement squeeze summary Intervals treated (measured) See attached Treatment description including volumes used and final pressure 81' 2502' Representative Daily Average Productior~t~'~ctio~-Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 8765' 9216' Tubing Pressure Prior to well operation N/A Subsequent to operation 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 Title Operations Engineer Manager Form 10-404 Rev. 124-85 WELLS2/04 J. L. Brady, ATO 1502, 263-4245 Date ~//¢~ Submit in Duplicate~ Drill Site 6-17 DESCRIPTION OF PROPOSED WORK ARCO Alaska, Inc. intended to perform an EDTA pre-flush and an amine phosphonate inhibitor squeeze on DS 6-17. The operations were cancelled. No work was performed. ARCO Alaska, Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 17, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 6-17 DS 6-18 Permit No. 82-90 Permit No. 82-99 Enclosed is the "Intention'' Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/SAS:sd Enclosures CC: Standard Alaska Production Co. File Pl(DS6-17)W1-3 P1(DS6-18)W1-3 RECEIVED AUG 1 8 Alaska 0ii & Gas Cons, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchlieldCompany AR3B--6132-C A J~ OIL AND GAS CONSERVATION CO/" ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~, Amend order [] Perforate ~' Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well ~at surface 3' FNL, 860 FEL, Sec. 11, TION, R14E, UM At top of productive interval 379'FSL, 2638'FEL, Sec. 11, TION, R14E, UM At effective depth 75'FSL, 2477'FWL, Sec. 11, TION, R14E, UM At total depth 39'FSL, 2457'FWL, Sec. 11, TION, R14E, UM 5. Datum elevation (DF or KB) 74' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 6-17 8. Permit number 82-90 9. APl number 50-- 029-20760 10. Pool Prudhoe Bay 0il Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11500 feet Plugs (measured) 9222 feet 11444 feet Junk (measured) 9183 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface 2502' Product i on 10822' Liner' 986' Perforation depth: measured true vertical 20" 2361# Poleset 81' 81' 13-3/8" 2032 sx Fondu & 2502' 2502' 400 sx PFC 9-5/8" 500 sx Class G 10822' 8765' & 33 bbls PFC 7" 325 sx Class G 11490' 9216' 11090-11110' 11120-11140' 11150-11170' 11182-11202' RECEIVED 8943-9018' Tubing (size, grade and measured depth) AUG 1 8 1987 5½", 17#, L-80 plastic coated @ 10428, 4½", 12.6# N-80 @ 10536/~laska Oil & Gas Cons. Commiss, Packers and SSSV (type and measured depth) Baker SAB Packer @ 10443'MD, Camco Bal-0 SSSV @ 2024'MD Anchorage 12.Attachments Description summary of proposal J~ Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,,~certify that thee foregoing is true and correct to the best of my knowledge Signed Z~/~~.<~/C~_¢...~ 'Title Operations Engineering Manager Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test [] ~o~ca;tiorl. clearance by order of ~;::~'/ ~ ~ ~, ,~'~'~ Commissioner the commission Date Form 10-403 Rev 12q-85 (SAD) 263-4242 Submit in tripli(~ate?., ARCO Alaska, Inc. proposes to add perforations within both the Sadlerochit interval and the Sag River formation in well 6-17. The proposed perforation intervals are as follows: Existi.ng Perforations Proposed Perforations Sag River 10818-10848'MD (30') 11090-11110'MD (20') Sadlerochit 11018-11038'MD (20') 11120-11140'MD (20') 11048-11068'MD (20') 11150-11170 'MD (20') 11182-11202 'MD (20') Ref: BHCS 7/1/82 A 5000 psi WP wireline lubricator and BOP, tested to 4000 psi working pressure prior to the job, will be utilized for this operation. RECEIVED AUG 1 8 1987 'Alaska Oil & Gas Cons. Commission Anchorage ~ _ iiiii j i ii J l i i 41 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) ,:3.5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF RECEIVED AUG 1 8 1987 Alaska Oil & Gas Cons. Commission Anchorage N I REL I NE BOP EQU I PHENT DATE: June 24, t987 R~,-,..RENCE: ARCO Magnetic Tape~ w/ti.si ing t '--t A 5-.-t 0-8'? Magtape :.':.30t t CI.-I CNL/M$ Dre~s 2-t6 .)-t4--87 Mag't~pe $30t6 CH CNI_/M~ Dres'.s · ~ j · -i 6--t7 5-t0-87 Magfape ~'SOt2 CH CNL/MS Dre.s's' 7 .... t5 5-t 5-87 Mag't'p.ape~017 CH CNL./M~ Dre~s' F:'Lea.~e .sign and return 'l'he ai'tmctled copy a~ r'eceip't of daTa. I:;.:ec e i red HAVE A NICF Ro_~'a ri'ne Peek ATO .... i 5291::' 'I'I:i:ANS f~873t 9 Al:> p roved R El E · x,-.--/Alaska 011 & Gas Cons. Commission AnChorage D I $'r R I B U T I 0 N -"' CentraL Fi Le.s '"' F:'hi LLips Chevrc~r~ F'B We[ [ F'i [es' I) & M R & I) ~' Sohio F:'~ M c F:'h e e t e r s' ~' State of ALaska · "'E x × o iq H a r a 't h o in T e x a c o Mol') i t PS. 7--/b"~, o5 4~q_ D- ~a~ed- R~ra'o=- ?ua/ ARCO Alaska0 Inc. P.O. Box i00360 Anchorage, Alaska DATE: June 4, t987 REFERENCE' ARCO .. Cased Hole Final t-tA 5-t(}-87 CH CNL/GR Run t, 5' Dress: 5-t6 5-2t -87 FLowmeter Log Run t, 5 · Ca,nco 6-t7 5-tG-87 CH CNL/GR Run t, 5" Dre~s 9-4 5-t 8-87 GR/Te~np. ~urvey Run t, 5" Camco t3-34 4-t 5-87 Leak De~/Prod. Log Run t, 5" Camco 18-~ 5-27-87 Pun~p-In Temp ~urvey Run t, 5" Camco PLease sign and return the attached copy as receipt of data. Received By,. HAVE A NICE DAY! Rosanne Peek A'¥0-t529 TRANS ~87285 Approved DISTR Central Fi Les Chevron D&M Extension Exploration Ex x on Marathon Mob i [ · .-Phi LLips F'B WeLL Fi Les R &D ~L . -..~.,$oh i o ~.~, .... ~$ta~e of Alaska · . Texaco ARCO Alaska, Inc.[~/ Prudhoe Bay Engineering Post Office Box *100360 Anchorage, Alaska 995.10-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 9, 1986 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-17 Permit No. 82-90 Dear Mr. Chatterton: Attached is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve SFS/aLB/jp At tachment cc: Standard Alaska Production Company Pi(DS 6-17)W1-3 Alaska 0il & Gas Cor~ Anchora? JLB2/22 ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging , Stimulate j~ Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 3' FNL, 860' FET., Sec. 11, T10N, R14E, UM At top of productive interval 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, UM At effective depth 75' FST,, 2477' FWL, Sec. 11, T10N, R14E, UM At total depth 39' FSL, 2457' FWL, Sec. 11, T10N, R14E, UM 11. Present well condition summary Total depth: measured 11500 feet Plugs (measured) true vertical 9222 feet 5. Datum elevation (DF or KB) 74' RKB 6. Unit Qr Property name Prudhoe Bay Unit 7. Well number 6-17 8. Permit number 82-90 9. APl number 50-- 029-20760 10. Pool Prudhoe Bay Oil Pool feet Effect)ye depth: measured 11444 feet Junk (measured) true vertical 9183 feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 11090'-11110', 11120'-11140' true vertical Size Cemented Measured depth ~ue Vertical depth 20" 2361# Poleset 81' 81' 13-3/8" /2032 sx Fondu & 400 sx Permafrost C/2502'/2502' 9-5/8" /500 sx Class G & 33 bbls Permafrost C/10822'/8765' 7" 325 sx Class G 11490' 9216' , 8868'-8943' Tubing(size, grade and measured depth) 5-1/2" 17# L-80 plastic coated 10428' & 4-1/2" 12.6# N-80 10536' Packers and SSSV (type and measured depth) Baker packer @ 10443' MD.'. Camc. n Ba]-0 ,~ggV ¢. 2024' MD 12.Attachments Description summary of proposal I~ Detailed operations program [] i 0 1,986 Alaska 0il & Gas Cons. Comb Anchorage BOP sketch 13. Estimated date for commencing operation October 13, 1986 14~ If proposal was verbally approved Name of approver Date approved 15.1 hereby c/eirtify that t,l~e f~ego~.~g is true and correct to the best of my knowledge I/ Signed ~/~,~,~{(x' ,~ ~ Title Operations Engineerin~ Manager Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Returned Commissioner I Approval No..~_~E¢/ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate DESCRIPTION OF PROPOSED WORK ARCO Alaska, Inc. intends to perform an EDTA pre-flush and an amine phosphonate inhibitor squeeze on DS 6-17. performed in the following manner: The operations will be 1. Obtain a well test. 2. Move and RU pump trucks. 3. Perform inhibitor squeeze as follows: 48 bbl of EDTA 107 bbl of amine phosphonate inhibitor blend 587 bbl of diesel Oil will be used to displace these solutions to the formation. 4. Shut the well in for 12 hours. e Obtain a well test. JLB2/22 P,. 0, B:'.:'.., x 'i (i)OS6(~ 'T' F;..' A N ;:?., '.ii: ii!', aS t i 2 )i) ]1 ,?? 'i" [;.'. iil B U 'T' iii (J jJAN 2 Oil & Gas 6ons, ~ommtssion'- Anchorage r': '¢;: t.i i t ]" :2: :,;.: e !. F;; ,?!,: D .il. 4'~ . · :r ,.'.'. ~...~ i i 0 · "' i" ~::, X -:':'t r' f] .~- . ........ :-- i i.e,:!: ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: June 5, 1985 Reference' ARCO Pressure Data 6-4 Static Gradient 6-14 Static Gradient 6-17 Static Gradient 6-18 Static Gradient 18-1 PBU 4-28-85 Camco 4-28-85 Camco 4-21-85 Camco 4-28-85 Camco 5-18-85 Camco Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 133 Chevron D& M Expl. Services Ex:. Exploration Exxon Marathon Mobil Phillips PB Well Files R & D Sohio, State of Alaska Texaco ARCO Alaska, Inc.( Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date: January 29, 1985 Reference: ARCO CH Finals ~_~4-6 Prod. Loggoing Svs. 1-9~ Production Profile 12-19Injection Profile 4-14 Spinner 18-3 Prod. Logging Svs. 4-4~.~Spinner 1-9 CNL ~5-9'/Depth Determination ~12-22Perf. Record 12-28Perf Record EPL .... ~2-27Perf. Record 4-8 Spinner 4-15 Spinner ~-6-3 Spinner ~.~R3-18Spinner ~'6-3 Diff. Temp. __--15-9 Collar Log .2-15 Temp. Survey 12-27-84 #1 DA 5" 1-3-85 #1 Camco 5" 1-2-85 #1 Camco 5" 12-16-84 #1 GO 5" 1-10-85 #1 DA 5" 12-15-84 #1 GO 5" 12-20-84 ~1 GO 5" 11-9-84 ~1 Sch 5" 11-29-84 ~1 Sch 5" 12-3-84 ~1 Sch 5" 10-4-84 31 Sch 5" 12-1-84 ~1 Sch 5" 12-27-84 ~1 GO 5" 12-16-84 ~1 GO 5" 12-21-84 ~1 GO 5" 12-2§-84 ~1 GO 5" 12-21-84 ~1 GO 5" 12-2~-84 ~1 GO 5" 12-24-84 #1 GO 5" and return tha attached copy as receipt of data. Received by Pam lambert ATO i429C Chevron D & M Exploration Services Extension Exploration Texaco ~arathon Mobile Mmbile E & P Phillips Prudhoe Bay Well Files R & D Sohio State of Alaska ARCO Alalka. Inc. II a Subsidiary of AtlarlticRIchlleldComl;)any : : ARCD A La:=':km, Irlc'~ F',.O,, B.'.:)x i8O360 Ant: h o'r' a g e, -A !. ask m / i> ... S~ i .... i ~-":~'-" i ,.':>-'.~i -84 // D,. 3:... i ---4 i 0.-22-S4 Alaska Oit & Gas Cons. Commission Anchorage t""" :.: .:':i hi (.'1. C'.-' L.....'.-i fl] C. C) [;: .[.',, m C .'.':) L....-'.'i fl,' C .:.'%' F:'i Les D' i ;ii.' "[' i:;.L i }}:, U '¥' i 0 N Alaska Oil & (~c,s ¥~s. L;uiilIllJssJor~ Anci~o=rage ARCO Alaska, in~/' Post office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, Reference: 1984 ARCO Pressure Data 3-15-84 PBU/CDBR Otis 5-25-84 PBU/CDBR Camco 5-30-84 PBU/CDBR GO 5-25-84 PBU/CDBR Camco 6-29-84 PBU Camco 5-24/25-84 CDBR GO 6-16-84 Static Survey GO 6-15-84 Static Survey GO 6-14-84 Static Survey GO 6-14-84 Static Survey GO 6-30-84 PBU GO 7-2-84 PBU/CDBR GO 6-20-84 Static Survey Camco 6-20-84 Static Survey Camco 6-21-84 Static. Survey Camco 5-19-84 CDBR 5-20-84 CDBR 6-22-84 PBU/CDBR Camco 6-28-84 Static Survey Camco CDBR CDBR CDBR CDBR -84 CDBR CDBR D.S. 1-4f D.S. 1-25 D.S. 1-26_r- D.S. 3-19 D.S. 3-22f'' D.S. 3-23-~ D.S. 6-17-~' D.S. 7-7A:~-~'~ D.S. 7-13 D.S. 7-14 D.S. 7-16~-~ D.S. 7-16 D.S. 9-8v D.S. 9-18/ D.S. 12-16J D.S. 12-17-' D.S. 13-33--- D.S. 14-8 D.S. 14-23 '~--5-16-84 D.S. 14-24~ 5-17-84 D.S. 14-25 5-18-84 D.S. 14-32~' 5-20-84 D.S. 14-33~- 4-29/30 D.S. 14-34 f 5-19-84 /P/lease ~ data. sign and return the attached copy as receipt of Kelly McFarland ATO-1429F Trans. 