The URL can be used to link to this page

Home My WebLink About181-104CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:10-426 form for 1A-pad S/I non-witnessed MIT-IA 7/8/25 Date:Wednesday, July 9, 2025 8:16:26 AM Attachments:image001.png MIT KRU 1A-PAD SI TESTS 07-08-25.xlsx Morning, Please see the attached 10-426 form from the S/I non-witnessed MIT-IA on 1A-05 that was performed on 7-8-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58$ 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811040 Type Inj N Tubing 370 740 780 780 Type Test P Packer TVD 5920 BBL Pump 5.5 IA 365 3300 3220 3200 Interval V Test psi 3000 BBL Return 5.3 OA 10 25 25 25 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1A Pad Non-witnessed Beck/Gschwind 07/08/25 Notes:MITIA every 2 years at maximum Anticipated Injection Pressure per AIO 2C.083 Notes: 1A-05 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2025-0708_MIT_KRU_1A-05 9 9 9 9 9 999 99 9 9 ¾ 9 -5HJJ AIO 2C.083 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1A-05 (PTD 181-104) Report of suspect IA pressure increase Update 11/7/24 Date:Sunday, November 10, 2024 4:07:26 PM Attachments:1A-05 90 Day TIO Plot & Schematic.pdf Diagnostic MITIA KRU 1A-05 8-9-24.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, November 7, 2024 1:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1A-05 (PTD 181-104) Report of suspect IA pressure increase Update 11/7/24 Chris, KRU 1A-05 (PTD 181-104) (AIO 2C.083) 90 day monitor comes to an end today 11/7/24. DHD passed tubing and IC pack off tests on 8/7/24. Passed a MITIA to 3300 psi on 8/9/24 (see attached 10-426) and bled the IA to 100 psi for the 90 day monitor. The IA pressure slowly increased and was again bled on 10/8/24. The IA pressure continues to slowly increase. It is believed that the increase of IA pressure being observed is due to the known waivered issue of T x IA on gas, caused by the 4168’ md column of gas in the tubing (confirmed with a tubing fluid level shot taken 10/8/24). CPAI plans to have the well secured with a tubing plug and have the well circ’ed out with fresh fluids. If CPAI decides to bring the well back on water injection, the well will be un-secured, an AOGCC witnessed MITIA will be scheduled and the well will be put on a 90 day monitor while on water injection. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, August 5, 2024 8:46 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1A-05 (PTD 181-104) Report of suspect IA pressure increase Chris, KRU 1A-05 (PTD 181-104) (AIO 2C.083) was reported by Operations to have suspect IA pressure increase while shut in. CPAI intends to perform initial diagnostics after which a 90 day shut in monitor will be started. If IA pressure continues to increase during the 90 day monitor further diagnostics will be scheduled at that time. The proper paperwork for continued injection or corrective action will be submitted upon completion of the monitor period. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 2750 2500 = 1250 N a 2000 N � 750 a` 500 250 0 0.04 -0.04 Pressure Summary for 1A-05 Rate Summary fml I m N .a .+ ry ry ry N a o o N n .+ n ry ry ry a o m N N N r ry ry N 0 m o 0 o ® M M m m m m m m m m m m m m m m m m m o m''c c o 0 0 0 o a aoo 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0i � .++� �� .. .. ryV N N N N N N N N N N N N N N N N N N N L'iV N N N N N N N N N N m o 0 o N o N o O o N N N o O O o N O N m o N N o N o N N O o NVN N N N N N N N N N N N N N N N N N N NVN N N N N N N ry N N Date e0 50 a d a E 30 F 20 — IA PRESSURE — OA PRESSURE — TUBING PRESSURE (PSI) — TEMPERATURE)DEGF) — DRY GAS)MSCFD) — MI GAS )MSCFD) — PRODUCED WATER (BPD) — SEAWATER )BPD) KUP INJ WELLNAME 1A-05 WELLBORE 1A-05 v �.VIIIJllJr11��Ip$ Alaska, Inc. �oiwnu,ps Well Attributes Max Ani MD FIeM Name1-1--AP WWI Wellh°re 6+slua Icl (°) MB(IIKBI K PAR KRIVER NIT 2 2J IN 9.50 2,100.00 TO MStu, RKB) ],6]5.0 Cmmment X26 Repm) Dale SSSV: TRDP AnnWvlbn Lest WO: End Due W911986 REPS. 04 31D1 Rk lg Reeee Due 914/1981 1AM,1/&2ax]9:11:SS AMI Last Tag Venl®I soM1emetlo(eoeug gnMratlon DepthsK13) 1 End Dab Milbore Did had By NArvLIER. x5.x- cOrvDVOT0R132.a60.0 SAFETY VLV: 1ANA GAS LIFT. xAsiD sUNEACE;N,bN.0ReG- GAS LIFT; 4.473.9 GAS LIFT. CASSE GAS LIFT; E31.7 GAS LIFT. ESIXE GAS LIFT; ED ED GAS LIFT. e.3M.5 PRODUCTION; W.1-6M3- GAS LIFT, E6]3.fi sga; 6]tue PACKEN.E] o INIEGTIORLSM..o LEAK-C-nAND;668a0 IPERF GCG. e,MO. LEAK-D.B,66AtD IPERFl e.esz.oe,asao- IPERFl SSEG.B-6..0- NIPPLE. 6.910 BPI SURVE,8 RMS O SEAL A-SY 6.:9 PACKER. ERE3 NIPPLE. zom.1 6OSO.o+2.] - - PemL011w.015.D cemem'. zov.D nKe IPERF],01C.o-10s8..0� IPERFl].ofis.o70EG.o- IGR.7,1W.0 LINER',%284.x-7670.0 Last Tag: ELM ],0]6.0 2r2012019 to-05 luaquap Last Rev Reason AnnWatlon End Date WNlho,e Mctl By Reso v Reason: Pulled CEV 1I6I2022 1A-05 zemubaej m Casing Strings Cuing Deac,lptlm CONDUCTOR GD(IV 20 ID (In) 1894 Tap(M(B) 32.6 and Deptb(dual 80.0 Set Dept D)-. 80D WtlLen RL. Gntle 94.00 H40 Top TM1,eatl WELDED Cuing Descnpticn SURFACE OD (in) 13318 ID (in) 1241 Top (flK8) 31.6 Suit Depth lflKe) 3,0959 set Deem (rvD)... 2,632.1 vmlm p... wzee 72.00 L40 Tap Th.W ETC C:i,q Ducripam PRODUCTION GO (in) 95I8 ID (in) 8.68 Top June) 29.1 Set DepthlflKB) 6,633.4 Set Depm(NDL.. 5,810.1 WBLen(I... wade 47.00 LSO Top Thred! ETC Cuing Ducrinew LINER OD (in) ] IS (in) 6.28 Top(IIKB) 6,284.2 Suit Depth RRUEN 7,670.0 sR Depm RVDl.. 6,845.3 RiMann l... Sued, 26.00 K55 Top Thread BUTT Liner Details Top(IIKB) l'RVDLftKB) TOPI.IP) Men Des Com namina ID (In) 6284.2 5,462.1 5.81 SLEEVE BAKER SETTING SLEEVE 6.276 6, NT4 S468.2 1 5.82 1 NIPPLE BAKER SEAL NIPPLE 6.250 6,293./ 5,411.5 1 5.60 HANGER I BAKER HYDRAULIC HANGER 6.276 Tubing Strings Tubing 13- line- Strang NIS-11D (In) Top (IIKB) set Deph ln.. set Depm (ND) (... DR (Rub Gred, Top Cohne lion TUBING 3.5"x28]5" 3112 299 262 ],013.5 6,189,7 9,20 J-55 ETC Completion Details Top IflKB) Top(ND) RKER ToplO N OD peened! ID N-un" (in) (In) Maine model Gun 26.2 26.2 0.26 HANGER 3.500 8.000 FMC HANGER 1,807.1 1,]35.] N.41 SAFETYVLV 2.813 5.937 CAMCO TRDP-1A SAFETY VALVE 2,851.2 2,460.4 45.87 GAS LIFT 2.875 5.312 CAMCO KBUG 4,4]3.9 3,738.6 23.63 GAS LIFT 2.875 5.312 CAMCO KBUG 51030.5 4,250.8 22.35 GAS LIFT 2.875 5.312 CAMCO KBUG 5,342.7 4,543.1 18.57 GAS LIFT 2.875 5.312 CAMCO KBUG S684.8 4,871.4 14.15 GAS LIFT 2.875 5.312 CAMCO KBUG 61026.0 5,205.9 8.92 GAS LIFT 2.875 5.312 CAMCO KBUG 6,328.4 OSM.0 5.47 GAS LIFT 2.075 5.312 CAMCO KBUG 6,6]3.6 5,850.3 3.32 GAS LIFT 2.906 5.937 OTIS 3.5x 1.5 6,716.8 5,893.4 3.17 SBR 2.813 4.000 BAKER SEE 6.743.0 51919.6 3.03 PACKER 3.000 6.156 BAKER PH RETIEVABIE PACKER 6,788.4 51964.9 2.81 BLAST JT 2.991 3.500 6,974.0 6,150.2 3.00 NIPPLE 2.750 4.484 AVA PORTED NIPPLE 6,984.9 6,161.1 3.00 SEAL ABBY 2.441 4.000 BAKER SEAL ASSEMBLY 6,992.3 6,168.5 3.00 PACKER 3.000 6.156 BAKER FB-1 PERMANENT PACKER "Nu=VER 3.5'Y.875"' 7,007.1 61183.3 3.00 NIPPIE 2.250 3.668 CAMCO D NIPPLE NO GO 7,0127 6,188.8 I 3.00 SOS 2.441 3750 CAMCO SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tap Tap ITVD) Topincl RIKB) BIBS) r) I Du Coin Run D. ID (in) SN 6,13M.0 6,030.4 2.89 LEAK -CSAND CSAND LEAK AT 6854. 1012612002 6.883.0 6,059.4 2.96 LEAK -CSAND CSAND LEAK AT 6883'. 10Q612002 6,976.0 6,152.2 3.00 BPISLEEVE BPI ISO SLEEVE 4l2]I2006 2.320 7,186.0 6,361.9 3.00 FISH 4" Vann Gun 322.86'Iong W411981 0.000 Mandrel Inserts at al °^ N Tap ItIKB) TopIEI NIKS) Intl Top l°) MVMe Model Mile) Vabe Sery Type LeShTNpi Po(in) Type (in) TRuRun IWI) Run Ovh Cam 1 2,351.2 2,460.4 45.87 1 GAS LIFT DMV BK 0.000 0.0 1011/1991 2 4,473.9 3,738.6 23.63 1 GAS LIFT DMV BK ILMID 0.0 1Z1111991 3 6030.5 g250.8 22.35 1 GAS LIFT DMV BK 0.000 0.0 1Z11/1991 4 5,342.7 4,543.1 18.57 1 GAS LIFT DMV BK 0.000 0.0 12/11/1991 5 5,684.9 4,871.4 14.15 1 GAS LIFT DMV BK 0.000 0.0 12/11/1991 6A6,673.6 5,205.9 8.92 1 GAS LIFT DMV BK 0.000 0.0 1Z1111991 ] 5,506.0 5.4] 1 GAS LIFT DMV BK 0.000 0.0 1011/1991 8 5,850.3 3.32 117 GAS LIFTDMVRO00.0 3110/199] 9 5,958.5 2.84 1 INJ DMV BK Owo 0.0 101 612021 KUP INJ WELLNAME 1A-05 WELLBORE 1A-06 ConocoPhillips Alaska, Inc. 1AM. VMOEBB e: 11: 57 AM Perforations& Slots Veni®i senem,ee teM.e Shoe Ren nervcEN xs.x- .I( BIm929.0 ro IKG) (RKBI aimlrvRl (RKB) LA4N Zone 9aia Iehmsni ) Typa tam 8,822.0 8,929.0 5,998.4 6,105.3 91311981 4.0 IPERF 120 Reg q4" PVannGuns UNITE2,G-1, UNIT B, tA-OS 8,952.0 8,956.0 fi,128.3 6,132.3 UNIT B, IA-05 901981 4.0 IPERF 120 Reg. Ph, Vann Guns 6,962.0 6,966.0 6,138.3 6,144.2 UNIT B, IA-05 91311981 4.0 IPERF 120 Deg. Ph, 4"Vann Guns ],013.0 7,015.0 6.189.2 6,191.2 UNIT B, IA-05 6ISI1986 4.0 Squeezed conqucTOlr, 3xs eq.B 7,052.0 7,056.0 6,228.1 6,232.1 A5, 1A-05 9I3I1981 4.01PERF 120 deg. Ph, 4' Vann Guns SAFETY vcv'. 1.am.1 7,085.0 7,092,0 6,241.1 6,2681 A4,1A-05 901981 4.0 IPERF 120 deg. Ph, 4"Vann Guns GAS uFr. 2a51.2 Cement Squeezes 1 Top INBI Rim I.) Pump aGn TOPIRKB) Bim IRKB) IRKB) IRKB) Ge[ Be. Oaie Auij.0 1 Avio.uj a Ev.zI 8,1912 Cement SUNFACE;9163.085G- Notes: General & Safety Bna GNe AnnWNlon 1/212021 NOTE Heavy Ena6c weight svAngs from 6000'-6974'RKB ]29I1998 NOTE Unable to Establish lnj Rate; Very Slow LEAK GAS LIFT; 0.47ae GAS LIFT; SOME GAS LIFT; 5.31x.7 GAS LIFT; S.SG.B GAS LIFT; SOME GAS LIFT; 6.35.5 PRODUCTION. xa.19,S3a.a- GAS LIFT; S.S19.8 See 6,]1G0 PACKERE,74l0 INJECTION; 6Me- LEAK- CS psa5ao IPERF', GC2. &a21 LEAK-CSANR;60At0 I PERF', 6.95x.MEREO0 IPERF', 9.BSxDa,9530� NIPPLE; 6.970.0 U BPI SJEEVE, GGG6S O SEAL ABBY; 6.980.9 PACKEN. SZ.3 NIPPLE. 7.00].1 SOS; 7.012.7 - - Peit,]0136].015.0 CemenC ].019A RI® WENT 7,052.0-]OSB.LO� INERT 7,M.D7B 0- FISN;],1EE0 UNION',%20f.?7mtt0 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1811040 Type Inj N Tubing 2544 2558 2555 2554 Type Test P Packer TVD 5920 BBL Pump 8.4 IA 49 3300 3245 3225 Interval O Test psi 1500 BBL Return OA 14 19 19 19 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1A Pad Beck / Borg 08/09/24 Notes:Diagnostic MITIA to 3300 psi Notes: 1A-05 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)Diagnostic MITIA KRU 1A-05 8-9-24 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1A-05 (PTD 181-104) Report of suspect IA pressure increase Date:Monday, August 5, 2024 8:51:19 AM Attachments:1A-05 90 day TIO & schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, August 5, 2024 8:46 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1A-05 (PTD 181-104) Report of suspect IA pressure increase Chris, KRU 1A-05 (PTD 181-104) (AIO 2C.083) was reported by Operations to have suspect IA pressure increase while shut in. CPAI intends to perform initial diagnostics after which a 90 day shut in monitor will be started. If IA pressure continues to increase during the 90 day monitor further diagnostics will be scheduled at that time. The proper paperwork for continued injection or corrective action will be submitted upon completion of the monitor period. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,075.0 2/20/2019 1A-05 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled CSV 1/6/2022 1A-05 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.94 Top (ftKB) 32.6 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 94.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 31.6 Set Depth (ftKB) 3,095.9 Set Depth (TVD) … 2,632.1 Wt/Len (l… 72.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 9 5/8 ID (in) 8.68 Top (ftKB) 29.1 Set Depth (ftKB) 6,633.4 Set Depth (TVD) … 5,810.1 Wt/Len (l… 47.00 Grade L-80 Top Thread BTC Casing Description LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 6,284.2 Set Depth (ftKB) 7,670.0 Set Depth (TVD) … 6,845.3 Wt/Len (l… 26.00 Grade K-55 Top Thread BUTT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,284.2 5,462.1 5.87 SLEEVE BAKER SETTING SLEEVE 6.276 6,290.4 5,468.2 5.82 NIPPLE BAKER SEAL NIPPLE 6.250 6,293.7 5,471.5 5.80 HANGER BAKER HYDRAULIC HANGER 6.276 Tubing Strings Tubing Description TUBING 3.5"x2.875" String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 26.2 Set Depth (ft… 7,013.5 Set Depth (TVD) (… 6,189.7 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 26.2 26.2 0.26 HANGER 3.500 8.000 FMC HANGER 1,807.1 1,735.7 32.41 SAFETY VLV 2.813 5.937 CAMCO TRDP-1A SAFETY VALVE 2,851.2 2,460.4 45.87 GAS LIFT 2.875 5.312 CAMCO KBUG 4,473.9 3,738.6 23.63 GAS LIFT 2.875 5.312 CAMCO KBUG 5,030.5 4,250.8 22.35 GAS LIFT 2.875 5.312 CAMCO KBUG 5,342.7 4,543.1 18.57 GAS LIFT 2.875 5.312 CAMCO KBUG 5,684.8 4,871.4 14.15 GAS LIFT 2.875 5.312 CAMCO KBUG 6,026.0 5,205.9 8.92 GAS LIFT 2.875 5.312 CAMCO KBUG 6,328.4 5,506.0 5.47 GAS LIFT 2.875 5.312 CAMCO KBUG 6,673.6 5,850.3 3.32 GAS LIFT 2.906 5.937 OTIS 3.5 x 1.5 6,716.8 5,893.4 3.17 SBR 2.813 4.000 BAKER SBR 6,743.0 5,919.6 3.03 PACKER 3.000 6.156 BAKER FH RETIEVABLE PACKER 6,788.4 5,964.9 2.81 BLAST JT 2.991 3.500 6,974.0 6,150.2 3.00 NIPPLE 2.750 4.484 AVA PORTED NIPPLE 6,984.9 6,161.1 3.00 SEAL ASSY 2.441 4.000 BAKER SEAL ASSEMBLY 6,992.3 6,168.5 3.00 PACKER 3.000 6.156 BAKER FB-1 PERMANENT PACKER ***w/XOVER 3.5"x2.875*** 7,007.1 6,183.3 3.00 NIPPLE 2.250 3.668 CAMCO D NIPPLE NO GO 7,012.7 6,188.9 3.00 SOS 2.441 3.750 CAMCO SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,854.0 6,030.4 2.89 LEAK - C-SAND C-SAND LEAK AT 6854'. 10/26/2002 6,883.0 6,059.4 2.96 LEAK - C-SAND C-SAND LEAK AT 6883'. 10/26/2002 6,976.0 6,152.2 3.00 BPI SLEEVE BPI ISO SLEEVE 4/27/2006 2.320 7,186.0 6,361.9 3.00 FISH 4" Vann Gun 322.86' long 9/4/1981 0.000 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,851.2 2,460.4 45.87 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 2 4,473.9 3,738.6 23.63 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 3 5,030.5 4,250.8 22.35 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 4 5,342.7 4,543.1 18.57 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 5 5,684.8 4,871.4 14.15 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 6 6,026.0 5,205.9 8.92 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 7 6,328.4 5,506.0 5.47 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 8 6,673.6 5,850.3 3.32 1 1/2 GAS LIFT DMY RO-5 0.000 0.0 3/10/1997 9 6,782.0 5,958.5 2.84 1 INJ DMY BK 0.000 0.0 12/16/2021 1A-05, 1/6/2022 8:11:56 AM Vertical schematic (actual) LINER; 6,284.2-7,670.0 FISH; 7,186.0 IPERF; 7,065.0-7,092.0 IPERF; 7,052.0-7,056.0 Cement; 7,013.0 ftKB Perf; 7,013.0-7,015.0 SOS; 7,012.7 NIPPLE; 7,007.1 PACKER; 6,992.3 SEAL ASSY; 6,984.9 BPI SLEEVE; 6,976.0 NIPPLE; 6,974.0 IPERF; 6,962.0-6,968.0 IPERF; 6,952.0-6,956.0 LEAK - C-SAND; 6,883.0 IPERF; 6,822.0-6,929.0 LEAK - C-SAND; 6,854.0 INJECTION; 6,782.0 PACKER; 6,743.0 SBR; 6,716.8 GAS LIFT; 6,673.6 PRODUCTION; 29.1-6,633.3 GAS LIFT; 6,328.5 GAS LIFT; 6,026.0 GAS LIFT; 5,684.8 GAS LIFT; 5,342.7 GAS LIFT; 5,030.5 GAS LIFT; 4,473.9 SURFACE; 31.6-3,095.9 GAS LIFT; 2,851.2 SAFETY VLV; 1,807.1 CONDUCTOR; 32.6-80.0 HANGER; 26.2 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 9/4/1981 1A-05 ... TD Act Btm (ftKB) 7,675.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292062700 Wellbore Status INJ Max Angle & MD Incl (°) 49.50 MD (ftKB) 2,100.00 WELLNAME WELLBORE1A-05 Annotation Last WO: End Date 6/9/1986 H2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,822.0 6,929.0 5,998.4 6,105.3 C-3, C-2, C-1, UNIT B, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 6,952.0 6,956.0 6,128.3 6,132.3 UNIT B, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 6,962.0 6,968.0 6,138.3 6,144.2 UNIT B, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 7,013.0 7,015.0 6,189.2 6,191.2 UNIT B, 1A-05 6/5/1986 4.0 Squeezed 7,052.0 7,056.0 6,228.1 6,232.1 A-5, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 7,065.0 7,092.0 6,241.1 6,268.1 A-4, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,013.0 7,015.0 6,189.2 6,191.2 Cement Notes: General & Safety End Date Annotation 5/25/2021 NOTE: Heavy Erratic weight swings from 6000'-6974' RKB 3/29/1998 NOTE: Unable to Establish Inj Rate; Very Slow LEAK 1A-05, 1/6/2022 8:11:57 AM Vertical schematic (actual) LINER; 6,284.2-7,670.0 FISH; 7,186.0 IPERF; 7,065.0-7,092.0 IPERF; 7,052.0-7,056.0 Cement; 7,013.0 ftKB Perf; 7,013.0-7,015.0 SOS; 7,012.7 NIPPLE; 7,007.1 PACKER; 6,992.3 SEAL ASSY; 6,984.9 BPI SLEEVE; 6,976.0 NIPPLE; 6,974.0 IPERF; 6,962.0-6,968.0 IPERF; 6,952.0-6,956.0 LEAK - C-SAND; 6,883.0 IPERF; 6,822.0-6,929.0 LEAK - C-SAND; 6,854.0 INJECTION; 6,782.0 PACKER; 6,743.0 SBR; 6,716.8 GAS LIFT; 6,673.6 PRODUCTION; 29.1-6,633.3 GAS LIFT; 6,328.5 GAS LIFT; 6,026.0 GAS LIFT; 5,684.8 GAS LIFT; 5,342.7 GAS LIFT; 5,030.5 GAS LIFT; 4,473.9 SURFACE; 31.6-3,095.9 GAS LIFT; 2,851.2 SAFETY VLV; 1,807.1 CONDUCTOR; 32.6-80.0 HANGER; 26.2 KUP INJ 1A-05 ... WELLNAME WELLBORE1A-05 1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Friday, July 14, 2023 12:08 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3 Subject:CPAI 10-426 form for Non-witnessed shut in tests on 1A-02 and 05 on 7/13/23 Attachments:MIT KRU 1A-02 & 05 SI TESTS 07-13-23.xlsx Please see the attached 10‐426 form for Non‐witnessed shut in MIT‐IA’s that were performed at 1A pad on 7/13/23. Please let me know if you have any questions or concerns. Thank you, Shelby Sumrall / Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659‐7022 Cell phone: (907) 943‐0167 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 1A-05PTD 1811040 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1810710 Type Inj N Tubing 2817 2820 2820 2820 Type Test P Packer TVD 5835 BBL Pump 1.2 IA 1180 1810 1770 1760 Interval 4 Test psi 1500 BBL Return 1.2 OA 506 510 510 510 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1811040 Type Inj N Tubing 2840 2855 2850 2850 Type Test P Packer TVD 5920 BBL Pump 5.4 IA 415 3500 3440 3430 Interval V Test psi 3000 BBL Return 5.4 OA 36 40 40 40 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1A Pad Hembree / Hills 07/13/23 Notes: Notes: 1A-02 1A-05 Notes:MITIA to maximum anticipated injection pressure per AIO 2C.083 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2023-0713_MIT_KRU_1A-05        J. Regg; 10/12/2023 Originated: Delivered to:14-Jan-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-05 50-029-20627-00 907568283 Kuparuk River Multi Finger Caliper Field & Processed 13-Dec-21 0 12 1A-19 50-029-22111-00 n/a Kuparuk River Plug Setting Record Field- Final 9-Dec-21 0 13 1E-31 50-029-22791-00 907551730 Kuparuk River Leak Detect Log Field- Final 7-Dec-21 0 14 1E-31 50-029-22791-00 907551730 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-21 0 15 1L-19 50-029-22049-00 907423896 Kuparuk River Multi Finger Caliper Field & Processed 27-Dec-21 0 16 1L-19A 50-029-22049-01 n/a Kuparuk River Multi Finger Caliper Field & Processed 10-Jan-22 0 17 2W-16 50-029-21255-00 907594924 Kuparuk River Plug Setting Record Field- Final 29-Dec-21 0 18 3B-16 50-029-21289-00 907292763 Kuparuk River Leak Detect Log Field- Final 28-Nov-21 0 19 3B-16 50-029-21289-00 907292763 Kuparuk River Multi Finger Caliper Field & Processed 3-Dec-21 0 110 3F-04 50-029-21449-00 907551131 Kuparuk River Multi Finger Caliper Field & Processed 4-Dec-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:01/14/2022Wd͗ϭϴϭϭϬϰϬͲ^Ğƚ͗ϯϲϮϮϵBy Abby Bell at 12:45 pm, Jan 14, 2022 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϭϭϬϰϬͲ^Ğƚ͗ϯϲϭϲϰJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 MEMORANDUM State of Alaska Permit Number: 181-104-0 Inspection Date: 7/3/2021 Alaska Oil and Gas Conservation Commission TO:Jim Regg l DATE: Wednesday, July 14, 2021 eek �l�(olZ/j SUBJECT: Mechanical Integrity Tests P.I. Supervisor Packer Depth Pretest Initial ConocoPhillips Alaska, Inc. Well 1A-05 - Type Inj IA -05 FROM: Austin McLeod KUPARUK RIV UNIT 1A-05 Petroleum Inspector 3000 a 9 IA 600 -- OA 1a5 - Src: Inspector 3220 las - Reviewed By: P.I. Supry J��-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -05 API Well Number 50-029-20627-00-00 Inspector Name: Austin McLeod Permit Number: 181-104-0 Inspection Date: 7/3/2021 Insp Num' mitSAM210704163024 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-05 - Type Inj w ' TVD 5922 --Tubing 1610 1610 1610 — 1610" PTD 1811040 - Type Test BBL Pumped: 52 'BBL SPT Test psi1 Returned 3000 a 9 IA 600 -- OA 1a5 - 3290. las 3220 las - 3200 las Interval REQVAR p/F P Notes: MITIA to MAIP. AIO 2C.083. Wednesday, July 14, 2021 Page I of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ictoria Loepp By Samantha Carlisle at 3:53 pm, May 18, 2021 321-248 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.05.18 15:31:01 -08'00' VTL 5/19/21 DSR-5/18/21 X X 10-404 DLB 05/18/2021 dts 5/19/2021 JLC 5/19/2021 Jeremy Price Digitally signed by Jeremy Price Date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ast Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,075.0 2/20/2019 1A-05 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: REVISE PATCH DRAWING - Added LEAKS 7/7/2020 1A-05 pproven Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.94 Top (ftKB) 32.6 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 94.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.41 Top (ftKB) 31.6 Set Depth (ftKB) 3,095.9 Set Depth (TVD) … 2,632.1 Wt/Len (l… 72.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 9 5/8 ID (in) 8.68 Top (ftKB) 29.1 Set Depth (ftKB) 6,633.4 Set Depth (TVD) … 5,810.1 Wt/Len (l… 47.00 Grade L-80 Top Thread BTC Casing Description LINER OD (in) 7 ID (in) 6.28 Top (ftKB) 6,284.2 Set Depth (ftKB) 7,670.0 Set Depth (TVD) … 6,845.3 Wt/Len (l… 26.00 Grade K-55 Top Thread BUTT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,284.2 5,462.1 5.87 SLEEVE BAKER SETTING SLEEVE 6.276 6,290.4 5,468.2 5.82 NIPPLE BAKER SEAL NIPPLE 6.250 6,293.7 5,471.5 5.80 HANGER BAKER HYDRAULIC HANGER 6.276 Tubing Strings Tubing Description TUBING 3.5"x2.875" String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 26.2 Set Depth (ft… 7,013.5 Set Depth (TVD) (… 6,189.7 Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.2 26.2 0.26 HANGER FMC HANGER 3.500 1,807.1 1,735.7 32.41 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,716.8 5,893.4 3.17 SBR BAKER SBR 2.813 6,743.0 5,919.6 3.03 PACKER BAKER FH RETIEVABLE PACKER 3.000 6,788.4 5,964.9 2.81 BLAST JT 2.991 6,974.0 6,150.2 3.00 NIPPLE AVA PORTED NIPPLE 2.750 6,984.9 6,161.1 3.00 SEAL ASSY BAKER SEAL ASSEMBLY 2.441 6,992.3 6,168.5 3.00 PACKER BAKER FB-1 PERMANENT PACKER ***w/XOVER 3.5"x2.875*** 3.000 7,007.1 6,183.3 3.00 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,012.7 6,188.9 3.00 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,840.0 6,016.4 2.85 PATCH - UPR PKR (ME) BAKER 35 "KB" UPR STRADDLE PACKER ASSY, 2.78" OD, ASSY OAL= 32.39', 15000# SHEAR RELEASE PACKER, 7360# SHEAR RELEASE SNAP LATCH, MIN ID AT SNAP LATCH = 1.63" 10/25/2008 1.630 6,844.0 6,020.4 2.86 UPR SPACER PIPE 2-3/8" UPR SPACER PIPE, ANCHOR LATCH 10/25/2008 1.920 6,854.0 6,030.4 2.89 LEAK - C-SAND C-SAND LEAK AT 6854'. 10/26/2002 6,861.0 6,037.4 2.90 LWR SPACER PIPE 2-3/8" LWR SPACER PIPE, PBR SEAL RECEPTACLE 10/23/2008 1.920 6,883.0 6,059.4 2.96 LEAK - C-SAND C-SAND LEAK AT 6883'. 10/26/2002 6,898.0 6,074.3 3.00 PATCH - LWR PKR (ME) BAKER 35 KB LWR PACKER WITH 23' OF SPACER PIPE, TOOLSTRING LEN= 31.8'. MAX OD= 2.78"; CENTER ELMT @ 6898'. 10/23/2008 1.830 6,976.0 6,152.2 3.00 BPI SLEEVE BPI ISO SLEEVE 4/27/2006 2.320 7,186.0 6,361.9 3.00 FISH 4" Vann Gun 322.86' long 9/4/1981 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,822.0 6,929.0 5,998.4 6,105.3 C-3, C-2, C-1, UNIT B, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 6,952.0 6,956.0 6,128.3 6,132.3 UNIT B, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 6,962.0 6,968.0 6,138.3 6,144.2 UNIT B, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 7,013.0 7,015.0 6,189.2 6,191.2 UNIT B, 1A-05 6/5/1986 4.0 Squeezed 7,052.0 7,056.0 6,228.1 6,232.1 A-5, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns 7,065.0 7,092.0 6,241.1 6,268.1 A-4, 1A-05 9/3/1981 4.0 IPERF 120 deg. Ph, 4" Vann Guns Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,013.0 7,015.0 6,189.2 6,191.2 Cement Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,851.2 2,460.4 45.87 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 2 4,473.9 3,738.6 23.63 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 3 5,030.5 4,250.8 22.35 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 4 5,342.7 4,543.1 18.57 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 1A-05, 5/18/2021 2:11:26 PM Vertical schematic (actual) LINER; 6,284.2-7,670.0 FISH; 7,186.0 IPERF; 7,065.0-7,092.0 IPERF; 7,052.0-7,056.0 Cement; 7,013.0 ftKB Perf; 7,013.0-7,015.0 PACKER; 6,992.3 BPI SLEEVE; 6,976.0 IPERF; 6,962.0-6,968.0 IPERF; 6,952.0-6,956.0 PATCH - LWR PKR (ME); 6,898.0 LEAK - C-SAND; 6,883.0 LWR SPACER PIPE; 6,861.0 IPERF; 6,822.0-6,929.0 LEAK - C-SAND; 6,854.0 UPR SPACER PIPE; 6,844.0 PATCH - UPR PKR (ME); 6,840.0 INJECTION; 6,782.0 PACKER; 6,743.0 GAS LIFT; 6,673.6 PRODUCTION; 29.1-6,633.3 GAS LIFT; 6,328.5 GAS LIFT; 6,026.0 GAS LIFT; 5,684.8 GAS LIFT; 5,342.7 GAS LIFT; 5,030.5 GAS LIFT; 4,473.9 SURFACE; 31.6-3,095.9 GAS LIFT; 2,851.2 SAFETY VLV; 1,807.1 CONDUCTOR; 32.6-80.0 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 9/4/1981 1A-05 ... TD Act Btm (ftKB) 7,675.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292062700 Wellbore Status INJ Max Angle & MD Incl (°) 49.50 MD (ftKB) 2,100.00 WELLNAME WELLBORE1A-05 Annotation Last WO: End Date 6/9/1986 H2S (ppm) DateComment SSSV: TRDP Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 5 5,684.8 4,871.4 14.15 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 6 6,026.0 5,205.9 8.92 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 7 6,328.4 5,506.0 5.47 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 8 6,673.6 5,850.3 3.32 OTIS 3.5 x 1.5 1 1/2 GAS LIFT DMY RO-5 0.000 0.0 3/10/1997 9 6,782.0 5,958.5 2.84 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 12/7/1998 Notes: General & Safety End Date Annotation 3/29/1998 NOTE: Unable to Establish Inj Rate; Very Slow LEAK 1A-05, 5/18/2021 2:11:27 PM Vertical schematic (actual) LINER; 6,284.2-7,670.0 FISH; 7,186.0 IPERF; 7,065.0-7,092.0 IPERF; 7,052.0-7,056.0 Cement; 7,013.0 ftKB Perf; 7,013.0-7,015.0 PACKER; 6,992.3 BPI SLEEVE; 6,976.0 IPERF; 6,962.0-6,968.0 IPERF; 6,952.0-6,956.0 PATCH - LWR PKR (ME); 6,898.0 LEAK - C-SAND; 6,883.0 LWR SPACER PIPE; 6,861.0 IPERF; 6,822.0-6,929.0 LEAK - C-SAND; 6,854.0 UPR SPACER PIPE; 6,844.0 PATCH - UPR PKR (ME); 6,840.0 INJECTION; 6,782.0 PACKER; 6,743.0 GAS LIFT; 6,673.6 PRODUCTION; 29.1-6,633.3 GAS LIFT; 6,328.5 GAS LIFT; 6,026.0 GAS LIFT; 5,684.8 GAS LIFT; 5,342.7 GAS LIFT; 5,030.5 GAS LIFT; 4,473.9 SURFACE; 31.6-3,095.9 GAS LIFT; 2,851.2 SAFETY VLV; 1,807.1 CONDUCTOR; 32.6-80.0 KUP INJ 1A-05 ... WELLNAME WELLBORE1A-05 1 Weingarth, Stefan From:Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent:Tuesday, May 18, 2021 2:14 PM To:Weingarth, Stefan Subject:[EXTERNAL]Re: 1A-05 Swap Tubing Patch CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Stefan, Verbal approval is granted to proceed with previous approved scope. Please submit a 10-403 for the work by the end of the day. Thanx, Victoria Sent from my iPhone On May 18, 2021, at 1:46 PM, Weingarth, Stefan <Stefan.G.Weingarth@conocophillips.com> wrote: Victoria, Thanks for taking the call today. As discussed, a 10-403 was previously approved to replace 1A-05’s tubing patch to allow for larger clearance for logging injection splits. CPAI plans to progress the proposed scope. Scope remains the same as previously approved (program attached). The team noticed 1A-05’s previously approved sundry expired 12/17/20. Do we have verbal approval to progress operations? We will be submitting an updated 10-403 for the work shortly. ǡ Ȃͳ͵Ͳ͸ ǣͻͲ͹Ǧʹ͸ͷǦ͸Ͳ͵ͺȁǣͻͲ͹ǦͶͶͶǦ͹ͷ͸ͻ <1A-05 C Sd Tbg Patch Procedure_1-6-2020_jwp.xlsm> Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, January 28, 2021 9:44 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: RE: KRU 1A-05 (PTD 181-104) Update and intent to AA Attachments: 1A-05 90 day TIO trend 1.28.21.pdf Chris, The KRU 1A-05 (PTD 181-104) gas injection monitor extension period did continue to exhibit unexplained IA pressure increase. CPAI intends to submit an AA application for continued water injection only with known TxIA communication on gas as the well has already passed a diagnostic MITIA and monitor period while on water injection. The well will be allowed to remain on water injection while the AA application is being generated and processed. