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Home My WebLink About185-145KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϭͲ&ĞďͲϮϲ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶǇ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶǇƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt>>ED W/η ^Zs/KZZη &/>ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^dηϭ ϭͲϮϬ ϱϬͲϬϮϵͲϮϮϭϭϮͲϬϬ ϵϭϬϱϵϳϯϰϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮͲ&ĞďͲϮϲ Ϭ ϭϮ ϭͲϭϰϱ ϱϬͲϬϮϵͲϮϯϱϮϲͲϬϬ ϵϭϬϱϵϲϳϵϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϳͲ&ĞďͲϮϲ Ϭ ϭϯ ϭ&ͲϬϵ ϱϬͲϬϮϵͲϮϬϵϴϯͲϬϬ ϵϭϬϱϯϵϯϭϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϲͲ:ĂŶͲϮϲ Ϭ ϭϰ ϭ,ͲϭϬϭ ϱϬͲϬϮϵͲϮϯϱϴϱͲϬϬ ϵϭϬϱϯϵϰϯϭ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϭϴͲ:ĂŶͲϮϲ Ϭ ϭϱ ϮͲϭϰ ϱϬͲϭϬϯͲϮϬϬϰϬͲϬϬ ϵϭϬϱϵϳϯϰϮ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϳͲ&ĞďͲϮϲ Ϭ ϭϲ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϯͲ:ĂŶͲϮϲ Ϭ ϭϳ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϰͲ:ĂŶͲϮϲ Ϭ ϭϴ ϯ^ͲϲϮϰ ϱϬͲϭϬϯͲϮϬϴϲϴͲϬϬ ϵϭϬϱϯϵϭϴϰ <ƵƉĂƌƵŬZŝǀĞƌ dƵďŝŶŐWƵŶĐŚZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂů ϮϱͲ:ĂŶͲϮϲ Ϭ ϭϵϭϬW>^<EKt>'Z/Wdz^/'E/E'EZdhZE/E'KWzK&d,dZE^D/dd>>ddZdKd,ddEd/KEK&͗&ĂŶŶǇ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗190-162214-138183-104217-138185-145223-104T41362T41363T41364T41365T41366T41367T41367T41367217 138185-145223 104ϱϮͲϭϰϱϬͲϭϬϯͲϮϬϬϰϬͲϬϬ ϵϭϬϱϵϳϯϰϮ<ƵƉĂƌƵŬZŝǀĞƌWĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϳͲ&ĞďͲϮϲϬϭGavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.11 13:44:36 -09'00' 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:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Report of gas bubbling in the cellar of Kuparuk gas lifted producers 2A-15 (PTD #185-146) & 2A-14 (PTD #185-145). Date:Thursday, January 15, 2026 10:34:51 AM Attachments:image001.png AnnComm Surveillance TIO for 2A-15.pdf AnnComm Surveillance TIO for 2A-14.pdf From: NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com> Sent: Saturday, January 10, 2026 4:48 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Buck, Brian R <Brian.R.Buck@conocophillips.com>; NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com>; Kolstad, Scott <Scott.Kolstad@conocophillips.com> Subject: Report of gas bubbling in the cellar of Kuparuk gas lifted producers 2A-15 (PTD #185-146) & 2A-14 (PTD #185-145). Victoria and Jack- This email is to inform you of the current situation of Kuparuk gas lifted producer 2A-15 (PTD #185-146) and 2A-14 (PTD #185-145). The well was identified by the operations group to have gas bubbling in the cellar on 16 Dec 2025. DHD harvested compositional gas samples from the cellar and IA to evaluate and compare the cellar gas to the process gas. The initial evaluation of the gas sample suggested “produced gas” based on the presence of the heavier components (C6 – C8). For further evaluation, Isotopic gas sampling was harvested and has been send in for expedited processing. DHD conducted a TIFL to prove integrity of the tubing and production packer with the intentions to secure, circulate out the IA and perform a CMIT-TxIA to verify the integrity of the production casing. However, after 2A-15 had been shut in for the TIFL, the tubing pressure increased to ~1000 psi and the IA pressure bled from ~1300 psi to ~200 psi , the operations group noted gas now bubbling from the cellar of 2A-14 (PTD #185-145) the well immediately adjacent to 2A-15. Cellar gas samples from 2A-14 were harvested today and are currently being evaluated. CPAI has developed a plan for the initial diagnostics, to systematically evaluate the identified potential sources. Because the bubbling appeared to spread with an elevated pressure on the tubing of 2A-15, the initial step is to put the well back on production to see if the bubbling will subside to the original status. An evaluation of “in area” geology is being conducted to determine potential uncemented formations or faults which could be potential sources. An evaluation of “on pad” and nearby wells will also be conducted to look for any abnormal operating conditions in which may be contributing to the bubbling. CPAI will notify the AOGCC with any major scope changes or if information from the diagnostics confirms the pressure source. Attached are current copies of the 90-day TIO plot and well bore schematics. Please feel free to contact with any questions or concerns. Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 Well Name: 2A-15 & 2A-14 Facility: CPF2 PTD: 185-146 & 185-145 Well Type: Prod AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: Notification Maximum Pressure (if applicable): 2089 Date of Occurrence (if applicable): 1/10/2026 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 15' of Fill) 7,527.0 2A-14 1/7/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added POGLM assembly 2A-14 6/17/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: *** SURFACE ANNULUS CEMENTED FROM 2033' TO SURFACE *** 7/31/2010 worthms Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 37.3 103.0 103.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 30.2 3,051.0 2,888.1 36.00 J-55 BTC PRODUCTION 7" Tie- Back 7 6.28 22.0 2,047.6 2,037.8 26.00 L-80 TC-II PRODUCTION 7 6.28 2,047.6 7,227.0 5,778.1 26.00 J-55 BTC LINER 5 4.41 7,006.0 7,860.0 6,285.1 15.00 K-55 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.0 Set Depth … 6,879.0 Set Depth … 5,529.7 String Max No… 2 7/8 Tubing Description TUBING WO Wt (lb/ft) 6.50 Grade L-80 Top Connection 8rd EUE ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.0 22.0 0.00 HANGER 6.000 FMC Tubing Hanger TC-1A-EN w/pup jt. FMC 2.875 488.6 488.6 1.02 NIPPLE 3.703 Camco 'DS" Nipple 2 7/8" x 2.312" 2.312 2,611.4 2,549.7 32.48 GAS LIFT 4.750 Camco 2 7/8"x1"KBMG, GLM w/1"DUMMY & BK-5 Latch CAMCO KBMG 2.347 4,079.6 3,598.6 46.33 GAS LIFT 4.750 Camco 2 7/8"x1"KBMG, GLM w/1"DUMMY & BK-5 Latch CAMCO KBMG 2.347 5,270.0 4,409.6 45.86 GAS LIFT 4.750 Camco 2 7/8"x1"KBMG, GLM w/1"DUMMY & BK-5 Latch CAMCO KBMG 2.347 6,106.1 4,991.6 45.45 GAS LIFT 4.750 Camco 2 7/8"x1"KBMG, GLM w/1"DUMMY & BK-5 Latch CAMCO KBMG 2.347 6,691.5 5,399.1 45.32 GAS LIFT 4.750 Camco 2 7/8"x1"KBMG-M , GLM w/1" DCK-2 SOV & BEK-Latch CAMCO KBMG- M 2.347 6,746.7 5,437.4 46.38 SEAL ASSY 5.460 80-32 Baker Seal Assembly w/Locator SPACED 7' OFF FULLY LOC. 3.250 6,754.2 5,442.6 45.97 PBR 5.860 80-32 Baker PBR 3.250 6,777.6 5,459.1 45.22 PACKER 5.970 Baker 47-B2 FH Retrievable Packer 2.430 6,824.5 5,491.8 46.30 NIPPLE 3.703 Camco 2 7/8"x2.312" "X" Nipple 2.312 6,871.7 5,524.6 45.89 OVERSHOT 6.000 Baker Poorboy Tubing Stub Overshot Space out 1' off top of slickstick. 3.375 Top (ftKB) 6,863.7 Set Depth … 7,451.8 Set Depth … 5,953.6 String Max No… 2 3/8 Tubing Description TUBING Original 2.875 x 2.375" Wt (lb/ft) 4.70 Grade N-80 Top Connection EUE8rd ID (in) 2.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,863.7 5,519.1 45.81 SLICK STICK 3.125 CAMCO SLICK STICK COVERED BY POORBOY OVERSHOT 2.410 6,881.2 5,531.3 45.71 PACKER 6.150 CAMCO HRP-ISP PACKER 2.344 6,918.6 5,557.5 45.77 PRODUCTION 4.750 CAMCO KBMG 2.347 6,956.7 5,584.1 45.44 NIPPLE 3.400 AVA 'BPL' PORTED NIPPLE 2.250 7,322.6 5,850.7 39.00 BLAST JT 2.375 1.995 7,429.8 5,935.8 36.48 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.250 7,431.0 5,936.9 36.48 PACKER 4.156 BAKER 'DB' PACKER 3.250 7,434.0 5,939.3 36.47 SBE 3.250 BAKER SEAL BORE EXTENSION 2.441 7,445.1 5,948.2 36.46 NIPPLE 3.400 CAMCO 'D' NIPPLE NO GO 1.813 7,451.0 5,952.9 36.45 SOS 2.375 OTIS SHEAR OUT SUB 1.995 7,451.4 5,953.2 36.45 WLEG 2.375 OTIS WIRELINE ENTRY GUIDE 1.995 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,416.0 3,830.2 49.53 PACKER - PATCH - UPR 2.285" PIIP Upper Patch Assembly (Assembly includes the PIIP Packer, spacer pipe, POGLM, spacer pipe, Anchor Latch all listed below. OAL = 17.36', ME to ME of Patch is from 4418'.19' to 4432' RKB TTS PIIP CPP2 87058 6/17/2024 1.380 4,419.7 3,832.5 49.72 SPACER PIPE Spacer Pipe in Upper Patch Assembly 6/17/2024 1.600 4,423.0 3,834.7 49.45 POGLM POGLM included in Upper Patch Assembly. POGLM has 1" OV w/0.25" Carbide Port with check. NPT threaded (NON-REMOVABLE, must pull Upper Patch Assembly to change OV CPAI POGLM 6/17/2024 1.600 2A-14, 6/18/2024 7:33:07 AM Vertical schematic (actual) LINER; 7,006.0-7,860.0 FLOAT SHOE; 7,858.5-7,860.0 FLOAT COLLAR; 7,784.5- 7,786.3 STAGE COLLAR LINER; 7,746.9-7,748.3 FISH; 7,535.0 RE-FRAC; 7,504.0 RE-FRAC; 7,504.0 FRAC; 7,504.0 IPERF; 7,504.0-7,542.0 APERF; 7,478.0-7,488.0 APERF; 7,462.0-7,467.0 WLEG; 7,451.4 SOS; 7,451.0 NIPPLE; 7,445.1 SBE; 7,434.0 PACKER; 7,431.0 SEAL ASSY; 7,429.7 IPERF; 7,348.0-7,414.0 PRODUCTION; 2,050.0-7,227.0 HANGER; 7,006.0-7,017.2 NIPPLE; 6,956.7 ISO-SLEEVE; 6,956.7 PRODUCTION; 6,918.6 PACKER; 6,881.2 OVERSHOT; 6,871.7 SLICK STICK; 6,863.7 NIPPLE; 6,824.5 PACKER; 6,777.6 PBR; 6,754.2 SEAL ASSY; 6,746.7 GAS LIFT; 6,691.5 GAS LIFT; 6,106.1 GAS LIFT; 5,270.0 PACKER - PATCH - LWR; 4,429.8 ANCHOR LATCH ON SPACER PIPE; 4,423.9 LEAK; 4,424.0 POGLM; 4,423.0 SPACER PIPE; 4,419.7 PACKER - PATCH - UPR; 4,416.0 GAS LIFT; 4,079.6 SURFACE; 30.2-3,051.0 GAS LIFT; 2,611.4 PRODUCTION 7" Tie-Back; 22.0-2,047.6 Casing Nipple; 2,046.2-2,047.6 Cement Retainer; 2,033.6- 2,036.1 CEMENT; 22.0 ftKB NIPPLE; 488.6 CONDUCTOR; 37.3-103.0 HANGER; 22.0 KUP PROD KB-Grd (ft) 37.29 RR Date 7/30/1985 Other Elev… 2A-14 ... TD Act Btm (ftKB) 7,863.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032004000 Wellbore Status PROD Max Angle & MD Incl (°) 49.73 MD (ftKB) 4,419.91 WELLNAME WELLBORE2A-14 Annotation Last WO: End Date 7/31/2010 H2S (ppm) 50 Date 12/5/2016 Comment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,423.9 3,835.3 49.37 ANCHOR LATCH ON SPACER PIPE Spacer Pipe and Anchor Latch included in Upper Patch Assembly TTS Anchor Latch CPAL 28704 7 6/17/2024 1.380 4,424.0 3,835.3 49.36 LEAK TBG LEAK IDENTIFIED BY EL LDL AT 4424' RKB (0.25 BPM, 1100 PSI) 5/23/2023 2.441 4,429.9 3,839.2 48.83 PACKER - PATCH - LWR 2.285" PIIP LOWER PACKER WITH WLEG, MOE = 4432' RKB, OAL = 3.55' TTS PIIP CPP2 87016 6/13/2024 1.380 6,956.7 5,584.1 45.44 ISO-SLEEVE BPI SLEEVE, 2.25" OD, 1.81" ID, OAL = 28.5 AVA BPI 6/13/2024 1.810 7,535.0 6,020.6 36.25 FISH CRX PLUG 33" CRX PLUG in RATHOLE (No Go ID=1.856") 1/8/1998 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,611.4 2,549.7 32.48 1 GAS LIFT GLV BK 1 1,277.0 6/13/2023 0.188 4,079.6 3,598.6 46.33 2 GAS LIFT GLV BK 1 1,337.0 6/14/2023 0.188 5,270.0 4,409.6 45.86 3 GAS LIFT DMY BK 1 0.0 6/13/2023 0.000 6,106.1 4,991.6 45.45 4 GAS LIFT DMY BK 1 0.0 6/13/2023 0.000 6,691.5 5,399.1 45.32 5 GAS LIFT DMY BK 1 0.0 4/22/2023 0.000 6,918.6 5,557.5 45.77 6 PROD DMY BK 1 0.0 1/8/1998 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,348.0 7,414.0 5,870.6 5,923.2 C-4, UNIT B, 2A- 14 10/5/1985 6.0 IPERF 60 deg. phasing; SOS Csg Gun 7,462.0 7,467.0 5,961.8 5,965.8 A-3, 2A-14 6/13/2015 8.0 APERF 0 deg phasing, Deep Star Strip Gun 7,478.0 7,488.0 5,974.7 5,982.7 A-3, 2A-14 6/13/2015 8.0 APERF 0 deg phasing, Deep Star Strip Gun 7,504.0 7,542.0 5,995.6 6,026.2 A-3, 2A-14 10/5/1985 6.0 IPERF 60 deg. phasing; SOS Csg Gun Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,504.0 7,542.0 1 FRAC 10/16/1985 0.0 0.00 0.00 7,504.0 7,542.0 1 RE-FRAC 6/30/1990 0.0 0.00 0.00 7,504.0 7,542.0 2 RE-FRAC 10/28/1997 0.0 0.00 0.00 1 Scale Inhibitor 8/19/1990 0.0 0.00 0.00 2 Scale Inhibitor 2/7/1993 0.0 0.00 0.00 3 Scale Inhibitor 5/2/1997 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 22.0 2,033.0 22.0 2,023.9 CEMENT SURFACE ANNULUS CEMENTED TO SURFACE 7/31/2010 2A-14, 6/18/2024 7:33:07 AM Vertical schematic (actual) LINER; 7,006.0-7,860.0 FLOAT SHOE; 7,858.5-7,860.0 FLOAT COLLAR; 7,784.5- 7,786.3 STAGE COLLAR LINER; 7,746.9-7,748.3 FISH; 7,535.0 RE-FRAC; 7,504.0 RE-FRAC; 7,504.0 FRAC; 7,504.0 IPERF; 7,504.0-7,542.0 APERF; 7,478.0-7,488.0 APERF; 7,462.0-7,467.0 WLEG; 7,451.4 SOS; 7,451.0 NIPPLE; 7,445.1 SBE; 7,434.0 PACKER; 7,431.0 SEAL ASSY; 7,429.7 IPERF; 7,348.0-7,414.0 PRODUCTION; 2,050.0-7,227.0 HANGER; 7,006.0-7,017.2 NIPPLE; 6,956.7 ISO-SLEEVE; 6,956.7 PRODUCTION; 6,918.6 PACKER; 6,881.2 OVERSHOT; 6,871.7 SLICK STICK; 6,863.7 NIPPLE; 6,824.5 PACKER; 6,777.6 PBR; 6,754.2 SEAL ASSY; 6,746.7 GAS LIFT; 6,691.5 GAS LIFT; 6,106.1 GAS LIFT; 5,270.0 PACKER - PATCH - LWR; 4,429.8 ANCHOR LATCH ON SPACER PIPE; 4,423.9 LEAK; 4,424.0 POGLM; 4,423.0 SPACER PIPE; 4,419.7 PACKER - PATCH - UPR; 4,416.0 GAS LIFT; 4,079.6 SURFACE; 30.2-3,051.0 GAS LIFT; 2,611.4 PRODUCTION 7" Tie-Back; 22.0-2,047.6 Casing Nipple; 2,046.2-2,047.6 Cement Retainer; 2,033.6- 2,036.1 CEMENT; 22.0 ftKB NIPPLE; 488.6 CONDUCTOR; 37.3-103.0 HANGER; 22.0 KUP PROD 2A-14 ... WELLNAME WELLBORE2A-14 Originated: Delivered to:9-Jul-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1H-10 50-029-22346-00 909358839 Kuparuk River Patch Setting Record Field- Final 27-May-24 0 1 2 1H-104 50-029-23610-00 909292908 Kuparuk River Leak Detect Log with ACX Field & Processed 22-Apr-24 0 1 3 1L-06 50-029-21164-00 n/a Kuparuk River Leak Detect Log Field- Final 7-May-24 0 1 4 1L-06 50-029-21164-00 909298478 Kuparuk River Multi Finger Caliper Field & Processed 8-May-24 0 1 5 1L-06 50-029-21164-00 n/a Kuparuk River Plug Setting Record Field- Final 7-May-24 0 1 6 1L-24 50-029-22170-00 909422478 Kuparuk River Multi Finger Caliper Field & Processed 4-Jul-24 0 1 7 1L-24 50-029-22170-00 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1 8 1R-35 50-029-23050-00 909353301 Kuparuk River Multi Finger Caliper Field & Processed 29-May-24 0 1 9 2A-14 50-103-20040-00 909382630 Kuparuk River Patch Setting Record Field- Final 13-Jun-24 0 1 10 2B-11 50-029-21089-00 n/a Kuparuk River Plug Setting Record Field- Final 11-May-24 0 1 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39155 T39156 T39157 T39157 T39157 T39158 T39158 T39159 T39160 T39161 193-030 218-084184-133 191-066201-210 185-145184-035 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:13:09 -08'00' 92A-14 50-103-20040-00 909382630 Kuparuk River Patch Setting Record Field- Final 13-Jun-24 0 1 T3916039160 201 210 185-145184 035 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1L-03A 50-029-21182-01 199037_1L-03A_HEX Plug_17Jul2022 199037_1L-03A_RBP_03Apr2022 199037_1L-03A_WFL_04Jan2023 1L-28 50-029-22951-00 199098_1L-28_LDL_29May2022 1Q-01 50-029-21247-00 184231_1Q-01_IPROF_09Jan2023 1Q-05 50-029-21233-00 184217_1Q-05_HEX Plug_18Jul2022 1R-07 50-029-21332-00 185072_1R-07_LeePPROF_14Jan2023 1R-19A 50-029-22185-01 191085_1R-19A_SBHPS CUT_18Jun2022 1R-36 50-029-23057-00 201227_1R-36_IPROFWFL_30Jun2023 1Y-19 50-029-22391-00 193107_1Y-19_PPROF_26Mar2022 1Y-32 50-029-21854-00 188093_1Y-32_PPROF_27May2023 2A-14 50-103-20040-00 185145_2A-14_LDL_23May2023 2A-19A 50-103-20197-01 201083_2A-19A_CHC_20Feb2023 5of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38351 T38352 T38353 T38354 T38355 T38356 T38357 T38358 T38359 T38360 T38361 2/29/2024 2A-14 50-103-20040-00 185145_2A-14_LDL_23May2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:38:59 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-05-23_21139_KRU_2A-14_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21139 KRU 2A-14 50-103-20040-00 Caliper Survey w/ Log Data 23-May-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 185-145 T37680 Kayla Junke Digitally signed by Kayla Junke Date: 2023.05.31 11:21:37 -08'00' STATE OF ALASKA • A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend Perforate �I Other Stimulate Alter Casing r � r Change Approved Program Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: r' 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 185-145 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20040-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25570 KRU 2A-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7863 feet Plugs(measured) none true vertical 6288 feet Junk(measured) 7535 Effective Depth measured 7785 feet Packer(measured) 6778,6881,7431 true vertical 6223 feet (true vertical) 5459, 5531,5937 Casing Length Size MD TVD Burst Collapse CONDUCTOR 66 16 103 103 SURFACE 3021 9.625 3051 2888 PRODUCTION 5179 7 7227 5778 LINER 854 5 7860 6285 RECEIVED cAti '+ NOV 1 22015 JUL 0 8 2015 Perforation depth: Measured depth: 7348-7414, 7462-7467,7478-7488,7504-7542 True Vertical Depth: 5871-5923, 5962-5966, 5975-5983,5996-6026 CC Tubing(size,grade,MD,and TVD) 2.875", L-80,6879' MD, 5530'TVD,2.375", N-80,7452'MD, 5954'TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER 47-B2 FH RETRIEVABLE PACKER @ 6778 MD and 5459 TVD PACKER-CAMCO HRP-ISP PACKER @ 6881 MD and 5531 TVD PACKER-BAKER'DB' PACKER @ 7431 MD and 5937 TVD NIPPLE-Camco'DS"Nipple 2 7/8"x 2.312"@ 489 MD and 489 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 173 3342 2776 -- 211 Subsequent to operation 174 3369 2769 -- 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development PI Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F,7 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact John Peirce (,265-6471 Email John.W.Peirceconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature4.‘ Phone:265-6471 Date / f 7-/ iS ✓" r a -1-k.:-z-- VTi.. T/Z/i3 RBDMS JUL - 8 2015 Form 10-404 Revised 5/2015 4 "Vy/f Submit Original Only • 2A-14 WELL WORK SUMMARY 0 DATE SUMMARY 4/14/2015 DRIFTED TBG &TAGGED @ 7515' SLM WITH 10' x 1.75" BAILER. SET XX PLUG @ 6825' RKB, SET CATCHER ON PLUG. PULLED OV FROM @ 4080' RKB. IN PROGRESS. 4/15/2015 SET 1/4" PORT OV @ 4080' RKB. PULLED CATCHER &XX PLUG @ 6825' RKB. COMPLETE. 5/1/2015 NC SAND SCALE SQUEEZE: PUMPED 50 BBLS SW AHEAD OF TREATMENT. PUMPED 25 BBLS OF SEAWATER PRE-FLUSH CONTAINING 80 GALLONS OF WAW-5206, PUMPED 138 BBLS OF SEAWATER CONTAINING 760 GALLONS OF SCW-4004, PUMPED 296 BBLS SW FOLLOWED BY 20 BBLS DIESEL OVERDISPLACEMENT. FP'D F/L WITH 10 BBLS MEOH. 6/7/2015 DRIFTED TBG. w/ 10'x 1.75" BAILER AND TAGGED @ 7512' SLM. IN PROGRESS (READY FOR E-LINE PERF) 6/13/2015 PERFORATE 7462' -7467'WITH 1.69" DEEP STAR GUN 8 SPF 0 DEG PHASED. PERFORATE 7478' - 7488'WITH 1.69" DEEP STAR GUN 8 SPF 0 DEG PHASED. HIGH GAMMA RAY FROM SCALE BELOW 6900'AND ABOVE 7400' REQUIRED CORRELATION ABOVEANDBELOW ZONE. K1 MARKER COULD NOT BE SEEN IN SCALE ZONE. 6/25/2015 TAGGED @ 7510' SLM ( EST. 12' OF FILL) MEASURED BHP @ 7381' RKB (2211 PSI). JOB COMPLETE. 6/29/2015 PUMPED 2OBBLS OF DIESEL DOWN THE TUBING FOR FREEZE PROTECT. JOB COMPLETE. 1. KUP PROD 0 2A-14 • ConocoPhillips "' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APSUWI Field Name Wellbore Status net(°) MD(ftKB) Act Btm(NKS) cmomwvl5ps 501032004000 KUPARUK RIVER UNIT PROD 49.73 4,419.91 7,863.0 °-° Comment HOS(ppm) Date Annotation End Date KB-Grd(k) -.Rig Release Date 2A-14,6/30/20151:31:00 PM SSSV:NIPPLE 80 11/1/2014 Last WO: 7/31/2010 37.29 7/30/1985 Vertical schematic(actual) Annotation Depth(MB) End Date Annotation Last Mod By End Date ...._..........._..........................._....._.__....._....................._..,...............Last Tag:SLM 7,510.0 6/25/2015 Rev Reason:TAG hipshkf 6/30/2015 HANGER;22.0-:+ ,e) asi ngS ng DOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread . -.- Casing ption 16 15.060 37.3 103.0 103.0 62.50 H-40 WELDED ,,,,, , ,, ,,, ,,,; , , , ;ue MI:),a,a„.em Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.765 30.2 3,051.0 2,888.1 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread `- PRODUCTION 7"Tie- 7 6276 22.0 2,047.6 2,037.8 26.00 L-80 TC-II .AAI CONDUCTOR;37.3-103.0.AJtA/',:. r...c :s_&e V'e Back.. Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread E PRODUCTION 7 6.276 2,047.6 7,227.0 5,778.1 26.00 J-55 BTC ; x NIPPLE;488.6 .s , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...WtlLen(I...Grade Top Thread LINER 5 4.408 7,006.0 7,860.0 6,285.1 15.00 K-55 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com On) PRODUCTION 7"Te-Back: '. k 7,006.0 5,618.8 44.97 HANGER LINER HANGER 5.000 22.0-2,0476 Tubing Strings .4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection GAS LIFT;2,611A-4 4 TUBING WO 27/8 2.441 22.0 6,879.01 5,529.7 6.50 L-80 8rd EUE - Completion Details ._ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.0 22.0 0.00 HANGER FMC Tubing Hanger TC-1A-EN w/pup jt. 2.875 SURFACE;302-3.051.0.-A e- 488.6 488.6 1.02 NIPPLE Camco'DS"Nipple 2 7/8"x 2.312" 2.312 - 6,746.7 5,437.4 46.38 SEAL ASSY 80-32 Baker Seal Assembly w/Locator SPACED 7'OFF 3250 GAS LIFT;4,079.6 4 FULLY LOC. 6,754.2 5,442.6 45.97 PBR 80-32 Baker PBR 3.250 ® 6,777.6 5,459.1 45.22 PACKER Baker 47-82 FH Retrievable Packer 2.430 GAS LIFT;5,270.0II 6,824.5 5,491.8 46.30 NIPPLE Camco 2 7/8"x2.312""X"Nipple 2.312 6,871.7 5,524.6 45.89 OVERSHOT Baker Poorboy Tubing Stub Overshot Space out 1'off 3.375 II of slickstick. ® Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection GAS UFT;6,106.1 II TUBING Original 23/8 1.995 6,863.7 7,451.8 5,953.6 4.70 N-80 EUE8rd M 2.875 x 2.375" - • Completion Details ® Nominal ID GAS LIFT;6,691.5 X Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 6,863.7 5,519.1 45.81 SLICK STICK CAMCO SLICK STICK COVERED BY POORBOY OVERSHOT 2.410 ® II 6,881.2 5,531.3 45.71 PACKER CAMCO HRP-ISP PACKER 2.344 SEAL ASSY;6,746.7 =- 6,956.7 5,584.1 45.44 NIPPLE AVA'BPL'PORTED NIPPLE 2.250 PBR;6,754.2 7,322.6 5,850.7 39.00 BLAST JT 1.995 PACKER;6,777.6 . '®" 7,429.8 5,935.8 36.48 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.250 ® 7,431.0 5,936.9 36.48 PACKER BAKER'DB'PACKER 3.250 NIPPLE;6,824.5 '� 7,434.0 5,939.3 36.47 SBE BAKER SEAL BORE EXTENSION 2.441 ® 7,445.1 5,9482 36.46 NIPPLE CAMCO'D'NIPPLE NO GO 2.250 7,451.0 5,952.9 36.45 SOS OTIS SHEAR OUT SUB 1.995 SLICK STICK;6,863.7-, 7,451.4 5,9532 36.45 WLEG OTIS WIRELINE ENTRY GUIDE 1.995 OVERSHOT;6,871.7 iT I i Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PACKER;6,881.2 SRNTop(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,535.0 6,020.6 36.25 FISH CRX PLUG 33"CRX PLUG in RATHOLE(No Go 1/8/1998 PRODUCTION;6918.6 ID=1.856") II NIPPLE;0,956.7 Perforations&Slots V. Shot Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (kKB) Zone Date t) Type Com III 7,348.0 7,414.0 5,870.6 5,9232 C-4,UNIT B, 10/5/1985 6.0 IPERF 60 deg.phasing;SOS 2A-14 Csg Gun PRODUCTION;2,050.0-7,227.0 7,462.0 7,467.0 5,961.8 5,965.8 A-3,2A-14 6/13/2015 8.0 APERF 0 deg phasing,Deep Star Strip Gun (PERF;7,348.0.7,414.0 7,478.0 7,488.0 5,974.7 5,982.7 A-3,2A-14 6/13/2015 8.0 APERF 0 deg phasing,Deep s Star Strip Gun )MIISEAL ASSY;7,0-29.7 7,504.0 7,542.0 5,995.6 6,026.2 A-3,2A-14 10/5/1985 6.0 IPERF 60 deg.phasing;SOS ,, Csg Gun PACKER;7,431.0 513E;7,434.0 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) I (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com NIPPLE;7,445.1 ?_ 7,504.0 7,542.0 5,995.6 6,026.2 FRAC 10/16/198 A-SAND FRAC-PUMPED 5 STAGES OF 2200# ■ 5 20/40 8 125 bbls DIESEL • SOS;7,451.0 7,504.0 7,542.0 5,995.6 6,0262 RE-FRAC 6/30/1990 A-SAND FRAC-PUMPED 113668 16/20 WLEG;7,451.4 'L. CARBOLITE 7,504.0 7,542.0 5,995.6 6,026.2 RE-FRAC 10/28/199 A-SAND FRAC-PUMPED 316,2638 PROPPANT UP 7 TO 13.6 PPA 10/14 IN PERFS APERF;7,462.0-7,4670 _ - Mandrel Inserts _ _ St APERF;7,478.0-7,488.0 _ _ ati RE-FRAC;7,504.0 on Top(TVD) Valve Latch Port Size TRO Run RE-FRAC;7,504.0 - N Top(ftKB) (MB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com IPERF;7,504.0-7,5 , .0 1 2,611.4 2,549.7 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,281.0 8/4/2010 FRAC;7,50404.0 FISH;7,535.0 _ 2 4,079.6 3,598.6 CAMCO KBMG 1 GAS LIFT OV BK-5 0.250 0.0 4/6/2013 .-. 3 5,270.0 4,409.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/30/2010 4 6,106.1 4,991.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/30/2010 5 6,691.5 5,399.1 CAMCO KBMG- 1'GAS LIFT DMY BK-5 0.000 0.0 8/4/2010 M ' 6' 6,918.6 5,557.5 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 1/8/1998 LINER;7,006.0-7860.0 - 25c%ci3 WELL LOG TRANSMITTAL pATC BA LOGGED 1/I'END 2ND H To: Alaska Oil and Gas Conservation Comm. June 22, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ;X. ; JUN 2 6 2U1J RE: Perforation Record: 2A-14 Run Date: 6/13/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20040-00 SCONE) JUL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: /12...d.....47) Image Project Well History File' Page 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(~"- - _J_ L~ _~ Well History File Identifier Organizing{done) /~ Two-Sided III IIIIIIIIIII II III RESCAN DIGITAL DATA [] Color items: D Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: ~, [] Other: , NOTES: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) n Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /S/ Scanning Preparation 30= bO BY: BEVERLY BREN VINCENT SHERYL~ LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: V~YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: ~ BREN VINCENT SHERYL MARIA LOWELL' DATE: //, /o 0(~. /S/ ~ (SCANNING IS COMPL~HIS POINT UNLESS SPECIAl. ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS RESCANNEDBY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked {done) 10125/02Rev3NOTScanned.wpd • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 8, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2A -14 Run Date: 11/28/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -14 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 103 - 20040 -00 Production Profile Log 1 Color Log 50 -103 - 20040 -00 mow FE? t . 2011 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood �-, K ��- 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.woo F ego Date: Signed: Alaska C3 a Gay. ??fia ash • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: String Shot: 2A-14 Run Date: 7/20/2010 July 23, 2010 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 2A-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20040-00 ~ q jai ~ " ~, i ' .F ,;; ''> fl ~ z ~.., ,~ ;+.1 t~ as r ~~ , ~.1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto halliburton.com~ s Date: ~)g )iii'; 1 ~S ~ _ l ~~~ ~ g ~~ Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut: 2A-14 Run Date: 7/17/2010 July 23, 2010 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 2A-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20040-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto halliburton.com ~~. >: ,, , Date: i 3, is ~ , n "~ ~~' ~J:~ Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: CAST-F /CBL /Casing Inspection (CASE): 2A-14 Run Date: 7/19/2010 • July23, 2010 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 2A-14 Data in LAS format, Digital Log Image files 1 CD Rom SO-103-20040-00 CASE Log 1 Color Log 50-103-20040-00 CBL Field print 1 Color Log 50-103-20040-00 CAST-F Field print 1 Color Log 50-103-20040-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto @halliburton. com ~ ,a r Date: , , ~~ ,, ~ , 6 lJ~~ l [~r '~ /~~ f Signed: ~® ~et~ ~ ~ ~, ~ ~ WELL LOG S TRANSM/TTAL PROACTIVE DIAGNOSTIC SERVICES INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 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 Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 23-Ju1-10 2A-14 1 Report /EDE 50-029-20040-00 2) Caliper Report 22-JuF10 1A-24 i ~ S- IYS 1 ~9~3 Signed Print Name: 1 Report /EDE 50-029-22984-00 ~~,~ Date : !UL 3 ~ 2110 f~°t~. Dt~rrtl?~i~~i,~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MALI.: pdsanchoraaer~memoryloa.com WEBSITE : www.memorvlon.com C9Documents and Settings\Diane Williams\Desktop\Transmit_Conoco.docx • Memory Multi-Finger Caliper ~j Log Results. Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-14 Log Date: July 23, 2010 Field: Kuparuk Log No.: 7432 State: Alaska Run No.: 2 API No.: 50-103-20040-00 Pipet Desc.: 9.625" 36 Ib. J-55 Top Log Intvl1.: Surface Pipet Use: surtace Casing Bot. Log Intvl1.: 1,980 Ft. (MD) Inspection Type : Buckling & Restriction Inspection COMMENTS This caliper data is tied into the top of surface casing @ 0'. This log was run to assess the condition of the 9.625" surtace casing with respect to buckling and minimum I.D. restrictions. The caliper recordings indicate buckling from surface to ^1,550', with severe buckling recorded in joint 5 (-220') and joint 6 (--232'), restricting the I.D. to 7.58" and 8.38" respectively. Heavy deposits restrict the I.D. to 6.43" in joint 46 (1,979'). Log plots of the centered and off-center caliper recordings across buckling recorded in the surtace casing logged and a graph illustrating minimum recorded diameters on a joint-by joint basis are included in this report. The caliper recordings indicate the 9.625" surtace casing logged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional wall toss recorded throughout the surface casing logged. This is the second time a PDS caliper has been run in this well and the first time the 9.625" surface casing has been togged. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 7°~} are recorded throughout the surtace casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded throughout the surface casing logged. MAXIMUM RECORDED ID RESTRICTIONS: Heavy Deposits Minimum LD. = 6.43" Jt. 46 @ 1,979 Ft. (MD) Heavy Deposits Minimum I.D. = 7.21" Jt. 43 @ 1,808 Ft. (MD) Heavy Deposits Minimum I.D. = 7.36" Jt. 45 @ 1,937 Ft. (MD) Heavy Deposits Minimum I.D. = 7.40" Jt. 44 @ 1,889 Ft. (MD) Heavy Deposits Minimum I.D. = 7.42" Jt. 42 @ 1,790 Ft. (MD) Field Engineer: Wm. McCrossan Analyst: HY. Yang Witness: R. Overstreet PraActire Diagnostic Services, Inc. / P,O. Box 1x'69, Stafford, TX 77497 Phone: {28i} or (888; 565-9085 Fax: (281) 565-1369 E-maii: PDS a~memorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907} 659-2314 J'~5 -its it x}96-3 • PDS Multifinger Caliper 3D Log Plot ~'-`~ aruk Company : ConocoPhill~ps Alaska, Inc. Field : Kup Well : 2A-14 Date : July 23, 2410 Description : Detail of Centered Caliper Recordings Across Buckling Recorded in 9.625" Casing. PDS Muftifinger Caliper 3D Log Plot ~,__~~.. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-14 Date : July 23, 2010 Description : Detail of Off-Center Caliper Recordings Across Buckling Recorded in 9.625" Casing i • Joint 14 Buckling ? -~ --- ~. _ __ 600 ::;.., Joint 15 ~k __. ._ ._ Buckling 650 ~ .__ ,., ~ Joint 16 ~ Buckling - v`~ - - _ - , .: 700 ~ ' - V Joint 17 4 ,.....:,~: ~ Buckling j ~. „ - _ -, . '" Joint 18 750 Buckling . ~ .- '- ._. Joint 19 00 • ~: - , w il Buckling ,, fr - k ,. Joint 20 ..~ i Y "~ ~ .~tpg ` _ Buckling ,~ „~~_ __. - , 850 . a ." ~.,.. ~. ,:. _ . Joint 21 i -: ~ ._,, Buckling ` ? 900 _ - ,~-' Joint 22 Y:_ a~ _~._ _. . Buckling _ , _..~ ,,,~ ` 950 Joint 23 Buckling ~m ,- ~. 1000 _ Joirrt 24 Buckling :,~ -. Joint 25 1050 ~.. Buckling • ` ,4-w . Joint ze 1100 - Buckling .. Y _ Joint 27 -- ~_.,:. .,._ ..._. ~ ~.a Buckling ~ ., . „~'" `.: 1150 _ .. .~.w „ ,-, ~u Joint 28 Buckling -, , 1200 Joint 29 1_ - °- Buckling i _;.-:: - 1250 _ ` -_ Joint 30 Bucklin 9 ~ -: I 1300 ~_ _ ^" Joint 31 Q~ ~r4linn - ~` ~ • • Joint 32 Buckling 1350 Joint 33 Buckling 1400 Joint 34 Buckling 1450 Joint 35 Buckling Joint 36 Buckling 1500 Joi~rt 37 1550 1600 Joint 38 1650 Joint 39 ' Joirrt4o 1700 Joint 41 1750 Joitrt 42 Min. LD. = 7A2" 1800 Joint 43 Min. LD. = 7.21" -1_ 1850 Joint 44 Min. LD. = 7.40" _ _ __ 1900 Joint 45 Min. LD. = 7.36" _ _.. -= Joint 46 1950 Min. LD. = 6.43" Nominal I.D. (ins.) 7.7 9.7 Min. I.D. (ins.) 7.7 9.7 Comments Depth Max. I.D. (ins.) 1ft:900ft 7.7 9.7 ~. -- _ _:n =e~.: ,: -. xa. ; ~ _ '_ may,,:: a-==rt _.--_ i - ~.~ .- ~~ `'.~ ~~ ^~ 3-D • C: ,_~ti Minimum Diameter Profile Well: 2A-14 Survey Date: July 23, 2010 Field: Kuparuk Tool: UW MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 8.765 inches Minimum Measured Diameters (In.) 2.75 3.25 3.75 425 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 0.1 v 4 -I 6 - 8 10 12 14 16 18 20 d ~ 22 E 0 z z4 "o z6 za 30 32 34 36 38 40 I, 42 ~. 43 46 • • PDS Report Overview ~.~,_ S,, Body Region Analysis Well: 2A-14 Survey Date: July 23, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: HY. Y'an Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 36 > >f -55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body r;.- metal loss body 50 40 - 30 20 10 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 47 penc. 0 47 0 0 0 0 loss '24 23 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion iblehole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body ~-_ metal loss body 0 50 0 10 Bottom of Survey = 46 100 20 30 40 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2A-14 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: Conoco Phillips Alaska, Inc. Nominal LD.: 8.765 in Country: USA Survey Date: July 23, 2010 Joint No. Jt. Depth (Ft.) I'cr~. Uiw~~t lin`.1 Pen. Body (Ins.) Pen. % Metal loss ~. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -0 U 0.03 7 -1 8.95 PUP 1 5 u 0.01 ~ I 8.85 Bucklin . 2 48 a 0.01 3 2 8.84 Bucklin . 3 91 ~? 0.01 2 1 8.85 Bucklin . 4 135 i) 0.01 2 1 8.87 5 178 O 0.02 6 Z 7.58 Severe bucklin . 6 220 t) 0.02 r, 1 8.38 Severe bucklin . 7 263 i; 0.01 ~ 1 8.87 Bucklin . 8 306 U 0.01 i 8.88 Bucklin . 9 349 +) 0.01 ~ 8.89 Bucklin . 10 392 l) 0.01 I 8.87 Bucklin ` 11 435 ll 0.01 ? I 8.87 Bucklin . 12 478 (1 0.01 ~' I 8.85 Bucklin . 13 521 a 0.01 ~' i 8.87 Bucklin 14 564 +> 0.01 ; 8.78 Bucklin ~ 15 607 t) 0.01 > 8.84 Bucklin . 16 650 U 0.01 Z 1 8.79 Bucklin . 17 693 U 0.02 i 8.84 Bucklin . 18 736 ll 0.02 4 8.84 Bucklin . 19 779 a 0.02 4 8.79 Bucklin . 20 821 t) 0.01 3 8.84 Bucklin . 21 864 +) 0.01 ~' 1 8.84 Bucklin . 22 907 U 0.01 2 V 8.81 Bucklin . 23 951 !' 0.02 4 8.86 Bucklin ~ 24 994 U 0.01 2 i 8.80 Bucklin . 25 1036 !? 0.01 3 8.83 Bucklin . 26 1078 t) 0.02 4 _' 8.83 Bucklin . 27 1121 !) 0.02 4 8.80 Bucklin . 28 1165 +) 0.01 2 ! 8.82 Bucklin ' 29 1204 !) 0.01 ? I 8.78 Bucklin . 30 1247 O 0.01 _' 8.81 Bucklin . 31 1291 +) 0.01 1 I 8.85 Bucklin . 32 1334 i? 0.02 4 1 8.79 Bucklin . 33 1377 !' 0.02 4 8.83 Bucklin . 34 1420 +) 0.01 3 ' 8.78 Bucklin . 35 1463 ~) 0.01 Z I 8.86 Bucklin . 36 1506 l) 0.01 > I 8.88 Bucklin . 37 1550 (1 0.01 ? I 8.86 38 1593 ~1 0.01 t 8.88 39 1636 U 0.02 -1 8.87 40 1679 C. 0.01 8.72 Lt. De osits. 41 1723 +! 0.02 a 7.45 Hea de osits. 42 1765 U 0.01 ~~ I 7.42 Hea de osits. 43 1808 U.U I 0.02 4 7.21 Hea de osits. 44 1851 t) 0.01 i 7.40 Hea de osits. 45 1895 !) 0.03 E~ 7.36 Hea ~ de osits. 46 1939 +2n~ 0.03 7 6.43 Hea de osits. _ Penetration Body Metal Loss Body Page 1 C~ S, PDS Report Cross Sections ~. Well: 2A-14 Survey Date: July 23, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: HY. Yan Cross Section for Joint 46 at depth 1978.86 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Rernaining wall area = 100 °~o Tool deviation = 18 " Finger 2 Projection = -2.03 ins Heavy Deposits Minimum I.D. = 6.43 ins HIGH SIDE = UP Cross Sections page 1 • • PDS Report Cross Sections 1 ~ ,, Well: 2A-14 Survey Date: July 23, 2010 Field: Kuparuk Tool Type: UW MFC 10 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f )-55 Anal st: HY". Y"an Cross Section for Joint 43 at depth 1808.21 ft Tool speed = 43 Norninal ID = 8.765 Upset OD = 9.625 Remaining wall area = 100 % In upset region Tool deviation = 14 ° Finger 23 Projertion = -0.912 ins Heavy Deposits Minimum I.D. = 7.21 ins HIGH SIDE = UP Cross Sections page 2 ~~ ~ KUP a 2A-14 ConoeoPhillips ` ` I Att ributes n le 8 MD TD II ~ Wellbore A PI/UWI Fleld Name Well Status Inc! (°) N1D (RI(B) Act Btm (R KBI al'I"~r 'I' / 501032004000 KU PARUK RIVER UNIT PROD 49.73 4,419.91 7,863.0 ~, Comment H2S (ppm) Date Arero[atlon F11tl Da[e KB-Gd (t4 Rig Release Daze ••• - 3228 PM l C f 2 6 2 20 G4 SSSV: LOCKED OUT 150 1/10/2009 Last WO: 37.29 7!30!1985 I We l an :- A-14 /1 / i : smematic-Aaual Arrwta8an Dep th (rtKB) Entl Date Amotatlan Last Mod ey End Dale Last Tag' SLM 7.515.0 8/27!2009 Rev Reason: GLV C/O. PULL CATCHER Imosbor 6/12/2010 Casin $trin 5 String O D String ID Set Depth Set Depth (ND) Sldng Wl Sldn g Casing D escription gn) Pn) To B IRKB) (RKBI (Ibslft) eratl e String Top Thrd CONDUCTOR 1 6 15.060 37.3 103.0 103.0 62.50 H-00 colvcucl aP, 103 SURFACE 95/ 8 8.765 0.0 3.051.0 2.888.1 36.00 J-55 PRODUCTION 7 6.751 0.0 7,227.0 5,779.0 2f+.00 J-55 sarFrr vlv O LINER 5 4.300 7.006.0 7,860.0 6.285.7 15.00 K-55 1 &l8 Tubin Strin s 1 Slnrg O D Strang ID Bet Depth Set DepM (TVD) Strang Wt Strin g Tubing Description Gnl Iin) Top (PotB) IRKeI InKB) (Ibs4[) Grad e String Tap Thrtl Gras uFT, 1 66s TUBING 271 8 2.441 0.0 6,991.0 5608.2 6.50 J-55 BRD EUE TUBING 2 3/ 8 1.995 6,991.0 7,452.0 5,953.8 4.70 N-80 8RD EUE SURFACE Other I n Hole A ll Jewel :Tubin Run & Retrievabie Fish etc. 3.051 lop Depfh (ND) Top lnd Top (Po(B) (RKBI (°) Descrtpbon Comment Run Dale ID (inl cas uFT 1 848 1 845.1 11.70 S AFETY VLV Camco TRDP-tA-SSA' (Locked Out on 7/8/96) 10/5/1985 2.373 3.393 , , 1,886 1,882.2 12.83 G AS LIFT CAMCOlKBMGrt/DMY/BKf!/ Comment: STA 1 5122/2009 2.347 3.393 3.127.0 4542 G AS LIFT CAMCO/KBMC~/1/DMY/BTM///Comment: STA2 5/22/2009 2.347 cns uFT, 4 623 3 968 0 48 16 G AS LIFT CAMCO/KBMGIt/DMY/BK/// Commeni~ STA 3 5/23/2009 2347 4 623 , , . . 5.329 4,450.1 46.58 G AS LIFT CAMCO/KBMG/1/DMY/BK///Comment: STA4 11/19/1998 2.347 5.822 4.7921 44.84 G AS LIFT CAMCO/KBMGrt/DMY/BW// Comment: STA 5 10/25!1997 2347 eras uFT, 5 329 6,320 5,147.0 46.67 G AS LIFT CAMCO/KBMG/1/OPEN//// Comment: STA 6 6/11/2010 2.347 . 6,877 5.486.6 46.60 G AS LIFT MERLAfrGPD/1.5lDMY/RK!!/ Comment: STA 7 10!26!1997 2.375 6,864 5,519.3 46.03 S BR Camco'OEJ' 10/5/1985 2.406 cAS UFr. 6.881 5.531.2 45.72 P ACKER Camco'HRP-I -SP' 10/5/1985 2.344 s,c[2 6,905 5.548.0 45.93 P LUG 2.25" WEATHERFORD WRP 6/7/2010 0.000 6,919 5,557.7 45.80 P RODUCTION CAMCO/KBMG/1/DMY/BK/!/ Comment: CLOSED STA 8 1/8/1998 2.347 GAc LIFT 6,957 5.584.4 45.43 N IPPLE AVA BPL PORTED NIPPLE 10/5/1985 2.250 , s 32o 7,431 5,937.0 36.63 P ACKER Baker 'DB' 70/5/1985 3.250 7,445 5.948.2 36.58 N IPPLE Camco'D' Nipple NO GO 70/5/1985 1.813 oAS 7,451 5,953.0 36.56 5 05 Otis 10/5!1985 1.995 S ~en 7.452 5.953.8 36.55 T TL ELMD @ 7451' ON SWS GLS 9/17/1997 10/5/1985 1.995 7.535 6,020.6 36.25 F ISH CRX PLUG 33" CRX PLUG in RATHOLE (No Go ID=1.856") 1/8/1998 686a SBR Pertora tions 8. Slots , shot Top (TVD) etm (TVD) DerS Top pR(B) Btm (RKBI (RKBI (RKBI Zone Date (~••• 11'Pe Co mment 7,348 7,414 5,871.0 5,923.4 C -0, UNIT B. 10/5/1985 6.0 IPERF 60 deg. phasing; SOS Csg Gun PACY.ER. 6.881 2 A-14 7,504 7,542 5 995.6 6,026.3 A -3. 2A-14 10/5/1985 6.0 IPERF 60 deg. phasing; SOS Csg Gun Notes: General 8 Safe Fstl D ate AmotaOon PLUG, 6,gOS 5/9/2006 NOTE: WAIVERED WELL: IAx OAxOOA-PROD CSG xFORMATION COMMUNICATION 6111!2010 NOTE: ATTEMPTED TO PULL GLV @ 6817', FAILED DUE TO CORKSCREWED TBG PROOUCriora, fi,PiP wPPLE eee7 PRGDUCTION, ?,227 :PEav 7,348-7414 F PACKER.7431 k t NIPPLE, 7445 e ~ ~ ~~ nCE, 7,0.51 ~ TTL, 7 452 IPERF, 7,504-7,542 FISH, 7,635 LINER. 7.8dU TD. 7 863 Brett Packe r r Page 13 of 21 07/13/2010 _t ~ C~~ ING /TUBING /LINER DETt -: DRILL SITE l~U ~,~¢!1 ~ ~-A ~ ~,~ ARCO Alaska IBC. ~~ DATE ~~ x l" ~~ Subsidiary of AtianticRichfia,dCompany `~ Page ~ of ~ pages #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH C n TE C'S c K .~; . z, o ... •a" " # -ss Rw ~ s~ .G ~s~S l~ L f~T CaGGo2 ~ G4 G • Q GiJ ~L ~A•~" Sfia ~' • 70 " s . 3 0 ,Q W LO % ~ D .~ .30~~ 40 e ~ 1<i/~Vi ~E, p ~i6E" .~ - S~ ~ 36 ~` C' si n n 7a YiP~L 6!'• 4 .IPS• 4~ .s` // •-dd~ !~/~< r ~ ~ O / " ~ ~ 7- tf .~ / : ,t/r;~ . •Gi XE' $i 77~ 3 G~'i .vasr i ,v ' ~ ~'~i•A-? 'g E'N .G G ~' ~ T T - w f .P S. ~ W y' < d L ~~ ~~' S . A 1~' < ZE,~S - ~ L-'S~', e N v .~'. ,P C ~ -.f!d ~-- CS ~ ~.C 7 ~' ~- s ~. /0 rr-n - S~ crC C ~Q6'SS• 7' TE' G ..Gi S ~' ..~Sez ~sT- ~v c L5• Z h~E .r~ i GENT: ~ ~"L S ~ cry ~' eN Lam' u,8 ~ "Z ors'. C . eta .~ ~ sv s, ~- - • z Pf' .