9290 DISTRIBUTION ~hevron D&M Dr i 11 ing Exp. Services Ext. Exploration Exxon Get ty Marathon M0bil E & P Chorage' Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office B~ 360 Anchorage,,[ ka 99510 Telephone 907 277 5637 April 13, Reference: 1984 ARCO Pressure Data D.S. 6-9f 3-23-84 Static D.S. 6-17 ~ 3-24-84 Static D.S. 7-16 ~ 3-10-84 Horner Plots w/listing D.S. 12-8B-~ 3-22-84 Static D.S. 12-19 J3-21-84 Static D.S. 14-8 f 3-23-84 Static D.S. 14-27 ~ 4-2-84 Static D.S. 14-32f- 4-2-84 Static D.S. 14-34f3-25-84 Static D.S. 15-4j 3-15-84 PBU 3-15-84 Common Data Base Report D.S. 15-13f 3-11-84 PBU 3-11-84 Common Data Base Report Camco Camco Sch Camco Camco Camco DA GO DA Camco Camco gn and return the attached copy as receipt of data. FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFarla~evron ATO-1429F Trans. # 148 DISTRIBUTION D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files Carolyn Smi t~ / Sohio State of Alaska ARCO Alaska, Inc. Post Office ~ 360 Anchorage,*%~,..ska 99510 Telephone 907 277 5637 December 27, 1983 Reference: ARCO Pressure Data ~~.S. 6-17 12-9-83 Static ~.S. 7-16 12-4-83 Static ..S. 7-17 12-5-83 Static ~,'~.S. 7-19 12-9-83 Static p~.S. 7-22 12-5-83 Static .~-D~. 7-24 11-19-83 Static S. 7-25 11-21-83 Static .S. 7-26 11-21-83 Static ~D.S. 13-14 12-7-83 Static Camco Camco Camco GO Camco DA DA DA DA se sign and return the attached copy as receipt of data. Kelly McFar land ATO-1429F Trans. # 702 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroline Smith Sohio ARCO Alaska, inc. Post Office Bp,,',' 360 Anchorage.~(' ;~a 99510 Telephone 907 277 5637 September 21, 1983 Reference' Arco Pressure Data D.S. 2- iA 7-6-83 7-6-83 D'.S. 6-17 ~'/ 9-1-83 D.S. 7-2 ~/' 8-27-83 8-27-83 D.S. 11-2 ~"'" 8-25-83 8-25-83 D.S. 13-4 ~' 8-31-83 D.S. 13-14 / 8-31-3 D.S. 13-18 ~/ 8-31-83 Pressure Build-up Pressure Build-up Data Sheet Static Survey Pressure Build-up Pressure Build-up Data Sheet Pressure Build-up Pressure Build-up Data Sheet Static Survey Static Survey -- Static Survey se sign and return the attached copy as receipt of data. Otis Camco GO GO DA Otis DA .. Kelly McFarland ATO-1429F Trans. # 524 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTF~IBUTION North Geology Phillips Prudhoe Bay R & D Caroline Smith Sohio State of Alaska ARCO Alaska, Inc.~' Post Office Box 360 Anchorage. Alaska 99510 Teiepho?e 907 ~77 July 26, 1983 Reference: Arco Pressure Data * D.S. 4-8 .~ .... 6-22-83 Pressure Falloff Survey w/Print-out D.S. 6-17~ · D.S. 6-19 6-30-83 6-30-83 6-30-83 Static Survey Pressure Build-up Pressure Build-up S,~rvey Report D.S' 6-22/' 7-3-83 7-2-83 D.S. 9-1~" 7-9'83 7-8-83 Pressure Build-up Pressure Build-up Survey Report Pressure Build-up Pressure Build-up Survey Report D.S. 12-7A 7-6-83 7-6-8'3 D.S. 18-7 5-18-83 5-18-83 Pressure Build-up Pressure Build-up Survey Report CORRECTED Pressure Buils-up Pressure Build-up Survey Report * Please note there is a typo on this, it is labeled as a dr~wdown, but is in reality a falloff. //~lease sign and return the attached copy as receipt of data. Sch Otis Otis Otis Camc, Camc, DA Kelly McFarland ATO-1429D Trans. 9 445 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips~ Prudhoe B~~_ ~. Sohio State of Alaska ARCO Alaska, Inc. ~* Prudhoe BayI~,.=lineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 27, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: ~'i~ DS 6-18 DS 6-19 DS 6-20 DS 6-21 DS 6-22 DS 6-23 DS 6-24 Permit No. 82-90 Permit No. 82-99 Permit No. 82-114 Permit No. 82-124 Permit No. 82-127 Permit No. 82-i31 Permit No. 82-133 Permit No. 82-i 47 Enclosed are the Completion Reports for work done on the abOve-mentioned wel 1 s. Very truly yours, D. [, $cheve Regional [n§~neer DFS/JCD/lw Enclosures cc: Sohio Petroleum Co. ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRIchfleldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, ]]nc. 82-90 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20760 4. Location of well at surface 9. Unit or Lease Name 3' FNL, 860' FEL, Sec. ll, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval lO..Well Number 379' FSL, 2638' FEL, Sec. ll, T10N, R14E, UM 6-17 At Total Depth 11. Field and Pool 39' FSL, 2457' FWL, Sec? ll,. T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 74' RKB .] ADL 28311 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/17/82 06/30/82 07/13/82 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD-F'I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost l1500'MD,9222'TVF~ l1444'MD,9183'ME YES~ NO[:]Inipple@202~etMDl 1900' (approx) 22. Type Electric or Other Logs Run II~I/BH£/GR/SP. DII/FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9! .5# H-40 qurf Rl' 3fl" 23fi1# !3-3/8" 72.0# L-80 Surf 7507' !7-1/?" 7032.~x Fondu & 400s~ Permafrost o_~/~,, /17 n~ I_RN ~, o,,,w~ 1NR??' 17-1/~" Rflfl~ £1a~ ~ ~ 3.~ hhl~ P~rmafrost S00-95 .7" '29.0# L-80 lnEll' 11490' 8-1/2" 325sx Class G 24. Perforations open to Production '(M'D+TVD of Top and Bottom and 195. TUBING RECORD ,,, interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11090-11110 MD 4 spf 5-1/2"/4-1/',!" 10536' 10443' 11120-11140 MD 11150,11170 MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11182-11202 MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8868- 8943 TVDSS Ref' BHCS N/.A 7/1/82 .. . · · , 27. PRODUCTION TEST Date First Production Method of'Operation (FlOwing, gas lift, etc.) ?'/ll/F3 Flowing Date of test-' - Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ~;/79/R'q 17 ~, '" TEsTpERIOD ~ 196g ·939 476 87 · I 726 ... FIo"v~'l~u~n~- Casin~'Pr'essure CALCULATED' OIL-BBL GAS-MCF WATER-BBL IOILGRAVITY-API(corr) Press. 8!7 N/A 24_HOURRATE I~ 3250 2·359 918 26.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10972' 8863' N/A 0/W Contact 11350' 9119' Base Sadlerochit Not Reached : 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~"~~~~ Regional ,~/~¢~ Signed Title ~' n n '~' n¢,"', ~' Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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. ~ltem 16 and 24: If this well is completed for separate production from more than one interval (multiple completioq), 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 suppleme,ntal 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.( Prudhoe Ba~ .-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: ~!!?!~ Permit No. 82-90 D.S. 2-19 Permit No. 81-186 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmi Attachments cc: Sohio Petroleum ECEIVED JUN 2 8 983 Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASK IL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER []~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-90 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20760 4. Location of Well 3' FNL, 860' FEL, Sec. 11, T10N, R14E, UM 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, UM 39' FSL, 2457' FWL, Sec. 11, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 74' RKB I ADL 28311 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 6-17 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO, Alaska, Inc. intends to replace the surface controlled subsurface safety valve in DS 6-17 with an Otis Type K, ambient type tubing safety valve. This valve is a normally-closed type with a preset dome charge. The valve uses a plunger and seat for its seal and closes when flowing tubing pressure drops below the preset dome pressure charge. Pressure must be applied to the tubing from the surface to reopen the valve. This change is necessitated by the loss of both surface control lines to the valve which was previously in place. Well 6-17 is completed with 5%" tubing and presently produces with a capacity of 3500 BOPD at a tubing pressure of 800 psi. Its producing GOR is 730 scf/STB. Approved Copy Returned t ECEIVED. JUN 2 8 983 Alaska Oil & Gas Cons. Corn~liss[o~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _~01t% ~ ~2---j ,~:;~C~ Title The space below for Commission use Date C°nditi°ns°fAppr°val'ifanY:K-valve testing to be the sane as conventional surface controlled sub- surface safety valve tests. Witness of bench testing will be necessary if operational limitations make conventional flow testing procedures impractical. IIRIGINAL SIGNED By Order of ~' "%.~0 ~Z Approved by BYLOHHIE C. SMITH COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~' Prudhoe Ba~ .-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 6-17 DS 6-18 DS 6-19 DS 6-20 DS 6-21 DS 6-22 DS 6-23 DS 6-24 Permit No. 82-90 Permit No. 82-99 Permit No. 82-114 Permit No. 82-124 Permit No. 82-127 Permit No. 82-131 Permit No. 82-133 Permit No. 82-147 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmi Attachments cc: Sohio Petroleum RECEIVED 5 lg83 Alaska Oil & ~as ~;o~s, ~on'ur~tssion An~hera~e ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany K(A STATE OF ALASKA ALAS OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, Alaska 99510 4. Location of Well 3' FNL, 860' FEL, Sec. 11, TION. R14E, UM' (Surf) 379' FSL, 2638' FEL, Sec. 11, TION, R14E, UM (Top Prod) 39' FSL, 2457' FWL, Sec. ll. R14F= IIM (Tn~ 5. Elevationinfeet(indicateKB, DF, etc.) 6. LeaseDesignationandSerialNo. __ 741 RKB ADL 28311 12. 7. Permit No. 82-90 8. APl Number 50029-20760 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 6-17 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 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 J~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Begin perforating operation 2/11/83. RU perforating uni't, pressure tested surface equipment. RIH w/ gun #1, shot 11182-~1202' MD, 4SPF. Flow to tank for cleanup, monitored rate and took shake'~-~S~' .............. PO'OH. RIH w/ temperature tool and run temp survey from 1'0800-11400 . P~O~H. RIH w/ gun #2 shot ll__!_5_Q..!~qllZO .... MD, 4SPF. POOH. RIH w/ gun #3, shot_]]_]20-111"~O'MD, 4SPF. POOH. RI'H"-~/ gun #4, shot 11090-11110' MD, 4SPF. POOH and RD unit 2./12/83. " ........................... All depths referenced to BHCS 7/1/82. RECEIVED JUN 1 5 !983 Alaska'0il & Gas L;0ns,, u0mmissl0~ An~herag. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~ ~""~t,~/~ ~14~q Title Reaional EnQineer The spac~ below for C~or~miss~on us~/'~//'- - ~ Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO. Alaska, Inc. [' Post Office I~ ,360 Anchorage. AlasKa 99,510 Telephone 907 277 5637 June 10, 1983 -' .... ' Reference: Arco Cased Hole Finals ~'D.S. 1-8 -~ ~ 4-18-83 CH CNL ~.D.S. 1-24~/ 2-4-83 ' PLS/Temperature ~D.S. 5-11-~ 4-17-83 EPL ~--D. S. 5-11~ 4-17-83 PAL ~-D.S. 6-17~/ 2-11-83 PLS/Temperature ~'D. S. 7-2~ 2-13-83 ACBL/VDL/GR/Sig -'D.S. 9-4~/ 4-17-83 CH CNL ~D.S. 11-6j 4-22-83 CFS -~-'D. S. 12-17/ 2-3-83 ACBL/VDL/GR/Sig ~D.S. 14-13~ 4-25-83, EPL Run 6 5" Sch Run 1 5" DA Run 1 5" Sch Run 1 5" Sch Run 1 5" DA Run 1 5" DA Run 7 5" Sch Run 1 5" GO Run 1 5" DA Run 1 5" Sch Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. 9 368 DISTRIBUTION R&D ~'.P.~'LLI PS' MARATHON ~B~L ~ ',i D&M ,-<~E~ .~':~ ~ ~ '~:'U~''~ .'~-,-: -.S!AIE.:.OF ALAS~ DALLAS CAROLINE SMITH RECEIVED JU t'i ! 5 !983 ARCO Alaska, Inc.~'I Post Office .360 Anchorage, Alaska 99510 Telephone 907 277 5637 Ap=il 14, 1983 Reference: Arco Pressure Data D.S. 6-17 2-13-83 Static Survey Camco sign and return the attached copy as receipt of data. Kelly McFariand AFA-403 Trans. # 277 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M DALLAS Alaska Oil & Gas Cons, CcmmissioD Anchorage CAROLINE SMITH ARCO Alas,~a. ,r,c. i.,; a SuDsi~Iiar¥ of AtlanIicRic~.:,'~!'.::2 :' '~" Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 8, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Re' D.S. 6-17 Permit No. 82-90 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc' Sohio Petroleum ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany RECEIVED DEC 0 8 19B2 AlaSk~ Oil & Gas CoNs. Commission A~ch0rage STATE OF ALASKA O~M ALASKA IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Na~p~r~tor Alaska, Inc. 3'Ad~r?s6. BOX 360, Anchorage, Alaska 99510 4. Location of Well 3 FNL, 860' FEL, Sec. 11, TiON. R14E, UM 379' FSL, 2638' FEL, Sec. 11, TION, R14E, UM 39' FSL, 2457' FWL, Sec. 11, R14E, UM Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 74' RKB ADL 28311 12. 