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Compliance Specialist CPF1 & 2 Sent: Thursday, January 07, 20218:52 AM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 1A-05 (PTD 181-104) Update 1/7/2021 Chris, Subsequent the last correspondence KRU 1A-05 (PTD 181-104) was circ'd out and passed a 30 day monitor period on water injection with no indications of TxIA communication. The well was WAG'd to gas on December 10, 2020 and the IA has displayed some pressure increase, but injection rate and temperature have similarly increased, as such CPAI plans to extend the monitor period on gas an additional 30 days for further review. Follow up communication will be made upon the conclusion of the monitor period. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Thursday, January 7, 2021 8:52 AM To: Wallace, Chris D (CED) Cc: Sender, R. Tyler Subject: RE: KRU 1A-05 (PTD 181-104) Update 1/7/2021 Attachments: 1A-05 90 day TIO trend 1.7.2021.pdf Chris, Subsequent the last correspondence KRU 1A-05 (PTD 181-104) was circ'd out and passed a 30 day monitor period on water injection with no indications of TxIA communication. The well was WAG'd to gas on December 10, 2020 and the IA has displayed some pressure increase, but injection rate and temperature have similarly increased, as such CPAI plans to extend the monitor period on gas an additional 30 days for further review. Follow up communication will be made upon the conclusion of the monitor period. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, September 22, 2020 2:36 PM To: Wallace, Chris D (CED) <chris.wallace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617 @conocoph i I I ips.com> Subject: RE: KRU 1A-05 (PTD 181-104) Update: Report of suspect IA pressure increase Chris, There has been a change in plan with KRU 1A-05 (PTD# 181-104). CPAI now has a desire to put the well onto water injection as soon as the tubing and IA have been circulated with clean fluids. The plan at this point in time is to complete the circ out, put the well onto water injection and monitor for 30 days to verify TxIA integrity on water injection. If the well shows indications of TxIA while on water injection the well will be shut in and secured for diagnostics. If the well proves TxIA integrity on water injection, the well will remain on normal injection status until WAG'd to gas injection in which another 30 day monitor period will begin to investigate for TxIA communication while on gas injection. Depending on the results of 30 day gas injection the proper paperwork for continued injection or repair will be submitted. Let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, September 22, 2020 2:36 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: KRU 1A-05 (PTD 181-104) Update: Report of suspect IA pressure increase Chris, There has been a change in plan with KRU 1A-05 (PTD# 181-104). CPAI now has a desire to put the well onto water injection as soon as the tubing and IA have been circulated with clean fluids. The plan at this point in time is to complete the circ out, put the well onto water injection and monitor for 30 days to verify TxIA integrity on water injection. If the well shows indications of TxIA while on water injection the well will be shut in and secured for diagnostics. If the well proves TxIA integrity on water injection, the well will remain on normal injection status until WAG'd to gas injection in which another 30 day monitor period will begin to investigate for TxIA communication while on gas injection. Depending on the results of 30 day gas injection the proper paperwork for continued injection or repair will be submitted. Let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM CorwcpPh Ips Fro • Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: S111111,ay, September 20, 2020 4:03 PM To: Wallac , hris D (CED) <chris.waIlace @alaska.gov> Cc: CPA Wells Sbpt .<,�n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophi s.com> Subject: KRU 1A-05 (PTI1-104) Update: Report of suspect IA pressure increase Chris, 11-1, KRU 1A-05 (PTD# 181-104) update to igfform you of the current status of the IA diagnostics. DHD performed a passing diagnostic MIT -IA to 3300 psi and an IA DDI, w ich has shown continual IA pressure build up. It is CPAI's intention to secure the well and perform additional diagnostic see if the leak appears to be a gas only leak or if the TxIA communication occurs with fluid present in the tubing st i g. Depending on the results of the additional diagnostics, the proper reporting for continued injection or corrective action ' be submitted at that time. Attached is a copy of the current 90 day TIO plot. Please let me know if you have any questi res or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM +CanocaF [Ilps Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, September 20, 2020 4:03 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 1A-05 (PTD 181-104) Update: Report of suspect IA pressure increase Attachments: 1A-05 90 Day TIO.pdf Chris, KRU 1A-05 (PTD# 181-104) update to inform you of the current status of the IA diagnostics . DHD performed a passing diagnostic MIT -IA to 3300 psi and an IA DDT, which has shown continual IA pressure build up. It is CPAI's intention to secure the well and perform additional diagnostics to see if the leak appears to be a gas only leak or if the TxIA communication occurs with fluid present in the tubing string. Depending on the results of the additional diagnostics, the proper reporting for continued injection or corrective action will be submitted at that time. Attached is a copy of the current 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TERM Canoc.;Wl9ips Fpm: Well Integrity Compliance Specialist CPF1 & 2 Sen . unday, August 30, 2020 9:04 AM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU IA -6 -5 -WTD 181-104) Report of suspect IA pressure increase Chris, KRU 1A-05 (PTD 181-104) was reported by Operations to have suspect IA pressure increase while shut in. CPAI intends to perform initial diagnostics after which a 30 day sliutyn monitor will be started. If IA pressure continues to increase during the 30 day monitor further diagnostics will be scheduled at that time. The proper paperwork for continued injection or corrective action will be submitted upon completion of the monitor period. A 90 day TIO trend and wellbore schematic are attached. Matt Miller Filling in for Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 354-5520 WELLS TEAM Conoc;mlips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, August 30, 2020 9:04 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1A-05 (PTD 181-104 Report of suspect IA pressure increase Attachments: 1A-05 90 day TIO plot 8-30-20.pdf, 1A-05 Schematic.pdf Chris, KRU 1A-05 (PTD 181-104) was reported by Operations to have suspect IA pressure increase while shut in. CPAI intends to perform initial diagnostics after which a 30 day shut in monitor will be started. If IA pressure continues to increase during the 30 day monitor further diagnostics will be scheduled at that time. The proper paperwork for continued injection or corrective action will be submitted upon completion of the monitor period. A 90 day TIO trend and wellbore schematic are attached. Matt Miller Filling in for Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 354-5520 WELLS TEAM Cm co tg ip% THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-05 Permit to Drill Number: 181-104 Sundry Number: 319-548 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Va DATED thi\I day of December, 2019. 3BDMSf�DEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAr 96 9Rn RF-®rmwr. DEC 12� 7111 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing PatcheEl 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli sAlaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service p 181-104 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20627-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A s Will planned perforations require a spacing exception? Yes ❑ No 2 KRU 1A-05 9. Property Designation (Lease Number): 10. Field/Pool(s): r ADL 25647 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,675' 6,850' 7138 6314 4000psi none 7186 Casing Length Size MD TVD Burst Collapse Conductor 47' 20" 80, 80, Surface 3,064' 133/8 3,096' 2,632' Production 6,604' 95/8 6,633' 5,810' Liner 867' 7" 7,670' 6,845' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6822-7092 5998-6268 3.5x2.875 J-55 7,013' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER FH RETIEVABLE PACKER MD= 6743 TVD= 5920 PACKER - BAKER FB -1 PERMANENT PACKER MD= 6992 TVD= 6169 SAFETY VLV - CAMCO TRDP-1A SAFETY VALVE MD= 1807 TVD= 1736 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service (] 14. Estimated Date for 12/26/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG 171 GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com /2 Contact Phone: (907) 265-6471 Authorized Signature:Date: ' - W 12. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: 9BDMSf'�DEC 19 2019 Post Initial Injection MIT Req'd? Yes No IS/ Spacing Exception Required? Yes No 111 Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I (("A K71_ /L/16 /1-1 � Submit Form and Form 1O a ,s Approved appl t ja�oll�o�lltq rom the date of a roval. :::/// PP J Attachments in D7,cate �i�n •� �._/.n KUP INJ WELLNAME 1A-05 WELLBORE 1A-05 ConocoPhillips Aas'hi, He 1Aas911.n54Am nbt Last Tag veawlCeneelzcnemapclsoms9 ................................................................. ""NGER, 26'.2 ................. AnnoyXon I Depth USE) I End Date wanlmle us, a. By Last Tag: SLM 1.m50 Up s"guep Last Rev Reason A^^^IaDo^I End bade W.11oons Est Moe By Rey Reason: CORREOCTED MISSING BPI ISO SLEEVE 1811r2019 IPPrVed Casing Strings Casing Description OD (in) ID (1.) Top lXKel ms Deem Red) Am DePen(Tw1... wuLan p... Grade Top Th.a CONDUCTOR 20 18.94 32.6 80.0 Boo 94.00 H40 WELDED coeguc]GR, s2saao Lasing Deac"ptlon OD In, ID 9n) Top PIKE) Set Depth XIKBI Set Depth IND1... WMLen (L.. Gntle Tap Tbread SURFACE 13318 12.41 31.6 3,095.9 2,632.1 72.00 LA0 BTC SAFETY VIN, t M).1 Casing Description On (in) ID (in) Top(XKBI Set Depth /nKB) Bel Depth INDL.. When 11... Gnde Top Thl-d PRODUCTION 9518 8.68 29.1 6,6334 5,810.1 47.00 L-80 BTC GAS LIFT: g.eet2 Cazing DascrrptWn OD(1 10(in) TOP PIKE) Set DepthnKB Set Depen NO.. NW'n(I...-men Top Tbmed ( ) (TVD) LINER ] fi28 .2842 7,610.0 6,845.3 26.00 K-55 BUTT Liner Details suapnce snas,oes.g_ Top INKS Top (TVD)("a) TOPIoa I°I nem Dea NommallD in (in) 6,284.2 5,462.1 881 SLEEVE BAKER SETTING SLEEVE 6.276 6,290.4 5,468.2 502 NIPPLE BAKER SEAL NIPPLE 5250 6,293.) 5,4]15 5.60 HANGER BAKER HYDRAULIC HANGER 69fi Tubing Strings GAa LIFT,4,mC. Tubing.-5rip[bn airing Ma... l0 (In) '.PMK Set Depth ltt.. Set Depth IN01 (... Wtllbllq Gentle-iop Lonnectlan TUBING 3.5"r3.815" 312 299 262 ],0135 81891 9.20 J-55 BTC GASUFTs,ams Completion DOW IIs SAS EFT , S,a421 GAS UFT; ENSI Top IND) Topind Nominal TDp (nKB 1 (WILD) 1°1 Item Des coin m Ib) 28.2 26.2 02fi HANGER FMC HANGER 3.500 1,807.1 1,]35.] 32.41 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.913 GAS LIFT; a..0 6,116.8 5,893.4 3.17 SBR BAKER SBR 2.813 6,743.0 5,919.6 3.03 PACKER BAKER FH RETIEVABLE PACKER 3.000 6,188.4 5,9649 2.81 BLASTJT 2.991 6,974.0 6,150.2 300 NIPPLE AVA PORTED NIPPLE 2.750 79849 .161.1 3.00 SEALASSV BAKER SEAL ASBEMBLV 2.441 GAR LIFT; EMS 5 7,992.3 .168.5 3.00 PACKER BA R FB -1 MANENT A KER / ROSS VER .000 3.5'.815- ],00].1 71833 3.00 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,0123 8188.9 3.OD SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) mP IND) mpmel pFODVC'P0.,M.1d,633e- GASUI sax;;nee vncKEa; e.]43o TOP MIKE) .84].0 (PIKE) 6,023.4 (') 287 Des PATCH Upper Co. ET 35" a"UPPER TRADDL A KERq Y (OAL=3239'/15CON SHEAR RELEASE PACKER/ 7360# SHEAR RELEASE SNAP LATCH) 0 6861' Rnn nab 1 5200 8 ID gn) 1.830 .819.0 6,055.4 295 PATCH Lower BAKER LOWER SNAP LATC A KE WI H23'0 SPACER PIPE. TOTAL TOOLSTRING LENGTH=41 8'. 1012 BO 8 1.630 INJECTION: a.]02.0 MAX OD= 2.16"; CENTER ELEMENT @ 6898'. 6,918.0 8,152.2 3.00 BPI SLEEVE BPI ISO SLEEVE 427/2006 2.320 6,381.8 300 FISH 4" Vann Gun 322.86'long 9/4/1981 0.000 PAT& S.Cdu AARO IPENF', B,6YtO6,9e5.0� Perforations B Slots PATCH Lover; 6,aR0 A, Q \ 4166 D.na TOP RYD) Bim (ND) (sharp Top (nKB/ Sam /nKB) (XHBI (flKB) LinkM Zone Oace 1 Type Co. , 9!3/1881 40 PERF 120 tleg. Ph, 4"Vann Guns 6,822.0 6,929.0 5,996.4 8105.3 - UNIT B, 1A-0 S (PERF; s,Snoa,ase.o_ 6,952.0 6,958.0 6,1283 6,132.3 UNIT 8, 1A-05 9/311981 4.0 (PERF 120 tleA-Ph, 4"Vann Guns 6,962.0 6,968.0 6,138.3 6,144.2 UNIT B, 1A 05 91311981 40 (PERF 120 tleg. Ph, 4"Vann Guns PERPEN206,e6e.0 .0 7,015.0 6,189.2 6,191.2 UNIT B, IA -05 6/511986 4.0 Bqueezetl ],052.0 7,056.0 6,228.1 6,232.1 A5, 1A-05 9/3/1981 4.0 (PERF 120tleg. P.4"Vann Guns NIPPLE; 6,x]40 BPIs1EEVE', 8 a]6.g 1,065.0 ],0920 6,241.1 .2661 A-4, 1A -0S 91311981 4.0 (PERF 120 tleg. Ph, 4"Vann Guns Cement Squeezes aEAL ASSY', e,spe PACx6x16.ea2a iIQW, Be'IND) Top (IIXB) Bfm (XKB) (MLD) IKKBI Des ShRnab Co. 1,013.0 ],015.0 6,189.2 6,191.2 ement 6/611988 Squeeze Mantlrel Inserts NIPPLE: ].0J]1 ed .I 60&;],012] PeY,],0130.],0150 cement ],ma.DM<BLa' an ¢` Valve etch Poe Size TqO qun N TOPIXKB TopPIKS) I (nNBI Make Model ODgn) Bery Typ Type (in) (pail Ron DaM Com 1 2,8512 2,460.4 CAMCO KBUG 1 GASLIFT ID BK 0.000 00 12111/1991 2 4,4)3.9 3,138.6 TANGO KBUG 1 GASLIFTDMV BK 0.000 0.0 12/11/1991 IPERF; 70007056.0 3 .0305 4,250.8 CAMCO KBUG 1 =AS DMY BK 0000 0.0 12/1111991 4 5,342.1 4,543.1 CAMCO KBUG 1 GAS LIFT DMV BK O.OW 0.0 12/11/1991 IPERF7,06.07,e12,0� 5 5,684.8 4,811.4 CAMCO KBUG 1 GASLIFT DMV BK 0.000 0.0 12/1111991 5 6,026.0 5,205.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 1 6,328.4 5,5060 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/11/1991 RSH;71e6.0 8 6,613.6 5,850.3 OTI 3 x 112 GALS LIFT DMV RO-5 0.000 00 311011981 1.5 9 6782.0 5,958.5 CA% KBUG 1 INJ DMV BK 0000 0.0 120/1998 LINER; 6,]64.2-7,E7n0 canocoPrrillips KUP INJ WELLNAME 1A-05 WELLBORE 1A-05 Alasl+a, llx:. ,ga6'a O n n:5a AN Notes: General & Safety yr e o xMnlatie (aNa'I EM Oah gnnobiion ............................. ................................ ......._.............. 32911998 NOTE: Unable Establish lDl Rale; Very Slow LEAK FwrvcER:261_ 102612002 NOTE: FOUND LEAKS@ 6860'MD 86883'MD )12912010 NOTE: View SrhemafiE wl Alaska SEbemBIiE9.0 M/ CONDUCTOR: DOEM0 SAFETY ,1,91]1 GAS UFT: 1651.1 SURFACE 1316d.094 GAS LIFT; Goa LIFT: C. GAS LIFT, 5.301.7 GAS LIFT 68668 GAS LIFT: 8.S.0 GABLIFT', 6323,5 PRODUCTION:C91d669.3— GAS LIFT 8.8136 FEB. 6,716a PACKER: 6.74BU INJECTION: EJBQL0 PATCH U, ESO0 'FEAR .. US ISO B PE R8.823.USISO0 PATEN —, Em PERF. ES. BE USE 0� IPFR F. 65610,59I� NIPPLE', 60]00 BPI..SBAE:F I SEAL ASSY: ARM 9 PACKER. 6..B NIPPLEp.EO]I 505:].011] PM: Q.mSO],015a� Y/. y Cw 7.01SOCKBI, IPER1:].W20]0%0------ IPERF:7,06I FISN', TREE LINER: 63N.2-7ai0.0 Proposal to Install 1A-05 Injector C Sand Tubing Patches 1A-05 injector selective completion has 3.5", J-55 tubing and perforations in KuparukA, B, and C sands. A C Sd tubing patch was set 10/25/08 at 6847 - 6879' RKB. A 3-16-19 IPROF verified it is holding, but 1A-05 takes over 4000 BWPD, which looks like C Sd injection either via a leaky lower packer on C Sd selective, or to C Sd via leaky Sqz perfs at 7013 - 7015' RKB in 7" casing. A recent IPROF shows all injection disappears at or near tubing tail with no injection reaching A Sd perfs. This procedure will pull the current restrictive 1.62" min ID tubing patch to replace it with 2 new patches with 1.81" min ID's, but before setting the new patches, we will pull a C Sd DV, then set a plug in tubing tail nipple with gauges for 'A Sd only' BHP, then set C Sd gauges, followed by a 'C Sd Only' LDL, followed by pull all gauges to see if gauge data suggests communication between C and A Sds inside casing or via a possible channel behind casing. Next, C Sd tubing patches with 1.81" min ID will beset for passing 1-11/16" logging BHA's for water flow logging below patches to look for up flow behind tubing tail via possible lower packer leak. We can also log to detect trapped 'gas bubble' behind tubing tail under lower packer of C selective and under upper packer of C selective via Sigma logging. If lower packer has integrity, we should detect a trapped gas bubble as present. Following diagnosis, we hope to determine correct work options to convert 1A-05 to 'A Sand only' injection. Procedure Slickline Wor Digital Slickline: 1) Pull the entire retrievable tubing patch assembly at 6847 - 6879' RKB from the tubing. 2) Set a Catcher Sub, then pull DV at 6782' RKB to leave pocket open, then pull the Catcher Sub. 3) Set 2.25" tubing tail plug with gauges in 2.25" D Nipple at 7007' RKB for A Sd BHP. 4) Set gauges on a flow thru tubing hanger in C Sd selective at 6965' RKB below the known tubing leaks at 6838' and 6895' RKB in tubing in C Sd selective. E -line: 5) RU Seawater transport to pumping unit to fullbore pump down the tubing while performing LDL to verify the plug set at 7007' RKB is not leaking. RIH to log static baseline LDL pass from surface to 6950' RKB. Park BHA at 6950' RKB, then pump through tubing leaks and open pocket at 6782' RKB at 2.5 bpm (62 bbls), 2.0 (30 bbls), 1.5 (22.5 bbls), 1.0 (15 bbls), and 0.5 bpm (7.5 bbls), then SD. POOH while pumping Dsl FP to 2000' TVD (19 bbls). Evaluate BHP data for C to A Sd communication. Digital Slickline: 6) Set a Catcher Sub, then set a DV at 6782' RKB, then pull the Catcher Sub. 7) RIH & set lower straddle packer of tubing patch #1 at 6891' RKB. POOH. RIH & latch the upper run section of straddle patch into the lower packer, then set upper straddle packer at 6875' RKB, to complete lower patch at 6875 - 6891' RKB with 1.81" min ID. 8) RIH & set lower straddle packer of tubing patch #2 at 6856' RKB. POOH. RIH Match the upper run section of straddle patch into lower packer, then set upper straddle packer at 6840' RKB, to complete the upper patch at 6840 - 6856' RKB with 1.81" min ID. 9) RIH with LDL BHA through tubing patches while pumping Seawater from a transport down the tubing to verify that the tubing patches are holding. POOH with logging BHA. RD. If LDL verified no leaks present in C selective, then additional logging diagnostics may be performed. Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Monday, December 16, 2019 2:50 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1A-05(PTD 181-104, Sundry 319-548) Set tubing patch Attachments: MIT KRU 1A PAD (1of2) 07-14-19.xlsx Victoria, Per MIT KRU 1A Pad Report attached, a 1A-05 MIT -IA passed 7-14-19. John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, December 5, 2019 1:32 PM To: Peirce, John W<John.W.Peirce @conocophilIips.com> Subject: [EXTERNAL]KRU 1A-05(PTD 181-104, Sundry 319-548) Set tubing patch John, What is the MIT -IA history on this well? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoorar7alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (9 07) 793-1 24 7 or Victoria LoeooQalaska gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: jim.reaaAalaska Dor AOGCC Inspectorsnalaska o : ph b b ok C1uk q ov OPERATOR: ConocoPhillips Alaska Inc FIELD/UNIT/PAD: Kuparuk/KRU/1A Pad DATE: 07114/19 OPERATOR REP: Caudle / Duffy AOGCC REP: Jeff Janes chmt wallaceGRalaska Dov Well to -04A INTERVAL Sun.. Pressures: Pretest Initial Is Min. 30 Min. 45 Min. 60 Min. 4•Four Yuar Cyde PTD 2001940 Type lnj N Tubing 1 790 3300 3210 3180 1 Type Tee' P Pecker TVD 4797 BBL Pump 1.3 IA 265 487 495 493 Interval V Test psi 3000 BBL Rehm 1.3 DA 274 276 277 277 Result P Note$: MIT -T every 2 years to 3000 psi against tubing plug @ 8533' per AO 28.011 Well 1A -04A Pressures: Pretest IMtial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001940 Type Inj N Tubing 880 1200 1220 1220 Type Test P Packer TVD 4797 BBL Pump 1.8 IA 280 3300 3200 3200 Interval V Test psi 3000 BBL Retum 1.8 OA 278 293 294 294 Result P Notes: MIT -IA every 2 years to 3000 psi per AI0 2B 011 Well 1A-05 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 80 Min. PTD 1811040 1 Type Irl W Tubing 2460 2460 2460 2460 Type Test P Packer TVD 5920 BBL Pump 3.5 IA 600 1700 1635 1605 Interval 4 Test psi 1500 BBL Return 3.2 OA 0 0 0 0 Result P Notes: Well 1A-10 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811600 Type Inj W Tubing 2425 2425 2425 2425 Type Test P Packer 5446 BBL Pump 1.3 IA 1110 1905 1880 1880 Interval 4 s Test psi 1500 BBL Rehm 0.4 OA 370 420 420 420 Result P Notes: Wall IA -12 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811780 Type Inj W Tubing 2400 2425 2425 2425 Type Test P Packer TVD 5822 BBL Pump 3.6 IA 40 3300 3220 3200 Interval V Test psi 3000 1 BBL RaWm 3.5 OA 175 360 360 370 Result p Notes: MlVA every 2 ye vs st MAP per A10 28.049 Well 1Al2 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811780 Type in! W Tubing 2425M20DO 2425 2425 Type Test P Packer TVD 5822 BBL Pump 1.6 IA 100218 231 Interval V Test psi 1800 BBL Return 1.4 OA 1901910 1860 Result P Notes: MIT -OA every 2 years to 1800 psi per A102B.049 TYP9 M Dudes TYPE TEAT Codes INTERVAL Sun.. Reauk Codes W -Water P=Pressure Tsst 1=lnWal Teat P.P. G=Gas O=OMer(dmcdbe in Nolee) 4•Four Yuar Cyde F=Fab 3•Stu, V= Required by Variance I=lmmnclusbre I = IMus$ial wwwaser O= Met (describe in robust N = Nut Injecting Form 10426 (Revised 01/2017) MIT KRU 1A PAD (loR) 07-1419 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg �/J/// DATE: Thursday, July 18, 2019 P.I. Supervisor ' "' / / 19 SUBJECT: Mechanical Integrity Tests / L ConocoPhillips Alaska, Inc. IA -05 FROM: Jeff Jones KUPARUK RIV UNIT IA -05 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry-'T NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -05 Insp Num: mitIJ190716090423 Rel Insp Num: API Well Number 50-029-20627-00-00 Inspector Name: Jeff Jones Permit Number: 181-104-0 Inspection Date: 7/14/2019 Packer Depth Well 1A-05-Typeln 'TVD 502, - Tubing PTD 1811040 - Type Test SPT Test psi 1500 IA BBL Pumped: 3 5 BBL Returned: 3.2 OA 4YRTST - P/I'i P Interval - — -- - Notes: I well inspected, no exceptions noted. , Pretest Initial 15 Min 30 Min 45 Min 60 Min 2460 2460 2460 21160 600 1700 - 1635 IGoS - 0 c 0 0 Thursday, July I8, 2019 Page I of I Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: f 4/ AOGCC +.. ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 +Ik Anchorage, AK 99501 181104 TRANSMITTAL DATE0ME- TRANSMITTAL# •M'Il 1E-104 1A -OS IA -07 50-029-23234-00 50.029-20627-00 50-029-20658.00 EA77-00006 EOSH-00028 EOSH-00029 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL (PROF IPROF FINAL FIELD FINAL FIELD r 20 -Feb -19 16 -Mar -19 r 1 1 1 H-118 50-029-23578.00 EOSH-00030 KUPARUK RIVER WL IPROF FINAL FIELD 17 -Mar -19 1 2A-17 50-103-20193.00 EA77-00009 KUPARUK RIVER WL IPROF FINAL FIELD 18 -Mar -19 1 2V-04 50-029-21041-00 EA77-00010 KUPARUK RIVER WL Caliper FINAL FIELD 18 -Mar -19 1 1H-11450-029-23584.00 EOSH-00031 KUPARUK RIVER WL ]PROF [PROF FINAL FIELD 19 -Mar -19 1 X -15A 50-029.21426.01 EA77-00011 KUPARUK RIVER WL FINAL FIELD 19 -Mar -19 1 LDL L FINAL FIELD 20 -Mar -19 1 8 A Transmittal Receipt signature confirms that a package (box, A7 Ir envelope, etc.) has been received and the contents of the X acka int Nam Signature Date p ge have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may Please return via courier or sign/scan and email a copy t chlumberger and CPAI. not have been verified for correctness or quality level at this Alaska PTSPrintCenter@slb.com Tom_narc point. Schlumberger -Private • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 02,2016 TO: Jim Regg P.I.Supervisor l 11 I i g SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-05 FROM: Brian Bixby KUPARUK RIV UNIT 1A-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry , ER— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-05 API Well Number 50-029-20627-00-00 Inspector Name: Brian Bixby Permit Number: 181-104-0 Inspection Date: 10/25/2016 Insp Num: mitBDB161026051433 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-05 - Type Inj G'I TVD 5922 " Tubing 2650 2650 - 2650 - 2650 PTD 1811040 - Type Testi SPT Test psi 1500 " IA 1320 2015 - 1970 - 1960 Interval 4YRTST P/F P / OA 180 180 - 180 . 180 Notes: 3.5 BBLS Diesel to Fill IA and 23 BBLS bled back. , . ,i APR 2 2017 Wednesday,November 02,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,July 20,2015 TO: Jim Regg -Ref, Di, IS P.I.Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-05 FROM: Bob Noble KUPARUK RIV UNIT 1A-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-05 API Well Number 50-029-20627-00-00 Inspector Name: Bob Noble Permit Number: 181-104-0 Inspection Date: 7/17/2015 Insp Num: mitRCN150719133040 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well f 1A-05 • Type Inj N" TVD 5922 Tubing 2350 - 2350 ' I 2350 ' 2350 ----------- ---- --- — -- --- PTD 1811040 Type Test EITest psi 1500 ' IA 1400 1950 1900 1890 Interval 4YRTST 1P/F P OA 115 - 115 120 - 120 Notes: 1 ask them if they didn't want to put more pressure on the well as it could fall back to within 500 psi of the tubing pressure.They said no because it wasn't going to count because the well was shut in. t '6J !fity l Monday,July 20,2015 Page 1 of 1 Imageeoject Well History File Cover I~e XHVZE This page identifies those items that were not scanned during the.initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ! ~ L- ~ ~-~- Well History File Identifier RESCAN DIGITAL DATA X Color items: [] Diskettes, No. [] Grayscale items: [] Other. No/Type ~ Poor Quality Originals: [] Other: NOTES BY: BEVERLY ROBIN VINCENT (~ MARIA WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) ~ Logs of various kinds [] Other Project Proofing BY; ~OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation BY: OBIN VINCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING pREPARATION: BY: Stage 2 BY~ (SCANNING I$ COMPLETE AT THIS POller UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ~ YES NO BEVERL'~VINCENT SHERYL MARIA WINDY IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10102Rev3NOT$canned.w~l . . UNSCANNED, OVERSIZED MATERIALS AVAILABLE: I'??! IOf FILE # I lIt-If} LoG-- To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission 1333 W. 7th Ave., Ste. 100 I Anchorage, Alaska 99501 Voice (907) 279-1433 ¡Fax (907) 276-7542 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission o r J N DATE: Wednesday, July 27, 2011 TO: Jim Regg (l cl P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A -05 FROM: Chuck Scheve KUPARUK RIV UNIT 1A -05 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry `-- NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1A - 05 API Well Number: 50 029 - 20627 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727065332 Permit Number: 181 - 104 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11A-os ' Type Inj. W' TVD 5922 IA 1600 1 2960 - 2900 - 2900 P.T.D' 1811040 ' TypeTest LsPT Test psi 1500 1 OA 210 220 220 220 Interval 4YRTST P/F P %Tubing t 2425 2425 1 2425 2425 Notes: Wednesday, July 27, 2011 Page 1 of 1 • Conoco Phillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri123, 2010 Mr. Dan Seamount Alaska Oil ~ Gas Commission 333 West 7'~ Avenue, Suite 100 Anchorage, AK 99501 yr~1. -((pp F Dear Mr. Dan Seamount: ~~~~ !r/ ~1..A' . .