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185-146
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: SLM 7,715.0 2A-15 2/28/2021 raineg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Noted subsidence drift tight spots 2A-15 9/6/2025 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: TAGGED APPARENT CUT IN 2-3/8" TBG @ 7740 SLM 4/15/2015 hipshkf NOTE: Chemical cuts @ 7756' and 7755' MD in 2 3/8"TBG, unable to pass through cuts. 5/18/2001 pproven NOTE: WORKOVER 5/6/2001 osborl NOTE: Chemical cut @7755' & 7758' RKB; tubing possibly severed 7/29/01 5/4/2001 lmosbor 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 30.0 104.0 104.0 62.50 H-40 SURFACE 9 5/8 8.92 30.6 3,373.3 2,788.8 36.00 J-55 BTC PRODUCTION 7 6.28 24.3 7,442.5 5,714.0 26.00 J-55 BTC TIE BACK 7 6.28 30.8 2,092.0 1,891.9 26.00 L-80 TC-II LINER 5 4.41 7,211.8 8,112.0 6,223.7 15.00 J-55 FL4S Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.3 Set Depth … 7,040.0 Set Depth … 5,426.7 String Max No… 4 1/2 Tubing Description TUBING WO 2011 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 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) 22.3 22.3 0.00 HANGER 6.000 TUBING HANGER w/ 2.38' PUP FMC GEN IV 4.500 489.4 489.4 0.66 NIPPLE 5.210 DB NIPPLE Camco DB 3.812 2,810.4 2,395.6 45.39 GAS LIFT 5.984 4 1/2'' x 1'' Camco 'KBG-2' w/ DV & BK Latch Camco KBG-2 3.938 4,391.6 3,497.6 45.82 GAS LIFT 5.984 4 1/2'' x 1'' Camco 'KBG-2' w/ DV & BK Latch Camco KBG-2 3.938 5,485.5 4,304.1 42.44 GAS LIFT 5.984 4 1/2'' x 1'' Camco 'KBG-2' w/ DV & BK Latch Camco KBG-2 3.938 6,295.9 4,897.3 43.81 GAS LIFT 5.984 4 1/2'' x 1'' Camco 'KBG-2' w/ DV & BK Latch Camco KBG-2 3.938 6,875.1 5,310.4 45.12 GAS LIFT 5.984 4 1/2'' x 1'' Camco 'KBG-2' w/ DCK-2 SOV & BEK Latch Camco KBG-2 3.938 6,919.1 5,341.5 45.00 XO Reducing 4.500 CROSSOVER 4.5" x 3.5" 3.500 6,926.8 5,346.9 45.00 SEAL ASSY 4.000 LOCATOR SEAL ASSEMBLY (+7' SEAL ASSY STICK-UP) Baker Seal Locater 3.000 6,934.1 5,352.1 45.03 PBR 5.700 80-40 POLISH BORE RECEPTICLE Baker 80-40 3.000 6,957.0 5,368.3 45.10 PACKER 5.970 FHL RETRIEVABLE PACKER Baker FHL 2.940 7,038.0 5,425.4 45.16 SEAL ASSY 4.000 LOCATOR SEAL ASSEMBLY (+ 1' SEAL ASSY STICK-UP) Baker Seal Locater 2.970 Top (ftKB) 7,040.0 Set Depth … 7,655.0 Set Depth … 5,873.2 String Max No… 2 7/8 Tubing Description TUBING WO 2001 Wt (lb/ft) 6.50 Grade n-80 Top Connection Hyd-511 ID (in) 2.99 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) 7,040.0 5,426.8 45.11 PBR 5.890 PBR Baker 4.000 7,054.2 5,436.8 44.90 PACKER 7.000 FHL Hydrostatic Packer Baker FHL 3.000 7,104.8 5,472.6 44.96 NIPPLE 3.500 DS NIPPLE w/2.813" PROFILE Camco 2.812 7,179.2 5,525.3 44.77 3.5"x2.875" 3.500 CROSSOVER 3.5" x 2 7/8", 6.5", N- 80, HYDRIL 2.875 7,650.3 5,869.6 40.10 OVERSHOT 4.125 BAKER BOWEN OVERSHOT w/ 2 3/8" GRAPPLE & PACKOFF 3.125 Top (ftKB) 7,651.0 Set Depth … 7,783.9 Set Depth … 5,972.0 String Max No… 2 3/8 Tubing Description TUBING Original Wt (lb/ft) 4.70 Grade N-80 Top Connection EUE-8rd ID (in) 1.92 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) 7,657.6 5,875.2 40.06 BLAST RINGS 2.375 BLAST RINGS (3) 1.920 7,759.7 5,953.5 39.98 LOCATOR 2.375 LOCATOR w/5.5' SEALS 1.920 7,761.5 5,954.9 39.99 PACKER 2.375 BAKER DB PACKER 1.920 7,764.5 5,957.2 40.00 SBE 2.375 SEAL BORE EXTENSION 1.920 7,777.6 5,967.2 40.04 NIPPLE 3.000 CAMCO D NIPPLE 1.810 7,783.1 5,971.5 40.06 SOS 2.375 OTIS SHEAROUT SUB 2.000 7,783.4 5,971.7 40.06 WLEG 3.000 OTIS WIRELINE RE-ENTRY GUIDE - TTL ELMD @ 7778' ON OTIS TEMP LOG 10/10/1985 2.000 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) 4,405.0 3,507.0 45.80 TIGHT SPOT SUBSIDENCE DRIFT: SPECIAL CLEARANCE RBP 3.66" X 77") TO 4405' RKB. 9/6/2025 0.000 4,418.0 3,516.0 45.73 TIGHT SPOT SUBSIDENCE DRIFT (* 3.69", 4' 1.875" WB, 3.75" TO 4418' RKB) 9/6/2025 0.000 5,525.0 4,333.2 42.56 UPR PACKER (ME) 4-1/2" PIIP w/ Anchor Latch (OAL 26.13' SN: CPP45007 / CPAL45003) 7/18/2019 2.000 2A-15, 9/7/2025 8:56:21 AM Vertical schematic (actual) LINER; 7,211.8-8,112.0 FLOAT SHOE; 8,110.5-8,112.0 FLOAT COLLAR; 8,033.5- 8,035.2 LANDING COLLAR; 7,957.3- 7,958.7 RE-FRAC; 7,857.0 RE-FRAC; 7,857.0 FRAC; 7,857.0 IPERF; 7,857.0-7,906.0 Primary – Full Bore; 7,470.0 ftKB WLEG; 7,783.4 SOS; 7,783.1 NIPPLE; 7,777.6 SBE; 7,764.5 PACKER; 7,761.5 LOCATOR; 7,759.7 IPERF; 7,691.0-7,744.0 OVERSHOT; 7,650.3 PRODUCTION; 2,092.0-7,442.5 FLOAT SHOE; 7,440.7-7,442.5 FLOAT COLLAR; 7,354.2- 7,355.9 HANGER; 7,211.8-7,223.0 FISH; 7,111.0 NIPPLE; 7,104.8 PACKER; 7,054.2 PBR; 7,040.0 SEAL ASSY; 7,038.1 PACKER; 6,957.0 PBR; 6,934.1 SEAL ASSY; 6,926.8 GAS LIFT; 6,875.1 Primary – Full Bore; 5,534.0 ftKB GAS LIFT; 6,295.9 LWR PACKER (ME); 5,550.0 TUBING LEAK; 5,538.0 SPACER PIPE; 5,527.0 UPR PACKER (ME); 5,525.0 GAS LIFT; 5,485.5 TIGHT SPOT; 4,418.0 TIGHT SPOT; 4,405.0 GAS LIFT; 4,391.6 SURFACE; 30.6-3,373.3 FLOAT SHOE; 3,371.4-3,373.3 FLOAT COLLAR; 3,283.5- 3,285.2 GAS LIFT; 2,810.4 Squeeze – Behind Casing Squeeze; 1,953.0 ftKB TIE BACK; 30.8-2,092.0 CEMENTER; 2,076.0-2,078.5 Primary – Full Bore; 34.9 ftKB CEMENT; 30.8 ftKB NIPPLE; 489.4 CONDUCTOR; 30.0-104.0 Grouting / Top-Up; 34.9 ftKB HANGER; 30.5-35.5 HANGER; 22.3 KUP PROD KB-Grd (ft) 34.89 RR Date 8/9/1985 Other Elev… 2A-15 ... TD Act Btm (ftKB) 8,131.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032004100 Wellbore Status PROD Max Angle & MD Incl (°) 46.12 MD (ftKB) 3,900.00 WELLNAME WELLBORE2A-15 Annotation Last WO: End Date 6/7/2011 H2S (ppm) 40 Date 11/20/2015 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) 5,527.0 4,334.7 42.57 SPACER PIPE 2-3/8" Spacer Pipe 7/18/2019 2.000 5,538.0 4,342.8 42.62 TUBING LEAK Tubing Leak Identified w/ LDL @ 5538' RKB 6/19/2019 3.960 5,550.0 4,351.6 42.68 LWR PACKER (ME) 4-1/2" PIIP (OAL 4.89', SN: CPP45020) 7/17/2019 2.000 7,111.0 5,477.0 44.94 FISH FISH left in hole fromm 9/16/90 - workover 5/3/01 pulled junk up @7111 5/7/2001 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) 2,810.4 2,395.6 45.39 1 GAS LIFT GLV BK 1 1,259.0 7/13/2022 10:00 0.188 4,391.6 3,497.6 45.82 2 GAS LIFT GLV BK 1 1,269.0 7/17/2022 12:00 0.188 5,485.5 4,304.1 42.44 3 GAS LIFT OV BK 1 0.0 5/31/2023 6:00 0.250 6,295.9 4,897.3 43.81 4 GAS LIFT DMY BK 1 0.0 7/18/2018 5:30 0.000 6,875.1 5,310.4 45.12 5 GAS LIFT DMY BK 1 0.0 7/17/2019 3 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,067.4 1,874.7 45.67 XO THREAD 7.000 6.276 2,076.0 1,880.7 45.57 CEMENTER 7.000 HALLIBURTON ES CEMENTER 6.276 2,088.6 1,889.5 45.47 BUSHING 7.000 TRIPLE CONNECTION BUSHING 6.276 7,957.2 6,104.9 39.88 LANDING COLLAR 5.000 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,691.0 7,744.0 5,900.8 5,941.5 C-4, 2A-15 10/7/1985 6.0 IPERF SOS 3 3/8" Ultra Jet; 60° PH 7,857.0 7,906.0 6,028.0 6,065.6 A-3, 2A-15 10/7/1985 6.0 IPERF SOS 3 3/8" Ultra Jet; 60° PH 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) 7,857.0 7,906.0 1 FRAC 10/17/1985 0.0 0.00 0.00 7,857.0 7,906.0 1 RE-FRAC 6/30/1990 0.0 0.00 0.00 7,857.0 7,906.0 2 RE-FRAC 5/8/1998 0.0 0.00 0.00 1 Scale Inhibitor 4/2/1997 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 34.9 3,373.0 34.9 2,788.7 Primary – Full Bore Lead 342 bbl 12.2 ppg Arctic Set III + Tail 72 bbl 15.8 ppg Class G... Conductor pipe loose and sliding down hole. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 34.9 109.0 34.9 109.0 Grouting / Top -Up Top Job 80 sx Arctic Set I **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 5,534.0 7,442.0 4,339.8 5,713.7 Primary – Full Bore Tail 102 bbl 15.9 ppg Class G **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 7,470.0 8,112.0 5,734.1 6,223.7 Primary – Full Bore Tail 31 bbl Class G ^^Csg OD=5 1,953.0 3,371.0 1,795.0 2,787.2 Squeeze – Behind Casing Squeeze Top Job 41.5 bbl Arctic Set I + Tail 58 bbl Arctic Pack -LW **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 30.8 2,078.5 30.8 1,882.4 CEMENT 6/2/2011 2A-15, 9/7/2025 8:56:22 AM Vertical schematic (actual) LINER; 7,211.8-8,112.0 FLOAT SHOE; 8,110.5-8,112.0 FLOAT COLLAR; 8,033.5- 8,035.2 LANDING COLLAR; 7,957.3- 7,958.7 RE-FRAC; 7,857.0 RE-FRAC; 7,857.0 FRAC; 7,857.0 IPERF; 7,857.0-7,906.0 Primary – Full Bore; 7,470.0 ftKB WLEG; 7,783.4 SOS; 7,783.1 NIPPLE; 7,777.6 SBE; 7,764.5 PACKER; 7,761.5 LOCATOR; 7,759.7 IPERF; 7,691.0-7,744.0 OVERSHOT; 7,650.3 PRODUCTION; 2,092.0-7,442.5 FLOAT SHOE; 7,440.7-7,442.5 FLOAT COLLAR; 7,354.2- 7,355.9 HANGER; 7,211.8-7,223.0 FISH; 7,111.0 NIPPLE; 7,104.8 PACKER; 7,054.2 PBR; 7,040.0 SEAL ASSY; 7,038.1 PACKER; 6,957.0 PBR; 6,934.1 SEAL ASSY; 6,926.8 GAS LIFT; 6,875.1 Primary – Full Bore; 5,534.0 ftKB GAS LIFT; 6,295.9 LWR PACKER (ME); 5,550.0 TUBING LEAK; 5,538.0 SPACER PIPE; 5,527.0 UPR PACKER (ME); 5,525.0 GAS LIFT; 5,485.5 TIGHT SPOT; 4,418.0 TIGHT SPOT; 4,405.0 GAS LIFT; 4,391.6 SURFACE; 30.6-3,373.3 FLOAT SHOE; 3,371.4-3,373.3 FLOAT COLLAR; 3,283.5- 3,285.2 GAS LIFT; 2,810.4 Squeeze – Behind Casing Squeeze; 1,953.0 ftKB TIE BACK; 30.8-2,092.0 CEMENTER; 2,076.0-2,078.5 Primary – Full Bore; 34.9 ftKB CEMENT; 30.8 ftKB NIPPLE; 489.4 CONDUCTOR; 30.0-104.0 Grouting / Top-Up; 34.9 ftKB HANGER; 30.5-35.5 HANGER; 22.3 KUP PROD 2A-15 ... WELLNAME WELLBORE2A-15 WELL LOG TRANSMITTAL 9905784923 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2A-15 Run Date: 7/19/2019 185146 31199 September 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-15 Digital Data in LAS format, Digital Log Image file RECEIVED 1 CD Rom 50-103-20041-00 SEP 12 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: 212LIq Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS a � E JUL 29 21319 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown El Performed: Suspend El Perforate El Other Stimulate El Alter Casing E] Change Approved Program ❑ Plug for Redrill ❑erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing Patch ❑� 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 185-146 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20041-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 2A-15 ADL0025570 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,130 feet Plugs measured None feet true vertical 6,238 feet Junk measured None feet Effective Depth measured 0 feet Packer measured 7, 5550, 6927, E feet true vertical 0 feet true vertical 5, 4352, 5347, 4 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 feet 15 104' MD TIE BACK 2,061 feet 6 2,092' MD SURFACE 3,343 feet 11 3,373' MD PRODUCTION 7,418 feet 6 7,443' MD LINER 900 feet 7 8,112' MD JEWELERY TYPI MD '-pth MD&TVD feet Composite Tubing (size, grade, measured and true vertical depth) 2.411 N-80 7,783' MD 5,971' TVD Packers and SSSV (type, measured and true vertical depth) UPR PACKER (ME) - 4-1/2" PIIP W/ AN 5,525' MD 4,333' TVD SPACER PIPE - 2-3/8" SPACER PIPE 5,527' MD 4,335' TVD LWR PACKER (ME) - 4-1/2" PIIP (OAL , 5,550' MD 4,352' TVD SEAL ASSY - LOCATOR SEAL ASSEM 6,927' MD 5,347' TVD PBR - 80-40 POLISH BORE RECEPTIC 6,934' MD 5,352' TVD 12. Stimulation or cement squeeze summary: PACKER - BAKER FHL RETRIEVABLE PACKER 6,957' MD 5,368' TVD Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (required per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 4 Contact Name: Jan Byrne / Dusty Feeborn Authorized Name: Jan Byrne Contact Email: N1617@conocophillips.com Authorized Title: Well Integrity Complicance Specialist Contact Phone: 907-659-7224 Authorized Signature: � Date: 7/25/19 v*T[ `7/f// 9 ,Ito%�tilr� R MS�UL 312019 Form 10-404 Revised 4/2017 Submit Original Only July 25, 2019 Commissioner Chmielowski Alaska Oil & Gas Conservation Commission 333 West 7w Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 2A-15 (PTD 185-146) for tubing patch repair. If you need additional information, please contact us at your convenience. Sincerely, /�L �� Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 SWELLS TEAM CQr0xdFh84x 2A-15 DESCRIPTION OF WORK COMPLETED SUMMARY Summary FAAr passing a compliance CMIT TxIA the well exibited TxIA communication whi e as setting the new GLD. Diagnostics culminated in an LDL identifying a leak in the 538'. A retrievable 4.5", -31' OAL, Paragon 2 Packer patch was set over the tubing ,.,hfrh nnssina MITs were performed. Pertinent well work is copied below. LOGGED TEMPERATURE SriNNCK w� - • •• -- TBG @ 5538' RKB TIE INTO TBG TALLY 6/6/11 STATION STOPS @ 5537'8,554T RKB, U - TUBE FOR FREEZE PROTECT, PULLED 3 1/2 AVA CATCHER ON CA -2 PLUG @ 7105' RKB, ATTEMPT TO EQUALIZE CA -2 PLUG @ IK PLUG @ 7105' RKB RECOVER RUBBER FROM HO HOLE FINDER RAN ON 5 233AI9ENT0 PULLED 4 1/2 CATCHER ASSEMBLY @ 6919' RKB, PUMPED 125 BBLS INHIBITED SEAWATER W145 BBLS DIESEL FREEZE PROTECT, SET 4 1/2 CATCHER ASSEMBLY @ 6919' RKB, SET 1" DV @ 6875' RKB, PULLED 4 1/2 CATCHER ASSEMBLY @ 6919' RKB, SET LOWER 3.76" P2P PACKER @ 5550' RKB (ME) (OAL 4.89'/ SN: CPP45020), CMIT TBG x IA 2500 PASS. PRE CMIT T/I/0= 20012010, (3.2 BBLS), PRESSURE UP, T/1/0= 9 59 5 /7 3 5 010. 15 MIN T/1/O= 245012275/0 (75/75), 30 MIN T/1/0=2420/2250/0 (30/25) 07/18119 PULLED 4 1/21 I s t to i i vv�- P2P SPACER ANCHOR LATCH @ 5525' RKB (ME) (OAL 26.13'/ SN: CPP45007 CPAL45003), SET 4 1/2 TTS TEST TOOL IN UPPER 3.76" P2P @ 5525' RKB, MIT TBG PASS ING DV PCMIT TBG x IA PASS, PULLED V EXTENDED ORT) @ SAME. MIT TBG 2500 PASS, PULLED 4 1t/2 TTS T ST TOOL @ 525'5485'RKB, SET1RKB. (1/4" COMPLETE. CMIT TAA: 2 BBLS TO PRESSURE UPT/1/0=2600/2500/0,15MiNT/1/0=2600,2450,0,30 MIN T/1/0= 2600,2445,0 MITT: PRESSURE T/1/0= 2350/250/0, BUMP UP (.25 BBLS) T/1/0= 2575/255/0,15 MIN �wn-9555/955/0- 30 MIN T/1/0=2655/25510 LEMEM: UPR PACKER SPACER TUBMG LM PACM£F LINER:13f1lB.M.- .En TEMP KUP PROD WELLNAME 2A-15 WELLBORE Mex Angle &MD 2A45 TO ✓ conQCp�11ll1P5 AlvsMs. Uln Well Attributes IKUPA UK RI RUN All.PA 92W4 PRO sIRWs ML IRK.) ntl I? s90000 I 1 All. -MW AV, 01911985 LEMEM: UPR PACKER SPACER TUBMG LM PACM£F LINER:13f1lB.M.- .En TEMP WELL LOG TRANSMITTAL 4905784923 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper (MFC) and Leak Detect Log: 2A-15 Run Date: 06/19/2019 and 06/20/2019 3106 1 July 19, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 2A-15 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20041-00 RECEIVED AUG 0 5 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 0 FRS—ANC@halliburton.com Date: D6,�7-10�11 q Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 26, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Free Point Record / Tubing Cut Record / Perforating Torch Recorc Run Date: 5/24/2011 - 5/25/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -15 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20041 -00 g .i S P Y PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: tf Signed: j/itiLj._,, • WELL LOG TRANSMITTAL II . PROAc1ivE DiAgNOSric SERVICES, INC. To: AOGCC Christine Mahnken } t;Tg ) ! . "% (i "I_ Z(,'!. 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 attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Correlation Log 02- Jun -11 2A -15 CD 50- 103- 20041 -00 lcl ?33 2) Signed : LP. (I L/ Date : 3 6 !� l l ' Print Name: 1 I a— L_. 3k14...,1_ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E - MAIL : PDSANCHORAGEaMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\ Distribution\ TransmittalSheets \ConocoPhillipsTransmit.docx / S C — ) Y( STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well Plug Perforations r Stimulate r Other r Alter Casing r Pull Tubing l FFrforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Fbrf orate r Re -enter Suspended Well r' 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j;� Exploratory r . 185 - 146 3. Address: 6. API Number: Stratigraphic r Service f P. O. Box 100360, Anchorage, Alaska 99510 - 50 - 103 - 20041 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25570 ` - 2A - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8130 feet Plugs (measured) None true vertical 6238 feet Junk (measured) 7111 Effective Depth measured 8034 feet Packer (measured) 6957, 7054, 7761 true vertical 6163 feet (true vertucal) 5368, 5437, 5955 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 104 104 SURFACE 3343 9.625" 3373 2789 PRODUCTION 7418 7 7442 5714 LINER 900 5" 8112 6224 j t.1 i ,` /b', i'tr� +r1 y:" �? i r i Perforation depth: Measured depth: 7691'- 7744', 7857-7906' ; 1 ,h.' i .. True Vertical Depth: 5901'- 5942', 6028' -6066' 4' -y ti.+ n s ' ' �4 `r i. ' / ` r 4, O , Tubing (size, grade, MD, and ND) 4.5, 3.5, 2.375, L -80, N -80, 7040, 7655 MD, 5427, 5873 TVD •34n L Packers & SSSV (type, MD, and ND) PACKER - BAKER FHL RETRIEVABLE PACKER @ 6957 MD and 5368 TVD r ! 4'!'7J, /S.j PACKER - BAKER FHL HYDROSTATIC PACKER @ 7054 MD and 5437 TVD On PACKER - BAKER DB PACKER @ 7761 MD and 5955 ND NIPPLE - 4 1/2" x 3.812" Camco "DB" Nipple @ 489 MD and 489 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation 1516 6007 4419 -- 288 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development IV -' Service r Stratigraphic r 15. Well Status after work: Oil'; Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. 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: f 310 -434 ✓ Contact Erik Nelson @ 263 -4693 Printed Name E Nel O Title Wells Engineer Signature ,� Phone: 263-4693 Date // �� / � • Form 10-404 Revised 10/2010 B��s JUL 13 2011 Sub mit Original Only J KU P 2A -15 Ifr, Pyjl „' C�oPbilhi^' II.._Att r ibutes Max Angle & MD TD `t % Wellbore API/UWI Field Name Well Status Inc! r) MO (ftKB) Act Btm (ftKB) _ -- 501032004100 KUPARUK RIVER UNIT _ PROD_ __ 461 3,900.00 8130.0 Comment H25 (ppm) Date Annotation End Date KB (ft) Rig Release Date .. ?'1C+t°° r SKkiiikrl... SSSV: NIPPLE 45 1/17/2010 Last WO: I C d 5!3/2001 34.89 8/9/1985 • :, . Ara+at' <. AnnolBt Depth (ftKB) End Dale Annotation Last Mod ... End Date Scale'r496800 Last Tam Rev Reason: WORKOVER _ _.,,_ __ _ _ _ _ ninam 6/18 /2011 Casing Strings HANGER, 22 'ate r'" Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ...'String Top Thrd CONDUCTOR 16 15.060 30.0 104.0 104.0 62.50 H y (f.. Casing Description String 0... String ID ... Top (ftKB) set Depth K. - Set Depth (TVD) ... String Wt.. String ... Suing Top Thrd SURFACE _ 95/8 8.921 30.6 3,373.3 2,788.8 36.00 J -55 BTC C asirg Description S tri ng 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd P ROD U CTIO N 7 6.276 24.3 7,442.5 5,714.6 26.00 J -55 BTC •r De - -- .. _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (TVD) ... String Wt... String ... String Top Thrd - =- TIE BACK 7 6.276 30.8 2,092 0 1,891.9 26.00 L - 80 TC - II Illir Casing Descuption String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR, LINER 5 4751 7271.8 8,172.0 6,2237 15.00 J FL4S 30-104 Liner Details Top Depth'. NIPPLE, 489 %.. (ND) Top Inc! Nom,. '*:'' Top (RKB' (ftKB) ( °) Item Description __. Comment_ ID(in) : j 7,211.8 5,549.0 44.96 HANGER BAKER LINER HANGER & TIE BACK RECEPTACLE 5.000 X F Tubing Strings Tubing Description ( String 0... 'String ID Top (ftKB) Set Depth (i Set Depth (ND) .. String Wt... String ...'String Top Thrd TUBING 45"x35" ' 41'2 3958 L - _223 I 7,040.0 I 5,426.7 .... I 1260 L80 . I _ IBTM TIEBACK, F 31 -2.092 - -_ _ -_ ..__ Completion Details GAS LIFT, C - Top Depth 2,810 (TVD) Top Intl Noml... Top (ftKB) (RKB) (1 Item Description Comment ID (in) 3 22.3 22.3 -1.17 HANGER FMC Gen IV 11 "X 4.5" Tbg Hgr with 2.38 -ft Pup 4.500 ' a - 489.4 489.4 0.66 NIPPLE 4 12" x 3.812" Camco "DB" Nipple 3.812 SURFACE, 6,919.1 5,341.5 44.97 XO Reducing 4 1/2" IBT Box X 3 1/2" EUE 8rd Pin X0 3.500 31 3.373 - 6,926.8 5,347.0 45.00 SEAL ASSY Seal Assembly Locator (+ 7 41 Seal Assembly Stick -up) 3.000 GAS UFT. 6,934.1 5,352.1 45.03 PBR 80-40 Polish Bore Receptacle 3.000 r ,: , z' 4.392 6,957.0 5,368.3 45.11 PACKER Baker FHL Retrievable Packer 2.940 741 7,038.1 5,425.3 44.87 SEAL ASSY Seal Assembly Locator (-r 1 -9 Seal Assembly Stick -up) 2.970 GAS LIFT, • Tubing Description String 0... String ID ... Top (RKB) S et Depth (8... Set Depth (TVD) ... String Wt... Slung ... String Top Thal 5.486 2 7/8 2.992 7 040.0 L _ 7 655.0 j 5,873.1 I 6.50 n -80 Hyd -511 Completion Details .iillIti 'Top Depth GAS61� , _ (ND) Top Inc! Nomi... 1 ) Top (ftKB) (ftKB) (°) Item Description _ Comment ID (in) 7,040.0 5,426.7 44.87 PBR BAKER PBR 4.000 gar GAS LIFT, _ 7,054.2 5,436.9 45.08 PACKER BAKER FHL Hydrostatic Packer 3.000 6.875 - `. - .. 