~ ,0~=,0 TP rvi L ~' ewes' Sir •~ e~'~,3e~ T r< tt r w< Pl,~~ w a tzc. ~ ~ s s < f~iv ~ s< ~ ~ P~~~ D ~ fiv % ..1e9 !i'• n s^ ~ . ~- _ /Jrn I9 l rl /1 /l ~~w ~ L`~: .sw wL- ~L/~ii T~ ~% CLC'i'Ail~ ~wiw~y ~ !d S ~"/YE.s~?sF~ "~~ ~' ~! //4 ~iE'S ~UOltJE'LG ~i ~GTf~ •~T...'~ Brett Packer Page 17 of 21 07/13/2010 ___ ~ ARCO PM 118 OUAUTY LITHO PRINTING -ANCHORAGE R. o~ r~ :. y Y/° 7 u il~'1~~L~ ~QE ~~f1 ~~~L To: AOGCC Christine e+a-. ~k~rt,~o/ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 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 Internationat Airport Road Suite C ,;+~'°~~~,w ,[,i ~!~ '`.`.` , ~t~ Anchorage, AK 99518 Fax: (907) 245-8952 Print Name: • .C ~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : Cdsancl~®ragela?memorvl®g.cgm WEBSITE : www.memorylog.c~sm C:\Documents and Settings\Diazie WilliamslDesktop\Transmit_Coneco.docs • Memory Multi-Finger Caliper Log Results. Summary ;. Company: ConocoPhillips Alaska, Inc. Well: 2A-14 Log Date: July 19, 2010 Field: Kuparuk Log No.: 10653 State: Alaska Run No.: 1 API No.: 50-103-20040-00 Pipet Desc.: 7" 26 Ib. J-55 Top Log lntvl1.: Surface Pipet Use: Production Casing Bot. Log Intvl1.: 6,82p Ft. (MD) Inspection Type : Buckling & Restriction Inspection COMMENTS This caliper data is tied into the drill floor @ 0'. This log was run to assess the condition of the 7" production casing with respect to buckling and minimum I.D. restrictions. The caliper recordings indicate buckling from -30' to _1,550', 3,450' to --3,520', and -3,595' to _3,620'. 3-D log plots of the centered and off-center caliper recordings highlighting the buckling are included in this report. No significant LD. restrictions are recorded throughout the production casing logged. The caliper recordings indicate the 7" production casing logged appears to be in good to poor condition with respect to corrosive and mechanical damage, with wall penetrations ranging from 20% to 73% wall thickness recorded in 39 of the 166 joints logged. Recorded damage appears as isolated pitting. No significant areas of cross-sectional wall loss are recorded throughout the production casing fogged. MAXIMUM RECORDED WALL PENETRATIONS: Isolated pitting (73%) Jt. 75 @ 2,974 Ft. (MD) Isolated pitting (62%) Jt. 74 @ 2,944 Ft. (MD) Isolated pitting (51%) Jt. 115 @ 4,659 Ft. (MD) Isolated pitting (49%) Jt. 76 @ 3,020 Ft. (MD) Isolated pitting (46%) Jt. 79 @ 3,127 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the production casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the production casing logged Field Engineer: G. Etherton Analyst: C. Waldrop Witness: R. Do/cater & D. Rowell ProAetlve Diagnostic Services, Inc / P.O. Box 1369, Stafford, Tx 77493 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-maii. PDSi~memoryiog.com Prudhoe Bay Fieid Office Phone: (90?;i 659-23Q7 Fax: (907j 659-2314 ~~~ ~~t5' ti~~~ PDS Mu(tifinger Caliper 3D Log Plot L.. _ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-14 Date : July 19, 2010 Description : Detail of Centered Caliper Recordings Across Buckling Recorded in 7" Casing. Comments Depth Max. I.D. (ins.) 3-D Log (Centered) Image Map (Centered) 1ft:1200k 6 7 72° 0° 90° 180° 270° 0° Min. I.D. (ins.) ~ 6 7 Nominal I.D. (ins.) 6 7 Landing Joint ~ - -- ' ~ - Casing Hanger >... ~ ~ Joint 1 - 50 ~ Buckling ~~~ -.~_ Joint 2 ~ ~, Buckling ' ,~ ~ ~~ : ~ 100 . , ~. ~~ _ Joirrt 3 Buckling ~ ~_ Joirrt4 150 Buckling °,: .r _, . Joint 5 20Q Buckling ~ - Joint 6 Buckling 250 .~.. Joint 7 ~~! Buckling + '" 300 _ a: .: : Joi~rt 8 -• ,; 1 Buckling t:~ _~_ 350 ~ ~ Joint 9 ~ Buckling .; ,~ e ~ Joint 10 400 Buckling - 1j_ _~. Joint l1 ~` Buckling 450 _ - ,_ ____- __ Joint 12 Buckling 500 Joint 13 Buckling `f > _- Joint 14 550 ~ Buckling _--,. _~ ~ _ - --- Joint 15 ~ ~ 600 ~ Buckling y "°'" _ Joint 16 _ Buckling '~ 650 ~~ Joint 17 Buckling - _ i- i __ ~ ~ - ~" 700 ~ - -- Joint 18 ~- ~ Buckling -~~ - - Jnf nt ?a /.~® • i~ r~ i~ • • • PDS Multifinger Caliper 3D Log Plot ~~ . _~~, Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-14 Date : July 19, 2010 Description : Detail of Off-Center Caliper Recordings Across Buckling Recorded in 7" Casing. • • • • Joint 70 2800 Joint 71 2850 Joint 72 Joint 73 2900 Joint 74 2950 Joirn 7s 3000 Joint 76 Joint 77 3050 Joint 78 3100 Joint 79 3150 Joint 80 3200 Joint 81 Joint s2 3250 Joint 83 3300 Joint 84 3350 Joint 85 3400 Joint 86 3450 Joint 87 Buckling Joint 88 3500 Buckling Joint ss 3550 Joint so 3600 Buckling n~~ _ °. ~:._ .._ . _ i_ ' Nominal I.D. (ins.) :.....................................................................: 6 7 Min. I.D. (ins.) 6 7 Comments Depth Max. I.D. (ins.) 3-D Log (Off-Center) Image Map (Off-Center) i i .. _ _ ____.__ ~zr~______ , _ ?ft:1200ft 6 7 0° 0° 90° 180° 270° 0° • Correlation of Recorded Daman Pipe 1 7. in (0.0' - 6777.4') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 2 A-14 Kuparuk ConocoPhillips Alaska, Inc. USA July 19, 2010 . A pprox. Tool De viation ^ A pprox. Borehol e Profil e ~0 20 779 I 40 ~ 1561 GU ,~ 2361 D . ~,~ ~ v -_ E gr) "~ ~ 3154 `~ ~ E z - .~ c . __ _: Q. ~, o 100 4010 120 4871 i I 140 ~ ~~ 5723 160 6565 1b5 677i 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 165 • PDS Report Overview ~---~~~._ ~,. Body Region Analysis Well: 2A-14 Survey Date: July 19, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C. Waldro Tubing: Nom.OD Weight Grade &Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f -55 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 100 80 60 40 20 0 0 to 1 to 10 to 20 to 40 to over 1 % 10°'0 20% 40% 85% 85% Number of'oints anal sed total = 166 gene. 2 53 76 28 7 0 loss 93 73 0 0 0 0 Damage Configuration (body ) 150 100 5 ii 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of "oints dama ed total = 131 131 0 0 0 0 Damage Profile (%wall) ~ penetration body metal loss body 0 50 100 1 50 ~ ~ ~ I I 100 j 150 Bottom of Survey = 165 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf J-55 Well: 2A-14 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 6.276 in Country: USA Survey Date: July 19, 2010 Joint No. Jt. Depth (Ft.) Pen. UI~SC1 Qns.) Pen. Body (Ins.) Pere. % Mc~r~l loss °~~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 0 O.Ur, 0.03 8 1 6.19 7" Landis oint .2 17 t! 0 U 0 N A 7" Casin Han er 1 30 1~ Q02 7 I 6.21 Bucklin . 2 67 t) 0.03 t3 1 6.21 3 106 (~ 0.03 ~) 1 6.20 Shallow ittin .Bucklin . 4 145 U 0 i) U 6.19 5 184 n 0.01 ~' I 6.21 r 6 227 (7 0.02 7 1 6.19 Bucklin . 7 267 t! 0,02 I 6.21 8 303 t) 0.00 1 U 6.19 9 346 (! 0.01 2 tl 6.22 Bucklin . 10 385 (1 0.02 6 1 6.22 11 425 (~ 0.01 ? tl 6.22 12 464 ~) 0.01 _' (1 6.22 Bucklin . 13 503 t; 0.01 ? I 6.22 14 542 U 0.05 13 i 6.23 Shallow ittin . 15 582 t! 0.03 ~ I 6.21 Bucklin . 16 622 (! 0.04 1 ~ U 6.22 Shallow ittin . 17 661 0.03 ~i (> 6.22 18 700 U 0.02 1 6.20 Bucklin . 19 743 t! 0.01 Z U 6.22 20 779 t! 0.01 ? t) 6.21 `' 21 819 n 0.02 - I 6.21 22 857 a 0.03 7 (! 6.22 Bucklin . 23 897 ~! 0.02 Fi I 6.21 24 936 I~ 0.03 ~) !? 6.22 Shallow ittin . 25 975 i! 0.01 a 6.23 26 1016 ~) 0.02 t~ ~ ~ 6.23 27 1055 ii 0.03 7 6.23 Bucklin . 28 1095 t! 0.03 ~~ ~ 6.24 Shallow ittin . 29 1134 t! 0.04 1t) I 6.22 Shallow ittin . 30 1172 (! 0.03 ~~ U 6.23 Shallow ittin Bucklin . 31 1212 t! 0.01 3 n 6.20 32 1255 (i 0.03 7 t) 6.22 33 1294 !! 0.03 8 I 6.22 Bucklin . 34 1336 i) 0.01 ? (! 6.23 35 1375 U 0.03 ~i i 6.23 Shallow ~ittin . 36 1413 t! 0.06 1 ti 1 6.22 Shallow ittin Bucklin . 37 1447 i! 0.06 1 S 1 6.22 Shallow ittin . 38 1483 t i 0.03 t3 I 6.21 39 1523 !) 0.04 1? i 6.22 Shallow ittin .Bucklin . 40 1561 t! 0.03 8 ? 6.22 41 1600 (! 0.02 6 ~ ~ 6.20 42 1640 i? 0.07 1t3 I 6.23 Shallow ittin . 43 1679 ~:! 0.03 ~) I 6.23 Shallow ittin . 44 1723 ~! 0.05 I4 I 6.23 Shallow ittin . 45 1762 t! 0.03 ii t 6.19 46 1806 i? 0.02 6.23 47 1845 0.04 1 U 1 6.23 Shallow ittin . 48 1886 0.05 13 1 6.20 Shallow ittin . _ Penetration Body Metal Loss Body Page 'I ~ i PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf J-55 Well: 2A-14 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: July 19, 2010 Joint No. Jt. Depth (Ft) {'c~n. Ulxc~l ,In;.) Pen. Body (Ins.) Pen. % Mct,rl Ions °%, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1926 ~! 0.05 14 1 6.23 Shallow ittin . 50 1966 a 0.05 14 1 6.22 Shallow ittin . 51 2005 t~i 0.02 (~ I 6.24 52 2044 ! ~ 0.05 15 1 6.23 Shallow ittin . 53 2083 (? 0,06 15 _' 6.24 Shallow ittin . 54 2123 (t 0.05 15 1 6.23 Shallow ittin . 55 2164 (t 0.07 2U I 6.24 Isolated ittin . 56 2205 tt 0.03 ~) t? 6.23 Shallow ittin . 57 2245 i) 0.08 l2 I 6.24 Isolated ittin . 58 2285 t) 0.08 ~2 I 6.23 Isolated ittin . 59 2323 ~t 0.04 I~' i 6.24 Shallow ittin . 60 2361 U 0.04 IO U 6.22 Shallow ittin . 61 2404 U 0.04 12 1 6.22 Shallow .ittin . 62 2441 O 0.09 ~5 ~ 6.24 Isolated ittin . 63 2481 (~ 0.08 21 1 6.22 Isolated ittin 64 2521 U 0.07 2(1 1 6.22 Isolated ittin . 65 2561 U 0.07 1 ~) I 6.24 Shallow ittin . 66 2600 U 0.14 i9 3 6.24 Isolated ittin . 67 2639 !' 0.09 25 1 6.23 Isolated ittin . 68 2680 ti 0.14 39 6.23 Isolated ittin . 69 2716 it 0.13 i5 ? 6.23 Isolated ittin - 70 2758 (t 0.09 ~'"I .! 6.22 Isolated ittin 71 2798 O 0.10 Zf3 ? 6.21 Isolated ittin 72 2842 t? 0.16 45 i 6.24 Isolated ittin . 73 2881 ii.l ; 0.14 >F1 _' 6.23 Isolated ittin - 74 2920 U 0.23 62 6.24 Isolated ittin - ~ 75 2960 t t 0.26 7 , 1 6.23 Isolated ittin 76 2999 i) 0.18 4~) 6.23 Isolated .ittin . 77 3039 ~ ~ 0.06 16 6.20 Shallow ittin 78 3079 ! ` 0.04 12 1 6.23 Shallow ittin . 79 3116 r? 0.17 4V 6.21 Isolated ittin . 80 3154 0.07 2U 1 6.20 Isolated ittin . 81 3194 ! ~ 0.04 I 1 1 6.18 Shallow ittin . 82 3238 ti 0.09 25 1 6.22 Isolated ittin , 83 3275 (t 0.08 21 I 6.20 Isolated ittin . 84 3318 it 0.08 22 I 6.18 Isolated ittin . 85 3361 (t 0.03 t3 i) 6.21 86 3404 U 0.16 44 6.23 Isolated ittin . 87 3448 O 0.11 31 I 6.22 Isolated ittin Bucklin 88 3491 r? 0.12 34 ~' 6.19 Isolated ittin Bucklin - 89 3534 (t 0.08 2"~ ,' 6.21 Isolated ittin . 90 3578 U 0.13 36 ~ 6.21 Isolated ittin .Bucklin - 91 3621 U 0.10 2t9 I 6.21 Isolated ittin . 92 3664 t' Q06 1 ti I 6.22 Shallow ittin . 93 3707 (t 0.12 34 1 6.22 Isolated ittin . 94 3750 i' 0.06 1' I 6.22 Shallow ittin . 95 3793 !t 0.04 It) it 6.22 Shallow ittin . 96 3836 tt 0.08 _'1 ! 6.23 Isolated ittin . 97 3879 0.09 24 6.24 Isolated ittin . 98 3923 0.06 17 I 6.21 Shallow ittin . _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf I-55 Well: 2A-14 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Cornpany: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: July 19, 2010 Joint No. Jl. Depth (Ft.) Pen. Up~cl (Irn.) Pen. Body (Ins.) Pen. %, Metal I oss °,_ Min. LD• (Ins.) Comments Damage Prolile (% wall) 0 50 1O(? 99 3966 i) 0.04 10 6.21 Shallow iuin . 100 4010 ti 0.06 18 I 6.23 Shallow ittin . 101 4053 (i O.Oh 18 ? 6.24 Shallow _ittin . 102 4092 (~ 0.06 16 I 6.21 Shallow ittin . 103 4135 ii 0.06 I' i 6.26 Shallow ittin . 104 4179 U 0.06 15 1 6.22 Shallow ittin . 105 4222 t) 0.04 I1 ~~ 6.22 Shallow ittin . 1U6 4265 I? 0.03 ~) I 6.22 Shallow ittin . 1U7 4309 ii Q05 14 I 6.21 Shallow ittin . 108 4352 ii 0.04 10 I 6.20 Shallow ittin . 109 4395 U 0.04 12 ~' 6.20 Shallow ~ittin . 110 4439 U 0.05 14 1 6.21 Shallow ittin . 111 4482 (1 0.04 1U Z 6.20 Shallow ittin . 112 4525 (i 0.06 I6 2 6.22 Shallow ittin 1 13 4569 (? 0.05 i "~ 6.22 Isolated ~ittin . 114 4612 t) 0.04 11 i 6.23 Shallow ittin . 115 4655 O 0.18 51 6.19 Isolated ittin Lt. De osits. 116 4699 ti 0.04 11 I 6.20 Shallow ittin . 117 4742 t) 0.08 1:3 1 6.21 Isolated ittin . 118 4785 U 0.05 13 ~' 6.22 Shallow ittin . 119 4827 !I 0.05 14 I 6.19 Shallow ittin . 120 4871 ;i 0.11 3U ? 6.19 Isolated ittin . 121 4914 U 0.06 17 ? 6.20 Shallow ittin . 122 4958 ~1 0.04 10 ? 6.20 Shallow ittin . 123 5UU1 n U.U6 15 1 6.22 Shallow ittin . 124 5044 i? 0.04 12 I 6.21 Shallow ittin . 125 5088 i? 0.05 14 4 6.25 Shallow ittin . 126 5123 !~ Q05 14 6.19 Shallow ittin . 127 5166 ~ r 0.06 I (, _' 6.23 Shallow ittin . 128 5209 !'~ U.O6 1 i > 6.21 Shallow ittin . 129 5253 i) 0.05 1 9 6.20 Shallow ittin . 130 5296 U 0.04 1 U 6.20 Shallow ittin . 131 5339 U O.U4 1t) _' 6.21 Shallow ittin 132 5381 (i 0.05 15 1 6.21 Shallow ittin . 133 5424 ii 0.04 I I ~' 6.22 Shallow ittin . 134 5467 i= 0.06 17 6.20 Shallow ittin . 135 5510 U Q05 13 Z 6.24 Shallow ittin . 136 5553 t) 0.05 13 _' 6.22 Shallow ittin . 137 5597 :I 0.04 12 6.21 Shallow ittin . 138 5640 !) 0.14 38 6.23 Isolated ittin . 139 5680 ! I 0.04 1 ~ 6.23 Shallow ittin . 140 5723 t; 0.03 {) 6.22 Shallow ittin . 141 5766 1) 0.06 1 i 6.21 Shallow ittin . 142 5806 i1 0.04 i l) 6.21 Shallow ittin . 143 5848 l? 0.06 1 ~ 6.20 Shallow ittin . 144 5887 (i 0.04 I ~' 6.19 Shallow ittin . 145 5929 ~! 0.05 i 3 _' 6.20 Shallow ittin . 146 5972 0.05 13 6,23 Shallow ittin . 147 6015 ! ~ 0.06 I' ~ 6.23 Shallow ittin . 148 6052 ~! 0.04 11 6.20 Shallow ittin . _ Penetration Body Mctal Loss Body Page 3 ~ i PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf J-55 Well: 2A-14 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: July 19, 2010 Joint No. Jt. Depth (Ft) I'~~n. t 11~sc~r (lns.j Pen. Body (Ins.) I'rn. % M~~t.~l Loss ",~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 149 6095 U 0.07 1 ~? 6.21 Shallow ittin . 150 6139 ~ ~ 0.05 l ~' 6.21 Shallow ittin . 151 h182 tr 0.06 1(~ ~ 6.20 Shallow _ittin . 152 6225 ~ ~ 0.05 1 ~ 6.20 Shallow ittin . 153 6269 0.07 1 ~~ 6.21 Shallow ittin . 154 6312 U 0.04 1 ~' 6.24 Shallow ittin . 155 6355 ! ~ 0.05 1 a ~ 6.23 Shallow ittin . 156 6394 U 0.08 21 -1 6.22 Isolated ~ittin . 157 6438 i~ 0.06 18 -l 6.19 Shallow ittin . 158 6481 i1 0.05 13 -1 6.24 Shallow ittin . 159 6522 ~'~ 0.07 20 4~ 6.22 Isolated ~ittin . 160 6565 ~ ~ 0.07 19 ~ 6.23 Shallow ittin . 161 6608 t1 0.05 14 ~ 6.20 Shallow ittin . 162 6652 ti 0.10 Zti ~ 6.21 Isolated ittin . 163 6695 U 0.04 I 1 t 6.24 Shallow ittin . 164 6738 ~~ 0.06 15 ~~ 6.25 Shallow ittin . 165 6777 (! 0.10 28 1 6.24 Isolated ittin . _ Penetration Body Metal Loss Body Page 4 • PDS Report Cross Sections ~.~ S ., Well: 2A-14 Survey Date: July 19, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 7 ins 26 ppf )-55 Analyst: C. Waldrop Cross Section for Joint 75 at depth 2974.23 ft Tool speed = 43 Norninal ID = 6.276 Norninal OD = 7.000 Remaining wall area = 96 °i° Tool deviation = 44 " Finger 39 Penetration = 0.264 ins Isolated pitting 0.26 ins = 73% Wall Penetration HIGH SIDE = UP Cross Sections page 1 __ PDS Report Cross Sections _~ ~ ~, Well: 2A-14 Survey Date: July 19, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f )-55 Anal st: C. VValdro Cross Section for Joint 74 at depth 2943.65 ft Tool speed = 43 Nominal ID = 6.2 76 Nominal OD = 7.000 Remaining wall area = 97 Tool deviation = 41 " Finger 39 Penetration = 0.225 ins Isolated pitting 0.23 ins = 62% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ,~--`~ S KUP ~ 2A-14 ConocoPl'lillips ~ Well Attributes le & MD TD "' "~ Wellbore P P W WI Field Name Well Status Inc! MD (ftK8) Att Bbn (ft KB) 501032004000 KUPARUK RIVER UNIT PROD 49.73 4,419.91 7,863.0 Comment H2S (ppm) Date Annotation End Dare KB~rd (ft) Rig Release Dare ~~~ ~2A14 CY171201i1d s1 ;F I'M Wet CwRi ' SSSV: LOCKED OUT 150 1!10!2009 last WO: 37.29 7/30/1985 . Stiiematb ~ Aduul Armofation DepBr (RKB) End Dala Annotation Last Mod By End Dare Last Tag: SLM 7.515.0 8127!2009 Rev Reason: GLV C/O, PULL CATCHER Imosbor 6/12/2010 Casin Stria s String O D String ID Set Depth Sat Depth (ND) String Wt String Casing D escription (in) (in) Top (71KB) (ftKB) (ftKB) Qbs/ft) Grade Striny Top ThM CONDUC TOR 1 6 15.060 37.3 103.D 103.0 62.50 H-40 cordDUCroR, 103 SURFACE 95 !8 8.765 0.0 3,051.0 2,888.1 36.00 J-55 PRODUCTION 7 6.151 0.0 7.227.0 5,779.0 26.00 J-55 saFErv vLV. 1 818 9D LINER 5 4.300 7,006.0 7.860.0 6.285.1 15.00 K-55 , Tubin Stria s Stang D D Strang ID S¢t Depth Set DepN (TVD) String Wt Stnnq Tubin Description (inl lira) Top (ftKB) (ftK8) (flKB) (IbsHt) Grad e String To p Thrd GAS LIFT, TUBING 2 7 B 2 441 0 0 991 6 0 5 608.2 6.50 J ~5 SRD EUE 1,886 . . . . . TUBING 2 3/ 8 1.995 6,991.0 7,452.0 5.953.8 4.70 N-80 8RD EUE suRFACe, Qther I n Hole A ll Jewe l :Tubin Run & Retrievable Fish etc. 3,051 Top DepM (TVD) Top Intl Top (ftK8) (~B) (") Doscription Comment Run Date ID (in) GAS LIFT, 1 848 1 845 1 11 70 S AFETY VLV Camco TRDP-IA-SSA' (Locked Out on 778796) 10/5!1985 2.313 3as3 , , . . 1.886 1.882.2 12.83 G AS UFT CAMCO/KBMG/1/DMY/BK///Comment: STA 1 5/22/2009 2-347 3,393 3,127.0 4542 G AS LIFT CAMCOlKBMG/1/DMYlBTM!/l Commem: STA2 5!2212009 2.347 Gras uFr, 4,57.3 4.623 3,968.0 48.16 G AS LIFT CAMCOlKBMG/1/DMY/BK///Comment: STA3 5/23!2009 2.347 5,329 4,450.1 46.58 G AS LIFT CAMCO/K6MG/1/DMY/BK!//Comment: STA4 11/19/1998 2.347 5,822 4,792.1 44.84 G AS LIFT CAMCO/KBMC~J1/DMY/BK/!! Comment: STA 5 10125:1997 2.347 cns uFr, 6 320 5 141 0 46 67 G AS LIFT CAMCO!KBMG/1/OPENiU!Comment: STA6 6f1ll2010 2.347 5,329 . , . . 6,817 5,486.6 46.60 G AS LIFT MERLAITGPD/1.5/DMY/RK//!Comment: STA 7 10;2671997 2.375 6,864 5,519.3 46.03 S BR Camco'OEJ' 10l5l19S5 2.406 cns uFr, 6,881 5,531.2 45.72 P ACKER Camco'HRP-I-SP' 10/5/1985 2.344 sazz 6,905 5,548.0 45.93 P LUG 2.25" WEATHERFORD WRP 6!7/2010 0.000 6,919 5,557.7 45.80 P RODUCTION CAMCOlKBMGl1/DMY/BK/!/Comment: CLOSED STA8 1/8/1998 2.347 GAS LIFT, 6,957 5,584.4 45.43 N IPPLE AVA BPL PORTED NIPPLE 10!5!1985 2.250 s,3zo 7,431 5.937.0 36.63 P ACKER Baker 'DB' 1015/1985 3.250 7,445 5,948.2 36.58 N IPPLE Camco'D' Nipple NO GO 10/5/1985 1.813 GAS LIFT, 7,451 5,953.0 36.56 S OS OILS 10/5/1985 1.995 e,et ~ 7.452 5.953.8 36.55 T TL ELMD ~u) 7451' ON SWS GLS 9! 17/1997 10!5!1985 1.995 7.535 6.020.6 36.25 F ISH CRX PLUG 33" CRX PLUG n RATHOLE (NO GD ID=1.856") 1/8/1998 sBR sand Perfora tions & Slots . sna Top (TVD) Bfm (TVD) Dens Ta ftKB) Bbn flIKB) (ftKB) (ftKB) Zone Date (~-- T Co mnaM 7.348 7,414 5,871.0 5,923.4 C -0, UNIT B, 10!5!1985 6.0 IPERF 60 deg. phasing: SOS Csg Gun PACKER, 6,681 2 A-14 7.SD4 7,542 5,995.6 6,026.3 A -3, 2A-14 10!511985 6.0 IPERF 60 deg. phasing; SOS Csg Gun Notes: General 8 Sa End Dare Annotation PLUG, s9o5 519/2006 NOTE: WAIVERED WELL IA x OA x OOA- PROD CSG x FORMATION COMMUNICATION 6171/2010 NOTE: ATTEMPTED TO PULL GLV Qa 681 T, FAILED DUE TO CORKSCREWEDTBG PilODUCTION, 6919 NIPPLE, 695] PRODUCTION. 1,221 IPERF, 7,398-],114 3 1 PACKER, 1,431 NIPPLE, 1,445 SOS, 1,451 ~ Tit., 1.452 IPERF, ],5047,542 FISH, 1,535 LINER. 1.%0 m, 1a63 Brett Packer Page 13 of 21 07/13/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey /Plug Setting Record: 2A-14 Run Date: 6/7/2010 June 25, 2010 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 2A-14 Digital Data in LAS format, Digital Log Image file 50-103-20040-00 ~ f'; <;~ ,~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barret ~°~" • ~~ ~ ~ ~n Date: -`~~ _y i~ °~s3~ Signed: • ~~ • • J. Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. ~,'~:~ a~~;a ~ l~ ~`~~~ ~ " ~~ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-14 Sundry Number: 310-175 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, 2010. Encl. ' ~ ~ ~~~ STATE OF ALASKA `'~~ { ~'~ALAS~IL AND GAS CONSERVATION COMMISSI~ ~,~ 19 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 R~~~IVED 4111N 0 g 2010 1. Type of Request: Abandon ~"" Plug for Redrill ~"""; Perforate New Pool ~°`` Repair well ~ 8S Suspend ~"" Rug Perforations ~"" Perforate Pull Tubing ~°, ~ At~C~ension Operational Shutdow n Re-enter Susp. Well ~'°" Stimulate Alter casin ~ " ~~ g Other: > 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~, Exploratory 185-145 3. Address: Stratigraphic ]"`~ Service " 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20040-00 " 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes [~ No 2A-14 - 9. Property Designation: 10. Field/Pool(s): ADL 25570 Kuparuk River Field /Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7863 6288 ' 7785' 6223' 7535' Casing Length Size MD ND Burst Collapse CONDUCTOR 103 16 103' 103' SURFACE 3051 9.625 3051' 2888' PRODUCTION 7227 7 7227' 5779' LINER 854 5 7860' 6285' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7348'-7414', 7504'-7542' 5871'-5923', 5996'-6026' 2.875 x 2.375 J-55 / N-80 6991' / 7452' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - CAMCO 'HRP-1-SP' MD= 6881 ND= 5531 PACKER -BAKER 'DB' MD= 7431 ND= 5937 CAMCO'TRDP-1A-SSA' MD= 1848 ND= 1845 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch E~loratory ~"`' Development ': Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/22/2010 Oil Gas ~" WDSPL ~ Suspended li 16. Verbal Approval: Date: WINJ '" GINJ WAG Abandoned Commission Representative: GSTOR ~~ SPLUG j"` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name J. ett Packer Title: Wells Engineer ~' ~~ ~~~ D t ~ ~~/lam Phone: 265-6845 Signature a e C mmi sin nl Sundry Number: ~j' O ~ ~~ 5 Conditions of approval: Notify Commission so that a representative may witness // Plug Integrity " BOP Test Mechanical Integrity Test Location Clearance ~,-- Other:~ ~ ~~~~ ~S4 ~ ~ ~c?.