~ APR 2 ~~. 201.0 . ,~asl<a Oil ~ Gx Caps. Oammssion ~IIICIK(aQ~ Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRLn.. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering.the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru Apri117, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since ~.1 ' Perry ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4123110 1A. 1F. 1Q Si 1Y PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off da#e Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF n/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/6!2010 1A-05 50029206270000 1811040 SF Na 6" Na 4.25 4/7/2010 1A-08 50029203130000 1780400 SF Na 10" n/a 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" n/a 2.55 4/2/2010 1A-15 50029207110000 1820170 SF n/a 4" n/a 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" n/a 4.25 4/1/2010 1 Q-02 50029212480200 2051420 22" Na 22" n/a 7.2 4/6/2010 1 Q-03 50029212490200 1842330 27" Na 27" n/a 3.4 4/6/2010 1Q-05 .50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 1 Q-06 50029212240000 1842080 32" Na 32" n/a 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" n/a 32" n/a 3.82 4/1/2010 1Q-15 50029213080000 1850460 22" n/a 22" n/a 2.97 4/1/2010 1Q-16 50029213090000 1850470 25" n/a 25" n/a 3.82 4/1/2010 1Y 21 50029223870000 1931020 23" n/a 23" n/a 3.82 4/1/2010 1 Y 24A 50029223717100 2041250 26" n/a 26" n/a 3.82 4/1 /2010 1 Y 28 50029223800000 1930890 28" n/a 28" n/a 5.52 4/1/2010 1Y 31 50029223810000 1930900 6'8" 0.65 24" 3/21!2010 5.52 4/1/2010 S WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 2, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1A-05 Run Date: 9/2/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A -05 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 20627 -00 Injection Profile Log ND'! n 2Oi 1t'= 1 Color Log 50- 029 20627 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating u-re /6/-/O Attn: Rafael Barreto tT 5� 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto@ Wi i t_; Date: NOV Signed: l �k� 0th k G CO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~~ ' : °: 1. Operations Pertormed: Abandon ^ Repair Well ^~ ~ Plug Perforations ^ Stimulate ^ Other " Q Set Ratch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 181-104 / 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20627-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' { 1 A-05 8. Property Designation: 10. Field/Pool(s): ADL 25647 Kuparuk River Field /Kuparuk Oil Pool ` 11. Present Well Condition Summary: Total Depth measured 7675' feet true vertical 6850' ~ feet Plugs (measured) Effective Depth measured 7138' feet Junk (measured) frsh @ 7186' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 80' 80' SURFACE 2995' 13-3/8" 3095' 2613' PRODUCTION 6533' 9-5/8" 6633' 5810'z~E~~~~~~ ~l~'I~ i! r ~~~~ LINER 867' 7" 7151' 6327' Perforation depth: Measured depth: 6822'-6929', 6952'-6956', 6962'-6968', 7013'-7015', 7052'-7056', 7065'-7092' true vertical depth: 5998'-6105', 6128'-6132', 6138'-6144', 6189'-6191', 6228'-6232', 6241'-6268' Tubing (size, grade, and measured depth) 3.5" / 2-7/8", J-55, 6998' / 7010' MD. ~~ ~«< Packers & SSSV t e & measured de th (yp p ) pkr- BAKER'FH' RETR. ; BAKER'FB-1' PERM. pkr- 6745' ; 6989' Camco TRDP-1A SSSV= 1809' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 1335 - -- 1566 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 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: 308-225 Contact John Peirce @ 26 5-6471 Printed Name John Peirce Title V1lells Group Engineer Signature ,~ ~ i ' G[ Phone ~- Date ~ 1 -~ ~"'Q S . +CJ Pre ared b Sharon Allsu Drake 263-4612 ~"~~'~~~, "'~~. r,~rltl ~. '~ 20DB ~ Form 10-404 Revised 04/2006 ,,.;~ ~ M Submit Original Onl 1A-05 Well Work Summary DATE SUMMARY 7/20/08 ATTEMPTED PULL PATCH ~13' WL, NO SUCCESS. IN PROGRES~ 7/21/08 ATTEMPTED PULL PATCH @ 6830' RKB. NO MOVEMENT. JOB SUSPENDED, READY FOR CTU. 8/5/08 RIH AND LATCH PACKER @ 6856' CTMD.HAD NO MOVEMENT AFTER 61 JAR LICKS.JOB INPROGRESS 8/6/08 PULLED 5 92' FEET O~pDE° °~''T~nN nF PATCH. RIH AND LATCH SECOND SECTION OF PATCH AND USED DEPLOYMENT FLANGE TO CAPTURE PATCH.RIG BACK FOR THE SLICKLINE TO TRY AND REMOVE NEXT SECTION. JOB IN PROGRESS. 8/7/08 PULLED UPPER 23.5' PATCH ASSEMBLY FROM TREE (BOTTOM OF STINGER HAS FLOW CUT HOLE 6" UP FROM BOTTOM OF STINGER ). COIL TUBING PULLED LOWER PATCH ASSEMBLY INTO TREE AND RETRIEVED 23' PATCH ASSEMBLY W SLICKLINE (FISH NECK HAS 1/2" FLOW CUT HOLE 6" FROM TOP. OF FISH NECK ). 8/7/08 RIH W/ 3" G SPEAR AND PULLED THIRD SECTION OF PATCH.LEFT LOWER SECTION IN PLACE FOR NOW.BOTTOM OF SECOND SECTION AND TOP OF THIRD SECTION HAD A SEVERE WASH OUT INSIDE THE SNAP LATCH PROFILE. JOB ONCOMING 9/4/08 ATTEMPT TO PULL LOWER PATCH PACKER @ 6888' RKB. 3.5 HRS TO SHEAR GR. JOB IN PROGRESS. 9/5/08 ATTEMPT TO PULL LOWER KB STRADDLE PACKER @ 6888' RKB, NO SUCCESS. JOB IN PROGRESS. 9/6/08 ATTEMPT TO PULL KB STRADDLE PACKER @ 6888' RKB. NO SUCCESS. (***IMPACT TOOL RECORDED 7900# TO 10750# JAR LICKS***). JOB IN PROGRESS. ***SERVICED SWAB 4 TIMES IN 2 DAYS***. 9/7/08 ATTEMPT TO PULL KB STRADDLE PACKER @ 6888' RKB, NO SUCCESS. JOB SUSPENDED. 9/16/08 CT FISH LOWER "KB" PATCH PACKER ASSEMBLY FROM 6888' RKB UTILIZING DUAL ACTING JARS. LATCHED FISH @ 6895' CTMD, 30 JARS LICKS, MAX. P/U WEIGHT 38,000#. NO LUCK, PUMP OFF -POOH. CUT CT, RE-DRESS CONNECTOR FOR RE-START IN AM USING HAMMER OR HEAVIER JARS. 9/17/08 P/U 1-3/4" CTC, 2.125" CV, DC, ACCELERATOR, UP/DOWN BAKKE HAMMERS, IGT & 3.5" GS, LENGHT 19.24'. RIH AND TAG KB STRADDLE PACKER @ 6892' CTMD. WORK BAKKE HAMMERS PUMPING S.D @ 1/2 BPM FOR 20 MIN. PULLED FREE @ 24,000#. POOH -INSPECT FISH -WASH OUT NEAR BOTTOM SET OF ..PACKER ELEMENTS. SLIPS ARE INTACT. WELL FREEZE PROTECTED, HAND OVER TO DSO. 9/27/08 TAGGED~g 7110' SLM. CALIPER FROM TTL @ 7010' RKB TO SURFACE. BRUSH & FLUSH TBG FROM 6800 TO 6950' RKB, JOB COMPLETE. 10/23/08 SET BAKER " 35" WL KB BTM SNAP LATCH PACKER ASSEMBLY.WITH _ MID ELEMENT AT 6898'. READY FOR SLICKLINE TO SET UPPER ASSY. 10/25/08 SET 35 "KB" UPPER STRADDLE PACKER ASSY (OAL= 32.39'/ 15000# SHEAR RELEASE PACKER/ 7360# SHEAR RELEASE SNAP LATCH) @ 6861' SLM. JOB COMPLETE. -_ ;.: ~ ~A1'~K?tz~j~~~~5 , ~ ~ KUP Well Attributes ~ 1A-05 i^' ' Wellbore AFUU\Yl F,eW tJiu~v 5002920627D0 KUPARUK RIVER UNIT Well Status fruJ:ln~ Ytell Tyµ (INJ PWI Inel (•) AMU (tMU) TD (max) (n.. 49.50 I 2,100.00 7,675.0 ••• ::r°. ,~~ t~-:5 ~ "38818: SJ AM - _ ,., ,~ ,... r.F 1 j wnaucroR~ sarery vane, ~ ~ 1,x09 GAS LIFT, Comment ~H2S (ppm) Dale Annotation End Date KB~rtl (ft) Rig Release Date SSSV: TRDP 0 7/1/2008 Last WO: 2/24/1987 39.01 91411981 Annotation Depth (RI(B) End Date Annotation l End Data ( Last TaD: SLM 7. 110.0 9/27/2008 Rev Reason: TAG. PULL OLD PATCH. SET NEW PATCH 10/302008 rCasing Strings String OD Skiing ID I Set Depth Set Depth (ND) String YJt Strin g I Casing Description lin) (in) Top (RKB) (ftK6) (RKB) (Iba/ft) Gretl e String Top TAed , CONDUCTOR 20~ 18.936 0.0 80.0 80.0 94.00 H-40 SURFACE 13318 12.191 0.0 3,095.0 2,631.5 72.00 L-80 PRODUCTION 9 5/8 8.525 0.0 6,633.01 5,809.7 47.00 L-80 LINER 7 6.151 6,284.0 7,151.0 6,327.0 26.00 ' ~ K-55 2,853 3 Tubin Strings SURFACE String DD String IU Set DepN Set Uepm (TVD , 3,095 Tubing Deacription lint On) lop (RKB) (RKB) (RKB) ` TUBING 312 2.992 0.0 6,998.0 6,174 GnsuFT. ~ TUBING ~ 27/8 2.441 6,998.0 7 010.0 6,186 4,478 , } Other In Hole (Afi Jewelry; Tubin g Run &,Bet_rievable, Fish, etc.} GA650~ ~ lop Depth (ND) Top ~ Top (RKB) (RKB) Incl (°) Deseripton ~ Comment 1,809.0 1,734.6 32.O6I Safety Valve . Cameo TRDP-tA GAS LIFT 9 349 ~ ~ 2,853.0 2,461.7 45.99 GAS LIFT CAMCOIKBUGIIIDMYIBKII/Comet , 4,476.0 3,740.5, 23.SO~ GAS LIFT CAMCO/KBUG/1/DMY/BK//I Comm 5,033.0 4,253.6 23.17 GAS LIFT CAMCO/KBUGl1/DMYIBK//I Comm GAS uFT, 9,667 5,345.0 4,545.4 18.96 GAS LIFT CAMCO/KBUGl1/DMY/BK!/I Comm 5,687.0 4,873.5 14.26 GAS LIFT CAMCO/KBUGl1/DMV/BKI/I Comm GA5 1 e) 6,028.01 5,208.0 9.08 GAS LIFT CAMCO/KBUGl1/DMY/BKII/Comet 6 ~8 u_ ; r 6,331.0 5.508.6 5.10 GAS LIFT CAMCOIKBUGIIIDMY/BKII/Comet GA5 LIFT, 6,331 PRODUCTION, 6,633 GAS LIFT, 6,676 SBR, 6,719 S 'ACKER, 6,745 INJECTION, ' 6,784 ~ PATCH Upper, 6,807 IPERF, 6822-6,929 PATCH Lower, 6,879 IPERF, 8,952-8.958 IPERF, 6.982E.968 NIPPLE, 8,976 SLEEVE-C, 6,976 'ACKER, 8,9&9 j NIPPLE, 7,004 {{ 3 505, 7,009 > TTL, 7,010 •. 3 e 1 7,0137,015 Cement, 7,013 IPERF, ],052-7,OSfi IPERF, 4_~- 7,O6S7, 092 LINER, 7,151 FISH, 7,188 r0, 7979 STA 5 VJt Sblrg t) Grade I SMna Too Thni T'FH' RETRIEVABLE PACKER 619/1986 3.000 ,~..~ COIKBUGl1/DMYIBK///Comment: CLOSED STA 9 12/7/1998 2.875 35 "KB" UPPER STRADDLE PACKER ASSY (OAL= 10252008 1.630 Y/ 15000# SHEAR RELEASE PACKER/ 7360# SHEAR ASE SNAP LATCH) @ 6861' .R LOWER SNAP LATCH PACKER WITH 23' OF 102312008 1:830 :ER PIPE. TOTAL TOOLSTRING LENGTH=41.8'. MAX 2.78", CENTER ELEMENT @ 6898'. 'D' Perforations FISH 4" Vann Gun 322.86' long Certt@Ot $QU®®ZBS __ _ Top Depth Dtm Gepth. Top (RKB) Btm (RKB) (RKB) (RKB) ~ DeacNptlon Start Date Comment ~ 7,013.0 7,015.0 6,189.2 6,191.2 Cement Squeeze 6/6/1986 ~ Notes: Ge_nera_I & Safety I Entl Date I Annotltlon I • • ~L~ Lr~ j ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) B59-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~ ~~"'~'~aa:. ~ '.? ;; E ~~~°~~ Suite C Anchorage, AK 9951$ Fax. (907) 245-8952 1) Caliper Report 27Sep-08 1 A-05 1 Report / EDE 50-029-20627-00 2) Caliper Report 28Sep-08 3G25X 1 Report / EDE 50-103-20246-00 VIA'- ~~~^~~ 1~9~~ Signed Print Name: ,~~i3,~-J~. ~ ~~c.lM.Ey~,~ Date ~ ~ '. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245951 Fax: (907)245-88952 E-MAIL : ~~sar3ch~r~U;'C~rr3esn~rrtl~~ve?~: WEBSITE: v+rvw.rraerr~r;rloC.rs~r~i ~ /~ C:\Documents and Settings\Owns\Desktop\Trensmit_Conoco.doc • Memory Multi-Finger Caliper Leg Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1A-05 Log Date: September 27, 2008 Field: Kuparuk Log No.: 7268 State: Alaska Run No.: 3 API No.: 50-029-20627-00 Pipet Desc.: 3.5" 9.2 Ib. J-55 BTC Top Log Intvl: Surtace Pipet Use: Tubing Bot. Log Intvl: 6,998 Ft. (MD) Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD Top Log Intvl: 6,998 Ft. (MD) Pipet Use: Tubing Tail Bot. Log Intvl: 7,010 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS This caliper data is tied into the Shear-Out Sub @ f,010' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and 2.875" tubing tail with respect to ~rrosive and mechanical damage. The caliper recorded a hole in joint 222 (6,867'). The caliper recordings indicate the remainder of the 3.5" tubing logged is in good to fair condition with respect to corrosive damage, with a maximum wall penetration of 31% recorded in an area of general corrosion in joint 26 (808'). Other recorded damage appears as scattered pitting above the SSSV. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate the 2.875" tubing tail is in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of crams-sectional wall loss or l.D. restrictions recorded. The joint tabulation information for the 2.875" tubing tail is combined with the 3.5" tubing joint tabulation sheets. This is the third time a PDS caliper has been run in this well and the second time the entire 3.5" tubing and 2.875" tubing tail have been logged. A comparison of the current and previous log (December 24, 2005) indicates little, if any, change in corrosive damage during the time between logs, with the exception of the new hole recorded in joint 222 (6,867'). A comparison graph illustrating the difference in maximum-recorded penetrations on a joint-by joint basis is included in this report. The current log indicates a reduction in minor scale compared to the 2005 log. Scale can slightly exaggerate reported damage by interfering with the determination of undamaged wall during penetration calculations. The slightly lower overall maximum- recorded penetrations in the 2008 log appear to be the result of a reduction in scale since the 2005 log. MAXIMUM RECORDED WALL PENETRATIONS Hole (100%) Jt. 222 @ 6,867 Ft. (MD} Corrosion (31%) Jt. 26 @ 808 Ft. (MD) Isola#ed Pitting (29°~) Jt. 30 ~ 925 Ft. {MD) Isolated Pitting (28%) Jt. 22 ~ 689 Ft. (MD) Isolated Pitting (28°h) Jt. 29 @ 900 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 8%) are recorded y~y ~~~1i ry ~0~~ .. >:~ MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer: Wm. McCrossan Analyst: M_ Lawrence Witness: S. Ferguson ProActive Diagnostic Services, Inc. J P.Q Box 1369, Stafford, T`~ 77497 Phone: (281) or (888) 565-9085 Fax: (Z81) 565-1369 E-mail: PDSCa~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 vT ~ I'~s I -rod ~'0~i1o9~l~- r \~~ PDS Multifinger Caliper 3D Log Plot ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1A-05 Date : September 27, 2008 Description : Detail of Caliper Recordings Across Patch Interval • • • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (8.9' - 6998.3') Well: 1 A-05 Pipe 2 2.875 in (6998.3' - 7010.2') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: September 27, 2008 . A pprox. Tool De viation ^ A pprox. Borehol e Profil e 39 765 1529 2305 GLM 1 3061 p ii c 3820 s Y Q GLM 2 4584 GLM 3 GLM 4 5357 GLM 5 GLM 6 6120 GLM 7 GLM 8 Chem 9 22 5.9 7010 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 225.9 1 25 50 75 100 v E Z 125 C Q 150 200 • L~. S ,~ Well: 1 A-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: IJSA Maximum Recorded Penetration Comparison To Previous Survey Date: September 27, 2008 Prev. Date: December 24, 2005 Tool: UW MFC 24 No. 214320 Tubing: 3.5" 9.2 Ib J-55 BTC Overlay Max R ec Pen . (mils) 0 5 0 10 0 15 0 20 0 25 0 0.1 7 ' 17 27 37 47 57 66 76 86 95 d 105 a ~ 115 125 8 135 145 154 164 173 182 191 200 209 218 225 ^ September 27, 2008 ^ December 24, 2005 Difference D -100 -5 iff. in Max Pen. (mil 0 0 5 s) 0 10 0 i ~ I 7. 17 27 37 ~ ~ 47 S7 66 76 86 95 ;, ~ 105 ~ 115 Z 125 ~ -° 135 145 I 154 164 173 182 191 i ~ 200 209 f 218 225 -36 -1 8 0 1 8 3 6 App rox Corrosion Rate (mpy) • PDS Report Overview ~ S~ Body Region Analysis Well: 1A-05 Survey Date: September 27, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal sL• M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 f -55 BTC 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°k wall) ~ penetration body metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 233 pene. 8 175 37 12 0 1 loss 58 175 0 0 0 0 Damage Configuration (body ) 50 40 30 20 10 0 isolated general line ring hole / poss pitting conosion corrosion corrosion ible hole Number of ~oints dama ed total = 44 41 2 0 0 1 Damage Profile (% wall) ~ penetration body _ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 Chem 9 Bottom of Survey = 225.9 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf J-55 BTC Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEET 1A-05 Kuparuk ConocoPhillips Alaska, Inc USA September 27, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul~.~~t ilm.) Pen. Body (Ins.) Peen. °i~ 1~Icl,rl loss `;4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 9 ~? 0.01 ? ' 3.00 PUP 12 (! 0.01 2 1 2.9 PUP .3 23 t~ 0.01 2 I 2.94 PUP .4 29 a 0.01 ? I 2.96 PUP 1 39 t) 0.01 4 .95 2 70 t! 0.01 Z 2.93 3 102 ~. ~ 0.01 Z 2.92 4 133 t i 0.03 1 3 I 2.93 Shallow ittin . 5 164 t ~ 0.01 ~ ' 2.93 6 196 U 0.00 ~ ~ 2.93 7 2 7 t! .01 ~ 2.96 8 258 t! 0.01 4 -t 2.91 9 288 t! 0.0 13 a 2.91 Shallow ittin 10 318 t! 0.04 l a 2.90 Shallow ittin . 11 347 t t 0.04 l b I 2.92 Shallow ittin 12 377 ~ ~ 0.04 I ~ I 2.93 Shallow ittin . 13 404 t! 0.0 13 _' 2.93 Shallow ittin . 14 434 ~ i 0.0 18 _' 2.91 Sh~ Ilow ittin . 15 464 t! 0.04 17 -1 2 95 Shallow ittin . 16 495 U 0.02 9 _' 2.92 17 5 4 u 0.04 1 ~1 _' 2.95 Shallow ittin . 18 554 (! 0.03 11 _' 2.91 19 585 t! 0.03 13 _' 2.95 Shallow ittin . 20 616 t1 0.04 16 _' 2.94 Shallow ittin . 1 45 t! 0.0 >ts .95 Isol~ ed itti 22 675 a 0.07 28 2.92 Isolated ittin . 23 705 t~ 0.06 22 -1 .9 Isolated ittin . 24 734 l) 0.05 2O -1 2.95 Shallow corrosion. 25 765 t! 0.06 22 2. 3 Isolated ittin . 26 796 t I 0.08 > 1 -l 2.92 Corrosion. 27 827 t! 0.06 Zl t 2.94 Isolated ittin . 28 57 t! 0.07 1~ ~ 2.92 Isolated ittin . 29 888 a 0.07 2£3 ~ 2.96 Isolate ittin . 30 918 t) 0.07 2e? ,' 2.96 Isolated ittin . 31 949 l) 0.06 24 -k 2. 0 Isolated ittin . 32 980 (1 0.04 14 2.93 Shallow ittin . 33 101 ~ 1 0.06 > _' 2.94 Isolated ittin . 34 1041 U 0.04 15 2.96 Shallow ittin . 35 1072 t! 0.05 .'l) I 2.90 Isolated ittin . 36 1102 ~! 0.04 I J 2.95 Shallow ittin . 37 1133 O 0. 4 18 ~ 2.92 Shallow ittin 38 1164 t1 0.04 15 _' 2.94 Shallow ittin . 39 1195 t ~ 0.01 4 2.96 40 1226 c! 0.01 ' _' 2.94 41 1256 a 0.01 4 2.94 42 1287 t) 0.01 2 I 2.94 43 1318 a 0.02 t3 .92 44 1347 i ! 0.01 ? 2.96 45 1378 0.01 _' 2.92 46 1409 0.01 _' 2.95 _ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC Well: 1 A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 27, 2008 Joint No. Jt. Depth (Ft.) I'~~n. i 11~,~~t (Im.l Pen. Body (Ins.) Pc~n. °io 1~1c~l,il I o,ti ° ~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 47 1439 (~ 0.01 5 2.93 48 1470 U 0.00 1 _' 2.93 49 14 9 t 1 0.00 1 2.94 50 1529 ti 0.01 4 2.95 51 1559 t ~ 0.01 i .93 52 1589 t ~ .O1 -i 2.93 53 1619 c ~ 0.02 `? 2.95 54 1651 (~ 0.01 I 2.93 55 168 0 0.01 ~1 c ! 2.96 56 1713 (~ 0.01 2 ,? 2.9 57 1744 (~ 0.01 2 ' .9 58 1774 t) 0.01 ~' _' 2.93 58.1 1805 t ~ 0 ~ i { ? 2.81 Camco TRDP-1 A SSSV 9 1817 a 0.01 ~ 2.91 60 1848 t ~ 0.03 1 1 2.93 61 187 a 0.00 I 2.9 62 1910 t~ 0.04 1 I 2.93 Shallow ittin . 63 1941 U 0.02 ~~ 2.92 64 1972 ~ ~ 0.01 -1 2.94 65 2002 t ~ 0.01 a .95 66 203 ~ ~ 0.00 I 2.92 67 2061 a 0.01 i 2.92 Lt D osits. 68 2092 ~ ~ 0.02 9 ~ 2.92 69 2122 ~~ 0.02 9 ~ 2.91 70 a 0. 9 9 o f 71 2184 r ~ 0.01 1 _' 2.96 72 2215 a 0.01 S _' 2.95 73 2245 U 0.01 4 _' 2.91 74 2275 t) 0.01 -1 2.96 75 2305 tt 0.01 _' 2.93 76 335 a 0.01 ~ 2. 5 77 2365 U 0.01 2 ,1 2.93 78 2396 t1 0.01 2 _' 2.96 79 2426 (~ 0.02 9 l 2.93 80 2456 a 0.01 ? 2 2.91 81 2486 U 0.01 ? 2.94 82 2517 U 0.02 9 I 2.91 83 2 546 t ~ 0.01 ~' 2.94 84 2577 t1 0.01 4 _' 2.91 85 2608 a 0.01 Z t~ 2.89 8 2637 (1 0.03 11 _' 2. 5 t. De osits. 87 2666 11 0.01 2 2.84 Lt. De osits. 88 2695 It 0.0 2 .92 89 2724 l) 0.02 8 _' 2.95 90 2757 t~ .01 ~ _' 2.92 91 2788 t~ 0.01 1 2.93 92 2818 U 0.01 2 Z 2.94 92.1 2848 t~ 0 0 U N A GLM 1 Latch ~ 2:30 93 2854 t ~ 0.01 -1 ~' 2.94 94 2886 !! 0.02 ~l ' 2.91 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.2 ppf )-55 BTC Well: 1 A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 27, 2008 Joint No. Jt. Depth (Ft.) Nc°n. Ul~x~t (Ins.) Pen. Body (Ins.) Pc~n. °4, ~r~t.~l Ic~ss 3~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2915 t~ 0.01 2 I 2.91 96 2943 t~ 0.01 4 2.91 97 2973 ti 0.01 4 2.92 98 3003 U 0.01 a 2.92 99 3033 U 0.01 3 I 2.94 100 3061 tl 0.00 I I 2.93 101 3092 t) 0.01 ~' _' 2.93 102 3122 U 0.01 6 ~ 2.94 103 3152 U 0.03 I1 S 2.96 104 3183 t I 0.02 9 3 2.89 105 3213 ~ ~ 0.01 2 ~' 2.94 106 3244 t~ 0.02 ~t ~' 2.91 107 3273 I ~ 0.01 -t I 2.91 108 3303 t~ 0.01 ~ I 2.90 Lt De osits. 109 3334 i ~ 0.01 _' .93 110 336 a 0.01 ~ 2.93 111 3394 ~ I 0.03 1 , _' 2.93 Shallow ittin Lt. De sits. 112 3425 U 0.01 1 ! 2.94 113 3456 U 0.02 ~> ? 2.96 114 3486 t~ 0 01 1 .9 1 15 3516 i) 0.01 _' _' 2.95 116 3545 tl 0.04 14 _' 2.92 Shallow ittin Lt. De sits. 117 3576 t~ 0.01 ? _' 2.94 118 3606 tt 0.01 -t ~ 2.94 1 9 3637 l) 0.01 ~' 2.92 120 3667 U 0.03 II ~ 2.93 121 3698 U 0.01 ? 2.93 122 3729 a 0.01 i 2.93 123 3759 U 0.01 ~ 2.90 124 3790 t ~ 0.01 2.90 125 3820 t? 0.01 4 2.90 126 3849 t) 0.03 1u I 2.93 127 3879 l) 0.01 ~ Z 2.91 128 3908 U 0.00 ~ 1 2.93 129 3939 t) 0.01 5 2.93 130 3967 a 0.01 5 2.93 131 3998 U 0.03 1 U I 2.9 132 4029 t~ 0.01 3 2.96 133 4059 t I 0.01 -1 2.93 134 4090 t~ 0.02 ~) .' 2.93 135 4121 U 0.01 4 1 2. 4 136 4153 t ~ D.01 4 ? 2.92 137 4182 U 0.01 2 I 2.89 138 4212 t> 0.01 4 1 2.90 139 4242 tt 0.01 4 ~ 2.91 140 4272 t1 0.03 11 ~' 2.94 141 4303 U 0.01 4 ~ 2.94 142 4335 U 0.01 2 ; 2.93 143 4365 a 0.01 2 2.94 144 4396 U 0.01 U 2.88 Lt. De osits. t _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC Well: 1 A-05 Body Wall: 0254 in Field: Kuparuk Upset Wall: 0.254 in Cornpany: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 27, 2008 Joint No. Jt. Depth (Ft.) I'~~n. lllrif~t (Irn.l Pen. Body (Ins.) Pc~n. 44, ~~~i.~l I~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4427 (~ 0.02 t3 I 2.92 146 4457 tt 0. 4 15 a 2.94 Shallow ittin Lt. De sits. 146.1 4486 iJ 0 0 u N A GLM 2 Latch ~ 4:00 147 92 . ~ 0.01 5 ? 2.93 148 452 2 ~ ~ 0.01 ~ I 2.94 149 4554 tJ 0.00 1 2.93 150 4584 tJ 0.04 17 _' 2.94 Shallow ittin . 151 4616 t t 0.01 ~ s 2.93 152 4644 t J 0.02 t3 _' 2.95 153 4676 (t 0.01 _' I 2.92 154 4705 (J 0.01 I 2.93 155 4736 tt 0.01 _' 2.92 156 4766 t J 0.01 ' _' 2.95 157 4796 r i 0.01 a i 2.91 158 4826 ti 0.03 lu ~~ 2.8 159 4857 i J 0. 2 ' J - 2.93 160 4886 U 0.03 13 ~, 2.95 Shallow ittin . 161 4916 l J 0.01 Z 2.93 16 4946 a 0.01 ~ 2.95 163 4977 U 0.01 ~ _' 2.94 164 5 08 a 0.01 i I 2.93 164.1 5039 U 0 U lJ N A GLM 3 Latch @ 8:00 165 5046 t 1 0.02 ~ t -1 2.88 166 5075 U 0.01 ? I 2.93 167 5106 U 0.01 4 2.95 168 5138 tJ 0.01 4 2.93 169 5168 a 0.02 ~) S 2.90 170 5199 a 0.01 1 1 2.93 171 5229 U 0.01 5 ? .94 172 5260 t J 0.01 4 1 2.92 173 5290 (t 0.03 10 ~ 2.90 Lt. De osits. 174 5321 t t 0.02 t3 ~' 2.91 174.1 5351 U 0 U (t N A GLM 4 Latch ~ 11:00 175 5357 t) 0.04 ltd 2.94 Shallow it[in . 176 5388 U 0.01 i _' 2.91 177 5417 i J 0.01 ~ ' 2.93 178 5447 t t 0.02 ~) ~' 2.95 179 5476 a 0.01 b ~' 2.92 180 5505 t J 0.03 1 U _' 2.91 181 5536 i J 0.01 4 2 2.94 18 5567 U 0.02 £1 I 2.95 183 5597 tt 0.01 t, ~ 2.91 184 5626 U 0.02 ~) I .90 185 5657 t J 0.02 ~) .' 2.92 185.1 5686 u 0 U U N A GLM 5 Latch @ 8:30 186 5692 lJ 0.04 16 1 2.90 Shallow ittin . 187 5725 U 0.01 5 t J 2.91 188 5754 t t 0.01 4 ! J 2.93 189 5783 t ~ 0.02 `) 2.9 190 5814 t ~ QO1 ~ I 2.93 _ Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC Well: 1 A-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 27, 2008 Joint No. Jt. Depth (Ft.) I'wr. 11IsF~t i1n5.1 Pen. Body (Ins.) Pen. `~~ lile•t,rl I oss , ~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 191 5844 i ~ 0.01 4 4 2.93 192 5874 a 0.01 5 U 2.91 193 5904 (~ 0.01 5 2.94 194 5933 cl 0.01 4 ~ 2.93 195 5963 tl 0.01 ~~ .95 196 5994 i ~ 0.01 -1 2.94 196.1 6024 t~ 0 U it N A GLM 6 Latch ~ 8:00 197 6030 U 0.05 'U -1 .95 Shallow ittin . 198 6061 t) 0.05 1 ~) I 2.91 Shallow ittin . 199 6092 l) 0.03 13 t~ 2.93 Shallow ittin Lt. De sits. 200 6 20 U 0.03 I a I .92 Sh I w ittin . 201 6152 U 0.01 5 ! ~ 2.95 202 6182 t) 0.01 ~ +~ 2.90 203 6211 U 0.01 ~ I 2.91 204 6240 U 0. 2 ~~ .90 205 6271 U 0.01 5 Z 2.93 2 6303 a 0.01 5 s 2.93 206.1 6334 i) 0 0 i) N A GLM 7 Latch @ 8:00 207 6340 (? 0.01 S 2.91 208 6371 t) 0.01 ~ 2.92 209 6401 a 0.02 - I 2.94 210 6432 r 1 0.01 ~' I 2.92 211 6463 t) 0.03 1 c l I 2.92 212 6494 ~~ 0.02 ~) I 2.91 213 6523 cr 0.01 > I .92 214 6553 it 0.01 5 2.92 215 6584 c) 0.01 5 2.9 216 6614 r ~ 0.02 ~) 2.93 217 6645 l) 0. 2 ~) 2.91 217.1 6672 O 0 ~~ ~ ~ N A GLM 8 Latch ~ 10:30 218 6687 U 0.02 9 2.94 218.1 6719 U 0 t) i) 2.81 Baker'SBR' Seal Assembl 218.2 6746 l) 0 O tl 3.00 Baker'FFiL' Retrievable Packer 219 6753 i) 0.03 I a 2.95 Shallow ittin . 21 .1 6785 I) 0 it u N A Chem. In'. Mandrel 9 Latch ~ 6:0 220 6792 C) 0.01 5 2.95 221 6824 t) 0. 1 ~ 2.96 222 6857 i ~ 0.33 1 t)t) t ~ 2.90 Hole. 223 6885 ii 0.01 4 2.92 224 6914 ~) 0.01 4 1 2.90 225 6944 U 0.07 26 2.92 I lated it in . 225.1 6975 i) 0.01 4 it 2.96 PUP 225.2 6978 U 0 0 ~~ 2.32 AVA'BPL' Ported Ni le w Sleeve 225.3 6980 a 0.00 1 1 2.96 PUP 2 5.4 698 U l) n N A k r e l I 225.5 6995 it 0 U n N A Baker'FB-1' Permanent Packer 225.6 6998 i ~ 0.00 1 2.34 2.87 "PUP 225.7 7001 u 0 U ~~ 2.25 Camco'D' Ni le NO GO 225.8 7003 ~? 0.01 l) 2.39 2.875" PUP 225.9 7010 i~ 0 U I1 N A Shear-Out Sub _ Penetration Body Metal Loss Body Page 5 PDS Report Cross Sections ~~~ ~~ „ Well: 1A-05 Survey Date: September 27, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.2 ppf J-55 BTC Analyst: M. Lawrence __ _ __ __ Cross Section for Joint 222 at depth 6866.66 ft Tool speed = 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 92 ~° Tool deviation = 4 ° Finger 20 Penetration = 0.326 ins Hole 0.33 ins = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 PDS Report Cross Sections ~~ ~~ „ u Well: 1A•05 Survey Date: September 27, 2008 Field: Kuparuk 7001 Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.2 ppf 1-55 BTC Analyst: M. Lawrence Cross Section for Joint 26 at depth 808.203 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 Tool deviation = 5 ° Finger 20 Penetration = 0.08 ins Corrosion 0.08 ins = 31% Wall Penetration HIGH 51DE = UP • • Cross Sections page 2 ~ ~ ,_ ;.. . .:. £one~~t5p~ Atka, Inc, KRU 1 A-05 ns , API: 2062700 Wed 8W A TS: 3 88'28 3SSV . TRDP O . ~ 1987 TD: 3 7675 SSSV AnredarFiukl: LastWlO: 224n987 RevR~son: PostFCOTag,Set (1808-1810, P T 00:3.500) Ratetence Ret patB: ~ t date: 6/t 1!2008 7138 TD: L~tT 7875 Last T Date: 5/9/2008 Max Hole : 50 t~ n Size To Bottom TVD VYt tirade Thread CONDUCTlK2 20.000 0 80 80 94.00 CAS 13 0 3095 2632 72. L-80 . CAS 9. 0 6633 5810 47.00 L-SD t LMIER 7.000 6284 7151 6327 2fi.Q0 K56 T ~ °._ _ :. . SRB T TVD 1Alt tirade 171read 3.500 0 8998 8174 9.20 8 C 2875 6998 10 618fi &50 J-55 8RD t~t101tfS=.cif ltnltlB . interval TVD Zone Status Ft SPF Oats T Comment 6822 -6929 -fi105 3,C-2,G1, 1 7 4 813!1981 PERF 1 20 deg. Ph, 4• Vann Guns B 1~b2 -8958 8128 - 8132 T B 4 4 9/3ft981 PERF 120 . Ph 4• Vaeu~ ~ X62 - 6138 - 6144 UNIT B 6 4 9/311981 IPERF 1 20 . Ph 4' Vann Guns 7013 - 7015 6189 - 6191 UNITE 2 0 616!1986 7062-7066 6228-6232 AS 4 4 9pl198t IPERF 1 20 .Ph 4'VannQums 7065 -7092 6241- A-4 27 4 9/'3/1981 PERF 1 20 . Ph 4' Vann Guxs Date Comment TO 3 - 7 erd - ;., WveS St MD TYD Matt Mfr Man Type V Mtr V Type V DD t.atcit Pant ' T'RO ate Vtv Run Cmnt 1 2653 24fi2 eo KBUG DMY 1.0 BK .1100 0 12n1n981 2 44 3741 Cameo KBUG DMY 7. 0.0~ 0 12n1n99t 3 5033 4253 Camco KBUG 1.0 BK 0.000 0 12l11n99t ,,i 4 5345 4546 Camco KBUG OMY 1.0 BK 0.000 0 t?!11/1991 ~ S 5687 4874 Cmneo KBUG DMY 1.0 BK 0.000 0 12/11/199t SBR (s71sa72o, "~ 6 6028 5208 Cemco DMY 1.0 BK 0. 0 12)11/1991 OD_3_~ 7 6331 8609 Camco KBUG Y 1.0 BK 0.000 0 12n1/t991 ! B 6676 6853 Otis 3. 1. DM t.5 RO-5 0 311 1997 prl4ts7~as, St IMD TVD Man Mfr Man Type Y Mfr V Type V OD !.etch Port TRO Date Viv oos.tsst Run Ctrett ~ 9 6 784 59 60 Camco UG DMY 1.0 BK 0.000 0 12/7/1998 Closed -` .~ JEYkELRY ~ r'~ ` - . TYD ~ 1809 1737 SSSV _ CammTRDP-1A -~ 2.813 6719 5&96 SBR Baker 2.873 6745 5922 PKR Bakar'FH' RETR. 3.000 -- 6830 6006 PATCH SET BOTTOM (BAIQ;R 35 WL BTM SNAP LATCH) P TCH PACKER A 6888' 1.900 ~ REFERC-LACED TO SLB 10l26f0Y LEAK DETECT LOG - 5!12!1006 (~,~) SET SNAP LATCH ASSEMBLY ON TOP OF PACKER ~ 6!188' RKB - 6/7i~06 SET BAKER 36 "KB' UPPER STRADDLED PATCH PACKER AT 6830FT. TOTAL PATCH LENGTH6830'-6888'. PATCH 1.90° EUE SPA(3=R PmE atIFT ID 1.556•. 