7,104.8 5,472.6 44.96 NIPPLE CAMCO DS NIPPLE w/2.813" PROFILE 1.810 AMU 7,145.0 5,501.1 44.86 SLOTTEDJT 2.992 7,179.2 5,525.3 44.77 X0 Reducing CROSSOVER 3.5" x 2 7/8", 6.5", N -80, HYDRIL 2.875 IF SEAL ASSY, - - 7,650.3 5,869.5 39.61 OVERSHOT BAKER BOWEN OVERSHOT w/ 2 3/8" GRAPPLE & PACKOFF 3.125 s, PBR, 6,934 934 Tubing Description String 0... String ID...ITop (ftKB) 'Set Depth (f... Depth (Ivo) .'String Wt... String ._'String Top Thnl PACKER, 6,957 - -- - TUBING Original 2 3/8 1 920 7,651.0 7783-9 5,972 0 4 70 N-80 EUE 8rd Completion Details Top Depth' SEAL ASSY, _ ' (ND) Top Inc' 7,038 `s-- Top (ftKB) (98(8) ("I Item Description Comment ID (in) PER, 7.040 --- ---- " - _ 7,657.6 5,875.1 39.64 BLAST RINGS Chemical cut @7755'&7758' RKB 1.920 PACKER, 7,054- .- . _ . _ "_ ::::: 7,759.7 5,953.5 39.98 LOCATOR LOCATOR w /5.S SEALS 1.920 fit I 7,761.5 5,954.9 39.99 PACKER BAKER DB PACKER 1.920 NIPPLE, 7,ms -- - - - - -- 7,764.5 5,957.2 40.00 SBE SEAL BORE EXTENSION 1.920 i 7,777.6 5,967.2 40.04 NIPPLE CAMCO D NIPPLE 1.812 7,783.1 5,971.4 40.06 SOS OTIS SHEAROUT SUB 2.000 FISH,7,111 - ,... -( 7,7834 5,971.7 40.06 WLEG OTIS WIREUNE RE -ENTRY GUIDE - TTL ELMO @ 7778' ON OTIS 2.000 TEMP LOG 10/10/1985 11 Other In Hole fWireline retrievable plugs, valves, pumps fish, etc,) Top Depth (TVD) Top Intl Top(ttK8) (ftKB) ( ° ) Description Comment Run Date ID(in) ' 7,111 5,477.0 44.94 FISH FISH left in hole Location Unknown JUNK LEFT IN HOLE; 5/7/2001 From 9/16/90 - workover 5/3/01 pulled junk up to new level @7111 PRODUCTION,__ erforations & Slots 2.092 - -- - --- shot Top (8110) Btm (TVD) Dens T RKB) Blot (9103) (RKB) (RKB) Zone__ Date (sh••• T • Comment OVERSHOT, _ ■ # 7,691 7,744 5,900.8 5,941 S 5 A - 3, 2A - 15 ,10/7/1985 6.0 IPERF SOS 3 3/8" Ultra Jet; 60 deg. phasing OVER= r C-4, 110/7/1985 6.0 IPERF SOS 3 3/8" Ultra Jet 60 deg phasing IPERF,_ 7.69,4 End Date 7,906 6,028.0 C,O656i 2A -15 _ - -. ral & Safety l .744 Y it : Notes: Gene Annotation It 5/4/2001 NO I Chemical cut @7/55' & 7758' RKB; tubing possibly severed 7/29/01 I LOCATOR' i iltIS Mandrel Details 7.760 Top Depth Top 1 1 1 Port PACKER, 7,761 °?'" (TVD) Inc' OD 1. Valve Latch Size TRO Run SBE, 7,764 _ a Stn Top (ftKB! (ftKB/ (% Make Model (inl Sent Type TYpe ( (psi) Run Date Com... 1 2,810.4 2,395.5 4534 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 6/62011 1 2 4,391.6 3,497.6 45.88 CAMCO 1080 -2 11 GAS LIFT DMY BK 0.000 0.0 6/62011 NIPPLE, 7,778 - • 3 5,485.5 4,304.1 42.44 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 6/6/2011 1 *1 sos, 7,783 iu , • - 4 6,295.9 4,897.3 43.81 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 6/6/2011 WLEG, 7.783 - f` ` .. 5 6,875.1 5,310.4 45.12 CAMCO KBG-2 1 GAS UFT SOV BEK 0.000 0.0 6/6/2011 IPERF, - 7,857 -7,906 ... - .. LINER, 7, 8,112 N I TD, . -- TD, 8,130 -"- - • KU P • 2A -15 C ` •drps . e . MC. - KB - Grd (ft) Rig Release Date ••• 34 -89 8/9/1985 Wel .., d>1�411 PM ..._r «r . —.. _. - __. _._.. __._.. ___.___. _ —_ _ ____ ___ Scale Inh®Bn, ° Notes: General & Safety HANGER, 22 r End Date Annotation , If' 5/18/2001 NOTE: Chemical cuts @ 7756' and 7755' MD in 2 3 /8"TBG, unable to pass through cuts 5/9/2006 NOTE: WAIVERED WELL IA x OA x OOA - PROD CSG x FORMATION COMMUNICATION 5/102010 NOTE: TUBING LEAK FOUND @ 6366' ON 0.5 BPM LDL 9/102010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 CONDUCTOR, 30 -104 Mr NIPPLE, 489 - fift A TIE BACK, A0K, 31-Z092 GAS LIFT, Itial 2,810 1 SUACE, 31 - GAS LIFT, .11F. 4,392 r� ril GAS LIFT, 5,/136 L ■■r` GAS LIFT, _ _ 6,296 it GAS LIFT, _ 6,675 SEAL ASSY, "- 6,927 - - '-.. PBR,6,934 PACKER, 6,957 SEAL ASSY, 7,038 S-` - ' - PBR,7,040 — PACKER, 7,054 - -- . NIPPLE,7,105 '— '— -- n fg I FISH, 7,111 — __- + 4, Ma Ir PRODUCTION, 2,092 -7,442 if OVERSHOT. 1 :..1 7,650 IPERF._ - ---- .., ._. 7,691 - 7,744 itBK I LOCATOR._ 7,760 IF PACKER, 7,761 SBE,7,764 -- -' _ -- Sifk NIPPLE, 7,778 SOS, 7,783 _ — __ — _ . - - WLEG,7,783 - ' 7. IP]E,I 85 7 -,906 1 1 L fI LINER, 7,21 1 1. L INER, TD, 8,130 • ConocoPhitlips Time Log & Summary WelAnew Web Reporting Report Well Name: 2A - 15 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/22/2011 8:00:00 AM Rig Release: 6/10/2011 3:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/22/2011 24 hr Summa Road rig from 2T -Pad to 2A -15 and spot rig over 2A -15. Accept Nordic Rig 3 @ 08:00 hrs on 5- 22 -11. RU and Spot auxiliary equipment. Load pits with 9.8 ppg Brine. Circulate well with 250 bbls 9.8 ppg brine. Monitor well fro flow. Install TWC, ND Tree and BOPE. Fill stack and RU Test equipment. Attempt to conduct Initial BOP test at 250 / 3,500 psig. Found to have problem with TWC. 05:00 08 :00 3.00 MIRU MOVE MOB P Move Rig From 2T -14 to 2A -15. Spot Rig Over Well. Accept Rig @ 0800 hrs. 08:00 11:00 3.00 MIRU MOVE RURD P Pull Nordic 3 over 2A -15 and set down. Accept Nordic rig 3 at 08:00 hrs on 5- 22 -11. Berm up,spot equipment, spot and hook -up high line trailer,spot and hook up open top and kill tank. Load fluid and weight up to 9.8 ppg. 11:00 14:00 3.00 COMPZ WHDBO PULD P PJSM. P/U lubricator, test void between master valve and otis connection on lubricator. Lub out BPV and UD Lubricator. Initial Pressure: IA -600 psi / OA -50 psi / TBG -430 psi. 14:00 16:30 2.50 COMPZ WHDBO KLWL P R/U Hoses and treating iron to Kill Well. PT iron to 250/3500 psi and hold for 5 mins. Call DSO and Kuparuk security for gas venting operation. Start circulating 9.8 ppg brine down tubing talking return up IA at 3 bpm, 190 psi, check flow to kill tank, good returns, increase pump rate to 6 bpm, 580 psi. Pumped 250 bbls,shut down pump and monitor well for 30 mins. FCP =1050 at 6 bpm. Final Pressure: IAP -0 / OAP -20 / FTP -0. 16:30 17:30 1.00 COMPZ WHDBO MPSP P Install Two-way check valve. 17:30 21:00 3.50 COMPZ WHDBO NUND P ND Tree,stack, and NU I8OP,stack. 21:00 00:00 3.00 COMPZ WHDBO BOPE P Rig up test equipment, t=ill stack. Attempt to test BOPE 250 / 3,500 psi. Problem at well head 05/23/2011 Attempt to Pull TWC, Recover TWC and Install BPV. Open ram cavities and clean same. Break BOP at TBG spool and clean debris off TBG hanger. NU BOPE and Shell test. Call out AOGCC for witnessing of test. Conduct Initial BOP Test. 00:00 01:00 1.00 0 0 COMPZ WHDBO BOPE T Continue to Attempt to get solid BOP Test Page 1 of 18 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 05:30 4.50 0 0 COMPZ WHDBO MPSP T Attempt to recover TWC - not able to engage profile after multiple attempts. Wash hanger and continue to attempt to engage - no luck. Suck fluid out of stack with hose inside of TBG hanger top. Attempt to engage and was successful. Pull TWC and found seal missing and metal filings in profile, Reinstall 2nd TWC and conduct test - good test. After further discussion, decision was made to set BPV and open all ram cavities. Clean and wash out ram cavities, break flange at TBG spool and remove debris from off top of TBG Hanger. 05:30 06:00 0.50 0 0 COMPZ WHDBO MPSP T install BPV 06:00 09:00 3.00 0 0 COMPZ WHDBO BOPE T Open all ram caities and clean out same. 09:00 12:00 3.00 0 0 COMPZ WHDBO BOPE T PJSM. N/D BOPE stack, Clean Hanger, Install Blanking Plug, 12:00 14:30 2.50 0 0 COMPZ WHDBO BOPE T PJSM. N/U BOPE 14:30 15:00 0.50 0 0 COMPZ WHDBO BOPE T Shell Test BOPE at 250 / 3,500 psi - Good Test, Call out AOGCC Rep. 15:00 22:00 7.00 0 0 COMPZ WHDBO BOPE T Continue to Test BOPE at 250 / 3,500 psi - when AOGCC Rep arrived. blanking plug failed, replace ball and make up into hanger threads with tongs. 22:00 00:00 2.00 0 0 COMPZ WHDBO BOPE P Continue to conduct initial BOP Test 250/3500 psi. on blind rams, LPR's, UPR's and Annular with 4 1/2 Test Joint. UPR's failed. PT hydrualic and manual chokes - Hydrualic failed. Tear down and found choke seat to be shattered. X5/24/2011 Continue to conduct initial BOPE test. Pull blanking plug and BPV. Unland TBG and Attempt to pull seals from PBR at 7,040 -ft. No Luck. RU E line, Run free point, indicates to be free to packer. 00:00 01:30 1.50 0 0 COMPZ WHDBO BOPE P PT hydraulic choke - good test. Continue to test LPR's, and Annular with 3 1/2 Test joint. Conduct draw down: System pressure - 2,950 psi, Pressure after closure - 1,900 psi, 200 psi gain - 16 seconds, Full pressure was re- gained in 87 seconds, N2 - 4 bottles at 2,100 psi. Test was witnessed by Chuck Scheve. 01:30 02:00 0.50 0 0 COMPZ WHDBO SFTY T Held PJSM on opening doors and changing out ram packers 02:00 04:00 2.00 0 0 COMPZ WHDBO BOPE T Open up Upper ram doors and pull VBR's. Change out ram packers, top seals and door seals. Page 2 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:30 1.50 0 0 COMPZ WHDBO BOPE P Test UPR's at 250/3,500 psi with 3 1/2 and 4 1/2 Test joints. - Good test. Pull blanking plug and BPV. Total BOP Test time = 32.5 hrs. 05:30 07:30 2.00 0 0 COMPZ WELLPF THGR P Make Landing pup joint and Screw into Top drive, Set 20k Top drive wt down on hanger and BOLDS, Pull _ up to 170k before hanger unlanded, then pulled up to 170k max pull within 41 inches of movement. Which was 45k over calculated string wt. Made several attempts to pull seals free with no luck. Made decision to mix up 6% safe lube in KWF and reverse circulate down hole to help with wall friction. 07:30 09:00 1.50 0 0 COMPZ WELLPF CIRC P Mix safe lube into mud pit system. Reverse circulate 9.8 ppg KWE wL 6% safe lube at 6 bpm at 1,000 psi thru open pocket at 6,987 -ft. Surface to surface. 09:00 12:00 3.00 0 0 COMPZ WELLPF PACK P Continue to work pipe from 35k to 170k in attempt to pull seals from PBR at 7,040 -ft. No success. E line was called out for free point and cut. 12:00 12:30 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM with E Line crew on RU, well control and free pointing stuck pipe. 12:30 00:00 11.50 0 0 COMPZ WELLPF CUTP P Spot equipment and RU with full lubricator system. Not able to work pipe while running free point. Reconfigure setup and attempt to rig up with grease head pack off pressure control, unable to latch onto TBG and work pipe while free pointing. Reconfigure setup and attempt to rig up with double pack off pressure control, unable to latch onto TBG and work pipe while free pointing. Reconfigure setup by removing landing pup jts and using full 4 1/2" TBG landing joint allowing the ability to work pipe during free point operations. RIH with free point tools to 7,054 -ft, unable to get any deeper due to CA2 plug set at 7,104 -ft with 5 -ft catcher on top. Conduct free point and indications show free pipe above Packer. 05/25/2011 Continue to POOH w/ free point. MU Perforator, RIH and perforator - perf at 7,020 -ft., POOH. Rehead rope socket - do to over pull. RIH w/ RCT cutter and cut at 7,015 -ft. POOH and RD E line. Circ 1 1/2 hole volumes. POOH laying down de completion. Recovered seal assembly from 7050 ft. RD tubing equipment. 00:00 01:00 1.00 0 0 COMPZ WELLPF CUTP P POOH and lay down free point tools. Page 3 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 12:00 11.00 0 0 COMPZ WELCTL CPBO P Made RCT perforator and RIH to tied into packer and GLM #1, RIH to 7,011.5 -ft ccl depth and burn circulation hole at 7,020 -ft. Perforator welded to TBG wall, work free pulling up to 3,200 Ibs (max Safe pull) several times before pulling free. POOH and Rehead due to stress from max safe work pulls. Pick up 2.94" OD RCT cutter and RIH to 7,054 -ft and tie in. Make cut at 7013', in the single full joint between GLM #1 and PBR. POOH e -line and attempt to pull tubing. Pull 170k #; unable to pull completion. Rig up circulating sub and pump into tubing. After 10- minutes, attempt to pull pipe again and observe free pipe at 160k #. RDMO eline. 12:00 13:00 1.00 0 0 COMPZ WELCTL CIRC P Circulate 1.5x tubing volumes 9.8-# /gal KWF. 13:00 23:00 10.00 7,050 0 COMPZ WELLPF PULL P POOH laying down landing joint and tar . 45. Numbered yvith white paint and segregated all completion equipment identified for further investigation. Corrosion noticed on couplings from #72 to #1 as per tubing run tally 02/2001, found tight spot in CSG @ 1500 ±- ft, GLM #4 pulled through @ 30k OSW, GLM #3 pulled through @ 35k OSW, GLM #2 pulled through @ 30k - 65k OSW, GLM #1 pulled through @ 70k OSW. Recovered seals from PBR, Seal Assembly shipped to Baker production for inspection and redress 05/26/11. 23:00 00:00 1.00 0 0 COMPZ WELLPF OTHR P RD Tubing equipment, RU Drill pipe equipment. 05/26/2011 Change over to Drill pipe equipment. Set wear ring @ 28 -ft. PU -MU & RIH w/ BHA #1 to tight spots @ 32 -ft & 37 -ft, work through to 331 -ft, PU -MU drill pipe & cont. RIH w/ BHA #1 to 7038 -ft, wash down to 7056 -ft pumping 9 BPM @ 2500 psi, pump 35 bbl sweep, 10 BPM @ 1800 psi ICP, 3070 psi FCP, POOH f/ 7056 -ft & LD BHA #1. RU HES E -line and RIH w/ RCBL, log up f/ 7040 -ft to 3095 -ft. 00:00 03:00 3.00 0 0 COMPZ WELLPF OTHR P Continue to RU Drill Pipe equipment. Unload pipe shed of De -Comp equipment. Load BHA equipment 03:00 03:30 0.50 0 29 COMPZ WELLPF OTHR P RIH and set Wear Ring- RILDS 03:30 04:00 0.50 0 0 COMPZ WELLPF SFTY P Held Pre -Job safety meeting w/ Baker fishing and Rig crew on PU & MU of BHA #1 04:00 05:30 1.50 0 331 COMPZ WELLPF PULD P PU & MU Casing Scraper Assembly (BHA #1) RIH to 32' and sat down, work through to 37' sat down, work through and continue to RIH w/ BHA #1 to 331 -ft Page 4of18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 12:00 6.50 331 7,056 COMPZ WELLPF PULD P PU & RIH w/ BHA #1 (Casing Scraper) picking up 3 1/2" Drill Pipe from pipe shed from 331 -ft to 7038 -ft, (135k UW, 95k DW, 207 jts) PU joint 208 & wash down to 7056 -ft, 9 BPM @ 2500 psi. 12:00 13:00 1.00 7,056 7,056 COMPZ WELLPF PULD P Pump 35 bbl sweep, 10 BPM @ 1800 psi ICP, 3070 psi FCP 13:00 13:30 0.50 7,056 7,056 COMPZ WELLPF SFTY P PJSM for POOH of BHA #1 & Drill pipe 13:30 16:30 3.00 7,056 331 COMPZ WELLPF PULD P Blow down TD & POOH f/ 7056 -ft to 331 -ft (135 UW, 93 DW) 16:30 17:30 1.00 331 0 COMPZ WELLPF PULD P Stand back DC's, break down BHA #1 17:30 18:00 0.50 0 0 COMPZ WELLPFSFTY P PJSM w/ HES E -line crew 18:00 21:00 3.00 0 0 COMPZ EVALWE ELOG P RU HES E -line, set up tools for RCBL log 21:00 22:30 1.50 0 7,040 COMPZ EVALWE ELOG P RIH w/ RCBL to 7040 -ft, make initial correlation pass, RBIH. 22:30 00:00 1.50 7,040 3,495 COMPZ EVALWE ELOG P POOH logging @ 50 FPM to 3495 -ft as of 00:00 X5/27/2011 Continue POOH w/ CBL f/ 3495 -ft. PU -MU 430 grain string shot to second collar above TOC. PU -MU Baker RBP & RIH to 32 -ft, RBP will not pass. PU -MU 6.151" OD String Mill, RIH through tight area @ 32 -ft to 36 -ft w/ minimal work. RIH w/ RBP, Set © 2700 -ft (top of retrieving neck) P/T RBP to 3500 psi- good, No -Flow test- good. C/O hole over f/ 9.8# to seawater. Dump 25 sacks sand on RBP. Tagged TOS @ 2642 -ft (5k 2i�y down) POOH w/ RBP running tool f/ 2642 -ft to 1608 -ft. �� 00:00 01:00 1.00 3,495 0 COMPZ EVALWE ELOG P Continue POOH w/ RCBL f/ 3495 -ft It to surface. LD RCBL equipment. Located TOC at 2,180 -ft. 01:00 02:15 1.25 0 2,089 COMPZ FISH ELNE P PU -MU 340 grain String Shot. RIH to 2,099 -ft with ccl at 2,089.5 -ft (second CSG collar above estimated TOC at 2,180-ft.) 02:15 03:30 1.25 0 0 COMPZ FISH ELNE P RD Eline from rig floor and clear all E line equipment from rig floor 03:30 04:30 1.00 0 0 COMPZ WELLPF OTHR P Load sand & RBP to Rig floor 04:30 11:30 7.00 0 0 COMPZ WELLPF PLUG T STBY for completion hand to fly from PBU to KRU due to bridge out' 11:30 12:00 0.50 0 0 COMPZ WELLPF SFTY P PJSM with Baker rep. 12:00 13:00 1.00 0 0 COMPZ WELCTL PLUG P MU Baker RBP. RIH to 32 -ft unable . to work through restriction, POOH. L/D same. 13:00 14:00 1.00 0 0 COMPZ WELLPF MILL T MU string mill assembly and work through resriction @ 32- 36 -ft, pumping @ 4 bpm 50 rpm 2 -4 WOB, POOH with string mill. 14:00 15:00 1.00 0 0 COMPZ WELLPF PULD T MU magnet assembly. Make four runs through restriction, till magnet was clean. Pump sweep to surface, metal shavings in returns, POOH L/D magnet. Page 5of • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 17:00 2.00 0 2,700 COMPZ WELCTL PLUG P MU Baker RBP. Start in hole with RBP on DP, no trouble through restriction, continue in hole. et 11.21 -ft RBP w/ top of retrieving neck @ 2700 -ft. 17:00 17:30 0.50 2,700 2,700 COMPZ WELCTI PRTS P Pressure test RBP to 3500 psi, good, No -Flow test- good 17:30 18:00 0.50 2,700 2,569 COMPZ WELCTL MPSP P PUH to 2569 -ft, Change hole over f/ 9.8 to seawater 10 BPM @ 900 psi ICP, 820 psi FCP. 18:00 22:30 4.50 2,569 2,569 COMPZ WELCTL MPSP P pump 25 sacks (1200 #) sand, let / settle -1 hour. 22:30 23:30 1.00 2,569 2,642 COMPZ WELCTL TRIP P RIH f/ 2569 -ft to TAG 72' in on std 24 © 2642 -ft, set 5k down 23:30 23:45 0.25 2,642 2,642 COMPZ WELCTL SFTY P PJSM- Tripping out of hole 23:45 00:00 0.25 2,642 1,608 COMPZ WELCTL TRIP P POOH w/ Setting Tool f/ 2642 -ft to 1608 -ft 05/28/2011 Continue POOH w/ RBP setting tool. ND BOPE & Attempt to remove TBG Spool using Hydratight system. 00:00 01:30 1.50 1,608 0 COMPZ WELCTL TRIP P Continue to POOH f/ 1608 -ft to Surface 01:30 01:45 0.25 0 0 COMPZ WHDBO OTHR P Pull Wear Ring f/ 28-ft 01:45 02:15 0.50 0 0 COMPZ WHDBO SFTY P PJSM- ND BOPE 02:15 04:45 2.50 0 0 COMPZ WHDBO NUND P ND BOPE & Spacer Spool. 04:45 05:15 0.50 0 0 COMPZ WHDBO SFTY P PJSM w/ Pesiak, FMC & Rig crew 05:15 00:00 18.75 0 0 COMPZ WHDBO NUND P Attempt to ND Tubing Head using Hydratight. Break all head bolts free from original make up torque, found standard studs used with the Hydratight system - 1 3/8" Studs were to long due to FMC Gen V TBG head design (Bolts screwed into flange rather than bored thru) , locate 1 3/8" x 15" studs at whse. Install and attempt to place hydra jack heads in place, unable to to get face to face contact due to CSG head taper to center of bolt hole distance. Design stand off subs 5" long with 3" top face and 4" bottom face with 1 1/2" ID and have machine at Baker machine shop. Standby with crews while machining - (load 7 ", 26#, TCII csg in pipe shed). Stand off subs arrived on location. RU Hydratight system and begin controlling CSG Growth while NF) TRC; Spnnl Ran out of stud length with Hydratight jacks with 8 3/8" of growth in 34 cycles, remove jacks and continue to manually control CSG Growth - gaulding 1 3/8" x 22" bolts. Page 6 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/29/2011 24 hr summary Continue to control CSG growth by adding string wt, by hanging off Test plug. Remove TBG Spool, Pull and set 50k in slips with 7" and NU Spacer spool, CMT Cross and 11" Class III BOPE Stack , install 7" rams. RIH w/ MSC and cut 7" CSG at 2,072 -ft. Verify cut, Monitor well. Circulate 79 bbls to open top kill tank. Change out improper riser. 