7. Permit No. 82-90 8. APl Number 50- 029-20760 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 6-17 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 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 I-~X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand in this Prudhoe Bay Unit well. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals' Ref' BHCS 7/1/82 11090-11110' MD 11120-11140' MD 11150-11170' MD 11182-11202' MD RECEIVED DEC 0 8 1982 Alaska 0il & Gas Cons, Commission Anchorage 14. I hereby certify that the f~regoing is_true and correct to the best of my knowledge. Signed 2~,~/,~~/~ Title Regional The space below for Commission use Engineer Date IJ~/~.~ Conditions of Approval, if any: Approved by COMMISSIONER Approved COpy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office I~~? 360 Anchorage,~ ~ka 99510 Telephone 907 277 5637 November 16, 1982 RE: ARCO Magnetic Tapes with Listings D.S. 14-7 10-27-82 D/A D.S. 14-26 D.S. 13-14 11-5-82 Run'-I & 2 SCH *D.S. 13-24 *D.S. 6-17 7-1-82 SCH D.S. 13-15 D.S. 6-24 10-31-82 Run 1 SCH . _ CNL (10570 - 11600) Tape #ECC 1505 12-30-81 CN-GR, CDL, DIFL, BHC/AC D/A Tape #ECC 1191 'Open Hole Logs Tape # 66023 5-17-82 Open Hole Logs Run 1 SCH Tape #65124 (Corrected) DIL/BHC/FDC-CNL/CH CNL/GR Tape #65256 (Corrected) Run 1 10-18-82 Open Hole Logs Run 1 & 2 SCH Tape #65747 Open Hole Logs Tape #66017 * Please see attached letters regarding the replacement tapes for wells 13-24 and 6-17. .]~lease sign and return the attached copy as receipt of data. Becky Benedict AFA .- 403 Trans. #623 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE DALLAS SCHLUMBE _,.{ OFFSHORE SERVICES 5000 GULF FREEWAY, P.O. BOX 2175 HOUSTON, TEXAS 77001, (713) 928-4000 PLEASE REPLY TO 500 W.-~i~ERNATIONAL i~RPORT ROAD LANTIC RICHFIELD COMPANY ANCHORAGE, AK November 12, 1982 Dear Customer' We have discovered an error in the Library Tapes for the fol 1 owing we 11- COMPANY NAME: ATLANTIC RICHFIELD COMPANY WELL NAME: D.S. 6-17 LOGGING DATE' 1 JUL 82 JOB NUMBER' 65256 Enclosed are replacement tapes for the above listed well. Please destroy the original tapes you have already received and replace with these enclosed. We apologize for any in- convenience this has caused. Thank you, SEK: smm cc: distribution A DIVISION OF SCHLUMBERGER LIMITED ARCO Alaska, Inc. Post Office B.,px 360 Anchorage,( ka 99510 Telephone 907 277 5637 August 18, 1982 Reference: Arco Opem Hole Finals D.S. 6-17 7-1-82 BHCS/GR D.S. 6-17 7-1-82 DIL/SFL D.S. 6-17 7-1-82 FDC/CNL (Raw) D.S, 6-17 7-1-82 FDC/CNL (Poro) D.S. 6-17 7-1-82 C?L/Cyberlook Rum 1 2" & 5" Sch Run 1 2" & 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Please sign and return the attached copy as receipt of data. Kelly McFarlamd Trans. # 391 DISTRIBUTION NORTH GEOLOGY' DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M Alaska 0il 8, Gas Cons. Commission Anchorage ARCO Alaska, Inc.(:' Post Office 15_.. 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 18, 1982 Reference: Arco Directional Surveys D, S '~i/6~i7 7-13-82 D.S. 6-19 7-25-82 Do S, 14-11 8-11-82 Do S. 18-2 8-4-82 Gyroscopic Multishot Magnetic Survey Gyroscopic Multishot Gyroscopic Multishot SS Teleco AMF SS ~/Please sign amd return the attached copy as receipt of data, Kelly McFarlamd Trans, # 398 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON C~-%rRON EXXON MOBIL GETTY D&M GEOLOGY DALLAS ~CO Alaska, Inc. Po'st Office Box~ Anchorage, Ala~,.~ 99510 Telephone 907 277 5637 August 19, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are completion reports and gyroscopic surveys for the fol low.ing wells' DS 13-25 DS 1E-15 Sincerely, P. A. Van Dusen District Drilling Engineer PAV/JG'llm Enclosures GRU1/L74 REEE!VEfl AUG 1 9 ' 982 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ORIGINAL ' ,i STATE OF ALASKA ' ALASKA .L AND GAS CONSERVATION C MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-90 3. Address 8. APl Number P. O. Box 360, AnchOrage, AK 99510 50- 029-20760 4. Location of well at surface q., i~"tA'f;O-N,~- 9. Unit or Lease Name 3' FNL, 860' FEL, Sec. ll, T10N, RI4F., UM ' V~_mF~EO ! Prudhoe Bay Unit Producing Interval At Top Surf.~[ 10. Well Number 6-17 379' FSL, 2638' FEL, Sec. 11, T10N, R14E, U~-H._~_._~ 11.Fie~dandPoo~ At Total Depth 39' FSL, 2457' FWL, Sec.,. 11, T10N~ R14F.~ TTM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 74' RKB/ A:DL 28311 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 06/17/82 06/30/82 07/13/82 17. Total. Depth (MD+TVD) 18.Plug Bac'k Dep(h (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost I1500'MD,'9222',TVD I'1444'MD,9I'83'MD YES~ NO[]'1'nipple@2024eetMDI 1900' (approx) 22. Type Electric or Other Logs Run DIL/BHC/GR/SP, DIL/FI)'c/C2qL/GR/Cal, CBL 23. cASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 ', Surf 81' 30" 2~61' # 1.3-'3/8" 72.0#. L'80 '! Surf 2502' '17-1/?." 2032sx F~l~-~ 400sX Permafrost C · 9-'5/8" '47.'0# L-'80 ¢, r'S]lrf 1O~2~.' 12-'1/4" 500SX Class G ~ 33 )bls Permafrost C ' s00',:9 7" '29.0# L-:80 ' 105ll' 11490' 8-1/2" 325sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2"/4-1/2" 10536' 10443' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A · ,, 27. N/A PRODUCTION TEST .... Date First Production I Method of Operation (Flowing; gas lift, etc.) I "Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ ,.. "'Flow Tubing Casing Pressure . cALCULATED· .~ O.'IL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATEI~ .... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · A!!aska Oil & ~as Cons Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10 972 ' 8863' N/A O/W Contact 11350 ' 9119 ' Base Sadlerochit Not Reache~. 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ TitleAre~3 Drilling ~,n~'E)ate 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 DS 6-17 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0300 hrs, 06/17/82. Drld 17-1/2" hole to 2510'. Ran 63 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2502'. Cmtd 13-3/8" csg w/2032 sx Fondu & 400 sx Permafrost. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10841'. Ran 271 jts 9-5/8" 47#/ft, L-80/S00-95, BTC csg w/shoe @ 10822'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form .to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11500' TD (06/30/82). Ran DIL/BHC/GR/SP f/10814'-11494'. Ran DIL/FDC/CNL/GR/Cal. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 33 bbls Permafrost C, 125 bbls Arctic Pack. Ran 24 jts 7" 29#/ft, L-80, BTC csg f/10511'-11490'. Cmtd 7" lnr w/325 sx Class G. Drld cmt to 11444' PBTD Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/11436'-10390'. Ran 5-1/2" (4-1/2" tailpipe) completion assy w/tail @ 10536' & pkr @ 10443'. SSSV ball valve @ 2024'. ,Tstd tbg hanger & packoff to 5000 psi -ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 1800 hrS,~.07/05/82 ' Gyroscopic survey ran 07/13/82. JG'llm 08/16/82 GRU1/DH22 Eastman Whipstock ~_~ A PETROLANE COMPANY REPORT of SUB-SURF,4CE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY DS 6r Well Number: 17 WELL NAME Prudhoe Bay, North Slope, Alagka LOCATION JOB NUMBER TYPE OF SURVEY DATE Directional Single Shot J U L 1 5 i982 SURVEY BY Controlled Drilling Consultants A!~ska 0il & Gas Cons, Commission Anchorage OFFICE (Dale ~endrix) ARCO ALASKA, INC, F'R'III)HOE BAY, NORTH SLOPE:, AL. ASKA r~SS, 0-10775 MT.I, DRILLER; DALE HENDRIX 1&-JUN-8 I)E£.'.I..INAT.TON; SO 1/2 DES, EAST SURVEY PROV.TDED BY CONTROL. I. ED DRILI. ING CONSULTANTS VERTICAL. SECTION CAL. CUL. ATE FLAN rmu,-~,~=~-~--~ . · ~.j~J______ w ..................................................................... : ................... Whip.~tock A PEIROI~NE COMf~NY RECORD OF SURVEY RADIIJS OF CURVATURE ARC[) ALASKA, ' T ! ME D-ATE I'IS 6, WEL. I.. NOJ 17 DSS (CDC) F'RUDHOE'-BAY'~ .... NORTH-"S:[iOF'E'~--~[~:ASKA' 09.09.4.. 0..- JUIZ 8~ T R U E M'l.-.". A',~. H RE>IT-DRTFT £1R'I'FT----CO ti I)EPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI1 FEEl' D H D H FEET FEET FEET FEET FEET FEET D H DG/IOOF O. 0 0 0 0 O. 0.00 0.00 -74.00 0.00 0.00 0.00 0 0 0.00 2500. 0 0 0 0 2500. 2500.00 0.00 2426.00 0.00 0.00 0.00 0 0 0.00 ....... 2660. .......... 1 ........ 6--S-"68'--3-6--~'-~1'60'~ ..... 2659"~'99 .......... 0"i'I0--~58~i-99 ..... 0.~6 ~ ................ i.43-"E ..............t"~54 ...... S"-68-'3'6"'-'E .............. 0..'.69- 2837. 0 54 S 79 12 E 177, 2836.96 0,03 2762.96 1,41 S 4,39 E 4,61 S 72 8 E 0.15 2932. 2 30 S 76 12 W 95, 2931.92 1,95 2857,92 3.44 S 4,44 E 5,62 S 52 13 E 3.52 3056. 7 0 S 19 36 W 124, 3055.46 10,45 2981,46 10.05 S 2.87 W 10,45 S 15 56 W 4.84 3180. 10 0 S 8 0 W 124. 3178,08 28,70 3104,08 27,82 S 7,23 W 28.74 S 14 34 W 3491. 17 18 S 9 48 W 154, 3479.96 101,87 3405,96 100,73 S 19,51W 102,56 S 10 51W 2.21 3739. 23 0 S 13 18 W 248. 3712.68 186,80 3638,68 184,38 S 36.40 W 187,94 S 11 10 W 2,35 3859, .~.~ 48 S 15 4g W 4014, ~7 42 S 17 0 W ......... ~ ................. ~ ...... ~ ............... 4~30. 33 4~. S ~.0 0 W 4354. 37 18 S 22 0 W 4508. 41 42 S 25 0 W 4632. 46 6 S 27 18 W 120 ........... -'"4821,95,..~--.~36.29 3747,95 232.37 S 48.B,1: W 155~960.36~~m~ .~. ~t~.~ 299,31 s 68,45 w 12~4246.94 48a,~9~j41]~a.94., .471.04 ~ ~j~ W 124. 4455,06 670.46 43~O~-RO~,~Z;~~ 206.15 W 760.98 S 261.30 W 237,44 S 11 52 W 2.47 307,04 S 12 53 W 1.28 416'e86 .... S.---i4-~o"~._ ..... ~'87 .... 488,44 S 15 20 W 3,05 585,54 S 16 42 W 3,11 670,47 S 17 54 W 3,77 804.60 S 18 57 W 3.09 4826. 4° 0 SOl 0 W 194. 4594.47 804.34 4520.47 ..... - ........~ ..................... ~ 25""W ......... ~92I'~98 ....... S 18'52"W ........ ., ~ ...... ~ ..~ .............. ~' ~'72 ............ 4"650"¥21' 87~..41S ~98. 5001', ...... !2-'18'-S ....... 1'5-'-42-W ............ 17~. 47~.4.~1 ?~.1 5=~ 2 24 . . 5028..95 1215 65 S 393 76 W 1277 83 S 17 57 W 0.37 .~.1, 44 1 S 15 W 520, 5102 95 1277 80 · · · 5877 46 4g S 16 ~4 W 356, 5352.67 1531.37 5278.67 1459.62 S 463,26 W 1531.37 S 17 37 W 0.73 ... 5~8 570~ 82 1926,44 5628,82 1836 82 S 580,74 W 1926,44 S 17 33 W ...71 6405. 50 1~ S 18 12 W .~ . -.. 6709. 50 12 S 17 6 W 304, 5897.42 2160.00 5823.42 2059.38 S 651.56 W 2160.00 S 17 33 W 0,28 6892. 50 :'"6'S"'"1'6'-'48'"W ...... 183f ......... 6014"i"67 ...... 2300~'47 5940-~'67 ...... 2193"~F6'-8 .......... 692.'5t .... W ...... 2~00-~--49 .......S"i"?3t W ...... 0,14- 71.97. 50 24 S 16 24 W 305. 6209.70 ..~34 93 6135 70 2418,48 S 759 50 W 2534 93 S 17 26 W 0,14 7713. 49 48 S 15 24 W 516. 6540.69 2930,62 6466,69 2799.18 S 867.95 W 2930,66 S 17 14 W 0.19 8065, 46 54 S 16 6 W 352. 6774.60 3193.50 6700.60 3052.30 S 939,33 W 3193,57 S 17 6 W 0,84 8385. 45 42 S 16 6 W 320. 6995,68 3424.77 6921,68 3274.58 S 1003.49 W 3424,89 S 17 2 W 0,37 W 0 63 8868. 42 48 S 16 ~.4 W ].79 7341.54 3761.75 7267 54 3598 33 S 1097 28 W 3761,92 S 16 58 9195, 42 48 S 17 6 W 327, 7581.47 3~83,91 7507,47 381]..08 S 1161.31 W 3984.09 S l& 57 W 0.15 ........................................................ . ARC. O At..ASKA~ INC~ COHPU]'ATIOF! PAI;~E t'.~Uo .. ~"' ~DS 6, WEI..I.. NO~ 17 DSS (CDC) TIME DATE F'RUDHOE' BAY, NORTH SI. OFE, ALASKA 09109;42 TRUE MEASURED DRIFT DEIFY COORS~ERTICA[. 9ERTICA[_ SUBSEA R ~C T ~ N G U L:'"A-'"'R ........... C-'E"O-"'S'"'U" R"'E ........... DOGLE, DEF'I'H ANGLE DIRECTION LENGTH DEF'TH SECTION TVD 0 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEEl' D M D M FEET FEET FEE]' FEET FEET FEET D M DG/100~ 9502, 42 30 S 17 30 W 307, 7807~27 41~1,~0. 7733,27 400~,67 S 1223,16 W 4192,08 ~ 16.58 W 0.13 9655, 41 6 S 17 6 W 153, 7921,32 42~3,87 7847,32 4107,03 S 1253,48 W 4294,06 S 16 58 W ...... 9 ~'~ 0; ......... ~4 ~' .......... ~""'S'-'"'I9'--3'6-"~ .......... 3'0 ~-"- 8'15'1-;' 1"~---4'4'~ 4' ';"~'4'~8077T' I'~ .... '~'2~ 7';~2'-S ..... I' 5'1-6'~"60-'W ...... -4'4 · 4T'48--- S ..... I'~ ...... 2'-" W .......... 0"~"54' ~o 82~6,08 4483,71 S 1386.84 W 4693,2~ S 17 11 W 10256~ 43 30 S 21 42 W 2~6, 8370.08 10561. 