3" GS FISHIl~K3 NECK t1P. SEE PATCH SCHEMATIC IN WORKB~Ki FM.E FOR Pert ) - SNAP LATCH - 6/8Pt006 6976 6152 SLEEVE-C 2.75AVAB CLOSED set4127/20~ 2.3 Pert 6152 IP AVAP T~NIP 2.750 '~) 6989 BS PKR Baker'FB-1' 3.000 7004 6180 NIP Camco'D'N' GO 22511 SLEEVEC 7009 B9 Camoo 2.441 1~1. 7oto 9s rn 2.4at oo-z - :~ F LSH , Comment aKR n6 6 a vann Gwr .81r ( OD:8 t56) ,..:.„ , ,~ . . NOM 1 Unable: to Estat4tsh 1 Ra Sk>Mr LEAK See WSR 3/29/98 ~ ' (7004-7006 1 MD & F 6854 0D2.876) SpS ()009.7010, 002.87'5) CetI191t (7019~7D1~ PeA (7062-7058) Dorf (7065.7092) 4° Vorn Cixr - p18B-7187, OfJ:2.000) • -- , / (1 ~ , i 1 i~1 I ~ i tl \ f r-~~ ! SARAH PALM_ GOVFan-nQ AI.ASS-A OII, AIQD ~'irA S 33 , ~t COZITSER'QATIOIIT COMI~IISSIOIQ 3 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Daniel Hemnann Wells Group Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Wield, Kuparuk River Oil Pool, Sundry Number: 308-225 ~~N~~ J U N ~ 4 Dear Mr. Hemnann: $~_~b~ ~---. 1A-05 2008 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of June, 2008 Encl. ~"~~ .Q~ ~ 6 as~o~ o STATE OF ALASKA ~,l U ~ ~ ~ !~ ~ ~ ~ .~G r~ 4 ALASKA OIL AND GAS CONSERVATION COMMISSION b i ,q ~ ~riu ls{)I~rii~ld~ APPLICATION FOR SUNDRY'~~~s~!-,L;,~ 20 AAC 25.280 ' ~``' 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ er Q Alter casing ^ Repair well ~~ Plug Perforations ^ Stimulate ^ Time Extension ^ Set Patch / Change approved program ^ Pull Tubing ~~$erforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 181-104 3. Address: Stratigraphic ^ Service 0 ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20627-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS NO ^~ 1A-05 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25647 RKB 100' Kuparuk River Field !Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7675' ~ 6850' ~ 7138' 7186' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 80' 80' SURFACE 2995' 13-3/8" 3095' 2613' PRODUCTION 6533' 9-5/8" 6633' 5810' LINER 867' 7" 7151' 6327' Perforation Depth MD (6822'-6s2s', ss52'-ss5s', Perforation Depth ND (ft 5sss'-6105', s12b'-6132', Tubing Size: Tubing Grade: Tubing MD (ft): 6962'-6968', 7013'-7015', 7052'-7056', 7065'-7092' 6138'-6144', 6189'-6191', 6228'-6232', 6241'-6268' 3.5" / 2-7/8" J-55 6998' / 7010' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER'FH' RETR. ; BAKER'FB-1' PERM. pkr= 6745' ; 6989' Camco TRDP-1A SSSV= 1809' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 3, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the fo egoing is true and correct to the best of my knowledge. Contact: Daniel Herrmann @ 263-4119 Printed Name a ~ I mann Title: Wells Group Engineer Signature Phone 263-4119 Date Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: i~ ~'"~, 1~~~ „~t~El ;~ ~) 1f~Q~ APPROVED BY ~ / 6 Approved by' COMMISSIONER THE COMMISSION Date: (~ U Form 10-4~e sed Oi6/~00 Submit in Duplicate • • We111A-OS Proposed Tubing Patch Install for Injection Profile Modification lA-OS is a selective injector with 3.5" tubing. An IPROF ran on 7/22/04 indicated most PWI was entering the C sand through tubing leaks at 6854' and 6883'. A patch was run and set over the leaks on 06/08/06 at 6830' to 6888'. An IPROF run on 8/27/07 showed the patch was leaking 50% to the C sand. The 58' leaky tubing patch will be removed and another 58' tubing patch will be set in its place to return the lA-OS well back to injection as an `A sand only' injector. i Recent Work Complete: 8/27/08: IPROF run and patch found to be leaking 50% to the C-sand. The exact location of the leak on the patch undetermined. Proposed Tubing Patch Install Procedure: Slickline: I . RU Slickline. RIH and pull Baker retrievable patch set @ 6830'-6888' E-line: 2. RU E-line. RIH with patch assembly consisting of 3.5" packer, 23' of 2 3/8" spacer pipe & snap-latch receptacle. Set packer with spacer pipe @ 6898'. This will place the lower packer ~15' below the lower tubing leak. Slickline: 3. RIH with upper patch assembly consisting of snap-latch stinger, 21' of 2 3/8" spacer pipe, and 3.5" packer. Sting and latch into snap-latch receptacle and set top packer at 6840'. This will place the upper packer ~15' above the top the tubing leaks, completing the patch at 6840' to 6898'. Return the well to `A sand only' injection and obtain valid injection test. JDH 6/24/2008 ~~ CpncacCtPhillpS Alaska, ~t?C= KRU 1A-05 1A-05 API: 500292062700 Well T e: iNJ An le TS: 3 de 6826 SSSV T : TRDP Ori Com letion: 9!4/1981 An le TD: 3 de 7675 SSSV (1809-1818 Annular Fluid: Last W/O: 2/24/1987 Rev Reason: Post FCO Tag, Set PATCH Assembl OD:3.500) Reference Lo Ref Lo Date: Last U date: 6/11/2006 Last Ta : 7138 TD: 7675 ftK6 ~,,;, Last Ta Date: 5/9/2006 Max Hole An le: 50 de 2100 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 80 80 94.00 H-40 SUR. CASING 13.375 0 3095 2632 72.00 L-80 PROD. CASING 9.625 0 6633 5810 47.00 L-80 LINER 7.000 6284 7151 6327 26.00 K-55 7ubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 6998 6174 9.20 J-55 BTC 2.875 6998 7010 6186 6.50 J-55 EUE 8RD PerforationsSu mma Interval TVD Zone Status Ft SPF Date T e Comment i 6822 - 6929 5998 - 6105 C-3,C-2,C-1, B 107 4 9/3/1981 IPERF 120 deg. Ph, 4"Vann Guns 6952 - 6956 6128 - 6132 UNIT B 4 4 9/3/1981 IPERF 120 d . Ph 4" Vann Guns 6962 - 6968 6138 - 6144 UNIT B 6 4 9/3/1981 IPERF 120 d . Ph 4" Vann Guns 7013 - 7015 6189 - 6191 UNIT B 2 0 6/6/1986 7052 - 7056 6228 - 6232 A-5 4 4 9/3/1981 IPERF 120 d . Ph 4" Vann Guns 7065 - 7092 6241 - 6268 A-4 27 4 9/3/1981 IPERF 120 d . Ph 4" Vann Guns _ _ Stimulations & Treatments Interval Date T e Comment 7013 - 7015 6/6/1986 Cement Gas Lift M andrelsNahres St MD ND Man Mfr Man Type __ V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2853 2462 Camco KBUG DMY 1.0 BK 0.000 0 12/11/1991 2 4476 3741 Camco KBUG DMY 1.0 BK 0.000 0 12/11/1991 3 5033 4253 Camco KBUG DMY 1.0 BK 0.000 0 12/11!1991 4 5345 4545 Camco KBUG DMY 1.0 BK 0.000 0 12/11/1991 5 5687 4874 Camco KBUG DMY 1.0 BK 0.000 0 12/11/1991 SBR (6719b72o 6 6028 5208 Camco KBUG DMY 1.0 BK 0.000 0 12/11/1991 OD:3 500) 7 6331 5509 Camco KBUG DMY 1.0 BK 0.000 0 12/11/1991 . 8 6676 5853 Otis 3.5 X 1.5 DMY 1.5 RO-5 0.000 0 3/10/1997 PKR :In'ection M andrelsNalves ,. '. (s7a5~7as, oD:s.15s> St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 9 6784 5960 Camco KBUG DMY 1.0 BK 0.000 0 12!7/1998 Closed Other lu s e ui . `etc. -JEWELRY De th TVD T e Descri lion ID 1809 1737 SSSV Camco TRDP-1A 2.813 6719 5896 SBR Baker 2.813 6745 5922 PKR Baker'FH' RETR. 3.000 Perf (6822929) ert (6952956) I I - 6830 6006 PATCH SET BOTTOM (BAKER 35 WL BTM SNAP LATCH) PATCH PACKER AT 6888' REFERENCED TO SLB 10/26/02 LEAK DETECT LOG - 5/12/2006 SET SNAP LATCH ASSEMBLY ON TOP OF PACKER @ 6888' RKB - 6/7/2006 SET BAKER 35 "KB"UPPER STRADDLED PATCH PACKER AT 6830FT. TOTAL PATCH LENGTH 6830'-6888'. PATCH 1.90" EUE SPACER PIPE DRIFT ID 1.556". 3" GS FISHING NECK UP. SEE PATCH SCHEMATIC IN WORKING FILE FOR SNAP LATCH - 6/8/2006 1.900 6976 6152 SLEEVE-C 2.75 AVA BPI CLOSED set 4/27/2006 2.320 Perf 6976 6152 NIP AVA PORTED NIPPLE 2.750 (6962E968) 6989 6165 PKR Baker'FB-1' PERM. 3.000 7004 6180 NIP Camco'D' Ni le NO GO 2.250 SLEEVE-C , 7009 6185 SOS Camco 2.441 (6976977, I L 7010 6186 TTL 2.441 oD:2.750) Fish `- F ISH De th Descri lion Comment PKR 7186 4" Vann Gun 322.86' Ion (ssssssso' OD:6 156) General Notes . Date Note NIP 3/29/1998 Unable to Establish In' Rate; Ve Slow LEAK See WSR 3/29/98 (70047005 10/26/2 002 FOUND LEAKS 6854' MD & 6883' MD , OD:2.675) SOS (7009-7010, Cement (7013-7015) Pert (7052-7056) Pert (7065-7092) 4" Vann Gun (7186-7187, OD:2.000) z_ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken -- 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk . Log Description Date BL Color CD 4 1007 08/30/07 Se hAnnaft"...,,,, ,_1&.,. \ ,I I, . NO. 4398 S'Gfì.NNED SEP 18 Z007 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth /l ~ Well Job # 2H-02 11846438 INJECTION PROFilE l )ï:l' 1"64- 07-"~ 08/21/07 1 2P-427 11846437 INJECTION PROFilE -¡ ,,(' ,.Q~':4 - nJ-'$( 08/20/07 1 1A-07 11850429 INJECTION PROFilE ,) I c.- /15' l - /39 08/22/07 1 10-08 11850427 SBHP SURVEY I~ -O.<';}~ 08/20/07 1 3A-09 11850426 GlS ¡q / - --,z.¡z¡ 08/20/07 1 2W-09 11850428 INJECTION PROFilE U:r~ 1"ir4- .;;>tOl 08/21/07 1 1 l-17 11839642 INJECTION PROFilE UT(' ,~ 1-(")4":1, 08/23/07 1 2M-13 11839643 PRODUCTION PROFilE 08/24/07 1 1G-04 11837494 INJECTION PROFilE ()11". I~~-J~I 08/24/07 1 2N-350 11839644 DDl ;::)(:)1 - /--:).< 08/25/07 1 2N-350 11839645 PM IT .[J¡.,. I _ ~ ,<; 08/26/07 1 1A·05 11839646 INJECTION PROFilE I )T (" _ / i( 1 -IA"I-I 08/27/07 1 2H-15 11837498 INJECTION PROFilE U::rC- ~-t\"xL 08/29/07 1 2A-04 11839649 INJECTION PROFilE I) :r:(\~ 11r</ - á.~~ 08/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~, 1/ . 1~efr¡ 11?¡( {)? ? DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-05 KUPARUK RIV UNIT IA-05 Src: Inspector \%\",\01.\' FROM: Bob Noble Petroleum Inspector NON-CONFIDENTIAL Reviewed By: /p P.I. Suprv ---.J",fZ.- Comm Well Name: KUPARUK RIV UNIT lA-OS T"~:; :'~um: mitRCN07071YI:;~')51 Rei Insp Num: API Well Number: 50-029-20627-00-00 Permit Number: 181-104-0 Inspector Name: Bob Noble Inspection Date: 7/15/2007 Packer Depth l'r.;!est Initial 15 Min. 30 Min. 45 Min. ~----,~~~-- Well I IA-05 IType Inj. I W P.T.Di 1811040 iTypeTest ¡ SPT --~~ Interval 4YRTST P/F Notes: TVD i Test psi : P ./ 5922 A IA-;-!3()O {' OA I 170 I Tubing 1 2150 2800 I I 2800 i 2800 I I I 70 ---¡-~-¡- I -1---------l-~-- 2'';0 I 2150 I i I I 60 Min. -- 2800 I 170 I ---L.____-+ I 2150 I I -. -- sCANNED AUG 0 6 2007 Friday, July 20, 2007 Page I of 1 ~ ~ MEM 0 RAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '1(at,¿ì b/ {( 04 P.I. Supervisor I \ DATE: Wednesday, June 02, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-05 KUPARUKRIVUNIT IA-05 /61-/0 Lf- FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :JlJe--- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT lA-OS API Well Numbe Permit Number 50-029-20627-00-00 Inspector Name: 1811040 Inspection Date: Chuck Scheve 5/30/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: IA-05 Type Inj. P TVD 6850 IA 1250 2080 2050 2050 P.T. 1811040 TypeTest SPT Test psi 1480.5 OA 125 125 125 125 Interval 4YRTST P/F P Tubing 1000 1000 1000 1000 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 02, 2004 Page I of I STATE OF ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate __ Plugging Alter casing Repair well 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska, lnG, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic ~ Service 4. Location of well at surface R10E, UM R10E, UM R10E~ UM 675' feet 850' feet Plugs (measured) 899' FSL, 311' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1250' FNL, 1172' FEL, Sec. 7, T11N, At effective depth 1252' FNL, 1189' FEL, Sec. 7, T11N, At total depth . 1242' FNL, 1213' FEL~ Sec. 7, T11N~ 12. Present well condition summary Total Depth: measured 7 true vertical 6 feet Junk (measured) feet Effective depth: measured 71 51 ' true vertical6 327' Casing Length Size Conductor 8 0' 2 0" Surface 30 64' 13 3/8" Production 6 6 0 4' 9 - 5 / 8" Cemented 20 Sx PF 1600 Sx Fondu & 900 Sx Class G & 300 AS II 280" Sx Class G 6952'-6956',7052'-7056' 6128'-6132', 6228'-6232', Liner 1 3 8 6' 7" Perforation depth: measured 6822'-6929', true vertical 5998'-6105', Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J-55, tubing tail @ 7010' Packers and SSSV (type and measured depth) FHL pkr @ 5891', FB-! pkr @ 6989', TRDP SSSV @ 1791' 13.' Stimulation or cement squeeze summary Convert well to water injection. Intervals treated (measured) N/A ' Treatment description including volumes used and final pressure N/A OR IGF N Perforate Other X 6. Datum elevation (DF or KB) feet lOO' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-05 9. Permit number ~1-104 10. APl number 50-029-20627 11. Field/Pool Kuparuk River Oil Pool Vann gun fish @ 7186" WLM Measured depth True vertical depth 80' 80' 3O95' 2613' 6633' 5810' 6284'-7670' 5462'-661 3' 7065',7092' 6241'-6268' 6962'-6968', 6138'-6144' REEEIV£D JUN 1 0 1992 Alaska 0il & Gas Cons. C0m~iSS'tOt~ Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Averane Production or Injection Dat~ OiI-Bbl Gas,Md Water, Bbl Casing Pressure 400 1200 0 - 1200 - 0 - 0 - 2900 1000 Tubing Pressure 35O 2200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations. 16. Status of well classification as: Water Injector X Oil __ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 suBMIT IN DUPLICATE WELL ARCO Alaska, Inc~ ) Subsidiary of Atlantic Richfield Compan,~ / R ,~' IPBDT r"3NTRACTOR REMARKS , FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDAYS I DATE ,ecc,.,m #/?.,.a,¥ Alaska Oil & Gas Cons. Anchorage F'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather JTemp' J ChUl Fact°r I Visibility IWindVel'lSignedReport OF OF miles knots 'ARco Alaska, Int..(-)'. ( ' WELL SERVICE REPOR'I' R ¢E!VI::'D JUN 10 1992 ^lasl(a 0il & 8as Cons. CommissiOn Anchorage r"l CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ARCO Alaska, Inc. ~ Subsidiary of Atlantic Richfield Compaf WELL SERVICE REPOR' , ,cMARKS OPERATION AT'REPORT T~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knoto ~. AH~,U Alaska, Inc. ~ Sul:)stdiar~ of Atlantic Ricl~field Company .il =BDT 1EMARKS WELL SERVICE REPOR FIELD. DISTRI DAYS DATE OPERATION AT ~EI~T TIME 113o /Z4~ l~lH ~OK-I & l"i~V. SET~. 63Z4'WL&POH. 1550 ~IH ~ oK-l Ass'~. LATCH Gt.V ~ 6015' WL ~ POH' . R/H"~OM-I ~ ~.",55. LATCH I'/z" OV (RO-5) ~ ~?I'WL~POH. ~IH '~OK-~ ~v 1'/4'JD$. LATCH I" GLV ~ 6$Z4'wL &~ PON. RIH ~ J~ DV oN OK-J A55'f. 5ET ~ ~3~5' WL ~ POH . 5WA~ VALVE ' / '/' jU~ 1 C 1992 Alaska Oil & ~as r"'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Signed knots KDOS MORNINO WELL REPORT FOR 03/19/92 DRILLSITE lA PACE ! W Z S E 0 T L N A L E T PRODUCTION WELL STATUS 7" 10" TP TT WC H2S CSO CSO PSI CHK DEC % PPM PSI PSI OAS LIFT STATUS SI CN OAS INJ AH TEMP METER VOLS LI DEC READINO MSCF EB S/I IMPACT C H M 0 R I D EPL S N E BBLS 1 B PR 3 B PR 8 B PR 10 A PR 17 B PR 18 B PR 19 B PR 20 B PR 22 B PR 23 B PR 25 B PR 26 A PR 27 B PR 28 PR 278 176 127 80 150 1200 800 336 176 119 65 50 1300 740 395 176 129 60 50 1100 980 320 104 56 15 40 1300 50 487 176 122 60 175 1420 280 360 176 108 35 0 1425 i00 359 176 138 20 200 2050 550 321 176 80 2 335 176 88 10 383 176 155 78 298 176 112 40 612 176 32 10 322 176 134 65 338 176 72 18 0 980 100 0 1000 680 0 1520 680 50 1100 150 0 1180 500 15 2050 850 0 1100 300 70 65 70 50 0 65 65 70 0 65 0 348 0 0000 0 0 0 14 0 0000 0 0 0 299 0 0430 2 234 2096 355 0 0000 0 0 0 0 0 0000 0 0 0 28 0 0000 0 0 0 52 0 0000 0 0 0 28 0 0000 0 0 0 687 0 0000 0 0 0 0 0 0000 0 0 0 745 0 0000 0 0 0 7O 0 0000 0 0 0 53 0 0000 0 0 0 721 0 0000 0 0 TOTALS: 3400 0 234 W Z S E 0 T L N A L E T 2 B SW 4 A SW 5 B SW 6 B SW 7 B SW 9B SW 11 B PW 12 B SW 13 B OI INJECTION WELL STATUS ALLOW ACT 7" 10" INJ INJ TT CS~ CS~ PSI PSI DEC CHK PSI PSI 2500 2178 81 50 520 ~00 81 25 440 2500 75 20 740 2500 2175 76 50 40 40 4000 1856 77 15 1100 220 2500 2299 156 66 1280 350 2500 1842 76 12 1050 980 4000 3853 100 40 50 200 14 B PW 2500 2123 151 24 400 200 15 B OI 4000 3799 99 30 80 75 16 B SW 2500 1984 76 12 220 260 INJECTION VOLUME INJ INJ METER VOLS VOLS READING BBLS MMSCF 0 4459 0.000 0 9 0.000 ° °°° 0 000 0 4286 0.000 0 4065 0.000 0 4000 0.000 0 6779 0.000 0 0 9.373 0 2266 0.000 0 0 15.636 0 7558 0.000 S/I C H M O R I D S N E 0000 0 0000 0 0000 0 0000 0 0000 0 0330 71 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 TOTALS: SWI: 31311 + PWI: 6266 = JUN t 0 1992 Alaska.Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS~ CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 JUNE 9, 1992 WATTY STRICKLAND ARCO ALASKA IN. P O BOX 1900360 ANCHORAGE, ALASKA 99510 RE: 85-0163 81-0071 81-0096 81-0104 86-0141 KUPARUK RIVER UNIT KUPARUK RIVER UNIT KUPARUK RIVER UNIT KUPARUK RIVER UNIT KUPARUK RIVER UNIT 3J-2 lA-2 lA-4 lA-5 2T-2 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR FOR THE REFERENCED WELLS. OUR FILES ARE MISSING PAPER WORK FOR THE CONVERSION OF THESE WELLS AS I MENTION APRIL 29, 1992 IN A CONVERSATION I HAD WITH YOU . THESE WELLS HAD 403'S SUBMITTED IN NOVEMBER OF 1991 TO CONVERT OIL TO WATER-INJECTORS AND OUR MONTHLY PRODUCTION REPORTS SHOW THESE WELLS W~RE CONVERTED IN NOVEMBER AND AOGCC DIDN'T RECEIVE THE 404'S ONCE THE CONVERSION WAS COMPLETED. THIS MATTER NEEDS TO BE CORRECTED SO OUR FiLE ARE CURRENT AND UP TO DATE.' WOULD YOU PLEASE CHECK THIS PROBLEM AND FORWARD THE APPROPRIATE DOCUMENTS TO ME. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST 1. TYpe 0f'""Request: 2. "Name"o~;"'Operat~r ...... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Aba'r~don_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well Plugging _ Time extension Stimulate Perforate _ Other '6. Datum eleVa'ti~m (DF o'r KB) Change approved program X Pull tubing,. _. Variance 5. Type of Well: Development X Exploratory _ Stratigraphic Service... ~. ....... RECEIVED ARCO Alaska. linc. 3. Address P. O. Box ! 00360, Anchorage,,,,,A,,,K 99510 ~t. Location of well at surface 899' FSL, 311' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1250' FNL, 1172' FEL, Sec. 7, T11N, R10E, UM At effective depth 1252' FNL, 1189' FEE, Sec. 7, T11N, R10E, UM NOV ~ § ~ At total depth ..124_21...FN L, ... 1...2.!3' FEL,. Sec, .7,.T.1.....1..N, R!0E,^~".LI~. ~sk:a 0ii & 6as Cons. Corem 12. Present well condition summary Total Depth: measured 7 6 7 5' true vertical 6 8 5 0' Effective depth: measured 71 51 ' true vertical 6 3 2 7' Casing Length Size Structural Conductor 8 0' 2 0" Surface 3 0 6 4' 13 3/8" Intermediate Production 66 0 4' 9 5/8" 900 Liner 1 3 8 6' 7" Perforation depth: measured 100' RKB.. feet . 7. Unit or Property name Kup.aruk River U...n..!.t ..... 8. Well number 1A-5 ................. 9. Permit number 8.1...-104 10. APl number 50-.0.29-20627 ,,.~Field/Pool Kuparuk River Field ~aruk River Oil Pool feet feet feet feet Ancn0rage Plugs (measured) Junk (measured) Vann Gunn @ 7186' WLM Cemented Measured depth True vertical depth 200 Sx Permafrost 80' 1600 Sx Fondu & 3 0 9 5' 300 Sx ASll Sx CG & 300 SX ASII 6633' 280 SX Class G 7 6 7 0' 80' 2613' 5810' 6613' 6822'-6929',6952'-6956' true vertical 5998'-61 05',6128'-6132' Tubing (size, grade, and measured depth) 3 1/2", 9.5# J-55, tbg w/tail @ 7010' Packers and SSSV (type and measured depth) ,6962'-6968',7052'-7056',7065'-7092' ,6138'-6144°,6228'-6232',6241'-6268' Packer: FHL @ 6745' & FB-1 @ 6,9,8,,9'; SSSV: Camco TRDP @ 1809' 13, Attachments Description summary of proposal _ Detailed operation program _ BOP sketch _ C0n. ver,t ,well, from 0il p, ro.,~,qcer ,to, WAG !njecto,r,., (We!lb0re sche,matic attache,d),,. ........ 14. Estimated date for commencing operation 15. Status of well classification _ December. 1991 Oil m Gas _ Suspended 16. If proposal was verbally approved Name of approver Date approved Service .WAG , Injector '"~7. I hereby certify ihat'the fOregoing ii" ~rue ar~'d"corre~t ":~o' the b'~st'"of my" knowledge. iSigned ~-(~J. ~ Title Ol°~/'~+; ~).~,~ '~"~,~/~ee r- Date /I/I ~ / ~ ..... FOR COMMISSION USE OI~LY COn~iiions of approval': "' Notify C°mmiss'io'n' So 'representaiive 'rnay'wit'n~ss ............ IApproval Plug integrity~ .~P Test _ Location clearance ,Z~z/~,p~'' '~o,~.~.~.~ ~ ...... Mechanical Integrity Test'__ Subsequent form require 10-..~ ~ ORIGINAL SIGNED BY Approved by order of the Commission .... LONNIE O. SMITH Commissioner Date Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE Well; 1A-0.5 Completion Date: 0 6 - 0 9 - 8 6 Spud Date: 0 8 - 1 1 - 81 Maximum Hole Angle:49.5 deg. @ Original Rig RKB: 26.2 All depth are RKB MD to top APl# 50-029-2062700 C Sand: CLOSED A Sand: OPEN 21 00' MD of equipment. Well Type: OIL Tree Type: PRUDHOE FMC GEN 2 5000# Tree Cap Type: OTIS Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: 0 6 - 0 9 - 8 6 Jewelry I SSSV: CAMCO TRDP-1A 2.812" ID @ 1809' 2 SBR: BAKER @ 6719' 3 PKR: BAKER FH @6745' 4 PKR: BAKER FB-1 @ 6989' 5 CROSS OVER: 3.5" TO 2.875" @ 6998' 6 NOGO: CAMCO "D" NIPPLE 2.250" ID @ 7004' 7 SHEAR OUT: CAMCO @ 7009' 8 TUBING TAIL: 2.875" TUBING @ 7010' Minimum ID:2.250" Casing and Tubing Size Weight Grade To_~ Bottom 20" 94# H-40 0' 80' 13.75" 72# L-80 0' 3095' 9.625" 47# L-80 0' 6633' 7" 26# K-55 6284' 7151' 3.5" 9.3# J-55 0' 6998' 2.875" 6.5# J-55 6998' 7010' CASING CASING CASING ~BING TUBING TAIL Gee Lift Information Death Stn# Valve ~ Sz. Latch Port Sz. AID# 2853 1 G/L 1" BK 0.1562 4476 2 G/L I" BK 0.25 5033 3 D/V 1" BK ~ 5345 4 G/L 1" BK 0.25 5687 5 D/V 1" BK 6028 6 G/L 1" BK 0.3125 6331 7 G/L I" BK 0.3125 6676 8 O/V 1.5" RO-5 0.25 Date Run 06-30-88 Production Equipment Death Stn# Model Tvae Sz. Latch VIv/SIv AID# _ - 6784' I GLM D/V 1" BK 6976' 2 AVA 2.75" 3,5" BPL ISO Date Run 06-30-87 11-05-90 7,8 Perforation Data Interval SPF Date Phase FT Zone Comments 6822-6929 4 09-03-81 120 1 07 C34 4" VANN GUNS 6952-6956 4 120 4 B 4" VANN GUNS 6962-6968 4 1 20 6 B 4" VANN GUNS 7052-7056 4 120 4 A5 4" VANN GUNS 7065-7092 4 120 27 A4 4" VANN GUNS Comments: VANN GUNN 322.26' LONG @ 7186' LAST TD: 7089' ON 02-28-90 PBTD: 7151' PBTDSS: 6227' LAST REVISION DATE: 07-18-91 ARCO flaska, In(~~ Post Office i~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 25, 1987 Transmittal #6038 RETURN TO: ARCO Alaska, Inc. Attn:~ Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted,.herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~IA-1 Kuparuk Well Pressure Report(Otis) 8-12-87 lA-5 Kuparuk Well Pressure Report(Otis) 8-12-87 Receipt Acknowledged: DISTRIBUTION: oons. COmmiss~on Anchorage Unocal D & M State of Alaska BPAE Chevron Mobil SAPC ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfieldCompany ARCO Alaska,~ .... Post O~,..e Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal # 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lA-5 Static Well Pressure Report 6-8-87 2T-13 PBU Well Pressure Report 7-11-87 2A-11 PBU Well. PressUre. Report 4-16,18-87 2U-13 Pressure Buildup Survey 4-25-87 2C-16 GLM Survey & Temp Gradient Survey 4-13-87 Receipt Acknowledged: DISTRIBUTION: Date: BP Chevron MObil SAPC Unocal State of Alaska..~.:: DAM ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. '~' Post OfficeBt~,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal # 5898 RETURN TO: - ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ' ---3I-3 ~31-14 ~31-14 /~31-14 .__31-12 --lA-5 -~iA-16A --3N-17 --3N-18 CET 5-19-86 6815-7828 CET 5-4-86 6690-8293 CBL/CBT 5-5-86 6590-8292 CBL 5-5-86 6588-8295 CET 5-4-86 6789-7344 CET 6-6-86 6270-7024 CET 6-6-86 3991-6976 CET 6-10-86 7446-8902 CET 6-10-86 8742-10500 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Date: BPAE Chevron Unocal ~ault (film) ARCO Alaska, Inc. is a Subsidiary of AllanlicRIchfleldCompany ARCO Alaska, ~nc. ~7 276 1215 .. September 2, 1986 Mr. C. V. Chatterton Alaska 0i~ and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska Subject- Kuparuk River Field _ Production Surveys Dear Mr. Chatterton: In compliance with Rule 9 of Conservation Order Number 173, Kuparuk River Field Rules, we are hereby submitting production survey informa- tion for the second quarter of 1986. Production survey information consists of production logs and production tests as identified in Attachment 1. Production logs {spinners} identified in this attachment will be sent under separate cover. Note that several initial spinners -': not previously submitted to the State are being submitted at this time. _If you have any question<, concerning the information reported, please contact me at (907) 263-4935. Sincerely, _- :'= . V. L. F~rguson Senior Operations Engineer VLF-pg:O074 Oil & Gas Cons. Co~missicn . Alaska. :nC. i~. a Sub~'~;e,,v O! Atiant.;clRichfiel¢Co~-.~any ?.c .r. . f. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] Recomplete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage~ AK' 99510 4. Location of well at surface 899'FSL, 311'FWL, Sec.5~ T11N, R10E~ UN At top of productive interval 1250'FNL~ 1172'FEL~ Sec.7~ TllN, R10E~ UN At effective depth 1252'FNL~ 1189' FEL~ Sec.7~ T11N, R10E~ UM At tlO~%12d'eFDl¥~, 1213'FEL, Sec.7, T11N, R10E, UN 5. Datum elevation (DF or KB) RKB I 00 ' 6. Unit or Property name KuDaruk River IJ13il; 7. Well number 1A-5 8. Approval number Permit #81 -1 04 9. APl number 50-- 029-20627 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured 7675 feet true vertical 6850 feet Effective depth: measured ~ ~,,~ ~/ feet true vertical feet C%Sjnn~ Length Size uctor ~ 80' 20" Surface 3064 ' 13-3/8" Producti on 6604 ' 9-5/8" Li net 1 386 ' 7" Plugs (measured) None Junk(measured) Vann gun fish @ 7186'WLM Cemented Measured depth True Vertical depth 20 sx PF cmt 80 'MD 80'TVD 1600 sx Fondu & 3095'HD 2613'TVD 300 sx AS II 900 sx Class G & 6633'MD 5810'TVD 300 sx AS II 280 sx Class G 6284'-7670'MD 5462'-6613'TVD 'Perforation depth: measured 6952'-6956'MD 6962 ' -6968 'MD true vertical 6128 ' -6132 'TVD 6138 ' -61 44 ' TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 7010' P~c~rsp ~nrd L~Sb~Y4(.~y,o,e aFnBd- measured depth) 1 pkr (~ 6989', & TRDP SSSV ~ 1809' 7052'-7056'MD 7065'-7092'MD 6228'-6232'TVD 6241'-6268'TVD 6822'-6929'MD 5998'-6105'TVD RECEIVED 12. Stimulation or cement squeeze summary 13. J U L - l°88 Intervals treated tm, easured) 7013' - 701 Alaska Oil & Gas Cons. Commission Treatment description including volumes used and final pressure A~chorao~ 50 sx Class G Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Prior to well operation Subsequent to operation 14. Attachments ([Jompletion Well History) Daily Report of Well Operations [~ Water-Bbl Casing Pressure Tubing Pressure Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed Form 10-404 Rev. ~--1'-85 Title (DAM) $W0/060 Date Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Inst~uctions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 606031 Pool 102 Operator ARCO Alaska, Inc. ICounty. parish or borough North Slope Borough Lease or Unit ADL 25647 Title Recompletion State Alaska JWell no. 1A-5 API 50-029-20627 IARCO W.I. Prior status if a W.O. Spudded or W.O. begun Workover IOate IHour 6/1/86 Date and depth as of 8:00 a.m. 6/01/86 thru 6/02/86 6/03/86 6/04/86 6/05/86 6/06/86 6/07/86 thru 6/09/86 Th~a~ove is correct Complete record for each day reported 1630 hrs. 56.24% 7" f/6284'-7670' 718.6' PBTD, Circ ann 9.5 ppg NaCl/NaBr Accept rig @ 1630 hfs, 6/1/86. Pull dummy f/GLM @ 6638' DPM, RD S/L unit. Bullhead killed tbg w/9.6 ppg NaC1/NaBr & Litesal pill. 7" f/6284'-7670' 7186' PBTD, POOH w/3%" tbg 9.5 ppg NaCl/NaBr Displ ann to 9.6 ppg brine, C&C; losing fluid. ND tree, NU & cst BOPE. Unsting f/SBR, circ & water back brine to 9.5 ppg; well static. POOH, std back 3%" tbg. 7" f/6284'-7670' 7186' PBTD, Rev CBU 9.5 ppg NaC1/NaBr POOH w/3%" tbg. PU pkr retrv'g tl, RIH w/3%" DP, wsh over SBR, pull pkr loose, CBU. 7" f/6284'-7670' 7186' PBTD, Prep to sqz cmt 9.5 ppg NaC1/NaBr Pull pkr. RU Schl, RIH, perf @ 4 SPF f/7013'-7015' WLM. Make 6.00" gage ring/JB rn to 6730', RD Schl. Rn 6.125" bit/7" csg scrpr. RIH, set CR @ 6990'. RIH to sqz cmt. 7" f/6284'-7670' 7186' PBTD, Circ & filter brine 9.5 ppg NaC1/NaBr TIH w/stinger. RU BJ, est IR @ 2/5 BPM. 2000 psi Sqz'd 50 sx C1 "G" cmt, POH w/stinger. RIH w/bit, drl up retnr & cmt to BP. Circ& filter brine. 