00:00 03:30 3.50 0 0 COMPZ WHDBO NUND P RIH and Land 13k of DC wt on Test plug in TBG spool. DC wt plus 11" BOP stack were enough to control CSG growth, remove gaulded stud. Flange to Flange growth = 19- 1/32" . Set back 11" BOP stack, POOH with DC's. 03:30 06:00 2.50 0 0 COMPZ WHDBO CUTP P MU and Engage with 7" CSG spear at 41 -ft., Pull up to 85k and land 7" CSG in 50k tension in slips. Release CSG spear and breakdown same. Remove 7" x 11" CSGpack 06:00 16:00 10.00 0 0 COMPZ WHDBO NUND P Install and NU 11" 3M x 5M DSA, 11" 5M Spacer spool, 11" 5M CMT cross, and 11" Class III stack. Change LPR's from VBR's to 7" solid body rams. Shell test BOPE from above LPR's to Annular to 500 psi. 16:00 19:30 3.50 0 2,072 COMPZ FISH TRIP P MU and RIH w/ 5 1/2" MSC, POS on 3 1/2 DP to 500 -ft. Obtain Free torque w/ pumps off = ? ?k Continue to RIH to 1,000 -ft and Obtain Free torque w/ pumps off = ? ?k. and continue to RIH to 2,057 -ft± and locate CSG collar. RIH to 2,072 -ft cut 7" CS,G -PU and verify cut, setting 5k down. Observed fluid attempting to seep from riser seal. 19:30 21:30 2.00 2,072 2,072 COMPZ FISH OWFF P Monitor well, Seen signs of gas from the warming of the arctic pack due to the column of 170 degree sea water in the 7" CSG- Close annular divert returns to open top tank to keep from bring on arctic pack to the rig pits. 21:30 22:30 1.00 2,072 2,072 COMPZ FISH CIRC P Circulate 55 bbls to open top tank at 4 bpm at 600 ICP and 560 psi FCP. Monitor well still signs of gas. Circulate an additional 24 bbls at 2 bpm at 1800 psi. Shut down and monitor for flow - no flow. Blow down kill tank lines and top drive. 22:30 22:45 0.25 2,072 2,072 COMPZ RIGMNT SFTY T Held pre job on non - routine task of changing out improper riser with drill pipe in hole. 22:45 00:00 1.25 2,072 2,072 COMPZ RIGMN1 NUND T Open OA to open top tank - BOP stack fluid level dropped below annular. Close in annular strip out 6 -ft. riser and reinstall 9 -ft and seal tubes. Page 7 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/30/2011 24 hr summary Open up well and Monitor. POOH and lay down MSC. PU Spear and engage 7" CSG Stub, Circulate out Arctic Pack to open top tank. Monitor well. Drain stack, break at CSG head flange and remove 7" CSG slips. NU. POOH laying down 37 -ft of 7" CSG and pulled 125k OSW. RIH with 7" CSG to 2,072 -ft., release spear and RIH with MSC to 165 -ft, cut 7" CSG. RIH and retrieve 3 jts of 7" CSG. RIH w/ MSC and cut at 295 -ft. 00:00 00:15 0.25 2,072 2,072 COMPZ RIGMNT SFTY T Held PJSM on open up annular and monitoring for leaks while monitoring well for flow. 00:15 00:30 0.25 2,072 2,072 COMPZ RIGMNT OWFF T Open up annular and monitoring for leaks while monitoring well for flow - No flow - slight loss in fluid 00:30 02:00 1.50 2,072 0 COMPZ FISH TRIP P POOH with MSC and lay down Same. Lost 5.2 bbls over pipe displacement. 3.3 bph static losses 02:00 02:30 0.50 0 2,072 COMPZ FISH FISH P PU and MU Spear assy and engage at 40 -ft. PU to 100k and had string movement, 10k over string wt. 02:30 06:30 4.00 2,072 2,072 COMPZ FISH CIRC P Begin circulating diesel at 2 bpm taking returns to open top kill tank thru choke manifold. Pressure increased at 64 bbls away and began to hydrualic CSG out of the hole. Open OA valve to kill tank and continued to circulate at 2 bpm at 230 psi. Followed by 190 bbls of 150 degree SW @ same rate, circulate nut all artic pack to ()pan tnp tank 06:30 08:00 1.50 2,072 2,072 COMPZ FISH CIRC P Blow down all lines. 08:00 08:30 0.50 2,072 2,072 COMPZ FISH OWFF P Monitor well for flow, no flow observed. 08:30 11:00 2.50 2,072 2,072 COMPZ FISH NUND P ND BOPE, RU lifting slings, pull casing slips. 11:00 12:30 1.50 2,072 2,072 COMPZ FISH NUND P NU BOPE 12:30 13:30 1.00 2,072 2,072 COMPZ FISH CIRC P Circulate bottom up @ 4 bpm @ 60 psi. 13:30 16:00 2.50 2,072 2,010 COMPZ FISH PULL P Pull on 7" casing, initial 30' pulled free, tight spot, work pipe to 223K, before pulling free, lay down first joint, start on second joint, pull up 4', tight again, walk weight up to 250K, unable to free pipe. Made decision to cut casing. 16:00 16:30 0.50 2,010 2,072 COMPZ FISH PULD P RIH and set CSG back on cut stub at 2,072 -ft and Release casing spear at 65 -ft. and POOH, broke off spear. 16:30 18:30 2.00 0 0 COMPZ FISH CPBO P MU Baker MS casing cutter and RIH to 167 -ft and locate CSG collar with cutter. PU 2 -ft to 165 -ft and Make cut. PU 2 -ft and Slide down and locate cut for verification. POOH and inspect cutter - showed good signs of cut. 18:30 19:00 0.50 0 0 COMPZ FISH FISH P PU and RIH w/ spear and engage 7" CSG stub at 65 -ft. PU and had 125k up - indicating CSG did not cut! Release spear and POOH. Page 8 of 18 . , Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:00 1.00 0 0 COMPZ FISH CPBO P PU and RIH with cutter and locate cut at 165 -ft. Procced to cut CSG in same initial cut - had same indications, continue to cut for 15 minutes longer. POOH and inspect knives - good in wear on top of blades. 20:00 20:30 0.50 0 128 COMPZ FISH FISH P PU and RIH w/ spear and engage 7" CSG stub at 65 -ft. PU and had 5k up - indicating CSG did cut! POOH and Release spear. 20:30 21:30 1.00 128 0 COMPZ FISH PULL P POOH laying down 3 jts of 7" 26 #, J -55 BTC CSG 21:30 00:00 2.50 0 0 COMPZ FISH CPBO P PU cutting BHA and change MSC assy. RIH to 297 -ft and locate CSG collar. PU 2 -ft to 295 -ft and Make cut - seen indications of good cut. POOH and knives showed same indications. 0 COMPZ P 05/31/2011 RIH and Retrieve CSG from 295 -ft. Wash BOP Stack. Set Test plug. Open Ram cavities and clean. Conduct weekly BOP test at 250 / 3,000 psi w/ 3 1/2 and 7" Test joints. MU and RIH w /BHA #13. Mill on obstruction in the 9 5/8" Casing at 254 -ft. 00:00 01:30 1.50 0 0 COMPZ FISH FISH P PU and RIH w/ 165 -ft with BHA #10 Spear assy. Engage and PU to 88k, CSG not cut at 295 -ft. Release spear and POOH with the same 01:30 02:30 1.00 0 295 COMPZ FISH CPBO P PU and inspect MSC, RIH to 295 -ft with BHA #11. Cut CSG at 80 rpm pumping at 8 bpm at 990 psi, seen pressure drop to 740 psi. 02:30 03:30 1.00 295 0 COMPZ FISH TRIP P POOH from 295 -ft and inspect cutter - good signs on knives. 03:30 04:30 1.00 0 295 COMPZ FISH FISH P RIH to 165 -ft with BHA #12, engage fish and pull 5k osw at 41 ft. out. Continue to POOH to spear, release spear. 04:30 05:00 0.50 130 130 COMPZ FISH OTHR P Change over from 3 1/2 DP equipment to 7" CSG equipment. 05:00 06:00 1.00 130 0 COMPZ FISH PULL P POOH laying down 7" CSG and strap same - 7 Joints total recovered = 294.85 -ft, 1 of 2 Centering guides recovered, JT# 7's centering guide left in hole, this what caused the uniformed scraps in the picture. 06:00 07:30 1.50 0 COMPZ FISH PULD P PU swizzle stick assembly with magnet. Wash out BOP equipment. Flush choke and surface lines. 07:30 09:30 2.00 COMPZ WELCTI BOPE P PJSM. Set test plug, open ram doors, inspect ram blocks. 09:30 12:00 2.50 COMPZ WELCTI BOPE P Troubleshoot test plug, reset test plug, shell test to 3,000 psi. Page 9 of 18 i l • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:00 5.00 COMPZ WELCTL BOPE P Perform weekly BOPE test. Test waived by AOGCC (Bob Noble) on Y / , 05 -30 -11 @ 09:30. Function & PT V ,,, BOPE and choke manifold to /y `7 250/3,000 psi. Good test. Pull Test Plug. Rig down test equipment. 17:00 21:00 4.00 0 172 COMPZ FISH PULD P Make -up BHA #13 Double String Mill Assembly. 21:00 21:30 0.50 172 254 COMPZ FISH TRIP P Trip in BHA #13 with 3 1/2" Drill Pipe from the Derrick. The Lower 8 3/8" String Mill tagged the obstruction in the 9 5/8" Casing at 254 -ft. PUW = 48K. SOW = 48K. RPMs = 70. RWT = 50K. PR = 7.2 bpm /110 psi. 21:30 00:00 2.50 254 329 COMPZ FISH MILL P Mill on obstruction in the 9 5/8" at 254 -ft with the Lower 8 3/8" String Mill. Pass through after —1 hour of milling. Continue in with BHA until the Upper 8 1/2" String Mill has tagged the same obstruction at 254 -ft. Continue milling on obstruction. Opened up the obstruction in the 9 5/8" Casing to 8 1/2 ". Pass through and continue down to the top of the 7" Casing. Tagged the top of the 7" Casing with the 8 3/8" String Mill at 329 -ft. (Note the expected top of the 7" was . 295 -ft.) Passed through the obstruction several times with no rotation or circulating. Good. 06/01/2011 Trip out with BHA #13. Pull the remainder of the 7" Casing to the next "cut" at 2,072 -ft. Drift Casing with String Mills and the inside of the 7" Casing with a Tapered Mill. TIH with a 9 5/8" Csg Scraper to the top of th 7" Stump. Circ Well w /Hot Diesel and swap Well back to Sea Water. 00:00 00:30 0.50 329 329 COMPZ FISH CIRC P Pump a 20 bbl Hi -Vis Sweep at 9.5 bpm /190 psi to clean up Well. Blow down Top Drive. 00:30 01:30 1.00 329 0 COMPZ FISH TRIP P Trip out from 329 -ft. Lay down BHA #13. 01:30 02:45 1.25 0 329 COMPZ FISH TRIP P PJSM. Pick -up BHA #14, ITCO Casing Spear. Trip in with 3 1/2" Drill Pipe from the Derrick. Tag and plant Spear in the 7" Casing at :{29 -ft Pulled to 130K to free Casing. 02:45 04:00 1.25 2,072 1,743 COMPZ FISH TRIP P PUW = 80K. Trip out with 3 1/2" Drill Pipe. Release Spear and lay down same. 04:00 09:00 5.00 1,743 0 COMPZ RPEQP1 PUTB P PJSM. Rig to handle and lay down the remainder of the 7" Casing. Note: Cut joint had two long splits down each side approximately 5' long, pictures in 2A -15 file. Strap & tally 7" decompletion, unload same from pipe shed. Page 10 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 13:00 4.00 0 COMPZ RPEQP1MILL P PJSM. PU & MU BHA# 15 double string mill assembly with tapered mill. TIH dry tag casing stub @ 2,072 -ft, work mills through stub with minimal torque several times. Continue in hole tapered mill to 2,398-ft. 13:00 14:00 1.00 COMPZ RPEQP1CIRC P Circulate bottoms up @ 8 bpm 560 psi, shut down, monitor well, 1.8 bph static loss. 14:00 16:30 2.50 COMPZ RPEQP1 PULL P TOOH w/ BHA # 15 and lay down same. 16:30 18:00 1.50 COMPZ RPEQP1PULD P MU BHA # 16, 9 5/8" scraper assembly. 18:00 20:00 2.00 0 2,070 COMPZ RPEQP1TRIP P PJSM. Trip in with BHA #16 with 3 1/2" Drill Pipe from the Derrick. Lightly tag the top of the 7" Casing Stump at 2,070 -ft with the Casing Scraper (Tapered Mill 9 -ft inside of the 7" Casing). 20:00 23:00 3.00 2,070 2,065 COMPZ RPEQP1 CIRC P Pick -up and circulate Well with hot Diesel at 4.0 bpm /250 psi. Total volume = 100 bbls. Swap Well back over to Sea Water at 5.0 bpm /100 psi. Total volume = 160 bbls. Blow down Top Drive and Lines. 23:00 00:00 1.00 2,065 800 COMPZ RPEQP1TRIP P PJSM. Trip out with 3 1/2" Drill Pipe. X6/02/2011 RU E -Line. Record a Caliper Log Log and a Gyro Log. RD E -Line. MU and RIH with BFT Back -Off Tool. Perform initial back -off on the 7" Csg Collar at 2,099 -ft. TOOH. MU and TIH with ITCO Spear and complete back -off. 00:00 00:30 0.50 800 0 COMPZ RPEQP1TRIP P Completed tripping out with 3 1/2" Drill Pipe. Lay down BHA #16. 00:30 01:30 1.00 0 0 COMPZ RPEQPITRIP P Clear and clean Floor. Wash out BOP Stack. 01:30 06:00 4.50 0 COMPZ EVALWE ELOG P PJSM. Rig up E -Line Equipment. RIH with PDS 40 Arm Caliper /GR ( in memory mode) Good data, however gama tool failed. Run Halliburton gama tool to 600 -ft for depth correlation. 06:00 11:30 5.50 COMPZ EVALWE ELOG P RU & MU Gyro tool string. RIH w/ Gyro on E -Line to 2,050 -ft with several stops. POOH. RDMO HES E -Line equipment. 11:30 15:00 3.50 0 COMPZ FISH PULD P MU BHA # 17 back -off assembly. TIH w/ same on 3 1/2" DP to straddle casing collar @ 2,090 -ft. 15:00 16:00 1.00 2,397 COMPZ FISH PULL P Set anchors. Perform initial back -off on the 7" Collar at 2,099 -ft. Got 4 1/4 turns. 16:00 20:00 4.00 2,397 0 COMPZ FISH TRIP P Trip out with 3 1/2" Drill Pipe standing back in Derrick. Lay down BHA #17. Page 11 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 23:00 3.00 0 2,072 COMPZ FISH TRIP P PJSM. Make -up BHA #18, ITCO Spear. Trip in with 3 1/2" Drill Pipe from the Derrick. Up Weight = 68K. Down Weight = 66K. Plant Spear in the 7" Cut -Off Stump at 2,072 -ft dpmd and complete backing off the connection at 2,099 -ft elmd. 23:00 00:00 1.00 2,072 2,070 COMPZ FISH CIRC P Pick -up and circulate at 8.0 bpm /400 psi. Blow down Top Drive. 06/03/2011 Trip out with BHA #18 and the "backed -off " 7" Casing Stub. RU and run 7" Casing. Pump Cement as designed. Lift Stack. Set Slips. Cut -off Casing. Install Pack -Off. NU new Tubing Spool. Test Pack -Off. 00:00 03:30 3.50 2,070 0 COMPZ FISH TRIP P Trip out with 3 1/2" Drill Pipe standing back in Derrick Lay down BHA #18 and the recovered,_ "backed -off' 7" Casing Stub with Pin end. Lenght = 19.90 -ft. Clear and Clean Floor. 03:30 07:30 4.00 0 2,092 COMPZ CASING PUTB P PJSM. Rig up to handle 7" Casing. Pick up Triple Connection Assembly with pin end down. Single in with 7 ", 26 lb/ft, L -80, TCII Casing from the Pipe shed. Install Centeralizers. Make -up torque = 10,000 ft/Ibs. (Note: Had to rotate one turn with a slight bobble to get through the milled spot in the 9 5/8" Casing at 251 -ft.) Continue in hole to 2,092 -ft. 07:30 08:30 1.00 2,092 COMPZ CASING RCST P Locate casing stub, screw into stub. Over pull 50M #. Pressure test casing to 2,000 psi, bump to 2,500 psi for 10 mins (charted). 08:30 11:00 2.50 COMPZ CASING PULD P PJSM. Change tongs and elevators. RU cement head, test to 3,000 psi. 11:00 12:30 1.50 COMPZ CASING CIRC P Pressure up casing to 3,500 psi, ES cementer opened @ 3,190 psi. Circulate 100 bbls of 90 Deg. SW to condition well @ 5 bpm 12:30 13:00 0.50 COMPZ CASING SFTY P PJSM with SLB cementers and other parties involved in cement job. Page 12 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:30 1.50 COMPZ CASING CMNT P Flush lines with 3.5 bbls. PT lines 4,000 psi. Batch up 15.7 ppg AS1. Pump 5 bbls fresh water. Pump 10 bbls neat cement @ 4.8 bpm @ 290 psi, pump 50 bbls 15.7 ppg AS1 w/ cem net @ 4.8 320 -360 psi, mix & pump 81 bbls of 15.7 ppg @ 4.9 bpm 400 -485 psi, shut down. Drop closing plug, pump 2.6 bbls above plug, chase with 5 bbls water, start t' r 1✓ pumping 72 bbls SW flush @ 5 bpm � @ 460 psi, at 178 bbls away total, started getting good cement returns to s urface, shut well in, pump remaining flush and squeeze 35 bbls cement into leak @ 5 bpm 650 psi, 70 bbls away slowed rate to 2 bpm, 75 bbls away slowed rate to 1 bpm, 82 bbls away, bump plug, bump pressure to 2,200 psi, close ES cementer, holding good. Bleed back to verify plug integrity. RDMO SLB cement equipment and HES cement head. 14:30 20:30 6.00 COMPZ CASING NUND P Lift BOP stack and install Emergency Slips with casing in 50 K tension. Cut off casing with Wachs Cutter. Set Stack back down. Break out space -out Pup Joints. Lay down recovered stub from the Cut -Off Joint (length = 21.68 -ft). Rig down and load -out casing handling equipment. Note: Five hours after cement job, TOC in OA is one foot below surface. 20:30 23:00 2.50 COMPZ WHDBO NUND P Pick -up BOP Stack and set back on the stump. Nipple down Cement Cross. 23:00 00:00 1.00 COMPZ WHDBO NUND P Nippled up FMC 11" x 5K Tubing Spool. 06/04/2011 Nipple up BOP Stack. Install VBPRs. Test. MU and RIH with 6 1/8" Bit Assembly. Drill cement and the ES- Cementer. 00:00 01:00 1.00 COMPZ WHDBO NUND P install the 7" Pack -Off. Test the same to 3,000psi x 15 minutes. Good test. 01:00 05:30 4.50 COMPZ WHDBO NUND P PJSM. Nipple uo BOP Stack, Install VBPRs in the Lower Gate. Page 13 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 10:00 4.50 COMPZ WELCTI BOPE P Install Test Plug. Fill BOP Stack. QOl t� Rig up test equipment. Test BOPE V to 250/3,500 psi. Upper & Lower VBR's, pipe rams, and annular. Pull test plug. 10:00 12:30 2.50 0 1,866 COMPZ WELLPF MILL P PU & MU BHA # 19 milling assembly. TIH w/ BHA #19 on 3 1/2" dp to 1,866 -ft. 12:30 14:30 2.00 1,866 1,866 COMPZ WELLPF SLPC P PJSM. Slip & Cut drill line. 14:30 16:30 2.00 1,866 1,950 COMPZ WELLPF MILL P Continue in hole with BHA # 19 to 1,950 -ft. Start milling cement stringers and cement to ES cementer. 16:30 23:30 7.00 1,950 2,638 COMPZ WELLPF MILL P Start drilling on ES Cementer @ 2,077 -ft. to 2,079 -ft. Fell through. Continue to wash and rotate down to 2,152 -ft. Pump a 20 bbl Hi -Vis Sweep and chase back to surface at 7.0 bpm /500 psi. Continue to RIH. Set down at 2,575 -ft. (Note: expected Top of Sand at 2,642 -ft.). Bring Pump on line. However, unable to wash through. Turn on Top Drive. Making slow hole. Cement in return across the Shaker. Drilled through a 5 -ft Cement Stringer down to 2,580 -ft. Fell Through. Continue down to the Top of Sand at 2,638 -ft. Pull back up hole to 2,542 -ft. 23:30 00:00 0.50 2,638 2,542 COMPZ WELLPF PRTS P Rig up test equipment. Blow down Top Drive. 06/05/2011 Pressure test Casing. TOOH. MU and RIH with 6 1/8" Concave MITI. Dry Drill. TOOH. PU and RIH with Rev Circ Junk Basket. Wash into Sand. TOOH. Recover pieces of the lost 7" Casing Centralizer. Re -run Rev Circ Junk Basket #2. Recover more Centralizer pieces. Re -run RCJB #3. 00:00 01:30 1.50 2,542 2,542 COMPZ WELLPF PRTS P Pressure test 7" Casing at 250 psi x 10 minutes and at 2,500 psi x 30 minutes. Good test. Record on Chart. Rig down test equipment. 01:30 03:00 1.50 2,542 0 COMPZ WELLPF TRIP P PJSM. Trip out standing back the 3 1/2" Drill Plpe in the Derrick from 2,542-ft 03:00 04:00 1.00 0 0 COMPZ WELLPF PULD P Break out the 6 1/8" Cone Bit. Lay down the two Boot Baskets and clean. Recovered —10 pounds of cement cuttings. Clean off the String Magnet and recovered — 5 pounds of metal cuttings. Make up the two Boot Baskets and a 6 1/8" Concave Mill. 04:00 09:00 5.00 0 2,647 COMPZ WELLPF TRIP P PJSM. Trip in with BHA #20, tag TOS @ 2,645 -ft. Pump 20 bbls down string, work BHA to 2,647 -ft. TOOH w/ BHA #20 and lay down same. Page 14 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 14:00 5.00 0 2,665 COMPZ WELLPF TRIP P PU & MU BHA #21 RCJB assembly on DP to 2,645 -ft. Up weight 78K Down weight 69K, drop ball, tag TOS 2,645 -ft, start circulating @ 5 bpm 520 psi, work pipe down to 2,665 -ft, some metal & sand in returns, decision made to POOH and check JB. 14:00 16:30 2.50 26,665 0 COMPZ WELLPFTRIP P TOOH w/ BHA #21, check junk basket, three 1" x 1" metal pieces and one 3" x 4" metal piece (part of missing casing centralizer) Rerun BJ assembly. MU BHA #21. 16:30 19:30 3.00 0 2,690 COMPZ WELLPF TRIP P TIH w/ BHA # 22 (RE -run of BHA #21) on 3 1/2" Drill Pipe to TOS @ 2,656 -ft. Up Weight = 78K. Down Weight = 69K. Work RCJB and wash from 2,656 -ft down to 2,690 -ft. Pick back up let sand settle. Re -tag top of Sand at 2,680 -ft. 19:30 23:00 3.50 2,690 0 COMPZ WELLPF TRIP P PJSM. Trip out with 3 1/2" Drill Pipe and stand back in Derrick and BHA #22. Break out RCJB. Recovered 3 more 1 1/2" x 1" pieces and several small pieces of the mising 7" Casing Centralizer. Clean String Magnet. 23:00 00:00 1.00 0 896 COMPZ WELLPFTRIP P Make -up RCJB for re -run #3. Trip with BHA #23 and 3 1/2" Drill Pipe to 896 -ft. 06/06/2011 Continue to run RCJB to fish remaining pieces of the 7" Centralizer. RIH with Pulling Tool. Swap Well over to 9.8 lb/gal Brine. Reverse Sand off of RBP. Release Baker RBP and TOOH. Pick -up and RIH with the Lower Completion Section on 3 1/2" Drill Pipe. 00:00 02:00 2.00 896 2,695 COMPZ WELLPF TRIP P Continue to trip in with BHA #23 on 3 1/2" Drill Pipe. Found Top of Sand at 2,685 -ft. Wash RCJB down to 2,695 -ft at 5,0 bpm /570 psi. 02:00 04:00 2.00 2,695 0 COMPZ WELLPF TRIP P Trip out with 3 1/2" Drill Pipe and BHA #23. Break out RCJB. Recover 4 more small flat pieces of metal from the Centrilizer. Clean String Magnet. Break -out and lay down remaining BHA. 04:00 07:00 3.00 0 COMPZ WELLPFTRIP P PJSM. PU Baker RBP retrieving_, head. TIH to 2,673 -ft.. 07:00 09:00 2.00 COMPZ WELLPFCIRC P Dsiplace hole with 9.8 ppg KWF, pump a 10 bbl high VIS pill, circulate out remaining sand. Latch RBP (&_ 2,702 -ft, equalize and release RBP minimal drag to 2,624 -ft, fluid swaping downhole. 