46 42 S 24 30 W 305, 8585,34 4~08,18 8511,34 4682,38 S 1471,58 W 4~08,18 S 17 27 W 1,23 10775. 47 42 S 28 0 W 214, 87~0,74 5063,35 8656,74 4823~1~ S 1541,02 W 5063,38 S 17 43 W 1.29 FINAl. CLOSURE - DIRECTION; DISTANCE; S 17 DEBS 43 MINS 8 SECS W 5063.38 FEET Eastm. an WhiPStock A PE'i'f:~OI ANE COMt:~.INY C:HA[(/ ' E~; I:(E.t..AI Ell.! I.IA I'A t: ILl::. ARCO ALASEA, INC. DS 6, WELL. NO; 17 DSS P I~ U ri H 0 E'- B A'Y~--NO R~lq~-~ tT.O F'EY~' .~. A ( CDC ) .......................................................... BOTT OH""-'HOIzE-AS~E MBI:'Y VALI.IE$ USED FOR DEPTH ARE DEF'TH DESCR I F'T I ON 2510. O0 JETTING. ASSEMBI..¥ ......... 4903-~ O0 ............................. PACI~:E]I:,'"-HOLE 5953.00 F',~CKED HOLE 8143,00 F ~CKED HOLE .A PEIROEANE COMP4NY [ R lt..L I NG-"r,~A YS ..................................................................................................................................... ~- ............................................................................................................................ VALUES IJSED FOR DEPTH ARE DA Y lie F' T FI 1. 438,00 2 2510o00 .................. 3 ............. 251'0¥00 ................................................................................................................................................................................................................................................... : .................................................. 4 3206,00 5 4689,00 ........................ 6 .......................... 5'I'~",'00 ................................................................................................................................... 7 6847,00 8 8143o00 ................ 9 .............................. 9562-;00 ................................................................ 10 11 10841,00 .................. I2 ................... ~'084~;'00 11124.00 WEIGHT ON BIT WEIGHT IS GIUEN F'ER 1OOO POUNDS ~)A[.t.JES I.JSE[i FOR~ ..... [EFTHi ~ ........ ARE' ..... DEF'TH .......................... WE'IGH1 468~.00 0,00 4903, O0 70, O0 595~; O0 ................................... 70';00 814~,00 70,00 9715,00 70,00 REVOLUTIONS PER MINUTE Vi~[.1]ES USE[I FOR [IEFTH ARE~-MD Eastman APE I'ROtANE COMF~NY 2510,00 .......................... I-7'0;-0'0 4689,00 0,00 4903,00 135,00 8143,00 160,00 9715,00 110,00 , ARC'O ALASKA, · I NC., "" D.S. 6-17 (SEC 11 T10N R14E) ";!; SF'ERF~Y-'.{;LIN WELL SURVEYING COMF'ANY ,::,, ANCHORAOE~, ALASKA .......,::,~:. ..... : :,, ,. '??' :'~:' C:OHPUTATION DATE. DATE .:OF SURVEY ,JULY, 13, Bn,"" GYROSCOPIC SURVEY PAGE I~82 PRLIriHOE BAY ALASKA dLILY 14, 1982 ,, :., VERTICAL SECTION CALCULATED ALONG, CL~S'URE ..... .. : .,,j , ,' ,~,,, : .. .:.". .'.i.~ /..,f m ' m TRUEI I Imm .~LIE-SEA COURSE M E A'._:;Uf:(E [~ VERT I F:AL VERI' I C~L I NCL I NF~,T I ON DEF'TH DEF'TH DEF'TH BEG MIN 0 0. O0 10() 1 O0.00 '200 200.00 ; 'c;(J(.) ;:~(..)(..!. (..II.! ,,., 400 400.00 :' 500 500.00 "~00 6'0~) ;' O0 700 700.00 800 C~ ()0.00 , ';;' 00 90 (). 00 1000 1000.00 1100 1100.00 --74.00"'" 25. O0 126. ()0 · ..::2/:,. O0 326. O0 426. O0 ':'-" 626. O0 726.00 ,. ,' , .,.',"'. ~ ~"?'~;,-, ,, :': ~,~i:?':y::,, " · couRs~,.'.: .' DIRECTION DEGREES o - o -'N ..... o ~0 ""s:"e~.q~.,H o 6 N ~';:~)~.:'w 0 2 S-, 1'~ 30,.E o 5 s 40'..:':,0'~ E ~ '-- 4-': g -'2~..~¢Y"-W o 6 N "i~;e~,: w JOB NUMBER BOSS-16084 KELLY BUE;HING ELEV. = OF'ERATOR-SAMEC 74.00 F T. DOG-LEG SE VER I TY " TOTAE ',', ' REC:TANGIJLAR C:OORD I NATE~ VER'FI~:AL .PEG/lO0 0.00 "' 0.34 0.31 0.07 ,,.,, 0.08 0.07 0,0~ 0.14 0,03 NORTH/SOUTH EAST/WEST w w. SECT I ON o ;'0o , o. GO ,0.02 $ .. "0~ ,~0 ,'0.05 N " 0,6.4 , ! ,, ,,, 0.17 N 0.6'? 0.17 N: ,0.70 O. 07 N O. 65 0.04'-~ ' O. 63 0.0~ 8 ., '0,68 0.12 N" 0.72 '0';;'-00 ..... 0.12 '0.18 ¢..). 0'::1 (). 0':? 0.16 0.26 0.27 0.14 _L 200 i 199.9.<) 300 . 1299.98 400 1399.9 C: :::.: 26.00 926. O0 1026. O0 1 I :;5. 1 ':..':'25.98 1 ':.:']:S. 99 0 1:3 N 34.89 W 0 6 N .0'70 E 0 26 N O. 19 W' o 36 .....N'':< 5~ ~?;'-'E o. 48 N ,' 7';(sp" .E ' 0" ,..,, 20 N. 21. ~':)' E .... (.)(..) 1 9i:~. 98 1. 425 16 (:) 0 159. 9.9. F.=:_ 1 ._,"- .~."" ::..., 17 ()() 16':?'?. 9:=: 16'25 0.14 0.16 O. 33': O, i7 O. '20 0.48 0 4 N. 70.69 W 0. o'-'"'.., '" 86.10,E, 0 11 0 1 ~ ~, '- · C) i 'S,.o.'"= 60 E 0.03 0.37 N 0.85 W 0./,:.3 N 0,96 W 1.11 N 0.?,'6 W 2.0'2 --'N ........ -0'. "~' 1 W 3,23 N O, 77 N 4.20 N 0.57 W 4.49 N 0·5:';.: W 4. F;'t' ._z N O. 56 W 4.50 N 0 Fi':, W .... ("). -.,' .. ().., -'0 ":' F; -0.76) · --1 -2.7,5 --3 ~, 73 '' :"-4.03 -4,03 -4.03 i 'i..)8 '77 9 '7 ..,.,.~ :s 5.5.., 0 E 0.46 0 25 S ,57.50 E 0.06 0 31 S 75.&9 E 0.17 4.24 H c).18 W 3.80 N 0.48 E · "-' 49'N I 24 E ', ,..i. · .... :3.91 -....:,, 7'3 . ,,, (.) . . :. / ..'('),"b. 9? J. z...:,. '76 2 ::::' C)0 21 o...::,... 96 z.'-' ..... "=' 23 () 0 229 9. ':76 ".::'::.".;it5. '? 6 3.34 N :2. ('..)2 E. :3. 1:2 N 2.76 E '-' 75 Iq .::....:, E .~:. '- ~,,;.-, :.-' 'iC) O '25()C~ 2(-.,()() l'i ..... 2:::00 1 , .'2'.:~0C) 24 ;?5. , .;. I:% .: 5. '?,"j ..... :,.: S 60 60 E 0.08 0 48 ~ 77,39 E 0,32 0 :.:',.'~ S (.,8. 0 E O. I 2.3:3 N 4,31 E 1 f)4 N ':' 41 E 1.5'7 N 6.62 E -3,71 --:3. (30 26Y'P. "..;:7'P9. 28'P9. () .:..:'? S 80. 0 E 0.14 .0 :::4 ':' 63.39 E ' 0 1:3 2 19 ,-.c' 7'?. 69 W -"". 81 1·2:7 N 7.68 E Q,._ - . ..._, N :=J.6,6 E 0.:86 N .... ".7.1 '"' · _', E t ,. :E;F'ERF;:Y.'"'i:;UN WEL. L L=:LIIq:VEYII',IG COHF'ANY F'A(3E 2 ARCA ALAF;};::A, tNC. S.S, 6-17 (S;EC 11 TiON Ri4E) F'RLU:~HOE BAY A L A S I< A ,JLILY 14, 19-o.-,. ,_,.~ VERTICAL SECTION CALF':LIL. A'I'ED ALL Nu ¢i. OSURE · ....:.. ... · TRUE" ' .... SuB-SEA · '..' C:OURSE c0u sE"': [IA'f E ..OF' SURVEY dUt. Y 13, ]..::,<.k',.'.,, DOSE; OYROSCOPIC ::;URVEY ". ,_IL]B NUMBER BOSS-16OF:4 KELLY BLISHING ELEV. = OF'ERAI'OR-SAMEC " DOG-LEG TOTAL 74, 00 F:'I". ME A:::;I_IF;:ED VERT I CAL DEF"I'H DEF'TH V EI'.~"i' I CAL I NCL INA l' .f ON D I RECT I ON :SEVER I TY RECTANGLILAR COORS I NATE:3 I]EF'TH DEG M I N DEGREES DEG/100 NORTH/SOLITH EAST/WEST VEI:?'F I CAL SECT I ON I :300('}. . .._":' "~ q, 9, .. . , 70 3050 3049,37 b' I O0 3098. :":::: · 2:1.50 2:148.07 :3200 :3197. 18 ' :3400 '-' -"? ...,o; i, 74 .:: ..... 0 I.~ 34:5' 7,., 6 i' :.:: 6 ~..)~.) ..) 5 ::]: ,;':. :34. :3700 367 ;5.7 A 3::_::OCI :3767.4.2 '3~i]~' ~'8:57,59 4.0 o 0 . 39-t 6.19 4-100 40:32.. 7' 6 .4 ..::U,U 4 ]:-'i. 6 · '".;('- i 4-:3 () 0 4.198. :--': 7 i 4.4 ()(.~ 427 :--:. 2 () ......................... :,I:. 5'~..~'F ......... --'z'F~._,"~."l:~'f'.~ · '1 <'.' c,(.~ ;I 4.'::"6. '?8 : ;I 7,r-~, () '-I. 4 ':'.";', 6 C', ...... · .I ...:,/ .. 1. ,,' "'l;..J(..,~() "~ '¢1,, · '.:,75.85 ">c~":,5 70 .,.,~. ";-'9 75. o7 ::.:() 2 4 . 8:3 :30 '74.07 '::'....: :.: o. ~' :3:'-"~ :I '7,74 '.,'.,,',.'~ 13, 56 ut.,0%:i:. :'::4 :36 () l. 70 · --:Ao':: 42 '::/:.;::;:. 59 :3872, 152 ..... "'""": 76 .., ;,, .. ~,;;,. 4 ()4 '2.96 41:24.87 4204.20 4 ':~ I..; '..:, · 98 4 "- .:;: :', ,, · 'i .'1' ;',.::, ,, '1 / · , ~,, ,. ,;..:, ,5 5/.=, ' e.2~.,.,,,q..~W. 7.4! ;3.40 $ 7 IO S .2!'?,'.".,0';. w 04 i:::I 'P '.'.':6 S 1 t'; 80. W 5; 54 15. e':-': S 10 2/_-, S lO;Gq W 8 58 """ " O. · ;_--I . 1.76. W ,,, 1.75 24.12 S 3.44 W Z&.-..,. 2 l 2'3 · 79 11 ::: $ 9.:89 w 1.42 1:3 '13 ' S---i0:,$9.--W4 2 09 · ., :~'7 $ 'll,:<',O',.W 2.39 17 3:2 :3 '11~89'W 1.~4. 1 '.-? :36 S 1 ~i';' 56 W 2.1:3 '. 22 20 S 13, 89 W '-.", 7:3 24 :;:::4 S 15,60~ W 2· ,:,.:, 33.34 S 78.57 $ i 06.5:3 S ¢' 90 W f.-~"~, 79 a'"',i ii .. ~, 13.5'7 W 78.34 19.26 W 106.51 1:3'7 · 59 S 2 6. '? 9 W 1:3::3. (~/, 172 36 '" 34,77 W 17:3 210. c,.-, '.E; . '"' '- ,;,.:, _ 44 '.:'::: W 21 .::. 19 z.'"' 19... 2;95.94 .... S ' 72.67 W 302 · 62 '.--' '" 90 · 12 W ~!p:2,65 2. E:9 ,~4..", 83 S 2. t:; 1 '>.:'~.~':2.91 S 11 () 08' W 4 (h: .... .t::;:..'i 44!5. :36 S 1'-~"' 25 , _ .: .:,. t,4 46:3 79 ':'?'" 42 500.20 'S 1 · _, ;~. 67 W ,..,.:4.. :::,o 7 · ~.;;0 :-3 18':") i'~::: "W · .. ., ... 6~ k.~, ,ot"~.. b ..~-_ ~, 7F.: W E,'""~...,/ ......, 0.." A:: .'57, 62' 'S '"' ~'' :3:3, --- ~ i, W 7 2'7, 4 :.2 "'; ' i; '~ ~ .... .. · /'.; ..... ::./ ~;i; :.:.'. '/ 9" ('~ 7 W 7'i.;,!. 1L: 3 5 W ,_,'::'/-_,,.?. 7 6 :30 W 9 2'.:;'. 3 9 ,:, U,:,. (')!=, ::; :302 · 871.72 S 322. 9::::5 274 S ' 999,78 S 362~ 1 <-)6:3.9?) !3 382. .i 1 :;.-'::::. 69 S 401 · 42 W 1 ] ':T,'/. '7:'.: 1194 ":'/ ::; 4.21 -'-' · .,:. :, 7,:, W 12,':., 6 ":":' . .. · · ._, 1260.63 S 4z~2.64 I,%1 1..:,,: .... ' :2 ,~:;~: 7 .......... · '1,'~ ."l ! .,'o o,:, S 1~.89 W 31 '.:;:6 S 20, 89 W ......... C. ',",-, '"R'¢,'-" ~ 36 1i S 25,10. W 38 49 S ~6.~,0 W 4. 1'.",.. .': ...c: 2'7 ;"¢.0' '"W 45 I S 27. L4~ ~ "'' 'W q.z 4 ',S 23,50 W o 17, 39 W S 17.39 W S 17.30 W S 16.50 W S ~6.89 W S 17.60 ~ , S 17. o0 W 2.7:3 :3, 1'-' 2.4:::) 2:. ':--/..-} 4 · t () O, 67 o. 'i"L5 O. 15 0.54 0 · 1.10 O. 5" · _ 0 .! ARC:O ALASKA, INC. D.:3. 6-17 ('.SEC; 11 TION R14E) F'RU[IHAE BAY ALASKA ~..,S.;F:'Ei..'RI::~Y-:::;IJN WELL SURVEYING COHF'ANY ,JULY 14, 1982 VERTICAL SECTION CI~LCULATED ALONG CLO:.3URE · . TRUE "".'" SUB~SEn. .. :_ : .. ..:. : COURSE MEA:=;URED VER]' I CAL VERT I CAL I NCL l NAT I ON DEF'TH DEPI'H DEPTH DEG M I N ~ ~- ... 17 57. , .1 17 44 47 5301.61 5227.61 . 45 4, o'"'-'-' 5370.23 52'76.23 47 41 5700 5800 5':',(:)0 ¢015~$E~.,, DOG-LEG DIRECTION SEVERITY DEGREES DEG/1 O0 ~_,()()C) 61 (:)C) 62C) C) 6,::':C)0 6 4 ()(') 6o00 0. ee lo: ,.w. , 2. S 19,39 W 1.09 S 19,:1.9, W ',,', O. 15 S 1~_':i¢? W .... ' .... 0.46 ' ;e,,m,.e',.:w 0.26 $ 18.80 W 0.25 P A Ci tS DA'I'E..,OF SURVEY ,JULY BOSS GYROSCOPIC E&.IRVEY dOB NUMBER BOSS-16C)84 KELLY BLISHING ELEV. = OPERATOR-SAMEC 74. OC) FT. ,, ' .TOTAt2.''., =_,-- · ... RECTANGLILgR COORD I NATES NORTH/SOUTH EAST/WEST VERT I ;::AL SEC:T I ON 4.3 5494.43 49 11 ,5&98.24 5624.24 49 48 "'/' ":' ....... .'.'3 57 .:,,,; ,, 61 bo:z::.:?,. 6, l 50 I327.58 S ,.,..463.62 W 1395.21't~ ,;, ,,,485,14 W i464.18 $.., .,, ,5,98.17 W 15:34 59 S -.v- . ,5,:,Z · 76 W 1605.55 S 557'61 W 1676.80 E; ='e...':, o5 W 405.84 4 76, 7:-:: 54.~, 40 1/= 23. '?.% 1699. 1 1774.5:3 1748.54 8 1820. $6 ~, 1893.08 '.3 ' 607. ! 2 W .63{.88 W 656.61 W 1850, 40 -.o0o, 11 6600 67C)0 /'=,:=:C) C) 6 '20 0 7000 7 ]. C) C) S 18.50 W 0.2:3 1965.70 S ' S. 18, 80 '. W 0.23 .."-'¢.) o'-'°-,::,. 32 S ~; 18,89::W 0 12 ~.110,81 S ') .'] ~"m q 6t.:.o. 77 6C.;0;~ 77 50 6 61 '1. 7. "':' ',=: ,'- 60'/.'-'~. 82 50 1:3 S. 18,..t,.~ W o. 2 l S 18.80.W. 0.14 681.12 W 705.63 W 7o0.37 W 755.07 W 779.79 W , 804.60 1,4 .-%..-,~ ( ,:..~0 .~ 2386 -..":' 462 72(')C) 7:3C)C) '7Ll. O() 82.9. '3'P W '-".~ 03 W 878.47 W 2616.. C')C) ";'/- ';'"::' 2 C) 1500 7 '?()0 8....,.' 60 W o,, I ';i: 2,-'-. I .-.:. '"'' . 03 .::.,'" t8. i0 W 0.4.0 269C). 47 $ 8.10 W 0..54, 2 '76'.'2.79 ' S 5202.84 W ,926.87 W 750.50 W : I i 7 ::':.: 0 (.) '7 'P () C) 8000 /,/:, ('.)('.), 'i:,' ()' ' ,.",'" ............ _ _ t:,. , '::) i') "{ Ii:-'. L :' % 6/=,A 7_. 30 c.,_,' :::":/.:,'. :30 47 .:,"~""' 67:34.70 6660.70 47 20 S 17, 80 W (). 4. 5 2 !..'); 34.6. 7 ::2; 9'7:3, 79 · S 17.6".9 W 0.97 ..'::":>0,=;.. . _ c,,:,""'-' E; 9'F~/=,. o~'"",::, W S 17,' 80 W C), 57 '-";' 24 S .:::;7/=,. IOI'F~. 11 W 2'::E.,'(=,. 12 :Et 0 7 0.81 3144.5'F,' '":' 1 O0 := ?. f'-)C) 8300 1041,67 W 1064. O0 W 1086.00 W ::.:: 4 C)(.) :'2:5 00 860C) 7(') I (). 6 ./::, ,'.'.'. ' .... :/,. 66 45 :l. :ir: 7081.2 :-2: 7 C) 07.2 :=; 44 5 () · _, ,'. 41 7078.41 44. :Z'::: ,-',-:, 1 '-:2. ':' · .=, ?.,' ,., :33:=:6. '--'= .-i._l S 1107, 74. W 11 '=": ,./. 03 W 1150.40 W ARCO ALA;,-.,t,t-~, INC. D,S. 6-17 (:-':EC 1'1 T/ON R141£) .J :SF'ERF(','[.=-'.:SUN N.E~._L- SURVEY .[ I',IC.~ C:OMF'ANY ANF:HORAOE,' Ii~ ,RLASI<A COMPUTATION DATE- F'AGE 13A'rE .OF SURVEY JULy 1:3, BOSS OYROSCOPIC SURVEY ,p. F'RLIDHC~E BAY .JULY 14t. 1982 A L A :{; K A ~ , . VERTICAL SEC:TION CALC:UL_A'FEFI ALONG CLOSLiRE TRUE SUB--SEA [::OURSE dOB NUMBER B088;-16084 KELLY BUSHING ELEV. = OF'ERATOR-:E;AMEC 74. O0 FT. M[-'A:SLli";E D V[=R'I" I r:AL VER'F ! (':AL I NC:L r NAT 1 ON 131RECT I ON :.:.;EVER I TY RE[::TANGULAR COARD I NATES VERT I C:AL DEPTH 87 (") 0 880(") DEPTH DEF'TH DEG M I N '7224'.07 ' 7150.07 - 4:3 57 7296. :'::1 7222.3I 43 32 7369 13 72'P5.1 ~ · ,.