7" f/6284'-7670' 7151' PBTD, Displ 3%" compl w/diesel 9.4 ppg NaC1/NaBr CO cmt. Rn CET log f/7040'-6770', RD Schl. RIH w/R-3 pkr, set @ 6990', tst sqz perfs to 2000 psi & lnr lap to 2500 psi, POOH. RIH, DO BP, trip f/csg scrpr, filter brine, POOH. RU Schl, RIH, set pkr @ 6989'. RU & rn 225 its, 3%", 9.2#, J-55 BTC compl w/SSSV @ 1809', FB-1 pkr @ 6989', seal assy btm @ 6994', FHL pkr @ 6745', & TT @ 7010'. ND BOPE, NU & tst tree. Displ well to diesel. RECFtVED Drilling Superviso~tagka 0ii & G~$ CarTs. C0mm~s. For form preparati,e~n'd d~bution, ~ see Procedures IV(anu~l, Section 10, Drilling, Pages 86"~1~ 87. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 603031 Pool 102 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 6/10/86 Date and depth as of 8:00 a.m. County or Parish Lease or Unit Tte A.R.Co. Date Complete record for each day reported Old TD New TD Released rig Date 1600 hrs. Classifications (oil, gas, etc.) O±l North Slope Borough ADL 25647 Accounting cost center code State Alaska Recompletion API 50-029-20627 56.24% JWell no. lA-5 6/1/86 7" f/6284'-7670' 7151' PBTD, RR Diesel Fin displm't, set BPV. Iotal number of wells (active or inactive) on this I Dst center prior to plugging and bandonment of this well J our Prior status if a W.O, 1630 hrs. RR @ 1600 hfs, 6/9/86. PB Depth 6/9/86 Knd of rig Type completion (single, dual, etc.) S lng le Move to iH-Pad. Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data RECEIVED 7151' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected _. The ab~t~s correct Drilling, Pages 86 and 87. ( Ui'L STATE OF ALASKA ' 'C~~' ' ~' ALASKA AND GAS CONSERVATION ,v~MISSION WELL COMPLETION oR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~L, OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2.Al~rr~e/~{ Op. erator. 7. Permit Number asKa, Inc. 81-104 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20627 4. Loc~tion of v~l~ a~t surface 9. Unit or Lease Name 899 FSL, FWL, Sec.5, T11N, RIOE, UN Kuparuk River Unit ~%~(~p Producino Interval 10. Well Number FNL, 1T72' FEL, Se¢.7, T11N, RIOE, UM lA-5 F~_p; l l. Field and Pool ~;~r~).}al h1213' FEL, Sec.7, TllN, R10E, UN Kuparuk River Field 5.1%l(~v~atl~OKnBin feet (indicate KB, DF, etc.) I 6.ADLLease25647Designation and Serial No. Kuparuk River 0il Pool I 1%8~tleZ~31udded 13. Date T.D. Reached 14. Date COMP., Susp.'or Aband. [1§. Water DePth, if offshore 16. No. of Completions 08/26/81 09/04/81' N/A feet MSL 1 I 17. Total Depth (MD+TVD) 18. Plug B~ck Depth (MD+TVD) 19. Dire~:tional Sur'vey 20. Depth Where Sssv set I 21. Thickness of Permafrost 7675'MD,6850'TVD 7151 'MD,6327'TVD YES)~ NO [] 1809 feet MDI 1650' (approx) 22. Type Electric or Other Logs Run BCHS/DIL/GR, FDC/CNL/NGT/Cal, CBL/VDL/CCL/GR, Gyro, GET/GE 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:" 94.0# H'40 Surf ...... ~u' " ~:50" ...... 200 sx Permafrost ' ' -1~-3/~,' /z.O# L-§0 Surf 3095' 17-1/2" 16'00 sx Fondu & 300 Sx ~S I1' ~-~/~" ~7.0# L-80/500-95 Surf 6633' 12-1/4" 900 sx Class G & 300 sx AS II /" 2b.U# K-b5 6284' 7670' 8-1/2" 280 sX C1 ass 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) 6822 ' -6929 'MD 5998 ' -6105 'TVD 3=1/2" 7010' 6745 ' & 6989 ' 6952 ' -6956 'MD 6128 ' -6132 'TVD 6962 ' -6968 'MD w/12 spf 6138 ' -6144 'TVD 26. ACID, FRACTURE, (~EMENT SQUEEZE, ETC. 7052',7056'M~ 6228 '-6232 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7065 '-7092 'MD 6241 '-6268'TVD See SUndrY' NOtice, dated 7/21/82 for fracture data. 7013' - 7015' 50 sx Class G 27. PRODUCTION TEST Date First ProduCtion I Method of Operation (Flowing, gas lift, etc.) ......... 1 2/26/8iI F1 owing Date. of Test' "HOurs Tested ' ' PRODUCT ON FOR oIi~,BBL GAS'-iVICF WATER-BBL . CHOKE SIZE I GA'S~OI[ RATIO' 1/30/82 11 hrs. TESTPERIOD e 666 293 -- 176/64 I 473 cALCuLATED Ftcw Tubing Casing Pressure OiL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 145 -- 24-HOUR RATE -~ 3010 1424 -- 25° ~ , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas Or'water. Submit core chipsl Core Analysis: #1: 6796'-6856'; cut and recover 60' #4 6976'-7036'; cut 60' and recover 59.5' #2: 6856'-6916'; cut and recover 60' #5: 7036'-7079'; cut 43' and recover 43.8',%~) ~C[IVED #3: 6916'-6976'; cut 60' & recover 57' #6: 7079'-7170'; cut 9!' and recover 91' J U N 2 6 Alaska Oi~ ~ Gas Cons. Commission Anchorage ........... ~ ~.~.~.. z, ............ Form 10-407 N01E:'Well was recompleted 6/9/86. WC1/070 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 6824' 5997 ' N/A Top Upper Sand 6827' 5998' Base Upper Sand 6850' 6026' Top Lower Sand 7044 ' 6215 ' Base Lower Sand 7092' 6291' Base Kuparuk 7133' 6305' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ., ~ ~ Associate Engineer Signed ~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well Completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show t:he producing intervals for only the interval reported in item 27. Submit~a separate form for each additional interval to be separat'~lY 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 ATTACHMENT II Drill Site lA Wel 1 No. 1A-4 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Loo Date Dri 11 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB Site Well No. Log Date 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 !1/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Dri 11 Si te 1C Well No. 1C-1 1C-2 1C-3 1C-4 1C-5 1¢-6 1C-7 1C-8 ' .Log Date 5/9/8i 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 "; 11/30/81 5/t9/81 5/21/81 Drill Site Well No. Log Date 1D 1D-1 ~ 1/80 5 / 23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 lB-7 6/8/81 ~_.,.,~""iD-8 (ws-8) 5/i0/78 AJaska Oil & Gas co:,~ ,._ ~,"2. = ..... Attachment Page 2 Drill Site 1H Drill Site lQ Well No. 1H-3 1H-4 1H-6 1H-7 1H-8 Wel 1 No. LogI .Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 L,o9 Date Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-i7 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Log Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/8O 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Log Date Drill Site Well No. 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/12/83 Alaska Oil & Gas Ar~orage 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/!9/82 5/7/83 Attachment Page 3' Drill Site 1Y Wel 1 No. Log Date 1Y-1 6/6/83 .10/21/83 1Y-2 6/10/83 3/4/84 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~E~-~I~ 5 / 10 / 83 ~. 11/21/83 1Y-I2 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill-Site 2Z' Well No. Log Date 1Ll~,~_ 7/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 ' 8/5/83 '2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF'pg'O052 ',--'" Alaska Oil & Gas Cons. Com~-!:tl .... Anchorage STATE OF ALASKA (' ALASKA IL AND GAS CONSERVATION CC~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~X OTHER [] 2. Name of Operator 7. Permit No. ARCO A1 aska, I nc. 81-10b, 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20627 4. Location of Well Surface: 899' FSL, 311' FWL, Sec.5, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 9. Unit or Lease Name . Kuparuk River Unit 10. Well Number lA-5 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River 0il Pool ADL 25647 ALK 465 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data i~KR 1 [0(1 ' 12. 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., proposes to convert well 1A-5 to a selective single completion. The procedure will be as fol 1 ows: 1. Well will be killed with brine. The weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A cement squeeze will be performed to proveide zone isolation between A & C Sand, if required. 4. A retrievable packer will be run to test casing integrity. 5. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 6. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: April 1, 1986 R~c~IV~D MAR 1 7 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~[~h~ ,~~[ ~/ Title Associ ate Engineer The space belq('~for Commission use Conditions of APproval, if any: ..Approved Copy ~®t~u~rned Approved by COMMISSIONER the Commission Form 10-403 (PJA) SN/137 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Drill Site lA Drill Site 1C Well No. "' 1A-4 1A-5 1A-7 ~1A-9 ~1A-11 '~1A-12 '~IA- 14 '~ 1A-15 ",,1A-16A Wel 1 No. '"~1C-1 '"~1C-2 '~1C-3 ~,~1C-4 1(;-8 ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 517182,,,~ 1/25/82~x,~.. 3/23/83//"~ . 1/19/83<i) ~-. 3/21/83/ 3/8/82 4/1/82 6/5/82 5111182-,,... ~ ~- 6~8~82/ u Dri 11 Site Wel 1 No. Log Date Log'Date . 5/9/81 5/8/81 7/13/81 11/8/81"> 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 19 J Drill Site 19 "~19-1 12/26/81 ~19-2 6/25/81 '~19-3 11/16-18/81~'--z ~ 3/12/82 / '~18-6 11/18/81~ ~ 9/10/82/ ~19-7 11/23/81 ~19-8 12/28/81~> ~19-9 ~ . Well No. ~Log Date '~ID-1 1/80 ""~lD-3 8/5/80 19-4 "~7/30/80~, ~ 8/13/807 ~ ~D-S 6/Z1/SZ ~lD-6 6/9/81 ~1D-7 6/8/81 ~ZD-8 (WS-8) S/ZO/78 RECEIVED FEB ~ ! ~986 Al~k~ OII & G~ Co~. ~mmi~lo~ Anchorage ARCO Alaska, Inc. ~, Post Offic~ 1OO36O Anchoragm~ Alaska 99510-0360 Telephone 907 276 1215 DATS: 09-05-85 TRANSMITTAL NO: 5332 i<~TURN TO: ARCO ALASKA, INC. KUPARUK_ OPERATIONS ENGINEERING RECOP, DS CLERK ATO-1115B P.O. BOX 100360 ANCi~UKAGE, AK 99510 TRANSMITTED RECEIPT AND SEQUENCE OF HEREWITH ARE THE FOLLO%4ING ITttMS. kETUPd~ ONE SIGNED COPY OF THIS EVENTS PRESSURE DATA 1H-3'~ PBU 03-07-85 2A-!--- 'C' SAND PBU 08-03-85 2B-13" 'C' SAND PBU 08-01-85 2C-~] 'A' SAND PBU 08-16-85 2V-2' 'A' SAND PBU 07-27-85 2V-5 ~ 'A' SAND PBU 06-25-85 PLEASE ACKNOWLEDGE TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL 1A-8~" bBHP & blISC. la-5 . PBU & MISC. IA- 3/ PBU la-3-- PBU lB-2-- 'C' SAND P~U lB-2-- 'C' SAND PBU lB-5 ~ bTATIC TEMP.LOG 1E-21-' RUN BHP & MISC. 1F-5 '/ PBU 'A' & 'C' bAND 1F-5/z PBU 1G-15-/ 'C' SAND PBU 1G-15/ 'A' SAND PBU & MISC. 1G-15/ 'C' SAND PBU 1R-10,,-wBHP & HISC. 1R-9/ BiiP& ~,lIbC. !R-12 / BHP & MISC. 2A-1/ 'C' SAND PBU 2A-1'~ 'A' SAND BHP 2A-l-" 'C' SAND PBU 2A-13~- BlIP & MISC. 2B-13/ 'A' SAND i~HP 2B-13~ 'C' SAND PBU 2B-13-' DATA FROM BliP SURVEY 2B-13--/ 'C' SAND PbU 2C-8 ~ PBU 2G-16" PBU 2G-16/ PBU RECEIPT ACKNO%~LEDGED: BPAE D~ILLING B. CURRIER L. JOttNSTON CHEVRON £u(ubIL D & M NbK CLERK SERVICE REPORTS/PRESSUR3S 08-22-85 08-14-85 08-12-85 08-11-85 08-05-85 08-06-85 { ISLTD ) 08-15-~5 O8-O3-85 08-18-85 08-17-85 08-10-85 0~-06-85 08-09-85 0~-15-~5 08-15-85 08-19-85 08-04-85 08-04-85 O8-03-85 08-25-85 08-02-85 08-02-85 08-03-85 08-01-85 08-17-85 08-17-85 08-1~-85 DlSTF, IBUTION: W. PASHER EXXON DATA *PLEASE NOTE--DISTRIB- UTION CONTINUED ON - ~ NEXT PAGE. /~' ~ ? ~ ~ · A ..:_v.-.z' ' ~; . P~ILLIPS OIL UNION : ~ C~:;,~., J. ~T~,~ELL K.TULIN/VAULT ...... <":'~,~ .... ~.?::,~ :. ARCO Alaska, Inc. is a Subsidiary of AtlanticRici~fieldCompany ARCO Alaska, In~m ..... Post Offic% .x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 TRANSMITTAL NO: 5331 I<ETURN TO: ARCO ALASKA, INC. KUPARUK OPEP, ATIONS ENGINEERING RECORDS CLERK ATO-1115B , P.O. BOX 100360 ANCHOR3~GE, AK ~9510 %'KANSMITTED HEREWITH AKL THE FOLLOWING IrfEMb. P~'EASE ACKNO~{LEDGE RECEIPT AND RETUt~ ONe: SIGNED COPY OF THIS TRANSNITTAL. PRESSURE FINALS/ASSORTED VENDE~S CAMCO 1C-4 / STAT.lC GRAD I ~:N~' 04-25-85 ' 2G-1. --'/ PRESSURE BUILD-UP 04-17-85 OTIh· 2X-,~ 5 "' FLO~ING Pi{ESSU~{E .. TOk~2UE ~TURN 2D-2p'''~ 24 HOUR PBU 07-09-85 04-21/22-85 GUAGE #63137 LYNES ~ 2X-4 / PRESSURE PtEPO RT 08-12-85 DRESSER ATLAS 1Y- 2 -'" 2C-8 ~,/ 2G-9 2H-1 ~/ 2W-7 PRESSURE SURVEY PRESSURE SURVEY PRESSURE SURVEY PRESSURE SURVEY PKESSURE SURVEY PRESSURE SURVEY PRESSURE SURVEY PRkSSURE bURV1:Y 08-13-85 08-05/06-85 08-07-85 08-16-85 08-22-85 08-24-85 08-22-85 0~-25-85 RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON MOBIL* NSK CLERK DISTRIBUTION: ~. PASHEK EXXON PHILLIPS OIL* J. RATHMELL* DATE: STATE OF ALASKA* SOHIO* 'UNION* K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska. Inc. Post Office Box 100360 Ancl~orage, Aiaska 99510-0360 Tc,~ephone 907 276 1215 DATE' 05-2 9-85 TRANSMIm~"?'~ . _ ,~ NO 5~03 RET URN TO- ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11!SB P.O. BOX 100360 AR~CIIORACE, Al'( 99510 TIUINSMI'fTED IIEREW1TiI ARE TIlE [,'OL ..' RECEIPT AND RETURN ONE SIGNED CO LOWING ITEt4~' PLEAS~? ACK£~OWLEDCE PY OF THIS TPJ:I'~S>~ITTAL. .... SnQU~;NC~'' OF ~'VENTS PRESSURE DATA -2A-B PBU- 2A-5 SBHP -2B-1 PBU 2B-2 PBU 2B-15 PBU- -.2B-16 PBU 2F-7 PBU- 2F-8 2 PBU- 2 G-I_..~ PBU 2G-!2 PBU- 2H-15 ISB!IP z~,-13 ~BU- 2X-13 PBU '~ ' SAND POST FRAC STATE 'A'.SAND STATE 'A' SAND POST FRAC SAND 03-16-85 11-21-84 04-01-85 04-02-85 04 -09-85 04-10-85 04 -14- 85 04-20:-85 .......... 04-13-85 04-11-85 03-23-85 04-10-85 04-21-85 03-30-85 BAKER/ LYNES PRESCURE~ nuPORmS~xz. _ (ONE COPY OF EACH) lA-1 PBU 04 -23-85 lA-2 PBU 04-23-8 5 lA-2 PBU 04-23-85 lA-5 BUILD-UP 04-23-~5 lA-6 PBU 04-23-85 iA-6 BUiLD-UP 04-23-$ 5 iA-10 BUILD-UP 04-23-85 iA-10 BUILD-UP 04-23-85 SET DEPTH 7i87' 7476' 7476' 6957' 8300' 8300' 8415' 8415' TOOL NO. 1722 1302 1512 1734 1719 2062 1508 1299 RECEIPT ACKNOWLEDCED: ':; 3PAE* DRILLING .J. CURRIER* i',. OOtlNSTON 2!IZVR0ll* MOBIL* L .:, :', CLERK DISTRIBUTION: W. PASIIER EXXON PHILLIPS OIL* RA.hM~LL* D--Z'-.,~',~,;;s u,, ~ b=~ Cons. (';ommisslon Anchorage STATE OF ALASKA* SOHIO* UNION* K.TUL!N/VAULT I-RAi'~5~i'ii TTAL NO ' 5 ~ F;: E T U R N A'-- i A-2 O 4---23-1:~.5 A-2 04-23-'85 A'-5 04-'23-17!5 A -- 6 (-) ,1 - 23 - 85 A-.: 0 04-23-~75 A.-.10 (::--5 04-2~-6"~"..> C-.5 04-.23-85 F-3 n4 o-- ~-, . ,, -.. JF 3 (.)4 ~": ~" ...... z. ,.> -- 8 .:> F:'-.- 5 0,1 --. 23 -. [:)5 F'.-5 0, '"" '5 I::.--7 F-7 F; - 4 C, ,1 ~' 3 ""::' · . -'~:. ~ C:' ..2 G-4 04-'''~ "~' ((') H I:: 'T 00 L. C l:)I':'Y [) I:: I:: A C I"1, ) ..~ 1777 T -.Df:: F:' '1" I"1 ',. Vi t.; i' 7 'l '? ,6 7,176 (::'. 30 (') ('~ ','Z ,:~ ,.: 0 0 ,94 1 '5 7 ,,'.. C) C) ? 2 ,'.::i 8 <;,~ ~-'~" .9 .) 5 '1 '-"- .:) .:) '7 () ,' .5 7 (') '? 5 .' 3 1 '" '?; 'i ''~ 6 -? 0 t T (:) l:i I... '1 I' ~,'.. i 30'" '1 5 t '> t '73,: t7'i9 ,-) .-) ,, ,) ~ ",9~? I 503 I:."" t ::;0t -'. C) t · J '7 '7 "7, 1777317 I :75t 5 I:;:EC:EIF'T ACI<NOWLEI)[;ED' · "- ....... ............................ ~" ......................... ' --'f~,=, TZ-" " I) I $"t"l:;: :[ i':< U'F ]: ON' · e -,.--::.o,Or~ ~AL. AS'I<A* E<l::'~'~ [::.* I)R :[ I..L ]: NG I,,1, i::'ASH[:'I:;; ~,~:~!~,[_ ', F.<, CLJI:i;I-:;]:EI:;:~ L. J(]I'-INS"I"ON i::'.XXON .701--lI[)-x. %s Cons. [: I"1 E: V F;; [) i',l -×- HOB I I_.x' F:'H II_L I F'5' 0 T L-x. LIN I []i',~.x. Anchorage I) & 1-i~(- N,S'I( C L I:: I::; I( J, RAI'HHI::'.LL-I~ I(,TLILIN/Vf:~ULT ARCO Alaska, Inc& Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 'i'RAN;~MITTAL N0:5185 FREI'URN Ti]: ARCO AL_A.'.gKA, INC ATTN' RE[;OI;:I),S' CL. ERI< ATO-t t t 5B F'.O. BOX t00360 ANCHOI:;:AGE, Ali I'I:(AN3HITTED i"IEi:(EWII'H ARE THE: F:'OI...I_OWIN6 R£CE'[F'T AND RETURN ~A I l'E. flS. CK NOWLEDGE ONE SIGNED COF'Y OF.' 'I'HIS 'FF(AN,~'MIT'fAL. WSR/SFqUENCE OF EV[.:'.i'.~IS (ONE COPY 01:' EACH) t A-t 1:. Ii LI G4-.2 t -85 t A-I F'BU 04--22-g5 t a- 2 R LI i',l L Y N E 5' R E C [) R I) E R 5' 04 -. 21 -.. II 5 tA'-2 I:ZND I:'~.~LI/F(UN WF(DF' 04-'23-8'"~ t ~-t-,_ ,~ I:,I'IF 0'1- t ?-85 I A-4 SBHF:' '04-t ?-85 I A-5 F'Ii':U 04-'2t -"95 t A-5 PUl_L F'BU ~'~ "~"~ o5 1 A-6 I::'BU 04-2 t -'85 IA-6 I"IAN[; OFF LYNIT. S F'RI:::,.~$UF~:E BOHBS' F"OF,: F'BU F I N I S H F' B[J RLIN LYNES RECDRDEI?S F'LILL LYNE3 I:(ECORDERZ F'BU F'BU Z B H I::' SBHF' RUN LYNE3 RECORI)EI:(S RE'i-RIEVE LYNE3 F<ECOi:~DIEI?3 RUN SF'I NNER/TEHI::'ER~TLIF(E SLIRVEY---L. EAK DETECT ION RUN F'DU 5'LIF(VEY Z.N,J E C T I V Z T Y' T E s'r INJECTZVITY TEJ'T INJECTION '['IEST/'A'SAND T EHF'ER~TURE/SF' I N NER-- LEAl( DETECTION RUN LYNES TANDE:N F'RES3~JF(E BOHDZ F'OR F'BU R E T R I E V E L Y N E: S R E C'O R D E R 5' RUN L. YNES RECOI:(DEI:(S ..... 'C' 5'ANI) ONLY RIETRIEVE I_YNE.~ i'(ECOF(DER~ tA-6 I A--iO iB-75 tB-S t (::-4 tC-6 tC-6 t E.--4 t E-5 tE:-t 8 t E-t 6 t E-27 tE-27 1 F:'-3 iF'-;3 IF-5 t F-5 i:;: E C E I F' T Bi""AE* B. C U R R I E I:;:* (;I"IE VI:;:ON* D & M* CAMCO C'A M C 0 C A N C 0 CA/iCO CAHCO . CAHCO [:ANCO CAMCO OTIS 04-2t-' 8~' '".> 0 T I ,S' 04-22-115 ' [)T I,.9 (.) ,l - 21 '- 8 5 C A M C 0 ,34 - '~ o / ,'~ -~, _ n 5 ,:.:.,,. .... CAMCO 04-2t-85 CAHCO 04-22-85 CAMCO 04 .,.. G-..95 CAMCO 04-25-85 CAMCO 04-2t -'85 OTIS' · 04-'2~-.95 0'¥I$ 04 -23-"~'5 o C A H C 0 .~ -. ") C c- 0 1 ....8-J.> CAi'i[:[) · 0,1-t 9-85 04-20-.95 ARCO O4-22-85 &RCO 04-27-85 OTIS 04-2t -85 0'i' I ,S' -.-.,., ,.,.., O'l" 15' 04 ":'t "':" -'.... - 6.> 0 T 15' 04-22-85 o'rI$ · ACI<NOWLFDGED: D I ,S' 'f' R I B t.l"r I 0 N: Di:;: I 1...I.. I NJ; L.,I, F'A,SHER I .... JOi'-IN.~TON EXXON. *- H 0 B I I... * F' I-'11 L. I... I F:' 5' [) I L N 3 !< C I.. E. i:;,' !< .x-,.J. F< f:':'~'l' i"1M E L L ) I)ATE: ...._ ~ ~o,;,~,~.... ,STRTE OF .~LASKA ,SOH I 0 ,UNION K. 'FUI.. ~ N/VA'UL ]' ARCO Alaska, Inc. iB(~x Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 :'::E.1"LJF(i~I TO: '1" F;.' r::, N ,S' hi I T T E:: I) Fk: 1""] C E I i="1F ~'.".l N D ;-q F;,' C (] ~::ll... ~'::'~ S I< A, I i"-I C ,, ,q T'i" N: R Iii: C O R I) S C I.. Iii: I::: I( r.'.~ T 0 .... i i i 5 E~ F',O~. I:~O× i r:.~NCHDi:;~;-?~C-F:_', Pll< ?S;'"~ i ;',3 D A'i"E::: (') 4 .... 30-85 'I"F;~AN$ M I T'i" P'~ L. I"1 Iii: R Ii!: W ]: T I"1 A F:,' Ii!: T I"l iii: F:' [)I...I... 0 W I N [; R I:::'1' U F;: N 0 N 1"" F:' O R T..7 ( O N E C [)F:' Y [) F E:' ~.~ C i"1 ) ARco Alask,'.a., I,nc. (~r ' ' · Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ......... r,r', C (} ~"'~L ~'..,,t k .A ,. I. .... A.T ·I" N · · R I!: C 0 '" ~ '" K I, ,~. C [.. IE R 1< .. ,.'ti'r0 .... tl,.i'5B . . . I: F',.O., BOX t tff ....... ['It~:F:;I:;H];TH ARE THF:' ,,,~::'r"¢'~::'i'F"l, ..... .... ~r,,,.~n RETUF;:N ONE S'Z(;NI:;D COF'Y .OF . , .. 0 T 1' ..~'" I':' R E .?'6..> i...IR E X 'U ,...,..a,/~:-.. ....... Y ;S' ' (' 0 N E ,. ., 1 A"""; ~' F:' B~ i '~"' ~ * (" ':: .. · . - ~b ~) .... ~ ,:¥ .... :) ...> I::' B U ( I f'~ I T I A I... ) ~n.,..'~ .... ~ (;~ .... t 2 ~ I::' B I...I ( I N ]: T :[ A I... ) ,,r.~ ,..,'~ _ ,,."~ -,* ...: ,.,° ,;~... .. 2 ~"" f ~' I::' B.U. 0 4 "" "~'" "' ~ F' B t.J ~ ]: N I 'l' :[ Al... ) (') 4 .... 04 .... 2D ..... ~ F:'BU :.. 03 .... (')i .... ~'5' .~: L -'" ~:, ~ ,~'.. BI i1::' 04 -" 0 ,:. 6 .... o~ F:' B U 0,:, .... ,,: i .... s::.':.., '"*~1... I 0 j F:'BU ..... n''~.-.~:~'::' .... H i;2~ F'BU O;J"-04 .... '"" "t '" ¢ I::'.};-~11. (~,:~"- 1 &,""o.:> "'X ..... i ;~ ~ 1~:'f:',lj 0 Z .... .d. ..... "" ~;? ... '"*"" :' ""' "'"""~"" I'"'" ,.,tJI~L~,., , 61:.. :..:: ~ t", A I',, f l" Il,. L ,.', ,;, t.. ll~ l::. ~ :" ~ :"'' 5 t 2 <? ,. Alaska b,, & L~aS C0.rts, .6g~p, missi911i Anchora9~ "; ;~'::; L L ! l".! [; l.d., F:'A :.;' H I:: F;,' · !.. .. fg I-.I i',!,:: 'F (] t,! E X X 0 N i'! ¢! T;' 'r f :,-. ::.'"'"i '!'~ I, 'r r:, .,, I"l T [.. i'J 2'K CL.":'''''~: ..... ,.. ,,,,,, ,.j ~ l:::/','""l-~i"if::'~ ;... ;' · ARCO Alaska,,Jnc,. [s.4,~bsidiary of AtlanlicRichfieldCompany · .. h...~, ~ ,.':.... i".. F' ):.:': !. i 1::, T', J ~ '.'" ' ! "', ', ,' !:" "." ! .t.; .) ..: ~,..:: '..' ,... i (:; ~-.: ,::. !... '!: !::' "i" 5' !...i F.: V [:i: :';" l:;:l...!i'-.! (:~..,':'."~,'? !... [ F:"T' ':"1 '~:":/F'"r" F:' i:.:.; l:-, ,",I l F:' l:;t ,':':'~ (:.: ,::' 'T, :1; i""i ',..,~i... r'", "r', .,"' .... fit! I::' '~':' ! t ; ', ?, I I I::' t:;.' iii: f.'i' 5'~ ii::: iii: F:: ~::' '::' ~"'~ ~::' "r ..... l...! .,.' t ',. ~ ' ~':'~ ' ,~i.' ,'::': [".~ ..... 'f':'J::' r',"" i::~ i":... ... . ' ¢'~ ' .'i' ~.-, i' ! .ii", !':' i::.' ,'::'~ "'" ,.... r..; ~.h,? :I: !..I ..! !i!: ri:: "f' :I: f:) N ' C ' ;".'? ,t.~ i"..! i."':" :('? i:;: !.:'~ ):)l.,.I i',! ,:: 2. F:' (:i ':" ) ' C ' ,:.'? ~:'-~ i'.~ ?, .ii", R I'::: :(::, L! N ,: 2:: r:' ~:.;. 5' ) F" :l::, t..! ..... F' !... (::! ~.,J T.,. i',! ~::; .,.,r'"' ...~"{ F:' F' '8 !..t F..' !..I N !:; ~.. 'v' ' ,? ::'.? B !.-1 I::' F:' Ii.; U F'? t..l I::' B U ," ,.T' ~..J F:' .,7..:.:! ! i::' [':'; I...! F' I':': U F:' I._ !..~ :i: iii::' 'f: ~::'~ ii ]: ?, il i'", ~. ~ ........ . ..... (:! T':I: I::.: ~'.':i r..! !:.':: (:'! 'i-:i: ":, .i i ~.1 i::~. ~ r':' "." · " 'y' t' .:', ("r r .'" ... ~ ,... (:: ~':", iii::: ~..~ (::: ,:":'~ i""i !.::: t"" .% i'." ~"" =."'~ '.... J"l ~ I ~...- '_.~ 0'?' 'r .~', 4. ~.:' 'j",f';~t~::'~ t .-...' '...'.! k. L.. L.. i-'., :"~ t.,i !:" t ! ... (:~ '!-:!: ,'ii' · ...- ~ .... i ~..', .... I I t!...IE. !.Iii:: ~:.'~ '~' I' ':." '::: .'::. i"'! :.:' (':: ~-~:: ;'.-'; ,.... .. ~ ; -.... ~.., I"~ "¢' T /." t.., ; J. ,... 0 -? .!: ,'?': ~"j "," T ':." '... ~ .h ,.;. '"~ i" t i. ,'? (':~ 'i" .!: ':" '"" -"' T ,?' ,..= ~ . AClantic Ritchfield Company Arco Alaska, Inc. TRANS}E[TTAL To: Wm.-Van Al'en/Sate of AK Date." 31 Angusg, 1983 From: EXTENSION/EXPLORATION' . . Transmitted herewith are the following: Mud logs 'f'rom the folio.wing wells: lA_5-~'~'. lA-8 ~-West 'Sak 12') 1B-5'~(West ~Sak 7) 1C'4 "~" 1C-5~" 1C-6/ 1D-4-' · . ~p__5~- 1G-~~ 1H_3.~ 1H-6~ 1Y-i~ ~ 2C-?~ ~X-2~" .~ ~.'' g-ll-81 7-22-78 "11-27-77 1-1-81 2-9-81 · 3-1.--81 12-31-79. 4-7-78 8-20-82 10-12-82 7-24-82 .. 5-19-82 2-4'83 7-8-83 6-29-83 7-2-83 6-10-83 . . Also: included is an expanded' c'ore-'tog 'from well 2X~2',TT-2'-83. A blueline copy and a Sepia is provided .for each well.. · · . R.~. eipt .Aeknowledge[~! ' . [/Rgturn receipt to: Arco Alaska, Inc. ~ Attn: XM~X~NgawoYEf E. McAlister P.O. Box 100360 Anchorage, AK · 99510 Date: Alaska Oii& 6~S Co~',s. O0,,i,~ii~ Anchorag~ Prepared by: B.B'~ne TRANSMITTAL TO- William Van Allen FROM' D.W. Bose/Shelby J. Matthews WELL NAME' Transmitted herewith are the follow.!ng' PLEASE NOTE' BL - BLUELINE, .S - SEPIA, i-C-Z? / '/4-5 - R~E I PT ACKNOWLEDGED'. /LEASERETURN RECEIPT TO' ARCO ALASKA, INC. AT%N· SHELBY J. MATTHEWS - AFA/311 · P O. BOX 360 ANCHORAGE, AK. 99510 TO: DATE: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: ~~LEASE RETURN RECEIPT TO: .~ °o DATE: ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 July 21, 1982 C. V. Chatterton State of Alaska Oil and GaS Conservation Con~n. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. c~atterton: Enclosed are subsequent reports for Kuparuk Wells &i~-5, lA-6, 1D-2, 1D-3, 1D-4, and iD-5 covering acid stimUlations. Sincerely, ../E. A. SimSns~ EAS/er cc: L. K. Blacker -AFA 330 w/o Attachment L. B. Kelly -AST 306 w/Attachment L. M. Sellers - ANO 332 w/Attachment H. Co Vickers -AFA 326 w/o Attachment RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska InC. is a subsidiary OI Atlaf'HicRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-104 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20627 4. Location of Well SL: 899' FSL, 311' FWL, Sec 5, T11N, RIOE, UM BHL: 1246' FNL, 1208' FEL, Sec 7, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. / __RKB-100' ADL 25(;47 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 9. Unit or Lease Name Kuparuk River 10. Well Number 1A-5 11. Field and Pool Kuparuk River Kuparuk River Unit Field Oil Rool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation )k~] Abandonment RePair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On July 9 and 10, Kuparuk Nell 1A-5 was stimulated in the Upper and Middle Sands with 12% HC1. A coiled tubing unit was used to spot and squeeze a total of 150 bbls (6300 gals) of 12% HC1 with MSR into the perforated intervals of 6822-6829', 6952-6956', and 6962-6968'. After the acid was displaced with diesel, the well was opened to cleanup tanks. Nitrogen was circulated alternately with diesel to displace the spent acid and underbalance the wellbore to aid in flow. The two N2 surges consumed a total of 1203 gal N2, while the total volume of diesel used was 69 bbls (2898 gals). Before stimulation, the well was producing at a rate of 2341 STBD. After stimulation, the well tested at 3209 STBD, or an increase of 868 STBD. During cleanup, approximately 350 bbls were flOwed to separate tankage before returning the well to the prodUction line. This volume included ail previously circulated fluids. RECEIVED 2B 3 JUL o 1982 ^!~_~k~ Oil & Gas Cons, Comm!8_.!_-n 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Anchorage ~ ~'~c~ Regional Operations Engineer Signed . . Title Date '" ihes acebe~or~ommi~ ~ T p io~ ~ond'tionso Appro al, 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 Bo J0 Anchorage, Alaska 99510 Telephone 907 277 5637 July 6, 1982 C. V. Chatterton State of Alaska 'Oil and Gas Conservation Co~m. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton :. Enclosed ~are Sundry Notice Subsequent Reports for Kuparuk Wells,~lA-5, and lA-8 which cover the acid stimulation. Sincerely, . . Simonsen FAS/er cc: L. B. Kelly - AST 303 w/Attachment L. M. Sellers - ANO 332 w/Attachment ARCO Alaska. In(: is a subsidiary of AllmnticRichtb'ldCompany 1 STATE OF ALASKA O~vl ALASKA ' L AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator ARCO Alaska, 3. Address P.0.Box 360, 4. Location of Well SL: 899 ' BHL: 1250' __ KB:I 00 ' 12. 7. Permit No. Inc. 81 -104 Anchorage, AK 99510 FSL, 311' FWL, Sec. 5, T11N, RIOE, UM FNL, 1172' FEL, Sec. 7, T11N, RIOE, UM 8. APl Number 9. Unit or Lease Name"~''-----'''~' Kuparuk River Unit 10. Well Number 1A-5 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. K u p ar u k IADL 2,5647 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Field River 0il Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stim u late [] Abandon [] Stimulation ~ Abandonment Repair Well -1 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). Kuparuk Well 1A-5 and Lower Sands on squeeze 5040 gallons of 12% HC perforated intervaIs 6822-6929 and 7065-7092'. Nitrogen was weilbore. The weii was fIow t rate of 2349 BPD and a gas rat was stimulated with 1~2_~ ....... HC1 acid in the Upper, Middle May 28, 1982. A coiled tubing unit was used to 1 with mud and silt remover into the ', 6952-6956', 6962-6968', 7052-7956', used to displace and underbalance the ested for 6.0 hours at an average oil e of 1743 MCFD. All circulated and produced fluids were flowed to stock tank~ and then deIivered to a waste disposaI weli. The well is presently flowing to the Central Production Facility. A-27 14. I hereby certify thazt the foregoing is,t)rue a}qd,r,~arrect to~e Th~.. ~el:for C om mA':se best of my knowledge. Regional Title Operations JUL 2 o 3982 Alaska Oil & Cons. Engineer // Date ~ Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS OH WELLS OTHER [] ~/~ 1. DRILLING WELL [] COMPLETED WELL)C] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-104 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20627 4. Location of Well SL: 899'FSL, 311 'FWL, Sec 5, T11N, RIOE, UN BHL: 1242'FNL, 1213'FEL, Sec 7, T11N, RIOE, UH 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-5 1 1. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 100' 12. 6. Lease Designation and Serial No. K u p a r u k RKB ADL 25647 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data River Oil Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate X~ 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 stimulate the Kuparuk Sands with acid. Acid will be spotted with a coiled tubing unit with BOR assembly tested to 4000 .psi. All circulated and'flowed fluids .will be diverted' to tankage on location. The well will be tested subsequent to the stimulation. Expected start date is Hay 28, 1982. A-17 RECEIVED Alaska 0ii & ~as C~)ns. Commissio · ~nchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~X S ~~Y~ Area Operations Engineer Signed _. _ . Title The spac~elow for Commission f . Condition[ of Approval, if a'ny: ApproVed Copy Date Approved by Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in. Duplicate WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well · OIL [[~ GAS [] SUSPENDED [] ABANDONED[].. SERvIcE.I 1 2. Name of Operator 7. Permit"Number ARCO Alaska, Inc, 81-104 - 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 5o- 029-20627 - 4. kocation of well at surface 899'FSL, 311'FWL, Sec 5, T11N, R10E, UM 9. Unit or Lease Name Kuparuk 25647 At Top Producing lnterval 1250'FNL, 1172'FEL, Sec 7, T11N, RIOEUM .WeUNumber 1A-5 At TotaI Depth 1242'FNL, 1213'FEL, Sec 7, T11N, R10EUM ll. Field and Pool Kuparuk River Field .5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB ADL 25647 Kuparuk River 0il Pool 12. Date Spudded 8/11/81 13. Date T.D. Reached 8/26/81 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mp!eti°ns 9/4/81 -- feet MSL 1 17. Total Depth (MD+.TVD) 18. Plug Back Depth (MD+FVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost ' 7675' MD 7547' MD YES[~X NOIlI 2047' feetMD 1650' (approx) .22. Type Electric or Other Logs Run BCHS/DIL/GR, FDC/CNL/NGT/CAL, CBL/VDL/CCL/GR · 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surf 80' 30" 200 sx Permafrost' 13 3/4" 72t~ L-80 Surf. 3095' 17 1/2' 1600 sx Fondu & 3(0 sx AS II 9 5/8" 47# L-8Oor Surf 6633' 12. 