°.~ / ~7 Subsequent Form Required: tl ~> ,. ~ ~ c_ fi APPROVED BY ~ ~ //O Approved by: COMMISSIONER THE COMMISSION / Date: ` ~l Icy Form 10-403 N ~ 6 ~ R ~ ~ ~ ~ A L ~-t~. Submit in Duplic • • 2A-14 Expense Rig Workover (PTD #: 185-145) Current Status The well is currently shut in awaiting a workover to replace the corkscrewed and leaky tubing and proactively repair the 7" production casing. This well is located in an area with surface subsidence due to permafrost thawing. The gyro data obtained in June 2009 indicated extremely corkscrewed and buckled tubing down to 1,600' MD throughout the vertical portion of the well. Due to the corkscrewed tubing, we have been unable to drift the tubing for a patch. The well also suffers from a shallow surface casing leak at 210' MD that was discovered in Nov. 2005, which will be cement squeezed during this workover. Scope of Work Replace the tubing, proactively cut & pull a portion of the 7" casing, re-run new 7" casing, circulate cement into the 9 5/8" x 7" annulus, and install a stack packer with new 2 '/8" L-80 tubing. General Well info MASP: 2,326 psi Reservoir pressure/TVD: 2,921 psi / 5,949' TVD (6/7/10) Wellhead type/pressure rating: FMC KRU Gen 3, 11" 3K btm x 7-1/16" SK top flange BOP configuration: Annular /Pipe Rams /Blind Rams /Mud Cross /Pipe Rams OMIT / MITOA results: CMIT TxIA-passed on 6/4/09, MITOA-failed on 11/7/05 (SC leak at 210' MD) Well Type: Producer Estimated Start Date: June 21, 2010 Production Engineer: Mike Balog /Evan Reilly Workover Engineer: Brett Packer (265-6845 / j.brett.packer@conocophillips.com) Pre-Rig Work 1. RU Slickline: Set catcher sub on top of WRP. Pull DV in GLM @ 6,817' MD 2. CMIT to 2500 psi. Perform drawdown or NFT. 3. Set BPV. Proposed Procedure l . MIRU Nordic 3. 2. Pull BPV. Circulate 9.6 ppg brine through open mandrel at 6,817' RKB. Verify well is dead. Set BPV. ND tree. Install FMC blanking plug in lift threads. NU 11" SM BOP and adapter spool. Pressure test BOP including annular to 250/3500 psi. Maximum potential surface pressure is calculated to be 2,321 psi based upon the SBHP obtained on 8/27/09 and using a 0.1 psi/ft gas gradient. 3. Pull blanking plug and BPV. Circulate hole clean. Attempt to pull tubing. A. If OEJ does not pull free, set tubing in tension, RU E-line and cut tubing at 6,842' RKB. POOH laying. down tubing 4. Run 7" scraper on drillpipe to top of tubing stub. 5. RU E-Line: Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. Based on cement top, determine depth of 7" collar to back off following .casing cut. RIH and fire string shot across that collar. RD E-Line. 6. Set RBP or IBP below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi. • Proposed Procedure Continued 7. RIH w/ muleshoe on drillpipe and spot 50' of sand on top of RBP/IBP. 8. Lay down one stand, install storm packer and hang off in 7" casing below surface (to reduce casing compression at the wellhead). 9. ND BOP, install long all-thread bolts on wellhead. Begin ND tubing head allowing 7" casing to grow. 10. Remove packoffs and RU Wachs cutter to cut tubing stump. 11. Spear 7" csg and pull in tension and. re-land in slips. Tack weld slips to casing: 12. NU 11" SM BOP on casing head. Change out lower rams to 7". Pressure test BOP to 3000 psi. 13. Retrieve storm packer. 14. RIH w/ multi-string cutter and cut 7" casing above TOC. 15. Circulate out Arctic Pack in the 9 5/8" x 7" annulus using hot diesel followed by hot seawater. 16. Spear and POOH laying down 7" casing. 17. Run 9-5/8" casing scraper to top of 7" stub. Circulate clean: 18. RU E-Line: Run memory GR, caliper, and gyro in 9-5/8" casing. RD E-Line. t 19. Run back off tool and back off casing stub. 20. Run tandem string mills to gauge the 9 5/8" csg for the ES cementer. 21. Make a dummy drift run for the 7" casing & ES cementer. 22. Spear and recover backed off 7" casing stub. 23. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. PT casing to 3000 psi. 24. Open ES cementer and pump cement into 9-5/8" x 7" annulus. Close the IA once cemensreturns at surface and squeeze cement into SC leak. Close cementer. WOC. ~' 7 ~ x ~ ~ 4~;N.,~~~-5 c? z~«.' 25. ND BOP, pu117" casing in tension and land in slips. Cut excess 7" casing and install packoff. NU new tubing . head. 26. NU 11" SM BOP, change out lower pipe rams to VBR's. PT rams and BOP stack to 3000 psi. ', 27. Drill out cement and ES cementer down to top of sand. Pressure test casing to 2500 psi. 28. RIH w/ RCJB and string magnets to clean up wellbore. 29. RIH with wash shoe and circulate out sand from top of RBP/IBP. POOH: 30. RIH w/ retrieving tool on work string. Release RBP/IBP and POOH. 31. RIH with po-boy overshot, stack packer, and PBR on 3 '/2" drill pipe. Go over tubing stub. Circ well full of corrosion inhibited fluid. Set packer. POOH laying down drill pipe. 32. RIH with new 2 '/g" tubing and seal assembly. Stab into PBR, space out and land. Pressure test tubing and IA to 3000 psi. Shear SOV. 33. Set 2-way check. ND BOP. NU tree and pressure test. 34. Pu112-way check. Freeze protect well. Set BPV. 35. RDMO Nordic 3. Post Rig Work 1. RU Slickline: Pull ball and rod, pull SOV and run new gas lift design, pull RHC body, pull catcher sub and WRP: 2. Return well to production. ,r M..~ _ a_ , ~---_.,, ~ KUP ~ 2A-14 cJPt' "~It~IIQG~PhI(fi~~~}5 ] ell Attributes ax An le & MD TD ~ ' Wellbore APIIUWI Field Name Well Status Incl (°) MD (RKB) Act Btm (R KB) ~ "~~r` " ' '' ~ 501032004000 KUPARUK RIVER UNIT PRODUCING 49.73 4,419.91 7,863.0 ' Comment H23 (ppm) Date Annotation End Date KB~rtl (R) Rig Release Date SSSV: LOCKED OUT 150 1/10/2009 Last WO: - 3729 7/30/1 985 Well COr./i - - 2A-14 9/6/2009 8'.1225 AM magic -Actual Annotation Depth (RKB) End Date Annotation Last Motl By End Dale Last Tay: SLM 7.515.0 8/27/2009 Rev Reason: TAG Imosbor 9/6/2009 Casin Strin s ' String O D String ID Set Depth Set Depth (ND) String Wt Strin g ~__._y.~ ~ 2 Casing Description CONDUCTOR (in) 1 (in) 6 15.060 Top (RKB) 37.3 (RKB) 103.0 (RKB) 103.0 (Ibs//t) 62.50 Grade H~0 String Top Thrd coNOUCroR, SURFACE 951 8 8.765 0.0 3,051.0 2,888.1 36.00 J-55 103 PRODUCTION 7 6.151 0.0 7,227.0 5,779.0 26.00 J-55 SAFETY VLV, --~ .may LINER 5 4.300 7,006.0 7,860.0 6,285.1 15.00 K-55 1'a~ Tubin Strin s ' String O D String ID Set Depth Set Depth (ND) Strang Wt Strin g Tubin Descri lion ling ling Top (RKB) (RKB) (ftK8) (IbslR) Grade String Top Thrd TUBING 27/ 8 2.441 0.0 991.0 6 - 5,6082 6.50 J-55 SRD EUE cns uFT. , 1.eae TUBING 23/ 8 1.995 6,991.0 7,452.0 5,953.8 4.70 N-80 SRD EUE Other In Hole All Jewel :Tubin Run & Retrievable Fish etc. _ SURFACE, ~ TOp Depth 3,051 (ND) Top Incl Top (ftK8) (ftK8) (°) Description Comment Run Date ID (in) GAS LIFT - 1,848 1,545.1 11.70 S AFETY VLV Camcn'TRDP-1ASSA' (Locked Out on 718/96) 10/5/1985 2.313 , 3,393 _ 1,886 1,8822 12.83 G AS LIFT CAMCO/KBMG/1/DMYBK///Comment: STA 1 5/22/2009 2.347 3,393 3,127.0 45.42 G AS LIFT CAMCO/KBMG/1/DMY/BTM///Comment: STA2 5/22/2009 2.347 _ 4,623 3,968.0 48.16 G AS LIFT CAMCO/KBMG/1/DMYBW//Comment: STA 3 5/23/2009 2.347 GAS uFr' 4,623 5,329 4,450.1 46.58 G AS LIFT CAMCO/KBMG/1/DMYBK/// Comment: STA 4 11/19/1998 2.347 5,822 4,792.1 44.84 G AS LIFT CAMCO/KBMG/1/DMYBW// Comment: STA 5 10/25/1997 2.347 6,320 5,141.0 46.67 G AS LIFT CAMCO/KBMG/1/DMYBW//Comment: STA6 4/5/1999 2.347 GAS LIFT, 5,329 6,817 5,486.6 46.60 G AS LIFT MERLA/TGPD/1.5/DMY/RK/// CammenC STA 7 10/26/1997 2.375 - 6,864 5,519.3 46.03 S BR Camco'OEJ' 10/5/1985 2.406 6,881 5,5312 45.72 P ADKER CamCO'HRP-I-SP' 10/51985 2.344 Gras uFT, -, ~ 6,919 5,557.7 45.80 P RODUCTION CAMCO/KBMG/1/DMY/BK///Comment: CLOSED STA 8 1/8/1998 2.347 s,a2z 6,957 5,584.4 45.43 N IPPLE AVA BPL PORTED NIPPLE 10/5/1985 2250 7,431 5,937.0 36.63 P ACKER Baker 'DB' 10/5/1985 3250 , - i` 7,445 5,9482 36.58 N IPPLE Camco'D' Nipple NO GO 10/5/1985 1.813 GAS LIFT, 6,320 ill 7,451 5,953.0 36.56 S OS OGS 10/5/1985 1.995 .7,452 5,953.8 36.55 T TL ELMD @ 7451' ON SWS GLS 9/17/1997 10/5/1985 1.995 7,535 6,020.6 3625 F ISH CRX PLUG 33" CRX PLUG in RATHOLE (No Go ID=1.856") 1/8/1998 GAS LIFT, s,an Perforations 8 Slots Shot Top (NDj Btm (ND) Dens Top (RKB) Btm (ttKB) (RKB) (RKB) Zone Date (sh... Tye Comment SBR, 8,884 _ 7,348 7,414 5,871.0 5,923.4 C am, UNIT B, 10/5/1985 6.0 IPERF 60 deg. phasing; SOS Csg Gun 2 A-14 7,504 7,542 5,995.6 6,026.3 A -3, 2A-14 10/5/1985 6.0 IPERF 60 deg. phasing; SOS Csg Gun - - Notes: General & Safe PADKER, 6,887 _ Entl Date Annotation 5/9/2006 NOTE: WAIVERED WELL: IA x OA x OOA -PROD CSG x FORMATION COMMUNICATION ~ Se S ' .~ i ( K 9 PRODUCTION, 6,919 NIPPLE, fi,95] ~ PRODUCTION, 7,22] IPERF, ],348-7,414 ~L I PACKER, 7,431 NIPPLE, 7,445 SOS, 7,451 TTL, 7,452 .IPERF, ~ - 7,5047,542 ' FISH, 7,535 LINER, 7,860 TD, 7,863 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 8, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2A-14 (PTD 185-145). 2A-14 was originally completed in July of 1985. The well is a selective single gas lifted producer located in an area with surface subsidence due to permafrost thawing. The well failed a TIFL in April 2009 and further diagnostics found a leak in the GLM at 5,822' MD. Due to the severely corkscrewed and buckled tubing, we have been unable to drift the tubing for a patch. In June of 2009, we were able to set a plug below the packer and the well passed a CMIT TxIA indicating packer and 7" casing integrity. This well was SI in May 2009 as a proactive measure to mitigate future potential subsidence , related problems. A SBHP on 6/7/10 measured 2,921 psi at the mid-pert depth of 7,446' MD (5,949' TVD) which equates to 9.44 ppg KWF. Following the recent SBHP, a plug was set in the tubing below the top packer isolating ourselves from the reservoir. Regardless, we will still use 9.6 ppg brine as a KWF. The MASP is 2,326 psi based upon this pressure. The objective of this workover is to replace the corkscrewed/buckled tubing,. cut & pull a portion of the 7" casing, re-run new 7" casing, and circulate cement into the 9-5/8" x 7" annulus. The 7" casing work is not required to fix an existing problem, but it will be done while the rig is on the well as a proactive measure. ~ j~ ~~L ~> ~~ ~ ' ~~, i~~- ~ .~,..~ , ~ a If you have any questions or require any further information, please contact me at 265-6845. Sincerely, ~~'~ v`°1 /'~ J. Brett Packer Wells Engineer. CPAI DriNing and Wells. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2A -14 Run Date: 6/12/2009 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 2A -14 Digital Data in LAS fog mat, Digital Log Image file 1 CD Rom 50 -103- 20040 -00 i ANNED NO ,1 2 7 2005 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 96() Office: 907 273 -3527 Fax: 907 273 -3535 rafaeLbarreto@halliburton.com L.); T7; (7 is 1 \I ‘k Date: NOV p� 5 0 9 Signed: P iF al �11�5 zSICi? O!i _ 2A-14 (PTD# 185-145) Report ~TxIA Communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~ ~ ~~ ~p~ Sent: Wednesday, April 29, 2009 9:19 AM ~( To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A Subject: 2A-14 (PTD# 185-145) Report Of TxIA Communication Attachments: 2A-14 Wellbore Schematic.pdf; 2A-14 TIO Plot.ppt Jim/Tom, Kuparuk gasiifted producer 2A-14 (PTD# 185-145) is suspected of having TxIA communication based upon a recent failed TIFL associated with regularly scheduled waiver compliance work. A leaking gaslift valve is suspected so slickline will troubleshoot and repair if possible. The well will be added to the producer SCP report and will be repaired or shut in and secured by 5/5/09. Attached is a 90 day TIO plot and a wellbore schematic. «2A-14 Wellbore Schematic.pdf» «2A-14 TIO Plot.ppt» / Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Celi 907-943-1720 / 1999 Pager 907-659-7000 #909 '' ~ '~. i ~~~~i. ~. E ~ i- ~~L ~~' • ` ~1 .., ~ ~ L% 8/6/2009 IAP 1200 1000 800 ~ a 600 400 T/l/4 P I ot - 2A-14 OAP ............................................................................................................................... ...................... 200 150 a E a~ 100 ~ Y 0 r v 50 200 0 0 29-Jan-09 11-Feb-09 24-Feb-09 09-Mar-~9 22-Mar-09 04-Apr-09 17-Apr-09 Date .~ i • ~ Cc~~cac~rPl~~Ilip~ A~~~~k~, 1n~. KRU 2A-14 **` 2~ ~'~ ~'~~NrN' _ ~Yi~'1 a7 w'~ '". I . „ .~,°`s w i~ ~ ~~,~~ ~ ~ ~ ti ~;,:, ~~ ~ _.,. a i~_ ~ ___~„`9`sii ',~- _ G ~ ~ `*~h_C° LI; __ ~ .,s ~ i- ~ API: 501032004000 Well T e: PROD An le TS: 38 de 7348 SSSV Type: LOCKED OUT Orig 7/30/1985 Angle @ TD: 35 deg @ 7863 sssv Com letion: ~iaaa-~aas, OD:2.875) Annular Fluid: Last W/O: Rev Reason: ADD TTL ELMD Reference L: Ref Lo Date: Last U date: 9/7/2007 Last Ta : 7518 TD: 7863 ftK6 Gas Lift Last Ta Date. 2/9/2006 Max Hole An le 49 de 4400 MandrelNalve ~ ; ~7'~` ' ~ *~' ~i83~11 ~!' a- k ~~,, _ + yi~ 'i;~y a =,~,~ itt~ ~ _ J ) r -. ~i - ~-~^i~ _ ~~~~ ~ ~,', = i s t c~~3~ ti ~s~~~~e „~~ d' ~r~ ~ ~ tses 1s87 ; Descri tion Siz e To Bottom TV D Wt Grede Thread ( - , CONDUCTOR 16.000 0 103 103 62.50 H-40 SURFACE 9.625 0 3051 2891 36.00 J-55 Gas ~in MandrelNalve PRODUCTION 7.000 0 7227 5779 26.00 J-55 2 ~` LINER 5.000 7006 7860 6285 15.00 K-55 (3393-3394, ~~~~ ~~t ~ i' ~ ; ` _ ~ ~ ~ ~ ~ ~kr' ~ r' ~ ~ '~ ~ 1 ' # ~ ' ~;'r E ~~ ~ ~ ~ ~ ~ ~ ti v ~I~ l~ ~ ~ ~ _ m ~ u r_ v r ~ ~ ~ ~ ~ , ~ . ~ ~ Size To Bottom ND Wt Grede Thread Gas Lift 2.875 0 6991 5609 6.50 J-55 8RD EUE MandrelNalve $"-- ' 2.375 6991 7452 5954 4.70 N-80 8RD EUE (4623 3624, r~i.~~~ ~ i ~E'~~Q~~ ~~ ~ °` -- ~' ~ ~f , i i ~ y ~,~ Jmi'~i Tf ~:= o~~~` ~ ~, ~~ ~t ~ - b _~ J aa~.~ ~i ~~~1 ~ Zone Status Interval TVD Ft SPF Date T e Comment 7348 - 7414 5871 - 5924 C-4,UN1T 66 6 10/5/1985 IPERF 60 deg. phasing; SOS Csg ~ B Gun 7504 - 7542 5996 - 6027 A-3 38 6 10/5/1985 IPERF 60 deg. phasing; SOS Csg Gun '~~ [- '~.~ ""~., ~ E~4f1~1~~~~~=~1~ ~,6~~~,~iF ~ ~ ;s"- =~'~ ~ " '_ . = ~k~~ rY.~ ~~e { ry,~~"= ~.%~1~n~"yr'. ~ ' ,-.., ~ _ ,~.~ ~` ~ ~ Interval Date T e Comment i 0- 0 8/19/1990 Scale Inhibitor Pum ed 30 BBI Diesel w/ 1 drum S-8660 0- 0 2/7/1993 Scale Inhibitor Pum d 26 BBis diesel w/ 55 Gal SS-8603+70 BBIs SW Scale Inhibitor Pum ed 10.7 BBIs SW and 5206 Preflush - 0 5/2/199 7 0 (' ( ~ ''y~ ~ I~~' '~~~~ ~ ~{~~?7' ~P :~i~~ 1 G G i, ~~ ~ IY~~ ~ ~ie~ ~~ _ ~ t y~ t~: _ ~4 ~ k a ai~~` ~~ ~., ~~~~ i i ai? i: ~ ~ ~ ~ r'~. i k~ ~ ~ ~ Vlv St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run ti Cmnt 1 1886 1883 Camco KBMG GLV 1.0 BK 0.156 1268 2/11/2006 2 3393 3131 Camco KBMG GLV 1.0 BTM 0.188 1307 2/11/2006 1 3 4623 3972 Camco KBMG OV 1.0 BK 0.250 0 2/10/2006 4 5329 4452 Camco KBMG DMY 1.0 BK 0.000 0 11/19/199 5 5822 4793 Camco KBMG DMY 1.0 BK 0.000 0 10/25/199 6 6320 5142 Camco KBMG DMY 1.0 BK 0.000 0 4/5/1999 seR 7 6817 5487 Merla TGPD DMY 1.5 RK 0.000 0 10/26/199 (6864~ss5, 1. Unable to locate GLM 3393' OD:2.875 ) ' '; i ~ - ~ ~~ ~ ~u ~ ~a ~w ~',~~, = j u' w ~ %~` ~ ~ 4~~G~ . ~~ 1'~~C$~S~ _ ~ ' `-r a~ ~; a~ ,;~.~ r ~ ~ 4 ii! , .~ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt PKR 8 6919 5558 Camco KBMG DMY 1.0 BK 0.000 0 1/8/1998 1 (6881~882, ~ i. CLOSED OD:6.156) . ~ - _ ~ ~ ~ r _ -- ~,~ . ~. e , i ~ ~ ~` ui ~~ ~ ~ s~~~" ~~ ` FL ~ ~~ ~ ~ ~ '~' , ,, E t - ~. ~~~ .;, w. ;, ii~ ~, a~ ~ e ~ ~ ~_ °- = ~ . , , TVD T e Descri tion ID De th 1848 1845 SSSV Camco TRDP-IA-SSA' Locked Out on 7/8/96 2.313 6864 5520 SBR Camco'OEJ' 2.406 6881 5531 PKR Camco'HRP-I-SP' 2.344 6957 5585 NIP AVA BPL PORTED NIPPLE 2.250 6957 5585 SLEEVE-C AVA BPI set 7/30/2003 1.875 ' ' 3 250 SLEEVE-C 7431 5937 PKR Baker DB . (6957~958, o 5o 7445 5948 NIP Camco'D' Ni le NO GO 1.813 ~:z.z ~ 7451 5953 SOS Otis 1.995 - 7452 5954 TTL ELMD 7451' ON SWS GLS 9/17/1997 1.995 ~ ~ s ' == e~ ~ ' ' ~S~#~« ~'.~ ~ ~ t ~" e~i ~ ~`'!' -_ ,1E : iaw' w ,.h~~h"~ij~,~~~E~}~ ~, i~ll ~,' a 9 , i e t~~.f a, i~~i~`...~sut N ~''~- De th Descri tlon Comment 7535 CRX PLUG 33" CRX PLUG in RATHOLE No Go ID=1.856" `~ ~lo ~ ~ .- *~w^~,~a~~ 4 ~ ~' ~i~ , r ~ ~ ~ - ,:~ n '; ~ ` i t ': ; ~ ~ ~ ;~, ~ ,ilr, c i - an i , h -°"~ : „~ ~x.:. ~ r ~ >;._ . B~, ~ '*~ ~ - ~ ~~~~ ~ ~ - - - - - ~ (7431-7432, Dete NOtB OD:4.158) 5/9/2006 NOTE: WAIVERED WELL: IA x OA x OOA - PROD CSG x FORMATION COMMUNICATION NIP (7445-7446, 00:2.375) TUBING (6991-7452, - OD:2.375, ID:1.995) Perf ~- -~-~- (7504-7542) --~-- --...-.. ............... . ..---- CRX PLUG _ (7535-7538, .. .. " OD:1.813) ~-----.. .: . .--- U -- -- c; - e Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 t~~~i~~' D~ C '~ ~ ZOC~~ Dear Mr. Maunder: • ., s ~; t ; ~,,. r:. -. r4. 1~~~1 ~:5 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLI). 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 AOGCG, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitorJsealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, --~ Perry Klein ConocoPhillips Well Integrity Projects Supervisor ~ • Surface Casing by Conductor Annuius Cement, Corrosion inhibitor, Sealant fop-off Report of Sundry Operations (10-404) Date Kuparuk Field WeA Name PTD # Initial top of cement Val. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12!14!2007 2A-02 184-050 SF na SF na 3.5 12!14/2007 2A-03 184-051 44" na 44" na 50 12/14!2007 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3,5- 12/14!2007 2A-05 184-067 SF na SF na 5 12/512007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 $.5 12!14!2007 2A-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.75 12!14/2007 2A-10 186-002 23' 3.1 11" 9/24!2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12!1412007. 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9/24!2007 3 12/5/2007 2A-22 195-068.. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 I ~_ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: THRU:' JUlie Heusser, Commissioner . Tom Maunder, ~ P. I. 'Supervisor January 4, 2001 FROM: SUBJECT: Chuck Scheve; 'Petroleum InspectOr Safety Valve Tests Kuparuk River Unit -2A Pad ThurSday, January 4, 2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2A Pad. As the attached AOGCC Safety Valve SyStem Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2A-12 had a slow leak when pressure tested. This valve will be serViced and retested by the operator. Earnie Barndt cOnducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhoUses entered at this location were clean and all related equipment apPeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2A Pad in the Kuparuk River Field. KRU 2A Pad,. 12 wells, 24 components, 1. failure 4.1% failure rate 21 Wellhouse inspections AttaChment: SVS KRU 2A Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS.doc Alaska Oil and Gas ConserVation CommiSsion Safety Valve System Test Report OPerator: Phillips: Operator Rep: Eamie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2A Pad Separator psi: LPS 96 HPS 1/4/01 Well Permit Separ Set L~ Test Test Test Date oil, WAC, CmJ, Number NUmber PSI PSI T~p Code Code Code Passed CAS or CYCLE 2A-01A 1840570 2A-02 1840500 2A-03 1840510 2A-04 1840530 12A-05 1840670 2A-06 1840640 ,2A-07 1840650 2A-08 1852480 2A-09 1860010 96 70 50 P P O~ 2A-10 1860020 96 70 55 'P P O~ 2A-11 1860030 96 70 50 P P O~ 2A'12 1860040 96 70 70 P 4 OIL · 2A-13 1851440 96 70 50 P P O~ :A-~4 I lS~n~0 9~ 70 70'P e Om :A-~ ~S~n~0~ 70 70 e P O~ ~A-16 i851470 96 70 70 P P O~ 2A-17 1931400 96 70 50 P P O~ 2A'18 1950590 96 70 60 P P OILi 2A-19 1931520 2A-20. 