09:00 12:00 3.00 COMPZ WELLPFCIRC P Circulate additional 120 bbls around @ 3 bpm, BDTD, monitor well. 12:00 15:00 3.00 COMPZ WELLPFTRIP P TOOH w/ Baker RBP, no problems. Lay down RBP. Page 15 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 18:30 3.50 0 124 COMPZ RPCOM PULD P Kick -out RBP. Prep rig floor for completion equipment. Perform final tally and inspection. MU lower completion assembly. Change handling equipment to run 3 1/2" Drill Pipe. 18:30 00:00 5.50 124 6,510 COMPZ RPCOM RCST P PJSM. Trip in with the Lower _ Completion Section on 3 1/2" Drill . Pipe. Running speed 90- ft/min per Baker Packer Rep. Completion Assembly passed through the ES- Cementer with no problems. Continue tripping in with the Lower Completion Section to 6,510 -ft. Up Weight = 123K. Down Weight = 87K. 06/07/2011 Tag PBR at 7,041 -ft. Locate and space out. Set Pkr. Shear free from new PBR. Spot Corrosion Inhibited Brine. Land Seal Assy. Pressure test. Un- sting. Test Csg. Single down Drill Pipe. Perform Weekly BOPE test. 00:00 01:30 1.50 6,510 7,041 COMPZ RPCOM TRIP P Continue to trip in the Lower Completion Section on 3 1/2" Drill Pipe. Tagged the PBR (set on 05/05/2001) at 7,040 -ft. Stab Seal Assembly into PBR. Locate and space -out. Mark Pipe. 01:30 02:00 0.50 7,041 7,025 COMPZ RPCOM CIRC P Pull Seals from PBR. Pump 21 bbls of Corrosion Inhibiterd Brine. Displace with 52 bbls of 9.8 Brine and spot the Corrosion Inhibited Brine on the back -side of the Lower Completion. 02:00 03:30 1.50 7,025 7,040 COMPZ RPCOM PACK P Up Weight = 135K. Down Weight = 90K. Sting Seal Assembly back into the PBR and bottom out. Pick up to string weight plus 1 -ft. Set Baker FHL Packer at 6,957 -ft with 2,100 psi. Increase pressure to 2,500 psi. Pull up and shear Seal Assembly from PBR at 6,934 -ft. Test the IA (with Seals strung in) at 1,504:isi x 10 minutes. Good. Breed off pressure. Pull Seal Assembly completely out of the PBR. Pressure test Casing /Packer at 2,500 psi x 30 minutes. Good. Record all tests on Chart. 03:30 12:00 8.50 7,040 0 COMPZ RPEQPI PULD P PJSM. Single down 3 1/2" Drill Pipe to the Pipe Shed. 12:00 15:00 3.00 0 0 COMPZ WELCTI BOPE P OOH, PJSM. Remove wear bushing. prep test equip. Install test plug. 15:00 00:00 9.00 0 0 COMPZ WELCTI BOPE P Test BOPE per Conoco /Phillips and AOGCC requirements at 250/3,500 $f psi. (Note: upper VBPR failed test. r Replaced and test). Test Annular at 250/3,500 psi.. 06/08/2011 Wait on proper size GLMs. Single in with the Upper 4 1/2" Gas Lift Completion. Page 16 of 18 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 COMPZ WELCTI BOPE P Perform Koomey draw down test. The States right to witness the test was waived by J. Jones. Rig down test equipment. Pull Test Plug. 01:00 01:00 0.00 0 0 COMPZ RPCOM RURD P Rig up Floor to handle 4 1/2" Tubing. 01:00 02:00 1.00 0 0 COMPZ RPCOM PUTB P Attempt to run the 4 1/2" Gas Lift Completion. Discovered that the wrong size GLMs were sent out. Re -group with Anchorage Engineer and Schlumber /Camco. Order out proper size. 02:00 17:00 (15.00 1 0 0 COMPZ RPCOM PUTB T Order proper size GLMs to be built, tested, and delivered to Location. 17:00 17:30 0.50 0 COMPZ RPCOM PUTB P Off -load GLMs in Pipe Shed. Verify and tally same. 17:30 00:00 6.50 0 4,750 COMPZ RPCOM PUTB P PJSM. Single in with the 4 1/2" Gas Lift Completion as designed. (153 Joints ran. Up Weight = 85K. Down Weight = 75K) 06/09/2011 Continue to single in with the 4 1/2" Gas Lift Completion. Locate PBR and space -out. Make -up and land Tbg Hanger. Pressure test Completion. Shear SOV. ND BOP Stack. NU Production Tree. Test Tree. Swap Well over to Diesel. Set BPV. Release Rig. 00:00 02:00 2.00 4,750 6,934 COMPZ RPCOM PUTB P Continue to single in with the 4 1/2" Completion as designed. 02:00 04:00 2.00 6,934 6,934 COMPZ RPCOM THGR P Locate top of the Upper PBR at 6,934 -ft and space -out. Pressure up on IA at 250 psi to confirm Seals are stung in. Good. Lay down Jts # 222, 221, and 220. Add Space -Out Pup Joints (23.43 -ft total). Pick -up Joint # 220. Make -up Tubing Hanger /Pup Joint Assembly. Pick -up Landing Joint. Install Head Pin. Bring on Charge Pump at 60 psi. Ease in with Completion. Pressure jumped to 210 psi when Seal Assembly entered the PBR. Bleed pressure and continue to ease on in.. Land Tubing Hanger with 14 -ft of Seals stung into the PBR and 7 -ft of the Seal Assembly out. RILDS. 04:00 07:00 3.00 0 0 COMPZ RPCOM PRTS P Rig pressure testing equipment. Test Tubing at 2,500 psi x 30 minutes. Good. Bleed Tubing down to 1,500 psi. Pressure test the 7" x 4 1/2" Annulus at 2,500 psi x 30 minutes. Bleed IA to "0" psi. Bleed Tubing to "0" psi. Pressure up on IA to 2800 psi, shear out SOV. Pump 5 bbls to ensure good flow. Set BPV. 07:00 10:00 3.00 0 COMPZ WHDBO NUND P PJSM. C/O UPR rams to 3.5 ". ND BOP stack and rack back. Page 17 of 18 • • Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 10:00 14:30 4.50 COMPZ WHDBO NUND P PJSM. Look over pre -rig tree pictures. NU Tree Orient tree. Have operations (DSO) come out and inspect tree orientation. Test tree void to 5000 psi, solid for 20 minutes. No blind flange on location for wing valve, Call for one. 14:30 20:00 5.50 COMPZ WHDBO PRTS P Blind flange on location. PJSM. MU blind flange on wing valve. Pull BPV. Install TWCV. Attempted to test tree to 5000 psi. The Tree had a Valve Stem and several Flange leaks (delivered that way) tthat had to be corrected before we got a good test at 250/5,000 psi. Pull TWCV. 20:00 22:30 2.50 COMPZ WHDBO FRZP P PJSM. Rig up Li'l Red Hot Oil Unit. Pressure test line at 3,000 psi. Good. 5wao Well over to Diesel from 9.8 lb/gal Brine at 2.0 bpm /1,900 psi. Total Diesel pumper = 240 bbls. Rig down Lil' Red.. 22:30 00:00 1.50 COMPZ WHDBO MPSP P Set BPV. Secure Production Tree and Cellar. 06/10/2011 Secure Cellar. Prep to back -off of Well. Release Rig. 00:00 03:00 3.00 0 0 COMPZ MOVE RURD P Prep to rig down. Break out Lines. Clean Pit. Back -out of Well Slot. Pick -up Mats and Herculite. Clean Wellhead. Released Rig at 03:00 hrs. Prep to move off of Location. Page 18 of 18 2A -15 Well Work Summary DATE SUMMARY 6/16/11 DRIFT TBG TO 2.82" TO 6980' SL . BAIL DRILLING MUD f/ 6980' - 6992' SLIV. PROGRESS Y 6/17/11 BAIL DRILLING MUD f/ 6996' TO 7004' SLM. IN PROGRESS 6/18/11 SET CATCHER @ 6921' RKB. REPLACED SOV W/ DV @ 6875' RKB. MIT -IA 2500 PSI, PASSED. DV's @ 5485', 4392' RKB. SET OV @ 5485' RKB. IN PROGRESS 6/19/11 PULLED DV @ 2810' RKB, SET GLVs @ 4392' & 2810' RKB. PULLED CATCHER @ 6921' RKB. READY FOR CTU C/O 6/22/11 RAN IN HOLE WITH JSN ASSEMBLY, TAGGED AT 7018 CTMD, PUH TO 7000 FT BROUGHT ON BRINE AND WASHED DOWN TO 7090.5 CTMD. TAGGED JETTED ON IT AND PULLED A WIPER TRIP TO 6800 FT. POOH. WELL FREEZE PROTECTED AND TURNED OVER TO DSO. READY FOR SLICKLINE. JOB IN PROGRESS 6/25/11 PULLED 3.5" CATCHER SUB FROM ABOVE CA -2 PLUG @ 7105' RKB. CATCHER FULL OF METAL DEBRIS: 1" - 2" PIECES & PIECE OF FLATTENED COLLAR OR RING GASKET ( ?) 9" CIRCUMFERENCE x 1 ". BAILED SAND AND DEBRIS OFF CA -2 PLUG. IN PROGRESS. 6/26/11 PULLED CA -2 PLUG FROM DS NIPPLE @ 7105' RKB. MEASURED BHP @ 7113' RKB: 2494 PSI. COMPLETE. • 4111 WELL LOG TRANSMITTAL I,. PuoAcTivE DiA g NOSiic 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 attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey M 1U' 3 201) 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 04- 3 1) Caliper Report 01- Jun -11 2A-15 1 Report/ CD 50- 103 - 20041 -00 2) Signed : Date : I 0 - L I Print Name: c°' to—, PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E -MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\Dishibution \Transu itWSheets \ConocoPhillips_Transmit.docx J —/(6 • • ' IIIII Multi- Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2A -15 Log Date: June 1, 2011 Field: Kuparuk River Unit I Log No.: 10156 State: Alaska Run No.: 2 API No.: 50- 103 - 20041 -00 Pipet Desc.: 9.625" 36 Ib. J -55 Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvil.: 2,069 Ft. (MD) 1 Inspection Type : Subsidence Inspection COMMENTS : 1 his caliper data is correlated by gamma ray recordings to the Halliburton Radial Bond log dated 26- May -2011. I This log was run to assess the condition of the 9.625" surface casing to identify areas of buckling or ID restriction due to subsidence. The caliper recordings indicate buckling from surface to 2,069' (EOL), with severe buckling recorded from —260' to — 280' and — 820'to —870'. Deformation in an area of severe buckling restricts the I.D. to 8.56" in joint 5 at 264'. No other significant I.D. restrictions are recorded throughout the I surface casing logged. Log plots of the centered, off - center caliper recordings and an overlay of both across the buckling recorded in the 9.625" surface casing logged is included in this report. A hole with 93% cross - sectional wall loss is recorded in an area of mechanical damage in the vicinity of I severely buckled casing at 266'. The caliper recordings also indicate an area of mechanical deformation just below the collar between joints 8 and 9 at 389'. If these recordings are the result of metal loss rather than expansive deformation, then an 85% wall penetration and 77% cross - sectional wall Toss may be present at I 389'. The caliper recordings indicate the remainder of 9.625" surface casing logged appears to be in good condition with respect to corrosive and mechanical damage, with no other significant wall penetrations or I areas of cross- sectional wall loss recorded. This is the second time a PDS caliper has been run in this well and the first time the 9.625" casing has been logged. 1 I MAXIMUM RECORDED WALL PENETRATIONS: Hole due to Mechanical Damage (100 %) Jt. 6 @ 266 Ft. (MD) Possible Mechanical Damage ( 85 %) Jt. 9 @ 389 Ft. (MD) 1 No other significant wall penetrations are recorded throughout the surface casing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 Hole due to Mechanical Damage ( 93 %) Jt. 6 @ 266 Ft. (MD) Possible Mechanical Damage ( 77 %) Jt. 9 @ 389 Ft. (MD) I No other significant areas of cross - sectional wall loss are recorded throughout the surface casing logged. I ProActive Diagnostic Services, Inc. / P.O. E3ox 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E-mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 I -1` 1 1 • • 1 ' MAXIMUM RECORDED ID RESTRICTIONS: Deformation Minimum I.D. = 8.56" Jt. 5 @ 264 Ft. (MD) 1 No other significant I.D. restrictions are recorded throughout the surface casing logged. 1 1 1 1 1 • 1 1 1 1 1 1 1 Field Engineer: E. Gustin Analyst: M. Lawrence Witness: L. Hinkel I 1 ProActive Diagnostic Services, Inc. / P.G. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565-1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 I • • lil, S PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk River Unit Well : 2A -15 Date : June 1, 2011 I Co mments Description : Detail of Caliper Recordings Across 9.625" Casing (Centered) Depth Maximum I.D. 3 -D Log (Centered) Image Map (Centered) i i 1ft:600ft $ inches 9.5 0° 0° 90° 180° 270° 0° I Minimum I.D. 8.5 inches 9.5 Nominal I.D. 8.5 inches 9.5 1 =EMU MIErj I IN r Pup Jt. 0.1 50 rim* ._ _ __ .. . Joint 1 Slight Buckling i I I 100 -- ' s . Joint 2 Buckling 1 4 I 1 I I Joint 3 150 — I i / I Buckling • I Joint 4 Ir li Slight 200 Buckling " -- Joint 5 : , 1 I Mechanical Damage Severe 250 Buckling I Joint 6 • Hole due to ' yins Mech. Damage ^."' Severe S Ow I Buckling 300 II Joint 7 I Buckling WIN - 350 .c — – – - I Joint 8 ,,,O„ Buckling +M OP 7. I _L 1...,-_ I Deformation / 400 � - - - ' Possible ■( ■■ y „�'' Mechanical Ell.1� ■ ■ ■ ■■ dir Buckling �' ■ ■ ■■ rriai■■i■ ' Joint 10 450 WAS■■■■ Buckling ■■■■ ' Joint 11 11111W.11.111 ■EI�� ■ ■ ■ ■■ Buckling 50 0 ■■�'■ ■■ ■■ ■ 11111.14.1111111111111 11111.14.1111111111111 ■ ■l ___�� ■■s■ ■■■■■ =_ ' Joint 12 ■■!S, ■ ■ ■■ Buckling 550 111M1111•1•1•111111111 ::,, ■■■IA-•IO■■ 1111111,111.11111111 Joint 13 ■■■i1111■ ■ ■■ 4 _ Buckling ■■!M'■ ■ ■■ 600 ■ ■•M■•■ ■` _ _ _.. _. EMEirailiMMA ■■■IAII■•■ Joint 14 Buckling ■ ■■■rd ■ ■ ■: 1 ■■.■sa■■ = - ■ ■c, ■__■■ �. 650 ■■D MI ■■ ■■ + Joint ng ■■���;� ■■■■ .1 ■■r■■■■■ 700 IMENEIMIIIIIII Joint 16 INN■■■■ Buckling 1111M■ ■ ■■ 1111111111111111••• .4t ■kyff■d■■ iii ' Joint 17 750 FAMINE= �„ Buckling -/ �►'■ � ■ NW ■■ ■■ Joint 18 ■ ■ ■■ -le Buckling 800 110.■ ■ ■■ ■ IFIR!M■■■ Joint 19 ■ ■C-g&, ■ ■■ "a- Severe Buckling ■■MIR� ■ ■■ ' Oval .11111M111.111111 _ Deformation 8 5 0 ■■K S1■ ■■ Severe ■■��E� ■ ■■ ■ B uckling ■■��JJ ■ ■ ■ ■■ Deformation • , . ■ ■�IM■ ■ ■■ ■ ■iii■ ■■ `is. I I Joint 21 wa- Buckling +fir I ,s Joint 22 I Buckling 950 — s. I Joint 23 _ illhr Severe Buckling � 1000 °ak _ .... . " - I Joint 24 ".e Olt Buckling a- 1 1050 — �: w r Joint 25 , ' Buckling w 1 - = • 1100 — lc Joint 26 . Buckling y -- S Joint 27 1150 — Slight I *!' I Buckling `Z I Joint 28 1200 Buckling +c Joint 29 ; i -+ Slight , "'..' Buckling 4 I 1250 — Joint 30 ir- 1300 ' — Joint 31 • '' I Buckling II I Joint 1350 Buckling .1 iollor I y Joint 33 Buckling 1400 ..1E 1 I I -mii El lis Joint 34 I Buckling 1450 "':� I Joint 35 4 . Buckling -. 1500 • " I: a Joint t _ Slight - I Buckling Joint 37 I Slight Buckling 1550 ....; ; 3- I Joint 38 dam. Slight :--r• Buckling 1600 Et I Joint 39 ■■R1R1 Slight ::t al ,�i Buckling I 1650 ■■a ..„,... _ Joint 40 t I Buckling — _ NEPAL = � -6.1.N. Joint 41 I Slight 1700 - �'.yr�r . kV Buckling . _ _ ... I Joint 42 ■� Slight Buckling 1750 — Ent 1 Ilit Joint 43 1� Slight f I lot - I Buckling - ' - - gr 1800 F Joint 44 Slight ■ +..^ I Buckling Fill ....., ,,,,„,;_ -4 - _ 1 Joint 45 Slight 1850 — 1. Buckling a Joint 46 - •ii -3. Slight I Buckling 1900 1 is Joint 47 E, I I Slight Buckling sr 1950 I Joint 48 ' Slight .• Buckling ' j , . . I 2000 w Joint 49 the- Buckling - - I S Joint 50 2050 - 1 1 B uckling Nominal I.D. I 8.5 inches 9S • Minimum I.D. 8.5 inches 9.5 I Comments Depth Maximum I.D. 3 -D Log (Centered) Image Map (Centered) 0° lft:600ft I 8.5 inches 9.5 0° I 90° 180° 270° 0° I I I I I I I I I 1 1 I • • Iii; S Multifinger Caliper 3D Log Plot ' ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk River Unit Well : 2A -15 Date : June 1, 2011 I Comments Description : Detail of Caliper Recordings Across 9.625" Casing (Off - Center) Depth Maximum Radius 3 -D Log (Off- Center) Image Map (Off- Center) 1. 1ft:600ft 4 inches 5 0° 0° 90° 180° 270° 0° I Minimum Radius �4 inches 5 Nominal Radius 4 inches 5 i 11111-1-1.11L' I Pup Jt. 0.1 Er I Joint 1 Slight ,■ Buckling ' 100 w -- Joint 2 - Buckling all 1 IQ I Joint 3 150 Buckling — MI : (. i Joint 4 /) Slight 200 \ — : ■ I Buckling 411111111 -1111 Joint 5 ■■■ IL I Mechanical — Damage Severe 250 ` Buckling _— I Joint 6 Hole due to �= -' G � - Mech. Damage IF 411 ...' Severe .� .0r I Buckling 300 -- ' l ■■ � Joint 7 ■ 'OM * $.. ,_ I Buckling VIM 350 I Joint 8 Buckling , _ ___ de iiiikh I Deformation / 400 C Possible ■■ ■■ Mechanical Damage ., Buckling r 1111111 I I Joint 10 450 - -- Buckling ■■r - Joint 11 -IC ogr 1 Buckling 500 - - -- i ■■ �. I Joint 12 _ Buckling -� 550 - -- - +, ', Joint 13 ■ 411 Buckling MEIN � imer I 600 Joint 14 ■ ■r I Buckling ■E► 1 LPIV , l i ,. _ _ 650 - dill i Buckling it . NEIL 1111 1 I n� 1M 700 — D — Joint 16 Buckling I It ■■ ■i • �- I Joint 17 750 - Buckling ME gr.. 4_4110004001110 amp I ■Er 4 N- Joint 18 Buckling 800 II at i _ -4 Joint 19 - Severe 11 ■SE■ g... I Buckling Oval Mal= MIPIPIr -� R .. Deformation 850 Joint 20 �� ' Severe i► r- iii I Buckling , �* Oval - Deformation I nnn I I , 9 Joint 21 ° ► �, r Buckling ■■ilaw' r I ■117110.1141M MI -- 2 . ■ ■� ■�:: 3 Joint 22 I Buckling 950 — ■■F MENOMONIE Joint 23 ■■R ■R ■■ Severe Buckling ■ ■ ' = fial ■ ■■ 1000 ■IMME=1 •■ I Joint 24 ■■ ■• .... _ Buckling minnimi OW I 1050 ■ ■rMEM■ iiimr Joint 25 Buckling ■■O ,■■■ 1100 41„ Joint 26 Buckling ' Ammo __ _ MEL 411111. da- 1 MEM , .11111ME Joint 27 1150 — Slight I Buckling ■■C I ■■ — ■ ■[ U ■■ _ — - ■C .� I Joint 28 1 200 ■r MN Buckling ■fl ■� i■ ■ 11111112 11111112 4 ■ ■■ r:` Joint t ■■m■■■ Slight i NOV Buckling • ' ILlfli!I — Joint 30 1250 IIIIU ■ ■■fd■m ■ 1300 ■U Joint 31 � I Buckling „ii ■ Joint 32 N■. Buckling 1350 - ill - I Joint 33 pew"' Buckling _�� ®�� IMP `'F 1400 IREf E 1 I ■ __ • ■■�uiu■■■ Joint 34 ■ ■p■r�■ ■■ I Buckling ■ ■ ■na■■■ - _ 1450 ;8�� ■■ I Joint 35 ME■ ■■ _. Buckling ■ ■■ .� I ■■EN■II?■■■ 1500 ■■rmrn■■■ _ Joint 36 Slight ■ ■ ■ ■■ - I Buckling _ 111111hall _ -- .....' Joint 37 E ■Rj■ ■■ -.or I Slight 1550 Buckling 11E51■ ■■ ffiurrM■ Joint 38 ■ ■��ur� ■ ■■ -� i Slight ■ ■r�■ii ■■■ '4, it Buckling ■1•M1 1600 ■ Joint 39 ■ ii i:: 7' 111"111" - row Buckling I 1650 ' t Ia.. Joint 40 j■■■ Buckling ■■ U•• MN ■ A■■■ _ I Joint 'Ill Slight Buckling 1700 i z . Joint 42 Iniram ■ Slight - _ Buckling 1750 � no� ■■ _ . ■ Joint 43 ■F�rF1■■■ Slight ■ ■��t 4 1■■■ - . ■ Buckling 18 00 ■ 1 .... - ..._ _ _ ... ■s■ Joint 44 - Slight WM air' ' Buckling WW _ - I Joint 45 1850 MN '.. Slight _ ��[� Buckling I Joint 46 Sir i ll .in. r% Slight Buckling 1900 _ _ ■ ■ I • '_ . .._ - - ,,' ' - . '''''':: s Joint 47 — I Slight Buckling 1950 1 I Joint 48 a Slight Buckling C I 2000 'ii Joint 49 ea„ Buckling II i] ant Pm i Joint 50 2050 = I Buckling I I . r __ _ -te .. Nominal Radius - I I 4 inches 5 Minimum Radius 4 inches 5 I Comments Depth Maximum Radius 3 -D Log (Off- Center) Image Map (Off - Center) 0° I 1ft:600ft 4 inches 5 I 0° 1 90° 180° 270° 0° I I I I I I I I 1 ' I I I • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk River Unit Well : 2A -15 Date : June 1, 2011 U Description : Overlay Centered and Off - Center Caliper Recordings Across 9.525" Casing M aximum I.D. Depth 3 -D Log (Off - Center) Image Map (Off - Center) 3 -D Log (Centered) Image Map (Centered) -.-1 imisIII■1111 4 Wit` i r 8.5 inches 9.5 lft:600ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° I Minimum I.D. --I 8.5 inches 9.5 Nominal I.D. I 8.5 inches 9.5 ■■■■®■■■S mumirimmpu I iIsi NEM! '= _ MINIM I ■■■uu1■■■■ 1111111111/8111111111111 1 I ■■ ■fly 100 is ■ ■ ■I1�1 ■ ■■■ , I ■■■i1�� _ ■■■� ■� u is I ■■■IIiii■■■■ 150 ■■■�II■■■■ I ■■■!i■■■■ . _,.. 11111111111111111111 200 ■■■S�1■■■■ I ■■■ti ■il■� ■ 11 if ■ ■C ■S■■ �. 1111111111111111111 250 M1111•11111111111 25° , r�, I ■■■■>wi■■ ■■■!L■■ ■ i ll i C I ■ ■ ■i11 ■■■ ■ 300 xi ■■■■M!■■■ - w I ■■■■ii■■■ ■■ ■E _ . y ■I' __ ■■■, _ 350 s I ■■■■ rs c i■■■ ■■■■■C!uu t I ��� ��s :imp ..9w,..,,...,„r,.....r_r_„,„sv,w _ , Ir"*"""" r ."„....___, r _r,..........7, 1 ,r, r ,i,„,wwwwor r ommirmammwqr -1----"""'"7"""P.r • i I V **116 W I 1 I i 1 '; f 1 ,„ i 11 P CD 0 0 0 0 0 0 0 0 0 C 0 1n 0 �) 0 Le, 0 I) 0 ILO C ger d' In e.0 c0 r.• ti CO 00 C E iii_ I 1 i ..„,„,„,,.a.,,,.......e L, I A ___,.._ .1,1( I N • • • • r• -•• MN NM - MN EN MN I r r MN A • tty ∎ri 4 4• ..r. ' lif 0 I,I —• v►a, y per .. ; ±-rpro yrirfropp' .• till. .., MUM -4 4 1 ,N1 4PMi114+ r t fl'tp1,+i4jiAA Sir +11°r1 i °, a! ohl `•4"11 F i , ,ti ti [ ■� k rya Illt maimi.ligaiiimmilmailikadihwalimmoNoimis , 0 M O O 0 r r in N N M M Qs r r r r r r r r r �.cr _ ......... .... _ f gm — .. .r — am .. .. .. r■r or .. i I — .. MO r .. --ioi_____Aoiodru_______a"—_aik_____—inoani—lt,..____ ' i ..t f'" 1-r{ I. M f IFV ir"P► 't 4 tf , rc..,..etR(711, fri i s r = ''S P., f Ote41110114 V.8010411.1fr L.. co' 0+141rp1 0041 -e • . i vr + liti ,41110 _ a is 'ie I in in tD en I- F- CO co in r r r r r r , , r r 1 1 . f i....