1/4 900 sx ·Class G cenent . 500-95 ?" 26~ ~ ,:' :~,.K-55 6284' 7670' 8 1/2" 280 sx Class G cement 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) ~ 1/?" ~;770' ~707' · - . 6822 ' _6929 ' .. 6952 ' -6956 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6962 '-6968 ' W/12. SPF DEPT~ INTERVAL (MD) AMOUNT & KIND OF MATER IAL USED 7052' -7056 ' · 7065'-7092' . . ~ . ,. 27. PRoDUcTION TEsT Date'First Prod.uction :.Method, .of Operati, on. (Flowing, Qas lift, ,,etc.) 12/26/81 I Flowln~ , Date of Test Hours Tested PRODUCTION FOI~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 1/30/82 .. 11 hr-~ ,. TEST pERIOD I~,, . ~ ?9~ .... :1 FlowTubing Casing Pressure, CALCULATED 'I~ OIL-BBL , GASr-.-iVICF WATER-BBL OI[_'G-R'A-ViTY-API (~r~') 24~HoU'R ,, .Press'145 ' R~'TET~ ,3.0;10 -' 1424 ,, 25° 28. CORE DATA . , · -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A ." ,: ,',: .... .......... . ii! · ... ; .. :' :..,.,, , , 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Top Kuparuk River Form. Base Kuparuk River Form. MEAS. DEPTH 68 24 ' 7133' TRUE VERT. DEPTH 6000' 6309' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/~\..~ .~~/~,~Y'-x TitleArea OpS' Engr. MAR ! 0 1982 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 inject'ion, 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.~°mpleted for separate production from more than one int'~rval (multiple ?i::;:: 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.)o Item 23: Attach:~d supplemental records for this well should show the detailS~:'~)f 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 Tra::~_.mi;ted he:'ev:ith are the following- ... PL~.~ ROTE- BL -'BLLEL!i~E, S - SEPIA, ? J. J. Pav,'elek/Ann Simonsen F - FILM, T - TAP- L,/CLE;-.:E RET';*:; RECE:?T TO' ARCO At. AStRA, INC. ~,~¢,,,~q- p~ ~,, Ct:~l l<n c, ho [ agB NORTti ~LOPE ~-' '~ ~ ~_ ,GI,., EER [i:G TO' TRAilSMITTAL ~ FROM' J.J. Pawelek/Ann Simonsen Transmitted herewith are the following: PLEASE HOTE: - BLUEL!,~E - SEPIA F - FILM, T - TAPE REC-~IPT AC~., ~u,,~L ~uE,] ~ RE ' PLEAS: ~, TURN RECEi?T TO ARCO ALAS!iA, Ii~C. ATT!'!: A[IN SI~.iO~ISE[! - AFA/3tl P.O. BOX 360 A~.,,~.. ~..- ,, 9~.~1 0 January 20, 1982 Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservat ion Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Updated Well Completion Reports Dear Sir' Enclosed please find the updated Well Completion Reports for the following wells' DS 11-2 DS Z4-~6 DS 12-13 DS DS 13- S ~'~S' ~'~ Ds 13- 7 DS14-15 DS B- 7 'Sincerely, G. L. Alvord Associate Engineer Enclosures GLA:ss ARCO Alaska, Inc is a Subsidiary of AtlanticRichfieldCompany if' '"]' STATE OF ALASKA ALASKAb¢,~ AND GAS CONSERVATION C(~.,,,,MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG · , : -1. Status of Well ., Classification. of Service Well · · OIL E~ GAS [] SUSPENDED [] ABANDONED [] .,: SERVICE [] 2. Name of Operator 7. Permit Number : ' ARCO Alaska, Inc. 81-104 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20627 4. Location of well at surface ~--.--~.____ 9. Unit or Lease Name 899' FSL, 311' FWL, Sec. 5, TllN, RIOE, UMI[OCATIoN-~I Kuparuk ?.5647 At Top Producing Interval I VERIFIED , 10. Well Number 1250' FNL, 1172' FEL, Sec. 7, TllN, RIOE, UM .surf._JF~ At Total Depth B.H. 11. Field and Pool 1242' FNL, 1213' FEL, Sec. 7, TllN, RIOE, UM Kuparuk River Field .5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 t~ool 100'RKB ADL 25647 , A~:E 465 · 12. Date Spudded 8/11/81 13. Date T.D. Reached8/26/81 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mPleti°ns9/4/81 -- feet MSL' 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey i 20. Depth where SSSV set 21. Thickness of Permafrost - · 7675'MD 6850'TVD 7547'MD 6722'TVD YES ~ NO E::]~I 2047 feetMD 1650' (approx) 22. Type Electric or Other Logs Run BHCS/DIL/GR, FDC/CNL/NGT/Cal, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" ,. 94# H"40 Surf 80' 30" 2~lo .~x Permafrost ].3-3/8" 72# L-80 Surf 3095' 17-~ 1600 sx Fondu & 300~ sx AS II 9-5/8" 47# L-80 Surf ~6.633, ~. !2,¼,' 900 sx Clas.s ',G,, cm:- S00-95J 7''~ 26# K-55 6284' 7670' 8-½" 280 sx Class "G" 24. Perforations open to Production (MD+TVD of T0P and, Bottom andr ,25. TUBING RECORD r .,interval, size and number) , ,, .SIZE DEPTH' SET (MD) PACKER SET (MD) 3~" 6770' 6702' 6952' - 6956' .,, . 6962' - 6968.' 12sp¢ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. " 7052' - .7056' ~... · DEPTH INTERVAl.., (MD) AMOUNT& KIND OF MATERIAL USED , 7065' - 7092' ': -- . .. 27. PRODUCTION TEST Date~F, irst Product on I Method of. Operation (Flowing, gas lift, etc.)r N/A N/A Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF' 'V~ATER-BBL CHOKESlZE IGAS-OILRATIO · '; ,.' ,, : TEST PERIOD I~. , I Flow, Tubing Casing Pressure' CALCULATED OIL-BIlL , GAS-MCF WATER-EEL OIE'GRAVITY-API (corr) ,' ,, "Press., 24-HOUR RATE :li~ .... : :' ' 28. coRE DATA ' ~!? ~,,~ j~ ~',' I '~ ~ j'~ . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , · , N/A JAN2 O 1982' " Alas~ Oi~ & Gas Cons."Commissio~ ' ' ~wchorage .. , ,- ...,.: .,~,. : ;.. · / - 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 Kuparuk 6824' 5997' Top Upper Sand 6827' 5998' Base Upper Sand 6850' 6026' Top Lower Sand 7044' 621 5' Base Lower Sand 7092' 6291' Base Kuparuk 7133' 6305' , 31, LIST OF ATTACHMENTs , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gneO ~.~.~)~"~'V~'~'~)~'~'"")litle Dist. Drl§ En.qr.Date -- INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas 'injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 a~i~d 24' If this Well is co~?leted for separate production fr~:m more than one interva.l. (multiple completion), so state in item 16, an~ in item 24 shoTM the producing intervals for only the interv~¥reported in item 27. Submit a separate form for each additional interval tobe 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 ~hould 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 NORTH ~LOPE E~GI~-IEERIi:G TO' J. J. Pav/elek/Ann Simonsen DATE' .. /~ /~,'- ¢ 2... WELL ,~..c.~,~..,= · Transm]~_d hore,.,ith are the following: PL¢*~.~' IIOTE' BL - BL~c~.~E, S - SEPIA, T,~?~_ F - FIL?,I, T - "'"' J. J. Pawelek/Ann Simonsen WELL "'" ' Transmi;ted herewith are the following' F- FILM, I - T~P r. E,- rE ~. ?T ,.Ct .... L.b,S . DATE' pi :-?.ct ~= ........ ?T TO' ARCO ALAS!iA, I~IC. afl ATT~I: ~,,~~ql~'''''~:~u:', :~,,_~,: - AFA/311. P.O. BO:': 360 · ,.- ~., Cc~lO A,iC~-~O2A'S,-, ,=~, ~_~ RECEIVED NOV o e !98! Oil & Gas Cons. Commission ^r~chorage Pav,,el ek/Ann Simonsen Transmit=ed he,'o'.,ith are ~ ~ ' ....... u;,e TOll O'...;i nc PL-~:c== ~ ,~Ol.~ BI_ - BLUELZ;iE q - SEPIA, F - FILM TAPE ---',. ~ ~ ~ ~ ~ ~ ?,.~ ~,,, ,0,.; L [: [:'a F_ ~ . DATE- RECE!?T '~: ..... ARCO ALAS~tA, IHC. ATT;' ......~.,,~ ~ I ~.'.,~*',~m:~ P.O. COX 360 ,:,:;C:'!'-~'' ' .... 9'9~1 0 L. ;'., ~ '~: ,Z. ~ ,~: ix & Gas Cons. An. chorags - AFA/311 October 9, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' Completion Gyroscopic Surveys Dear Sir' Enclosed please find the co.m. pletion Gyroscopic~Survey for the following,wells' DS 12-12,vDS 17-7s DS 17-9, 'A'5~A-6, q~-6~~ and B-7.~x Sincerely, P. A. VanDusen District Drilling Engineer PAV'cm Enclosures ARCO Alasi,~. Inr is n s~l)sid~nry ol AllanlicJ~i~:hh~ld(;ompany 907 263 4274 Les M. Sellers District Drilling Manager October 5, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 14-11 Kuparuk A-4 Kuparuk B-6 DS 14-16 ~~i~!A'5' '~ Kuparuk B-7 DS 17-10 q<~]paruk A-6 Kuparuk B-8 Dear Si r' Enclosed please find the following' 1) The Completed Well Reports for DS 14-tl, DS 14-16; Kuparuk A-4, A-5, A-6, B-6, & B-7. 2) The Monthly Report for Kuparuk B-8. 3) The completed Gyroscopic Survey for DS 17-10. Sincerely, P. A. VanDusen District Drilling Engineer PAV'cm Enclosures , E£EiV'ED OCT 0 8 i98' ,,2}ii & Gas ;' '~ STATE OF ALASKA ~" · ° iiiii ,ss,o. 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. 81-104 3. Address 8. APl Number Po0, Box 360 Anchorage, Alaska 99510 5o-029-20627 , . 4. Location of well at surface 9. Unit or Lease Name 899' FSL, 311' FWL, Sec 5, T11N, R10E, UM Kuparuk 25647 At Top Producing Interval 10. Well Number To be Submitted A-5 At Total Depth 1 1. Field and Pool To be Submitted /~//~-/uz_/ /~7/3~F~L~ S~.?~ T///V/~C/O~ LY~, Kuparuk River Field .5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 100' RKBI ADL 25647 12' Date SP Udded8/11/81 13. Date T.D. Reached8/26/81 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti0nSg/4/81 -- feet MSL 1 .17. TotalDepth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey ] 20. Depth where SSSV set [ 21. Thickness of Permafro~t 7675'MD ¢o;50 7547'MD YESI-~X NO[] 2047' feetMD 1650' (approx) 22. Type Electric or. Other Logs Run BHCS/DIL/GR, FDC/CNL/NGT/Cal, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 SUrf ' 80' 30" 200 sx Permafrost 13 3/8" 72# ,L-80 Surf 3095' 17 1/2" 1600 sx Fondu & 300 sx AS II 9 5/8" 47# L-80 or Surf 6633' .12.1/4" 9001~sx 'Class "G" cmt S00-95 7" 26# .K-55 6284' 7670' 8 1/2" 280 sx Class "G" cmt 24. Perforations open. to Production (MD+TVD of Top and Bottom and 25. TUBI"NG RECORD ihterval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2" 6770' 6702' 6952' - 6956' . . 6962' - 61968' 12 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7052' 7056' '~EPTH INTERVAL (MD) AMOUNT& KINDOF MATERIALU,SED 7065' - 7092' , , · , , . · 27. PRODUCTION TEST Date First Product on I Method of Operation (Flowing,_gas lift, etc.) N/AJ N/A · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO T'EST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-M'cF WATER-BBL OIL GRAVITY-APl (corr) 1~24-HOUR RATE ' Press. 28. CORE DATA -' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME include interval tested, pressure data, all fluids recovered and gravis:y, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be Submitted .;. ,. 31. LIST OF ATTACHMENTS · · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~, j~ Title Dist. Drl_q Engr. Date 10/5/81 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~i~eparate produCtion from~;rnore than one interval (multiple~i; completion)?;~© state in item ;:16, and in item 2~ show the producing inte~als 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 multip[~ 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 KUPARUK A-5 DRILLING HISTORY NU hydril & diverter. Spudded well @ 1600 hrs, 8/11/81. Drld 17 1/2" hole to 3120' Ran multis...h~t~.~ Ran 178 its 13 3/8" 72# L-80 BTC~tcsg w/shoe @ 3095' Cmtd ~3 3/8" csg,/.uuO sx Fondu & 300 sx Arctic Set II.--D 20" riser. Instl~ 13 3/8" pkoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 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 6648'. Ran 165 jts 9 5/8" 47#/ft L-80 csg w/shoe @ 6633'. Cmtd 9 5/8" csg w/900 sx Class "G" cmt. Instld 9 5/8" pkoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8 1/2" hOle to 7675'~. Ran BHCS/DIL/GR, FDC/CNL/NGT/Cal. 'Arctic packed 9 5/8" x 13 3/8" annulus w/300 bblsH~O, 45 bbls Dowell Arctic Set & 116 bbls Arctic Pak. Ran 34 jts 7" 26#/ftK-~55 lnr fr/6284'-7670'. Cmtd 7" lnr w/280 sx Class "G" cmt. Drld cmt to 7547' PBTD. Tstd lnr lap to 3000 psi. Displaced well to NaC1/NaBr. Ran CBL/VDL/CCL/GR. Ran 3 1/2" perf completion assy w/tail @ 6770' & pkr'@ 6702'. ND BOPE NU tree & tst to 3000 psi - ok. Dropped ball & set pkr. Tstd tbg to 3000 ~si & ann to 550 psi - ok. Dropped perf bar & perf'd j[~,~,2~-6~&6', 6962'-6968', 7052'-7056', 7065'-7092'. Flowed well to tst tanks. SI well. Released perf guns. Bullheaded diesel to 30 bbls. Pulled dummy valve. Closed SSSV. Instld tree cap & tstd to 3000 psi - ok. Secured well & released rig @ 1330 hrs, 9/4/81. D-~02 R2 Eastman Whipstock A PETROLANE COMPANY 'REPORT of SUB-SURFACE DIRECTION,4L SURVEY ARCO ALASKA, INC. COMPANY Pad A, Well Number: 5 WELLNAME Kuparuk Field, ~orth Slope, Alaska LOCATION JOB NUMBER A881G0500 TYPE OF SURVEY""""V Gyro-Multi Shot OCT 1 ~ 1~ ~.las~ Oil & Gas Cons. AnChorage SURVEY BY A. Hickman OFFICE Alaska DATE 30-Aug- 81 Eastman October 8, 1981 ARCO ALASKA, INC. P.O. Box 1479 Anchorage, Alaska 99510 P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 Well Number: A-5 Location: Kuparuk Field, North Slope,-Alaska Type of Survey: Gyro-Multi Shot Date: 30-Aug-81 Method of Com~utation: Radius of 'Curvature Surveyor: Andy Hickman Job Number: A881G0500 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Gyro-Multi Shot Survey run on the above-mentioned well. We wish to take this opportuity to thank you for calling on our services and trust that we may continue to serve.you in the future. Fi Technical Coordinator ct TJ/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/InStrument & Tool Rentals/Sales/Worldwide AI.~C'.O ALASKA, Ii'..![.'. ~ PAB A~,' WELL" NO ~ "5" GkiS ............................ ;" .................... .lOB'-' NUNBER,. ,--,'"'"'° ~o~_, ~ ,.,""","; ~-: "'" "*u ,_, ,.. ,., ..... i':.'(It::'ARLIK, ..... NORTH SLOPE? AL.A°,~;',_,~,A '~ i:~ '" .... "" IN B ~ -'"' ..... ,, ..z,u- AUU'-'o 1 Gi'"iS~,0'"75"~0 i'"iI:I~ :::LIF,,'i::.¥OR,* A i"IICKi"iAN r,,t.,. ATE.,, · CAMERA i"~O,~ ].213 GYRO NO~ 56¥ 90 DEG A/U NOt 1121 : i..-ORSiGHT: N 0 E VERTICAi-.. SECTION CAL. CULATEB .IN F'LAr'~ OF FR,_,Fuo~L .. ;:' "- " '~ '.42 . DIRECTION~-:S .~4 I.,Eo, M~N ~' RECOR'n OF' SURVEY AZ..~ A ' WE[.[.. NE) ,* 5 ..... ~'?"' JOB N~' "'"'"" t..~, ~ c:, j i','i B E F,' $M o o I G 0 50 0 ,.~L OF'E ~ .... ALASKA LIF'ARUK, NORTH" o. 1 ~I:1, :02:04 08-0CT-81 · T R U ['"_' !{-:o~H r~. ,...' ,.: N G L.,' L. i-.~'" R C L 0 "d L.," R E EASL!I:;:EB BRIF'f ....... I)R I F"'f C'OURS,-'-'- ., t:.r,,T z ,...~-.,L' "VE"I:~'T?.. . .,. CAL. .... ,...':":"':,-. '.c ..... .-, ..... .,:.:' --m T 'A t)OS DEPTH ANGL. r,... DIRECTION l...'r"i"lF:i','rH,...,.:~ , .'OEF'TH SECT'rFtN.,. _ 'I'*~I_'~,,- ~[:; 0 0.: r.;', .0 I N A ]' E S DISTANr':E.- DIRECTION .:::,c.,,-E F'- E E:..: T , t 00 o 200, 300, 400 ~ 500 600 700 qO 0 c) (5 p, F ~:. ~., F' E: E T F' E E 'T FEE T F'EET .... 0:30 N 77 0 W ,'3.~ 0 45 N 76 0 E: 6 4 6.3 .1. n .q ..-.~ .... 0 [-" .... .1nO~ A99,933 "-.,",;74 '"';'99,~933 0 48 S 1,9'''-~ ~ 4,5 S ,40 0 W 100, 799,,83 '2,45 699,,83; 4,3',! 'S 1,93 7 0 S 36 ¢. W In-"", °99 -'~ ~ ,, :, ,, ,::: : =,o i .,."., ...~:'.".'.. 79"::;', ~ .7.,8 ]..1. , ,'59 S ,.'3.,., F::4 F' E: Ii!: T B M D G / I · :":' G R i T Y 0 .,.'). :i':' "?", <).,63 c 88 4(;;' Ii: 1 ~ · --' '2 ', '. .... :',4 23 E r'~ ,;,..' "~ 05 5 ~ ¢--'. o,,:.~ ,~ ,. · ," .. 4.,72 :3 24 .4 E ~3.,67 1. 2 ~ ..':'.: 1 S 1 E: t...,-'"" W 3 · 7¢ 7 IOn;'>, I0 4~' S 20 0 W 100 o98~1.6 ....... 27~07 898,:I. 6 25 "'~7 . .,.. · ...,i -~ : ' ;. .~..I. 00 ,, .1. 5;30 .q .1. 6 0 l,:t I n 0 10 o ~ .-: ~;~?';" ' ~', -':,, ~ ~ ~' ,=,", ,",'::; ,::- - · ' ,. . ,, ~, ..., , ,.., ~.: :.4 o, :;.:: :: Y u .~;,::~'. ,.: 4 6 · o._ .::, 1 W , 0 ','-' 12 0 O, 20' I s S .1:6 0 W I. 0 0 il ,,"0, ,.,, .:., 7 + ..3,, J. 0 ,.O., o, , o. 0 o o ,., ..: , u t"z. O0, 233 0 S 26 0 W 10':4 ;::l'o':::~ ,:;': .1. ' ..... I. o-:, ,<:~ ,.. ,. ~. .... ,,.:~ 1,2 .,.,~. ~ . 1 ,:, o ,., ..:. 1 10 · '-~ 1,S 749,7'"'. · J...., ,.-.'. . ::::::::::::::::::::: : ,'~ , ~',-, -' · ¢-'~ '". ~ ,"',~:' -~¢,r,;,,"" -' ~ c:'. ;-~ .: ..... ,0, 26 ._-40,...q .,-_'8 0 W :l.n,",,.,, ~ ].465~n°~.~... .1.:,0~._,~' l~,~,~z.~-_', .lo,.~,,~ ¢. /7,74 J. 6,3c, ,..., ,. ,..,'~.~ 1~.., S334 0 i..,j. !00_ ~ .1. ~:;=;.4,. ,., ,42 24.1. ,6P,_ :I. 4'='4 ~ 42,.., 22.4 , ,:*.,2,. . ,.,q .1.0.1.,02. 1700, 28' 0 S ,'-'3., ,2. 0 ~,, 100 · .1. ,., 4 ,., · ,., .,:. ,.:. ,.:,... .... .,. .~. ,_, ,, ,::, ~. ,..,..,,: ~:..:.,,..., · -..., ,.., ....... * 61. !800~ ~c, 0 S 34 0 W i0."",, 1.7"'"' 60 .Tf338,,"'-'Z 142c",60 Sn':",95 S 15.r::. ,':.c.': -' · ~ ."450 ':"~ loon,, .~,~7 4._ S 74 0 W .1.00, 1811,61 3395,t::i: t72.1,61 ,. ,,..:._, :, 188,2.4w" ............ -. . 2000+ 44 0 S 34 0 W 100, 1887,19 460,59 1787,,19 .404,,55 S 2 .t. 0 0 · .49 ,.'3.'.. 0 S 3; 2 0 W .1. n ...... ,:.,., ~ .1. c,, .-:.:,.., ~ ,~, u ~: .... ...~':; ,_, ~ ._.7, 36 ] .... o'"',..'::i '::i ,6 8 .,,-" ,'-,_", ~:'.., · .:51. .-,'"'_. '".,.:,,:00 ~'-' 49 0' S ' '3;2 ..... 0 W .... 100, .... 2020 ~'95 ...... 609 ~ 0:3 ' 192() ~ ""'::'.:, _ ="~'"~,..,,:: ,, ~ ::-;"' 6 S 23300, 48 · ='' S '" 1 0 W 1 O0, 2086 ,, -") ': "-' '* I '",q -"~ '::"-' ;~ 08 S · 4 ,... -:) . ... ,.. o o-¥, 2 .'.1 9 o .., / .... ';' ~ · .,:: 4 0 0 · 4.'3 .1. =' --:r n =;'-. o c:, '"-: =: 9 0 2 ,.',, =;---. ,: ,::'", c:, ,, ,... S ,., .- 0 W 10"" .,... ,_'T'I,..,-:., , , , .~,. , 2 ,, ._ ~::, yg. ~.:. u/ · , .', S ............................ W W 2500, 48 0 S 37, 0 W J. O0.~ ~.")"'1~.:: , · 733 :::":3333, -,':t2.. , 2.t..1':;', 73, vx, nn 47 0 S 3,'3 0 W J. O0~ 2287,v'':;' 907,1'.' 2:,(87.,'"'9,-.. ,,.. -..) x.,- ,,.,- * .~,. e . .~-. ,:.,,:. · · z ,,: .......... 980 07 27'00' 46"45 S 33 0 W 100, 23,.o,ou O.~".~ 4 2 '"' -'z 2424,6Fi 1 .... "~8(;0 46 0 S ,:),_ 0 W I00, ..... x..,,,: 4 ,, 65 290C:.., -45 45 S 3;3 0 W 100, o4?-4,°-..' ,,., ';1..1. ''~ '~ 1 7 ":' '':~ ":;'4'"' ";', 720 ~ 7.4 S ':/"::'"~ '":';-? S / ~.) .,,,'...:. ,,,.... 84.3., "";"/o S 904,49 .::~'-' 96-4 · 6 9 S 4233~.I. 1 W · 463,27 W 5033,02 W 5.42,44 W 581,53 W ~:~:35.~ 76 S :3 0 "'>'::' W C. 7 9 ,., ,',~, ;.) .~ °;",9,4 .1. S XC: 33'7 bJ 'I. -.- ::}':'" "-i;'82,'334 S :30 48 t.,) 0,25 :I. ¢., ..,'::.' 4,6 8 .q 3 o. 5 7 W 0,75 1126., 4 2....,"::' ,.:'7 ..... ,. .,' W ::') ,, 2 5 :'AB A~ WELL NOt 5 GMS JOB NUHBER: A881G0500 TIHE DR'I'E :.iUF:'AR,LJK ~ NORTH-c:l,_,~_,'l-~ .r.~r.:-"~-:~ .,~.~t...~c,k,~.~.~,*, :'"~ ' ' li ~ 02 ~ 04 08-.OCT 81 3000,, 45 1':::,.:. ,..."--;.. 33 0 3100,..,,"L ....,~ C',.. S 3~ ~ 0 .7~nO ~ 45 ' 0~, ~ .... .:>,c" 0 3;300, 45 15 S S2 0 3400, 4,5 0 S 33 0 · 100, '"'=' ' , 36 9~::; .,~,.,o 4 J. 1 ,47 2464,''Cz 100, 2634 ~ 91 1 '-' 6 ': "~ ~' '::"~ ' 1009 2705,62 1336,9I ~.°60'::'~62,.¢ 100, 2.776,18 1407,69 2676,18 .]. O0 ~ ¢:"*' 46o, '?S 1478, ..=; 1 2'7a6, . · 7'3 ...... 75009 44 15 S 33 0 W 10,:"..',.. .,...--~ ¢, ]. v, , , ~I, l'::;aR, 72,. , ._2817,°1,. ~ ,.:, ~, ,~, ,. ,.. , ". ,.., , ,, · u 9 1617,0 a 2890 · ,,'::~ q~, 3700, 40 1~ S 35 0 W :I. 00~ 3066,2.[ -..,. , ~, . ' 1 ,:682 ~ 83 27¢;,6 · 2 :L 3800, 36 1=., S 35 0w" .,.~0'~,,, 31744~78 lV44, ,72 3044,73 3900, 33.,~,, ,..~ 3=o 0 W 100, '~22A~88 18ni,71., 3126,88 4000, 30_ 4=.., S 35 0, W 4:1.00, 27 45 S 35 0 W 4200, ' 25 O' S'36 ~ 0 W · 43.';00~ 2,; 0 S 37 C, W -**,',~ o4 0 S 38 o W 4 c.'; iR 0 4700 -48009 4900 · 5000~ -~o '~0 ="00 "'"' 0 ,J J. , .c~ ...C 52009 20 '15 S 5300, J. 9 0S 54009 18 0 ~' · .m'. =' £-~ p ,.. 5600, ].5 0 S 086,6"':".-- 1:[.1.1,42 134., P.::, ,.~':':' 158, Yi ! 83, ?6 '20 9 · 0 '7 . 5700 ~ ' 14 .... O' c: ...... , -'-' '" """-'"' - - ":'0 -'-'~' " ", ,., 44 0 "t.,J I 00; .... 4 U,~:: ,., = :, 98 ..... 2483;, ,:, / -~- / c, .J · '7' b: ., .... ~'. + 29 ~ I ..~ o-~'" * ~ 49 n,', · 4883 22 ........ 58009 12 '"~ :-~ 43 o W :I.,,,.,~ 4983~.42 2~'05,,-''' ,.. ........ : ~,u 9 , . 2u/c.:..,61 g; i3979:,.. ='" '" o W 1 O0, 0 ,. ~4994 ~ ~ ';, ,"', ,.';, 'T, .,'."0,¢0 .1.0 1=' S 4=; .......... -4 o ....... ¢ ,- .. 5 U,~.~ i b 3 2"";'-' 498 ,:.- ..... o " W 1 f''~ i..'~ .' o ,.., ~, W 1905,5°. ,, W 1949993 W 1791 ,.. u,, 1 ~ 7 W 2071 , '"' ': t:,~ 2 J. 1 ]. ,: 65 W 2151,19 t,.J 21 ,';,,~r, 1.4 W ,-.,.-;,:'., ,,z., 4" · "; '~ t ''':f ,~ W .,::,:, C ..:, 7" d id . .-,-,-~r-, %/ ;.'. .cl,;')..S, 7 · · -'..~7.,~, . W '-' ..... -48 2403~82 W 2432,86 .,,.., ; ..... i,,/ .,,: ,4 o 9 · 3 ":,2 W ,"', .4 ,.':)"Z C) .~,'~ "¥ ~...' '..~ 4' .. "..-" L.,.J 25 O 6, i O !,4 2525 ? :[ 0 S U F;.' E DOGL. f"G D I R E C T l '"' ~'' c. r-:'~ ~E' R ' o,; ._,_,,.. i]"Y Il i'i D G /t () 0 ::' 7' S 3~., 1.6 8 3i :I.E', W ,:3~00 S . ;.31 ,.. '') t. W 0 :~ 3.';1 ' "''''W ,'; 7 .#. ,~;. ~? ...~ S 31 =;9 W ;2,=:''' ,..(4,..,"z '7,.,. :2:'w' ..~:-' O0 S 3;2 8 W 2,7';' ¢'% o .7f2 .1.4 bJ S '32 :'.2' 0 t.:.,' 0,41 .q -.~- o 2 6 W ;3, :.-7.-.; 0 ~. %..: :i; :;:!;2...,";~t W i , ":'""., -~, S :.'ff';;: ,35 ;,,I 2, '.7::';;' S :;3:..3 4,.3 W .,,., ~..-,'" "; '= C' "-~ '' "% ,-, ;7'.', 5:L w e.:,i ~-.,r' $ "" Ld J S J!;3 I/ · :ii!: 7'; 3 25 J,,J I ~, 29 c:; "z ~. "~,"' i,,J I ,,..,"' ='--, S .]!;3 S'.';' ~,..l J, .,"':"',.::,,.., S :.33 46 W :!.,2~:3 S 7 3 53 t,.j i..:. 07:'.': S 33 58 W 2., .C' ~' .,I '") .:.,::,-, .~ W ~.~';"'? :~)::i A, WE:I...L tqO~,.,~:' Giq~:.' q JOB NL.IHBE:F;'.~ A881I',ub;;}027'- TIHE UF"ARUI"(~ NORTH SI_.:Ol::'E~,' ,..~L. AoI',A :J. 1 "'- ...;04 C: 0 i'ii::' L.i T' A 'T' :t_' 0 0,=,-0C l ....o.1. 34 6 W 74 ':.?W J.412 W S 3416 W 3.420 W S 34 45 W :..-~ 34 51 W S :34 56 U S 35 3 U · :,.J 7 W T R U E ~" '"" "~ ......... ~i~''''''~'~'' · E' (3 U EASURE:D ,.,RtF"[ ..... I)tRIF'T 'COURSE VE:RTI'CAL:"VER'T]:L:~... o,.oc.~:.~.~ F; C T A N L. A R c:, ~R" ,.. 'l" IEF'TH ANGL. E DIRECTION I...,..,,~TH DEF'TH SECTION TVD ?' 0 0 R :0 i ,'~' A E S DISTANCE F' E E T D H D N F E E: T F' E E T F' E... ~' T , ~::' ,_ ~... ~' c--r ~ F' E E T F' E: IE 'T' . ........ t~...~4 W 1 · .~ ..., ~ , ~. . ~ · 6 t00~ o 0 ~ 43 n W 100. ":: '~='° 95 '~ ''~ '=' * ~' ........ '::' :3 ' ''~ ' 4 .zn - ' 0 ,. ~' ............ :1.4ha 06' 6200· ~ ..,~ ~:~ 44 W 100, 5~78cI~ ~5~.8 ~ 96 oZ/U ~-'t5 212~,.. ,:'°~ S .... -., ~,~ ,:.'~:i-~' o,.,~ ,- ~ .... ............ ~ !::' ~ ~i:,400, 4 ' = S 53 r, W O0 -. o~:-~.--, 94 .,4/, I ]. "" q ........ ' ~'':' O0 · 4 a:..., 84 ~.. ~ .~.. .... ....... '~, ...... 2601 =:.47,4 ~, 45 60 W ~'" ¢ ~ ........' ' ,., ,A, 10u, 0876,"45 .... 2'e06', 64" =:,~ ~, ~.,, ~ ,., ~'A5, '~,: 14 -"/~ 89 ,.,~::1..-4 -~ ~f:, ....~ ~q":;', W .<,-z~ 06~ 6 5. , o U I "' i 0. =' ~' · ~ " aOO0.~ ,._?45. S o4 0 . lC),:],~_ 5iC;'TA, ~'% ~.e:.- u~ 5876_ . ol 214~', ~..90 ~ 1481,94 W Z(~lO"' .~,~s~', ....~,~ w 1 · 6 . 6~ly ,:.,..13 ~ 72 5976~I°,. 2.~49.,U1 S 1486~92 W : /000, .3 0 S .,., 0 W I~0, ~.,6~05 "'17~7 ..... z ~:; ...... , ..... 7100, 3 0 q o~. I "' z~,~ ~'=, ~ '-:~=- ~, ~. ~ ~':, o . .... o'~ 0 W ,.~ 1477~34 W 2620,58 "~ ? 'q O, .,.. ., ~ :% ...." 0 N U7 0 W ~,.00,..~,~,, .,.c.,. 1502~57 W ~:62,~ 49 73:00~ 3 C, N 78 0 W 10()-.: '~iT=;-/,~i ..... '6;/~::~12o/.':::/:.'-~77;]A4 7"149.c;'0 ~; 1_507,76 W 26°591 74C'()~ ? 45 N 69 0 W ~'.~ ~8 o ~ ]..~.~.~uo U' ~,~ ~/ ~ · .... ~ ~ ~. : ~ ,-- 0~21 0.2.1. O~ .4 Y 0 · 3 4 2627,97 2 6 27.7 8 0., 0 FINAl ....... r:l OSURE' .,.-- ']3IRE:CTION ~ -. ..,'=" ,.,~'""..-qr=,":..c-,, .,. ,...,..,._, ..:"'=", f'~iNS, 15 SEE:S W DISTANCE ~ 2627~ 78 FEET PAD ...... ' '~- ' =i7'-~ ~' ...................................... . .~'FI~'."".~Li~ ,;~:~z:~'~ .~' ,,.-'-:.~ ...... KUPARUI'(.., NORTH SLOPE], Ai._AS~:'A G~'i~:''' '0-...~' SUR"~EYOiS'I '~' i-'l ...... ~-':-~,i,, R~tN DAT'"' .., ,.,, .,',.~00 MD, .~. ,,.~.~ ~. ~_.r,.d~.,,'-.. .. , ~.. ~ 3F~.."Ai ......... Iri-..:::~ I ,.,~--~r~z~ NO: 121S GYRO NO: ~]66 9r, BEG A/U NO: 11'.°1 F'ORSIGt-iT: N 0 E RIG: ROWAN S4 ................... ' ._. ~'~ u, ?l ,-, ,... ,*. I ASSt ~'~.Ki A.~ WEt...L N. OI 5 GHS .Ir1B ,,,~,.-oc,", GO500 '"IFiE DATE ' ~'*.~"i~' NORTH" SKOF'E~ ~ '~ CODE: ':"; .... ;";' .......... ~'iE*':''''::'':'r~ ~'~'~ .... ~c.*, ...... '~n ~r,--,-,~"~',~'rr'~ '", E 'f .... I' ~i N f:l tJ R C L 12 c; l.j l'( E ~'EF;~T. ...... . ..... ........................................ ~l ....' ~"~ ' ~I C i*~ ...... ' .. 'f'l . N A Pi E D E F' T l'-I ,. E l- , r'l D i F' F E F' T H U i'< d ]: i'-.{ A T E q I} l E; T A i'4 C E .. l R E C T I 0 i't T l--I l C'" "' ':' ¢:' '::' F E E T F' E: E T F' E: E T F E E T F:' E E T F' E E T .................................................................................................. TOP ,~JF SANT]R 6824~.00 AanO '~'" o.-:,= =: -, ;.i~:;, ii; W , ~o~.7 · 823 '" '~03 ~ 2S 2147 Fl ~' 6219 oe 0 .~1='.-,= ...... T~F' L...,W~.,. SANDS 70~4 0'~ 824 61t9+°° ,¢,~ ..., .... -- q , -, q ~, ~ - -' o ~. ~ .... 26 ? f:' :32 =' '" t ..... WEa SAND.. t:,t:, ~.., ~.,.:, E. 70 ,S 9' Z 824 + 1 61,67 ~ 9' 2 2 t u, 0 + "=' S I ~i ? 6 ? 2 ~' q 34 ica~'c Kt. JF' SANDS 713~+00 630G:+87 ¢'":"~ :I. o,,. ~.., c:, 20 S ~ 87 2 :i. 50,, 6 ~. S E) i.. " RLI soO i · iTRT!ON: i : DEPTH?'/6?5 ' i ;~t40.82 ' WEST 1524.20 . i , : i SEC 5,~ :T11N - · ~RRCO ALASKA, INC. --~ .... -. , VERTICAl-PROJECTION. PAD R, WELL .NO:~ .5 GMS . !'. ~. '~.~. i ~ SCALE I IN. = lO00 FEET '' KUPRRUK, NORTH SLOPE, 'ALASKA ERSTI'IRN WHIPSTOCK~'INC.!'..-' ! ..... ~"'.' i . ': . i ~ - ...... I : · · i Suggested form to 1~ inserted in each "Active" well folder to check for tingly compliance with our regulations. v',' Operator, ~e[1 Name and Number Report.~fd Materials to be received by: , ,~)~/, ~,..&.;~f~£ Required ,, Date Received Remarks Comp letion Report Yes Well Histou Yes . , , .Core ~scription ~ ~~ . .~egistered Su~ey ,Plat ~ ~ 7--/~ ~] ~ /~ Inclination Su~ey ~ s . Dire~ional Su~ey ~~ ~[, . , Drill St~ Test Re~s ~,~~_ .. . NORTH ~$LOPE EHGINEERIi~G TRANSMITTAL TO' /~/~ ~ ~ FROM: J. J. Pawelek/Ann Simonsen DATE' //~)-Z- 9/ WELL NAME' Transmitted herewith are the fol'lowing' PLEASE HOTE'~-BLUELII.IE, ~)- SEPIA, F - FILM, T - TAPE RECEIPT ~,r,~u,.,L[DGED DATE- ~/~LEASE RETURN RECEIPT TO' OCT r~ ARCO ALAS~UN, INC. - ATTN:p. O. B oANHx 3 6 S IMONSENo - AFA/~Oil~chora~~asc°ns'C°m~issioo A~CHO~A~E, AK 9~510 NORTH 'SLOPE ~'~'P-I~.,EERII~G~,,~ TRAHSM!TTAL # ~ ~' TO' ~/~ ~~ FROM' J. J. Pawelek/Ann Simonsen DATE' //D-'~. ~/ WELL NAME' Transmitted herewith are the following' PLEASE HOT~- BLUELIHE, ~- SEPIA, F FILM, T - TAPE RECEIVED ~_/~_~~~....~~ OCT 06 ]981 RECEI PT ACK;;OWLEDGED DA~i~ika [Iii & R..~ Con.~: Commission · ~ -" ' -- Anchorage ~PLEASE RETURN RECEIPT TO ARCO ALAS~UN, INC. ATTN: AN~I SIMO~tSEN - AFA/311 P.O. BOX 360 ANCHORAGE, AK 99510 DATE- ./o '-~- o~/ WELL NA;.iE' Transmitted herewith are tile following- PLEASE IIOTE.'.. BL - BLUELIilE, S - SEPIA. F - FILM, (/T~- TAPE RECEI ~F ACK;~O',.:L::DGF')'-"[// C':'~~ -:l~..~.-:[~.~ -._ .. ' 1.98] /'~ PLEASE EETU,q[~ f~ECEI?T TO: A,:CO ALAS~3~I, IbC. ~ias~oitS6a~COns' ATTN: AN[~ S IMO?iSE~! - AFA/3I 1 ~chota~o C°~o~tSsio~ P.O. BO: 36O A~,r~n~> '" NORTH "SLOPE ENGINEERIHG (' TO' TRAHBMITTAL # ~~ Transmitted herewith are the following' PLEASE HOTE:~- BLUELIHE, ~SEPIA, F- FILM, T - TAPE RECEIPT AC .... ~'~-F. ~ ['.,~ iU,', L EDL~ RE, u,.,~ RE~.~_ I PT TO DATE: RECEIVED OCT 0 5 ARCO ALAS!CA, Ih'C. ATTN AN;i S I;m'~c '~ - ~mlmOil & Gas Cons. Commi~ion · ,,~,.i,,.~ El.., AFA/31 P.O. B OX 360 Anchorage ANCHO~,~=~-, AK 9~51. 0 ARCO Alaska, Inc. Post Office BoX 360 Anchorage, Alaska 99510 Telephone 907 277 5637 hand delivered SAMPLE TRANSMITTAL · SHIPPED TO: State of Alaska DATE: September Alaska 0il & Gas Conservation Commission 3001 Porcupine Anchorage, Alaska 99501 Attn: Mr. William VanAlen OPERATOR: ARCO SAMPLE TYPE: dry ditch and core chips SAMPLES SENT: core chips': 371 samples 6797 - '6919' 6919 - 6958' 6940, - 716'0' 7152 - 717.1' (one foot intervals} NAME: Kuparuk NUMBER OF BOXES: eleven dry ditch: Box #1: 90 - 1350' 2 .1350-- 3120' 3 3120 - 5190' .4 5190 - 5580' 5580'- 5610.' 