~ 42 5:-3 90 (')() 74. 42.12 7 :'": 6 [;:. 12 9100 7515.11 7441.11 , 'P200 7588.30 7514.30 ., . .. .I,.~ ....... "' L'" ~ '?: .... L-- ~ 'eh3c'~,') ' 76/-; 1, ,. 6 7,.,c, 7, ..,~ S;'40r~ 7'794.. E~,4 7660.84 9500 7808.39 77:34, 3~ DEG/IO0 NORTH/SOUTH EAST/WEST SECT I ON " ..... 3644, o$ '~718.41 C).44 3648.79 S 1235.C)9 W 0.29 3713.59 S 1256,90 W 0.29 3778.05 S 1278.97 W 0.14 3842.33-S .... 1301.3~ W 0,14 3~06.52 $ I323.~6 W 0.62 3'970,26'S 1346.90'W 3:.'.i-'50. 1 7 3918.50' · -,,"> c',z 60 4054.65 4122.69 4190.43 '26()C) 7:iii:E:'2 · 6/=, 7:=.)8.66 - ~"'- 7,:: o4. 'P'70C) 7W._,,::. C)2 ' q'-" . 'P:300 80:33.71 7'P59.71 ~9()0 8108.96 ' "' E:0.34';'96 0000 81R:'-~. 89 E: 109.6'9 0100 , 82.5:3.41 S 184.41 ;:l .::.:l Z. 0300 8404.45 :33:30.45 0400 o47._,. 76 ""' o4(.) 1.76 050'c) ~":' ~ ":" 52 847 .L ":;':' o614.30 8t, 4 0 ~, 0 () c, .... c~. '700 86 u' ..... 2.4. 5 It ): :(x) 874 '') '-"'::' ,::.,'"" 'c.' .~.... ....... C) 9 ()A ' ''" 5. . .... b:,d t 27 8741:27 ~ 000 888~. 40 8807.40 [ ~00" 89,.IJ; :36 ~..~'..~/,1;..:3~, 1200 901. 5, 9:3 :?:)4 I. 9:'3 I 300 '~C)S4, `14 S;'('~ t (), 14 ~ .35 A :¢ - m--~' . ':52 .. . ; ]. ~::,..: ..... '::~.D] .i 1400 9152.9'7 'P078. 197 150() 'P221. BE: 9'147.88 46 .'2,'6. S 28,80 W 47 :',ii:;;!:: S 29, 3'? W 4 :j.:3.:ii: ET -29.89 N 4:E: 5:E: S 29.60 W 48 13 S 29.19 W ii 7 ' '-4 'L ......... S'""28; 80 W 4.7 17 S 28,80 W 4/:, 41 '"S --,m 4,'!:- f.::/:, t:; 27:~:? W 4.6 :26 :3 27 46 2/_'.._,':' 1. ":..'5 40:=:2.83 S 1370, 73 W 1.15 4(:)93.86 S 1395.14 W · .,.:, 4154.47' c: 141~, 56 W 0';' 4'i ....... ~,'~'~I~.-~,8'-'-'~ :-: .......... i-44'~-;' 8~;"--W O. 35 0.41 1.47 O. 92 1.79 I. 79"' I 0.97 4:277.30 S .. .t460.1,~; W 4339.23 $' 1492.84 W 4401.72 S 15i(:i.80 [4 4464..95 S , 1546,29 W 4528.54 S 1575.76 W 4656.65 E; 1641.98 N 4'Y2(), 59' ~ 167'7.57 W 4 .,~..., 7. :.':: 8 4:32:3. 10 /"l J'5 4.:,o,:,. 43 4454.27 4520.4'.-? I'-~ I ..... 4~,:~ 7, 15 4654.77 4723.63 4793.52 4~:/S'4.-?Y; ........ 4936.71 500'?. 07 I. 14 478.f',. IL. S; t/14, '.':'.4 W ~.:,):.;;., 46 0.48 4850.46 S 1751.65 W 5156.67 O. 80 477,15.81 S 1788.47 W 52:30.80 (~ ; .'.:, "' a," ~"," .~ 76 S 1 "" ., ;::24, 4:3--[~ -- "'~.:,,':~zt 26 ,'.~-. '[' .'10(.) -.. ,..~ ...., ,. T. 0 · 4;_') 504',:.;. 36 S 1859.99 W 5:377.21 0.74 5109.62 S 1894.89 W .5449,63 o. 68' ' 514.1.67 S 1911'. 96 W 54 8L';. 64 O. 00 5173.69 S 1928.92 W 5!521.5'7 O. 00 5237.73 S 1962.82 W 5593.44 ~ .... " . ':_ '.": ~':. 4q F:EET AT..:8OU'!'H 20 DEG,. 32 M IN WEST AT HD = 11500 H .Jl-~ .[ ZONT'AI .... [) 1Li:! '1 .ACi 'i:iI:.:N T =· ,.-, .....' ,, , ,....'...' . .I I!h..'~"-" '"'~'"'"'i'" 't.~, ..... TIT-~T [i.,I ,'-]'l.;l' ...... .T ". I.'~:. I'i';'F:". ~'.~1".:'["~ l"ff'¥q.i--iJ .F')N" I-fiE :liS;E-QF ' "FFiRF.}:""DII Ib.J',l,_;Ii]lqit~L. RA'DTI...IS; 'OF' C'I. IRVAI'URF..-. .. ME:THO[i. '._::F'ERI?Y--SUN WEI. L g' ' '- , LIRVEY I NG COMF'ANY · . , ARCO ALASKA, INS:. · · D.~3. 6-17 (SEC'If TiON R14E)":"; ANCHORA(3E, ALASKA , ~.; ,~ ,'~. ', . , COMPUTAT, I'ON [lATE. P A L--~ E 5 DATE..OF. SURVEY dilLY_ 1"",:,. , ,. 1982 F'RLIDHCIE BAY ALASKA I'RUE ._ILILY 14,: 1'282 :: KELLY BUSHING ELEV. OPERATOR-SAMEC INI'ERF'L]I_AI'ED VALLIES FOR EVENi"i"'--;:~'":~:;~::;'""~- ~'*'~g ,. ,~.'~:,~.~.,' . ... .,~ SI_IB.--.SEA TOTAL MEA:--;URED DEPTH ._lOB NLIMBER BOSS-16084 VERT I CAL VERI" I CAL. MD-TVD VERT I CAL DEF'TH DEF'TH DI FFEREIqCE CORRECTI CIN RECTANGLILAR COORDINATES NORTH/$OLITH EAST/WEST ., ~ ~ ,.',-~,'.T~ ~, ~-,' ;: ., .... 74 O0 O. O0 '"'; ':"'"'"~""~.,~ 00' , O. O0 · '.:',; ..<.~',>~i~,,l:~.' ,' ' · 926,00 0,63 N' .' '~ ,. '~.~,".:c ;,~ ,, W ; 0, O0 97 :--:. 49 N ' 1.24' E O. 03 74. CIO FT. 1000 2:000 :3000 4000 O. O0 1000.00 '0:03 5(:)C)0 6000 7000 2999.70 2925. 3946,. 19 3872. 4719.24 4645. 5436 85 ~'"~ "" , ._m-.3 .:~ .-"- m 608:3.7'7 6009. O. 30 53.81 280.76 563.15 0.27 -53.51 ,, 3~3.08 8000 6734.70 6,6,60.70 2976. 9000 7442.12 7368.12 3648. 10000 8183.89 8109.89 4277. 11000 8881.40 8807.40 4.9~5. 11500 · 9221.80 9147.88 52:37. 24 S :' 10!9.11 W 7:? S ' 1235.09 W :30 S 1468.1:3 W e: ~s, ;::,:::-:~ 788. 4'7 w 7.3' $ :: :3.'i. 962.82 W '. ,': "" ): , '.. 7'": ," 1265.q'~o 1557.87 1816.11 349.07 292.57 2118 60 "' . ,~02,4~ 2278.12 15~.52 "I"I..IIE CAI_Cl..II.. AT I ON F:'F;;OCEI]I...II-~[::L-; ARIS BASE[:m OIq T'i-IE USE. OF .THREE DIMENSII::'NAI._ F;:AKIILI$ OF; CLIRVATLIRE MEI'tlOD. '.=;F'ERRY-SLIN WELL SURVEYING C:FIMI='ANY PAGE ARCO ALASKA, INC. D.S. 6-17 (SEC 11 TION I,:¢14E) ANCHORA¢,i~'.. t~LASKA ,~' ,! ::',.' , COMPUTATION DATE DATE .:OF SURVEY dULY I3,. l'=~R'-';c,. F'RUDHOE BAY ALASKA JULY 14, 1982 MEA'.=;LIRED DEPTH JOB NUMBER BOSS-16084 KELLY BUSHINO ELEV. = OF'ERATOR-SAMEC' , . .... ~":' 2' :'5¥' · "," !" '5 ;,,,'¥.:'/ '., ?.', ' ' .... INTERF'OLATED VALUES FOR EVEN':'i'O~i;~,EET OF SUB-SEA DEPTH. ", · ',:*,',~,,~::,',~,:.~:~.;~,,,~,,.: . , ,,,' , :.>' , ,, . ~, · =. JB-,..EA TOTAL ?; .. VERT IC:AL RECTANGULAR COORDINAI'ES DEF'TH NOR1-H/SOLITH EAST/WEST , ;: ~, :.-.-.;.~.~T..;,r.:. ,-~,..,,-. ,.,~;, : , ,, ~ '¢:~,,~., ,,.~, ,¢, · ,'.,.,",', .','.,~'t~.",', X,..',",, -74. O0 () O0 .... ;~"~:,:.'.i;$."'¢, O0 O, O0 0 0 ~ "' .',",'.. :~ '~; *~-'''' ' 74 TRLIE VERT I C:AL DEPTH MB-TVD VERTICAL DIFFERENCE CORRECTION O, O0 O. '00 ' O, O0 74.00 74. O0 FT. 174 274 374 174 00 100.00 274. O0 200. O0 374. O0 :300. O0 474 474.00 40.0. O0 574 ./:/74 574. O0 500. O0 674. O0 60.0. O0 774 ::5:74 974 7'74.00 874. O0 974.00 1 () 74 1174 .~. 274 1074,, 1174. 12:"74,. 00 O0 O0 7()0.00 80C), 00 90 C), 0 C) .l O0, OO 0. O0 O. 00 0.00 O. 00 O. O0 0.00. O. O0 O. O0 O. O0 O. 00., O, O0 0.00, O. O0 0.00 O. O0 O. O0 0.01 0.01 0. Oc) O. O0 O. O0 0.00- O, O0 0.01' 1 :=:'74 1474 1574 16'74 1. 7'74 i374. 1474. 1574. 1674. 1'774. 0 (.'.) 0C) O0 O0 O0 :300.00 4C.)0, O0 500. O0 ./=,00. O0 700. O0 ..... ~. N 0.62 W · , 4.48 N ": 0.49 W 4..-.,- N ~;' 0 57 W 4.....51 !'~ .... ;.~,,'-'"".' '0.53 W 4, :37 N "";..,. O, 3.5 W o O. 02 O. 02 O. 02 O. 02 0.02 0.01 O. O0 O. O0 0'. bO O. O0 I SPERRY-L=;LIN WELL SURVEYING COMF'ANY ARCO ALASKA, INC. D.S. 6-17 (SEC il TION R14E) PRUDHOE BAY A L A S K A ANC.:HORA, ,O.~. ,' ALASKA h ,~", ~..' , · , ',;, :,,..;, CO~PUTAT'ION [lATE. .JULY !4'' !.982 · , · .. DATE ,OF E:URVEY' dULY : F'AGE 7 dOB NUMBER BOSS-160:_-:4 KELLY BUF;HING ELEV. = OPERATOR-SAMEC m m INTERPOLATED VALUES FC, R EVEN,,j:'.~,~,F~ET OF SUB-SEA DEF"TH ~,, ,Q" ,t. ,,' ·., , · '"' ' ;' ' ,' ,'t' '" ' ]-RUE F-';UB- SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR MD-TVD DEF'TH DEPTH DEPTH NORTH/SOLITH DIFFERENCE 1874 1874.00 1800. O0 3.:B1 N 1974 1974. O0 1900. O0 3.54 N 2 C) 7 4 2 0'7 4.0 (') 2 C)C) ('). C) 0 2174 2174. C)O 21 (")0. O0 2274 22'74. O0 220C). O0 3.:36 N 3.22 N 2.85 N ~.45 N 2.02 N 1.&8 N 2374 ..o74. O0 2300 ¢..')0 : :2474 2474. OC) 2400. O0 ' '~'": '-'.~.~7A O0 '-'~'-'J' ..... ..,74 ...._ -- . ..._,(. u . O0 COORp!NATES EAST/WEST , ,-r.; ~;.."~.~;'i '(~" .'.', .,-, _,{¢:cx, ;;~. ,' , ,,, .:¢~ .~ ~ ~,,. ~ ., ,. ~. , ~ ~ Y . ,. ,, ~, .v .~ , 1.84 E ,,," '~.35 E ",,,..~',?,;'~"R, ~0 E ., ,*,.~.,~ ':.'¢ ,. O. 0:3 C). 03 O. c) 3 O. 04 O. 04 O. 04 O. 05 O. O& 74. OC) F T. ,VERTICAL CORRECTION o. oo o.o0 "0. O0 O. O0 O. O0 O. O0 ,.. O. Ol ,'. O. O1 ' 2 6 7 4 :2:.6 '7 4. C.)0 2,.'.- ¢.'.) 0.0 0 2774 2774.. O0 2700. C)O 2874 2874. O0 2RO0. O0 I. 31 1.06 O. 53 2974 2974. O0 :';:'.-1~'()0. O0 3074 · 30'74.00 3000.00 :3176 3174. O0 3100. O0 1.55 11.81 · "~-C: :B 7 N 7.40 E · ,,.!i ': e.4:~ E N N 7.97 E (:). (')'7 O. 07. O. 08 A. 20 O. 87 2.38 O. O1 O. O1 0.01 ...... 0.12 0.. ,66, 1.52 :3 2 '7 :.=: :2:2 '7 4. (.) (") 3 2 0 0. C)0 · _ .=,,::, 1 .:,.:, 7 4 00 3 :=: 00.0 C) .,:,4,=,.J :3474. O0 3400. O0 Z] '-~7 · ':".--' 7:3.70 102.3:3 98 W 6'4 W '--' '~' oo W m.c..-5 · ...I .~ 7.58 11.77 2.14 3.06 4.19 :':.'.'.'.~ 91 ....... ,74.00 35 () 0.00 '-'/":~'~ 3674, C;O 3/:.00 O0 · .~ 2:, :; :_ . · 1:34.70 171.69 17.15 24.16 '~ 37 7.01 AR~o ALASKA, INC: D.S. 6-17 (SEC; I1 TiON R14E) i-. , i i '-' I · =,FERRY-oLN WELL SURVEYING COMPANY ANCHORA~'iALASKA PRI_IDHC~E BAY ALA'.:;i<A JLILY 14, 1982 PAGE DATE,OF SURVEY dULY 1J:, 1982 · dOB NUMBER B0SS-16084 KELLY BUSHING ELEV. = OPERATOR-SAMEC ',, INTERPOLATED VALUES FOR E EN:...{~J:'~EET" ' OF V "' SuB-SEA DEPTH ", ., ~<. ~, , ,~ ~? · , , , ~ ¢;*.:~. . , . 74. O0 FT. MEA.=, _IRED DEF'TH · ~;,,~. 07 :3918 -. 40:31 ' 414:3 42/:,'~.? 439.4 4526 4666 TRUE SUB-SEA VERT I CAL VERT I C:AL MD-TVD DEPTH DEF'TH D I FFERENCE 3774. O0 3700. O0 , 3874. O0 3800. O0 3974. O0 :_39(',.'). O0 4074. O0 4000. O0 4174. O0 4100. O0 427'4. O0 ....... 4200'.- O0 4:374. O0 4;::00. O0 4474. O0 4400. O0 4005 45'74. O0 4500. O0 49:39 4674. O0 4600. O0 · _,07.:. 4774. O0 4700. O0 5208 ........... 4'874.'00 ........ 4 ~0'0; O0 534:3 . 4974. O0 4900. O0 . 5480 5C)74. O0 5000. O0 54.1 '?, - 51 '74 ' O0 5 t O0 O0 5760 5274. O0 5200. O0 5905 5374. O0 5:300. O0 ~056 ' 5474.00 5400'; O0 6:20:3 5574. O0 USO0. O0 TOTAL, , REC:TANGULAR cooRDINATES NORTH/~,uUTH · EAST/WEST "'." ';:. ;,','i.7",," '"'Z:'&. 213 73 - $'" , ,,: ,. ~,~:~ - .., ,.. w 310.48 '~ 77.9:3 W 366.56 S . :-:.,~':,:¢,9. z& ~W 429.07 S ;'; :'..!,;.125. 77 W ,60, ?o s' w ...... 748.85 S ~ 280;41 N 91':,. .04 ;:," : ~:"::':~37" 16 W .t 09:2.06 s..~',,.?,~.~¢0, 33 W I 181.37 S...;i'.':?.417 ,.6~ w i27:3.77 S 446.724 W 1574 .' 5'6'S .......... ~4~; O't' N 16,:c'? ...... E:9 S 584.46 W ', 33.23 44.35 57.83 74.45 95.34 120.63 152.53 1~2.52 231.15 265.05 299.88 44.5.69 486.50 531.60 5'82; ~6 634.52 VERTICAL CORRECTION '~S~,. 07 .. '" 1 1'. 12 i3.47 i" 1'6.62.,.. -: " 20.89 mi,¢0..' . ' '3'.~, 98 ' ' 38.64 33.90 34.83 ,,~ 34.8~ 36.84 39.21 40.82 45.10 50;'75 52. l& ., 's ARCO ALASKA, lNG,;'....'. :. D,S.'6-'17 (SEC. 11"Tt'ON RI4E) F'RUDHCE BAY SF'ERRY--SLIN WELL SURVEYING COMF'ANY ANC.HORA.,,OE?AL ASKA .. ;:,,~,: .'~,?.~..~ ~. COMPUTATION DATE- PAGE :: DATE ,,',OF. SURVEy...dULY 13, 1982 ALASKA ,JULY 14, 1982 ..lOB NUMBER BOSS-16084 · '. ~.'.~ KELLY BUSHING ELEV. :, ' ~'.':" ' OPE RA TOR- SAMEC · ,' l.'~ iL,';:,".~"7. '..."',7 i.' .r :'.~f?'i ~j:,: ~~'~ . ZNI'ERF'OLATED V~LUES FOR ~V~,'~J~:~ET OF SUB-S~ DEPTH" ,,'" 'I'RUE SLIB-SEA MEASURED VERT I C:AL VERT I CAL MD-TVD DEF'TH DEPTH DEPTH D I FFERENCE 6362 56'74. O0 6517 5774.00 6673 5874. 6828 5.974. 6984 6074. 7140 ' '6174. 7:.7-'96 6274. 7450 6374. 76u .....~-.474, 775S~ 6574. 790'~ 6674. :3~E~/ ' 6774. 8:203 . 6874. 8:34'7 , 6974,, :'.'i: 48 '!:? 7074. ,:,6.:,0 7174. ,"', 76 .~" 7274 · ,.:,::'06 7374. '.'.'-".) 4 :.':: 7474. O0 O0 00 O0 O0 O0 00 O0 O0 O0 ..... 00 O0 00 O0 00 0 ('.) ()0 5600,00 5700.00' 580 ('). 00 5900. O0 60C)0. O0 6100, O0 6200. OO ,'!.,7:00. O0 ...... 6400.00 6._,UO. O0 6600.00 ,!.700. O0 6c, rJV. O0 '7000.0 7100.00 7200. O0 73()¢~. O0 7400.00 TOTAL, REC:TANGULAR : CooRDiNATES NORTH/SOUTH ' ':'EAST/WEST " ' :~'"'~,:;~:~"2::~:;, , '";'~':'~" ~":'~""" ' 2o19.o2 S ,,' ~,06 W 2358;42 $ '.V"::~i~?..'814, 74 W 2470.90 ~.:."<,j~,~53~ 11 ~ ~ 1 ~ 7: 5 ~ m ,~ ,?'~,~06'4.79 W :3:.312.48 S 1126,86 W . 3406.52 S ' 1156.~5 W c, 4..o.51 S 1186 05 W 3677.23 S ,.I244.61 W VERTICAL "' CORRECTION · 688, 743,, 797). 854. .glO. , 73, . ':.', '.55,30 '.: 40 ........... ~ - ..,5.6~ ~6 55.56 77 55.81 966,93 · 1022.25 ;~.. 1076,71 , ,%'~' ' . 11°1~, · 42 l~eS.O~ .' I~o6.00 56.16. 55. 54.47 54, 70 53.68 · 50.90 47'; 45, 6~ 44.21 1283. 132~. '1373. 90 59 81 1415. 1456. 14~ 73 26 .;.,.~ 41.~3 40.53 · 38.96 1569. 65 76 37.43 37.11 = 74.00 FT. i · . ARCO ALASKA, INC, · . D.S, 6-17 (SEC tl TION n~4E~'"' ) SPERRY-.-SLIN WELL SLIRVEYING COMF'ANY ~, ~ ..~ · .... :.:. · .~ ~N~:HoRAOE'..'ALA,- KA . . ., COMPUTATION DATE F'AGE 10 ..... '~:i..:.7~: .;.'i ~:.' · .i '5 i. '>..:'!i:~ .::..' · .'