1931510 2A-21 1931330 2A-22 1950680 96 70 70! P P O~ 2A,24 1931440 96 70. 60 P ~ " OIL 2A-25 1960620 Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1% [300 var Remarks: Surface Safety on 2A-12 had slow leak, valVe to be serviced and retested I IOIt'll Pa~e 1 of 1 SVS KRU 2A Pad 1-4-01 CS.xls STATE OF ALASKA AL~-,_. ,A OIL AND GAS CONSERVATION COMMI~,.iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing :2. Name of Operator Operation Shutdown Stimulate X Plugging Perforate Alter casing Repair well Other ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 1386' FSL, 227' FEL, Sec. 13, T11N, R8E, UM 6. Datum elevation (DF or KB) RKB 122 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-14 feet At top of productive interval 1390' FSL, 1368' FEL, Sec. 13, Tll At effective depth 1333' FSL, 1118' FEL, Sec. 13, T11 At total depth 1318' FSL, 1076' FEL, Sec. 13, T11 12. Present well condition summary Total Depth: measured true vertical N, R8E, UM N, R8E, UM N, R8E, UM 7863 feet Plugs (measured) 6287 feet Effective depth: measured 7785 feet Junk (measured) true vertical 6223 feet 9. Permit number/approval number 85-145 10. APl number 5 o-103-20040-00 11. Field/Pool Kuparuk River Field/Oil Pool None ORIGINAL 1.81" CRX plug in rathole 13. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 195 SX AS II 1 21 ' 1 21 ' Surface 301 4' 9-5/8" 820SxASIII& 3051' 2892' Intermediate 330 Sx Class G w/110 Sx AS I top job Production 7193' 7" 750 Sx CI G/AS I 7 2 2 7' 5 7 7 8' Liner 8 5 4' 5" 150 Sx Class G 7 8 6 0' 62 85' Perforation depth: measured 7348'-741 4',7504'-7542' true vertical 5871 '-5924',5996'-6027' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 6990', 2.375, 4.7#/ft, N-80 @ 6990'-7451' Packers and SSSV (type and measured depth) Pkr's: Camco HR @ 6881' & Baker DB @ 7431'; SSSV: Camco TRDP-1A-SSA @ 1848' (Locked out Stimulation or cement squeeze summary 14. Prior to well operation Fracture stimulate "A" sands on 10/28/97. Intervals treated (measured) 7504'-7542' Treatment description including volumes used and final pressure Pum 316.3 M lbs 16/20, 12/18, and 10/14 ceramic proppant into formation, fp was 7200 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 3 9 9 332 708 1230 299 Subse( 6 9 4 349 1854 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1231 307 .. Service Title Wells Superintende, SUBMIT ~aska Oil~.° ~as Cons t~u~,,~'a~sSJ0Q DUPLICATE ARCO Alaska, Inc. ?" t.---. KUPARUK RIVER UNIT WELL SERVICE REPORT · K1(2A-14(W4-6)) WELL JOB SCOPE JOB NUMBER 2A-14 FRAC, FRAC SUPPORT 0927971122.4 DATE DAILY WORK UNIT NUMBER 10/28/97 PUMP "A" SANDS RE-FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~ Yes ~'~ NoI (~ Yes O No DS-GALLEGOS JOHNS FI ELD AFC~ CC~ DAILY COST ACCUM COSTI tSigg'e~ f'~) ~ P~~ ESTIMATE KD1621 230DS28AL $1 82,438 $202,522 Initial Tb.ci Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Ou 1300 PSI 800 PSI 635 PSI 800 PSI SI DAILY SUMMARY PUMPED "A" SANDS RE-FRAC WITH 316,263# PROPPANT UP TO 13.6 PPA 10/14 IN PERFS. LEFT 6975# 10/14 PROP. IN PIPE.' TIME LOG ENTRY 04:00 MIRU DOWELL FRAC EQUIP., LI'I-rLE RED PUMP AND APC SUPPORT EQUIP. 05:45 HELD SAFETY MEETING. 06:50 PRESSURE TEST TREATING LINE TO 9300 PSI. 06:55 PUMP BREAKDOWN STAGE 8000 PSI TO 5530 PSI, 25 TO 15 BPM. PUMP 5871# 16/20 PROPPANT FOR SCOUR. SHUTDOWN FOR ISIP 2114 PSI. 07:55 PUMP DATA FRAC AND FLUSH, $ T© -15 BPM AND 4970 PSI. SHUT DOWN FOR ISIP AND CLOSURE 09:09 PUMP 675 BBLS OF 50# GEL FOR PAD. 5'TO 15 BPM AND 5428 PSI. 09:58 PUMP 16,504# 16/20,2PPA STAGE, 15BPM AND 5254 PSI. 10:16 PUMP 285,496# 12/18 PROPPANT FROM 2 PPA TO 10# PPA, 16 BPM AND 5611 PSI. 11:32 PUMP 15,157# OF 10/14 PROPPANTTO 13.6 PPA. 11:33 START PUMPING FLUSH W/GEL, PUMPED 18 BBLS AND WELL SCREENED OUT, LEAVING 6975# 10/14 PROP. IN PIPE. MAX. PRESSURE REACH IN SCREEN OUT WAS 7200 PSI. 12:30 RDMO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $732.00 APC $7,200.00 $11,100.00 ARCO $400.00 $1,500.00 DOWELL $173,138.00 $178,590.00 HALLIBURTON $0.00 $5,500.00 LITTLE RED $1,700.00 $5,100.00 TOTAL FIELD ESTIMATE $1 82,438.00 $202,522.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSi~'N REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development 122' RKB feet ARCO Alaska. Inc. Exploratory _ 7. Unit or Property name 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1386' FSL, 227' FEL, Sec. 13, T11N, R8E, UM, 2A-14 At top of productive interval 9. Permit number/approval number 1390' FSL; 1368' FEL, Sec. 13, T11N, R8E, UM 85-145,/~o-~ At effective depth 10. APl number 1352' FSL, 1122 ' FEL, Sec. 13, T11N, R8E, UM 50-103-20040 At total depth 11. Field/Pool 1318' FNL, 1076' FEL, Sec. 13, T11N, R8E, UM Kul3aruk River Oil Pool 12. Present well condition summary Total Depth: measured 7 8 6 3 feet Plugs (measured) true vertical 6287' feet Effective depth: measured 7 7 8 5' feet Junk (measured) true vertical 6224 feet Casing Length Size Cemented Measured depth True vertical depth Structural 1 03' 1 6" 195 Sx CS II 1 03' 1 03' Conductor 3051 ' 9 5/8" 820 Sx AS III & 434 8' 431 7' Surface 330 Sx Class G Intermediate Production 7277' 7" 500 Sx Class G & 250 Sx CSI 7237' 6267' Liner 854' 5" 150 Sx Class G 78 6 0' 6 2 8 5' Perforation depth:measured RE( EIVED 7348'-7414' 7504'-7542' true vertical 5871 '-5923' 5996'-6027' NOV 2 8 1990 Tubing (size, grade, and measured depth) 2 7/8" J-55 x 2 3/8" N-80 set at 7452' Alaska0il & GasCons. Commissiot~ Packers and SSSV (type and measured depth) Anchorage Camco HR @ 6881', Baker DB @ 7431' Camco TRDP-1A-SSA @ 1848' 13. Stimulation or cement squeeze summary Hydraulically fracture stimulated the A Sand with 11400 lb of 16/20 mesh ceramic proppant. Intervals treated (measured) A Sand, 7504'-7542' Treatment description including volumes used and final pressure Pumped 437 bbl of fluids, with sand concentrations ranging from 2 to 8 ppg. FTP=7100psi. Representative Daily Avera(~e Production or Iniection Data 14. _ - OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7 7 4 5 9 4 - 0 - 1 I 0 0 2 3 6 Subsequent to operation 1 7 5 6 1 4 8 9 - 0 - 1 4 8 0 2 2 5 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector __ Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE .~RCO Alaska, Ir~, ,-"~- Subsidiary of Atlantic Richfield Corn WELL qONTRACTOR REMARKS FIELD - DISTRICT- STATE OPERATION AT/REPORT TIME Co,,~i'~ WELL SERVICE REPORT / DAYS DA~? /600 j(_.,l? lg2~- i ~06 $5'j'o,,~,; If',,," z:??,~ /5-o /~g/~ / I?o t I 207_ 170 5" i7o"7 /,~oo c .. -,:- ,-,... GaS Cons. 'Anchorage CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ISigned STATE OF ALASKA ~- ALASKA OIL AND GAS CONSERVATION C, OM~,.. _~iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1386' FSL 227' FWL, Sec 13, T11N, R8E, UM At top of productive interval 1390' FSL, 1368' FEL, Sec 13, T11N, R8E, UM At effective depth 1352' FSL, 1122' FEL, Sec. 13, T11N, R8E, UM At total depth 1318' FSL, 1076' FEL, Sec. 13, T11N R8E, UM 12. Present well condition summary Total Depth: RKB 122 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-14 feet 9. Permit number 85-145 10. APl number s0-1 03-20040 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool measured true vertical 7863' feet Plugs (measured) 6 2 8 7' feet Effective depth: measured true vertical 7785' feet Junk (measured) 6 2 2 4' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 103' 3051 ' 7277' 854' measured 7348'-7414' 7504'-7542' true vertical 5871 '-5923', Tubing (size, grade, and measured depth Size Cemented 1 6" 195 Sx AS II 9 5/8" 820 Sx AS III & 330 Sx Class G 7" 500 Sx Class G & 250 Sx ASI 5" 150 Sx Class G 12 SPF 60 degree phasing 6 SPF 60 degree phasing 5996'-6027' TVD 2 7/8" J-55 x 2 3/8" N-80 set at 7452' Packers and SSSV (type and measured depth) Measured depth True vertical depth 103' 103' 4348' 4317' 7237' 6267' 7860' 6285' Ju N 1 4 1990 .Oil & Gas Cons. Commission '~,,~ ~,nchorage Camco HR @ 6881', Baker DB @ 7431'. Camco TRDP-1A-SSA ~ 1848' 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch Refrac A Sands with 31,000 lbs Carbo-Lite proppant. (Wellbore schematic and procedure attached). 14. Estimated date for commencing operation 15, Status of well classification as: June 1990 Oil __ Gas __ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service P r o d u c e r Signed that the foregoing is true and correct to the best of my knowledge. FOR ~MISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test__ Subsequent form require 10- IIAppr°val No? Approved by the order Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy Returned llql o__ Date SU BMiT"[N/'i':Rii~Li'CATE WELL 2A-14 PRODUCER APl # 501032004000 SURFACE LOCATION' 1386' FSL, 227' FWL, SEC 13, T11N, R8E, UM TOP KUPARUK: 1390' FSL, 1368' FEL, SEC 13, T11N, R8E, UM SPUD: 7/20/85 ALL DEPTHS MD-RKB (TUBING SPOOL RKB=22') COMPLETION: 10/6/58 TREE: FMC GEN III 5000 PSI, 2-9/16" 16", 62.5# H-40 @ 103' A6 A4 9-5/8", 36# J-55 @ 3051' CAMCO OEJ PBR: CAMCO HR-1 PKR: AVA BPL NIPPLE: 2 7/8" X 2 3/8" XO: 7", 26# J-55 2.406" ID @ 6864' @ 6881' @ 6957' @ 7278' @ 7277' VOLUME: 0.0383 BBL/FT C2,3 & 4 BLAST JOINTS B BAKER DB PKR: @ 7431' CAMCO D NIPPLE: 1.821" ID @ 7445' CAMCO SHROUT: @ 7451' A5 , A3 A2 5"' 18# N-80 @ 7863' VOLUME: 0.0177 BBL/FT L SSSV · CAMCO TRDP-1A-SSA 2.312" ID @ 1848' GLM 1: 1886' / 1.0" CAMCO KBMG / .1875" GLM2: 3393' / 1.0"CAMCOKBMG/ D GLM 3: 4623' / 1.0" CAMCO KBMG / .1875" GLM4: 5329' / 1.0"CAMCOKBMG/ DV GLM5: 5822' / 1.0"CAMCOKBMG/ DV GLM 6: 6320' / 1.0" CAMCO KBMG/ .1875" GLM 7: 6817' / 1.5" MERLA TGPD/ .1875" GLM 8: 6919' / 1.0"CAMCO KBMG/ DV 2-7/8", 6.5# J-55 ABMOD, VOLUME: 0.00579 BBL/FT, XO at 6990' 5" LINER TOP @ 7066 7348'-7414' 12 SPF 2-3/8" 4.7# N-80 ABMOD, VOLUME = 0.00387 BBL/FT · ,'t~/////· __ __ PBTD: 7865' RE£EI, VED 7504'-7542' 6 SPFjuN 1 ~ ljcJ90 A~a~ka 0il & Gas Cons, Commission Anchora~ HOLE ANGLE ACROSS KUPARUK = 46 DEGREES MAX. HOLE ANGLE =47.07 DEGREES @ 3500' VOLUME TO TOP A PERF = 44 BBLS FILL AT 7602', 3/5/88 REVISION: 6/11/90 Attachment 2 Kuparuk Well 2A-14 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K81239 1. SI Well 2A-14, MIRU pump truck and freeze protect the well (16% water cut). . MIRU Slickline unit. Tag bottom. If less than 50 feet of rathole is discovered, consult with Operations Engineering to determine if the CTU is necessary. 3. Pull AVA commingling sleeve at 6957'. 4. Set AVA blanking sleeve at 6957'. 5. Pull GLV's at 1886', 4623', 6320', and 6817. Run DV's at 1886', 4623', and 6320'. 6. RIH with a 1.812" standing valve, or blanking plug, and displace the 7" casing with diesel, 6881' x 0.0302 bbl/ft = 207 bbl annular volume. 7. Run 1.5" DV at 6817'. 8. Pressure test the tubing. Also, pressure test the 7" annulus, while monitoring the 9-5/8" casing pressure. POH with standing valve and RDMO slickline unit. 9. Perform several A Sand only production tests to establish a base line pre-frac rate. 10. 11. Caution - Since the 7" annulus will be liquid packed, monitor 7" casing pressure during production testing. RU fracture equipment. Install "Tree Saver". Pressure up the 7" annulus to 3000 psi. Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled water with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. 12. 13. Pump the 100 Bbl pre-pad at 18 BPM. Shut down and determine the ISIP. The A Sand was perforated with 294 shots, 6 spf, at 60 degree phasing with a 3-3/8" Ultra Jet Casing Gun, with every 7th shot a big hole (Ultra Charge). Pump fracture treatment per the attached schedule. pressures following the ISIP. WHTPE* = Fracture Gradient* Frac Fluid Gradient Tubing Friction Excess Friction* Record the 2, 5, 10, and 15 minute Expected wellhead treating pressure: 5367 psig = 0.65 psi/ft (6009' TVD) = O.44 psi/ft = 320 psi/1000' @ 20 BPM (2-7/8") = 600 psi/1000' @ 20 BPM (2-3/8") = 1596 psi *These values are suspect and are based on data from the 1985 Micro-Frac. Due to the limited pump time of that job, there is very little data to work with. However, if excessive treating pressures are experienced, reduce the rate in small increments adjusting additive rates as appropriate. Attachment 2 continued Kuparuk Well 2A-14 Operations Engineer -- Obtain representative fluid samples from the pad, slurry, and flush stages. Place samples in hot water bath at 150° F to observe break time. 14. Rig down fracture stimulation equipment. Follow attached flowback schedule. Sundry Notice. Kuparuk Well 2A.14 No BOP's Will be Utilized during this Procedure. BOttom Hole Pressure (6200' SS) ~ 3241 psi No wOrkover fluid will be used during this process. RE£E]VE[2 jtJH I ~-~ 1990 ,:~,!~a .Oii.& ~ias Cons, Commission ' ~ ~nchora~ '~ ~-" STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION G~a,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV 15ED OIL I-~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-145 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20040 4. Location of well at surface 9. Unit or Lease Name 1386' FSL, 227' FWL, Sec.13, T11N, RSE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1390' FSL, 1368' FEL, Sec.13, T11N,.R8E, UM 2A-14 At Total Depth 11. Field and Pool 1318' FSL, 1076' FEL, Sec.13, T11N,.RSE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 122' ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 07/20/85 07/28/85 07/30/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. D~?ctional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7863'MD, 6287'T.V.D 7785'MD, 6223'TVD YES ~_1 NO [] 1848' feet MD 1500' (approx) _ 22. Type Electric or Other Logs Run DIL/SFL/CNL/LDT/GR/SP/Cal/Microl og, RFT, CET, GR/CCL, GCT, Temp. Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 b" 62.5# H-40 Surf 103 ' 24" 195 sx AS I I 9-5/8" 36.0# J-55 Surf 3051' 12-1/4" 820 sx AS III & 330 sx.Class G Performed top .job w/l l( sx AS I 7" 26.0# J-55 : Surf 7227' 8-1/2" 500 sx Class G & 250 s> AS I 5" 15.0# K-55 7006' 7860' 6-1/8" 150 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7452' 6881' & 7431' 7542'-7504' w/6 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7348'-7414' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7007' (TOL) 100 sx Class G See attached Addel,dum~ dated 11/1/85, for fracture da':~, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO ITEST PERIOD [~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10407 Rev. 7-1-80 ~/C3/56:DAN i CONTINUED ON REVERSE SIDE Submit in duplicate 29. · '. - . .. . r .' .._~_.~..~. - GEOLOGiCMARKERS . ~..~ . ' !: ', -' ~.~' ~ FORMATIONj~TESTS · ~ . '' .-~._ ,... . , : : : ~' :- - L ,. .. .:.., ,, NAME ' - Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C ~ 7348' 5869' Depth H~/dro. Press. Shut-in Press. ~ ,_._ 7352' 3374 psi TIGHT Base Kuparuk C 7414' 5922' 7352.5' 3358 psi 3372 psi 7356 ' 3361 ,psi ~ T I GHT Top Kuparuk A 7454 ' 5954 ' 7359' 3366 psi T I GHT ~ ~ ": ' :- 7358.5' 3365' psi TIGHT Base Kuparuk A 7614' 6083' 7365' 3369 psi TIGHT . 7365.5' 3368 psi TIGHT 7367' 3367 psi TIGHT · ~ 7377' -3372 psi TIGHT ' r:, 7379' 3376 psi 3272 psi 7385 ' 337-8 psi T I GHT 7403' 3389 psi 3148 - aborted before final SI 7405 ' 3386 psi ABORTED ' ~' ' '- ' 7405' 3385 psi TIGHT 7463.5' 3404 psi TIGHT - 7482' 3398 psi TIGHT ' _ 7480' 3380 psi TIGHT 31. LIST OF ATTACHMENTS Addendum (dated 11/1/85) . o. , 32. -I hereby certify that the fore~c~ing is ~'~Je and correct to the best of my knowledge . . i ' Signed '- ~~')'i~~ .~/~/Z/~L_., ~ Title ASSociate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service WellS: Gas injection, water injection, steam injection, air injection, salt water disposal; water supplY' fo~ 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 welI is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10~407 ADDENDUM WELL: 2A-14 lo/~6/85 Frac well in 5 stages w/total of 2200# 20/40 sand & 125 bbls diesel. Left 100 bbls 20/40 sand in csg. Rn Temp surv log f/7600'-7300'. Drilling ~uperintendent c ?"0 !": '!'S Date ARCO Alaska, Inc. Post Office B( '30360 Anchorage, Aiasr, a 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal =5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final -.~-IR- 14 ~J~IR- 14 2A-14 -~3A-1 ~3A-2 ~-~3A-3 Prints' CET/CEL 10-12-85 Run =2 8600 CET/CEL 10-13-85 Run =3 85.50 CET/CEL 10-02-85 Run #1 6795 CET/CEL 10-01-85 Run #1 7550 CET/CEL 10-01-85 Run #1 6680 CET/CEL 10-01-85 Run #1 6080 CET/CEL 12-30-85 Run ~2 6400 CET/CEL 12-30-85 Run fi2 7300 CET/CEL 10-!5-85 Run ~ =1 5887 CET/CEL 10-15 85 Run ~ - =1 3995 CET/CEL 10-!7-85 Run #1 7000 · . · CET/CEL 12-19-85 Run =1 ~ 5166 CET/CEL 12-19-85 Run ~1 6950 CET/CEL 10-05-85 Run #1 6860 CET/CEL 10-19-85 Run ~1 7000 CET/CEL 12-18-85 Run ~1 36 - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 - 6678 RE[ IV Receipt Acknowledged' ~/ ~'~"u'V'D~tSe.-lSSb'~/ - ~ K Drilling Vault(1 film) ARCO Ala5A3. Inc. i$ a Subsidiary ol AlianticRichfieldCompany STATE OF ALASKA ' ALASKA O,- AND GAS CONSERVATION CO~,,VllSSION ~.. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL EX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. · 85-145 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20040 4. Location of well at surface 9. Unit or Lease Name 1386' FSL, 227' FWL, Sec.13, T11N, R8E, UM -~ Kuparuk River Unit At Top Producing Interval VEriFIED 10. Well Number 1390' FSL, 1368' FEL, Sec.13, T11N, R8E, UM Surf. ~:'~ 2A-14 At Total Depth ¢7 11. Field and Pool 1:~18' FSL, 1076' FEL, Sec.l~, TllN, RSE, UM--~:B'H'~. , Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 122' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp~, Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/20/85 07/28/85 07/30/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+-rVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 7863 'MD ,6287 'TVD 7785'MD,6223'TVD YES~ NO [] 1848 feetMDI 1500' (approx) 22. Type Electric or Other Logs Run D I L/SFL/CNL/LDT/GR/SP/Ca 1/Mi crol og, RFT, CET, GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 10:3' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 3051' 12-1/4" 820 sx AS Ill & 330 sx Class G Top job performed w/11t) sx AS I 7" 26.0# J-55 Surf 7227' 8-1/2" 500 sx Class G & 250 s:( AS I 5" 15.0# K-55 7006' 7860' 6-1/8" 150 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7542' - 7504' w/6 spf 2-7/8" 7452' 6881 ' & 74:~1 ' 7348' - 7414' W/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7007' (TOL) 100 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · Form 10-407 * NOTE: Tubing was run & well perforated 10/6/85. DAM/WC79 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . ...-' GEoLoGIc MARl(ERS I~ORMATION TESTS' NAME - Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . . Top Kuparuk C 7348' ..~ 5869' DEPTH HYDRO. PRESS. SHUT-IN P. RESS. Base Kuparuk C 74i4~ 5922' 7352' 3374 psi TIGHT ' ' Top Kuparuk A .. . 7454'_.~.. 5954' 7352.5' 3358 psi 3372 psi Base Kuparuk A 7614' 6083' 7356' 3361 psi TIGHT' . 7359' 3366 psi TIGHT . -, 7358.5' 3365 psi TIGHT .'.; . 7365 ' 3369 psi T I GHT 7365.5' 3368 psi TIGHT 7367' 3367 psi TIGHT · 7377' 3372 psi TIGHT 7379' 3376 psi 3272 psi 7385' 3378 psi TIGHT 7403' 3389 psi 3148 - aborted before final SI 7405 ' 3386 psi ABORTED. ,. 7405' 3385 psi TIGHT 7463,.5' 3404 psi TIGHT 7482' 3398 psi TIGHT 7480' 3380 psi TIGHT 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _(~..~_~ _ , Title Date · INSTRUCTIONS General' This form is .designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office B0^ ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 198-6 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are the Well Completion Reports for the following wells: 3F-11 The bottomhol-e locations, TVDs, and geologic markers will be submitted when the gyroscopic surveys are received. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L149 Enclosures ARCO Alaska, Inc. is a Subsidiary o! AllanticRichlieldCompany ARCO Oil and Gas Company Well History- Initial Report- Daily Instructione: Prepare and submit the "Initial Repert': On-the first Wednesday affe; 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 904333 ICounty, parish or borough North Slope Borough Lease ADL 25570 or Unit ITitle Completion State Alaska IWell no. 2A-14 Nordic 1 API 50-103-20040 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun ID,te IHour IPrior status if a W.O. Complete 9/27/85 1500 hrs. 56.24% Date and depth as of 8:00 a.m. 9/28/85 thru 9/30/85 10/01/85 lO/O2/85 lO/O3/85 lO/O4/85 Complete record for each day reported 5" @ 7006' - 7860' 6863', Drlg cmt Wt. 10.8, PV 14, YP 7, PH 9.5, WL 11.6, Sol 17.5 Accept rig @ 1500 hfs, 9/27/85. NU & tst BOPE. RIH, tag ice plug @ 175', wsh dn to 277', circ& warm hole, POH. RIH to 2500 psi, displ brine w/ll.0 ppg drlg mud. RIH to 4683', C&C, RIH to 6996', wsh & rotate to TOL @ 7007' (DPM) w/no cmt on TOL. C&C mud, build mud wt; tst TOL; no tst. Prep to sqz. RIH w/7" Champ pkr, set @ 6620'. Sqz TOL w/100 sx C1 "G" w/.6% FDP-C344 & .25% HR-7, POH. RIH w/BHA, C&C, drl cmt to 6863'. 5" @ 7006' - 7860' 7200', Drlg cmt in 5" lnr Wt. 10.8, PV 11, YP 9, PH 13, WL 15.8, Sol 18 Drl to 7007', circ hole cln, press ts TOL to 3000 psi; OK, POH. RIH w/4-1/8" BHA on 3½" DP, drl cmt f/7007'-7070', drl & wsh cmt stringers to 7200'. 5" @ 7006' - 7860' 7200', Rev circ hole cln Wt. 10.9+, PV 11, YP 9, PH 13, WL 15.2, Sol 18 Drl qmt, plugs & LC to 7785', circ hole cln. Press tst lnr to 3000 psi; OK, POH. RIH w/5" csg scrpr, scrape 5" lnr. RU & rev circ hole cln. 5" @ 7006' - 7860' 7785' PBTD, TOH Wt. 11, PV 11, YP 8, PH 13+, WL 17.3, Sol 18 Compl rev circ, TOH. RU Schl, rn CET f/7763'-6795' Rn GR/CCL f/7764'-6895'. Rn GCT gyro f/7702'-surf. TIH w/6-[/8" bit & 7" csg scrpr to 7006' TOL, rev circ hole, TOH. 5" @ 7006' - 7860' 7785' PBTD, TOH, LD DP 11.2 ppg NaC1/NaBr Fin TOH. TIE w/4-1/8" bit & 5" cs§ scrpr to 7785', rev circ hole. Chg over circ sys to 10.9 ppg brine & wt up to 11.2 ppg brine. TOH. The above is correct Signature For form preparation a~ distribution, Date ITitle Drilling Superintendent 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 lest 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. Accounting cost center code District ICounty or Parish I Alaska Field lLease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE 904333 Nordic 1 North Slope Borough ADL 25570 Completion AP1 50-103-20040 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 9 / 27/85 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD lo/o5/85 thru 10/07/85 State I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well I our I Prlor status if a W.O. 1500 hrs. 5" @ 7006' - 7860' 7785' PBTD, RR 7.2 diesel RU Schl, perf w/60° phasing, 6 S?F f/7542'-7504'. Perf'd f/7348'-7414', w/120° phasing, 12 spf. Make gage ring/JB rn. Set DB Pkr @ 7431', RD Schl. RU & rn 2-7/8" x 2-3/8" compl string, stab into pkr, space out, drop ball, set pkr, tst tbg @ 2500 psi. Attempt to tst backside, sheared ball. RU Camco S/L, set std'g vlv @ 7445', tst backside @ 2500 psi; OK. Closed SSSV, bled tbg to 300 psi, tat SSSV f/15 min; OK. Pull std'g vlv. RD Camco. Set BPV. ND BOPE, NU & tst tree. Displ well to diesel. Press tbg to 1000 psi. Tst orifice vlv; OK. Set BPV. Secure well. RR @ 1100 hfs, 10/6/85. SSSV @ 1848', HRP-1SP Pkr @ 6881', DB Pkr @ 7431', "D" Nipple @ 7445' TT @ 7452' , New TD Released rig Date 1100 hrs. I PB Deplh Kind of rig 0/06/85 Type completion (single, dual, etc.) Single Classifications (oil, gas, etc.) 0il Alaska JWell no. 2A-14 Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7785 ' PBTD Rotary Well no. :Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, 8PM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Elfective date corrected The above is correct For form preparation and ~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION COcaMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-145 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20040 4. Location of well at surface 9. Unit or Lease Name 1387' FSL, 227' FWL, Sec.l:3, TllN, R8E, UM (Approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 2A-14 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 124' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/20/85 07/28/85 07/:30/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7863 'MD 7860 'MD YES 7~ NO [] 1 848 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D I L/SFL/CNL/LDT/GR/SP/Cal/Mi crol og, RFT, CET, GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 195 sx AS I I 9-5/8" 36.0# J-55 Surf 3051' 12-1/4" 820 sx AS Ill & 330 sx Class G Top job performed w/ll sx AS I 7" 26.0# J-55 Surf 7227' 8-1/2" 500 sx Class G & 250 s; AS I 5" 15.0# K-55 7006' 7860' 6-1/8" 150 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7542' - 7504' w/6 spf 2-7/8" 7452' 6881' & 7431' 7348' - 7414' W/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7007' (TOL) 100 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Tubing was run & well perforated 10/6/85. DAM/WC15 Submit in duplicate Rev. 711-80 CONTINUED ON REVERSE SIDE 29. ' NAME To be submitted wi GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. )n received. DEPTH HYDRO. PRESS. SHUT-IN PRESS. 7352' 3374 psi 7352.5' 3358 psi 7356' 3361 psi 7359' 3366 psi 7358.5' 3365 psi 7365' 3369 psi 7365.5' 3368 psi 7367' 3367 psi 7377' 3372 psi 7379' 3376 psi 7385' 3378 psi 7403' 3389 psi 7405' 3386 psi 7405' 3385 psi 7463.5' 3404 psi 7482' 3398 psi 7480' 3380 psi TIGHT' 3372 psi TIGHT TIGHT TIGHT TIGHT TIGHT TIGHT TIGHT 3272 psi TIGHT 3148 - aborted before final SI ABORTED TIGHT TIGHT TIGHT TIGHT 31. LIST OF ATTACHMENTS Well History (completion details) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer 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 suppl,v for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Inject'ion, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2A-14 Dear Mr. Chatterton- Enclosed is a copy of the 2A-14 Well History to include with the Well Completion Report, dated 8/27/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L51 Enclosure cc' 2A-14 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany well History- Initial Report- Dally iltttmcfleits: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. ~': .~ ~i Daily work prior to spudding should be summarized on the form giving inclusive dates only. Distriot Field Alaska Kuparuk River ICounty. parish or borough North Slope Borough ILease or Unit ADL 25570 ITitle Drill State Alaska IWell no. 2A-14 Auth. er W.O. no, AFE 904333 Parker 141 API 50-103-20040 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUnSpUdded IDate 7/20/85 IH°ur 1515 hrs. IPri°rstatusifaw'O' 7/20/85 thru 7/22/85 7/23/85 7/24/85 7/25/85 Complete record for each day reported Date and depth as of 8:00 a.m. 16" @ 103' 3071', (2968'), Circ Wt. 9.8, PV 13, YP 27, PH 10.5, WL 17.2, Sol 10.5 Accept ri~ @ 1130 hfs, 7/20/85. NU 20" Hydrl. Spud well @ 1515 hrs, 7/20/85. Drl, DD & surv 12¼" hole to 3071', 19 std short trip, CBU. 1620', 3.8°, N83.7E, 1619.89 TVD, 4.93 VS, .55N, 4.94E 1869', 11.8°, N86.5E, 1866.15 TVD, 40.06 VS, 4.61N, 40.15E 2550', 28.9°, S88.3E, 2499.65 TVD, 283.75 VS, 1.45N, 283.82E 3045', 46°, S89.6E, 2888.12 TVD, 587.61VS, 6.44S, 587.59E 9-5/8" @ 3051' 3071', (0'), WOC Wt. 8.9, PV 8, YP 7, PH 10.5, WL 11.6, Sol 4.3 TOH to rn csg. RU & rn 70 jts, 9-5/8", 36#, J-55 HF-ERW BTC csg w/FS @ 3051', FC @ 2961'. Cmt w/820 sx AS III, followed by 330 sx C1 "G" w/2% S-1 & .2% D-46. Bump plug. No cmt rtns to surf. Perform top job w/Il0 sx AS I cmt. WOC. 9-5/8" @ 3051' 3738', (667'), Turbine drlg Wt. 8.7+, PV 8, YP 9, PH 11, WL 20, Sol 3.2 WOC. ND 20" Hydrl. Instl pack-off & wellhead, NU & tst BOPE. TIH w/8½" BHA, tag FC @ 2960', Press csg to 1500 psi; OK.. DO FC, cmt, FS + 10' new hole to 3081'. Chg over to polymer mud. Conduct LOT to 13.9 ppg EMW, TOH. PU turbine, TIH, drl to 3738'. 3260', 45.3°, S88.6E, 3038.41TVD, 741.35 VS, 8.85S, 741.31E 9-5/8" @ 3051' 7075', (3337'), Turbine drlg Wt. 9.4+, PV 8, YP 5, PH 8.0, WL 8.0, Sol 8.4 Turbine drl to 7075'. 3720', 46.5°, N86.5E, 3358.52 TVD, 1071.37 VS, 2.80S, 1071.49E 4669', 47.4°, S88.4E, 4014.05 TVD, 1757.19 VS, 8.00S, 1757.33E 5195', 46.3°, N89.3W, 4374.17 TVD, 2140.54 VS, 12.77S, 2140.65E 5920', 44.9°, S86.1W, 4877.98 TVD, 2660.88 VS, 8.55N, 2661.46W 6825', 45.5°, N84.2E, 5513.11TVD, 3302.73 VS, 56.87N, 3304.28W RECEIVED The above is correct Signat~ ~,,~ ~. I Date~ ~,,~ Title Drilling Superintendent 56.24% A. RCO Oil and Gas Company Daily Well History--Interim Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final InstructiOns: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25570 Complete record for each day while drilling or workover in progress 7/26/85 7/27/85 thru 7/29/85 7/30/85 IState Alaska IWell no. 2A-14 7" @ 7227' 7235', (160'), ND BO?E Wt. 9.6, PV 9, YP 6, PH 8.0, WL 8.6, Sol 9.5 Turbine drl to 7235', 20 std short trip, CBU, POOH. Chg rams to 7" & tst to 3000 psi. RU & rn 174 jts, 7", J-55, 26# HF-ERW BTC w/FC @ 7137' & FS @ 7227'. Cmt 7" w/500 sx C1 "G" cmt w/3% KCl, .8% D-60 & .2% D-46. CIP @ 0530 hrs, 7/26/85. ND BOPE to set slips on 7". 7039', 44.5°, 82.7°, 5664.43 TVD, 3452.72 VS, 74.13N, 3454.61E 7160', 43.3°, 82.9, 5761.51 TVD, 3535.76 VS, 84.64N, 3537.85E 7" @ 7227' 7863', (628'), Strip over WL Wt. 10.9+, PV 14, YP 9, PH 10.5, WL 6.3, Sol 12 Chg rams to 3½", PU BOPE, set slips on 7" csg, cut off csg. NU & tst BOPE to 4000 psi. RIH w/4-3/4" BHA, TIH, tag cmt @ 7120', tst csg to 3000 psi. DO FC, hard cmt to FS. Chg out mud to 11.O ppg. DO shoe, CO to 7235', drl 10' formation. Conduct LOT to 14 ppg EMW w/ll.O ppg mud in hole. Drl to 7305', POOH f/6-1/8" stab. Chg BHA, TIH, wsh & rm stab thru shoe. Drl 6-1/4" hole to 7863' TD. C&C hole f/E-logs. Short trip to csg shoe; OK, POOH. RU Schl, log DIL/SFL/CNL/LDT/GR/SP/CAL/ micro log f/7850'-7226'. RIH w/RFT to take formation pressures f/7367', stuck tl @ 7379'; unable to wrk free. PU stripping tls, RIH over in. 7" @ 7227' 7863', (0'), RIH w/5" lnr Wt. 10.8+, PV 16, YP 8, PH 11, WL 6.3, Sol 12 Fin stripping in hole over Schl in to fsh, latch onto same, pull out rope socket, POOH w/fsh & LD same. RIH w/bit to 7830', wsh & rm 30' to btm, C&C, short trip to csg shoe, POOH. RU csg service, PU 23 jts, 5", 15#, FL-45 lnr & RIH on 3½" DP slow. 7863', 45°, N85E, 6255.93 TVD, 4021.69 VS, 136.25N, 4024.79E The above is correct For forn~epara~ion and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Superintendent ARCO Oil and Gas Company Daily ell History-Final Report Instructions: Prepare and submit the "Final Report" on lhe 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. I Accounting cost center code District County or Parish ~ State Alaska North Slope BoroughI Alaska Field Kuparuk River Auth. or W.O. no. AFE 904333 Lease or Unit Title ADL 25570 IWell no. 2A-14 Drill Parker 141 API 50-103-20040 Operator A.R.Co. W.I. rrotal number of wells (active or inactive) on this, ~CO Alaska, Inc. 56.24% Icost center prior to plugging and I labandonment of this well Spudded or W.O. begun Date IHour I Prior status if a W.O. Spudded 7/20/85 / 1515 hrs. I Date and depth Complete record for each day reported as of 8:00 a.m. 7/31/85 5" @ 7860' 7860' PBTD, RR Brine FRIH w/5" lnr. Set @ 7850' w/TOL @ 7006'. C&C mud, POOH, M&P 150 sx CL "G" @ 15.8 ppg. Displ w/Dowell, bmp plug w/3000 #, set pkr, set packoff, POOH, LD tool. RIH w/3½" DP open ended to 2000'. Chg over to brine, POOH, ND BOPE, NU well head. Release Rig @ 1900 hfs, 7-30-85. Did TD New TD Released rig Date 1900 hrs. Classifications (oil, gas, etc.) Oil PB Depth 7/30/85 ~< nd of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7860 ' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Prodl~t~of~___ o,, ~b~/ '/ · '~'~" Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable -~ ~ "'EflecJive. date corrected The above is correct Sign a~ull~l~ For form preparation and distribution, Drilling Superintendent ARCO Alaska, Inc.' Post Office BOx 100360 Anchorage, Alaska.99510-0360 Telephone 907 276 1215 DATE: 09-17-85 TRANSMITTAL NO:5356 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS. CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRAN~MII'?ED t~EKEWITH ARE qbe FOLLOWING RECEIPT AND RETUF. N ONE SIGNED COPY OF ThIS TRANSMITTAL. OPEN HOLE FINALS/ SCHL (ONE * OF EACa) 2A-14 ''~ 5"~'~. DIL/SFL-GR "-.~2'''j DIL/SFL-GR x~5"J LITHO DEN/NEU poRo ",~2''j LITHO DEN/NEU PORO ~5" ~ LI?HO DEN/NEU RAW ~2"~ LITHO DEN/NEU ~W ~ CYBE~OOK ~'5 & 10 " MICROLOG ~ ~ RFT LOG ~2 '~b// DIL/SFL-GR ~5"~, LITHO DEN/NEU PORO . D t4/ U ~: .~'2"~ LITHO DEN/NEU ~~ 5~) r4ICROLOG PLEASE ACKNOWLEDGE 07-28-85 RUN #1 7 07-28-85 RUN #1 7 07-28-85 RUN #1 7 07-28-85 RUN #1 7 07-28-85 RUN #1 7 07-28-85 RUN #1 7 07-28-85 RUN #1 7 07-2~-85 RUN ~1 7 07-28-85 RUN #1 7 07-16-~5 RUN #1 07-16-85 RUN #1 07-16-85 RUN ~1 07-16-85 RUN #1 07-16-85 RUN #1 07-16-85 RUN #1 07-16-85 RUN 07-16-85 RUN 07-16-8-5 RUN ~1 212-7838 212-7838 212-7817 212-7817 212-7817 212-7817 336-7670 212-7778 352-7482 7650-8065 7650-8065 7650-8112 7650-8112 7650-8112 7650-~112 7650-8065 7650-8073 765U-SU73 RECEIPT ACKNOWLEDGED: BPAE ~. CURRIER CHEVRON D & M*BL DRILLING*BL L. JOHNSTON MOBIL NSK CLERK*BL DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATH~ELL*SL DATE: STATE OF ALASKA*BL sohio /sm UNION K.TULIN/VAULT* FILM ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2A-14 Dear Mr. Chatterton' Enclosed is a Well Completion Report for 2A-14. The bottomhole location, geologic markers, TVDs, and tubing details will be submitted after the gyroscopic survey is run and the well completed. Also, I have not yet received the 2A-14 Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L27 Enclosure :~>:_ ~' ~ A!aska 0il & Gas ?: .: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany - ~' STATE OF ALASKA -- ALASKAL. . AND GAS CONSERVATION CC 41SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, - ' 85-145 · 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 103-20040 4. Location of well at surface 9. Unit or Lease Name 1387' FSL, 227' FWL, Sec. 13, T11N, R8E, UM (Approx) Kuparuk River Unit At Top Producing Interval 10. Well Number TO be submitted when gyro is run. 2A-14 At Total Depth 11. Field and Pool TO be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 124' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/20/85 07/28/85 07/30/85 N/A feet MS L N/A 17. Total Depth (M D+TVD) 7863 ' MD 18. Plug Back Depth (MD+-I'VD) 7860' MD YES19' Directional Survey[] NO E~X I20' Depth where SSSV setN/A feet MD I21' Thickness °f Permafr°st1500' (app fox ) 22. Type Electric or Other Logs Run D I L/SFL/CNL/LDT/GR/SP/Cal/Mi crol og, RFT '23.- CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 195 sx AS II 9'5/8" 36.0# J-55 Surf 3051' 12-1/4" 820 sx AS I'll & 330 sx Class G Top 3ob performed w/ll ) sx AS I 7" 26.0# J-55 Surf 7227' 8-1/2" 500 sx Class G 5" 15.0# K-55 7006' 7860' 6-1/8" 150 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=~, OIE-BBL GAS-MCF WATER-BBL el L GRAVITY-APl (corr) Press. 24-HOUR RATE I~' I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,i Form 10-407 TEMP/WC93 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. ' N/A . RFT data will be submitted when received.. .. . . 31. LIST OF ATTACHMENTS 32. I hereby cer~:ify that the foregoing is true and correct to the best of my knowledge ' Signed :)i~l')( .J V _]_,~ /'k-~'/i ,*' Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. . Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground 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". SUB. SURFACE DIRECTIONAL $URVEY [G~] UIDANCE [~ONTINUOUS ~]OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED WELL 2A-14 ('1386' FSL, 227' FWL, S13, TllN, R8E) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71264 Logaed By; PEPPLE Date 12-FEB-1986 Computed By; CUDNEY ~ SCHLUMSERgER :',: GCT DiRECTION&L SUqVEY CUSTOMER LISTINS aRC] ~L~SK&, I~3. 2A-14 KUD:RUK NORTH SLOPE,AL~SK~ SURVEY D~TE: 02-0C~-85 EN~INEmR: P:PP~L METHgDS OF C]MPUT&TION T30L LOSATION: T~NSENTI~L- INTERO2S~TI2N: LINE&R VERTICAL SECTI]N: ~SRIZ. DIST. PR]JECTED DE¢IiTZ]N ~N9 O~TO ~ T~RGET &ZI'4JTH AZIMUTH OF SOOTH 88 ~AST AR:O ~LAS~4, I~C. 2~-14 N2RTH SLDPE,AL~SK4 C]~PjT~TI2N INTEqPCL~TED V~LJES ~2R TRUE SJB-SEA MEASURE] VERTICAL VERTIC4L ]EPT~ DEPTq DE~H O.OD 0.00 -122.00 100.00 lO0.O0 -22.00 2DO.OD 200.00 78.00 300.0~ 299.~9 17~.9~ ~O0.OO 399.99 277.99 530.00 499.99 377.99 SOO.OD 599.99 ~77.99 700.32 699.99 577.99 ~O0.OO 799.99 577.99 ~]O.~g 899.99 777.99 1000.00 999.99 977.99 1190.00 1099.~3 977.98 12DO.OO 1199.)8 1077.98 1300.0~ 1299.~8 1177.98 l~O0.OO 1399.98 1277.9~ 15DO.OD 1~99.98 1377.98 1SO0,O3 1599.93 1~77.93 1700,00 1699.56 1577.56 l~O0.OO 1798.44 1676.44 19~0.0~ 1896.~4 177%.4~ ZO00.OD 1993.21 1371.21 2100.00 2088.50 1965.60 2200.92 2183.25 2061.05 2300.00 2275.04 215~.04 2%00.00 ~367.13 2245.13 2500.00 2655.94 233~.0a 2530.00 25¢2.22 2a23.22 2700.00 2625.52 2503.62 2~00.00 2705.66 2583.65 2~DO.OD 2782.~4 2550.~4 3000.03 2855.$5 !733,45 3100.00 2925.33 2803.33 3100.00 29~4.80 2872.80 3320.DD 3054.57 2942.67 3~DO.OD 3135.04 3013.04 3500.00 3204.21 3082.21 3500.00 3272.20 3150.20 3700.00 3340.~6 3218.46 3800.0~ 3409.07 3287.07 3~30.3) 3477,~0 3355.90 CDJRS~ DEVI~TIg~ 4ZIMUTq DEG ~IN 053 MI~ 0 0 ZO 0 15 0 25 0 16 0 ZO 0 6 0 Zl 0 6 0 25 0 0 0 0 0 0 3 6 10 12 12 19 23 8 15 14 12 23 $5 N D 3 S ~2 2 S 3 2~ S 27 13 S 5 33 S 38 I S 17 31 S 27 33 S 32 23 S 2~ 3~ 16 18 20 22 25 28 35 38 41 6 20 54 ~6 ~9 58 9 S 89 35 E S ~9 5 E S 88 57 E S 89 $ E S 89 1,3 E S 39 7 E S 8~ 7 S B9 3 44 46 45 ~5 47 47 34 8 5O !7 3 S 8~ 13 E S .~9 41 E N 89 ZO E S 8:) 22 -= D4rE: 12-=EB-85 fVEX 100 FEET OF MEASURE V:RTICAL DOGLEG RECT4N SECTION SEVERIT~ NDRTH! ~EET OEG!IOO FEE 0.00 0,42 0,69 0.80 D ,97 1.10 1.32 1.38 1.75 1.84 2.09 2.14 2.15 2.18 1.78 1.73 4.38 12.52 27.10 ¢5.82 71,85 101.88 134,67 171.43 212.65 258.40 309.09 354.25 42~.17 43~.21 555.52 525.03 599.95 771.44 342.41 915.56 :)87.85 10~0.87 1133.51 1205.97 D,O0 O. 0,39 O, 0,43 O. 0,42 1. 0.41 1. O,4B 2. D,32 2. 0.4:) 3. D.4Z 3. 0.3~ 3. D,75 4. ,3.71 4. 3,97 5. ,3.69 5. 0.40 5. 2.15 5. 3.5:) 5. 3.7~+ 3. ~.13 1. 3.12 O. 3.65 2. 1.45 2. 2.45 2. 2.85 2. 3.0~ 1. 3.25 O. 3.19 O. 3.4:) 1. 3.17 1. ~.15 2. Z.~l 3. 1.05 4. 3.55 4, D .81 3. 1.47 1. 0.$:) O. 3.63 1. 3.79 3. 1.27 5. 3.67 7. ~GE 1 ~. DATE 3F SJRVEY: 02-0'T-85 KELLY BUSHINS ELEVATION: 122.00 FT ENGINEER: PEPPEL DEPTH GULAR COORDINATES HDRIZ. DEPARTURE SOUTH EAST/WEST DIST. ~ZIMUTH T FEET FE:T DES MIN · 0'3 N, 0 O0 E O O0 ~ 0 0 : 30 S 0.41 E 0.'51 S 53 S 0.58 E 0.:)2 S 47 8 28 S 0.7~ E 1.50 73 S 0.94 E 1.~6 S 28 26 33 S 1.06 E 2.56 S 57 S 1 ~8 E 2.87 S 25 22 : O1 S 1.33 E 3 · 29 S 23 45 - 28 S 1.70 E 3.59 S 27 28 76 S 1.77 E ~.15 S 25 14 E 16 S 2.02 E 4.52 S 25 52 83 S 2.,05 E 5.25 S 23 4 : lO S 2.05 E 5.50 S 22 1 : ~5 S 2.09 E 5.84 S 2~ 55 E 70 S 1.67 E 5.94 S 15 21 E B1 S 1·63 E 5.04 S 15 39 E ~+6 S 4.28 E ,5.93 S 33 7 E · ~ 13 13 S 72 58 E 84 S 12 55 : · 09 S 27.09 -_. 27.11 S :37 41 E 98 N 45.84 E 46.85 23 N 71.91 E 71.:)5 N B~ 13 E 52 N 101.9~+ E 101,:)7 '~ ~3 35 E 50 NI 134.7~ E 134.76 OT N 171,50 E 171.51 ~ 8~ 18 ../ 29 ~ 212.71 E 212.71 ~ ~) 39 E 53 N 258.45 E 253.~5 ~ 89 52 :_ 21 S 309.14 E 309.14 S 8~ 57 E g4 S 364,29 E 364.29 S 97 S 424.20 E %24,20 S ~9 44 E 94 S 488.23 E ~8.~4 S 89 39 E 95 S 556.54 E 556.55 S 39 35 E 79 S 623.05 E 523.07 S 89 33 E ~5 S 599.98 E 700.00 S 89 38 E 22 S 771.51 E 771.52 S 03 S 842.53 E 342.53 ~8 N 914.72 E :)14.72 N ~5 N 988 O~ : ~8~ O~ ~ 89 54 = 17 N 1051.10 E 1D61.10 7~ N 1133.:30 E i133.