5620 - 5650' 5640 - 7675' · '~thirty foot intervals) (330 - 360' no sample .. ' (5790 -5820' no sampl ~UPON-/RECBIPT OF" THESE StaPLES, ,PLEASE NOTE ~Y DISCREP~CIES ~D ~IL A SIGNED COPY OF THIS FORM TO:' , ARCO ALASKA, INC. " : P 0 BOX 360 , :. ANHCHORAGE,. ALASKA' 99510 ' ~:' ' r- ,'"',' ATTN: R. L. BROOKS.. ...~ .~ ~,,~ /__.~~. SEP2$198! 'RFrFIVFD SEP 2 3 198t; ARCO NORTH '~LOPE EiIGI~,IEERII~G J. J. Pawelek/Ann Simonsen DATE' ¢-//.-' ~'/ WELL,,.,-,,.t._~"""~" . · Transmitted herewith are the following' · F- FILM, T - TAPE /CDT- DATE' ARCO ALAS!iA, INC. ATTH: Ar,I~I SIM0?!SE!! - AFA/311 P.O. BOX 360 A~Ct!r,~ .~ ~'~' 9951 ~,~,,u~, AK 0 RECEIVED .__ ~r'm . ,~r- ~ 4 198J Alaska Oil & Gas Cons. Commission Anchorage ( ( ALASKA OIL AND GAS CONSERVATION COMMISSION Hoy le H. Hami lton/~~ Chairman Thru: Lonnie C. Smith Commissioner Harold R. Hawkins Petroleum Inspector August 18, 19 81- Witness BOPE Test ARCO, ~_a?uk a-5 Sec. 7, Permit No. 81-104 August 14, 198I~ I left ARCO's DS 12-13 where the BOPE stack ~s-~ing ni~p'~ed down, subject of another report. I went to ARCO's West Kuparuk A-5 to witness another BOPE test. _A_ug~ust_ _15~_ 198~1 .. I wi tnessed the BO~ test on ARCO ' s West Kuparuk A-5 Well. There were no failures. I filled out an A.O.G.C.C. report (attached). · In summary: I wi~essed the BOPE test on West Kuparuk A-5 for AR~. The tests were performed adequately. oa<; #4 STATE OF ALASKA ALASKA OIL & -CAS OONSERVATION C(]v~.~SSION B .0. P.E. Inspection Report , _Inspector Operator_ ,~ ~. k"~ Wel 1 _ .~ -- ? Location: Sec~ _ .7 Pril lin~ Contractor Representative~_O~/ /2 ?j>~c ~ 4C,.n .... Permit #, ~'7.-- / ~ ~/ Rig # ~L~___R~pfesentative-~ ! D .ff /Ol~r,,~ ~.~ ~ .al._) . . Location, Genera~ Well Sign_ Ceneral Housekeeping_j2 ~' Reserve pit ~_d~ BOPE Stack Annular Preventer Pipe paros Blind Rams Choke Line Valves__ H.C.R. Valve Kil 1 Line Valves Check Valve__ Test Pressure .... ACCUMULATOR SYSTEM Pull Charge Pressure ~~ ~ psig Pressure After Closure / .TJP psig Pump incr. clos. pres. 200 psig min.j~--sec. Full Charge Pressure Attained: 7 __min ..... sec. ~2AJt~,2~23~ 2~ ~ p. siq N2 Controls: ~iaster ,-----, .R~_~_~___B_!i.n_ds_,s!l.i_tdl cover Kelly and Floor Safety Valves - Upper Kelly lower Ko1 ly. Ball Type Ins ide BOP_ Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold. vanes _ _ NO. flanges. Adjustable Chokes ,,. d'.~' _~_~ Hydrauically operated choke Test Results: Failures ./L2~2/Z" _ Test Time' ? _hrs ~' - ., Repair or Replacement of failed equipment to be made within_ '---- days and Inspector/Ccmmission office notified. Di stribut ion orig. - ~.O~&CCC cc - Operator cc - Supervisor ..SA. July 20, 198 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. Oo Box 360 Anchorage, Alaska 99510 Re~ Kuparuk 25647 A-5 ARCO Alaska, Inc. Permit No. 81-104 Sur. Loc~ 899'FSL, $11'FWL, Sec 5, T11N, R10E, Bottomhole Loc.: 1320~FNL, 1226'FEL, Sec 7, TllN, R10E, UM. Dear Mr. VanDusen ~ Enclosed is the, approved application for .permit to drill the above referenced well. Well.- samples and a mud log are not required. A directional su~y is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish., operations in these areas are subject to AS 16.50,870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code ). Prior to you may be contacted by the Habitat .Coord~ ~tce, Department of Fish. and Game.. Pollution of any waters of the State. is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative C~e, Chapter 70)and by the. Federal Water Pollution Control Act, as amended. Prior to ~ Mro P. A° VanDusen Kuparuk 25647 A-5 -2- July 20, 1981 commencing operations you 'may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling fiel~ work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dri-~ led. In the event Of ~uspension or abandonment, please give this .office adequate advance notification so that we may have a ~tness present. verY truly yours, Hoyl H. Hami 1ton chairman of Alaska 0il &~v ~~ ~ ~_~ ~~. _~,~s~fr~i~.~=~~sion cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environ_mental Conservation w/o/encl'. ARCO Alaska, Inc.' ~ Post Office B~..R 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 15, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Procupine Drive Anchorage, Alaska 99501 Subject: Kuparuk A-5 Dear Sir: Enclosed please find the following: le 3· Be · The application for Permit to Drill Kuparuk A-5 and a $100.00 check for the application fee. A diagram showing the proposed horizontal and vertical project ions of the wellbore. An as-built drawing of "A" pad indicating the proposed surface location. A proximity map indicating the relative locations of Kuparuk wells A-4, A-5 and A-8. A determination of maximum pressure to which BOPE could be subjected. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. Please feel free to contact us at 263-4270 if we can be of~ any assistance. Sincerely yours, P. A. VanDusen District Drilling Engineer PAV/DSS:pcg Enclosures RECEIVED Alaska Oil & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA " ALASKA ~.~ AND GAS CONSERVATION C~..,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ]~X lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] .EDRILL [] DEVELOPMENT OIL J~ SINGLE ZONE [~!~ C~*"E~)~'~--I DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2, Name of operator ARCO Alaska, Inc. JUl.. 3. Address l~laska Oil P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 899'FSL, 311'FWL, Sec 5, TllN, R10E, UM Kuparuk 25647 At top of proposed producing interval 10. Well number 1320'FNL, 1226'FEL, Sec 7, TllN, R10E, UN A-5 At total, depth 11. Field and pool 1320'FNL, 1226'FEL, Sec 7, TI. IN, RIOE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.)J 6. Lease designation and serial no. Kuparuk River 0il Pool 61'6L, 66' pad,__100' RKB ADL 25647 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number Fed :[ns Co #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to neares{ d[illing or completed 30 mi NW of Deadhorse miles t[at TD) 3685' feet we, (at_ ~lJ~f~ 120 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approxi~nate spud da'~e 7658'MD 6785'TVD feet 2469 8-10-81 19. If deviated (see 20 AAC 25.050) J20. Anticipated pressures 2592 psig@ 6(]0 Surface KICK OFF POINT 691 feet. MAXIMUM HOLE ANGLE 45 oJ (see 20 AAC 25.035 (c) (2) 3093 psig@ ~960 ft. ~ (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) 36" 20" 94# H-40 ,~lelded 80' Pad I Pad 114 ~1114 350 sx AS II 17½" 13-3/8 72# L,80 BTC 3090' Pad ~ Pad 3124 12700 2020 sx Fondu & 400sx 12¼" 9-5/8" 47#. L-80 BTC 6599' Pad Pad 6633 15760 1015 sx Class G 8½" 7" 26# K-55. ~TC 1325' 6333 J 5460 ~7658 16785 430 sx Class G I I ' ~ I 22. Describe proposed program: · ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparuk River Oil Pool develop- ment well to approximately 7658'MD, 6785'TVD. Selected intervals will be cored & logged. A 20" x 2000 psi annular diverter will be installed on the 20" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA DOPE stack will be installed o.n the 13-3/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressur.e will be 2592 psig based on cooling of a gas bubble rising at constant.volume. The well will be completed with 3½" 9,'2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the perma- frost interval. Selected intervals will be perforated within'theKUParuk formation a~d reported on subsequent reports..A downhole safety valve will be install~ed and tested upon conclusion· of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge S,GNED ~~ . _ _ _,~.. T,TLE Dist. Drilling Engineer DATE :::r'u~.¥ 1~,, The space below for Commission use CONDITIONS OF APPROVAL · Samples required Mud log required Directional Survey required APl number []YES ~[AI O []YES ~NO ~;i~'Y E S []NO 50- ~:) Z ~- -- Permit number Approval date (:~/-/~z-/~ ~l?/2~l/R1 J SEE COVER LETTER FOR OTHER REQUIREMENTS. '~~~, ~ ,COMMISSIONER DATE .'h~l~x '~tl 1 APPROVED BY by order of the Commission ----.z --, .... Form 10-401 Submit in triplicate Rev. 7-1-80 ....... - .......... ARCO'ALASKA, 'iNC.' ..................................... ~"~--~~ PRB R, WELL NO: 5 PROPOSED %11/ KUPRRUK FIELD, NORTH SLOPE, ALASKA '"" SCALE :1 IN. = 1000 FEET ....... 2000 ERSTHRN WHIPSTOCK. INC. S 34 BEG 43 H IN E 2699 FT (TO TRRGET) ' ' ..... : 2000 i000 0 ' - _ ...................... 0 .... SURFRCE .......................... ;, ............................................ m m I ......................................... ......... 1000 ..... ............ :...m.,-3000 · ~ .......... ~ 4000 - ~ .................... 7000 EOC TVD=2044 THO=2194 OEP=562 ..... J 7 e · ' ....... ' ;. -. I~DFT /' I '~CRSING POINT ' I. / - I i %JVO=2?O0 THD=S124OEP=1220 J / I : ...... ~-"% BEGIN DROP ............................. ,,~ .-. .... m TRRGET ...... 44 TVD,.3054 TIID.~2$ OD=IS?6 [ ~ ~ laa6 FT J TVD=5960 ~ 4t TOP N. SRK SANDS ' t ~"-]-~ =I L_: ....... ~ ...... :'.38 TVD=3230 TND=3867 OEP=ITel--.-/ . I THO=6839 DEP=2699 : · ~ K-12 TVD=3530 TMD=4251DEP=1981 I 3a SOUTH 2219 ~ ...................... ~ ....... L_ ................................. i ............. i ....................... WES? 1537 ........... 20 ._ ;1'7 14 AVERAGE ANGLE · 45 BEG 6 HIN e 6000 ................ ' ............................. 0 1000 2000 ........... VERTICAL SECTION . i _ 2000 .............. _ 9000 .................. DROP I I/2 DEG PER 100 FT ~ - . i ..... ~-:'.: i~ : .~--.: I ..... END DROP TVD=5760 THD=66S9 DEP=2699 K-5 TVD=5850 THO=6723 OEP=2699 :' TARGET (TOP KUP SANDS) TVD=5960 THD=6833 0EP=2699 TOP LOWER SANDS TVD=6150 T~D=7029 DEP=2699 BASE KUP SANDS TVD=6260 THO=7133 DEP=2699 LOGGING POINT TVD=6460 THO=7339 DEP=2699 TD {MRX) TVD=6785 THD=76S8 DEP=2699 ! ,ODD R'E'CEI1/EI) ........... ........ JUL ! S .]981 ..... ~ .............. ~ - _ ...... ~ ..... Alaska Oil & Gas Con~, ' I WELL A1 Y = 5,971,467.25 ' I " 1 X = 540,'1 78.17 ' ' : LAT = 7~o 19' 58.741' ~ .~ [ , < ., : LONG =_ 149040'26.679'' : I~. I WELL 'A2 ~Y = .5,971,34'6.82 ~1~-' Al I X = 540 178 32 I ~ ~ LAT : 70o19'57.557'' , > < ~ ~.: LONG = 149°40' 26.693'' ..... ~__i~_~__. :A~.~ ,; ., WELL A3 Y = 5 ,971 ,227,31 X = 540,178.51 < ~ : LAT : 70019, 56.381" ~l~I A~ ~ · ~LONG : 149o40'26.707'' > .~, WELL AL~' Y 5,971,\106.83 ~ . X = 540,178,52 ~i2.' AZlr --- LAT : 70o19' 55. 196" I - _ : -~ LONG : 149o40 26 725" < WELL A5 Y = 5,970,986.86 ~ X = ~'40,178.61 ~ , "~lJ A~(~ / LAT : 70019, 54 016" > ' .. · LONG : 149°40'26.741'' i I J ~lO' ~AG(~ :~ WELL A6 V = 5 970 866 70 ..... . X : 540,178.71 ' . LAT = 70°19' 52. 834" : ' J LONG : 149°40, 26 757" A,'/~ ~. WELL A7 Y = 5 97O 746 73 ................... , , · > ' ' X : 540,178.55 ' ! . ~ , ,, LAT = 70°19' 51.654" - ,~ .... LONG = 149°40'26 781" ~o71 A6~__ .· W~T ' ! ' ~AGi~'lr2- WELL /<8 Y = '.5,970,626.78 ' ~ , x: 540,178.59 LAT = 70o19'50.475'' > ~'~ LOjNG = 149°40'26.798'' RECEIVED · ~' Alaska Oil & Gas Cons. Commission ~~~lI) ' " Anchorage ~ ' , [' ,' ' ..:-?~..'-.:..:q.fi~,~ ' HEREBY CERTIFY THAT lAM -_=:"~"'¢'~"' ~' PROPERLY REGISTERED AND LICENSED - ~-S, .... .."~:" '.-~ ~ TO PRACTICE LAND SURVEYING IN -'i: ,.t.~....,.--r..: ...... . ..Z,,:~' ','.~.,.... THE STATE OF ALASKA Al, ID THAT / "./'/ ///,.2' /.. [: ..... :'--':'": ......... ~"' THIS PLAT REPRESENTS AN AS- // //" ~. .... ,"',":~t'~'": : "'" ~,,,, (/:.~,.:, ,,.~_;~.m,, .:~ ~.-' THAT ALL D I HENS IONS AND OTHER ;.. ,, ..-., .... '.~< .,~. ~.;.'.,r-~'X ~,',',-~ ...t-,'" DETAILS ARE CORRECT, AS OF: , :.. ....... .,' '-I '..:-:' DATE: ' ~'../" '" Ir,., "~'~?/'~'~.r.~il, t ~ '. ' "\~, ,~. . . AtlanticRichfieidCompany ~ DATE' DRAWING NO:' NORTH AMERICAN PRODUCING DIVISION iO.,Z.~O .. ALASKA DISTRICT- KUPARUK ii i ii I . ~500 ........ 400 ............ 300 ............. 200 300 201~' 100 I I IXlUM i I-I 0 I 200 I 300' I .. _ARCO ALASKA, INC. " .............. PRO R, NELL NO: 5 PROPOSED KUPARUK FIELD, NORTH SLOPE. ALASKA ERSTi'IRN NHIPSTOCK, INC. 1 ............... 200.. ...... ~ ............ 300 ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3093 psig from RFT & pressure buildup data. This pressure @ 5860' SS = 5960' TVD will be balanced by 10.0 ppg mud wt. Normal drilling practice calls for a 10.4 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 130 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2592 psi during drilling operations. Derivaton assumes a gas kick at reservoir temperature and pressure (160° F, 3093 psi), gas migration to the surface w/o expansion, and cooling to 60° F summer cellar temperature. This is well below the 5000 psi BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Pf = pressure final (surface) Ti = temperature initial (reservoir) Tf temperature final (surface) Vi : volume initial (reservoir) Vf volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf ie no expansion Pi = Pf ' ~ Ti Tf Then Pf = PiTf = (3108 psia}(60°F + 460) Ti (160OF + 460) Pf = 2607 psia = 2592 psig RECEIVED JUL 1 6 1981 Alaska Oil & Gas Cons, Comm{ss/on Anchorage Surface Dive .r System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pi't. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. 16" Conductor RECEIVED JUL 1 6 1981 Oil & Gas Cons. Commission Anchorage ance & Operation ~-- 1. Upon initial installation close annular ! preventer and verify that ball valves ! have opened properly. I 2. Close annular preventer and blow air ~ through diverter lines every 12 hours. ~ 3. Ct~aO~eg~nular preventer in the event or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not Shut in wel!... under any circumstances. r ~-5/8" 5000 PSI RSRRA BOP STACK~ ANNULAR PREVENTOR BLIND RAMS 8 PIPE RAMS 7 ! SPOOL PIPE RAMS 5 TBG HD 3 CSG HD 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. lO" 3000 PSI tubing head 4. lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" 5000 PSI and kill lines 7. 13-5/8" 5000 PSI 8. 13-5/8" 5000 PSI 9. '13-5/8" 5000 PSI pipe rams drilling spool w/choke pipe rams bl i nd rams annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUHULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUIIULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAN OF THE REGULATOR. OBSERVE TII.1E THEN CLOSE ALL UNITS SIHULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING 4~ PUI.1P OFF. " RECORD 0N IADC REPORT. THE ACCEPTABLE L0;~ER LIMIT IS 45 SEC0;IDS CLOSING TIHE AND 1200 PSI REbIAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT A;~D SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MA,qlFOLD. 4. TEST ALL CONPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MI NUTES. 8. CLOSE VALVES DIRECTLY UPSTREAH OF CHOKES. BLEED DOWNSTREAH PRESSURE TO ZERO PSI TO TEST VALVES. TEST REHAINING UNTESTED NANIFOLD -.. VALVES, IF ANY, WITH 3000 PSI UPSTREA~.I OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RANS AND CLOSE BOTTOM SET OF PIPE RAMS. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTON SET OF PIPE RAHS BACK OFF RUN~., NING JOI;;T AND PULL OUT OF H~LE. CLOSE BLI~j~ BLEEDRA~'IS ANDTo TESTzERO TOpsi.3000 PSI FOR lO MINUTES. 12. OPEN BLIHD RAHS AND 'RECOVER TEsT PLUG. MAKE SURE MAHIFOLD A;~D LINES ARE FULL OF ARCTIC ~ VALVES ARE SET IN DRILLI,qG DIESEL AND ALL POSITION. 13.TEST STANDPIPE VALVES TO 3000 PSI. 14,TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOO~:EY PUNP. 15.RECORD TEST I~(FO.~,IATION ON BLOWOUT PREVE:(TER TEST FORI,i SIG;~ A;~D SEHD TO DRILLI:~G SUPER- VISOR. . 16. PERFCRi1 CC~!PLETE BOPE TEST O~CE A WEEK FU~ICTIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE .. Company, YES NO REMARKS (2 thru 8) e 3. 4. 5. 6. 7. 8. (9 thru 11) 10. 11. Cas~-~~ thru 20) .... thru 24) 12. 13. 14, 15. 16. 17. '18· 19. 20. 21. 22. 23. 24. 25. Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ................ Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .......................... Is a conservation order needed .............................. Is administrative approval needed ........................... Is conductor string provided ................................ Is enough cement used to circulate on conductor and surface . Will cement tie in surface and intermediate or production str Will cement cover all known productive horizons ............. Will surface casing protect fresh water zones ............... Will all casing give adequate safety in collapse, tension and Is this ~well to be kicked off from an existing wellbore ..... Is old wellbore abandonment procedure included on 10-403 .... Is adequate well bore separation proposed ................... · · · I i i I i i I · Is a diverter system required ....................... ~ Are necessary diagrams of diverter ~'~OP e~ip~e~t att~g~e~ . . . Does BOPE have sufficient pressure rating - Test to ~'~=~ psig11'~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. ., Additional requirements e e ~ e e t i · · e i · · · t · · ,, i · · · i · · ® · · · · · · · · · · · · · · · · · · · __ Additional Remarks: Geology: ~fVA~ JAL ~ Engineering: ~ \ Lcs/~--~ BEW ~ rev: 03/10/81 -- INITIAL " I GEO.' .... UNIT 'ON/OFF POOL CLASS STATUS AREA NO. .i SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special'effort has been made to chronologically organize this category of information. .. I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2Desc.: Pipe2 Use: ConocoPhillips Alaska Inc. Decernber24,2005 8011 2 3.5" 9.2 Ib J-55 Tubing 2-7/8" 6.5 lb. J-55 Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: Top Log IntvI1.: Bot. Log IntvI1.: 1A-05 Kuparuk Alaska 50-029-20627-00 Surface (MD) 6,998 Ft. (MD) 6,998 Ft. (MD) 7,010 Ft. (MD) Inspection Type: COffosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the Tubing Tail @ 7,010' (Drillers Depth). This log was run to assess the condition ofthe tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.5" tubing is in good to poor condition. A maximum recorded wall penetration of 46% wall thickness is recorded in Jt. 21 @ 649'. Maximum penetrations ranging from 20% to 46% wall thickness are recorded in 19 of the 230 joints logged. The majority of the damage is recorded in the form of Isolated Pitting. No significant areas of cross-sectional wall loss or 10 restrictions are recorded throughout the 3.5" tubing. The caliper recordings indicate that the 2-7/8" tubing is in good condition. No significant wall penetrations, areas of cross-sectional wall loss or 10 restrictions are recorded. This is the second PDS caliper ofthis well. A comparison between this log and the previous log (June 3, 2002) indicates a slight increase in corrosive damage. A graph illustrating the difference in maximum recorded penetrations in each joint is included in this report. The internal surface of the tubing in the C Sand Interval appears to be in good condition. The known leaks @ 6,854' and 6,883' appear to correlate with collars in this interval. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting @ @ @ @ @ 649 Ft. (MD) 818 Ft. (MD) 707 Ft. (MD) 861 Ft. (MD) 893 Ft. (MD) ( 46%) ( 43%) ( 40%) ( 39%) ( 36%) Jt. Jt. Jt. Jt. Jt. 21 26 23 28 29 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded. 3.5" TUBING - MAXIMUM RECORDED 10 RESTRICTIONS: No significant 1.0. restrictions are recorded. \ Ok'" ,<6\ ~\, Àt? r:tJ;JV ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prucilìoe Bay Field Office Phone: 659-2307 Fa>:: (907) 659-2314 I I I I I I I I I I I I I I I I I I I . . 2-7/8" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 6%) are recorded. 2-7/8" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded. 2-7/8" TUBING - MAXIMUM RECORDED 10 RESTRICTIONS: No significant 1.0. restrictions are recorded. I Field Engineer: R. Richey Analyst: J. Thompson Witness: M. Chaney ProActive Diagnostic Services, Inc. / P.O. Bo>: 1369, Stafford, TX 77497 Phone: (281) 01' (888) 565-9085 Fa>:: (281) 565-1369 E-mail: PDS@memorylog.com Pl'udhoe Bay Field Office Phone: (907) 659-2307 Fa>:: 659-2314 I I I Well: Field: Company: Country: IA-05 Kuparuk ConocoPhillips Alaska Inc USA I Tubing: Nom.OD 3.5 ins Weight 9.2 ppf Grade & Thread J-55 ßTC I Penetration and Meta! loss ('Yo wall) I penetration body metal loss body 250 I 20 to 40 to 40'10 85% 200 150 100 I 50 o I Number of joints allalysed (total = 230) pene. 0 loss 9 160 221 51 o 17 o I I Damage Configuration ( body) 40 I 30 20 I !O o I ISolated pitting general !!!ìE' flng hole- / poss corrosion COITOSlon corrosion ¡ble hole I Number of joints damaged (total = 46) 38 5 3 0 I I I I over 85% 2 o o o o PDS Report Overview Body Region Analysis Survey Date: fool Type: fool Size: No. of Fingers: Analyst: Nom.ID 2.992 December 24, 2005 tv\FC 24 No. 040665 1.69 24 . fhompson Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (°/0 wall) p(>netratioll body o o Analysis Overview page 2 Clivi I eLM 2 elM 3 GlM 4 elM 5 GlM 6 GlM 7 GlM 9 metal loss body 50 100 47 97 Bottom of Survey = 225.4 I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 3.5 in 9.2 ppf J-55 BTC 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1A-05 Kuparuk ConocoPhillips Alaska Inc USA December 24, 2005 Appro". Tool Deviation Appro". Borehole Profile GLM 1 CLM 2 CLM " J ClM 4 CLM 5 CLM CLM 7 CLM 8 CLM 9 225.4 o 50 Damage Profile ('Yo wali) / Tool Deviation (degrees) I Bottom of Survey = 225.4 I I 31 758 1522 2300 3056 ...: LL c 3815 ..r::: ..., Q.. Q) 0 4581 5355 6120 6943 6995 100 I I I I Well: Field: Company: Country: lA-05 Kuparuk ConocoPhillips Alaska Inc USA I Overlay Max. Rec. Pen. (mils) I o 100 200 213 I I I I Maximum Recorded Penetration Comparison To Previous Survey Date: Prevo Date: Tool: Tubing: December 24, 2005 June 3, 2002 MFC 24 No 040665 3.5" 9.2 Ib J-55 BTC Difference Diff. in Max. Pen. (mils) ,100 ,50 o .50 213 ... ... 11 OJ = .Q ¡¡¡ ::0 Z ::0 ... Z c ... ], c ], I I 225 I I I I I II December 24, 2005 .June 3,20021 I I I 225 -23 o -14 14 Approx. Corrosion Rate (mpy) 100 23 I SH EET Alaska mc USA December UlATIO A-05 Well: Field: Company: Country: Survey Date: REPORT )-55 BTC 3.5 in 9.2 0.254 in 0.254 in 2.992 in Pipe: Body Wall: Wall: ID. I I 24,2005 Min ID. (Ins. Pet 0 00 Body Metal loss I Comments pitting. pitting. It. Deposi~~ pitting. Deposits. Deposits. pitting. pitting. pitting. Isolated pitting. pitting. pitting. pitting. Isolated pitting, Line corrosion. Isolated pitting, pitting. Isolated pitting. Isolated pitting. Corrosion. It. Deposits. pitting. Isolated r~i!ting. Shallow pitting. It. Deposits, It. Deposits. l ~lt. Deposits. Shallow pitting. It. Shallow pitting. PUP PUP PUP PUP Deposits. Shallow pitting. It. Deposits. Shallow Shallow pitting. Isolated pitting. Shallow pitting. It 3.02 2.95 2.94 2.97 2.95 2.92 2.93 2.89 2.95 2.94 2.91 2.90 2.90 2.92 2.90 2.94 2.93 2.96 2.95 2.95 2.88 2.94 2.95 2.94 2.92 2.94 2.93 2.90 2.94 2.94 2.96 2.96 2.91 2.95 2.93 2,9ì 2.91 2.93 2.93 2.93 2.94 2.91 2.94 2.94 2.91 2.93 2.92 2.95 Ins. i! .l) 1 0.01 (UB (1.02 0.02 OJ)2 0.02 0.04 0.02 ~(1.02 0.01 0.02 0.02 0.03 0.03 0.03 0.02 0.04 0.04 0.03 0.05 OJJ6 0.03 0.04 0.12 0.06 0.10 O,Oì 0.06 0.11 (LOS 0,10 0,09 0.08 O.Oì 0.05 O.Oì 0.05 0.07 0.05 0.06 0.05 0.ü2 0.01 0·02 (UB 0.ü2 0.03 0.01 0.02 I jt. joint No. Ft. 1 4 15 21 31 63 94 l'J"" ~J 156 188 219 251 280 3JO 339 36~ 3% 42ì 45ì 48ì 51 54ì 5Z? 608 63ì 66ì 69ì "7') .... I~L..~ ì58 ì89 820 850 881 910~ 942 9ì3 1003 1034 1065 1095 1126 115ì 1188 1219 J250 1280 1311. 1340 13ì1 1402 ~~~ .) "'.) 15 16 1ï 18 19 20 22 23 24 'J"" ~.) 26 2ì 28 29 30 31 '')') j,"} 34 'J"" ~J 36 3ï ~J1L 39 40 41 42 43 44 45 46 4 "" .) ì 8 9 10 11 12 13 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.2 ppf J-55 STC 0.254 in 0.254 in 2.992 in lA-OS Kuparuk ConocoPhillips Alaska Ine USA December 24,2005 Well: Field: Company: Country: Survey Date: Joint Jt Depth Pen. Min. Damage ProtÎle No. (Ft) Body !.D. Comments (OJ., wall) (Ins.) (Ins.) 0 50 100 47 1433 0.01 2.91 48 1464 0.02 2.87 Lt. Deposits. 49 1493 0.01 2.93 50 1522 0.03 2.94 51 1552 0.01 2.93 1':'') 1582 D.OI 2.89 Lt. Del2Q~t?, J~ "'~ 1613 0.ü2 2.93 J.) 54 1644 0.02 2.94 55 1675 0.03 2.96 56 1707 0.03 2.93 57 1738 0.02 2.89 Lt. Deposits. 58 1768 0.03 2.93 Shallow pitting. 58.1 1799 0 2.81 SSSV 59 1811 D.02 2.91 ~~L 1842 0.03 2.92 Shallow pitting. Lt Deposits. 61 1873 0.03 2.92 Lt. Deposits. p 1904 0.03 2.94 Shallow pitting. )~ 6i 1934 OJJ3 2.86 It Deposits. 64 1965 0.03 2.94 1996 0.02 2.93 2025 0.03 Z·91 Lt Deposits. 67 2055 0.03 2.82 Lt Deposits. ----.J).ª. 2086 0.02 2.90 69 2116 0.03 2.92 Shallow pitting. 70 2145 0.02 2.91 Lt. Deposits. 7! 2!78 0.02 2.94 _72 2209 0.03 2.93 T' 2239 0.03 2.88 Lt. Deposits. .) 74 2269 0.01 2.94 75 2300 0.02 2.92 ---1J? 2329 0.03 2.93 ï7 2360 0.02 2.93~ 78 2390 0.01 2.95 79 2421 O.C)3 2.90 « 80 ~2450 0.02 2.91 81 2481 0.01 2.92 82 2511 0.02 2.89 .......JiL 2541 0.02 2.89 84 2572 0.01 2.90 85 2602 0.03 2.88 86 2632 0.02 2.93 Lt. Deposits. 87 2661 0.01 2.92 88 2690 0.02 2.89 Lt. Deposits. 89 2719 0.03 2.89 Lt Deposits. 90 2751 0.02 2.91 91 2783 0.ü2 2.92 92 2813 0.02 2.92 92.1 2843 0 N/A CLM I (Latch (â) 3:(0) (P 2849 0.01 2.90 < -, 94 2881 0.01 2.90 Lt. Deposits. Body Metal Loss Body Page 2 I I Pipe: Body Wall: Upset Wall: NominaIID.: I I PDS REPORT JOINT TABULATION SHEET 3.5 in 9.2 ppf J-55 BTC 0.254 in 0.254 in 2.992 in Joint Jt. Depth No. (Ft.) I 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 ..1I.f~~ 113 114 115 116 117 118 . .J.l2......... 120 121 .In 123 I I I I I I I 126 127 128 .112 ...130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 I I I I I I I 2909 2933 2968 2998 3028 3056 3087 3117 3147 3178 3208 3239 3268 3299 3330 3360 3389 3420 3451 \481 3511 3540 3571 3632 3663 3694 . .... 3724 3755 3736 3315 3844 3875 3904 55L.)~ .. 3963~_ 3994 4025 4055 4086 4117 4149 4178 4203 4239 4269 4300 4331 4361 4393 Pen. Body (Ins.) 0.02 0.03 _í102 0.01 0.02 (U12 0.02 0.02 0.04 0.02 (J.02 0.02 0.03 0.02 0.ü2 0.02 0.03 0.03 0.02 0.01 0.02 0.04 0.01 (1.02 0.02 0.01 0.01 (1.01 0.02 0.01 0.01 0.03 0.01 íì 0.02 n 0.02 0.02 0.02 0.01 0.02 0.03 0.02 0.01 0.02 0.01 0.02 0.03 (1.01 (UB l1.O2 0.01 Min. I.D. (Ins.) 2.90 2.90 2.91 2.89 2.92 2.93 2.92 2.94 2.95 2.39 2.81 2.89 2.89 2.91 2.89 2.92 2.92 2.93 2.95 2.92 2.94 2.90 2.93 2.89 2~.<.JL 2.79 2.92 2.90 2.91 2.89 2.ß9 2.90 2.8ß 2.93 2.92 2.94 2.93 2.89 2.94 2.93 2.93 2.89 2.89 2.89 2.92 2.86 2.89 2.ß6 2.ß8 2.90 Well: Field: Company: Country: Survey Date: Deposits. Lt. Deposits. lA-05 Kuparuk ConocoPhillips Alaska Inc USA December 24, 2005 Comments Deposits. Shallow corrosion. Lt. Deposits. Lt. peposits. pitting. Shallow pitting. Lt. Deposits. It. Deposits. Lt. Del:>.Qsits. . .llI2eposits. Lt. Deposits. ,.. ..- U. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Page 3 Damage Profile (%wall) o 50 100 Body Metal Loss Body I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: I I Joint No. I 145 146 __146·1 147 148 149 150 151 152 1,.. ') :)j 121. 155 156 157 158 159 160 161 162 163 164 164.1 165 166 167 168 169 170 171 172 173 174 174.1 175 176 177 178 179 180 ~Uli 182 183 184 185 185.1 186 187 188 189 190 I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET 3.5 in 9.2 ppf }55 BTe 0.254 in 0.254 in 2.992 in t. Depth (Ft.) 4423 4454 .. . 4.4ß-=t 4489 4519 4550 4581 4612 4641 4673 ....4ZQ1 .__~L 4733 4763 4793 4823 4853 4883 4913 4943 4974 5005 5036 5042 5072 5103 5135 5165 5196 5226 5258 5287 5318 5349 5355 5385 5414 5445 5473 5503 5533 5565 5594 5624 5654 5684 5691 5722 5752 5782 5812 Pen. Body (Ins.) OJ) 1 0.04 o 0.01 0.02 0.02 0.01 0.01 0.02 0.ü3 0.01 0.01 0.01 0.02 0.02 0.01 0.05 0.02 CUll 0.01 0.03 o 0.02 0.02 0.02 0.ü1 0.03 0.02 0.06 0.02 0.04 0.02 o 0.01 0.02 0.01 0.02 0.02 0.03 0.02 0.03 0.02 0.04 0.05 o 0.