‘,.. „ j i : ' 1 , 1 NM INS r I- MN r NM • r r MN M NM NM • - NM NM ammo 1 ■■ I MIN= Ell ■ ■ ■■ 1950 ` tMPINS .3. . I ■ I" cN■■■■ I aik- INI 2000 or I Iii If I lift 2050 Nominal I.D. I 8.5 inches 9.5 Minimum I.D. i I 8.5 inches 9.5 I Maximum I.D. Depth 3 -D Log (Off- Center) Image Map (Off - Center) 3 -D Log (Centered) Image Map (Centered) --1 1ft.600ft I -- 1 , ► 1 'r:• 8.5 inches 9.5 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° ■ ■ ■ ■ 1 ■ ■ ■ ■ ■ 1 • • I Itti 9.625" Minimum Diameter Profile I Well: 2A -15 Survey Date: June 1, 2011 Field: Kuparuk River Unit Tool: UW XR MFC 40 No. 217957 I Company: Country ConocoPhillips Alaska Tool Size: Tubing I.D: 2.75 inches USA 8.921 inches I Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 0.1 2_ I 4. I 6 8 0 I 12 I 4 I 16 i I 8 20 I 22 I E 24 I z I + 26 I I is I za I 30 I I 32 ( 34 I I I 36 I 39 I 40 1 42 1 44 F I 46: I 48 1 I I 1 • • 1 PDS Report Overview 1 Body Region Analysis 1 Well: 2A -15 Survey Date: June 1, 2011 Field: Kuparuk River Unit Tool Type: UW XR MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 9.625 ins 36 ppf J -55 BTC 8.921 ins 9.625 ins 6.0 ins 6.0 ins 1 1 Penetration(% wall) Damage Profile (% wall) 5 0 sm Penetration body Metal loss body 0 0 50 100 1 40 30 ___ 20 1 10 — 10 0 I 0 to 20% 20 to 40 to over 40% 85% 85% • Number of joints analysed (total = 511 I 49 0 0 2 20 1 Damage Configuration ( body ) 50 30 1 40 30 1 20 — 10 40 0 1 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 50 1 Number of joints damaged (total = 46) 0 0 0 45 1 Bottom of Survey = 50 1 1 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 9.625 in 36.0 ppf J -55 BTC Well: 2A -15 Body Wall: 0.352 in Field: Kuparuk River Unit I Upset Wall: 0.352 in Company: Coco Alaska, Inc. Nominal ID.: 8.921 in Country: USA Survey Date: June no 1, 2011 Phillips I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 44 0.05 0.04 10 1 8.90 Pup 1 48 0 0.03 7 1 8.86 Slight Buckling. 2 92 0 0.03 7 1 8.86 Shallow apparent wear. Buckling. 3 135 0 0.03 9 5 8.88 Shallow apparent wear. Buckling. 4 178 0 0.03 9 5 8.87 Shallow apparent wear. Buckling. I 5 221 0.07 0.03 7 9 8.56 Shallow apparent wear. Severe Buckling. 6 265 0.64 1.01 100 93 8.79 Hole in area of mechanical wear! Deformation. 7 307 0.05 0.04 12 12 8.89 Shallow apparent wear. Buckling. 8 346 0.05 0.04 12 12 8.88 Shallow apparent wear. Buckling. I 9 389 0.07 0.30 85 77 8.88 Possible Mechanical Damage / Deformation. B. 10 432 0 0.04 12 12 8.88 Shallow apparent wear. Buckling. 11 475 0 0.03 9 5 8.89 Shallow apparent wear. Buckling. 12 517 0.06 0.03 7 6 8.88 Shallow apparent wear. Buckling. I 13 560 0.06 0.03 9 7 8.88 Shallow apparent wear. Buckling. 14 602 0.06 0.02 6 4 8.87 Shallow apparent wear. Buckling. 15 645 0.05 0.03 7 3 8.83 Shallow apparent wear. Buckling. 16 688 0.07 0.03 7 3 8.86 Shallow apparent wear. Buckling. I 17 731 0.06 0.03 9 7 8.83 Shallow apparent wear. Buckling. 18 775 0.05 0.03 9 3 8.84 Shallow apparent wear. Buckling. 19 818 0.04 0.04 10 7 8.83 Shallow apparent wear. Severe Buckling. 20 856 0 0.03 7 5 8.83 Shallow apparent wear. Buckling. 21 893 0.04 0.03 7 5 8.86 Shallow apparent wear. Buckling. I 22 928 0.04 0.03 7 3 8.87 Shallow apparent wear. Buckling. 23 962 0.06 0.03 9 4 8.82 Shallow apparent wear. Severe Buckling. 24 1006 0.06 0.02 6 2 8.87 Shallow apparent wear. Buckling. 25 1049 0.07 0.03 9 2 8.84 Shallow apparent wear. Buckling. I 26 1092 0 0.03 9 3 8.83 Shallow apparent wear. Buckling. 27 1135 0 0.03 7 2 8.85 Shallow apparent wear. Slight Buckling. 28 1179 0.04 0.04 10 4 8.79 Isolated Pitting. Buckling. 29 1218 0 0.04 10 6 8.85 Isolated Pitting. Slight Buckling. I 30 1254 0.12 0.03 7 2 8.88 Shallow apparent wear. 31 1292 0.20 0.03 9 3 8.83 Shallow apparent wear. Buckling. 32 1332 0.06 0.03 9 2 8.82 Shallow apparent wear. Buckling. 33 1366 0.05 0.03 9 3 8.86 Shallow apparent wear. Buckling. 34 1406 0 0.03 7 5 8.88 Shallow apparent wear. Buckling. I 35 1449 0 0.04 10 4 8.85 Shallow apparent wear. Buckling. 36 1492 0 0.03 9 3 8.85 Shallow apparent wear. Slight Buckling. 37 1530 0 0.04 10 3 8.87 Shallow apparent wear. Slight Buckling. 38 1569 0.13 0.03 7 3 8.86 Shallow apparent wear. Slight Buckling. I 39 1608 0 0.04 10 1 8.86 Slight Buckling. 40 1644 0.21 0.03 9 5 8.90 Shallow apparent wear. Buckling. 41 1679 0.05 0.03 9 3 8.83 Shallow apparent wear. Slight Buckling. 42 1720 0.13 0.04 10 3 8.89 Shallow apparent wear. Slight Buckling. 1 43 1759 0.04 0.03 9 4 8.88 Shallow apparent wear. Slight Buckling. 44 1797 0 0.04 10 2 8.84 Shallow apparent wear. Slight Buckling. 45 1833 0.06 0.02 6 4 8.87 Shallow apparent wear. Slight Buckling. 46 1871 0.05 0.02 6 3 8.88 Shallow apparent wear. Slight Buckling. I 47 1914 0 0.03 9 3 8.88 Slight Buckling. 48 1958 0.04 0.03 9 5 8.87 Shallow apparent wear. Slight Buckling. 49 1993 0 0.03 7 4 8.85 Shallow apparent wear. Buckling. I Penetration Bod y Metal Loss Body Page 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET 1 Pipe: 9.625 in 36.0 ppf J -55 BTC Well: 2A -15 Body Wall: 0.352 in Field: Kuparuk River Unit I Upset Wall: 0.352 in Company: ConoUSA co Phillips Alaska, Inc. Nominal I.D.: 8.921 in Country: Survey Date: June 1, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 50 2035 0 0.02 6 1 8.84 Buckling. 1 1 I I I I I I I( Penetration Body Metal Loss Body 1 1 1 1 1 1 1 1 1 1 I 1 Page 2 1 1 • • 1 PDS Report Cross Sections I Well: 2A -15 Survey Date: June 1, 2011 Field: Kuparuk River Unit Tool Type: UW XR MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: M. Lawrence 1 1 Cross Section for Joint 6 at depth 265.920 ft Tool speed = 39 I Nominal ID = 8.921 -- ---..� Nominal OD = 9.625 Remaining wall area = 49% i.e.' Tool deviation = 0° 1 AT \ NI \ \ 1 ■ l IA 1 1 WO Il II �� ' *ura. _ -- 1 Finger = 36 Penetration = 1.015 ins Hole due to Mechanical Damage 1.02 = 100% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 114 g. :31/4S PDS Report Cross Sections I Well: 2A -15 Survey Date: June 1, 2011 Field: Kuparuk River Unit Tool Type: UW XR MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: M. Lawrence 1 1 Cross Section for Joint 6 at depth 265.300 ft Tool speed = 39 8. '�- Nominal ID = 8.921 Nominal g w = 9r a ' Remaining wall area = 7% . Tool deviation = 0 . 4 1 Alt % 1 ,... Li li,„ 1 1 1 1 II Ilf 1 t , 1 ■■ ■ _ _ -41. •..•� 1 Finger = 40 Penetration = 0.670 ins Mechanical Damage in Deformation Possible 93% Cross - Sectional Wall Loss 1 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 2A -15 Survey Date: June 1, 2011 Field: Kuparuk River Unit Tool Type: UW XR MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: M. Lawrence 1 1 Cross Section for Joint 9 at depth 389.230 ft Tool speed = 39 Nominal ID = 8.921 1 111 1✓ � _ 1 Nominal w ll 95 Remaining g wall arr ea a = 23% Tool deviation = 0° 1 I 1 I 1 I I 1 ‘ i 1 _.10011 1 Finger = 20 Penetration = 0.300 ins Mechanical Damage or Deformation Possible 77% Cross - Sectional Wall Loss 1 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 2A -15 Survey Date: June 1, 2011 Field: Kuparuk River Unit Tool Type: UW XR MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 9.625 ins 36 ppf J -55 BTC Analyst: M. Lawrence 1 1 Cross Section for Joint 5 at depth 264.160 ft Tool speed = 39 I Nominal ID = 8.921 Nominal OD = 9.625 Remaining wall area = N/A Tool deviation = 0° / ' 1 1 1 1 1 1 1 I Minimum I.D. = 8.560 ins Deformation in Severe Bend Minimum I.D. = 8.56" 1 1 1 1 1 ' . ConocoPhillips KUP = Attributes ogle &MD TD Wdibore API/U WI Field Name Well Status Ind ( °) M 2A -15 D (RKB) Act Bun (ftIB) 1tl - 1.'II 501032004100 KUPARUK RIVER UNIT PROD 4612 3,90000 8,130.0 CbtoaoPliYpa "' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date 0 Schematic 40 O Pon - .� SSSV: NIPPLE 45 1/1 7/2010 Last WO: 5/3/2001 34.89 8/9/1985 Arrtotation Depth (m(B) 6M Date Amo tation Last Mod By End Date Scale hn�oimr, Last Tag: Rev Reason: Pull Patch, Nip Red; set Plug Imosbor 10/3/2010 Casing Strings ■ String OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (n) (in) Top (RKB) (RKB) (ftKB) (Ibslft) Grade String Top Thrd i - - CONDUCTOR 16 15.060 30.0 104.0 104.0 62.50 H -40 SURFACE (QC) 9 5/8 8.921 30.6 3,373.3 2,788.8 36.00 J -55 BTC CONDUCTOR. PRODUCTION (QC) 7 6.151 24.3 7,442.5 5,714.6 26.00 J-55 BTC 104 - ' LINER (QC) 5 4.151 7,211.8 8,1120 6,223.7 15.00 J-55 FL4S NPPLE.496 'I i Tubing Strings Stdng OD String ID Set Depth Set Depth (N song Wt String luting Description (nl (in) Top (RKB) (1188) (ftKB) (� I) Q d11 String Tap Thrd GAS LFT. TUBING 4112 3.958 0.0 7 ,031.0 5,420.4 D) 12.60 L - 80 IBT 3077 TUBING 31/2 2.992 7,031.0 7,179.0 5,525.2 9.30 L-80 8th TUBING 27/8 2.441 7,179.0 7,649.0 5,868.4 6.50 L-80 Hyd 511 TUBING 23/8 1.995 7,651.0 7,784.0 5,972.1 4.70 J-55 8rd SURFACE Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) (OCA 3,373 Top Depth (T/D) Top Ind GAS4 T. T op (RKB) MB) (°) Description Comment Rut Date ID (in) 496.0 496.0 0.68 NIPPLE CAMCO'DB' NIPPLE 5/5/2001 3.812 3,077.0 2,581.5 46.03 GAS LIFT CAMCO /KBG -2/1 /DMY /BK/ / /Comment: STA 1 3/31/2010 3.938 4 ,630.0 3,667.1 42.67 GAS LIFT CAMCO/KBG- 211 /DMY/6K// /Comment: STA2 4/16/2010 3.938 GAS LIFT, 5,668 ' 5,668.0 4,438.4 4226 GAS LIFT CAMCO /KBG -2/1 /DMY /BK/ // Comment: STA 3 6/12/2006 3.938 6,436.0 4,998.0 44.28 GAS LIFT CAMCO /KBG -2/1 /DMY /BK/ / /Comment: STA4 4/16/2010 3.938 111 6,987.0 5,389.4 45.16 GAS LIFT CAMCO /KBG -2/1 /DMY /BK/ / /Comment: STA5 4/15/2010 3.938 GAS LIFT, 5,426.7 44.87 PBR BAKER PBR 5/5/2001 4.000 6,436 7,054.0 5,436.7 45.09 PACKER BAKER 7 "X3 °'FHL' Hydrostatic packer 5/5/2001 3.000 7,100.0 5,469.2 44.97 CATCHER 3.5" CATCHER SUB (OSL =63') 9/30/2010 0.000 1 7,105.0 5,472.8 44,96 NIPPLE CAMCO 'DS' NIPPLE 5/5/2001 2.812 GAS 7,105.0 5,472.8 44.96 PLUG 2.812 CA -2 PLUG 9/30/2010 0.000 L FT, 4 6.997 7,145.0 5,501.1 44.86 Slotted TBG 5/5/2001 2.992' 7,649.0 5,868.4 39.61 X0 5/5/2001 2.375 7,650.0 5,869.2 39.61 OVERSHOT BAKER BOWEN OVERSHOT 5/5/2001 3.125 i 1 7,651.0 5,870.0 39.61 Fish FISH left in hole; Location Unknown JUNK LEFT IN HOLE; 5/7/2001 From 9/16/90 - workover 5/3/01 pulled junk up to new level @7111 • PBR, 7,040 7,690.0 5,900.0 39.75 Blast Rings 5/5/2001 2.375 I. 7,760.0 5,953.7 39.98 SEAL LOCATOR w/5.5" SEALS 5/52001 1.995 PACKER, 7,054 :--2 • 7,761.0 5,954.5 39.99 PACKER BAKER'DB' PACKER 5/5/2001 3.250 7,763.0 5,956.0 39.99 Blast Rings Chemical cut @7755' & 7758' RKB; tubing possibly severed 5/5/2001 2.375 7/29/01 • • CATCHER. • 7,100 I 7,764.0 5,956.8 40.00 SBE SEAL BORE EXTENSION 5/5/2001 3.250 NIPPLE.7.105 II PLUG. 7105 re 7,778.0 5,967.5 40.05 NIPPLE CAMCO 'Cr NIPPLE 5/5/2001 1.812 . 7,783.0 5,971.4 40.06 SOS 5/5/2001 2.000 7,784.0 5,972.1 40.07 WLEG OTISWIRELINE RE -ENTRY GUIDE - T EL MD @77 5/5/2001 2.000 sl°ae°78 } ON OTIS TEMP LOG 10/10/1985 • Perforations & Slots i � Top (TVD) Btm (TVD) Dens Top del Btm (MB) ( � ( B) Zone Date Oh.- Type Comment 7,6910 7,744.0 5,900.8 5,941.5 10/7/1985 6.0 IPERF SOS 33/8" Ultra Jet; 60 deg. phasing 7,857.0 7,906.0 6,028.0 6,065.6 10/7/1985 6.0 IPERF SOS 33/8" Ultra Jet; 60 deg. phasing " PR 4112 Notes: General &.Safety I . Date TB xo. 7649 5/18/20/20 01 NOTE: Chemical curs @ 7756' and 7755' MD a12 3/8"TBG, unable m pass through cuts. 5/9/2006 NOTE: WAIVERED WELL: IAx OA x OOA - PROD CSG x FORMATION COMMUNICATION 7,650 ( 5/10/2010 NOTE: TUBING LEAK FOUND @ 6366' ON 0.5 BPM LDL Fish, 7.651 V r. Had Rings 9/10/2010 NOTE_ VIEW SCHEMATIC w /Alaska Schematic9.0 7,690 IPERF, 7,891 -7,744 SEAL, 7.760 i. PACKER, 7,761 �7r•� Blast Rugs, .I. 7.763 SBE, 7,164 Ofr i NIPPLE. 7.778 I F 1! SOS, 7,783 ' e WLEG, 7,784 IPERF. 1 7.857 -7.906 .900 I 1 LINER (OC), ' - 8,112N TD, 8130 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 2, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log / Shot Rod: 2A -15 Run Date: 5/26/2011 - 5/27/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -15 Data in LAS format, Digital Log Image files '7 3 7 1 CD Rom — 50- 103 - 20041 -00 Cement Bond Log 1 Color Log 50 -103- 20041 -00 A : tiA4E4) St_ P 1 >U1; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com RECEIVED Date:. Signed: 0 JUN' 1 g 2011 ■ A uks O18 Gas Cons. Canmiatbn Anchorage ys- / (1( • • Slit:ZEE DIF n[LASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson Wells Engineer ConocoPhillips Alaska, Inc. 4 P.O. Box 100360 C� Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -15 Sundry Number: 310 -434 Dear Mr. Nelson: JAN l F LU I Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 / -- Daniel T. Seamount, Jr. Chair DATED this day of January, 2011. Encl. • • ConocoPhillips Alaska ECE1VED P.O. BOX 100360 DEC 2 (� Q ANCHORAGE, ALASKA 99510 -0360 Alaska Gas Cons. Commission Anchorage 20 December, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 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 -15 (PTD 185 -146). Well 2A -15 was originally drilled and completed in 1985 and was shut in on 13 September 2010 after failing a mechanical integrity test of the inner annulus (MITIA). This test was used to monitor the tubing integrity after a temporary patch was installed on 02 July 2010 following an initial failed tubing integrity by fluid level test (TIFL) on March 24, 2010. Well 2A -15 has had a surface casing leak between 192'- 360' since May 2003. As with many wells on the 2A and 2T drillsites, subsidence is assumed to be the root cause of the casing and tubing issues in this well. The purpose of this workover is to restore the integrity of the tubing and casing strings and provide a stronger wellbore to combat the effects of future subsidence. This will be accomplished by replacing the 4 -1/2" tubing and also replacing the top —1,500 feet of 7" production casing. By cementing the replaced production casing to surface, this will effectively mitigate the surface casing leak and will provide a stronger wellbore. If you have any questions or require any further information, please contact me at 263 -4693. Regar. s, / 0114 Erik Q. Nelson Wells Engineer CPAI Drilling and Wells STATE OF ALASKA . . ALASIAL AND GAS CONSERVATION COMMISSI 00 I l APPLI FOR SUNDRY APPROVA S I'I)" 5'1( 20 AAC 25.280 I 3 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well Change Approved Program f Suspend r Rug Perforations r Perforate r Rill Tubing PT Time Extension Operational Shutdow n r Re -enter Susp. Well l Stimulate Alter casing 9 p- " Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development }_ Exploratory r 185 -146 ' 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20041 -00 ' 7. If perforating, 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 r No r 2A - , 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25570 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 81304 6238 • 8034' 6163' 7105' 7651' Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 104' 104' SURFACE 3343 9.625 3373' 2789' PRODUCTION 7418 7 7442' 5714' LINER 900 5 8112' 6224' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7691' 7744', 7857 5901' 5942', 6028' - 6066' 4.5, 3.5, 2.875, 2. 375 L - 80, J - 7784 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 7 "X3 " 'FHL' HYDROSTATIC PACKER MD= 7054 TVD= 5437 PACKER - BAKER 'DB' PACKER MD= 7761 TVD= 5955 NIPPLE - Camco 'DB' nipple MD= 496 TVD= 496 12. Attachments: Description Sunmary of Proposal ; 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development i Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/1/2011 Oil P' ', Gas r WDSPL r Suspended 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson © 263 -4693 Printed Name Erik Nelson Title: Wells Engineer Signature �+ I Phone: 263 -4693 Date zoi)eG 7,0,40 Commission Use Only Sundry Number: J V `�q Conditions of approval: Notify Commission so that a representative may witness iJ Plug Integrity r BOP Test Mechanical tegrityTest "" Location Clearance r � E I Other: 4a 35 t .. doe OS ( *-2.s d os ` %nK '.. -E�c / -5- DEC - Ci Subsequent Form Required: G 0 , 4/ 0L1 Gas omm �'o It AII1Char2U9 APPROVED BY Approved b 0 ' COMMISSIONER THE COMMISSION Date: t / 2 I J l ��yg e Q1 q ,� /Z•. /o Submit in Duplicate 4,1.000 a R���NA� ,,,, • • 2A -15 Expense Rig Workover PTD #: 185 -146 Current Status The well is currently shut in awaiting a workover to replace the corkscrewed tubing and proactively repair the 7" and 9 -5/8" casing strings. This well is located in an area with surface subsidence due to permafrost thawing and has seen a minimum of 43.7" of subsidence through it's life. A RWO was done in 2001 in order to upsize the tbg to 4 -W from it's original 3-Y2". The well has suffered numerous tbg leaks in the past year and multiple patches and LDLs have been run. Scope of Work ✓ _ Pull corkscrewed tubing, proactively cut & pull a portion of the 7" casing, re -run new 7" casing, cement the 9-%" x 7" annulus, and install new 3-Y2" tubing. General Well info MASP: 2333 psi Reservoir pressure/TVD: 2931 psi / 5982' TVD Using SBHP measured on 21 July 2009 of 2721 psi at 5478' TVD and assuming an 8.0 # /gal fluid equivalent to mid -pert Wellhead type /pressure rating: FMC Gen V / 11" 5M BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe MIT -IA and MIT -OA results: MIT -IA failed 13 August 2010 Unable to MIT -OA due to csg leak Well Type: Injector Estimated Start Date: 01 January 2010 Production Engineer: Kelly Lyons RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 — 7407 E -Mail: Erik.Nelson @conocophillips.com Pre -Rip Work Request 1. Pull dummy from GLM #5 and leave open 2. Load well w/ 9.8 # /gal brine 3. PT tbg and csg packoffs and FT LDSs 4. Set BPV .f Proposed Procedure 1. MIRU Nordic 3. Accept Rig, take on fluids, pull BPV, and insure well is dead. 2. Install BPV & blanking plug, ND tree, NU 11" 5M BOPE, function and PT to 250/ 500 psi 3. Pull blanking plug & BPV. Screw in landing jt, BOLDS's, and pull to the floor. 4. LD tbg hgr and TOOH sideways w/ 4'/ ", L -80 IBT -Mod tbg. 5. MU and RIH w/ csg scraper (7 ") on 3-Y2" IF DP workstring. 1 6. RU HES E -line and run caliper /gyro /CBL logs and shoot string shot at identified collar. RDMO E -line 7. MU and TIH w/ RBP or IBP and set below TOC. PT to 3500 psi and drawdown test same. Dump sand. 8. ND BOPE and tbg head. Re -land 7" csg in tension. NU 11" 5M BOPE on 11" 3M casing head. Remove casing packoffs and slips. NOTE: At this point BOPE will be treated as a diverter due to our inability to test the BOPE due to the surface csg leak. 9. Cut 7" casing with multi- string cutter on drill pipe above TOC. Circ 9 -5/8" x 7" annulus clean. 10. Spear and TOOH laying down 7" casing. . . w -- Proposed Procedure Continued- - 11. Set test plug and test BOPE to 250/3000 psi. NOTE: Limitation due to working pressure rating of csg head. 12. Run 9 -5/8" casing scraper to top of 7" stub. Circ clean. P P 13. RU HES E -line and run caliper /gyro /CBL logs. RDMO E -line. 14. Run tandem string mill assembly to gauge casing for installation of new 7" csg string. Make dummy run for 7" csg and Halliburton ES cementer. 15. TIH w/ back off tool and back off casing stub. TOOH. 16. TIH spear and recover casing stub. TOOH. 17. Clout lower BOP ram to 7' and test ram to 250/3000 psi. 18. TIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing to 3000 psi. 19. Open ES cementer and pump cement (calculated plus — 100% excess) into 9 -5/8" x 7" annulus. / Squeeze remaining cement into surface casing leaks after obtaining cement circulation to surface. Close cementer. 20. WOC. ND BOPE and land 7" on slips. Cut 7" casing and install packoff. NU tubing head. 21. NU 11" 5M BOPE and test break to 250/3500 psi. 22. Drill out cement and plug. Pressure test casing to 3000 psi. TOOH. 23. TIH w/ reverse circulating junk basket to clean out remaining debris. TOOH. 24. TIH with wash shoe and circulate out sand on top of RBP. TOOH. TIH w/ retrieving tool on work string. Release RBP /IBP and TOOH. 25. TIH with seal assembly, packer, and 20' PBR on 3 - %" IF DP. Go over tubing stub. Circ in corrosion inhibited fluid. Set packer. TOOH laying down DP. 26. TIH with new 3 -1/2" tubing and seal assembly. Load tubing and IA with corrosion inhibited seawater. Stab into PBR and space out. Pressure test tubing and IA to 3000 psi. Shear SOV. 27. Set 2 -way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. — 28. Pull 2 -way check. Freeze protect well. Set BPV. 29. RDMO Nordic 3. Post -Rip Work: 1. Pull BPV 2. Pull DVs and SOV and run GL design 3. Pull ball / rod 4. Pull RHC body 5. Pull catcher sub 6. Pull 2.812" CA -2 plug 7. Handover to Ops • KUP 2A -15 (� imps # ) IWell Attributes Max Angle & MD ITD • 1 Wellbore API /UWI Field Name Well Status Inc/ (°) MD (ftKB) Act Btm (668) a I j 501032004100 KUPARUK RIVER UNIT PROD 46.12 3,900.00 8,1300 --°- Comment 1325 (ppm) Date Annotation End Dale KB (ft) Rig Release Date _- _ SSSV NIPPLE i 45 1/17/2010 Last WO. 5!3/2001 34.89 8/9/1985 """' ° � g,Cf `6 � }k ' . J A a PM Annotation Depth (HKB) End Date Annotation Last Mod By End Date Scale Inhmnor, Last Tag: ' Rev Reason: Pull Patch, Nip Red; set Plug _- _ _ Imosbor 10/3/2010 Casing Strings String OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (in) (in) Top(BKB) (ftKB) (HKB) (Ibs./ft) Grade String Top Thrd .. l ,. _ CONDUCTOR 16 15060 30.0 104.0 104.0 62.50 H-40 SURFACE (QC) 9 5/8 8.921 30 6 3,373.3 2,788.8 36.00 J -55 BTC I -- CONDUCTOR, PRODUCTION (QC) 7 6.151 24.3 7442.5 5,714.6 26.00 J -55 BTC 104 1 1 LINER (QC) 5 4.151 7,211.8 8,112.0 6,223.7 15.00 J -55 FL4S NIPPLE, 496 , .. Tubing Strings ! St mg OD String ID Set Depth Set Depth (ND) String Wt String _TubingDescription (in) (in) Top(CKB) (ftKB) (HKB) fibs/ft) Grade String Top Thrd GAS 3,,077 077 fl ___,.p - TUBI 41/2 3.958 00 7,031.0 5,420.4 12.60 L - 80 IBT U 2 .44 1 7 171 0 7,644 0 5,868. 