~1 ~ B9 42 : 4~ N 1205.33 E 120~.33 2~-14 K J:~AR'J~, NORTH SLDPE,ALASKA CO~PUTfiTISN DATE: 12-FEB-8$ INTErPOLaTED VALJES ~OR ~VEN 100 FEET 0= TRUE SUB-SSA ~SURED VERTICAL VERTICAL DEPTH DEPTt DEPTH 4000,09 3546,58 3424,68 4100,00 3615,84 3493,84 4ZOO,OD 3585,44 3553,44 4330.30 3755.30 3833.30 4~00,D0 3822,86 3700,86 4500,00 3888,31 3765,81 4500,0~ 3955,30 3833,30 4790,00 4022,45 3903,45 aSO0,OO ~0~0,33 3958,03 ~O0,O0 4157,90 4035.90 5000,00 4225,93 4103,93 5190,09 ~294,27 ~172,27 5220,0~ ~362,54 ~24~,54 5300,00 4431,24 ~303,24 5430.00 ~499,~0 ~377.90 5500.00 ~568.5~ ~445.59 5500.09 4637.44 ~515.44 5TDO.D~ 4706.~0 ~58~.90 5320.00 4776.77 465~.77 5~0.g0 4845.89 ~T2~.89 6gDO,OD 4917,12 ~795,12 6100,00 4987,3~ ~855.34 6ZOO,g3 505?,30 4935,30 6300.00 5127,10 5905,10 6~00,09 5196.?1 507~.71 8500,00 5256,25 51~,05 6500,33 5335,30 5213,30 57~0,00 540~,$7 5282.67 6800.9~ 5473.99 5351.99 6900.00 5543.51 5~21.61 7000,~0 5613,79 5491,79 71]0,00 5685,03 5563,03 TZgO,O0 5757.30 5635,30 7300.00 5831.~4 5709.8~ 7~O0.DD 5911.00 57~.00 7500,00 59~1,50 586~.50 7SOO.gD 5072.17 5959,17 7730.00 $153,~0 503!,~0 7820.00 5235.11 5113.11 7~$3.00 5285.59 516~.59 D~TE DF SJRVE¥: 02-3'T-85 KELLY BUSHING ELEVfiTION: 1ZZ.O0 FT 5N$I~EER: DE,DEL ,MEASURED DE~TH COURSE VSRTICAL DOGLEG RECT~N DEVIATION AZIMj'TH SECTION S:VERITY NORTH/ D~G ~N D:S MI~ ~E:T DES/lDO 46 ZZ S 85 25 E 1279,53 9,25 46 Z S 86 37 E 1353.69 0,53 45 ~5 S 85 50 E 1422,44 g,35 46 5 S 81 5 E 1493.95 1.99 48 34 S 85 3? E 1567,57 2.15 48 30 S 85 25 E 1642,60 0.63 48 5 S 85 43 E 1717,16 0,83 47 33 S 85 ? E 1791.16 O.SZ ~7 ~0. $ ~$ 35 E 186~.78 0.51 47 1Z S 87 $ ~ 193~.18 0.37 47 1 S 87 35 E Z011,44 0,38 46 51 S 98 3 5 Z084,43 0.41 46 ~7 S 88 32 E 2157,41 0,57 46 ~0 S 8) 4 5 ZZ3O,17 3.33 46 36 S 89 25 ~ 2302,87 O,Z~ 46 35 S 83 53 6 2375,53 46 17 N 89 35 E 244~.04 0.59 45 g$ ~ 89 9 E Z519,95 45 35 N 8~ 43 ~ ~591,45 ~,~1 45 Z1 ~ 8~ 19 ~ Z66Z,68 D..35 45 23 N 39 ~ E Z733.77 3.25 45 31 N ~3 5 E Z.~0&.88 9.3¢ 45 39 N 87 52 = 2875,23 0.38 45 ~7 N 87 42 ~ 2947.73 0.3~ 45 57 N ~7 24 E 301'9.39 0.30 46 13 N ~7 B E 3091.27 3.15 46 ~ N 87 15 E 3163.Z7 48 9 N 97 ? E 3235.13 45 59 N 85 52 E 3307.0~ 0.4) 45 %2 N 86 17 5 ~378.61 45 1 N 85 37 £ 3443,56 0.94 44 8 N ~5 17 : 3519.40 D.8Z 43 7 N ~4 58 E 358~,14 1.6~ 39 ~3 S ~ 51 E 3554.54 7,50 36 31 S 81 33 E 3715.37 Z.58 36 Z3 S 73 ~ ~ 3773.97 D.95 36 1 S 77 ZZ E 3,~32.07 Z.OZ 35 14 S Ti S : 3888.$2 ~.77 35 11 S 70 5~ E 3943.41 O.OO 35 11 S 73 5~ = 3977.92 3ULfiR CDDROItATES HDRIZ. DEPARTURE SOU'T~ E4ST/~EST DIST. 4ZIMJTH T ::CT~:. F::T. DES Miff 4.11 N 1278.51 E 1278.82 ~ ~ 48 E 0.32 S 1350.~0 E 135'3.9'0 ~ 89 59 E W-%1 S 1422,59 8.21 S 149~.05 : 1~94.07 S '89 41 . 12,56 S 1557,60 E 1567,65 18,82 S 1642,53 E 1542,$4 24.55 S 1717.00 E 1717.18 S 29.84 S 1790.91 E 1791.~6 34,52 S 1864,~$ E 186~,78 S :38 55 E 38,53 S 1937.80 E 1938.18 S 88 51 E 41.91 S 2011.01 E 2011.~5 S 85 48 = 44.57 S 20~3.95 E 238g.44 5 :)~ 46 ~ 46,88 S 2156,~1 E 2157,42 S 88 45 E 48.37 S 1229.55 E 2230.18 S 88 45 E 49.28 S 2302,35 E 2302,88 S 88 46 ~ 49.73 S 23?5,02 E 2375,54 S 8~ 48 E 49.52 S 2447.55 E 2448.05 S 8B 50 E 43.72 S 2519,~8 E 2519,95 S 88 53 E 47.%1 S 2591.01 E 2591.45 S 88 57 E 45.55 S 2662,29 E 2562,58 S 39 1 E 43.32 S 2733.43 E 2733.77 S 89 5 41 02 S 280~ 60 . 38,54 S 2876,01 E 2876,26 S 89 17 35,80 S 2947,57 E 2947.T'~ S 3Z,TZ S 3019,29 E 3g19,$7 S zg.z? S 3091,Z~ E 3091,35 S 8~ 27 : 25,80 S 3163,32 E 3163,43 S 22,28 S 3235,25 18 57 S 3307 1~,30 S 33?8,90 9.25 S 3449.95 E 3449.95 S 89 50 E 3,59 S 3519,93 E 3519,90 $ 89 55 E 2.26 ~ 3588,76 E 3583.75 5.85 N 3655,24 E 3555.25 ~ 8) 54 E 0.03 N 3715.97 E 3715,97 t 89 59 E 10.17 S 3774.40 e 3774.~2 S ~Z 06 $ 3832 29 E 3~32 36 S 89 40 37,19 S 388~,5~ E 3~8~.76 S 56 lg S 3943,0~ E 3~43 44 S 89 11 53.01 S 3977.34 E 3977,92 S C3MPUT~TI3:~' DATE: 12-F=B-B5 4RCO 4L~SK4, I~C. 2~-14 K3PARU<, NDRTH SLg DE ~/IL ~.SK¢. PaSE 3 DaTE 3F SdRVEY: 02-3:T-85 KELLY BUSqINS ELEV~T[3N: 122o00 FT EN~IWEER: PEPPEL [NTS.~POL~TED V~LJES F3R ~VEi 1003 FE:T 3: ME~SJRED OEP'T COJRSE VERTICAL D]GLEG RECTAN3UL~R 3EVI~TIDt aZIMdTt SECTION SEV=RITf N3RTH/SOUTH 3EG lin DES MI~ FEET D~3tlOD FEET TRUE SJB-S~ ME~SURE] VERTICAL VERTICAL ]EPTH DEPTq DE~fH -122.00 0 0 877.99 0 12 1871.21 16 26 Z733.~5 ~4 3~ 3~Z~.68 ~5 Z2 ~103.9347 1 4795,1Z 45 Z3 5491,79 45 1 $16~,~9 35 ll N O D ~ O.O0 0.00 O. S 11 50 W 2.09 0.75 4. t 9B 23 E 71.86 ).65 Z. S 8~ 1) E 555.52 2.B1 3. S 85 25 E 1279.53 0.25 ~. S 87 35 E 2011.44 D.3B 41. N 88 9 E Z733,77 0.25 43. N 85 3? E 34¢~.56 0.9~ 9. S 70 50 E 3977.92 O.OD 65. O.OO IOO0.OD 999.99 2300.30 1993.21 33~0.30 Z855.~5 5000,03 4225.~3 60DO.OD ~917.12 7030.03 5513,79 7353.00 5286.59 COORDInaTES H]RIZ. ~EP~RTURE EAST/WEST DIST. AZIMUTH FEET FE:T 3E~ MIN O0 N 0.00 E O.O0 N 0 O E 16 S Z.OZ E 4.52 S 25 52 ~ 23 N 71.91 E 71.95 ~ 88 17 '~ ~$ S 555.5~ E ~55.55 S 89 35 I1 ~ 1278.~1 E 1178.~2 N 8) 48 ~ 91 S 2011.01 E 2011,45 S $~ 48 E 32 S 2733.~3 E Z73~,77 S $9 5 E 25 S 3449.95 E 3~49.~6 S 8~ 50 : 01 S 3977.34 E 3977,92 S 89 1 ~ A~CO ~L~SKA, I4C. KJPAR'JK NC~TH SLg~E,AL~SK~ COmPUTaTION MEASURED ]EPTH DA~E: 12-FEB-85 INTeRPOLaTED V~LgES FOR EVEN 100 FE:T O: TRUE SJB-SEA VERTICAL VERTICAL DEPTH OEmTH 0,~ 0,00 -122,00 22,g0 22,D0 -100,00 122,00 122,00 D,O0 222,00 222,00 100,00 ~22,21 322,00 200,00 ¢22,21 422,00 300.00 522,01 522,D0 400,00 522,01 522,~0 50~.03 722,01 722,00 $OO,OO 322.~1 822.00 703,00 922,01 922,00 822,00 1022,01 1022,00 900,00 1122,02 1122,00 1DOD,O0 1222,02 1222,00 1100,00 1~22,02 1322,00 1202.00 1%22,02 1~22,20 1300,00 1522,02 1522,D0 1402,00 1522,12 1522,D0 1502.00 1722,52 1722,20 1600,00 1823,97 1822,D0 1700,00 1~26.25 1922,D0 1800,00 2230,10 2022,00 1902,00 2135,21 ~122,00 ~000,00 22%1,5~ 2222,00 ~100,00 2350,19 2322,00 2200,00 2%$1,3~ 2~22,00 ~300,00 2576,22 2522,D0 2400,00 2595,59 2522,00 2500,00 2320,82 2722,00 2600.00 2953.56 2822.00 ~70~.00 COJRSE VERTICAL DOGLEG DEVIETION 4ZIMUTq SECTION SEV=qITY DEG ~IN DEG ~I~ FEET O'E$/IO0 0 0 N 0 3 E 0,00 D,O0 0 22 S 58 4~ E 0,16 1,55 0 ZO S 51 58 E 0,52 ~,3~ 0 ZO S 3 27 W 0.68 0 20 S 30 10 E 0.87 0.3'9 0 19 S 3 3% W 0.96 0.23 0 14 S ~5 2~ ~ 1.18 0 11 S 1 li ~ 1.33 ~.~3 0 21 S ~5 2~ E 1.~6 D.53 0 8 S 3 ~ W 1,77 0 22 S 31 33 E 1,91 0,2~ 0 20 S 18 3~ W 2,06 0 1Z S %5 37 E 2.22 0,57 0 23 S % 12 N 2,13 0 14 S ~9 55 ~ 2.11 0.55 0 ll S 5 1% ~ 1.75 D.43 0 5~ N ~1 23 E 1.88 !.51 3 58 N 79 32 ~ 5.75 3.35 7 19 N 78 23 ~ 15,26 3,85 10 ~7 N 83 Z E 31.46 1.77 13 38 N 86 32 E 52,73 3,73 17 16 N 89 15 E 82,63 2,0B 18 %7 N 8~ 55 E 112,99 2,3~ Z1 23 S 39 2~ E 14~.54 2.49 24 18 S 88 53 E 191.58 2.7') 27 37 S 89 3 E 240,16 2.99 31 13 S 89 1~ ~ 296,54 3,03 35 0 S 89 ? 5 361,73 3,47 38 57 S 89 9 E 437,06 3.42 43 9 S 8~ 9 E 524.31 3.2~ 46 6 S 89 3~ E 524.56 1.13 45 ~3 N 89 3 E 727.92 0.50 45 19 N 88 7 E 829.29 0.90 47 9 N 89 Z] E 033.80 ~,52 46 52 N 88 29 E 10%1.17 D.71 46 17 N 87 51 E 1147.03 1.61 46 28 S ~5 51 E 1252.64 1.5~ 46 0 S 85 38 ~ 1357.05 0,43 45 39 S ~6 57 : 1459.~5 ~.2~ 4~ 33 S 85 38 : 1555.58 2.2~ 3395.19 Z922,20 2800,00 3239.03 3022,00 ZDO}.O0 3381.49 3122,00 3000.00 3526,21 3222,00 3103,00 3573,00 3322.00 3202,00 3~18.T2 3422.30 3300.00 3~54,22 3522.00 3409.00 4108.85 3622.00 3500.00 ~25Z.33 3722,00 360~,00 4398.5~ 3822,00 3700,00 D~TE 3F SJRVEY: O2-O:T-B5 KELLY BUSHIN$ ELEVATI3N: 122,00 ENGINEER: PE~PEL SUB-SE~ DEPTH NDqTH/ FEE 3ULER COORDInaTES H%RIZ, DEPARTURE SOUTH E~ST/WEST DIST, ~ZIMUTH T FEET FE~T DES MI~ FT 0,00 ~ 0,00 E 0,00 0.03 S 3,15 E 0,16 S 77 45 : 0,39 S 0,51 E 0.54 0,74 S 0.67 E 1,00 S 42 .3 :- 1,~1 S 0,85 E 1,5'5 S 31 1 1.~5 S 0.93 E 2,07 S 2,5 36 E 2.%1 S 1.1% E 2,57 S 25 15 E 2,53 S 1,28 E 2,92 S 25 59 E 3,13 S 1,~1 E 3,~3 S 2% 14 E 3.32 S 1.71 E 3.73 S 2.7 15 E 3,89 S 1,84 E ~.'30 S 25 21 E ~,25 S 1.98 E %,70 S 2~ 56 E ~,90 S 2,13 E 5.34 S 23 28 E 5,25 S 2.03 E 5,63 S Z1 7 5.%5 S 2,01 E 5,B1 S 20 16 E 5,79 S 1,55 '~ 5,~2 S 15 59 : 5.79 S 1.78 E 5,05 S 17 5 5.21 S 5.65 E 7.59 S 47 20 E 3.30 S 15.20 E 15.56 S 71 45 0.50 S 31.45 E 31.%6 S 89 5 E 1.39 N 52,75 E 52,78 ~ 88 29 2,%1 N 80,59 E 80,73 N 83 17 2.55 N 113.06 E 113.08 q 88 42 2.36 N 14~,61 E 149,52 q 39 5 1.TO N 191.65 E 191.65 q $9 29 0.82 N 240.21 E 240.22 N 89 48 0.03 S 295.59 E 295.59 S 89 59 1.DO S 351.77 E 361.77 S 3~) 50 2,16 S 437,13 E ~37.10 S 89 42 3.51 S 52~.33 E 52~.34 S 89 36 4,75 S 62%,57 E 524,59 S 8) 33 4.03 S 727,95 E 727.98 S 8~ 40 1.51 S 829.40 E 829.%0 S 8~ 53 0.58 N 933.~5 E ~33.95 ~ 8) 57 2.53 N 1041.39 E 1341.39 ~ 89 51 5.24 N 1147.33 E 1147.35 ~ 8) 41 5.59 N 1252,95 E 1252,95 ~ ~9 44 0.59 5 1357.25 E 1357.26 ~ 89 58 5,~4 $ 1459.9~ E 1~59,99 ~ $9 44 12.5~ $ 156~.61 5 156~,$6 $ ~9 32 E ARCO ALASKA, INC. 2~-14 KUmARUK CDMPUTATI]N DATE: 12-F.=B-B5 INTERPOLqTED VA' JES :IR ~VEN 100 ~EET O: TRUE SJB-SEA ~EASURE] V'ERTI$AL VERTZ'AL 4569,98 5922,00 3800,00 ~$99,3~ ~022,00 3900,00 4~67.13 ~122.00 6009.00 499~.2~ ~222.00 ~100.00 5160.57 ~322,00 ~200,00 5286,5¢ 4~22,00 ¢30~,00 5577.53 ~522.00 ~503.00 5721.53 ~722.00 ~60~.00 5854.57 6822,00 6702.00 63~6.9~ ~922,00 6169.5~ 5022,00 ~903,00 6292,5~ 5122,00 5000.00 6~36,6~ 5222,00 5103,00 65~0.B5 5322.00 5203,D0 6725.03 5~22.00 5300.00 6859.02 5522,00 5403.D0 7311.$1 '5622o~0 5500.00 7151.3~ 5?22°00 5503.00 7287.13 5822,00 5700.00 C]JRS5 VERTICAL DOGLEG ]EVI~TI}N AZIMJTH SECTION S=VERIT¥ 48 18 S 85 35 E 1679.89 ~,31 ~7 5.~ S 86 7 E 179Q.67 0,53 47 15 S 86 52 5 1899.38 4'7 2 S ~37 3% E 2007.22 9.37 ~6 ~2 S 88 1~ E 211~,05 3.37 46 gO S 8~ O E Z220.38 0,35 46 36 S 89 33 E 2325,27 D.32 46 Z3 N 89 ~1 E Z431.86 45 ~3 N ~9 ~ ~ Z535.43 ~.37 45 Z~ N ~ 25 ~ Z537.47 3,33 ~5 23 N 88 9 E 2738.70 0.23 45 36 N 8~ 1 E 2860,23 0.35 45 ~6 N ~? 45 E 2942,50 9.31 46 2 N ~7 17 5 3045.51 D.43 48 8 N 87 1~ E 3149.52 2.45 46 9 N BT 5 =. 3253.15 0.25 45 %9 N 85 29 E 3355.48 0.51 44 55 N 95 35 E 3457.73 D.95 43 %3 N 85 3 E 3554.83 }.9~ 40 17 N 89 58 ~ 3545.25 7.48 36 24 S 80 55 E 3723,37 1,40 35 15 S 7~ 35 E 3795,10 3.75 35 31 S 74 7 E 3~57.23 35 kl S 70 53 E 393~.62 O.OD 35 11 S 70 50 E 3977.92 2.03 7~13,55 59Z2,00 5803,D0 7537.89 $022,00 5300.00 7551.51 5122.00 5000.00 77~3.96 5222.00 5100.00 7~53.03 5285.59 516~.59 DATE 3F SJR~E¥: OZ-~C~-B5 KELLY 8USHIqS ELEVATION: 122.00 PT =NSINEER: PE~PEL SU)-SEA RE'TAN NDRTH/ FEE gl. 29. 36. 41. 45. 48. 49. 49. 45. DEPTH SOUTq T CDDROIN.ATES E~ST/WEST 74 81 73 53 20 5O 52 ~8 27 S 1679,77 S 1790.~2 S 1899,03 S 2005,80 S 2113,57 S 221~,87 S 2325.76 S 2~31.35 S 253~.95 S 2637.07 MDqlZ. DIST, FE:T 43.16 S 273).35 39.~3 S 2839.98 36.02 S 2942.3) 31.51 S 3045.4~ 26,~5 S 3149.55 21,37 S 3253,29 15,69 S 3355.74 8,52 S 3458.13 0.70 S 3555.40 5,B~ N 3646.95 · 14. 30. 53. 68. OE~qRTURE AZI'4UTH DES MIN 1579.91 S 89 15 E 1790.57 S 89 2 1~99.35 S 88 53 2007,23 S 8~ 48 2114,06 S 88 45 E 2220,39 S 88 45 2326,29 S 88 46 2631 85 S 8~ ~9 : 2535.43 S 2537.~7 S 8~ 59 ZZ 58 50 06 31 S 3723.95 S 3796.~5 S 3867.31 S 3934.30 S 3977.3& 2738.70 2840.25 2942,55 3'345,60 3149,55 325'), 36 3356.78 3~58.14 3555.~0 3545.95 3723.95 37'96.48 3867.43 3:)34.55 3 }77.92 S 89 5 E S 89 11 r- S 89 24 -.' 589315 S 8:) 37 E S 89 43 ~ S ~.19 51 E S ~9 59 E ~ 89 54 E S 89 58 S 8:) 46 E S 8} 32 S ,~9 1~., S ,j) I E 2~-14 KJPaRU( N3RTH SL2~E,AL~S(a C3MPUT~TI3~ D~TE: lZ-F'-3-g5 2~TE 3F SJR~E¥: OZ-3CT-85 KELLY BUS~ING ELEVaTIgN: 1ZZ.O0 FT ENGINeEr: ~E~PEL MARKER )qS~ KUPARJK C TOP ~JP~RJK ~ )~SE KgP~RJK A ~BTD TO INT=~POLaT=2 VALUES FOR ~EASJRED DE~TH SELD~ KS 73~8.00 ?~1¢.00 T~5~.OO 751~.00 7785.00 7363.00 ~HgSEN H]RIZ]NS 5869.35 5922.28 595G.~7 5083..~8 522'2.85 5285.59 ]~Ir~II= 1385' T~/D SJB-SF.~ 5~00.28 5100.~5 5154.59 SJRF~'E .OCATION ~T FSL,ZZT' FWL,SEC 15,TIlN,R RECT~NGJLAR C23RDIN NORTH/SDUT~ E~ST/ 4.03 N 35)5. 1.25 S 3,? 2~+. 5.1B S 3 ? ~+7. 3.85 S 3B~3. 3.25 S 393~. 8.01 S 3977. gS,UM ~TES JEST 15 E 57 E 3~ E KJ~RJ~ NINTH SL3>E~AL~SK~ C3MPJT~TI3N DATE: ~&g5 7 · D~TE OF SJR~EY: 02-9:T'85 KELLY BUSfllN3 ELEVATI3N: 122.00 FT ENGINEER: PEPPEL TOP BASE TOP B~SE PBTD M~RKER KUPARgK $ KUPARUK C ~UPARUK ~ KUP4RUK A ME~SJRED DEATH 5ELDW KB 73~8.00 7~1~.00 7~5~.30 751~.D0 7785.00 7853.00 S]RF 3qlGl~: 1385' FSL,Z2T' FW~,S TV:) RECT~NF~ FROM K3 S J'3- S =. a, N3qTH/ 5869.35 5747.35 5922.28 5300.28 1. 595~.47 5B32.~7 5. 5083.48 5951.%8 23. 6!22.85 5100.~5 53. 5256.59 515~.59 58. ES 1]~Tll~,R85,U~ JkAR CO2RDIN~TES S]UTq E~ST/4EST 03 N 3585.10 E 25 S 3724.15 E 18 S 37~7.57 E 85 S 38~0.3~ E 25 S 393~.87 E O1 S 3977.3~ E FINAL MEASJRE3 DE~TH 7853.00 WELL LOCAT.[.1N TRJE VERTiCaL 2~TH 5235.59 ~T.TD: S'JB-SE~ V~RTZ2AL DEPTH 5154.59 H3RI!DNT~L ]EPa~TUR5 DIST.&qCE AZIMUTH FEET D~G MZ~ 3~77.9Z S 89 I SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2A-14 FIELD KUPARUK COUNTRY USA RUN ONE BATE LOBBED REFERENCE 000071264 W ELL 2A-14 (1386' FSL, 227' FWL, S13, TllN, R8E) HORIZONTAL PROJECTION 4000 REF 13000'/1264 @ooo 2000 1 ooo - 1000 -2000 -9000 SOUTH -4000 -2000 NEST SCRLE : l/lOOO IN/FT -1000 0 ]000 2000 9000 4000 SO00 6000 EI:~T WELL 2A- 14 (1386' FSL, 227' FWL, $13, TllN, R8E) VERTICAL PROJECTION -gO00 - 1000 0 0 I000 ~000 ~000 4000 SO00 ~000 PROJECTION ON VERTICAL PLANE cji. - 271. S~i:J..EO IN VERTICAL OEPTHS HORIZ SCALE = 1/1000 IN/FT ll ' Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Well Hist°rY~' ' Samples .~ ,u~ ~o~ Core Chips Core Description Registered Survey Plat . , , ~nc~ination Surve~ , ..~ ro . t on Log Run Digitized Data ARCO Alaska, Inc...'"' Posl Otfice z 1003G0 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-30-85 TRANSMITTAL NO: 5317 RETURN TO: ARCO ALAbKA, INC. KU PAt'~U K OPERATIONS RECURDS CLERK tkTt)-i 115B P.O. UOX 100360 ANCttORAGE, AK 99518 ENGINEERING. TRANSMITTED }<ECEIPT AND KETUbRq OPEN ttOLE LIS TAPES ilERE~ITii-t{HE Till FOLLOWING ITEMS. ONE SIGNED COPY OF THIS TRANSMITTAL. AND LISTING/SCiIL/ONE COPY OF EACH PLEASE ACKNOWLEDGE 2Z-9 08-11-85 hUN %1 2Z-10 08-04-85 hUN ~1 3~,-8 87-23-85 i<UN ~1 1R-16 08-19-~ 5 RUN ~1 1R-15 08-12-85 RUN #1 1R-14 0~-06-85 KEN ~i2 2A-16 08-18-85 RUN ~1 2A-14 07-28-85 RUN ~1 2A-15 08-08-85 RUN #1 3487.0-7357.0 HEr' # 70730 3790.0-7866.0 REF 9 70712 5184.0-10065.5 REF ~ 70683 4062.5-8463.5 REF # 70754 3788.0-7442.5 REF # 70738 4602.0-9158.U REF t~ 70726 8979.0-9789.5 REF # 70753 7170.5-7871.5 REF # 70705 7420. 0-8142. 0 REF # 70731 RECEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE DRILLING W. PASIIER B. CURRIER L. JOHNSTON EXXON C1]EVRON [,~OB I-L PIIILLIPS OIL D & h NSK CLEI~K J. RATilMELL · ~ G~s Cons.. commL, smr' SOIIIO UNION K. TULIN/VAULT ^Fi.r'~ Alaqk.~. I.r ;~: ~ .e, ubsJdiar¥ ol AIlRnticR,,'hl.; ' ARCO Alaska, Inc. Post Office Bo. '0360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton- Enclosed are the July monthly reports for the following wells' 2A-13 3C-10 2Z-11 WSP-20 11-11 2A-14 1R-10 2Z-12 9-31 12-3 (workover) 3B-12 1R-11 2Z-13 9-32 12-5 (workover) 3C-8' 1R-12 2Z-WS#1 9-33 14-3 (workover) 3C-9 1R-13 WSP-9 (2) 11-10 14-5 (workover) L1-14 L2-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L120 Enclosures RECEIVED AUG ! 5 1~185 Ataska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany STATE OF ALASKA ALASKA (..__AND GAS CONSERVATION CO. .vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~ Workover operation [] _~. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-145 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 103-20040 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well at surface 1387' FSL, 227' FWL, Sec.13, T11N, R8E, UM (Approx) 5. Elevationinfeet(indicate KB, DF, etc.) 124' RKB 6. Lease Designation and Serial No. ADL 25570 ALK 2668 10. Well No. 2A-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1515 hrs, 7/20/85. Drld 12-1/4" hole to 3071'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7235'. Ran, cmtd, & tstd 7" csg. Drld 6-1/8" hole to 7863'TD (7/28/85). Ran logs. Ran, cmtd, & tstd 5" liner. PBTD = 7860'. Secured well & RR ~ 1900 hrs, 7/30/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 103'. Cmtd w/195 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3051'. Cmtd w/820 sx AS Ill & 330 sx Class "G". w/llO sx AS I. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7227'. Cmtd w/500 sx Class G. 5", 15.0#/ft, K-55, FL45 csg f/7006' - 7860'. Cmtd w/150 sx Class G. Top job performed 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/CNL/LDT/GR/SP/Cal/Microlog f/7850' - 7226' RFT - Depths are not available at this time. 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED ' 7 ~'~ 1985 Alaska Oil & Gas Cons. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. AFIch0rage NOTE--Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· ~ .... ,", ~,'-,/I TEMP/MR88 guhmit in duolicatP, MEMORANL)UM State ,of Alaska ALASKA OIL A~N~D GAS CONSERVATION CO~ISSION TO: C. ~b~tterton Chai~ THRU: Lonnie C. Smith Co~issi°ner FROM: Doug Petroleum Inspector DATE: July 31, 1985 FILE NO: D. ADA. 36 TELEPHONE NO: SUBJECT: B.O.P.E. Test Arco' s Kuparuk 2A-14 Well Permit No. 85-145 Kuparuk River Field Monday july 22, 1985..-.. I traveled from Prudhoe Bay to Kuparuk to ~i~tness th~ B~O.PiE' test at Arco's Kuparuk 2A-14 well. Tuesday julY 23_,__1985_~ The B.O.P.E. test commenced at 1:45 p.m. ~d was conclnded at 3:15 p.m. There were no failures and I filled out an A.O.G.C.C.B.O.P.E. Inspection Report which is attached. In s]ammary, I witnessed the successful B.O.P.E. test at Arco's Kuparuk 2A-t4 well. Attachment 02-00IA(Rev. 10/79) Location: Sec /~ ?7IN R ~ ~ ~,~, Drilling Con'tractor P6Fr~;f . Rig # /~'/ · . i · Date 7-. Z5-~$ Well .... /,~'~, ~,~ --//_lg Representative /~_~ JN ~ ~ Casing Set 8 ~/ ft. Representative Location, General Well Sign General Housekeeping Reserve pit : Rig ~OPE Sta6k' Annular Preventer -. Pipe Rams ~ ~":~ ~' Blind Rams ~ Choke Line ValUes H. C.R. ValveT-~'' Kill Line Valves~'~'3 Check Valve ~< Test Pressure ~; Ooo ACCUMULATOR SYSTEM Full Charge Pressure ~/~O psig Pressure After Closure {;+9~ psig 200 psig Above Precharge Attained: Full Charge Pressure Attained.-., ~ Controls: Master ~ Remote rain ~ sec min ~. sec Blinds switch cover.~ Kelly and Floor Safety ValVes. Test Results: Failures X/m~/~ ' Test Time Repair or Replacement of failed equipment to be made within. Inspector/Commission office notified. · Remarks: Upper Kelly. ,b~' Lower Kelly ~ / Ball Type ~' ! inside BOP g/ Choke Manifold No. Valves No. flanges Adjustable Chokes Hydrauically operated choke Test Pressure ~m~ Test Pressure " Test Pressure ~1 Test Pressure ~ · / Test Pressure ;/ hrs. days and Dis tribut ion orig. - Ao&GCc- CC - Operator · cc - Supervisor Inspector ARCO Alaska, Inc/'-~' Post Office ~: tx 100360 Anchorage, Alaska 99510-0360 Teiephone 907 276 1215 July 29, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska'Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2A-Pad Wells 13-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU10/L86 Enclosure If RECEIVED JUL Alaska 0il & Gas 'Cons. Commission · Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL 1~, ,: 5,960,867.69 Lot. 70° ~8' t5.5,~.2" X= 498,620.82 Long. 150000'40.220'' O.G. Elev. 86.3' Pad Elev. 91.5' I : ~, ~ FWL 2~7 FSL ~,446' ; WELL 14 Y:5,gso,~7.se Lat. 70°18'14.9519'' [ ~ ~ X=498,620.83 Long. ! 50°00'~.ZI9'' i 12 0 ~ ~ 13 O.G. Elev. 86.7' Pad Elev. 91.8' ~ Il 0 i $ ~4 FWL 227' FSLt,386' , lO0 J I ' e 15 WELL ~5 Y:5,960,74~68 Lot. 7~18'14.~8" . 9 0 ~: ~ 16 X=498,620.75 Lon~. 150°Od40.2Z~'' ~ ~ QG.Elev. 87~1' ~d E~v. 91.~' ~ FWL 227 FSL %326 'WELL t6 Y:5,960,687.66 Lot 70°18'1~.7714 ~ X~ 498,620.74 Lo~ 15~00'40.2 2~ O.G. Elev. 87.5' ~d E lev. 91.8' ~ ~ ~ FWL 227' ' FSLi,266' , 8 0 I 70 O~ 60 ; 50 I 04 I 1 i - 23 I 24 . ~;.-' LOCATED IN SECTIONS 13,14,23,24, T~tN,RSE. ~. L ¢1,¢ ~ , ~~) , HEREBY CERTIFY THAT , AM PROPERLY REGISTERED AND ' D.S.~- LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT, ALL DETAILS 14 I . ARE CORRECT AS OF D.S. 2-A ~HI R Y. ~ ARCO Alosko, Inc. ~~~~ DRILL SITE 2'A ~ CONDUCTOR AS- BUILT LOCATIONS i Dote' JULY 13, 1985 Scole' AS SHOWN ~~ /4~ ~ ~ -- ~q ..... -- Drown By: ~. ~.. Dwg' N°' NSK85-8. June 27, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2A-14 ARCO Alaska, Inc. Permit No. 85-145 Sur. Loc. 227'FWq], 1387'FSL, Sec. 13, TllN, RSE, I~. Btmhole Loc. 1316'FSL, 1074'FEL, 'Sec. 13, TllN, RSE, U~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be ~submitted on all logs 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 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to.commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to co~encing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~in KuParuk River Unit ZA-14 -2- June 27, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to com~encing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Harry W. Kugler Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~"~.. Post Office B~. ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2A-14 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2A-14, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot Diagram and description of the surface hole diverter system Diagram and description of the BOP equipment We estimate spudding this well on July 17, 1985. If you have any questions, please call me at 263-4970. Sincerely, JBK/TEM/tw PD/LI07 Enclosures Alaska Oil & Gas Cons. Commission .Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. ' -'" STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO~v, MISSION PERMIT TO DRILL DRILL E~x REDRILL [] lb. Type of well 20 AAC 25.005 SERVICE[] S~¢~A T I G R A P H I C~¢'~t?'j~ SINGLE ZONE [] MULTIPLE ZONE DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 EXPLORATORY [] DEVELOPMENT OIL [~(X DEVELOPMENT GAS [] 4. Location of well at surface 227' FWL, 1387' FSL, Sec.13, T11N, R8E, UH (Approx.) At top of proposed producing interval 1322' FSL, 1426' FEL, Sec.13, Ti1N, R8E, UH At total depth 1316' FSL, 1074' FEL, $ec.13, T11N, R8E, UH 9. Unit or lease name Kuparuk River Unit 10. Well number 2A-14 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 124', PAD 94' I ADL 25570 ALK 2668 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2A-1~well 60' ~ surface feet 16. Proposed depth (MD & TVD) 7828' MD, 6273' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1462 feet. 21 14. Distance to nearest property or lease line miles 1074' ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 45 o (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 07/17/85 2925 psig@ 80°F Surface 3347 psig@ 5792 ft. TD (TV•) Proposed Casing, Liner and Cementing Program SIZE Hole Casing 124" i b" ; i2-i/4;; 9-5i8 Weight 62.5# ~13. U# 26.0# i5.0# CASING AND LINER ~ Grade Coupling J-55 §TC -55/HF- Et~W BTC L Length 80' 2922' 7197' 803 ' MD SETTING DEPTH TOP TVD 29' I 29' 29' I 29' I 28' I 28' 7025'1 5702' MD BOTTOM TVD 109~ 109' 2951 ~1 2805' 7225~ 5845' 78281 6273' QUANTITY OF CEMENT (include stage data) ± 200 cf 718 sx AS III & 324 sx Class G 144 sx Class G blend 100 sx Class G blend 22. Describe proposed program: , ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7828 HD (6273 TVD). A 20", 2000 psi annular direr,er will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 2951' HD(2805' TVD). A 13-5/8", 5000 ~.~ psi~ RSRRA BOPE stack will be installed on the. 9-5/8" surface pipe. It will be tested upon installation and .l~"~ weekly thereafter. Test pressure will be 3000 psig. Due to gas injection at 2A Pad, Kuparuk "C" Sand pressure~l~. ~ are presently over 3500 psi (~ 6200'SS TVD) and still increasing. To drill the well safely, 7" casing will be set at 7225'MD (5845'TVD) (approximately 100' a~ve.t~e "C" Sand) The 13-5/8", 5000 psi, RSRRA BOPE stack i equipped with 3-1/2 rams will be reinstalled an~ the rams tested to 4000 psi, the annular to 3000 psi. A 6-1/8" hole will be drilled to TD. A 5" liner will be set at TD with a 200' overlap. Expected maximum surface pressure is 2925psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, (see attached sheet) Thespacebel~f~r~c~/l~sCn use /'/- -23. I hereby certify that the foregoing is true and correct to the best of my knowledge TITLE Area •ri 1 ~ ing Engi near Mud Icg required I--lYES ~NO Samples required []YES ~ CONDITIONS OF APPROVAL Permit number Approval date ' ¢~ / ~/~' 06/27/85 DATE APPROVED BY Directional Survey required I APl number ~-ES •NO 50-t0-~- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COM M I SS I ON ER DATE by order of the Commission June 27, 1985 Form 10-401 Submit in triplicate pFj~MiT TO DRILL __~ 1he well w~tL~_~ ~nnuli thr°ugh~uent ceg°rtS' · ,-ont'd~ .... long~' _~me~ - ~ on suv=~ ~rom ~__n interval= . -:ll be ~' --tion ano - _ ~. selec~ .__ fluiOS "' ---aruk formo ._~ IA-I~ ~ .-e efiec~' ,,~n.freeZ~'~ -~in the ~u~ of the .. · rem9era~u' 5rd tbg. '"~ _ ora~ed ~". _ completion _,~where down~_ including , ~, J-55~ '11 be perf ~ ~es~ed upon ~.osSings ~"~ · -.ith 5-~/2 , 9. ~_~ intervals wi ~stalled ~nu .~llboreS or ~'[,~n above ~nterval' Sele~valVe ,ill bt_'"no other cl°St~oximatelY lO~'~the liner wl~,, ~[nnulUS' %he~ ~'~ter the ~.wnhole sa~__~ There sr: ._ ~27'MD, a~v'. _ After ~uv, . o.q/B" x ~" ~ ~he suria~'_ .... laced as ~ .~_ liner ta~. . _, do~n the ~ ~ ~,.odUC ''1 be ceme~,Se~ -~-ve pit t~u'~~ ,~uid during ~ ~-~ure stimu, o~- annulUS w~.~ ~- ~veO cfi workOVer rig RECEIVED JUN 2 l 8G Alaska Oil & G~s Cons. Commission Anchorage 2000 1000 _ I 000 . 2000 _ 1000 0 1000 2000 3000 TARGET CENTER SURFACE LOCAT[ ON, 1387' FSL. 227' FWL SEC. 13. TlINi RSE i TARGET LOCATION, I : ; ; : ; 1:320' FSL. 1320' FEL .............. ~ : ..... -T'-'-:,--':-'fl -T' SEC. !3. TIIN. RSE" - i ..... "S 88 DEG 58 MINE 3734' (T.O TARGET) i · ARCO :ALASKA. INC. ' ' PAD 2A, WELL. NOt 14 PROPOSED .- KUPARUK FIELD,' NORTH SLOPE, ALASKA ..... -]c-~ '-]'-~:3 BASE PERMAFROST '-'-' KOP TVD=1462 TMD=1462 DEP=O TVD= 1 485 - ..... ~ TOP UONU SNDS TVD=1640 Tt'ID=1640 DEP=8 ..... -I$ ' =JUILD :3 DEO PER .1 oo FT . 2~ TOP 'W SAK SNDS-T- TvD-2245 THD=2269 DEP=1681 ' i · · ._ ~ ~ ....... ....... - -'K;-l':2 ' TVD=2605 TI"ID=2687.' DEP=380" ...... EOC (9 5/8 CSO PT) ' : -- - ......... : T_VD._=2805:._THD=295.1 .DEP=552 .............. . . ... : i. EL) ~ :' K-$ TVD=4465 Tt'ID,-$285 DEP=2193 - ! - . .,.:! - - ! · · · Alaska 0il & Gas'.Co~s, ' !44 ..DEG 40 --HI N :AVERAGE ANGLE '-. ?- cs~ PT ... ~ ~ ~,~OP UPPR SNDS TVD-591Z T~D-T~2Z DE ' .... ~ ............ ~ ..... '-' ~- ,TOP LOWR' SNDS-- TV'D"5999 -T~DA7442'; ............... ~ TARGET CNTR TVD~6024 TMD-~4~8 ~ ........ - . ~ ...... BASE KUP SHDS .TVD-61~ T~D=~6 ' ..................... ':~ ........ : ............... TD-(LOG PT)-~TVD-62Z~-TflD-782 .......... I I. I ..... --:- - O- i000 2000 3000 4000 . _]] ] ..... L ..... ]2 ] ............... :. VERTI CAL.;SECT I ON '- · , . _ _. 7'OO 800 I I I .............. ...... +'- :-- ~ .... _.. ARCO ALASKA, INC, : .... i ..... '.~ ' '-' ~ - , PAD 2A. WELL NO' 1~-14-15-16 PROP[ - '-: ....... ' --i ....... 2716'-T~T ..... KUPA-RUK"FIELD; NORTH-SLOPE' ALASKA .... ~ EASTHAN' WHIPSTOCK; INC. . 2643 ' NOTE' WELL PATHS EXTEND BEYOND .... .THIS-VIEWINg. WINDOW---: ............... 1 .... 1__540_ ..................... 1.~ ,.. . - _ _ 1623 · · . .............. ..y~/~'., ~ ................ ' ~Z'O-~-' '",,.- , . ' ' - ,- o~,'./- ;, ~ '~_, - ' ~,, : -'.r,..., , . 1540 ...... ...... rte ............ _~_g_ 1._ :.._]-~__._~:.: __-__L_: .... 3918 ... 4,161 3/ ll9 ~? . Surfe~e Divert. er 5ys_t.e~ 2. ~nkco Ouick c~nnect ~msy. ~" X 20" 2~0 ps~ ~oub]e z~d~e~ a~ep~r. 4. 20" 2000 ps~ ~r~]l~ng ~poo] w/~O" s~ out]et~. 2D" 2DDD pm~ ~nnu]er preven~r. 7, 2~' boil n~pp]e. .. ~intenan~e & ODermtton "-. '.. · verify ~mt ~l-1 vmlve, ~ve opene~ properly. Close ennular_preventer ~n~ bl~ a(r through ~tve~er ltne~ eve~ 12 ~ur~. o~rri~e an{ clo~e ~11 v, lve ~ u~tM dive,er _ . ... . . . .. q$" Conductor _ JUl\! , ~'- -~ Alaska Oil & Gas Oo~s. Anchorage 7 5 A~_ATCi~ C~Ac.'ri'i'Y T~5'7 I 4 2 5 IC~C)O ~':?:'·"--.·;~. , "~?-"!"::~,T!.'{~' ~.':':?,' . ': ':- · '::~:?:'·"' .... . . .~.·,:.: .,~,., . . ::,:~!:. ·..-·.1~ . ·. . .:.,·.:....===. ?·1_ ~ ·. ..... · __ -. . ·..'~:' :.1· (2)'Loc' L/~'~--. ='~;~.~- 2. Is well to be located in a defined pool ............................. "~__. _ . (e.thru 8) . 3. Is well located proper distance from property line .................. /~ . . . -' 4. Is well located proper distance from other wells .................... ~./C--__. i . ' . 5. Is sufficient undedicated acreage available in this po.ol ............ '~ 6. Is well to be deviated and is 'wellbore plat included ................ .~ ' ' . ' '. 7. Is operator the only affected PartY , ......... , ...... '. ......... ~.~...'/g,' ~ "' ~.~ ~o~':-~J* 8. Can permit be approved before ten-day wait ............ ' .... '.' ......... ~ ' (3) mdmin ~&~./ .~ W-~ 9. Does operator have a bond in force ............................ ' ...... .... (~/thru 12--7------ 10. Is a conservation order needed .... ' ................................... ' ~.~.~. ~-&L~-~ 11. Is administrative approval needed ...... ' .............. ~ .............. -- (10 and 125 12. Is the lease number approPriate ..................................... casg/F/ 'Fz , f- -Sf Is conductor string provided ........................................ (13 thru 21) .14 Is enough cement used to circulate on Conductor and surface 15. Will cement tie in surface and intermediate or production strings ... ~ ~ z 16 Will cement cover all known productive, horizons ' ~ ~ o 17. Will Surface caSing protect fresh water zones ..................... '-- 18. Will all casing give adequate 'safety in collapse, tension and burst.. 19 Is this well to be kicked off from an 'existing wellbore .............. 20. Is old wellbore 'abandonment procedure included on 10-403 21. Is adequate wellbore separation proposed ............................ ' -(22 t~u 26) (6) Add: .~~,. ~-~.~' 22. 23. 24. 25. 26. 27. Geology: Engineering: HWK ~ WVA ~. MTM ~ HJH JAL~----~. rev: 03/13/85 6.011 Is a diverter system required .... .................................... ~ Are necessary diagrams of diverter and BOP equipment$~~a~ta.c~ed72 ..... ~ i ~ Does BOPE have sufficient pressure rating- Test to~~f i~ .~v: ~-~~ . Does the choke manifold comply w/API RP-53 (Feb.78) ................... ~m~ ~g~.~ Is the presence of H2S gas probable .......................... ~ .... .. __ ~ ~-~ ~ Iq~ Additional requirements ........... . ....................... ;.'.,' .... ~ ~.8 o.~ ~R]~ ~/,;/d ..,:q Mz~a ~,'Rm'J . .,. ...~, . ~ . i~ ~ '~, - ...... ~.~ , - , , , INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE .... · Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No special 'effort has been made to chronologically organize this category of information. LLIS TAPE VER IFIC~TIO'N L!STZNG LVP 010.H02 VERIFICATION LiST!N3 PAGE I .... ,- RE:L H=4D'-R ~. L SF-RVIC: NA,N~,: ':DiT DATE :85/08/26 ORIGIN : RfEL NAME :1426'93 CONTINUATION ,~ :01 oREV!OUS R:_=L COMMENTS :LI.SRARY TAPE ~:~;: TAPE. H:AD~R ...... .,..,. SERVICE NAM; :'EDIT DATE :85/08/Z6 ORIGIN :0000 TAPE NAME :0705 CONTINUATION ~ :0t PREVIOUS TAPE COMMENTS :LIBRARY TAPE ~=~ FILE HEADER mIL ~ NA~= ::DIT SERVICE NAME VERSION # : DATE : MAXIMUM LENGTH ~ILE TYPE : PREVIOUS FILE "'" INFORMATION ,. 001 : 10.24 : RECORDS .....-,~- MNEM CONTENTS CN : ARCO ALASKA WN : 2A-1~ 'FN : KUPARUK RANG: 8E TOWN: SEC'T: 13 COUN: N.SLOPE STAT: ALASKA CTRY: USA MNEM CONTENTS Ifil INC PRES: E .~:.- ;x C 0 M M 'E N 'T S ;2.,. ~- UNIT TYPE CATE SIZE CODE I I I I I I I I I I I .i I / ! I UNI'T 000 000 015 055 000 000 006 055 000 000 008 065 000 000 002 065 000 000 004 065 OOO ,000 002 065 'OOO 000 012 0,55 000, 000 006 065 000 000 003 065 TYP'E CATE SIZE CODE ,IlI,l lJIl IIIJ l,l,II 000 000 001 065 LVP OIO.H02 VER!FIC.ATION LIST!R.$ OAG~ 2 ',' S CML U M -,- ~LASKA COM~UT!NG C~-NTF--R ~- I ELD CO PANY WELL = FieLD = KUPARUK COUNTY = NORTH SLOP~ 3DRDUGH STAT~ = ALASKA J35 NUMSER AT ,~C'S: 70705 RUN ~1~ DATE LOGG[2: 28 JUL 85 LDP: L. B. CUDNEY CASING TYPE FLUID DENSITY VISCOSITY PH FLUID LOSS 7.000" ::$ 7226' - 3IT SIZ~ = 6.125" TO 78,53' XC POLYM~ER ii.0 L~/G RM = 2.8'70 ~ `50.0 DF ¢!.0 S RMF = 2.690 @ 50.0 DF I1.0 RMC = 3.010 ~ 60.0 DF 6.7 C'3 RM '~T "~HT = 1.299 ~B 141. DF THIS DAT,4 HAS NOT,.~E~EN DEPTH SHIFTED - OVF-RL,AY~.. .. ,=iEILD PRINTS ".,..,.~::~::-~-.,. CVo, 010.~02 VE~FiCATIDN. L~STING,~ m'~G=~ . 3 HgL~ C~R~ECTi'~ -~~ _ uN-~ALiPE~ SCMLUM6ERG'ER LOGS iNCLUOE2 WITH T~IS MAGN:TiC TAPE: ,~ DUAL INDUCTION SP.H~:RICALLY :8CUSCm. L~G~ (DIL) '"-,- ::~ ~ATA AVa!LAaL~'_ ~, 7212' Tg 7~3'~'~ "' LITHO D=NSITY COMP;NS~T~n LOG (LDT) ~: CDMPENSATEO N~UTRON LJG (LOT) OA'T~& AVAILABLe: 7212' TO 7817' ~ DA'TA FORM,~T RECORD ENTRY BLOCKS TYF~; SiZE REPR CODE ENTRY 2 I 56 4 t 68 1 8 4 7.3 60 9 4 65 .lin 16 1 ,5,5 1 0 1 66 DATUM SPECIFICATION 5L~CKS MNEM SERVICE SERVICE UNiT APl AP1 ,APl APl FILE SIZE SPL REPR PROCESS iD ORDER ~ LOG TY~E, CL&SS MOD NO. COn:~ (OCTAL) DEPT ~T O0 000 O0 0 0 ,4 1 68 00000000000000 LVO 010.H02 VERiFtC.C, TI~N LISTING PAGE SFLU DiL gHMM C30 ILO DIL 3~HM O0 ILM OIL 3HMM SP DIL HV GR OiL '$,~ P ! C.~L= .~ L3T IN RHOB LOT G/C3 DRHO LDT G/C3 03 NR~T LDT RNRA L3T NPHI LDT PU pF-F LOT 30 NCNL LDT CPS O0 FUN'~. LDT CmS. nO '~SS LOT O0 QLS LOT O0 GR MLL G~PI O0 LA MLL iN O0 MNOR MLL OHMM O0 M!NV HLL OH,~M 220 120 120 010 BIO 310 28O 35O 356 ~20 000 358 330 330 O00 000 310 252 25O ...... DAT.~ D:QT RHO~ NPrtl QSS MNOR 7871,5000 SFLU -28.7~51 GR 2,4573 DRH8 35,2051 PEF 0,1025 QLS 3.2170 MiNV 11 3 · :5 5 49 8.1523 O. 1538 6.6'726 O, 0576 2. 3538 EFT P P H ! SS NOR 7800,0000 SFLU -18,8075 GR 2.5002 DRH8 35,.1562 PE'F 0.0757 qL$ 3.2170 MINV 3.5608 11B'1523 0.1401 ~,6023 -0.0103 2.3538 DEPT, SP RH3B NPHi QSS MNOR 7700.0000 SFLU -i 2 ,. ,4930 G R 2.4124 DRHO 46.6797 O, 0565 QLS 2,, 4417 MINV 3 · 3401 14. '0273 0. 0942 5. :5046 -0.0068 2.6741 DEPT SP NPHi QSS MNOR 7600.0000 SFLU -15,2715 GR 2.4436 DRHC~ 35,0586 PEF 0.0449 ~LS 4.18,43 MiNV 4.8718 97.8398 0.0430 3.9885 -0.0122 3.8655 OEPT 7500.0000 SFLU 5,7859 Oi 46 44 O1 O1 Oi Ci 02 '~I Ol O0 O0 Oi 31 30 O0 O0 O! O1 O0 ILD GR NR~T NCNL GR GR NR.~'T NCNL i:L g GR NRA T NCNL !LD GR NRAT NCNL ILS ! 88 00000000030000 I 68 00000000000000 i 68 00300000000030 1 ~2 00000000000000 i 68 00000000000000 1 68 00030000000000 i 68 00000000'300000 1 68 O0000000000OO0 I 6~ 03000000000000 i 68 0000000000'3000 1 68 03000003000000 I 68 00000000000000 I 68 0,3000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 .1 68 O00OO000000000 i 68 OOO00000000000 i 6:8 O000OOOO000000 1 68 00000000000000 1 68 O000OO00000000 2000,6875 ILM 118.1523 CALl 2,6038 RNRA .2983,5000 FCNL 1:1'9.5898 LA 3.3,225 ILM 118,1523 CALl 2.71 31 R N R A 2921. 5000 FCNL t19,589:3 LA 2.7'971 ILM 114,.0273 CALl 3,2932 RNRA 2.275.5000 FCNL 1'15.4023 LA 4,3406 iLM 9:7,8398 CALI 2,7131 RNRA 2627,5000 FCNL 99.0898 LA 6.098 4 I t M 2.9749 4.2195 2.7913 1065.6875 5.1582 3.3127 6.2351 2.8401 1028.6875 5.1882 2.89,28 6.0984 3.5,413 642,31,2.5 5.5242 4 309~ 6.3,250 2.8811 911.312~ 5.5242 5.985.1 LVP OlO.H02 VERIFICATION L!ST!NS PAG5 5 SP -23,4951 GR RHOB 2.3733 DRHG NOel 33.2520 PEF QSS 0.0269 QLS MN~R 4,7820 MIN¥ DEPT 7400.0000 SFLU SP -37.8633 GR R~OB 2.3997 DRHD NPH! 35.1074 QSS 0.0532 QLS MNOR 12.4941 MINV DEPT 7300,0000 SFLU S? -10o7795 RHO~ 2.3049 ORHO NPHI 54,5898 PEF qSS 0.0620 ~LS MNOR 1,4991 MINV DEPT 7200.0000 SFLU SP -7.1868 GR RHO5 2.2366 DRHO NPHI 63,2324 PEF ~SS -0.1592 QLS MNOR 0.3496 MINV DEPT 7170.5000 SFLU SP -0.5029 GR RHUB 2.3792 DRHO NPHI 62.1094 PEF DSS -0.0532 ~LS MNOR 0,3496 MiNV 39.964B 0,0122 3,5S81 -0.0190 6.0945 54,7617 -0.0029 7,7703 -0.0303 8.1504 1,7745 122,4023 0,0776 4,3~50~ -0,0322 1.4337 Z1.9580 78.6523 -0.35'96 95.2148 0.0117 0.0000 33.0742 $9,9648 -0.3477 54,7773 -0,0083 0,0000 GR NR~T NCNL GR ~LD GR NR~T NCNL GR ILD NRAT NCNL GR ILO GR NRAT NCNL GR ILO GR NRAT NCNL GR -:,-,- FILE TRAiL;R FILE NAME :EDIT ,001 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH :I024 ~!L~ TYPE : NEXT FILE NAME ~::;',-' mILE, HEADER ....... .,.-,- FILE N,AME : EDI'T SERVICE NAME : VER.SZON ~ D A T E : MAXIMUM LENGTH : 'FILE TYPE .: ,001 1024 89.9648 CALl 2.6155 RNRA 3023.5000 FCNL 91.0898 LA 50.3555 ILM 54.7617 CALl 2.7~55= RNRA 3123.5000 FCNL 55.4492 LA 1,4005 ILM 122.4023 CALl 3.7795 RNRA 1917,6875 FCNL 123.9023 LA 15.0801 ILM 78.6523 CAL'I 4.1570 RNRA 1~80.68'75 FCNL '79.6523 LA 13.9941 ILM 89.9648 CALl 4.0984 RNRA 1509.68'75 :FCNL '9i.0895 LA .5 · 215.5 2.8538 1059,6875 5.9773 60.355: 6.4929 3.0530 1022.8125 1,4424 7.5593 4,1215 465.1406 6.0906 2000.6875 6,4500 5.0007 295,1406 6,3132 2000,6875 6,4539 4 · 7546 317,3906 $, 3132 LVP 0!0.~02 V591=ICATIDN L!STINS PAGE PREVIOUS FILE : CONTENTS UNIT, TYPE ~rATE SiZ=~ COD= CN : ARCC ALASKA INC 000 OOO 016 065 WN : 2A-14 000 000 006 0,55 FN : KUOARUK OOC 000 008 065 RANG: 85 000 000 002 065 TSWN: llN 000 003 O0~ 065 SECT: 13 000 000 002 065 CDUN: N,SLOPE 000 ODO 012 065 ,STAT: ALASKA 000 COO JO6 055 CTRY: USA 000 000 003 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE PRES: E 000 ,000 00! 063 -'- SCMLUMB~ -'- ALASKA COMPUTING CENTER -,,'" COMPS, NY : ATLANTIC '~iCHFIELD COM~PANY WELL = FIELD : KUPARUK COUNTY = NORTH SLOP,E STATE = ALASKA LV~, 010.H~2 YE~i~C~TI~,~ ~ LiSTInG m~G~,_ 7 JO~ NUM~';R AT ACC: 70705 RUN ~1, OATE LO%CEO' 28 JUL '35 LOP: L. B. CUDN~Y CASING TYOE FLU!g DENSITY VISCOSITY LU'?D L~SS = 7.000" ~ 7226' - ~iT SIZE = 6.125" TO 7853' = XC P3LY~ER = ll.O LB/G RM = 2.870 ~ 60.0 D~ = 4!.0 S RMF = 2.690 @ 60.0 DF = 1!.0 RMC = 3.010 £ 60.0 OF = 6.7 C3 RM ~T ~HT = 1.299 ~ 141. DF ;;'-.,-.,..,..,. THIS. :2.~TA '~AS NOT 3~:N_,.. DE~TH, SHI~T:D,.. - 3VERL.~YS FIELD PRINTS -,-.,--,..,..,- .,. ............................................................................... .,..,..,..,..,..,. ,,..,..,..,..,..,..,..,..,..,..,..,..,..,..,..,..,....,..,..,." ~,,: :',.- -;1: ;;: ................ ~ .................. , ................ ~: :1: .............................. ~: ............................. :.~.- .,.. ;;! HOLE CORRECTION=CALIPeR SCH:LU~IBERGER LOGS INCLUDED WITH THIS MAGNETIC DUA'L INDUCTION SPMSRICALLY FOCUSED LOG (DZL) DATA AVAIL.ABLE: 7212' TO LITHO DENSITY COMPENSATED LOG CLOT) COMPENSATED 'NEUTRON LOG (LOT) DATA ,~V.&ILABLE: 7212' TO 7817' LVP OlO.H02 VERIF!C.aTION LISTING PAG~ ENTRY 5LOCKS TYP~ SiZE REaR CODE ENTRY 2 ! 66 0 ~ 1 66 1 8 4 73 1'2 9 4 65 .lin 0 1 56 0 DATUM SPECIFICATION BLOCKS MN.~M SERVICE SERVICE UNiT ID ORDER # OEPT CALZ SAM RHDS SAM DRHO SAM PEF SAM QSS SAM QLS SAM PT. iN G/C3 G/C3 OEPT 782t.7998 CALl PEP 5.2625 DSS DEFT 7800.2998 CALl PEF 5.7273 ~SS DEPT 7700.2998 CALl P~F. ~ 7.7781 QSS OEPT 7600.2998 CALl Pimp 3.7698 QSS APl API APl APl FILE SIZE SPL LOG TYPE CLASS MOO NO. O0 000 O0 O 0 4 1 O0 280 O1 0 0 4 1 00 350 02 0 0 4 i O0 356 O1 0 0 4 1 O0 358 O1 0 0 O0 000 O0 0 0 4 O0 000 O0 0 O 4 1 3.7268 RHO8 2..4690 0.0884 QLS 0.0020 5.1414 R~O8 2.!5237 0.1001 QLS ~0.0166 5.8757 RHO~ ,Z.3957 0.1025 CLS ~0.0342 6,3992 RHOB '2.4182 0.0527 ;~LS -0.0098 REPR PR3CESS COOE (SC'T,&L) ,58 00000000000000 68 00000000000000 58 00000000000000 88 00000000000000 68 OOO0000000, O000 58 00000000000000 8~ 00000000000000 ORH3 O. 142,6 DRHO 0.1499 DRHO 0.1343 OR'HO O. 0288 ~VP OlO.MO?_ V:A~FI"ATinN~ ~ . ~ LTST~NG~ PAGE O~PT 7500.299~ CA~i PE~ 2.9807 QSS DEPT 7400.Z998 CALl PEF 6.A°04_.~ ,~ DEPT 7300.293'~ CALl o~F 4.504~ QSS 9EPT 7200.29)3 CALl mE= 5~.0!17 .2SS 3EFT 7199.099~ CALl P;F 56.480,5 QSS 6.3562 0.0Z65 6.3953 7.7559 6.4~21 -0.1328 -0 151~ qLS ~LS R~9:3 QLS ',~L S LS 2.41 Z ~ 0.0249 2.5120 2 · 2991 2.265 9 2. 2327 0.0767 DRHO '3RHO 3.3132 0.0708 -0.4009 ...... ~iLE T,~A'rL=~' ;',:* =IL~ NAME :EDIT .001 SERVICE NANE : VERSION # : DATE : MAXIMUM L,:N~TH : 1024 FILE TYPE : NEXT EILE NA~IE : *:;: TAPE TRAILER ** SERVICE NAME :EDIT DATE :85/08/26 ORIGIN :0000 TAPE NAME :0703 CONTINUATIDN # :01 NEXT TAPE NAME : COMMENTS :LIBRARY TAPE' ....... REEL TRAILER '""" SERVICE NAME :EDIT DATE :8510.~/26 OR IG iN ,: REEL NAME :14.2.5913 CONTZNUATZON ¢¢ :0t NEXT REEL NAME ,: COM'MENTS :LIBRARY TAPE