ü3 0.02 0.02 0.02 0.01 2.90 Lt. Deposits. 2.87 Line shallow corrosion. N/A CLM 2 (Latch @ 4:30) 2.92 Lt. Deposits. 2.92 Lt. Deposits. ....1..2.L...L t. Deposits. 2.94 2.91 2.91 2.87 2.90 2.90 2.91 2.91 2.85 2.91 2.91 2.93 2.85 2.90 2.89 N/A 2.80 2.91 2.92 2.89 2.86 2.89 2.90 2.88 2.90 2.90 N/A 2.91 2.88 2.85 2.91 2.91 2.89 2.90 2.87 2.87 2.86 2.83 NJA 2.88 2.8.5 2.86 2.90 2.89 Min. I.D. (Ins.) Well: Field: Company: Country: Survey Date: 1A-05 Kuparuk ConocoPhillips Alaska Inc USA December 24, 2005 Comments Lt. Deposits. Lt. Deposits. Lt Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Shallow corrosion. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. CLM 3 (Latch @ 8:30) L t. DE:'P91ilt;;.__ Lt. Deposits. Lt. Deposits. Shallow pitting. Lt. Deposits. Lt. Deposits. Corrosion. Lt. Deposits. Shallow pitting. Lt. Deposits. Lt. Deposits. CLM 4 (Latch @ 9:(0) .U.D..E:'!!.Q?Î.\.?· Lt. Deposits. Lt. Deposits. Lt. L1. Lt. Deposits. L1. Deposit?,---~~ _~...~~ Shallow pitting. Lt. Deposits. Isolated pitting. L1. Deposits. ClM 5 (Latch @ 9:30) Shallow pitting. Lt. Deposits. L1. Deposits. L1. Deposits. L1. Deposits. Page 4 Damage (%wall) o 50 100 I Body Metal Loss Body I I Pipe: Body Wall: Upset Wall: Nominall.D.: I I I I I I I 207 208 209 210 211 212 -------- 213 : 214 I 215 I~Ui~ 217 217.1 218 218.1 218.2 219 I I I I I 224 225 225.1 225.2 225.3 225,4 I I I I I PDS REPORT JOINT TABULATION SHEET 3.5 in 9.2 ppf J-55 BTC 0.254 in 0.254 in 2.992 in Joint No. it. Depth (Ft.) 191 192 193 194 195 196 196.1 197 198 199 200 201 202 203 204 205 206 5842 5873 5902 5931 5961 5992 6022 6028 6059 6090 6120 6150 6180 6209 6238 6269 6301 6332 6337 6369 6399 6430 6461 6492 6522 6551 6582 .. 6613 6644 6674 6686 6718 6745 6752 yp 1-....._, 6791 6823 6856 6884 6914 6943 6975 6980 6987 6995 ¡) Pen. Body (Ins.) 0.02 0.01 0.02 0.01 0.02 0.05 o OJJ3 OJ)I 0.05 0,02 0,02 0.02 0.02 0.03 0.03 0.02 o 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.03 0.02 0.03 0.03 o 0.03 o o 0.03 o 0.03 0.03 0.01 0.01 0.02 0.05 o 0.01 o o n Min. 1.0. (Ins.) 2.88 2.81 2.88 1.88 2.87 2.76 N/A 2.90 2.84 1.91 2.85 2.89 2.85 2.84 2.91 1.80 2.86 ~.~"2!L 2.90 2,89 2.88 2,89 2.86 2.84 2.8<2...... 2,88 N/A 2.84 2.81 3.00 2.90 N/A 2.90 2.93 2.89 2.92 2.77 2.91 2,32 2.96 N/A N/A Well: Field: Company: Country: Survey Date: 1A-05 Kuparuk ConocoPhillips Alaska Inc USA December 24,2005 Comments Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Corrosion. Lt. Deposits. CLM 6 (Latch @IO:OO) Shallow pitting. Lt. Deposits. Lt. Deposits. Line shallow corrosion. U. Deposits. . ... Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits.__.~.__ _ CLM 7 (No Deviation) Lt. Deposits..~ Lt. Deposil<;....~_. __~.~_.. . . Lt Deposits. Lt. Deposits. Lt. Deposits. Deposits, Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. CLM 8 (No Deviation) Shallov.\i.J2it!ing. Lt. Deposits. SBR PACKER CLM Deviation) Lt. Deposits. Lt. Deposits, Shallow pitting. SlIDINC SLEEVE-AVA PORTED NIPPLE PUP PACKER X OVER Page 5 Damage Profile ('Yo wall) o 50 100 Body Metal Loss Body - - - - - - - - - Well: Field: Company: Country: Tubing: lA-OS Kuparuk ConocoPhillips Alaska Inc USA 3.5 ins 9.2 ppf J-55 STC Cross Section for 21 at depth 648. Tool speed = 48 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 1 0 - - - - - - - OS Rep rt ross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: December 24, 2005 MFC 24 No. 040665 1.69 24 j. Thompson it Finger 14 Penetration = 0.118 Îns Isolated Pitting 0.12 ins = 46% Wall Penetration HIGH SIDE = UP Cross Sections page 1 - - - ... ... ... ... ... Well: Field: Company: Country: Tubing: Cross Section Tool speed = 48 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 99 % Tool deviation = 6 0 ... ... ... ... lA-OS Kuparuk ConocoPhillips Alaska Inc USA 3.5 ins 9.2 ppf J-55 STC Joint 26 depth 817. ... ... ... ... ... ... ... S Report ross S ons Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: December 24, 2005 MFC 24 No. 040665 1.69 24 J. Thompson 7 ft Finger 14 Penetration = 0.108 ins Isolated Pitting 0.11 ins = 43% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ... ... ... I I I Well: Field: Company: Country: lA-05 Kuparuk ConocoPhiHips Alaska Inc USA I I Penetration and Metal loss (0/0 wall) I penetration metal loss body 10 I I o 1 to 10'% o to 1% 10 to 20 to 40 to 20°;;) 40% 85% over 8.5°/0 I Number of joints analysed (total = 2) pene. 0 2 0 0 0 loss 1 0 0 0 o o I I Damage Configuration ( body) 10 I I o I Isolated pitting general linE' ring hole / poss corrosIOn corrosion (01T0510n ¡hie hole I Number of joints damaged (total = 0) o 0 0 0 o I I PDS Report Overview Body Region Analysis Survey Date: fool Type: Fool Size: No. of Fingers: Analyst: Nom.lD 2.44'1 ins Nom. Upset 2.875 ins penetration body o o Bottom of Survey = 0.4 Analysis Overview page 2 I I December 24, 2005 MFC 24 No. 040665 169 24 I. fhompson Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile ("I" wall) metal loss body 50 100 I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: I I PDS REPORT JOINT TABULATION SHEET 2,875 in 6.5 ppf J-55 EUE 8RD 0.217 in 0.217 in 2.441 in ¡oint Jt. Depth Pen. No. (Ft.) Body (Ins.) .1 6998 0.01 ') 7002 0 .., 7003 0.01 .J .4 7010 0 I I I I I I I I I I I I I I I Well: Field: Company: Country: Survey Date: Min. I.D. (Ins.) 2.26 2.25 ') 'J r." ~..)..) N/A PUP Lt. Deposit.~. D NIPPLE PUP rU8INC rAIL Page 1 lA-05 Kuparuk ConocoPhillips Alaska Jnc USA December 24, 2005 Comments Damage ProtÎle (%wall) o 50 100 Body Metal Loss Body ~ .' ConocoPhilDps ¡....ka. Inc. 1A-05 API: 500292062700 SSSV Type: TRDP sssv (1809-1810. OD:3.500) SBR (6719-6720. 00:3.500) PKR (6745-6746, 0D:6.156) Perf (6822-6929) Perf (6952-6956) Perf (6962-6968) SLEEVE-O (6976-6977. OD:2.750) PKR (6989-6990. 00:6.158) NIP (7004-7005. 00:2.875) sos -.----- (7009-7010. 00:2.875) Cement (7013-7015) Perf (7052-7056) Perf (7065-7092) 4" Va'nn ë3un (7186-7187. OD:2.ooo) . ( Well Type: INJ Orlg 9/4/1981 Completion: Last W/O: 2/24/1987 Ref Log Date: TO: 7675 ftKB Max Hole Angle: 50 deg @ 2100 Annular Fluid: Reference Log: Last Tag: 7075 ELM Last Tag Date: 712212004 Casing String· ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING LINER -----.---- Tubing String - TUSING Size Top 3.500 0 2.875 6998 Perforations Summary Interval TVD 6822 - 6929 5998 ~ 6105 KRU 1A-05 Angle @ TS: 3 deg @ 6826 Angle @ TO: 3 deg @ 7675 Rev Reason: TAG, set BPC Last Update: 8/1/2004 Size Top Bottom lVD Wt Grade Thread 20.000 0 ao 80 94.00 H-40 13.375 0 3095 2632 72.00 L-80 9.625 0 6633 5810 47.00 l-80 7.000 6284 7151 6327 26.00 K-5!L. _ ·_·.__.n____._,._.".. Wi Grade Thread Bottom lVD 6998 6174 9.20 J-55 aTe 7010 6186 6.50 n-"j~-5 ËUE 8~º_ . Zone . ::~3,C:-2:C:f; B UNITB UNITB UNITB A~5 A~4 Status Ft SPF Date ._Type Commeni 107 4 9/3i198'1'- IPERF 120 deg. Ph, 4" Vann Guns 4 4 9/3/1981 IPERF 120 deg. Ph. 4" Vann Guns 6 4 9/3/1981 IPERF 120 deg. Ph, 4" Vann Guns 2 0 6/6/1986 4 4 9/3/1981 IPERF 120 deg. Ph, 4" Vann Guns 27 4 9/3/1981 IPERF 120 deg. Ph. 4" Vann Guns Comment 6952 - 6956 6128 - 6132 6962 - 6968 6138 - 6144 7013 - 7015 6189 - 6191 7052 - 7056 6228 - 6232 7065 - 7092 6241 - 6268 Stimulations & Treatments Interval I Date I Type 7013 . 7015 6/6/1986 Cement Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr 1 2853 2462 Camco KBUG 2 4476 3741 Camco KBUG 3 5033 4253 Cameo KBUG 4 5345 4545 Camco KBUG 5 5687 4874 Camco KBUG 6 6028 5208 Camco KBUG 7 6331 5509 Camcc)'-' "---KBUG .. 8 6676 5853 Otis 3.5 X 1.5 Injection MandrelsNalves St MD lVD Man Mfr Man Type VMfr V Type DMY DMY DMY DMY DMY DMY DMY DMY I V OD Latch 1.0 BK 1.0 BK 1.0 BK 1.0 BK 1.0 BK 1.0 BK ..m·---rO BK -TI·-_..,..R'Ö::s Port TRO Date Run VIv Cmnt 0.000 0 12/11/1991 0.000 0 12/1111991 0.000 0 12/11/1991 0.000 ' 0 12/11/1991 0.000 0 12111/1991 0.000 0 12/11/1991 . . 0.000 0 12/11/1991 O.ÖOÖ· Ö·· 3/10/1997 V Type V OD I Latch Port TRO [)ätëqRun . Vly···· . ÖMY-~==~LQ.._...L.ª!<O.O()q q..<:>. ..._..1?f7I1998 g:~~ 9 6784 5960 Camc() ·q·KBUG· . Other (plugs, equip., etc.) - JEWELRY -º!P~~.. TVD..!Y~. 1809 1737 SSSV Cameo TRDP-1A 6719 5896 SBR --Bakë-i·_····· .. 6745 5922 PKR Baker 'FH' RETR. 6976 6152 NIP AVA PORTED NIPPLE 6976 6152 SLEEVE-o 2.75 AVA BPC. FULLY OPEN, set 7/23/2004 6989 6165 PKR Baker 'FB-1' PERM. 7004 6180 NIP Camco '0' Nipple NO GO 7009 6185 SOS Cameo 7010 6186 TTL Fish.. FISH Depth I Description 7186 4" Vann Gun General Notes Date Note 3/29/1998 Unable to Establish Inj Rate; Very Slow LEAK (See WSR 3/29/98) 1-º,?6/2002 ¡:OU~[).~~!.<S @ 6854' MD & 6883' MD Description 1322.86' long ID 2.613 2.813 3.000 2.750 2.320 3.000 2.250 2.441 2.441 Comment Memow Multi-Finger Caliper Log Resul Summaw t?t" Company: PHILLIPS Well: 1A-05 Log Date: June 3, 2002 Field: Kuparuk Log No.: 4726 State: Alaska Run No.: 1 APl No.: 50-02920627-00 Pipe1 Desc.: 3.5" 9.2 lb. J-55 Top Log Intvll.: 6,713 Ft. (MD} Pipe1 Use: Tubing Bot. Log lntvll.: 7,001 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 3.5" tubing logged is in good condition, No significant penetrations are recorded throughout the interval logged. The caliper recordings indicate no areas of significant cross-sectional wall loss or minimum I.D, restrictions throughout the logged interval. The distribution of penetrations is illustrated in the Joint Tabulation Sheet of this report. The joint count numbering is an approximation based on the average joint length and the log start depth. TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant penetrations (> 12%) are recorded throughout the interval logged. TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 3%) are recorded throughout the interval logged. TUBING -MAXIMUM RECORDED I.D. RESTRICTIONS: No significant minimum I.D. restrictions recorded throughout the interval logged. Field Engineer' K. Higgins Analyst: M, Lawrence Witness: J, Kralick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 ins 9.2 ppf J-55 Wall thickness: Body = 0.254 ins Upset --- 0.254 ins Nominal ID: 2.992 ins Well: 1 A-05 Field: Kuparuk Company: PHILLIPS ALASKA, INC. Country: USA Survey Date: June 3, 2002 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage Profile No. Upset Bd@Up Body Loss Cplng 3ody ID Comments (% wall) inches inches inches % % inches inches inches ~) 50 10 224 0 0 .01 4 1 0 0 2.96 I -- 224.1 0 0 0 0 0 0 0 2.81 SBR 224.2 0 0 0 0 0 0 0 3.00 PACKER 225 0 0 .02 8 2 0 0 2.92 II ! I 225.1 0 0 0 0 0 0 0 N/A GLM 9 I 226 0 0 .01 5 3 0 0 2.96 227 0 0 12 2 0 .04 2.96 Shallow pitting. [] 228 0 0 .02 9 2 0 .03 2.90 [] 229 0 0 .02 9 2 0 0 2.92 -- 230 0 0 .01 6 2 0 .03 2.93 ! ! I 231 0 0 .01 4 2 0 0 2.94 I 231.1 0 0 0 0 0 0 0 2.31 AVA SLV 231.2 0 0 .01 4 1 . 0 0 2.97 PUP I 231.3 0 ___0 0 0 0 0 0 3.00 PACKER 231.4 0 0 0 0 0 0 0 N/A X-OVER Damage dassification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 1 * pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line length ~- 0.190 feet. Pipe Tabulations page 1 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.2 ppf J-55 Wall thickness: Body = 0.254 ins Nominal ID: 2.992 ins Upset = 0.254 ins 231 ] 231.2~ 231.41 Depth feet 6713.52 6721.25 6735.85 6754.66 6787.08 6794.04 6826.11 6857.82 6885.60 6915.79 6945.59 6975.40 6981.77 6989.55 6997.85 e[ Mean Nominal IN~m~T Type ID ID OD s I inches inches [ inches__~ I 7.7~_. 3.016 3.~ 2.992 3.50__9__0~----~ I 18.8~ ~ ~.ooo ~.023] 3.013] 2.992] 3.500] I ~'~ N/A ~ N/A ] 2.9~ 3.500 ~lm I~ 3.014 ~ 3.015 [ 2.992 ] 3.500 ~ I 31'7~~0 [ 3.0~.992 ]2~ 2.970] 2.961] 2.992 ] 3.5~- ~9'~ [ ~.007 ~ 3.001 [ 2.992 I 3.5~ ~29.8~I 3.004] 3.002[ 2,992 I-~ 2.3!3 ~.313~ 2.313 ] 2~vaslv [~~l ~.o~ ~.~ ~ ~.~o~p ]. ~.30 ~0~00 I 3.00~ 3.500 ~acker ]. N/A ~~~N/A I 2.992 ] 3.50~~- Well: Field: Company: Country: Survey Date: Depth feet 1A-05 Kuparuk PHILLIPS ALASKA, INC. USA June 3, 2002 Length Modal ~~m~a-~- ID ID I ID I OD Type Joint Tally page 1 ~ .... ~CHLUMBERG~R .... · ~ ~m~ m m ~mm~ ~mm~ ~ m m m mmm m m mmm~ m mmm m m mm~m m m ~ LIS TAPE VERIFICAIION LISTING LIS TAPE VERIFICATION bISTING bYP 009.H05 VERIFICATION 5ISTING PAGE ** REEL HEADER ** DATE :81/10/i6 ORIGIN : REEL NAME :REM5 ID CONTINUATION # :O1 PREVIOUS REEL : *~ TAPE HEADER SERVICE NA~E :$ERVIC DATE :81/10/16 ORIGIN :1070 TAPE NA~E :62167 CONTI~UAT£ON ~ :01 PREVIOUS YAPS COMMENTS :TAPE COMMENTS ** FIbS HEADER FILE ~gAME :SERVIC,O01 SERVIC~ NAME : VERSION ~ DATE : ~AXI~O~ LENGTH : 1024 PREVIOUS FILE ** IN~OR~ATION RECORDS MNE~ CONTENTS CN : WN : FN : RANG: TOWN: SECT: STAT: CTRY: MNE~ ATLANTIC ~ICHFIEbO COMPANY A-5 KUPARUK lOS 5 NORTH SLOPE ALASKA U.S,A, CONTENTS NEDIT~F ** RECORO TYPE 047 ** UNITTYPE CATE SIZE CODE 00 O00 026 065 O0 000 004 065 000 00( 00~ 065 000 00( 003 065 00 00() 00~ 065 O0. ~00(, O0 065 000 000 012 065 000 000 006 065 000 000 006 065 000 000 007 065 LVP RECORD TYPE 9 0 ** DATA FORMAT ENTRY BLOCKS ** R£CORD TYPE 047 ** ** RECORO TYPE 04? ** DATUM SP MNEM SER I DEPT ILM FUN IDD FUN SP GR FUN DT FUN GR FUN NPHI FUN RHO8 FUN DRHO FUN CALf FUN NRAT FUN NCNb FUN FCNL FUN URAN FUN POTA FUN CGR SGR FUN ** DAIA ** DEPT NPHI SGR URAN DCP~ SP URAN PAGE ECIFICATION BLOCKS VICE SERVICE D ORDER # 677 000 999:250 999,250 168.750 -999.250 168.750 7600.000 -999.250 43.604 94.625 1.019 94.625 NIT AFl AP1 APl AP1 FILE SIZE PROCESS SAMPLE REPR LOG TYPE CLASS ~OD NO' i bEVEL ~ CODE FT 0 O' 0 0 0 4 0 i 68 OHMM 0 0 0 0 0 4 0 I 68 OH~ 0 0 0 0 0 4 0 i 68 OHMM 0 12 46 0 0 ~4~ 0 i 68 ~V 0 1 0 0 0 4 0 1 68 GAPI 0 0 I 68 4 U$/F 0 52 3 0 0 0 GAPI 0 0 PO 0 68 0 4 0 G/C3 0 35 I 0 0 4 0 ~/C3 0 44 0 0 0 4 IN 0 28 3 0 0 ·4 GAPI 0 0 0 0 0 4 0 ! 68 0 42 i 0 0 4 0 ! ~8 0 34 92 0 0 4 0 34 93 0 0 4 PP~ 0 0 0 0 0 4 0 PP~ 0 0 0 0 0 4 0 PU 0 0 0 0 0 4 GAPI 0 0 0 0 0 4 GAP~ 0 0 0 0 0 4 0 1 68 99.250 SFLU - 9 Sh -999 DT ~50 GR -999t250 RHOB CA~I ',,,999,250 NRAT -99 250 9 50 FCNb -999 250 ThOR -9 144,1~50 SFL~ -999.250 Ib~ 1,859 ILD 1,752 GR 79,396 DT 107,~i2 GR 79.~96 RHOB 2.422 DRMO -0 CALI 8.422 NRAT FCN~ 565~000 THOR 1i.. B POTA O.Ozg~ CGR 86,563 DEPLr SP URA~4 DEPT SP URA~ DEPT SP NPHI DRAY SGR DEPT SP NPHi SGR URAN SGR DEPT SP NPHI SGR URAN SGR DEPT NPHi URAN DEPT SP NPHI SGR URAN DEPT SP NPHI URAN 009.H05 VERIFICATION 7500.000 8FLU -999,250 GR 43.506 R~OB 86.667 NRAT 1.285 T~OR 86.667 !400,000 999.250 GR 44.727 88.813 NRAT 1,597 7300.000 -999.250 35.352 RHOB 82 500 NRAT 0~687 THOR 82.500 7200.000 SFbU -999.250 GR 49 463 R~OB 9~:312 N~AT 0.126 T~OR 93,312 7100.000 SFLU -999 250 G~ 35:449 ~S 76.771 N'RAT 1.632 THOR 76,771 looo ooo SFLU 999:25o GR 35.791 RfiOB 66.792 NRAT 0.86~ 66.792 ~900.000 SFLU -999,250 GR 30.225 54,188 NRAT 2.604 ~hOR 54,188 6~00.000 SFLU -999.250 GR 54.590 RHOB 106.646 NRAT 2.600 ThOR LISTING -999,250 IbM 85"458 DT 2.414 D[iMO 3~496 NCNb 10.680 POTA ,i99 10~,708 GR ' 0,003 CALl 2136,000 FCN~ 0.032 CGR -999,250 71.250 2.4t4 DRMO 3.563 ~CNb 12.0 6 2,~05 IbD 105,312 GR 0,009 CAbI 025 CGR M -999.250 IL. 79.479 DT 2,398 DRMO 398 POTA 1.832 ILD i1~,$12 GR ',005 CALI 201~,000 FCNL ,029 CGR '999.250 ILM 3,852 59'656 DT 99 ~. 88 GR 2,430 DRHO , 0.010 CALI 3. 055 NCNb 2282~ 000 FCNb 9.648 POTA 0,021 CGR -999,250 ILM ~,586 ILD 5~.323 DT 98,~04 GR 2.416 DRMO 0~028 CALl 3.068 9.867 -999.250 ILM 47.948 DT 2.309 DRHO 2.744 NCNb 6,637 POTA 10.328 ILD 94,708 GR -9.oo 2722,000 FCN~ 0,0~2 CGR -999.250 IbM 105.625 DT 2,.]30 DRMO 4.109 NCNb 14.570 POTA 122,708 GR 0,007 CAbI 19403,000 FCNL- ,026 CGR PAGE '~,i56 8~-,458 83'021 2,240 781.250 · 422 539,000 78.833 712,752 .896 8,406 73i,500 75,688 1.791 7~,479 ~406 13,500 -90.~88 -- 850 ooo 64.458 4 570 5~5 445 709 000 -63 760 9 047 47~948 8,375 907,000 374 ., 625 000 90,438 6VP 009.H05 VERIFICATION LISTING PAGE 4 SGR 106,646 DEBT 6700.000 SFLU SP -999.250 GR NPHI 51.074 RhOB SGR 101.563 N~AT URAN 0.734 THOR SGR 101.563 DEPT 6600.000 Sf'5S SP -17.219 GA NPHI -999.250 RHOB SG~ -999 250 NAAI' URAN -999:250 T~OR SGR -999.250 DEBT 6500.000 SFLU SP ,-11.969 GA NPHi -999.250 RHOB SGR -999.250 NRAT URAN -999.250 THOR SGR -999.250 DEBT 6400.000 SFLU SP 4.262 GA NPHi -999 250 RHOB SGR -999:250 NRAT URAN -999.250 THOR SGR -999.250 D£PT 6300.000 SFLQ SP -17.531 GA NPHI -999.250 RHOb $GR -999.250 NRAT UEAN -999,250 T~OR SGR -999.250 DgP~ 6200.000 SFbO SP -24.250 GA NPH! -999.250 RHOB SGR -999.250 N~AT URAN -999.250 THOR SGR -999.250 DgP~~ 6~00,000 SFLU SP 37.250 GR NPHI -999.250 R~.OB BGR -999.250 NRAT URA~ -999.250 T~OR SGR -999.250 D~PT 6000.000 SFbU SP -10.727 GR NP~Jl -999.25Q RH00 -999.250 101.958 DT ~.~91 DRHO -0,010 CAbI . 24 NCNb 2098,000 FCNL 0.0~3 CGR 15.805 POTA . 6" 8,508 63.250 I01,125 3.039 93.604 PT 99.250 POTA 2000.000 IbP 90,250 GR -999'250 CAb~ ~999,250 FCNL 999~250 CGR 6.445 . 93. 604 .999,250 ..999.250 -999.250 F:OTA -999.250 CGR 2~ 170~ -999 -999 -999 094 00-0 250 2{5O 25O 4.555 I~ 2,990 IbD .~01.875 DT .i04,750 GR 999. 250 DRHO ..... 999~ 250 CAbl 2999,250 NCN5 ~999,250 FCNL 999~ 250 POTA ..... 999,250 CGR 2.959 101.875 -999.250 ~999.250 999.250 ,875 DT i17.000 GR -.999. 250 DRHO -999,250. 999,250 NCNb -999,250 -999.250 POTA -999.250 CGR '0 11~.2 5 .875 -999 ~50 -999,250 - 117,i88 DT -999.250 DRHO -999~250 NCNb -999.250 POTA 2.063 IbP 1.947 .I14,375 ~R 117,188 .... 999~250 CALI '999,~50 ,, 3. 107 IGM 2.548 lbo i 18,~250 DT 118'i 8 GR .-999 RH CAbI 999 FCNL -999. 250 POT. A -999' 250 CGR 2.496 118,250 ,,,99 ,250 -999.250 1.683 IbM i.464 I5D 133,750 DT ~01,000 GR -999.250 DRHO -~99,250 CALI 1,446 .133.750 999.250 ORAN SGR DEPT SP SGR URA~ DEPT , SP SGR ORAN SGR DEPT SP NPHi SGR URAN DEPT URAN SGR DEPT SP NPMI URA~i DEPT SP SG~ DEPT 8P URAN SGR DEPT 009.H05 VERIFICATION -999.250 NkAI -999.250 THOR -W99.250 5900.000 SFLU -15.289 GR -999.250 RHOB -999.250 NRAT -999.250 THOR -999.250 5500.000 SFLU -18,76b GR -999.250 RH05 -999.250 NHAT -999 250 THOR -999:250 5700.000 SFDO -19.797 GR -999.250 RMOB -999 250 NRAT -999:250 THOR -999.250 5600.000 SFGU -1~.750 GR -999.250 RHOB -999,250 NRAT -999,250 THO~ -999,250 5500.~00 SFLU -1~.742 G~ -999.250 ~HOB -999 250 NRAT -999:250 THOR -999.250 5400.000 $FLU -1~.734 G~ -999.250 RHOB -999.250 N~AT '999.250 THOR '999,250 5300.000 SFLU -10.750 GR -999.250 R~OB -999.250 NRAT -999 250 ~HOR -999:250 5200.000 SFbU ~ISTING 99;250 POTA 3.482 167;500 DT 99~250 NCNL -999.250 POTA 2.877 II~b~ .154.750 DT 999,250 -DRHD .-999.250 N'CNb 999i 250 POTA 2.402 ILM 97. 500 DT -99 50 POTA z.186 !18.500 DT -999,2~0 DRHO -999.2 0 NCN5 -999.250 POTA 8 :Ioo 688 DT 2.143 52.781 DT -999.250 DRMO -999'250 NCNb -999.250 POTA 2.426 IbM PAGE %999,250 FCNL .999~250 CGR -999,250 -999.250 ~999,250 CALI ~999,250 FCNb 999.250 CGR 1.745 167.500 2999,250 i. 999 . ~50 -999,250 2.074 IbD 2,018 1!9,750 GR 154.750 -999'250 CALl -999,250 -999,250 FCNL -999. 250 '999:'250 CGR -999 ;, 250 2.242 ILD i05,375 GR -999.250 CALI '999,250 F'CN~ '999,250 CGR 2 97 :999 "999 '999 2 250 25O 25O _ ,999'2 CAbI -999.~50 '.999'250 999.250 2,205 IbD 2 106~563 GR 84 5O0 250 ..... 999;250 ~'CNb . 999 250 -999.250 CGR -999.250 11 GR 1.877 79.688 -999.250 -999 250 -999.250 CGR _ 2,332 52;~81 -999.250 -999~250 -999.250 - 2,416 434 LVP 009.H05 VERIFICATION LISTING PAGE 6 SP URA~ D~P~ SP NP~i URA~ SGR DEPT SP ORAN DEFT NPHi SGR SGR DEFT NPHI SGR URA~ SP NPHi URAN DEFT NPHI URAIv SG~ DEPT SP NP~I -7.73% GR -999.250 RHOB -999.250 NRAT -999.250 THOR -999.250 5~00 000 SFLU 18:250 GR -999 250 RHOB -999!250 NRAT -999 250 TH[{R -999.250 5000.000 SFLU -17.750 GR 2999.250 R,OB 999.250 NRAT -999.250 THOR -999.250 ~900.000 SFLU ~12.977 GR -999.250 RHOB -999.250 NRAT -999.250 THOR -999.250 4BO0.O00 SFLU 438 GR 99,250 NRAI -999.250 THOR -999.250 q700,O00 SFLU -19.734 GR -999.250 RHOB -999.250 NRAT 999 250 THOR 4600.000 SFLU -19.047 GR =999.250 RHOB -999.250 NRAT :999,250 THOR 999,250 4500.000 SFhU -12.469 GR -999.250 RHOB -999.250 NRAT -999.250 THOR -999.250 999,250 DRHO -999.250 NCNI~ -999,250 POTA .i07 '63 50 CALI -999 50 FCNL 86,563 -999.250 :999.250 999.250 2 584 1~ 8~:ooo DT .-999 250 DRHO 999 ~ 250 tVCNL -999,250 POTA 2,385 IDD i13.188 GR :999,250 CAhi ..... 999.250 FCNL -999.250 CGR 2.406 84~000 ..999,250 -9~9.~o 2.891 I~M 2.773 lSD 2.850 . 92.188 .DT .107,375 GR 92,1~88 999'250 DRHD -".999~250 CA~I -999. 50 .-999.250 NCNI~ :999,250 FCNL =999,250 999.250 POTA ...... 999.250 CGR '999~250 99. 250 DRHO '999. 250 POTA 05 ILD ,428 88 GR 8~,250 '999~250 DRHO ' 999;250 CA~I ' 999 250 -999,250 NC~6 Z999,250 FCN5 2999 250 -999,250 PDIA ...... 999.250 CGR 999 250 5,391 IbM 93,250 DT 99.250 NCNI~ -999.250 POTA -999.250 CGR -999 -999 -999 387 250 2.50 250 250 3.223 IL~ 3.ii1 ILD 3,229 97.312 DT .117,000 GR . 97,~20 -999..2.50 DRMO ....999.250 CALX ' '999. 99~;~5o~o~ ....... ~9~.~o c~ ,,,,,~9~. 5o 2.494 IbM 2 bO 2,744 94;813 DT ti4 94.813 -9 ~>RhO 250 CAbI =999 250 '9 250 FCNL -..999:250 -999 250 POTA -9 250 CGR -999.250 LVP DEPT SP SGR URA~ DEPT NPHi URAm SGR DEPT SP NPHI URAN DEPT SP NPHI SGR URAN DEPT NPHi URAN DEPT SP NPHI URAN DEPT SP NPHI SGR URAN DEPT SP NPHI SGR 440 -1 -99 -99 -99 -99 430 -1 3 8 8 420 4 7 7 410 . 4 7 7 400 -1 3 6 6 390 ~4 3 5 5 3~0 -I 3 8 8 0 0.000 8.26b GR 9.250 RMOB 9.250 9.250 THOR 9.250 0.000 SFLO 1.703 GR 8.~67 RH05 2,438 NRAT 0.930 THOR 2.438 0.000 5.~44 G~ 2 041 61750 NRAT 2.i27 THOR 6.750 0.000 SFLU 9.R69 2'920 RHOB 0,438 NRAT I 373 TBOR 0~438 0.000 SFLU 4.453 GR 6.865 9,188 NRAT 1.941 ThOR 0.000 3.719 9 941 RHOB 3:969 NRAT 0.988 3.969 0.000 8,219 GR 8.~23 1,438 NRAT 1.635 THOR 1,438 __ 0,000 SFLU 0.938 GR 3.945 R~OB 0.094 NRAT 3.494 IL~ 3.797 I5D . 7~.938 DT .1!4,188 GR 999'250 DRHO .... 999.250 CALl -999.250 NCNb -999.250 FCNL 999;250 POTA -999.250 CGR 4.082 1~ 4.469 I~D 7~,563 DT 1~2'~88 GR 2 229 DRHO CGR 4.969 IL~ 4.8t3 ILO 73.000 DT 105,563 GR 2'193 DRHO ' :O"04B CALl 3 30 N{ 2 PAGE 7 4.070 77,938 999~250 :999.250 999.250 .027 7,~.563 14 39~ 5 5:soo -999.250 5.152 73.000 15.641 .500 .250 8.0 .~ 7 I~D 8 59.0 GR 59 o.oo 3'760 ~CN~ 2074.000 FCNL 57 0.020 7; 92 POTA -999 i 969 031 O0 250 64, 500 DT 3 445 N( 191 GR CAbI 12 680 6 2 oo I5. 789 .000 .250 11.180 IbM 11.352 ILO 11.898 51,844 DT 130~000 GR 51,84 4 2.121 D~HO ' 0.013 CALl 15.438 3.607 :NCN5 2078.000 FCNL 587,500 5.355 POmA 0,016 CGR -999.250 L 3 6 1950 1LD 88 GR FCNL CGR 8.719 68,938 17.922 .554 500 8 086 IbM 4 2.0 -0.007 CALl 3.764 NCNb 2048.000 FCNL 0,641 1.688 12.953 562,000 bVP 009.H05 VERIFICATION bISTING PAGE 8 URA~ 0,847 THOR SGR 40,094 DEPT 3600.000 SFbU SP -16,203 GR NPH£ 42,578 RHOB SGR 66.563 NRAT ORAN 2,408 THOR SGR 66.563 .. DEPT 35~0.000 aP 7,242 GR NPHi 46.436 SGR 79,688 NRAT URAN 1.857 THOR SGR 79.688 DE'PT 3400.000 SFLU SP -23,984 GR NPHI 37.012 $GR 59.469 NRAT URA~ 0.528 $GR 59.469 DEPi' 3300.000 SFbU SP ~22.7~9 GR NPH1 43.750 RHOB $GR 48.781 NRAT ORAN 0.447 THOR SGR 48,78I DEPT 3200.000 58 -17.000 GR NPHI 40.918 RHOB SGR 42.500 NRAT URAN 1.503 THOR $GR 42.500 DEPT 3100,000 SF~U $P 4,777 GR NPHi 55.713 SGR 50.03I NRAT ORAN 1.167 THOR SGR 50'03I DEPT 3077 500 SF~U NPHI -999,250 RHOB SGR -999.250 NRA~ ORAN -999.250 THOR $GR -999,250 4.941 POTA 0,01~ CGR 234 DRMO 0 ooo 7 ~93 76:688 DT .156 DRHO . 004 NCNb 9,320 POTA 165~.032 CAbI · 000 FCNb 0.019 CGR 11. 88 DT .078 DRHO .789 NCNb 6.535 POTA 13 i17 lbo o.o~o ~x 2oso.ooo ~'c~, 0.0t4 CGR 13.430 IbM 39. 2. 3 639 NCNb 4:086 POTA 14~523 750 GR 008 CAGI 209~,000 FCNL I~011 CGR' 0.142 IbM 47,000 DT D .o 6.~37 POTA 0.012 4,211 IbM ~000,000 42,250 DT , 72.375 GR -999~250 ORHO "999.250 CAbI -999,250 NCNb -999,250 FCNb -9991250 POTA "999~250 CGR ** FIL~ TRAILER -999.250 9.258 65,688 I4.367 .517 000 ~22~o 258 ~6,938 428.500 -999.250 ., I4,023 54,~3! 14, 33 .6a7.!oo .9gg. 250 4~4 031 569.500 -999.250 15.672 39,000 14,555 .585,000 999.250 2000.000 47 ' 000 14;375 305,750 -999.250 2000.000 42,2 0 -999'250 - 99.250 ~VP FILE NAME SERVlC~ NAME VERSION # : DATE : MAXIMUM LENGTH FILE TYPE NEXT FILE NAME :SERVIC,O0! : 1024 : ** TAPi{ TRAILER SERVICE NAME :SERVIC DATE :$1/10/16 ORIGIN :1070 TAPE NAME :62167 CONTINUATION ~ NEXT TAPE NAME COMMENTS :TAPE COMMENTS- ** ~£~5 TRAILER *~ SERVICE NAME :SERVIC DATE :81/10/16 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 NEXT REEL NAM~ : COMMENTS :REEL COMMENTS PAGE VgRIFIC~TiO~ LISTING 0~. o 6 lo~I Alaska Oil DVP ()(i,'~,,d05 VERIFICATI~H ** TAPi~ HLAOER *~ SERVIC~ NA~E :SERVIC DAT~ ;91/09/i1 ORiGIi~ :1070 TAPh ~:~E :62144 CO~TI~iUATi[]~ ~ :01 PREV~O~.}5 TaPE : FIbS ~A~E :SERVIC.O01 VER~iO4 ~ DATg : MAXiMd~ LENGTH : 1024 pRE~IO~J~ FIbE *~ ~NF,~R~ATION RECORD5 CN : FN : K[tPARUK TO~N: TU~NSHIP SECT: SECTIO~ CO0~: NO. SLOPE ST~T: AL, ASKA CTRY: USA MNEM CONTENTS PRES: Di~,~HCF ~NIT TYPE (]ATE SIZE CODE 000 000 004 ~5 ~oo ooo 005 065 · " n ';~ 0 006 06 uO.. uO ooo oo0 0o7 065 RECORD I~¥'P t)O~.H0~o VE~iFICATiO~ .~ISTING ** CO JO~ ~ , m R ~ C O R ~ 0 ~ 10707,621~4 Li~ ~2, LOGGED 26-AU BOT'TOi'< bOG INTER~/AL - 7646 FT' TOP !.jtj~; ii~S~]RVAU : 6632 FT BIT :~ 1 '~ ~] TYPE DE~Si FLUId) :.~/~SS : 3.2 C3 B H T : i~A. RiX SANDSTG~E ** DATA F~}NMAT ~ECO~D *~ ENTRY ~bOCKS T~PC 9 0 SiZe, R~P~ COO~ I I I 66 0 D A T 0 4PECiFICA'flUN ICC SERVICE DEPT GR DT 003 DgPT 7677.000 GR ~ Ibi,~ -999.250 GR D'~:~' 7~00 000 G~ ,Ib~ 1.859 GR DEPT 7500.000 GR Ibf4 2.199 GA 7400.000 GA 2,305 GA DEPT 7300.000 GR Ib~ 2.795 GR DEP'~ 7200.000 GA IbM 1'832 GA DEPT 7100.000 GR Ib~f 3.852 GR D~p..: 7000 000 GP,. IL~v~ 4.586 GR DEPT 6900,000 GR IbM 10.32~ GR DEPT 6800.000 Ibi~ 1.413 DEPT ~700.000 GR Ib~ 1.899 GA DE?T 6~00.000 Ib~Vt 2000.000 DEP~ 6551.000 Ib~,i 2000.000 U 0 ~ T Y P g ,. 0 0 4 0 0 GAPI 0 0 0 60 12 -999.250 71.250 DT ~05 D :40 7~' 68.~13 GR G~ G~ bVP OU<).'H05 VERZFICA?iON ~IS~iNG FIb~ ~iE SERVI~ NAM~ VERSIO'~ ~ DATE : MAXi~O~ LE~GTH : 1024 FIL~ SfPE NEXT FiLE NANE : PAGE 4 ** FiLE HEADER FILE ~-~E :SERVIC.O02 SERVICE NAME : DAT~ : MAXi~i{!'! LENGTH : 1024 FIL~ TYPE PREViO']S FILE ** i~F,]R,~qATION RECORDS CONTENTS PRES: FDNoO1F ** DATA F[JRMAT RECOND ENTRY TYPE 9 0 000 000 007 065 ** ** SIZ~ REPR CODE ENTRY ~ 73 6 0 I ~o 0 DATO~ SPECIFICATION BLOCKS MNEM o~, VICE SERVICE UNIf API A~i ~I' REPR iD ORDER ~ ~OG TY~E CLASS Mu_ NO bEVEL CODE DEPT FT 0 0 ~8 G / C 3 0 44 0 42 1 0 0 4 0 1 68 STA~ [S~ CPS ~ISTING 0 0 0 ~ 0 4 0 i 68 0 0 0 0 0 ** OA~4 CGR NCnb POTa DEFT CGR NC~L PO~ DEFT CGR NCNL POTA DEFT CGR NCNb DEFT CGR NCNb POTA DEFT CGR NCnb POTA DEFT CGR NCNb POTA DEFY CGR NCNb POT~ DEFY NCN~ POT~ DEPi~ 7677 14~ -999 -999 2144 0 '1500 83 2i36 0 7~00 78 1993 0 7300 75 2364 0 7200 90 2011 0 7100 64 2282 0 700O 63 236b 0 6900 37 2722 0 6~00 .00 .25 .25 .25 .00 .00 .02 .000 .021 .000 .032 .oOo .833 .000 .025 ,000 .000 .025 .00o .688 .000 .029 .000 .458 ,000 .021 .000 .760 .000 .021 .000 .865 .000 .012 .000 NPHI CALl FCNL ~P~I FCNL NPHi CALl FCNL STAB NPHI CALl NPHi CAbi STA6 CALl FCNL STA~ NPHI CALI FCNL NPHI CALl FCNb NPHI CALl FCNL NPHI 2999.250 OReO -999.250 [~RAT ~999,250 9.250 ~ R 999,~50 ~R 99 -999.2,50 565.000 tn~ ~1.758 u~A~. 1.019 00 8.42;2 'DRHO 0 NRAT 8.500 - 44.727 RHOB 2,~i4 fiGR 88.8!3 539.0~0 T~OR 12,086 ORAN i;597 8 ~500 ' ~0 513.5~0 THOR i3,398 ORAN 0.!26 8 8,509 DRHO 0.010 NRAT 3'055 717 9~648~RAN 8.500 ~5,79! RffOB 2,416 SGR 66.792 8,445 709.000 THOR . 9,867 ~RAc; 0,866 8 '5 30 '225 8,375 D~HO '9,008 ' NRAT 2,744 907 '00 CGR 90.438 CALl POTA O' 026 STAB DEP~i' 6700.000 NPHi CG~ I018.12b NCNb 209 .000 FCNL POTA 0 02~ ST~ ~ DEP[i 6600.000 NPMI CGR -999.250 CAL~ NCNb -999.250 FCNb POTA -999.250 STAB DEPT 6551.000 NPHI CGR -999.250 CALl NCNb -999,250 FCNL POTA -999.250 427.000 THOR i4.~70 U~A{'~ 2,600 S '500 51 ' 07 46 ~ '250 8.509 ,999 o~a =~nn -999.~50 8GR -999. 250 '999 .999 - 999 ~25 -~50 DRHO -999,250 ~RAT ~99R,~9 '999.2D0 ~H ~. -999.250 FILE ~ ~ r~i E ;SERVIC.002 VER610.q ~ DATE : MA~'I',~,d'~,~ . LENGTH ; 1024 FILE TYPE ********** gOF SERVIC? NA~ :~;RVlCw DATg 131/09/11 ORiGr~ :1070 TAPE M%~E 1621~4 NEXT T~PE ,qA~g : CO~E~$ :TAPE CO~ENTS