1 6.50 L -80 Std I 2 3/8 2 992 7,031.0 7 179.0 5,525.2 9.30 L -80 Hyd 511 TUBING 2.441 7,179 0 7,649.0 5,868.4 6 SO TUBING 31 TUBING 2 ! � J -55 8rd SURFACE ., Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) (QC), 3,373 Top Depth • Top (19 ) To Inc! GAS LIFT, 496.0 496.0 0.68 Top (MB) (8668) (°) Description Comment Run Date ID (in) NIPPLE CAMCO 'DB' NIPPLE 5/5/2001 3.812 F ; 3,077.0 2,581.5 46.03 GAS LIFT CAMCO /KBG -2/1 /DMY /BK/ // Comment: STA 1 3/31/2010 3.938 _ . 4,630.0 3,667.1 42.67 GAS UFT CAMCO /KBG -2/1 /DMY /BK/ // Comment STA 2 4/1&2010 3.938 GAS LIFT, ^-`- 4668 ' 5,668.0 4,438.4 42.26 GAS LIFT CAMCO /KBG -2/1 /DMY /BK/ / /Comment: STA 3 6/12/2006 3.938 6,436.0 4,998.0 44.28 GAS LIFT - -- CAMCO /KBG- 2/1 /OMY /B10/ /Comment: STA4 4/16/2010 3.938 6,987.0 5,389.4 45.16 GAS LIFT CAMCO /KBG -2/1 /DMY /BK/ / /Comment SIA5 4/15/2010 3.938 068 LIFT, 7,040.0 5,42677 44.87 PBR BAKER PBR 5/5/2001 4.000 6,438 -'' 7,054.0 5,436.7 45.09 PACKER BAKER 7"X3" 'FHL' Hydrostatic packer 5/5/2001 3.000 7,100 0 5469 2 44.97 CATCHER 15" CATCHER SUB (OSL =63') 9/30/2010 0.000 z 7,105.0 5,472.8 44.96 NIPPLE CAMCO DS' NIPPLE 5/5/2001 2.812 ' 7,105.0 5,472.8 44.96 PLUG 2.812 CA -2 PLUG 9/30 /2010 0.000 GAS LIFT,_ .- -- - --' 6,987 - -- !_ 7,145.0 5,501.1 44.86 Slotted TBG 5/5/2001 2.992 ; 7,649.0 5,868.4 39.61 XO 5/5/2001 2.375 4 7,650.0 5,869.2 39.61 OVERSHOT BAKER BOWEN OVERSHOT 5/5/2001 3.125 7,6510 5,870.0 39.61 Fish FISH left in hole; Location Unknown JUNK LEFT IN HOLE; 5/7/2001 From 9/16/90 - workover 5/3/01 pulled junk up to new level @7111 PBR.7,040 . - . ._ 7,690.0 5,900.0 39.75 Blast Rings 5/5/2001 2.375 7,760.0 5,953.7 39.98 SEAL LOCATOR w /5.5" SEALS 5/5/2001 1.995 PACKER, 7,054 S ..,. / 1 7,761.0 5,954.5 39.99 PACKER BAKER 'DB' PACKER 5/5/2001 3.250 7,763.0 5,956.0 39.99 Blast Rings Chemical cut ©7755' & 7758' RKB; tubing possibly severed 5/5/2001 2.375 7/29/01 NI D a 0 - ry t 7,764.0 5,956.8 40 00 SBE SEAL BORE EXTENSION 5/5/2001 3.250 7,100 7,778.0 5,967.5 40 05 NIPPLE CAMCO'0' NIPPLE 5/5/2001 1.812 7,783.0 5,971.4 4006 SOS 5/5/2001 2.000 7,784 0 5,972.1 40 07 WLEG OTIS WIRELINE RE -ENTRY GUIDE - TTL ELMD @ 7778' 5/5/2001 2.000 Slotted 1136, .. ■ ON OTIS TEMP LOG 10/10/1985 7,145 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Bjf i . ''''', i tm (Mai) ( ) Zone Date (sR•. Typa Comment 7,691.0 7,744.0 5,900.8 5,941.5 10/7/1985 6.0 IPERF SOS 33/8" Ultra Jet; 60 deg. phasing 7,857.0 7,906.0 6,028.0 6,065.6 10/7/1985 6 0 IPERF SOS 3 3/8" Ultra Jet; 60 deg. phasing - PRODUCTION ( QC), 7,442 Notes: General & Safety (- End Date Annotation 5/18/2001 NOTE: Chemical cuts @ 7756' and 7755' MD in 2 3/8"TBG, unable to pass through cuts. OVERSHOT, I 5/9/2006 NOTE: WAIVERED WELL IA x OA x 00A- PROD CSG x FORMATION COMMUNICATION 7,650 = 5 !10/2010 NOTE: TUBING LEAK FOUND @ 6366' ON 0.5 BPM LDL Fish, 7,651 - .__ _.........._ Blast Rigs, 9/10/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 7.690\ IPERF, HIM 7,691 -7,744 SEAL, 7,760 ____ __ II Blast Rigs, ;'+�! *. 7,763 SBE, 7,764 - NIPPLE,7,778 -- -- -- J. SOS, 7,783 -- WLEG, 7,784 -- - -- IPERF, 7,857 -7,906 .:.. 1 it LINER (QC), 8,112N J T0,8,130 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2A-15 Run Date: 6/27/2010 July 16, 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-15 Digital Data in LAS format, Digital Log Image file 50-103-20041-00 1 CD Rom "r,. . 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. ~ ~ S- (~/~ Anchorage, Alaska 99518 Office: 907-273-3527 ~ Qjf~ [,~ ~ Fax: 907-273-3535 rafael.barreto `' R ~~ Date: -~~~ t~ ~' ~~~~ Signed: _ ~i9.~ ~~' u STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~. operations Performed: Abandon Repair w ell ~ Plug Perforations ~"" Stimulate '"" Other ~ Patch Alter Casing `"°° Pull Tubing ~ F~rforate New Fbol Waiver "` Time Extension Change Approved Program Operat. Shutdown ""' Perforate l Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: `5~ Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ~'"" 185-146 3. Address: Stratigraphic r"' Service ~. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20041-00 7. Propert~r Designation: 8. Well Name and Number: ADL 25570 ~ 2A-15 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8130 feet Plugs (measured) None true vertical 6238 feet Junk (measured) 7651 Effective Depth measured 8034 feet Packer (measured) 7054, 7761 true vertical 6163 feet (true vertucal) 5437, 5955 Casing Length Size MD TVD Burst Collapse CONDUCTOR 104 16 104 104 SURFACE 3373 9.625 3373 2789 PRODUCTION 7442 7 7442 5714 ~~1C~'~ /~D LINER 900 5 8112 6224 (,~G ~/ JUL 1 5 2010 ~I~ska Clil fit G~ Ce~i. ('iOirNT1I3Si0f1 Perforation depth: Measured depth: 7691'-7744', 7857'-7906' ' I~tC1lb~8Q8 ' ' ' True Vertical Depth: 5901 , 6028 -5942 -6066 Tubing (size, grade, MD, and TVD) 4.5, 3.5, 2.875, 2.375, L-80, J-55, 7031', 7179', 7649', 7784' MD, 5420', 5525', 5868', 5972 TVD Packers &SSSV (type, MD, and TVD) PACKER -BAKER 7"X3"'FHL' HYDROSTATIC PACKER @ 7054 MD and 5437 TVD PACKER -BAKER'DB' PACKER @ 7761 MD and 5955 TVD no SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable i I ~ i :r ~ ~ ~~ k~ ,~ ~~~ ~~~ } . Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 1303 4298 6834 -- 281 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory "" Development Service . Well Status after work: Oil Gas WDSPL "" Daily Report of Well Operations XXX GSTOR ~ WAG ~°°° GASINJ ~°" WINJ SPLUG 16. 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 Dani Herrma 263-4619 Printed Name ni He n Title Wells Engineer Signature Phone: 263-4619 Date ~~ f7l~J~ % c~ -/CV Form 10-404 Revised 7/20~~MS .~~ 15 ~. ~` Submit Original Only _ ~'~, • KUP • 2A 15 ~CN~C~C?~'ll~~jp5 ~~ ' WeILAttributes _ ';.Max Mgle 8 MD TD te ~ Wellbore API/UWI ' Fieltl Name Wall Status Intl (°) MD (ftK6) Act Btm (flKe) r ' "' 501032004100 KUPARUK RIVER UNIT PROD j 46.12 3,900.00 8 130 0 C wnment H2S (ppm) Date 'AnnotatOn End Date KB-Grd (fq Rig Release Date _ SSSV. NIPPLE 45 I 01 34 89 1117/2010 j Last WO 15!3!20 8/9/1985 Well C nflg 2A-1 -..~ Scheln 3, 8113/LO L - ' L~ 'M a[i Auunl Annotation ° -.. Depth (ftK6) End Date . Annotation last Mod By - End Date Last Tag: I Rev Reason: Pull Plug/Caicher, Set NIP RDCR Imosbor __ 6/13/2010 wale mnmrter, ,, Casin Stnn s 0 , ~- ~ " '~ String OD String ID Set Depth Set Depth (ND) I String Wt String CONDJCTOR.- 1 Casing Description (in) (in) Top (ftK6) (ftK6) (ftK6) (Ibs/ft) Gratle ~ Str_ing Top Thrd to6 I~ '' CONDUC TOR 16 15.060 0.0 104.0 104.0 62.50 ~ H~0 SURFACE 9 5/81 8.765 0.0 3,373.0 2,788.7 36.00 J-55 NIPPLE. ash PRODUCTION ~' 7 6 151 0.0 7442 0 5 714.3 26.00 J-55 l ;. LINER ~' 5 4151 7,212.0 81120 6,223.7 15.00 J-56 "~" Tubing Strings cnsuFT.____ 3.0]] . String OD String ID Set Depth -- Set Deplh (ND) String Wt String ' Tubing Description (in) (in) Top (ftK6) (ftK6) (ftK6) (Ibs/ft) Grade String Top Thrd TUBING 4 1/2 3.958 0 0 J 0"31 0 5,420.41 12.60 L-80 IBT SURFACE, 3,3]3 ° a - TUBING _ - --_ 31/2 2.992 7,031.0 7,179.0 -- __ - _ 5,525.2, 9.30,E-80 8rd - -_ ~ TUBING 2 7/8 2.441 7,179.0 7 649 0 5,868 4 ~ 6.50 L-80 Hyd 571 GAS uFr, _ _ _ '~ TUBING 2 3/81 1.995 7,651 0 7,784 0 5,972.1 4.70 J-55 8rd 4,630 " `; ! Other-I n Hol_e_~A II Jew elry: Tubin g Run & Retrievable,. Fish, etc.)_ '~ Top Depths ' --<. ...~,. (ND) 1 Top Intl i GAS LIFT Top (ftK6) (ftK6) (°) Description Comment _.._ Run Date ID (in) _- 5.668 496 4960 068 NIPPLE CAMCO'DB'NIPPLE 5/5/2001 3.812 I 3,077 2,581.5 46 03 GAS LIFT CAMCO/KBG-2/1/DMYlBK/// Comment: STA 1 3731/2010 3.938 GAS LIFT, - 4630 3,667.1 42.67 GAS LIFT CAMCO/KBG-2/1/DMY/BK///Comment STA2 4/16/2010 3.938 sp36 _. 5,668 4 438.4 42 26 GAS LIFT CAMCO/KBG-211/DMY/BK!//Comment: STA 3 6/12/2006 3.938 6,436 4,9980 4428 GAS LIFT CAMCO/KBG-2/1IDMY/BK/7/Comment: STA4 4/16/2010 3.938 ^"- ` ~ 6,987 5,389.4 45.16 GAS LIFT CAMCO/KBG-2/1/DMY/BK!!l Comment: STAS 4/15/2010 3.938 GAS LIFT s,9w ' i I, 7 040 5,426.7 44.87 _ PBR BAKER PBR - --- - 5/512001 1 4.000 '+ ~ 7,054 5,436.7 45.09 PACKER BAKER 7"X3"'FHL' Hydrostatic packer 5/5/2001 3.000 ~ , 7,105 5,472.8 44.96 NIPPLE CAMCO'DS'NIPPLE 5!5/2001 2.812 r- 7,105 5,472.8 44.96 Nipple Reduce r 1.81" NIPPLE REDUCER 6/12/2010 1.810 PBR.zoao 7,145 5,501.1 44.86, Slottetl TBG 5/572001 2.992 7,649 5,8684 3961 XO 5/572001 2.375 7,650 5,869.2 39 61 OVERSHOT BAKER BOWEN OVERSHOT 5/572001 3.125 PACKER. ].050 -_._- s c^'" _"^ _ .7.-0 ~ _~ 7,651 5,870.0, 39.61 -.. Fish _ _ ;FISH left in hole; Location Unknown JUNK LEFT IN HOLE; - - -. 5/7/2001 _ ~ --;y- From 9/16!90 - workover 5/3!01 pulled junk up to new level j n @7111 NIPPLE. 7,tos ~ ,. 7,690 5,900.0 39.75 Blast Rings 5!5/2001 2.375 N pple Reducer, ],1os 7,760 5,953.7 39.98 SEAL _ LOCATOR w/5.5" SEALS 5!5/2001 1.995 7,761 5,954.5 3999 PACKER BAKER'DB'PACKER 515!2001 3250 k ~+ 7,763 5,956.0 39 99 I Blast Rings , Chemical cut @7755' & 7758' RKB; tubing possibly severed 5/5/2001 2.375 cloned Tec, _ ].tas - -` ~ , 7/29/01 J 7,764 5, 5 4000 SBE 1 -__ - 'SEAL BORE EXTENSION - - SIS/2001 3.250 ' 7,778 5,967.5 ~~ 40.05 NIPPLE CAMCO'D' NIPPLE 5/5/2001 1.812 7,783 5,971 4 40.06 SOS . S/512001 2.000 7,784 5,972.1 40.07 1 WLEG OTIS WIRELINE RE-ENTRY GUIDE - TTL ELMD @ 7778' 5/5/2001 2.000 ON OTIS TEMP LOG 10!10/1985 PROOUCnoN,_ __.- ~ i _ za6z ,1 ..-_ Perfora tions & $IOtS snnt -.-.- XO, ],669- °s" ToP (TVD) Btm (TVD) D s I ~. P( ) To ftK6 Bfm (ftK6) (ftK6) (ftK6) Zone Date (h... Type Comment - ovERStioT _ _ M~ 1,691 7.744 5,900.8 5,941.5 10/7/1985 j 6.0 IPERF SOS 3 3/8" Ultra Jet; 60 deg. phasing zsso '= ~ 7,857 1 ~ 7,906 i 6,028.0 6,065.6 ~ ~ 10x//1985 6.O .IPERF - _ __. SOS 3 3/8" Ultra Jet; 60 deg. phasing' Fish, 7 651 -- - . - Notes: General 8r Safety _ End Date ~ Annotation __ _ _ 5718/2001 _ ~, NOTE' Chemical cuts @ 7756' and 7755' MD In 2 3/8"TBG, unable to pass through cuts Blast Rings, ___ - ]s9o _~ 5/972006 NOTE: WAIVERED WELL: IA x OA x OOA -PROD CSG z FORMATION COMMUNICATION IPERF, __ ~ _ 5 /1 012 01 0 (NOTE: TUBING LEAK FOUND @ 6366' ON QS BPM LDL i _ 1 _-__. _ _ __ ],691 -]]44 SEAL 7,760 PACKER, 1,]61 ~- '~ r. ~~ -y } l Blast Rings, _.,-_.__-_ _ ] ]63 SBE. 7,764- NIPPLE. ],7]8 - - SOS. ] 183 --- -- WLEG. ],]84 r IPERF, _ - - ],857-7,906 LINER. B, t 12 ~ TD, B,t30 2A-15 Well Events Summary DATE SUMMARY 3/22/10 TIFL- INCONCLUSIVE (IN PROG SS), NFT- PASSED (AVERAGE 473.87 ~H) 3/24/10 RE-TIFL- FAILED (INFLOWED) _ 3/30/10 T 2.81" CSA-2 PLUG @ 7105' RKB. SET CATCHER @ SAME. PULLED OV @ 4630' RKB (GOOD CHECK). IN PROGRESS. 3/31/10 PULLED GLV @ 3077' RKB. SET DVs @ 4630' & 3077' RKB. PULLED DV @ 6987' RKB. LOADED WELL WITH 240 BBL DSL, TAKING RETURNS TO PROD. MITd TxIA TO 2500 PSI; POSSIBLE LINEAR LOSSES. SET DV @ 6987' RKB. DRAW DOWN IA TO TEST, TBG TRACKING. IN PROGRESS. 4/1/10 WITH HOLEFINDER IDENTIFIED APPARENT T..~,~ AK BETW N GLM 64 6' RKB & 6336' RKB. REPLACED DV @ 6436' RKB. REATTEMPTED TBG TEST WITH SAME RESULT. COMBO MITd TBG / IA, GOOD TEST. (36" x 3.5" CATCHER IN HOLE @ 7105' RKB). JOB SUSPENDED. 4/8/10 RUN PDS CALIPER FROM 7033' SLM TO SURFACE. GOOD DATA. DRIFT TBG TO 3.78" FOR PATCH AND TAG CROSSOVER @ 7031' RKB. COMPLETE. 4/9/10 PERFORM A LEAK DETECT LOG FROM 7075' TO SURFACE. WHILE LR PUMP 1 BPM OF DIESEL DOWN THE IA AND TAKING RETURNS TO THE TUBING FOUND T.HE~T THFSzI M # 1 ~ , 6987' WAS LEAKING. PERFORM STATION SURVEY ABOVE AND BELOW AS WELL AS TWO LOG PASSES TO CONFIRM LEAK. NO OTHER LEAKS WERE FOUND WHILE LOGGING 7075' TO SURFACE. 4/14/10 ATTEMPT TO PULL DV @ 6987' RKB. NO SUCCESS. S/D IN STA# 2 @ 4630' RKB & PULLED DV. IN PROGRESS. 4/15/10 PULL DVs @ 6436', 6987' RKB. SET EXT. PKG DV @ 6987' RKB. SET DV @ 6436' RKB. IN PROGRESS. 4/16/10 SET DV @ 4636' RKB. RUN HOLE FINDER UNABLE TO GET GOOD TBG TEST BELOW STA# 4 @ 6436' RKB. IN PROGRESS. 4/28/10 ESTABLISHED T X IA LLR 9 GAL /MIN @ 700 PSI 4/29/10 RAN BAKER ATLAS MICROVERTILOG FROM SURFACE TO 6530', DEPTH CORRECTED TO TUBING DETAIL. MADE MULTIPLE ATTEMPTS, COULD NOT GET BELOW 6530' WITH 3.60" OD X 17' TOOL STRING (OBJECTIVE WAS 7031'). FIELD INTERPRETATION: SAW AREAS OF 80% TO 100% EXTERNAL WALL LOSS AT 6007', 6011', 6102', 6197', 6289', 6352', 6386', 6451'. 5/10/10 PERFORMED LEAK DETECT. PUMPED DIESEL 0.5 BPM DOWN IA AT 1700 PSI, TOOK RETURNS TO FLOWLINE AT 200 PSI. LOCATED LEAK AT TUBING COLLAR AT 6366'. 6/2/10 ATTEMPT TO PULL CATCHER @ 7070' SLM, UNABLE TO PASS 7035' SLM, IN PROGRESS. 6/6/10 BAIL FILL ON CATCHER @ 7095' SLM, PULLED CATCHER SUB @ 7095' SLM, PULLED 2.812" CSA-2 @ 7099' SLM / 7105' RKB, IN PROGRESS. 6/7/10 RAN 4-1/2 D&D HOLE FINDER TO 4 1/2 x 3 1/2 XO @ 7031' RKB, PASS CMIT @1500 PSI. BRUSH & FLUSHED 2.81" NIPPLE @ 7105' RKB, ATTEMPT TO RUN 1.81" NIPPLE REDUCER TO 7105' RKB, SET DOWN IN 4 1/2" x 3 1/2" XO @ 7031' RKB. RAN 2.854" GAUGE RING TO 2.81"DS NIPPLE @ 7105' RKB. IN PROGRESS. 6/12/10 BRUSH 3.5" TBG FROM 7031' RKB TO 7179' RKB. GAUGE TBG TO 2.846" TO 7105' RKB. SET 1.81" NIPPLE REDUCER IN D-NIP @ 7105' RKB. JOB COMPLETE. 6/13/10 ATTEMPTED TO SET 4.5" WEATHERFORD ER PACKER AT 6392'. UNABLE TO GET THROUGH NIPPLE @ 496' (ID=3.812"). MAX TOOL OD=3.74". POOH AND RD. SL TO B&F NIPPLE. 6/15/10 DRIFTED TBG WITH 3.78" x 54" DUMMY TO 6900' SLM. BRUSHED & FLUSHED TBG BETWEEN 6450' & 6300' SLM; BRUSHED NIPPLE @ 496' RKB. DRIFTED TBG WITH 21' x 3" BAILER (MAX OD= 3.78") TO 6900' SLM, NO OBSTRUCTION. READY FOR E-LINE. 6/18/10 ATTEMPTED TO SET WEATHERFORD 4.5" PACKER. COULD NOT GET PAST D-NIPPLE AT A DEPTH OF 496'. O.D. MEASUREMENT OF TOOLS AT SURFACE SHOWED THE PACKER WAS 3.73", AND THE BAKER 20 SETTING TOOL WAS 3.82". WILL EVALUATE AND DECIDE HOW TO SET PLUG ON NEXT RUN. 6/20/10 SET WEATHERFORD 4.5" ER PACKER AT A DEPTH OF 6392' USING HALLIBURTON 3.59" DPU SETTING TOOL. CORRELATED WITH 3 1/8" TITAN GAMMA PERFORATOR. CCL TO MID ELEMENT OFFSET MEAURED AT 18'. 6/23/10 ATTEMPTED P/T ER PACKER @ 6392' RKB; TEST FAILED, PACKER BLEW DOWNHOLE. PULLED 4-1/2 ER PACKER FROM X-OVER @ 7031' RKB. BRUSHED AND FLUSHED f/ 6300' TO 6450' SLM. READY FOR E/L. - 2A-15 Well Events Summary 6/27/10 RAN WEATHERFORD ER PACK~WITH 3.74" RUN OD. SET PACKER AT~0' BELOW THE COLLAR LEAK AT 6367'. USED HES DPU SETTING TOOL, EST SETTING FORCE IS 44,000 POUNDS TO SHEAR WEAK POINT. READY FOR S/L TO TEST. 6/29/10 SET 4.5" ER TEST IN ER PKR @ 6390' MD. COMBO MIT TBG X IA, PASS. JOB COMPLETE 7/2/10 RUN HES 3.69" DPU TO SET 4 1/2" (OAL=36' 4",MIN ID=2.25") WEATHERFORD ER PKR PATCH SNAP LATCH ASSY IN LOWER ER PKR @ 6390' RKB TOP @ 6352' RKB. MITIA TO 2500 PSI ,. PASS JOB COMPLETE. . WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2A-15 Run Date: 6/20/2010 July 3, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-15 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20041-00 ~ ,, ~~~~.~~~ ~~~1) to ~~ 'y ~ ~ 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 ~~ ~aa Fax: 907-273- _ rafael.barreto ~~ Date: ,jam x ~~ ~' ~~~;:~`~' ~a~i~~ Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2A-15 Run Date: 5/10/2010 May 14, 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-15 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20041-00 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.barre Date: ~4!=,'`, .~ Zs~ i~ a ( ~~~ _I~~ ~~~~~ ~~~ Signed: ~, • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2A-15 Run Date: 4/9/2010 Apri123, 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-15 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20041-00 n» ~..:t~~r' ~..~.= z~:l~`! ~° tai; 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.b ~~~ 6"!I i~ i~~~ Lei t,.: Date: 1'f55~~~~/~ /g~b~ Signed: r.; ~. • r~~L.L L~E.a ~~~ PeoACnVE DlagNOStic 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 ` ~` ~~=' ~ ~'-~' `' Y~ ` ~ ~ ~ ` Fax: (907j 245-8952 1) Caliper Report 2) 08-Apr-10 2A-15 Signed Print Name: • 1 Report/ EDE 50-103-20041-00 ~;~ ~ ~ ; ', ~ ~ , Date : ~~ ~ ~ ~~ i ~ a ~•'__"' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL : IsdsasaclaoraaeCcr~a~aeraaflt~i•1®g.~ot~a WEBSITE : vv+nr+r~.~e~®ryd®g.c®m C:\Documenls and Settings\Diane Williatns\Desktop\Ttansmit_Conoco.docx • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. We(I: 2A-15 Log Date: Apri18, 2010 Field: Kupar~lc Log No.: 7399 State: Alaska Run No.: 1 API No.: 50-103-20041-00 Pipet Desc.: 4.5" 12.6 Ib L-80 Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 7,027 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS This caliper data is tied into the top of GLM 5 @ 6,987 (Drillers Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 4.5" tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. A 3-D log plot of the caliper recordings across the interval of a tubing leak is included in this report. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 15%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the tubing logged. r~~ w~~r Field Engineer: Wm. McCrossan Analyst: C. Lucasan & C Waldrop Witness: C. Kennedy ProActive Diagnostic Services, Tnc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS~memorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907} 659-2314 r$5"~ i~~ 1 ~53~ • • PDS Multifinger Caliper 3D Log Plot L, ...~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-15 Date : April 8, 2010 Description : Defail of Caliper Recordings Across Interval of Tubing Leak. • Correlation of Recorded Damag Pipe 1 4.5 in (2.2' - 6999.6') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 2 A-15 Kuparuk ConocoPhillips Alaska, Inc. USA April 8, 2010 A pprox. Tool De viation ^ A pprox. Borehol e Profil e 4 758 1532 2309 GLM 1 3113 ~ ~_ 3900 t a a~ D GLM 2 4701 5497 GLM 3 6304 GLM 4 GLM 5 221 7000 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 221 1 25 50 75 1 J 1 nn 1 Ql, v E Z 125 c 'o 150 ~ 175 200 1 ~j • • PDS Report Overview ~.~_ ~_,, Body Region Analysis Well: 2A-15 Survey Date: April 8, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: G Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body -a~-; metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 1% 10% 20% 40% 40 to over 85% 85% Number of'oints anal sed total = 233 pene loss . 0 223 10 0 114 119 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of "oints dama ed total = 8 8 0 0 0 0 Damage Profile (% wall) ~ penetration body _ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 ('I AA S Bottom of Survey=227 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal LD.: 3.958 in Country: Survey Date: • ELATION SHEET 2A-15 Kuparuk ConocoPhillips Alaska, Inc USA April 8, 2010 Joint No. Jt. Depth (Ft) I'c•n. t)LriF•t (In,.j Pen. Body (Ins.) P~•n. % Mclal I cnz °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 2 (? 