.. :.::."' .' :': ' :' :.'. "...'.... ": · ' '. .... · ~.'... '..": DATE .,OF SURVEY dLILY 13,. 1 F'RUDHOE BAY ALASI<A TRI...iE MEASLIRED VERT I CAL DEPTH DEF'TH 9180 7574, O0 9316 7674, O0 dLILY 14, 1.982 :'.' KELLY BUSH I NO. ELEV. ' OPERATOR-SAMEC , ,- ~-,~-~'~-;- ~ ; ~, ~,, , , ,~. , ,,,~,~ ,',,, , , ,, , . .' ,.':.~ .-'L;:' "~.~ INTERPOLATED VALUE:3 FOR E.V,E,N~:~p.~:'?'::.F.~.I~T .OF: SUB-SEA DEPTH .." : .'" , , ..., ..;. ,:.~:A~,~,~,~,~,,., , .. . :..... ...,. ..... ,, ::~.. :',:.., ......... %,,,:, ,, ~,,~;~,,,, , . ........ ~ ......... E;~ ~B-SEA TOTAL" VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL DEF'TH NORTH/SOUTH 'EAST/WEST DIFFERENCE CORRECTION JOB NUMBER BOSS-16084 74, O0 FT. 9453 7774, · - ';?588 7874. 9721 7974. wu 4'8. ' 7500. O0 376t]. 50 '-"' '~ :.~',.,';i~.'",'~ ';: · ... 76oo. oo 7" ', ' 7700.00 3940.71 3 1336.12 W 1679. ' "'~ "' W : 1714. 7800. O0 4025.6~ 5 :~ :~i!aA7. ~:~ ', 7900.00 4106.54 8 '::~1.400'26 W 1747. 8000.00 ' 4187.10 ~'.~:~,~':]~j~32~,4 W '% 177~. 81(iO, O0 42~9.13 ~','"?,:;?';:~i~;~0 W . 1812. 8:200.0o 'e; W " ~ 1846, '.-.785:3 ' 8074 9986 8174 10120 8274, O0 O0 O0 O0 O0 O0 39 36, 42 41 35.01 , 03 32.63 47 '.: ,~,~.44r, ",' 77 '"": ~," 33.30' ',", ., 98 ' ',. ::/ .., ~+o~u 1 ():257 8:374.00 8:-300.00 44:.]8. 10:397 8474.00 8400. O0 4:..,.' 6. 10794. _ 1 8574,00 o'-'~._, O' O'. O0 4619, 1A/:.87 8674, O0 8600, O0 4712, 108.'.]-:7 · 8774, O0 8700, O0 4809, 10 .,~c,~ 8874. O0 8:300, O0 4908. : 11. 1:38 8974.00 :i3'.~h)O. 00 5005.44 S 1835, 05 W ! · · -"-'.=; ....... ~ - 1889.80 W I 1 .-',: .... 'P074.00 9¢)00 O0 ._ 100.14 ~; · ., 114:30 9174.00 '~100.00 519:3,23 S 1939.26 W ................... T'f.~'~;iT~T .... -~;'~..~ 1 o...-., o,._... 9147 oo_ ~-.-,.-, .......... ............. o,.;, .::,...o7.73 8 1962~ .82 W 1883.68 1923.51 1967.37 .. 2013.50 ..... 2063.24 2114.89 THE CALCULATION PROCEDLII.;;ES USE A t_II,IEAR 'INTERPOL~ATION BETWEEN :36.70 39.~J~='~' 43.86 ' 46,18 4~,74 51,65 2164.09 2211.21 2256.51 .~,~' 4S>.20 47.13 45.30 21~'61 TI.Il!:" IqEARES"I" 2() F O0'T' h'l[I ( F'F.~OM F;,'AI'f I US (.:iF C:URVA'TURE ) F'("I I N'I"S SF'ERRY-SLIN WELL SURVEYING COMPANY PAGE 11 ARC. o ALASKA, · INC:. D.S. 6-17 (SEC 11 TION R14E) F'RUDHOE BAY ALA::;KA TRUE MEASURED VERT I CAL DEPTH DEPTH COMPUTA?{ON 'DATE- JULY 14, 1982 10819 10849 10888 10917 10972 INTERPOLATED VALUES FOR $.P.~,~..)~~I:NEY POINTS ' ,,,~.:~, ~:,,~,'~ ~'. ::.,. ~;: '~... . ~.' · ;. ~ .,,:~ .'~,~(?. . SUB-SEA TOTAL ' ,, '.~: . VERTICAL RECTANGULAR COORDINATE~ DEPTH NORTH/SOUTH · '~ EAST/WEST MARKER' 8761.93 8687.93 8781.7~ 8707.7~ 8807.39 8733.39 8826.43 8752.43 8862.75 8788.75 1264 9059.45 89:".::,5. 1293 9079. ;34 9005. 1350 9118.52 45 DATE ',OF, SURVEY, dULY, JOB NUMBER B08S-16084 KELLY BUSHING ELEV. = OPERATOR-SAMEC ,. ..... : ".. ' .... '--' .... ' ........ ' ......................... R R !. V~R' ,SANQ ..?:~',:.~,,:,~,..:,....: ',: ,, ...... ": 47$:,'7,~2'~,i;,i~.~,~,44,, .W'.:'~i,,."..,'.i,'.;,'.TOR 'S 0 " .... '"'~";"'~:'"' ':"'"" ;":' "~ · ' . - ',F ~ · ," :'Y :'!~ "'"'~j ' ;"" ~' ,.' '~ "'~.,' .'· · 4817.02 8 :i~!;!'~"~,':~'6D W i !,,:.: 'TOP SHUBLIK:,'~: ,:,:', .k."'",,,, ",,.: .' ,?' :, ,;.",.', :' ~ .... ~ 4842.59 S mi'' . 17'~.7.!8 W 'FOP SHUBLIK B 4861.6! S",'i~.!,J):]'7~,7.98,,,W TOP SHUBLIK C ~',..',, ' 4897.58 S "ii','~'1,~78;28 W, TOP SADLEROCHIT ' "' 50:-':6 54 ~"~':"i:'~-~ ' ..... ' ...... '' s ,,,..,::,~%l!~e..2, ~i ~ TOP HEAVY ,OIL,'-' ':"- '.,?' :. . ~ ,=.. .,,, ,..,l~,'~ .... ., ' ". , ,...,,"' <:,.~,..,' ',' . . . 51~a 13 ~' :,,~.~.~,.~Sg~,.~.:.~....~}~ .... ...~..,.,,48' W , , TOP ZON~ 3 ' ......,, .~ ,, .,.. 5141 67 ~.'j',"io~,',,,~g~:!."_,96 W .' SURVEY DEPT,H, . ' ."". 'i.:"' ',.',',, 1982 74.00 FT. ..:.., u 'P 118.5 :Z 9044. 1414 9162 62 "?'"'-"-' . ; ~..-'C.,O, 1444 91:E:.3.29 9109. 62 5!41.6'7 $ 1~,1..!.96 W ~ 182.66 $ '~i::'??:?i:&,~33, ~,~ w 15 0 0 c~ 9 s, i A'-' ........ ,,:, 9147. 8:3 523:7.73 S OIL/WA'FER CONTACT TOP ZONE 2 '" PBTD "~ TOTAL DEPTH DRILLER .,i'.'. . '" · .~ .. 'Z. ' ARCO. ~LASKA, INC. D,8.'.', ~.-;I:~:,'(E:EC i! TION R14EI ..,' '. STRATIORAPHIC SUMMARY DERIVED USING DIL DEPTHS'AND SPERRY SUN SURVEY DATA -MARKER ............. MEASURED DEPTH · ~, ~ ".~'?,?'~', ~:.~. BKB ,' , "~"~',~'. ' - ' ' ,..,,:,',~ e,~g~'~:.,, ,,,, , , , : ~,. TOP SAG RIVER SAND 10:319 8761 TOP SHUBL IK A 10E:49 8781 · 7~ ::";; 8707.79 ' '"'q" TOP SHIJBL IK B 1 oo~.d TOP G;HUBLIK C i 0917 "e~6'~:~?:~,,8752; 43," '""' TOP SADLEROCHIT 10972 7~,"':' . I'OF' HEAVY OIL 11264 905~45, 8~85.45 7LF'-, ' .ZONE :Z:" 1129:3 90797'm4 ;?:~'" 9005.34 SURVEY DEPTH 11.:.~ o . . ~:, -~ - OIL ~f[:~---~7i3 N TACT 11:350 TOF' Z ONE 2 11414 91 &~;:~J,~i~,:.,,,9088, 62 PB'rD 1 ~ 4.44 1' O'I'AL D[:F:'TH [.U.~I LLER 11500 9221.88. 9147.88 . .. , :...: .: ' . ...... , ,'. ~,,.~? , ' . ;Y'%,4 .:',,.. . . ~_. .:. 5 :~ ....... '' : ,' .......... : .... ~. ........... ; ..... }~r"" ~.~F'"'"~.*' ...... '-5;*i"[i-~ ........ ."'r~.":',"::' ..... ~}~'"-~ ........ i.,[TE,-D~:7~:--~. - ..... : .. 1.) F.I.~uFI L. INEAF~ E..X~I~F.d ULAI.[uN BELuW KLE..[LwT ,,TATION,, 2) F:['iMF'~I"rF:R F'I:~OARAM - SF:'F:'F(RY SI.IN THREE' DIMENSIONAL' ~ADIUS OF CURVATURE, DATA E':ALC:Ld..ATZC~N AND I Nt'E:RF'F)LATiON BY RADIUS OF CLIR~ATURE, C:OORD I NATES; 'FH~C:KN~$~. WITH REF. TO WELLHEAD VERTIC . ,',..( ,ORXu.';N- ,' FNL m6OF -L ) '" '" .". SEC i1 TION :R14E 4797.52S. 1721 . 44W ~ 4817 02S 177:2 /. = :" '::~i'84'2 5~-2'~ ......... i'747 18W .. .: ..... y,:~, ..... .. ;~ :,:';; , ~ , .~.., ~' .~,. ..... ..., ....:,~, :... :.. ,:.ae~l' bis,., j 75:z: ~8~ " " ..',48~7: 585-:" "j 778.28N 5086 54S 1 k~::-' W · ' - ". 51 · :. slo5. '-..- 1 ~ 1892, 48W ' 5141.67S 1911. :96W < .,.",~ ....:~ '" 514i~678 , {:~11,96W "". '. '520 I. 87'3' ' ' I ~43.84. W 523'7.73S 1962. :32W 'DATE OF SURVEY dULY 1<'..~, 1 ::~b:';""- . dOB NUMBER BOSS-16084 · ' KELLY BUSHING ELEV. = '74,00, FT,.,, ( . , O. OO 2000.00 4000.00 8000,00 ~OOOO. OOv Our Boss Gyroscopic Survey Job No. Boss-16084 D.S. 6-17 (S~Cll T10N R14E) Prudhoe Bay Field ~ Date: July 13, 1982 Operator: Jo~n Samec Scale: 1" = 2000' %%>. -:.::'..~:..', ~!;',':~! . ..... ~:'.;-- ''~~'''''' ' : . '; - . - ' 5593.44' 11500 2050. oo 4oho. oo soho. oo : VERTICRL PROJECTION -~obo ~ ARCO Alaska, Inc. Our Boss Gyroscopic Survey- _ Job *No. Boss-16084 D.S, 6-17 (S~Cll T10N R14E) ~ B~¥ Field S~ Date: July 13, 1982 Operator: John Samec Sca/e: 1" = 1000' O0 11500 --4000. O0 '-5000. O0 -60QO. O0 HORIZONTRL PROJECTION TELEEO Teleco Oiihe;d Serwces Inc. 220 A Center Court Anchorage, Alaska 99502 ARCO OIL & GAS JOB 129AK ROWAN 26 FSE: ALIM ALAM 6/17/82 6/18/82 6/19/82 6/20/82 6/21/82 6/22/82 6/23/82 Arrived on rig at 1100. Tool 263-23 and surface gear #182 on rig. John Emery is company representative. Dale Hendrix is directional driller. 13 3/8 casing is being run, (shoe at 2502). Cementing casing and nipping down and up. Tool goes in the hole at 1500 to drill through cement, make 400' of new hole and kick off with jet at 2900 from vertical. Continued jetting until 1230. Tool out of hole co change bit and to rotary drill. Tool shows 10 degree right hand walk in less than 400'. Company representative and directional driller are concerned about tool and drop 2 Single Shots 200' apart and show 3 degrees difference. Total right hand walk is 14 degrees in less than 900', so it is decided to make a dyna drill correction run. While tool was .in hole, tested tool at benchmark location. Azimuth varies up to 9 degrees at an inclination of 10.6 degrees. Suspected initially drifting sensor so its decided to change tool; but after reconsidering situation, told company representative that this condition is normal tool behavior with a high powered motor, thus, no need to change tool. But company representative was still doubtful about accuracy even though it was explained that in the North Slope area, magnetic interference is quite marked and attributed this to the azimuth differences. Tool 259-25 was picked up and tripped in hole at 0930, tested at benchmark location to show company representative that effect of dyna drill was still the same. Tagged bottom and made correction run until 2030 at which time tripped out of hole for BHA change. ~ Tripped in hole with semi-packed BHA to rotary drill. Dropped Single Shot (D=5862', A=196, I=46) and tool displayed closely (D=5877, A=196.4, I=46.7). Tripped out of hole to change BHA. Tripped in. hole with packed assembly to rotary drill. Tripped out of hole to change bit. .ARCO OIL & GAS JOB 129AK CONTINUED ROWAN 26 FSE: ALIM ALAM 6/24./82 6/25/82 6/26/82 6/27/82 6/28/82 Tripped in hole to rotary drill and dropped Single Shot (D=8096, A=197, I=47) which was close to tool, (D=8065, A=196, I=46.9). Tripped out of hole for BHA change, tripped in hole to rotary drill. Dropped Single Shot (D=8852, A=196.5, I=43) Tripped out of hole to change BHA. Tripped in hole to rotary drill. change BHA. Tripped out of hole to Tripped in hole to rotary drill. Tripped out of hole to change BHA. Rotary drilling. Rotary drilling to 10841' (casing point). Tool out of hole at 1800 6/28/82 and sent to AIA at 1600 6/29/82. Rig personnel satisfied with time savings and accuracy of tool. Job complete. CUSTOMER : ARCO LOCATION : PRUDHOE BAY, ALASKA ,' WELL PAD : DS-6 WELL NO. ~ DRILLING CO. : ROWAN CUSTOMER JOB NO, ~ TELECO JOB NO. : 129-AK MAGNETIC DECLINATION m 30.58 E PLANE OF PROPOSED DIRECTION I8 ~ DIRECTIONAL DRILLING 8URVEY REPORT 17 RIG NO' m 26 17.51 W PAGE I TELECO OILFIELD SERVICES OF ALASKA, INC. 228 CENTER CT., ANCHORAGE, 'ALASKA, 99582 TEL ~ (987) 279-8631 DATA REDUCED BY RADIUS OF CURVATURE METHOD TyPE OF SURVEY t MAGNETIC 8TART DATE ~ 86/16/82 FINISH DATE : 86/29/82 REPGRT PREPARED BY : ALIM ALAM MEASURED DRIFT TRUE VERTICAL DRIFT DEPTH ANGLE VERTICAL ~ECTION DIRECTION DEG MIN DEPTH DEGREES 2680 1.86 2659.99 8,21 2837 8.54 2836.96 .8.14 2932 2.38 2931,92 2.81 305B 7.18 3855.47 11.96 3180 18.36 3177.96 31.25 5537 13.54 3331.38 64.27 3491 17.18 3479.71 185.35 3739 23.88 5712.53 198.34 3859 25. A8 3821.81 239.85 4014 28.36 3959.67 318.78 4250 34,18 4143.94 423.18 4354 37.18 4244.51 495.86 4508 41,42 4363.34 591.62 4~32 46.86 4~52.69 676.24 4826 41.42 4592.48 889.85 5001 42,18 a722.53 926.92 5521 4&.12 5181.28 1283.84 5~7'7 46.42 5551.85 1536.~1 6405 58.12 5781.2~ 1951.75 C709 58.12 5895.83 2165.51 7197 58.24 6288.12 2548.27 7715 49.48 6539.11 2955.95 8065 46.54 6773.84 5198.82 838~ 45.42 6994.12 5438.11 B 79 E 8 76 W 8 19 W S 18 W S 18 .W S 18 W 8 13 W 8 28 W 8 23 W 8 26 W S · 28 W 8 27 W S 21 W S 16 W S 15 'W 8 16 W s 18 ,w S 17 W S 17 W S 16' W S 15 W S 16 W S 16 W TOTAL COORDINATES C L 0 8 U R E S DISTANCE ANGLE DD MM SS 0.66 8 1.51 8 11:48 8 62.97 183.7~ 187.'47 235.46 382.84 568.98 637.25 768.14 1.39 E ~8.08 4.36 E 4.61 S 78 52 ~8 E 4,45 E 6.28 S 45 48 57 E ~.58 W 11.97 S 16 22 5m W s. 21 w 3~.26 s 15 13 12 w 1~.9~ w 64.58 s 12 3i 36 w 21.18 w 185.89 s 11 ~2 2m w 38.21W 191.32 S 11 31 17 W 58.63 W 240.84 8 12 88 83 W 72.52 W 311.48 8 13 28 88 W 113.82 W 423.29 S 15 55 56 W 143.98 W 495.88 S 16 53 52 W 188.37 W 591.77 S 18 53 42 W 228.88 W 676.84 8 19 ~1 33 W 282.79 W 811.84 S 28 24 23 W 319.95 W 928.88 S 28 89 57 W 415.16 W 1285.52 S 18 52 19 W 482.96 W 1536.85 S 18 18 56 W 598.49 W 1931.91 8 18 82 47 W 668.72 W 2165.46 S 17 59 15 W 789.88 W 2385.94 S 17 55 38 W 776.48 W 2548.57 S 17 47 44 W 882.19 W 2935.95 S 17 29 18 W '952.48 W 3198.83 S 17 19 22 W 181~.24 W 3438.12 S 17 14 81W 871.19 1214.52 1459.88 1836.87 2193.98 2418.82 2888.28 3853.73 5276.12 DOG - LEG SEVERITY DEG/100 FT. 8.158 3.513 5.877 2.883 2.182 2.288 2.335 2.551 2.157 2.736 2.802 2.974 3.592 5.128 1.942 0.388 8.738 8.721 8.253 8.855 8.271 8.189 8.851 8.575 DIRECTIONAL DRILLING SURVEY REPORT PAGE 2 MEASURED DRIFT TRUE VERTICAL DRIFT TOTAL DEPTH ANGLE VERTICAL SECTION DIRECTION DEG MIN DEPTH DEGREES COORDINATES CLOSU RE8 DISTANCE ANGLE DD MM SS DOG - LEG SEVERITY DEG/100 FT. 8689 ~5.5~ 7289.83 564&,26 S 16 W 5~82.03 8868 ~2,48 7540,08 5767,18 S 16 W 5688.15 9195 ~2.48 7579.95 5989.26 S 17 W 5815.17 9502 ~2.50 7885,75 ~197.28 S 17 W ~012.88 9~55 al.06 7919.78 ~299.25 S 17 W ~189,61 99~0 al.06 81~9.62 ~99,72 S 19 W A588,29 10256 ~5.50 8568.85 ~698.71 8 21 W ~a87,49 10775 ~7. A2 8729.2~ 5069,08 S 28 W A828.22 · BOTTOM HOLE CLOSURE! 8069.25 FEET AT 8 17 ~ ,19 W 1875.29 W 1109.16 W 1172.26 W 1255,07 W 1262,89 W 1524,85 W 1592.98 W 1A75,66 W 15A~,~9 W PREPARED BY ABACUS COMPUTER SERVICE 820 W, 71ST. AVE,- ANCHORAOE, ALASKA ENTIRE CONTENT8 COPYRIGHT 1982 ABACUS COMPUTER SERVICE 56~.28 8 17 09 ~0 W 5767.15 S 17 07 2~ W 5989.50 S 17 05 19 W ~197,29 S 17 85 05 W ~299,27 S 17 0~ 56 W ~99,75 S 17 07 25 W ~698.72 S 17 1~ ~2 W ~915.89 S 17 28 52 W 5069.25 S 17 ~ 19 W (907) 3~-0761 8.592 0.615 0.208 0,098 0.915 0,~51 8.950 1.259 1.~9 Suggested form to be inserted in each "Active" well folder to d~,eck for timoly compliance w'J.~ our' regulations. Operator, Well Name and Number Reports and Materials to be received by:~v -__~__!~ Date Required Date Received Remarks Comp l etio n Report . Yes · We11 .History Yes y -- / ? - ~ ~L ~.,:~ ./'~'~,.~ _Samples. ~//0 P / :"~' ~''' Mud Log · Core Chips -- Core Description' . Registered Survey Plat y~_~ · ~, , Inclination Survey ,.-.:"- ~-,, I Directional Survey yes-- FI ,Drill Stem Test Reports ./~.~~ '- - 0 ~' . Production Test Reports ,~, , , , Digitized Data 7 ""'" . , ~' ARCO Alaska, Inc~ Post Office BOx 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 12, 1982 Reference: Arco Directional Surveys D.S. 6-17 6-16-82 Magnetic Survey Teleco D S. 6-18 7-7-82 Magnetic Survey Teleco ~e sign and return the attached copy as receipt of data. Kelly McFarland Trans. # 377 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON CHEVRON ,Alaska 0il & Gas Cons. Commission Anchorage TELEEO Teleco Oilfield Serwces Inc. 220 A Center Court Anchorage, Alaska 99502 July 26, 1982 ARCO OIL & GAS ROWAN 26, DS-6, #17 ATTENTION: JOE PUTNAM Dear Joe, Attached please find a copy of the computer calculated survey for the above mentioned well. On behalf of Teleco, I would like to thank you for the opportunity to serve you. We at Teleco realize the importance of good service and hope that you will continue to use our MWD services in the future. Please feel free to contact me if you have any questions. Enclosures SB-ck Sincerely, Steve Billeaud Field Service Supervisor RECEIVED AUG ] ,7982 ~c.horage ARCO Alaska, Inc. y Post Offic~[ x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 9, 1982 Ms. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Dear Elaine: Enclosed are as-built location plats Drill Site~F6'~ Wells Drill Site'S18 Wells If you have any questions, please call Sincerely, JoAnn Gruber Associate Engineer JG:sm Enclosures GRU1/L62 Plats for the following wells: ~L~, 21, 22, 23, 24 6, 7, 10 me at 263-4944. ARCO Alaska. Inc is a subsidiary of AtlanticRichfieldCompany CHK. JOB NO. f , LOC~.TEb I1.-I GE,(_- il >"T IOl,,J) ie..I,4-1~, IJ.H. THick, PI_.~T ~;~.EPP. ESEI',.IT5 ,~,1~i y_. A,K Zo~' 4'- 41aska.Oil & ~as Cons. 'AnChorage I~4 ~ C_ol~. C_..E L LA, R ~:¢::)Y. E'LEV.--- 37/--~ ' inc I l ~ I ~ OF Subsidiory of Atlantic Rich,ield Compon~ I NORTH ,S, LOP[ DRILLIN~-P~OE BAY III III ARCO Alaska, Inc. [' Post Office BI ,60 Anchorage. Al'a'ska 99510 Telephone 907 277 5637 August 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State ReportS Dear Mr. Chatterton: Enclosed are monthly reports for July on these drill sites: 2-25 13-25 18-3 2-26 13-30 1E-15 ~ 13-33 1H-3 6-18 14-21 1H-4 6-19 18-2 Also enclosed are three subsequent sundry reports for Kuparuk 1H-5 and completion reports for: 13-21 15-~ 13-24 18-1 13-26 1E-14 14-17 1H-5 1.4-22 The gyroscopic survey for DS 2-22 needs to be reran; a com- pletion report for this well will be submitted when the approved survey is received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG:sm EnClosures GRU1/L61 ARCO Alaska, Inc, ~s a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA , -, - - [ALASKA~, " .L AND GAS CONSERVATION C(' ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellxI~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-90 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20760 9. Unit or Lease Name FNL, 860' FEL, Sec. 11, TION, R14E, UN Prudhoe Bay Unit 4. Location of Well at surface 3 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 6. Lease Designation and Serial No. ADL 28311 10. Well No. DS 6-17 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of J u l y ,19...82 ,12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0300 hfs, 06/17/82. Drld 17-1/2" hole to 2510'; ran,cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 108/+1'; ran, cmtd & tstd '9-5/8" csg. Drld 8-1/2" hOle to 11500'. Ran 'open hol,e logs. Ran & cmtd 7" lnr. Disp well to NaCI. Ran CBL. Ran 5-1/2'" completion ass),. Secured well & released rig @ 1800 hfs, 07/05/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91,5#/ft, H-40, weld, conductor set @ 81'. Installed w/2361# Poleset. 13-3/8",72#/ft,L-80, BTC csg w/shoe ~ 2502'. Cmtd w/2032 sx Fondu & 400 sx Permafrost. 9-5/8" 47#/ft L-~0/S00-95, BTC csg w/shoe @ 10822' Cmtd w/500 sx Class G 7", 29#/ft, L-80, BTC csg, f/10511'-11490'. Cmtd w/325 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHC/GR/SP f/10814'-11494'. DIL/FDC/CNL/GR/Cal CBL f/11436~-10390', 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~ TITLE Area Drilling Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1.80 GRU1/MR23 DS 6-17 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0300 hrs, 06/17/82. Drld 17-1/2" hole to 2510'. Ran 63 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2502'. Cmtd 13-3/8" csg w/2032 sx Fondu & 400 sx Permafrost. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10841'. Ran 271 jts 9-5/8" 47#/ft, L-80/SO0-95, BTC csg w/shoe @ 10822'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt.- Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11500' TD (06/30/82). Ran DIL/BHC/GR/SP f/10814'-11494'. Ran DIL/FDC/CNL/GR/Cal. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 33 bbls Permafrost C, 125 bbls Arctic Pack. Ran 24 its 7" 29#/ft, L-80, BTC csg f/10511'-11490'. Cmtd 7" lnr w/325 sx Class G. Drld cmt to 11444' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/11436'-10390'. Ran 5-1/2" (4-1/2" tailpipe) completion assy w/tail @ 10536' & pkr @ 10443'. SSSV ball valve @ 2024'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 1800 hrs, 07/05/82. JG:llm 08/04/82 GRU1/DH22 ARCO Alaska, Inc. Post Office ~" ' 360 Anchorage,~, ska 99510 Telephone 907 277 5637 July 30, 1982 Reference: Arco Cased Hole Finals D.S. 6-17~ 7-8-82 Cement Evaluation Run 1 5" D. S. 6-17~/ 7- 4 - 82 CB L/VD Run 3 5" D.S. 13-25~'. 7-9-82 Cement Evaluation Run 1 5" D.S. 13-29~-/ 7-4-82 CBL/VD Run 3 5" D.S. 14-22~ 6-10-82 CBL/VD Run 1 5" D.S. 14-2~ 6-10-82 CNL Run 1 5" D.S. 15-31/. 7-8-82 Cement Evaluation Run 1 5" D.S. 15-6:" 6-6-82 CNL Run 1 5" D.S. 18-2-. 7-14-82 CNL Run 1 5" Please sign and return the attached copy as receipt of data. Kelly McFarland Trans, 9 332 D I STRIBUTI ON NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON ECEIVE MOBIL GETTY D&M GEOLOGY STATE,~ OF A~SKA ARCO Alaska, Inc. Post Office Bo~,~360 Anchorage. A( a 99510 Telephone 907 Z'77 5637 July 19, 1982 Reference: ARCO MAGNETIC TAPES & LISTS D.S.15-2 3/4/82 Tape # 62625 (REPLACEMENT TAPE) 'D,S.6-17 7/1/82 Tape # 65256 *NOTE: D.S. 15-2 is a replacement tape,, and one previously Transmittal # 281 sent to you should be destr,oyed. ~ Nor th Engineering. ~~ ~ ~~ / NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON MOBIL D&M GEOLOGY AlasKa; inc; Post Office Box 360 Anchorage. A~."ka 99510 Telephone 90~ 75637 July 12, 1982 Reference: ARCO DIRECTIONAL DATA D. S .6-17 6/16/82 Single-Shot p/lease sign and return the attached copy as receipt ~ data. Mary F. Kellis North Engineering Transmittal ~/ 266 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS S0}{IO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY A~3sk~ 0i~ & G~s Gons, Commission knchomge ~ ARCO Alaska, Inc. Post Office Bo~ ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 July 12, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' 'Enclosed are monthly reports for June on these drill sites- 2-24 .)-25 13-22 13-25 13-26 14-15 14-22 15-6 18-1 18-2 1E-13 1H-8 Also enclosed is a well completion report for Kuparuk 1E-12, and subsequent sundry reports for: 3-14 14-6 4-9 15-3 4'-15 Eileen No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it if you could store it in a secure area. ) Surveys for 2-22 and 13-21 are being reran; completiOn reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG'llm Enclosures RECEIVED JUL 1 21982 0il & Gas Cons. C0mmiss}c,n GRU1/L48 ARCO Alaska. Inc. is ~ subsidiary of AtlanticRichfieldCompany ' ~ STATE OF ALASKA ALASKA C["". AND GAS CONSERVATION CO~~ IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS il. Drilling well J~x Workover operation [] :2. Name of operator ARCO Alaska, Inc. :3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of Well at surface 3' FNL, 860' FEL, Sec. 11, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 6. Lease Designation and Serial No. ADL 28311 7. Permit No. 82-90 8. APl Number 029-20760 50-- 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. DS 6-17 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0ii Pool For the Month of. June ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0300 hrs, 06/17/82. Drld 17-1/2" hole to 2510'; ran,cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 10841'; Can, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 11500' as of 06/30/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 20", 91.5#/ft, H-40, weld, conductor set ~ 81'. Installed w/2361# Poleset. 13-3/8",72#/ft,L-80, BTC csg w/shoe @ 2502'. Cmtd w/2032 sx Fondu & 400 sx Permafrost. 9-5/8", 47#/ft, L-80/S00-95, BTC csg w/shoe @ 10822'. Cmtd w/500 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run None to date 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED J U L 1 2 ]982 Alaska 0il & Gas Cons. C0mmission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ijJ {~ ~j~ ~ Area Drilling Engineer ~,~ SIGNED ' , ~'"~.'~ ..., ,~ TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 GRU1/MR1 7 DS 6-17 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0300 hrs, 06/17/82. Drld 17-1/2" hole to 2510'. Ran 63 jt$ 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2502'. Cmtd 13-3/8" csg w/2032 sx Fondu & 400 sx Permafrost. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10841'. Ran 271 jts 9-5/8" 47#/ft, L-80/S00-95, BTC csg w/shoe @ 10822'. Cmtd 9-5/8" csg w/500 sx Class G. I nstl'd 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11500' as of 06/30/82. JG:llm 07/06/82 GRU1/DH22 Oil & Gas Cons. Commission ~cborage MEMORANDUM State of Alaska /) TO: C. ~. ;~t~rton DATE: J~ne 22, ~1982 . FILE NO: 108/Y Thru: Lonnie C. Smith C~ssioner ~_ TELEPHONE NO: FROU: Ben ~No~an ~trote~ Ins~ctor SUBJECT: ~'~itness BOPE Tests on ARCO's DS 6-17 Sec~ 11, T10N, R14E, Pru dhoe Bay Unit Wednesday, June. _16, 1982 - I departed my home at 12:4'5 p.m. for a 1:15 p.m. showup and 2:15 p.m. departure via Alaska Airlines flight #57 for Deadhorse arriving at 3:55 p.m. Weather: +29"F, light wind, light snow. Thursday, June 17, 1982 - BOPE tests on ARCO's Kuparuk 1E-13 w~re 'Completed., the subject of a separate report. BOPE tests on ARCO's DS 13-25 were completed, subject of a separate report. ~_riday, June 18, 1.98..2. - Standing by on ARCO's DS 6-17. Saturday, Ju. ne .!.9., 19..82 - BOPE tests on ARCO's DS 6-17 began'- at 11.30-a.m. and were completed at 1:25 p.m. BOPE inspection report is attached. I departed Deadhorse via Wien flight #10 at 3:30 p.m. arriving in Anchorage via Fairbanks at 6:00 p.m. and at my home at 6:30 p.m. In summary, I witnessed successful BOPE test on ARCO's DS 6-17. 