0.01 4 3.95 PUP 1 4 t) 0.01 4 I 3.93 1.1 36 U 0.01 4 I 3.93 PUP 1.2 41 it 0.01 3 I 3.93 PIJP 2 45 a 0.01 4 1 3.93 3 76 t) 0.01 2 1 3.90 ` 4 107 U 0.01 i 1 3.92 5 138 t) 0.01 ~ 1 3.87 6 169 t l 0.01 5 I 3.89 _ 7 200 ~) 0.01 ~ 1 3.93 8 231 t) 0.01 4 1 3.93 9 262 U 0.01 1 3.92 10 293 t) 0.01 ~ _' 3.90 11 324 U 0.01 3 U 3.94 12 354 U 0.01 a 1 3.91 13 386 U 0.01 s 1 3.93 14 417 U 0.01 3 1 3.90 15 447 U 0.01 Z 1 3.93 15.1 477 t) 0 U U 3.81 Camco DB Ni le 16 479 U 0.01 3 ? 3.90 17 510 U 0.01 3 1 3.92 18 541 U 0.01 ~ 1 3.88 19 572 U 0.01 3 I 3.88 20 603 i) 0.01 ~ I 3.93 21 634 U 0.01 ~i ! 3.92 22 665 U 0.01 3 1 3.92 23 696 C) 0.01 ~ ~J 3.93 24 727 U 0.01 4 I 3.91 25 758 U 0.01 3 3.92 26 790 U 0.01 4 1 3.92 2 7 821 0 0.01 ~ 1 3.93 28 852 U 0.01 ~ i 3.93 29 883 O 0.01 3 i 3.93 30 914 t) 0.01 ~ i 3.93 31 945 U 0.01 ~ 3.92 32 975 O 0.01 ~ I 3.89 ~ 33 1005 U 0.01 Z 1 3.91 34 1036 i) 0.01 ~' I 3.91 35 1067 i) 0.01 3 ~ 3.91 36 1098 U 0.01 3 I 3.89 37 1128 O 0.01 4 11 3.92 38 1159 (? 0.01 3 1 3.90 39 1190 O 0.01 3 1 3.95 40 1221 U 0.01 4 U 3.94 41 1253 (1 0.01 j 1 3.94 42 1284 t) 0.01 l ? 3.92 43 1315 (? 0.01 i ! 3.92 44 1346 (1 0.01 3 I 3.90 45 1377 0 0.01 2 I 3.90 46 1408 a 0.01 3 I 3.93 ~' _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 2A-15 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 3.958 in Country: USA Survey Date: April 8, 2010 Joint No. Jt. Depth (Ft.) I'c~n. I!I;~~~t (Ins-j Pen. Body (Ins.) I'evi. °~ Mc~t,il IUSC °i~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1439 i' 0.01 ~ 1 3.93 48 1470 i? 0.01 4 1 3.94 49 1501 t i 0.01 ~ ~' 3.93 50 1532 tl 0.01 4 _' 3.90 51 1564 ti 0.02 f3 I 3.90 `~F 52 1596 t) 0.01 3 3.85 53 162 7 i ~ 0.01 3 I 3.86 ` 54 1657 c ~ 0.01 4 i 3.86 55 1689 ii 0.01 4 3.93 56 1720 tl 0.01 3 3.92 57 1751 U 0.01 > I 3.92 ~ 58 1782 (~ 0.01 4 1 _3.89 59 1813 t i 0.01 5 I 3.89 60 1845 i) 0.01 4 _' 3.88 ~ 61 1876 t i 0.01 4 3.89 ~ 62 1907 U 0.02 ti I 3.90 63 1938 U 0.01 4 1 3.89 64 1969 O 0.01 3 1 3.94 ~ 6 2000 (~ 0.01 4 1 3.93 66 2031 i~ 0.01 -~ ~ 3.92 67 2062 ~ ~ 0.01 ~ _' 3.90 68 2090 tr 0.01 ~ 3.87 69 2121 t) 0.01 4 I 3.87 r' 70 2153 (I 0.01 4 ? 3.86 71 2184 U 0.01 3 I 3.~0 72 2215 i 1 0.02 8 I 3.91 73 2246 t) 0.01 i 3.93 74 2277 (I 0.01 ~1 3.94 75 2309 (r 0.01 1 3.91 ~~ 76 2340 U 0.01 s 3.87 ' 77 2371 i 1 0.01 ~ I 3.85 78 2403 (i 0.01 ~ 3.86 t 79 2434 i i 0.01 ~ 3.84 80 2465 (I 0.01 ? ! 3.89 ' 81 2496 t) 0.02 t3 4 3.83 82 2528 (~ 0.01 i 1 3.89 83 2559 11 0.01 d 3.91 ~ 84 2590 i~ 0.03 ~) ~' 3.91 85 2621 t i 0.01 -t ~' 3.91 ~ 86 2652 tr 0.01 1 3 3.91 87 2683 ti 0.01 ~ 3.90 88 2714 ii 0.01 i I 3.88 89 2746 li 0.03 i (1 ? 3.87 90 2777 U Q01 4 3.89 91 2809 U 0.01 3 2 3.88 92 2841 (1 0.01 3 ' 3.87 93 2873 U 0.04 I _; 1 3.89 Shallow ittin . 94 2904 i? 0.01 -1 3.90 95 2936 t ~ 0.01 5 .' 3.91 96 2967 t ~ 0.01 3 I 3.90 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal LD.: 3.958 in Country: Survey Date: i iLATION SHEET 2A-15 Kuparuk ConocoPhillips Alaska, Inc, USA April 8, 2010 Joint No. Jt. Depth (Ft.) I'c~n. 111xc~t (In.) Pen. Body (Ins.) Pen. % Mc lal I cuss % Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 97 2999 ;t 0.01 1 3.89 98 3030 U 0.01 ~ 1 3.88 98.1 3061 ~l 0.04 1 4 3 3.87 PUP Shallow ittin . 98.2 3068 t~ 0 U U N A GLM 1 Latch @ 7:00 98.3 3076 tl 0.01 4 I 3.85 PUP 99 3082 t) 0.01 1 3.86 100 3113 (1 0.03 1 t t ? 3.88 101 3144 0 0.01 -t 3.87 ~ 102 3175 U 0.01 I 3.91 103 3206 ~t 0.01 ~ 3 3.91 104 3237 (> 0.01 ~ 3 3.89 105 3268 U 0.01 1 3.90 106 3299 tl 0.01 -1 I 3.87 107 3331 n 0.02 ~~ 3.89 108 3363 ti 0.01 4 ~ 3,88 109 3394 U 0.04 15 1 3.87 Shallow ittin . 110 3426 U 0.01 4 1 3.89 111 3458 t) 0.01 -1 <' 3.90 112 3490 t) 0.01 1 2 3.91 113 3522 i I 0.01 =t 3.92 114 3553 ±1 0.01 3 1 3.91 115 3585 U 0.02 8 3.90 116 3618 U 0.02 8 ~> 3.87 117 3649 t) 0.01 3 2 3.88 118 3679 U 0.01 5 3 3.82 119 3712 l1 Q_01 ~ I 3.87 120 3743 t) 0.01 1 3.87 121 3776 U 0.03 t ~ _' 3.86 Shallow ittin . 122 3807 U 0.01 4 3.84 123 3838 U 0.01 ~ 3.87 124 3869 0 0.01 4 1 3.89 125 3900 U 0.03 I1 3.87 126 3932 l1 0.01 ~ I 3.91 127 3963 t1 0.02 ~3 ~ 3.90 128 3994 U 0.02 t3 1 3.90 129 4025 t) 0.01 3 1 3.91 130 4055 l~ 0.01 2 _' 3.86 131 4086 U 0.02 ~3 1 3.87 132 4119 O 0.03 13 ~' 3.88 Shallow ittin . 133 4150 (? 0.02 9 2 3.84 134 4181 i~ 0.01 ~ 1 3.89 135 4212 tl 0.01 ~~ 1 3.88 136 4240 t1 0.01 ~ 1 3.90 137 4272 U 0.02 t3 2 3.87 138 4302 it 0.01 3 t 3.86 139 4334 O 0.02 8 4 3.85 140 4364 c? 0.01 4 _' 3.85 141 4396 U 0.01 '~ 1 3.85 142 4429 U 0.03 itl 1 3.86 143 4459 ~ ~ 0.02 is _' 3.87 _ Penetration Body Metal Loss Body Page 3 i PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf L-80 Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: i ILATION SHEET 2A-15 Kuparuk ConocoPhillips Alaska, Inc, USA April 8, 2010 Joint No. Jt. Depth (Ft.) .'en. Utn~~t (Ins.) Pen. Body (Ins.) Pen. %, Metal I uss ",~<> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4491 t 1 0.01 4 :' 3.91 145 4522 O 0.01 3 ? 3.89 146 4553 l) 0.01 ? ~' 3.89 147 4585 i? 0.01 3.88 147.1 4618 t) 0.04 13 -1 3.86 PUP Shallow ittin Lt. De osits. 147.2 4626 U 0 0 U N A GLM 2 Latch @ 3:00 147.3 4632 !~ 0.03 1~ -1 3.88 PUP Shallow ittin . 148 4638 ~.) 0.01 4 1 3.87 ~ 149 4670 U 0.01 1 3.85 150 4701 a 0.01 3 I 3.85 151 4734 t) 0.02 9 I 3.86 152 4766 (1 0.02 9 ? 3.87 153 4797 t) 0.02 8 3 3.89 154 482 9 t) 0.01 3 1 3.89 155 4861 (1 0.02 8 1 3.89 156 4892 U 0.01 4 ~' 3.87 157 4924 U 0.01 i 3.86 158 4956 ~) 0.02 8 _' 3.86 159 4988 t) 0.02 ~ ? 3.83 160 5020 l) 0.03 9 2 3.84 161 5052 tl 0.01 2 1 3.87 162 5083 (~ 0.01 ~ ~' 3.87 163 51 15 t) 0.01 3 1 3.85 164 5147 O 0.01 4 3.88 165 5179 U 0.01 3 3.89 166 5110 t! 0.01 i I 3.88 167 5243 U 0.02 t3 i 3.87 168 5275 t) 0.03 10 ~ 3.85 169 5307 U 0.02 8 ~ 3.83 170 5338 l~ 0.01 Z ! 3.83 171 5370 !) 0.01 4 I 3.83 172 5402 a 0.02 8 ~ 3.88 173 5434 t) 0.01 4 3.88 174 5465 c) 0.02 ti 1 3.88 175 5497 U 0.02 ~ 3.88 176 5530 U 0.01 3 ~ 3.88 177 5561 O 0.02 t3 3.86 °~ 178 5594 U 0.01 a 3.84 - 179 5625 +) 0.01 a ~ 3.82 '' 179.1 5657 U 0.02 '> 3.82 PUP 179.2 5664 O 0 (1 U N A GLM 3 Latch Cl 4:00 179.3 5671 a 0.03 1 C) 3.84 PUP 180 5677 O 0.01 ~ 2 3.85 181 5708 U 0.01 3 ? 3.88 182 5740 (1 0.01 4 2 3.88 183 5771 U 0.01 5 3.91 184 5804 t~ 0.01 4 { 3.88 185 5836 U 0.03 9 3.87 186 5869 (? 0.03 1 U -1 3.89 187 5899 U 0.01 4 3.86 ___ Penetration Body Metal Loss Body Page 4 ~ i PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 Well: 2A-15 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: April 8, 2010 Joint No. Jt. Depth (Ft.) fern. Ulrsc~t (Ins.) Pen. Body (Ins.) Pen. % alel~il foss °io Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 188 5931 !) 0.01 5 -t 3.89 189 5962 i) 0.01 3 I 3.87 190 5994 (~ 0.01 3 1 3.86 191 6024 i) 0.03 e~ 6 3.86 192 6056 a 0.02 ti 1 3.86 193 6087 l) 0.02 ti 1 3.84 Lt. De osits. 194 6117 i) 0.03 ~) ~l 3.89 195 6149 t ~ 0.01 5 -1 3.86 196 6180 U 0.02 F3 3.89 197 6212 a 0.03 ~3 3.86 198 6242 t~ 0.01 3 ? 3.85 199 6272 U 0.03 9 ! 3.86 200 6304 U 0.01 4 1 3.87 201 6334 i ~ 0.02 t3 4 3.88 202 6366 r ~ 0.01 > ; 3.88 ~ 203 6396 U 0.03 9 4 3.88 203.1 6428 t) 0.03 ~) 3.89 PUP 203.2 6435 U 0 U ~) N A GLM 4 Latch @ 9:30 203.3 6442 U 0.03 10 4 3.89 PUP 204 6448 U 0.01 4 ~ 3.88 205 6479 i> 0.01 5 I 3.86 206 6510 i ~ 0.0'2 9 I 3.86 207 6542 t) 0.02 ti 1 3.85 208 6573 U 0.01 4 ? 3.86 209 6604 c) 0.01 4 ? 3.88 210 6635 U 0.03 12 3 3.87 Shallow ittin . 211 6667 U 0.01 ' 3.86 212 6698 U 0.01 4 1 3.85 213 6730 t) 0.01 2 3.85 214 6762 O 0.01 -' 3.84 215 6794 ~) 0.01 i ~' 3.86 216 6825 (~ 0.01 4 1 3.89 217 6856 ~ ~ 0.01 3 3.88 218 6887 +~ 0.01 3 ' 3.89 219 6918 U 0.03 11 _' 3.89 220 6949 O 0.01 3 ? 3.86 220.1 6979 t~ 0.03 9 1 3.87 PUP 220.2 6987 U 0 i) a N A GLM 5 Latch C~ 10:00 220.3 6994 U.(_~6 0.02 7 3.87 PUP 221 7000 c) 0 t) i) 3.88 _ Penetration Body Metal Loss Body Page 5 ConocoPhillips Alaska, Inc. KRU 2A-15 2A-15 API: 501032004100 Well T e: PROD An le TS: 40 de 7693 TUBING (o-7o3t, OD:4 500 ~ SSSV Type: NIPPLE Orig Com letion: 8/9/1985 Angle @ TD: 40 deg @ 8130 . , ID:3.958) ~ : Annular Fluid: Last W/O: 5/3/2001 Rev Reason: ADD TTL ELMD Reference Lo Ref Lo Date: Last U ate: 9/7/2007 Last Ta TD: 8130 ftK6 "I Last Ta Date: Max Hole An le: 46 de 3900 ! Casin Strin -ALL STRINGS C .~ Descri lion Size To Bottom TVD Wt Grade Thread 1 CONDUCTOR 16.000 0 104 104 62.50 H-40 I~ .~ SURFACE 9.625 0 3373 2789 36.00 J-55 PRODUCTION 7.000 0 7442 5715 26.00 J-55 ~ ~ LINER 5.000 7212 8112 6225 15.00 J-55 . ~ ~ Tubin Strin -TUBING 4 + Size To Bottom TVD Wt Grade Thread I I 4.500 0 7031 5422 12.60 L-80 Ibt 3.500 7031 7179 5526 9.30 L-80 $rd 2.875 7179 7649 5870 6.50 L-80 H d 511 I ~ 2.375 7651 7784 5973 4.70 J-55 8rd .l . Perforations Summa _ _ ~ Interval TVD Zone Status Ft SPF Date T e Comment TUBING (7031-7179 7691 - 7744 5902 - 5943 C~,UNIT B 53 6 10!7/1985 IPERF SOS 3 3/8" Ultra Jet; 60 de hasin , oD:3.5o0, ID2.99z) 7857 - 7906 6029 - 6067 A-3 49 6 10/7/1985 IPERF SOS 3 3/8" Ultra Jet; 60 de hasin _ Stimulations 8 Treatments Int®rval Date T e Comment 0 - 0 4/2/1997 Scale Inhibitor Pum 10.7 BBIs SW 8 SS5206 Preflush Gas Lift Mandrels/Valves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3077 2582 CAMCO KBG-2 GLV 1.0 BK 0.156 1260 6/15/2006 2 4630 3668 CAMCO KBG-2 OV 1.0 BK 0.250 0 1/9/2007 3 5668 4439 CAMCO KBG-2 DMY 1.0 BK 0.000 0 6/12/2006 ~ 4 6436 4999 CAMCO KBG-2 DMY 1.0 BK 0.000 0 4/24/2003 ~ ~ 5 6987 5390 CAMCO KBG-2 DMY 1.0 BK 0.000 0 5/15/2001 Other lu s e ui .et c. -COMPLETION De th TVD T e Descri lion ID xo psas-7s5o 496 496 NIP CAMCO 'DB' NIPPLE 3.812 , oD:z.a75) 7040 5428 PBR BAKER 4.000 7054 5438 PKR BAKER 7"X3"'FHL' H drostatic acker 3.000 - 7105 5474 NIP CAMCO'DS' ni le 2.812 7145 5502 Slotted 2.992 ~ TBG 7649 5870 XO 2.375 7650 5871 OVERSHOT BAKER BOWEN OVERSHOT 3.125 7690 5901 Blast Rin s 2.375 7760 5955 SEAL Locator sub & 5.5" seals 1.995 7761 5956 PKR BAKER 'DB' PACKER 3.250 TUBING ssl 77aa 7763 5957 Blast Rin s Chemical cut 7755' &7758' RKB~ tubin ossibl severed 7/29/01 2.375 p - , OD'2.375, 7764 5958 SBE SEAL BORE EXTENSION 3.250 IDa995) 7778 5969 NIP CAMCO'D'NIPPLE 1.812 7783 5973 SOS 2.000 7784 5973 GUIDE OTIS WIRELINE RE-ENTRY GUIDE - TTL ELMD @ 7778' ON OTIS TEMP LOG 10/10/1985 2.000 Fish - FISH sEn~ (776x7761 De th Descri lion Comment , oD'2.375) 7651 FISH left in hole; Location Unknown JUNK LEFT IN HOLE; From 9116190 - workover 5/3/01 pulled junk u to new level 7111 ''. Blast Rings General Notes p76?-77sa, Date Note oo:z.soo) 5/18/2001 NOTE: Chemical cuts 7756' and 7755' MD in 2 3/8"TBG unable to ass throw h cuts. 5/9/2006 NOTE: WAIVERED WELL: IA x OA x OOA -PROD CSG x FORMATION COMMUNICATION I i Pert (7857-7906) ~ ~ I~!/ELL LQG S TRANSMITTAL PI~AiC71VE D'u-gNOS1ic SERVICES ~IVC. 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/ MTTj 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 9951$ Fax: (907 245-8952 1 J Caliper Report 04-Mar•10 2A-16 1 Report/ EDE 50-103-20042-00 2) - ---- --- . __ ~~ 1~~a~ __ ~ _ Signed : Date Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ----- -' - __- - --.: WEBSITE: <: -- -- C'~Documenis and SettingslDiane Williams\Desktop\Transmit_Conoco.docx • • Memory Multi-Finger Caliper S La-g Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-16 Log Date: March 4, 2010 Field: Kuparuk Log No.: 10619 State: Alaska Run No,: 2 API No.: 50-103-20042-00 ', Pipet Desc.: 7" 26 Ib. J-55 Top Log Intvl1.; Surface Pipet Use: Production Casing Bot. Log Intvl1.: 8,560 Ft. (MD) Inspection Type : Con~vsive & Mechanical Damage Inspection COMMENTS This caliper data is tied Into the Sch/umberger Leak Detect Log (May 18, 2009) ~ 6,912'. This log was run to assess the condition of the production casing with respect to corrosive and mechanical damage. The caliper recordings indicate the 7" production casing logged appears to be in good to poor condition, with a possible hole recorded in joint 135 (5,834'). A 3-D log plot of the caliper recordings across this interval is included in this report. Wail penetrations ranging from 20% to 93% wall thickness are recorded in 77 of the 198 joints logged. Recorded damage appears as apparent wear throughout the casing logged with intermittent areas of isolated pitting. No significant areas ofcross-sectional wall toss are recorded throughout the casing logged. The caliper recordings indicate intermittent areas of deposits from 8,362' to 8,543', restricting the LD. to 5.27" at 8,512'. A graph illustrating minimum recorded diameters on a joint-by joint basis is included in this report. The caliper recordings indicate slight buckling from surface to --1,800', moderate budding from 250' to -290', and slight bends at 4,342' and 4,359'. This is the second time a PDS caliper has been run in this well and the first time the 7" production casing has been logged. MAXIMUM RECORDED WALL PENETRATIONS: Possible Hole (93%) Jt. 135 ~ 5,834 Ft. (MD) ' Isolated pitting (79%) Jt. 134 ~ 5,827 Ft. (MD) Isolated pitting (59%) Jt. 148 ~ 6,398 Ft. (MD) Isolated pitting (58%} Jt. 139 @ 6,032 Ft. (MD) Isolated pitting (57%) Jt. 137 Gc~ 5,928 Ft. (MD) MAXIMUM RECORDE D CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 12°~} are recorded throughout the casing togged. MAXIMUM RECORDED ID RESTRICTIONS: ' Deposits Minimum I.D. = 5.27" Jt. 197 @ 8,512 Ft. (MD} Deposits Minimum I.D. = 5.47" Jt. 198 ~ 8,542 Ft. (MD) Deposits Minimum I.D. = 5.64" Jt. 194 cQ 8,379 Ft. (MD) Deposits Minimum I.D. = 5.81" Jt. 135 Q 5,843 Ft. (MD} ' Deposits Minimum I.D. = 5.86" Jt. 196 cQ 8,490 Ft. (MD) t Field En ineer: G. Etherton Analyst: C. Waldrop Witness: R. Overstreet & S. Heim ProActive Diagnostic Services, Inc, / P.O. Box 1369, Stafford, TX 77497 Phone: {281) or {88$) 565-9085 Fax: (281) 565-1369 E-mail: PDSCamemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907) 659-23f4 ' i~s5 ~N~ rgNaa ' • • PDS Multifinger Caliper 3D Log Plot ' ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-16 Date : March 4, 2010 Description : Detail of Caliper Recordings Across Possible Hole in 7" Liner. Depth Max. Pen. (°~) Max. I.D. (ins.) 3-D Log Image Map 1ft:240Rr0 100'6 7 265' 0° 90° 180° 270° 0° Min.1.D. (ins.) 6 7 Nominal I.D. (ins.) 6 7` t 133 J i I ~ + -~ _ i - -_ - o n 5780 I j--.: 5790 Joint 134 -- Isolated pitting 5800 79% Wail _ ? .. Penetration 5$10 Shallow Apparent Wear I I , _ _. ~ 5820 -~_-~ . - - ,.._._. - - , _ 5830 i Joint 135 _ - : - _- ' Possible Hole (5,83x') 5840 . ~ ~ 93°~ Wall : I ~ ~ ` Penetration 5850 Shallow ~°_ Apparent Wear I ' 5860 ', _ _ -~-~ ~ ~. I . , _ . 5870 j Joint 13fi ~ i Isolated pitting 5880 49°k Wall R Penetration i • ~. - -- shallow 5890 ApparentlNear ' ~ ~ I ~ Comments Depth Max. Pen. (°Y6) ~ 1ft:240ft 0 Nominal l.D. pns.) 6 7~ Min. I.D. (ins.) 6 7 Max. I.D. (ins.) 100 6 7 3-D 0° 90° 180° 270° 0° i Correlation of Recorded Damage to Borehole Profile ?.~ Pipe 1 7. in (43.1' - 8534.9') Well: 2A-16 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Uate: March 4, 2010 ^ Approx. Tool De viation . Approx. Borehol e Profil e 1 43 25 1074 ~ ~\~S 50 2154 75 3233 v ~ ~ ~ Z 100 c 4311 ~ c ~ v o p 125 5394 150 ~ 6467 175 ~ r 7544 i 19t; 8535 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool Deviatio n (degr ees) Bottom of Survey = 198 • ,~~ Minimum Diameter Profile Well: 2A-16 Survey Date: March 4, 2010 Field: Kuparuk Tool: UW MFC 40 No. 217957 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 6.276 inches 2.75 1 6 it 16 21 26 31 36 41 46 51 56 61 66 71 76 81 86 y 91 E 96 Z 101 .. 106 111 116 121 126 131 136 141 146 151 156 161 166 171 176 ls1 186 191 196 Minimum Measured Diameters (In.) 3.25 3.75 4.25 4.75 5.25 5.75 6.25 • PDS Report Overview ~, ~,. Body Region Analysis Well: 2A-16 Survey Date: March 4, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217957 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 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 198 pene. 0 13 118 56 10 1 loss 0 194 4 0 0 0 Damage Configuration (body ) 150 100 50 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of "oints dama ed total = 196 49 0 146 0 1 Damage Profile (% wall) penetration body ,__i-. metal loss body 0 50 1 51 Bottom of Survey = 198 100 101 151 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • -LATION SHEET 2A-16 Kuparuk ConocoPhillips Alaska, Inc. USA March 4, 2010 Joint No. Jt. Depth (Ft.) I'e°n. Uptie~l (Inc) Pen. Body (Ins.) Pen. °i~ Mcl,rl I ~~ss 4i. Min. LD• (Ins.) Damage Profile Comments (%wall) 0 50 100 1 43 U.(17 0.05 15 4 6.25 Shallow A arent Wear. Sli ht Bucklin . 2 84 U 0.03 ~) -4 6.25 Shallow A arent Wear. ~ 3 128 U. 14 Q04 1 r) -1 6.27 Shallow A arent Wear. 4 171 U.t1f3 0.03 8 i 6.25 5 214 I) 0.04 1 1 '~ 6.25 Shallow A arent Wear. Bucklin . 6 257 U 0.04 i _' 'i 6.23 Shallow A ar nt Wear. Bucklin . 7 301 U 0.03 9 4 6.24 Shallow A arent Wear. Sli ht Bucklin . 8 344 t). I ; 0.03 ~) -1 6.25 Shallow A arena Wear. 9 387 0 0.04 12 6.25 Shallow A arent Wear. - 10 430 U.1 ~' 0.04 1 U 4 6.23 Shallow A arent Wear. 11 473 U. I U 0.06 16 ~i 6.25 Shallow A arent Wear. Sli ht Bucklin . 12 516 U.UG 0.09 24 7 6.25 A arent Wear. 13 560 U.1 1 0.1 1 3U tS 6.27 A arent Wear. 14 603 U.1 I 0.12 s3 N 6.26 A arent Wear. 15 646 (~. IU 0.10 28 ~ 6.26 A arena Wear. Sli ht Bucklin . 16 689 U.1 U 0.10 2£i - 6.23 A arent Wear. 17 732 U. l U 0.09 ~ 5 - 6.25 A arent Wear. 18 776 0 0.08 22 ~~ 6.25 A arentWear. 19 819 U.U6 0.09 25 ~., 6.23 A parent Wear. 20 862 O.Uc) 0.11 1U H 6.25 A arent Wear. Sli ht Bucklin . 21 906 O.U6 0.10 27 (, 6.27 A arentWear. 22 949 U.U)i 0.08 22 b 6.27 A arent Wear. 23 989 U.(t6 0.07 ~ t) - 6.25 Shallow A arent Wear. 24 1031 U. l O 0.09 Z=6 t, 6.26 A arena Wear. 25 1074 U.Ui 0.07 .9 -> 6.25 Sh~ Ilow A arent Wear. 26 1118 a 0.06 I i -I 6.25 Shallow A arent Wear. Sli ht Bucklin . 27 1161 U 0.08 ?2 t, 6.25 A arent Wear. 28 1204 U 0.06 I E; > 6.25 Shallow A arent Wear. 29 1247 U.U(~ 0.05 15 5 6.25 Shallow A arent Wear. 30 1291 U.Ub 0.04 12 5 6.27 Shallow A arent Wear. 31 1334 U 0.04 1 U 3 6.25 Shallow A arentWear. 32 1377 U 0.04 1 t) -1 6.25 Shallow A arent Wear. Sli ht Bucklin . 33 1421 U 0.06 17 .5 6.27 Shallow A arent Wear. 34 1462 U.US 0.06 1 ~ 4 6.27 Shallow A arent Wear. 35 1506 U 0.05 7 4 6.27 Shallow A arent Wear. 36 1548 i ~ 0.04 1 1 6.25 Shallow A ~ arent Wear. 37 1591 U 0.03 ~) i 6.25 Shallow A arent Wear. Sli ht Bucklin . 38 1634 U 0.03 8 4 6.24 39 1678 U 0.05 15 5 6.27 Shallow A arent Wear. 40 1721 U.1 U 0.06 1' t~ 6.28 Shallow A arent Wear. 41 1764 U. 14 0.05 I ~ (, 6.25 Shallow A arent Wear. Sli ht Bucklin 42 1808 O.U6 0.05 1 '~ (~ 6.27 Shallow A arent Wear. 43 1851 U 0.04 1 ~' i 6.25 Shallow A arent Wear. 44 1894 U-US 0.06 17 ~~ 6.26 Shallow A arent Wear. 45 1937 (~ 0.05 I d (, 6.27 Shallow A arent Wear. 46 1981 t ~ 0.06 ) "~ 6.26 Shall w A arent Wear. 47 2024 U.tLS 0.06 15 -k 6.26 Shallow A arent Wear. 48 2068 U.Ub 0.06 15 -1 6.27 Shallow A arent Wear. 49 211 1 I1 0.04 11 5 6.28 Shallow A arent Wear. - 50 2154 U 0.04 1 I (~ 6.28 Shallow A arent Wear. _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • iLATION SHEET 2 A-16 Kuparuk ConocoPhillips Alaska, Inc USA March 4, 2010 Joint Jt. Depth Pen. Pen. Pori. b1c~I,~I Min. Damage Profile No. (Ft.) Upset Body `%, l os~ LD• Comments (% wall) (Ins.) (Ins.) °,~, (Ins.) 0 50 100 rS I Bunn I nn~ I nns I iz I r. I ti~~ ., en....,,.,~~na,~. 66 2847 ! I 0.04 12 t~ 6.29 Shallow A arent Wear. 67 2890 t).1 1 0.05 13 f> 6.28 Shallow A arent Wear. 68 2929 U 0.04 12 !. 6.27 Shallow A arent Wear. 69 2973 U 0.04 I2 (~ 6.28 Shallow A arentWear. 70 3016 U. t Z 0.05 15 6.27 Shallow A arent Wear. 71 3060 U.1 1 0.04 12 G 6.28 Shallow A arent Wear. 72 3103 (I 0.05 13 6.29 Shallow A arent Wear. 73 3146 O.1 ; 0.04 I Z - 6.27 Shallow A arent Wear. 74 3190 il.~ 3 0.05 13 t3 6.29 Shallow A arent Wear. 75 3233 t).[)i 0.06 1 i ~ 6.29 Shallow A arent Wear. 76 3'277 !1 0.05 t; v 6.25 Shallow A arent Wear. 77 3319 U 0.05 1=1 - 6.25 Shallow A arent Wear. 78 3363 t).tl i 0.04 1_' (> 6.25 Shallow A arent Wear. 79 3406 (I 0.05 1 ~ 6.25 Shallow A arent Wear. 80 3450 (? 0.05 15 6.28 Shallow A arent Wear. 81 3493 !) 