02-00IA(Rev.10/79) '81 STATE OF ALASKA ALASKA OI ~ CAS CONSERVATION CC~'~IISSION B .O.P.E. Inspection Report _I__ns_.~o r Eate J ~ ~/~ Operator. ~ ~ Representative Well b, 5. ~' 7 ~ PerrpJ t # ~,~- location: Sec // T ~R/4~° M L;.F~_ /~Cising Set Prillinq Contractor ~-~ ~-J Rig ~ --~m Representative location, Genera] Well Sign Ceneral Housekeeping Peserve pit Rig ~f)PE Stack Annular Preventer- Pipe ~ams _--P Blind Rams Choke Line Valves__ H.C.R. Valve-- Kill l'Jne Valves, ~ - Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure _.~,~ __Pressure After Closure psig psig Pump incr. clos. pres. 200 psig min._~sec. Full Charge Pressure Attained: N2 ~~ ~ ~ .a~ ~'~.~ j~ psig Controls: ~ster d~D/~ Remote ~ Blinds switch, cover Kelly and Floor Safety Valves UP~r Kelly Lo, er Kelly Ball Type_ Ins ide BOP Choke Manifold No. Valves.__ No. flanges Adjustable Chokes. Hydrauically operated choke Test Time'/~ hrs Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure days and Test Results: Failures. ~9 Repair or Replacement of failed equipment .to be made within Ins[~ctor/Ccmmission office notified. Di stribut ion orig. - AO&CCC cc - Operator c - Supervisor Inspector June 11, 1982 Mr. ~ark A. Uajor Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Res Prudhoe Bay Unit DS 6-17 ARCO Alaska, Inc. Permit No. S2-90 Sur. Loc. 0'FILL, 851'FBL, See 11, T10N, R14E, Btmhole Loc. 0'FSL, 2525'FEL, Sec I1, TION, R14E, Dear Enclosed is the approved application for permit to drill the above referenced wel 1. Well sm-aples and a enid 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 lotf information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmueter surveys. ivtany rivers in Alaska and their drainage systems have been classified as important for the spawning or wtgration of anadroraous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to c~neing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and (lame. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water ?ollution Control Act, as amended. Prior to e~aumencing operations you may be contacted by a. representative of the Department of Environmental Conservation. To aid us in scheduling field work, we ~vould appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Commu~ission ~uay be present to witness // Mr. Mark A. Major Prudhoe Bay Onit DS 15-25 -2- June 11. 1982 testing of blowout preventer equipment before surface casing shoe ts drilled. In the event of suspension or abandonment, please give this off toe adequate advance notification so that we may have a witness present, Very truly yours, C. V. Chattert'on Chairman of ~l~ska 0tl and {las Conservation Commt~lon Eno I o sure Department of Fish & Game, Habitat Section w/o enel. Department of ~nvironmental Conservation w/o encl. CVC,, be ARCO Alaska, Inc. Post Office Bt,, ,60 Anchorage, Alaska 99510 Telephone 907 277 5637 June 4, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 6-17, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 6-17 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's posi- tion to the nearest well drilled; a sketch and description of the BOP equipment and testing procedure, and a sketch of the surface diverter system. Since we estimate spudding this well on June 15, 1982, your earliest approval of the permit will be appreciated. Sincerely, M. A. Major Area Drilling Engineer PAV/JG:llm Enclosures GRU1/LIO · ARCO Alaska, ~nc, is a subsidiary of AtlanticRichfieldCompany ALASKA ~LANDGAS CONSERVATION C v~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~( lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I-] REDRILL [] DEVEL..OPMENTOIL D(] SINGLE ZONE 2. Name of operator -- · w /,, ARC03. AddressAlaska' llnc. JU~,~ _ 8 P. O. Box 360, Anchorage, AK 99510 Alaska Oil&,r,~n.,~: 4. Location of well at surface Cornmi,, , 9. Unit or lease O' FNL, 851' FEL, Sec. 11, TION, R14E, UM (Approx.'~' ag~ st~r~udhoe Bay Unit name 2 ~a,~t top of proposed producing interval 10. Well number N & 2518' W of SEer, Sec. 11, TION, R14E, UN DS 6-17 At total depth 11. Field and pool 0' FSL, 2525' FEL, Sec. 11, T10N, R14E, UH Prudhoe Bay Fiel_d 5. Elevation in feet (indicate KB, DF etc.) I L~' Lease designation and serial no. Prudhoe 0il Pool RKB 74' PAD 37' AD 28311 12. Bond information (see~O AAC 25.025) Federal Tnsurance Co. Type Statewlde surety and/or number 8088-26-27 Amount $500,00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed Deadhorse 3NW miles 3960 ADL 28312 feet 6--8 well at surface 160 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 11832' MD-9192' TVD fe,.t 2560 06/15/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3474 psig@__.__Surface KICK OFF POINT 3200 feet. MAXIMUM HOLE ANGLES0 · 3°I (see 20 AAC 25.035 (c) (2) 4200 .._psig@°/_2._0_0__ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT , Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) ~u" ZU Y1.~¢~ H-/-;O Weld 80' 37 137 117 117 275 sx t:o surf 11-i/2 13-3/8 72¢f L-80 Butt 2500': 36 136 2536 2536 2300sxFondu+40OsxPF 12-1/4 ~)-)/8 47tf L-80 Butt 10280' 351135 1031518223 500MX G lstStage 500-95 Butt 857' 10315 [8223 1117218770 300MX PFI 2n.dStage 8-i/2 / ZY# L-BO Butt 996' 10836 ,~8555 11852119192 400MX Class G emt 22. Describe proposed program: ARCO Alaska, Tnc., proposes to d±rect±onally drill this well to 11832' MD (9192' TVD) produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-3/8", 5000 psi, RSRRA BOP stack w±ll be installed and tested. The annular preventer will be tested to 3000 psi, and the rams tested to 5000 psi. The BOP equipmenf, will be pressure tested to 5000 psi and operationally tested each trip. A str±ng of 5-1/2", 17#, L-80 tubing, packer, and gas lift mandrels will be run. Provisions for subsurface safet:y equipment will be run. A non-freezing fluid will be left in all uncemented annuli w±~.hin the permafrost interval, The packer will be set above the Sadleroehi~.. A separate sundry not:ice will be subm±tted when the well is perforated. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~~ TITLE Area Drilling Engineer DATE ~./t~/i~~ The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number I-lYES [~[AJ O •YES ~tNO ~]~YES UNOI 50- Ap~..~rova I date Permit number ~,~"~..~O ../~' ,~6"'~[1/,~'2 /'/ I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE .T~ m,~ 11_ / by order of the Commission Form 10-401 GRU6/B22 Submit in triplicate Rev. 7-1-80 ........;-- : .' -.- ......... _ ........... T--'-~--l~ =, ! J : ~!- .......... -7'"T ......... .-'?'T--' 7,,,,,,. .... ' ,'-T-t' .-.i---~- ~ -~ I-:--'---:--'-"[~,T," ;j ~,,"-.- ----~ ~-~D' '~"-'~' ....... , ' ! '-T .-'~-', ' i i'I ~-.. i--T'~ .r--'--i'-- . . · ~7-'T-~--T ~-i--T-. 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I ..... ~-r ....... ~--y-'~-~ .................... ~--"?~--~ .... , ----*--t---t-"~'-~*T ~-T-' ~~ ~...-~ ......... ~ ....... L-~.--~ ...................... ~- . =. __ ..... ~ ...... . .... ~__~ ...... ; ,, ~ .. .,_ :--r ........ ~ ~ , . : ~ ~ z'-~'--, ........... :'~"-'5~-"-~-z '~ ................. t-- t ....... ?7 'l-'? .... =-'-~--: ............ ='~ ...... = .... ~ ..... =-='='-"='-~ ............. .......... ~ ...... ==-+=--~-~-=-~=-.=-~-d--~--~ ......... =z_~_~_. ~ ~_~ ..... ~q-~-H-~-i ~ ................ ANNULAR PREVENTER BLIND RAMS PIPE RAMS SPOOL PIPE RAMS 13-5/8" BOP STACK DIAGRAM Accumulator Capacity T~st 1. Check and -fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC 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 a non-freezing liquid. 2. Check th at all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws, 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a.250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000.psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero.' Open bottom s~t of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with'~ Koomey pump. 15. Check operation of Degasser. 16. Record test Information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. SURFACE HOLE D iVERTER ARCO ALASKA I0" HYD. OPR. BALL VALVE WE ,L, L ' BORE ISLE DETAIL) I0' HYD. OPR. BALL,,VAL,V,E I ALL 90° TURNS ARE TEE CUSHION / ~LL QBORE I I RESERVE PIT AREA NOTE' SYSTEM SCHEMATIC INC. FLOWLINE DRILLING RISER "L 20" 2000 PSI WP ANNULAR PREVENTOR ' 0" HYDRAULIC OPERATED BALL VALVES (' f,,.~ DF{ ILL ING L-~.2~ "- '- ) ~o~to" DIVERTER L Valves on d±¥erter lines open automati- 20" cally when the annular ¢ONDUCTO~ "DETAIL" preventer is closed. P:PE 2026010203 CHECK LIST EOR NEW ~q~LL PERMITS ITLM APPROVE DATE ~~ 0- ~f'~- thru 8) (3) Admin (97t ~hru ~ ~.f'f''~ (4) Casg ~. ~.~.. (12 thru 20) (21 Vthru 24) (6) Add: ~.~.~. ~-~.-~f~_ Company, 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line ............ 4. Is well located proper distance from other wells ....... 5. Is sufficient ~ndedicated acreage' available in this pool 6. Is well to be deviated and is well bore plat included .. 7 Is operator the only affected party ..................... Can permit be approved before ten-day wait .............. 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Lease & Well No. 25. YES NO / Does operator have a bond in force .................. Is a conservation order needed .... i ! i 12 ilii iii ! iil Is conductor string prov±ded ........................................ Is enough cement used to circulate on conductor and surface ......... W±ll cement t£e in surface and intermediate or production strings ... W±ll cement cover all knOwn productive horizons ..................... W±ll surface cas±ng protect fresh water zones ....................... W±ll all cas±rig give adequate safety ±n collapse, tension and burst. Is .th±s well to be k±cked off from an exist±rig wellbore ............. Is old wellbore abandonment .procedure ±ncluded on 10-~03 . ........... Is adequate well bore separation proposed ........................... REMARKS Is a diverter system required · ~ _ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BoPE have sufficient pressure ,rating -Test to z~"~ psig .. ~ __ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. ~ t Geology: Engi, n~r ing: HWK ,, ~ LCS ~ .BEW WVA JKT rev: 01/i3/82 t INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE i Well Histo.ry 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. ~t C'..~~ ~'" ,/4, ' ; '~'~' . j" CURVE SPECIFICATIONS Company ARCO Alaska. !nc. Uell DS 6-17 : ECC~ 3012 Field Prudho e Bay County, State North Slooe, Alaska Date5-10-87 DELIVERY DATE 6-23-87 Curve Name (Abbrev.) S~andard Curve Name Logs Used Scale CCL ' ' Files' 1-3 i' ] CNAV Casing Collar Locator 't CN - Multi'Pace 't CN : Compensated Neutron " 60 - 0 SSN Short Space " - 50 550 LSN Long Space I " 0 - 200 GR Gamma Ray- " 0 - 100, 100 - 200 File 4 " 60 - 0 Average CN , ::"~P"E-"-N"A ,-, ,_--, ................ ~' .................................................................. ~"A":F-E ........ : H~I,, ~' '.-:-'--F-S--Y-5- ..... =~- ............ ..- ' ... .~...~. 4:~ ......... ~--~ ........................................................................................................................................... rE-RV~,_ N~cM,~. ,-P-~$S 't- zA-P'E-'~"' '~N'T'"'~-N~J.~.-~"I"O~'"'-'NUN"S"E-R-'~ ....... ,?"~ LR'E"V' 'I""O'U S'"'" 'T"'~'P"~"'"'N'~"M'~ ............. : ~MM-EH~'~-S"," .............................................................................................................................................................................................................. :"E'NG "T'"t~": .................. 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