0.05 15 ~ 6.28 Shallow A arent Wear. 82 3536 (LUt> 0.05 13 F; 6.28 Shallow A arent Wear. 83 3580 U. I!) 0.08 21 8 6.28 A arent Wear. 84 3622 ll 0.04 1 1 6 6.28 Shallow A arent Wear. 85 3665 ~! 0.06 627 Shallow A > arent Wear. 86 3708 ~! 0.04 Ei.2> ; _Sliallc~w_,1t~>.~rE>nI Wc~,~r_____ 0 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf )-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal LD.: 6.276 in Country: Survey Date: ELATION SHEET 2 A-16 Kuparuk ConocoPhillips Alaska, Inc USA March 4, 2010 Joint No. Jt. Depth (Ft.) Pen. Ul~sel (Ins.) Pen. Body (Ins.) Pen. io Mc~1al I cuss `;4, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 101 4354 O 0.06 16 6 6.13 Sli ht Bend. Shallow A arent Wear. 102 4398 0 0.05 15 6.27 Shallow A arent Wear. 103 4441 O US 0,16 45 ti 6.25 Isolated ittin Shallow A arent W ar. 104 4485 t).1 ; 0.06 17 ti 6.28 Shallow ittin Shallow A arentWear. 105 4528 O.10 0.05 1 5 6.26 Shallow A arent Wear. 106 4571 U.U~ 0.06 I (i Yi 6.29 Shallow A arent Wear. 107 4615 0 0.05 15 t; 6.27 Shallow A arent Wear. 108 4658 0 0.04 12 !, 6.25 Shallow A arent Wear. 109 4701 O.1 ~' 0.05 13 - 6.29 Shallow A arent Wear. 110 4744 !1 0.05 14 G 6.27 Shallow A arent Wear. 111 4787 U 0.05 15 6.27 Shallow A arent Wear. 112 4831 O 0.05 14 i 6.27 Shallow A arent Wear. 113 4875 U.1 _i 0.05 13 G 6.25 Shallow A arent Wear. 114 4917 0 0.05 14 7 6.26 Shallow A arent Wear. 115 4960 t) 0.06 15 t3 6.29 Shallow A arent Wear. 1 16 5004 i) 0.05 14 (> 6.28 Shallow A arent Wear. 117 5047 0. 1 Z 0.05 15 -" 6.25 Shallow A arent Wear. 1 18 5090 U.14 0.05 13 - 6.29 Shallow arent Wear. 119 5134 U 0.05 t 3 6.28 Shallow A arent Wear. 120 5177 0.16 0.06 15 ~~ 6.29 Shallow A arent Wear_ 121 5221 0. I I 0.05 14 (, 6.28 Shallow A arentWear. 122 5264 U 0.05 14 ti 6.29 Shallow A arent Wear. 123 5307 0.05 0.07 20 9 6.28 Shallow ittin Shallow A arent Wear. 124 5351 O.US 0.06 16 6.28 Shallow ittin Shallow A arent Wear. 125 5394 +).05 0.07 i t3 I t~ 6.27 Shallow A arent Wear. 126 5438 !~ 0.08 Z > - 6.25 Isolated ittin Shallow A arent Wear. 127 5481 U 0.08 12 ~~ 6.26 Isolated ittin Shallow A arentWear. 128 5525 O.U8 0.07 19 ti 6.28 Shallow A arentWear. 129 5568 0.0(> 0.07 2 I - 6.28 Isolated ittin Shallow A arent Wear. 130 5612 U 0.06 I6 ii 6.27 Shallow A arent Wear. 131 5655 U.09 0.08 22 ti 6.27 A arentWear. Sli ht Bucklin . 132 5698 U 0.05 15 2~ 6.27 Shallow A arent Wear. 133 5741 U 0.06 17 t3 6.27 Shallow A arent Wear. 134 5785 Q_06 0.29 79 1 ? 6.26 Isolated ittin Shallow A arentWear. 135 5828 U 0.34 ~) i 1 t~ 5.81 Possible HOLE. Shallow A arent Wear. 136 5867 U 0.18 49 '~ 6.21 Isolated ittin Shallow A arentWear. 137 5910 0.06 0.21 57 <`~ 6.23 Isolated ittin Shallow A arent Wear. 138 5954 U 0.10 Z9 ~ I 6.25 Isolated ittin Shallow A arent Wear. 139 5997 0 0.21 5£i fi 6.26 Isolated ittin Shallow A arentWear. 140 6041 0.05 0.07 19 6.25 Shallow ittin Shallow A arent Wear. 141 6084 0 0.14 S7 6.27 Isolated ittin Shallow A arent Wear. 142 6127 QOi 0.13 35 7 6.27 Isolated ittin Shallow A arentWear. 143 6171 (1.15 0.16 43 8 6.27 Isolated ittin Shallow A arent Wear. 144 6214 U.05 0.13 36 8 6.25 Is lated ittin Shallow A arent Wear. 145 6257 O.US 0.16 45 i 6.25 Isolated ittin Shallow A arent Wear. 146 6300 0 0.07 I t3 Y3 6.24 Shallow ittin Shallow A arent Wear. 147 6337 0 0.14 40 6.27 Isolated ittin Shallow A arent Wear. - 148 6380 0-19 0.22 5~) 1 U 6.28 _ Isolated ittin Shallow A arent Wear. 149 6423 O.U; 0.10 27 ~) 6.27 Isolated ittin Shallow A arent Wear. 150 6467 U. ~ ~ 0.12 2 Yi 6.23 Isolated ittin Shallow A arent Wear. _ Penetration Body iVletal Loss Body Page 3 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 2 A-16 Kuparuk ConocoPhillips Alaska, Inc. USA March 4, 2010 Joint No. Jt. Depth (Ft.) I'en. Ul~sc'1 (Ins.) Pen. Body (Ins.) Pen. % Metal loss °r~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 151 6510 U.17 0.12 32 9 6.25 Isolated ittin Shallow A arentWear. 152 6554 O 0.08 23 9 6.25 Isolated ittin Shallow A arent Wear. 153 6597 0.07 0.07 19 7 6.24 Shallow A arentWear. 154 6641 (? 0.11 30 7 6.27 Isolated ittin Shallow A arent Wear. - 155 6684 O 0.11 S1 £3 6.25 Isolated ittin . Shallow A arent Wear. - 156 6727 U 0.12 ~2 6.25 Isolated ittin Shallow A arent Wear. 157 6771 1).115 0.08 Z 1 8 6.26 Isolated ittin Shallow A arent Wear. 158 6814 1) 0.06 17 ;s 6.27 Shallow A arent Wear. 159 6856 U 0.07 2U .; 6.26 Isolated ittin .Shallow arentWear. 160 6900 U.O6 0.10 Z7 t5 6.26 Isolated ittin Shallow A arentWear. 161 6943 U.U6 0.07 20 8 6.24 A arent Wear. 162 6986 0 0.09 25 8 6.24 Isolated ittin Shallow A arent Wear. 163 7025 0.06 0.07 2U £3 6.24 A arent Wear. 164 7069 0.07 0.13 i5 £f 6.25 Isolated ittin Shallow A arent Wear. 165 7112 0.(16 0.07 16 '> 6.26 A arent Wear. 166 7155 U 0.08 23 c; 6.28 A arent Wear. 167 7199 0.06 0.08 1 9 I U 6.25 A arent Wear. 168 7242 l) 0.08 2 I ~~ 6.24 Isolated ittin Shallow A arent Wear. 169 7285 0 0.08 ..' 1 " 6.26 Isolated ittin Shallow A arent Wear. 170 7329 ~) 0.07 2~) B 6.25 A arentWear. 171 7372 U.U7 0.07 20 10 6.29 A arentWear. 172 7415 U 0.07 19 7 6.24 _ Shallow A arentWear. ' 173 7458 O 0.09 26 8 6.28 Isolated ittin Shallow A arent Wear. ~' 174 7502 U.O6 0.07 19 ~) 6.29 Shallow A arentWear. 175 7544 ~ ~.US 0.07 19 Ej 6.28 Shallow A arent Wear. 176 7587 1.1)5 0.07 ZU 'i 6.29 A arent Wear. 177 7631 11.06 0.11 3U I+~ 6.28 Isolated ittin Shallow A arent Wear. 178 7674 t) 0.07 19 is 6.27 Shallow A arent Wear. 179 771 7 u.US 0.08 12 I i! 6.27 A arent Wear. 180 7761 t).Ob 0.08 22 '~ 6.26 A arentWear. 181 7804 (L07 0.09 Z3 I U 6.22 A arent Wear. 182 7848 O.U8 0.10 26 1 I 6.26 A arent Wear. 183 7891 U.Uf3 0.08 22 ~~ 6.25 A arent Wear. 184 7934 O.U7 0.09 24 IO 6.27 A arent Wear. 185 7977 U.Ut~ 0.09 26 1 I 6.28 A arent Wear. 186 8020 U.i17 0.18 49 ti 6.25 Isolated ittin Shallow A arent Wear. 187 8062 11.07 0.10 27 111 6.27 Isolated ittin Shallow A arent Wear. 188 8105 C).U7 0.08 21 li 6.25 A arent Wear. 189 8147 U.12 0.07 ?U ES 6.26 Isolated ittin Shallow A arentWear. 190 8190 U.llb 0.08 ~ 3 ~~ 6.27 Isolated ittin Shallow A arent Wear. _ 191 8234 U.US 0.07 2l) ti 6.25 A arent Wear. 192 8277 U.U7 0.1 1 ~ 1 1 1 6.28 Isolated itti Shallow A arent Wear. 193 8318 U.l)8 0.11 ~ 1 9 6.24 Isolated ittin . Shallow A arentWear. 194 8362 t) 0.14 t9 1U 5.64 Isolated ittin Shallow A arent Wear. De 195 8405 0.1 U 0.13 35 7 5.88 A arent Wear. De osits. 196 8449 U.(19 0.14 3t~ tt 5.86 Isolated ittin Shallow A arent Wear. De c- 197 8492 t).U5 0.14 S7 111 5.27 Isolated ittin Shallow A arent Wear. De 198 8535 l).l7 0.18 51 lU 5.47 A arentWear. De osits. Penetration Body Metal Loss Body Page 4 ~~~ ~ PDS Report Cross Sections Well: 2A-16 Survey Date: March 4, 2010 Field: Kuparuk Tool Type; UW MFC 40 No. 217957 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f J-55 Anal st: C. Waldro Cross Section for Joint 135 at depth 5834.05 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 91 Tool deviation = 58 ° Finger 27 Penetration = 0.336 ins Possible Hole 0.34 ins = 93% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ -- PDS Report Cross Sections ~.~ ~~ „ Well: 2A-16 Survey Date: March 4, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217957 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f J-55 Anal st: C. Waldro Cross Section for Joint 134 at depth 5826.97 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 89 Tool deviation = 60 ° Finger 24 Penetration = 0.286 ins Isolated pitting 0.29 ins = 79% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 - PDS Report Cross Sections ~ ,. Well: 2A-16 Survey Date: March 4, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217957 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f J-55 Anal st: C. Waldro Cross Section for Joint 197 at depth 8511.56 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 90 Tool deviation = 61 ° Finger 29 Projection = •1.02 ins Deposits Minimum I.D. = 5.27 ins HIGH SIDE = UP • r1 L J Cross Sections page 3 ~ PDS Report Cross Sections 1~ --- - Well: 2A-16 Survey Date: March 4, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 217957 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 f j-55 Anal st: C. Waldro Cross Section for Joint 198 at depth 8542.15 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 90 Tool deviation = 67 ° Finger 5 Projection = -0.778 ins Deposits Minimum I.D. = 5.47 ins HIGH SIDE = UP • r1 LJ Cross Sections page 4 2A-16 ConoeoPhillips ~ Attributes An le 8 MD TD ~ tl1 t re APi'UWI Eleld (lame Well St,atris N:; !fiKEi ' Act Btm (hKb1 . ... SC1D3_DD4_00 KVPARUK RNER UNIT PRGD 6~~ E 7.90000 9888.0 ppml HZS I Dnte Anno4Nron _- Enrl Uate KE ' - ;rJ Ihj Rig Relea9e aate weeepn ~ -zA-ta, v2n~nto ro :+a PM - b° LCCKEG OUT 425 1/10x009 Last W! is 34.50 6!_0!1985 mAer:- Annamuan Depth IttKBI End Gate AnnoHblon Lat+t Mod ey Entl Date Lost Toy. 5LM 9.806.0 112012010 Rev Reason. Tay. G'LV C,'O. Cut Tbg. Pull Imosba 1;29,'2°010 Casing Strings String O D Siring ID Set Depm Se[ Depth (TVDI String Wt Shing Casmg Dts.npbon (eni (in; lop lhKBl (itKBJ IftKB1 Itbuitl 61aeW Strang ToP lnru ca+n.cTOa. laa CONDUCTGR 1 6 15-060 24.0 104.0 104.0 62.50 .H-40 -~ SAFETi viv SURFACE 9 (8 6. 65 0. 3.6 7.0 2.85 .1 36.00 J-5 . 1 eb9 o oRODUCTION 7 6 151 0 0 9.017.0 5 790 1 _^6 00 J-55 LINER 4 151 8.725 0 9.888.0 15 00 .1-55 °fi3LFf zeta Tubin Strin s 9 - string o D string ID set Depm sel Depm i7vD1 shing ,N, so-:ni; SURFACE. ! lubmg aescripbon finl IIRI rop lttK61 (hKBI IttK6'; IIY.c~h'. ':>racle 5'.ring lap Thr~ saov I TUBING 3 ! I~ .992 O G 85720 E.5s4 5 9.30 J-55 EUEBrdAEMOD oAS uFr 4 ].1 TUBING 2 7. 9 2441 8.57.0 8.7020 5.6223 6.5U J-55 E'dE TUBIN ' 3; 8 1 99. 8.702 0 9 396.0 E 031 B 4 7 N-80 EUE 3,U Othsr I n Hols All Jewel :Tubin Run 8 Retrievable Flsh etc. 'A' L"Fi' 5 318 Top Deptlt . ITVD) Tap Intl T hKB 181 i'1 Lks< - ion Comment Run Date ID IInV 3A3 ccr. 5 '.1 1.899 1.785.7 36.80 S AFETY VLV Camco TRDP-IA-SSA' LOCKED OUT 1!2212070 8/1511991 2.813 . 2.815 2386.3 54.19 G AS LIFT CAMCO/KBUG(1j0MY(8Kgl Comment: STA 1 iJ22l2010 2.922 GAS LILT 4 _ _ Y ommeM' e27e __. 4 Y ommeM: !1 5.794 085.8 55.84 G AS LIFT CAMCO/KBUG/1/DMY/BK/1! Comment: EM Pkg STA 4 12/°O/"2009 0.9C2 aAS LIFT. a.etz _ 6 °05 4.314 4 56.44 G A5 LIFT CAMCO(KBUG/1;DMY;BK!(; Comment. STA 5 5f2j1999 2 9C_° 6.612 4.535.1 57. G AS LIF C MCO/KBUGII!DMYIBKJI! Commenl. STA 6 8(15/1991 ..922 3AS cFr _ v omrnent . 1-1 ' ~ 7.525 5.0.^.`.1 58.55 G AS LIFT CAMCO/103UG/11DMYfBKli! CommerK STAB 8/15/1991 2.922 ~'A' 8.023 5.275.0 59.70 G AS LIFT CAMCOIF(BUGIIJDMY!BK//,1 Comm~rt: STA 9 5):J7999 2922 ~:~. 8.52 5.5 2.9 59.09 G AS LI AMCO/MMG-2!1.510 N/RK,'/1 Comment: STA 1U 7J25(2010 2371 ' 8.557 5.547 ~ 59.0'2 T BG CUT PRE-SIDETRACK CUT TUBING 1(27;_°010 3.99_° cAS L'FT, e eza 8.560 5.548.8 59 Ol T BG TUBING PUNCHES 4 spf. 5 1'z2 0" 7j27(2D10 2000 P UNCHES FT 3A5 L' 8.575 5.556.5 58.97 S BR Camw'OEJ' 8/1511991 2297 : gszw 8.542 8. ~ ACK CtlmcD'HRP-1- P' 811 i1 1 x.344 626 5.583.0 5887 C ATCHER PRE-SID TRACK CA CHER 1.8 'G- N iJ2 J~0 0 1675 TEe c`T. e.~,, 8.631 5.585.5 58.86 P RODUCTION CAMCO MG-1 1 MY Commem. STA 11 1KB ! /D IBK/!! 5!27; ^003 ^_.347 8.668 5.604.6 58.74 N IPPLE AVA BPL PORTED NIPPLE 8115(1991 ^.250 Teo PJNGyES. -- _ -~. 8. 68 5.604.6 58. 4 S LE -0 225" AVA BPC, set 5!20 5j20/2 6 1.875 e~aa 8.690 5.616.0 58.66 FI SH PIECES OF UPPER WRP ELEMENT 2 /1 011 99 5 D.D00 J 9373 6.0164 47.94 P ACKER Baker'OB' SJ15f1991 3250 9.389 6.027.1 48.07 N IPPLE Cameo'D' Nipple. NO GO Sj1571997 7.813 sea ae>s- - 11 is 11 f - 9.396 6.031.8 48.12 T TL NO TTL ELMU LOG AVAILABLE 8,11517991 1.995 PAGER. B•.p2 -. --. - 9.752 6.372.2 44.28 FI SH 1 1/_^" OV Empty Pocket Fell Uovmhole 2,n0l1995 0.000 Perforations 8 Slots GATCFEA snot Dem 8 B2a Top (ttKD) evn (nK8) Top ITVD) IhKB) Bbn RVDI IhK81 Zone Date (°n°~ T tx Comment 9._^84 9.348 5.956.4 5.999.5 C-4. 2A-'.6 9+9;1965 12.0 IPERF 3 318' Csg Gun: 60 dey ph PROOUCnoN. 9 Ei' 9 X182 9506 6.0842 E 10a 3 A-4. 2A-16 99;1585 1'_.0 IPERF 3 3%8' Csg Gun: 6G ~ ph ruPPLE e aee - 9-556 5558 6a 21 i E '401 A-3. 2A-t6 5rB11985 t^ 0 IPERF 3 3%8" Gsy Gun. 6G dey ph . . . SLEEVED e eea Notes: General 8 Saf . End ante Annotanon ~%?;1995 NOTE- `bg x Annulus sox-. -n-. ;inspect GLM t=. 8529' may bs fiow wi wsti. eeec 4 {1 Y E/C_I_°005 NOTP WAIVEREC) WELL IA x OA ANNULAR COMMUNICATION 5/15x'0 NOTE: LDL UND TU ING LEAI( .N 5863' L D PROOJCTION G,Ct~ IPERF. S.ZP°-8 }t8 PAGEP.. 4.3'3 KIPPLE. b J94 SOb. B,1'a- ~ IPERF E sP?-b50a IPERF. 6.a3b-Bb52 FISH 6'52 LINER 8888 -. TD. 088E `-H: F;ober age 11 of 27 February 11, 2010 • • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~,.: ~" ,~~` ~,,.. ~~~`' qqqq~~ ~yl a~ ~ ~~~ Dear Mr. Maunder: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we112A-15 PTD 185-146 Brinker Platelet job. Please call MJ Loveland or myself with any questions. Sincerely, ~;. ~'1- _ , Well Integrity Projects ,, `, ~~ ~ 2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~I'01V ~~ ~ ~ ~ ='~_~~~• ~0(l1t11133i0t9 REPORT OF SUNDRY WELL OPERATIONS`'"5~ 1. Operations Performed: Abandon ^ Repair Well 0 Plug Perforations ^ Stimulate ^ Other ^/ Platelet SC repair Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development^ . Exploratory ^ 185-146 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 1410'~fi0, Anchora e, Alaska 99510 50-103-20041-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 122' 2A-15 8. Property Designation: 10. Field/Pool(s): ADL0025570 • Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8130' • feet true vertical 6239'. feet Plugs (measured) Effective Depth measured 7850' feet Junk {measured) 7651 true vertical 6025' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 104' 16" 104' 104' SURFACE 3251' 9-5/8" 3373' 2789' 3520 2020 PRODUCTION 7320' 7" 7442' 5715' 4980 4320 LINER 900' S" 8112' 6225' 5700 5550 Perforation depth: Measured depth: 7691-7744 7857-7906 true vertical depth: 5902-5943 6029-6067 Tubing (size, grade, and measured depth) 4.5",L-80,7031 - 3.5",L-80,7179' - 2.875",L-80,7649 - 2.375",L-80,7784' and Packers &SSSV (type & measured depth) Baker FHL Packer 5927' and SSSV= NIP SSSV= 496' 12. Stimulation or cement squeeze summary: 'vr.T ~ ~. ~ rsv:5~ 'C-c~ ~it~t-~~ Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 200 ~ 470 5300 1275 230 Subsequent to operation 200 470 5300 1275 230 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact MJ Loveland/ Perry Ktein Printed Name Title WI Project Supervisor Signature Phone 659-7043 Date ~.; ~~ 3=rz.~T Form 10-404 Revised 04/200 s ` I ~ ~ p 1~, /~ ~ ~ Submit Origerf Ohly / ~~ °~ > 1,_J 2A-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/02/09 Brinker Platelets SC Repair -unsuccessful, Initial T/I/0=230/1275/80. Rigged up pump to the platelet skid and started pumping diesel down OA and established a LLR of 4.0 bpm @ 240 psi. Loaded batch #1, 100 - 8 mm light platelets and pumped at a rate of 2.0 bpm @ 120 psi. Loaded batch #2, 50 - 25 mm disc platelets and pumped at a rate of 2.0 bpm @ 200 psi. Loaded batch #3, 100 - 10 mm core cubed platelets and pumped at a rate of 4.0 bpm @ 1000 psi. Loaded batch #4, 100 - 8 mm light cubed platelets and pumped at a rate of 2.0 bpm @ 560 psi. On the same pump sequence loaded and sent an additional 100- 8 mm light cubed platelets and pumped at a rate of 2.0 bpm @ 560 psi. Loaded batch #5, 250 - 10 mm cubed platelets and pumped at a rate of 2.0 bpm @ 540 psi. Loaded batch #6, 100 - 10 mm light platelets and pumped at a rate of 2.0 bpm @ 220 psi. Rigged down pump and platelet skid. Final T/I/0=230/1275/20. Brinker Platelets SC Repair -unsuccessful i ~ '~ OD: ID: r (7031 OD ID (7~~ OD r (7651 OD ID p76c OD Blasi (778; OD (7857 ConocoPhillips Alaska, Inc. KRU 2A-15 2A-15 API: 501032004100 Well Tyke: PROD Angte~S: 40 derma 7693 UBING ao3t' 4.500 SSSV Type: - -- -- NIPPLE Orig Com letion: ____ 8/9/1985 Angle @ TD: 40 deg @ 8130 , 3.a56) Annular Fluid: Last W/O: 5/3/2001 Rev Reason: ADD TTL ELMD Reference Lo Ref Log Date: Last U date: 9/7/2007 Last Ta _ TD: 8130 ftKB Last Ta Date: Max Hole An le: 46 de 3900 Casin Strin - ALL S S Descrl tlon Slze _ To Bottom ND 1M Grade Thread _ CONDUCTOR 16.000 _ _ _ 0 104 _ 104 62.50 H-40 SURFACE 9.625 _ 0 _ 3373 2789 36.00 J-55 PRODUCTION 7.000 _ 0 _ ___ 7442 5715 26.00 J-55 LINER 5.000 7212 8112 6225 15.00 J-55 Tubin~Strin - TUBING 'r> Size To -Bottom ND Wt Grade Thread 4.500 0 7031 5422 __ 12.60 _ L-80 Ibt 3.500_ 703_1_ 7179 5526 9.30 L 80_ 8rd 2.875 7179 7649 5870 6.50 i L-80 _ H d 511 2.375 7651_ 7784 5973 4.70 J-55 Srd _ Perforations Summary __ Interval TVD Zone Status Ft SPF Date T e Comment JBiNG -7t7s 7691 - 7744 5902 - 5943 C-4,UNIT B -- - 53 - 6 10/7/1985 IPERF - SOS 3 3/8" Ultra Jet; 60 de hasin 3.500, z.ssz) 7857 - 7906 6029 - 6067 A-3 49 6 10/7/1985 IPERF SOS 3 3/8" Ultra Jet; 60 de hasin Stimulations $ Treatments - " Interval Date TyQe Comment 0 - 0 4/211997 Scale Inhibitor Pum 10.7 BBIs SW & SS5206 Preflush Ges Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 3077 2582 CAMCO KBG-2 GLV 1.0 BK 0.156 1260 6/15/2006 2 4630 3668 CAMCO KBG-2 OV 1.0 BK 0.250 0 1/9/2007 3 5668 4439 CAMCO KBG-2 DMY 1.0 BK 0.000 0 6112_/2006 ~ ~ ~ 4 6436 4999 CAMCO KBG-2 DMY 1.0 BK 0.000 0 4/24/2003 ' ~ 5 6987 5390 CAMCO KBG-2 DMY 1.0 BK 0.000 0 5/15/2001 Other (plugs, e ui .etc. - COMPLI=TION _Depth TVD . T e Descri lion ID xo X7650 496 ~ 496 NIP CAMCO'DB' NIPPLE 3.812 2.675) 7040 5428 PBR BAKER 4.000 7054 5438 PKR BAKER 7"X3" 'FHL' H drostatic acker 3.000 _ 7105 5474 NIP CAMCO'DS' ni le 2.812 7145 5502 Slotted TBG 2.992 7649 5870 XO 2.375 7650 5871 OVERSHOT BAKER BOWEN OVERSHOT 3.125 7690 5901 Blast Rin s 2.375 7760_ 5955_ SEAL Locator sub & 5.5" seals 1.995 7761 _5_956 PKR BAKER'DB' PACKER 3.250 JBING -7784 7763 -. 5957 . - Blast Rin s Chemical cut 7755' & 7758' RKB; Lubin ossibl severed 7/29/01 2.375 , 2.375, 7764_ 5958_ SBE SEAL BORE EXTENSION 3.250 t.as5) 7778 _5969 NIP CAMCO 'D' NIPPLE 1.812 7783 5973 SOS 2.000 7784 5973 GUIDE OTIS WIRELINE RE-ENTRY GUIDE - TTL ELMD @ 7778' ON OTIS TEMP LOG 10/10/1985 2.000 sEnL Fish - FISH ' De th Descrl tlon Comment z sesj 7651 _ FISH left in hole; Location Unknown JUNK LEFT IN HOLE; From 9/16190 - workover 5/3/01 pulled junk u to new level 7111 Rings General Notes -776x, Date Note z.soo) - 5/1812001 unable to ass throw h cuts. NOTE: Chemical cuts 7756' and 7755' MD in 2 3/8"TBG -- - - 5/9/2006 , NOTE: WAIVERED WELL: IA x OA x OOA -PROD CSG x FORMATION COMMUNICATION Pert -7908) T o • ` ® ®® ® fl Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • ~zl~~~ NC~V ~ ~ 200? Dear Mr. Maunder: ~~~,~~ Enclosed please find a spreadsheet with a list of we11s_from the Kuparuk field (KRL~. Each .of these wells was~found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on November 10, 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. Sincerel , ~ ~, =.~ Perry Klei ~~ ~~, ~~ ~ `,~' ~ ~; ConocoPhillips Well Integrity Projects Supervisor ... ~~ • ~ nC®hillips leaks InC. Surface Casing by Conductor ,4nnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Datp Kuparuk Field 11 /10/2007 Well Name PTD # Initial top of .cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-1 185-146 5" NA 5" NA 3.5 11/10/2007 2A-16 185-147 39" NA 39" NA 21 11/10/2007 2A-19A 201-083 12" NA 12" NA 6 11/10/2007 2A-20 193-151 9" NA 9" NA 7.5 11/10/2007 2A-24 193-144 5" NA 5" NA 2 11/10/2007 2A-25 196-062 10" NA 10" NA 2 11/10/2007 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ;i c'~~r~~ ~~~ ~ ~. Z~~i ~• NO.4482 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description RR Date ::~x::: BL Color CD 11 /07/07 3J-10 11850465 SBHP SURVEY / '- ~ 10/31/07 1 1B-OSA 11839682 INJECTION PROFILE "~ - 10/31/07 1 1 D-01 11846458 LDL - 11/01107 1 2A-15 11846459 PRODUCTION PROFILE ~j - ~ (o 11/02/07 1 1E-02 11850470 _ PRODUCTION PROFILE ff °O~ 11/04/07 1 2N-310 11745242 SCMT 11/04107 1 1E-119 10687772 _ OH LDWG EDIT ~ </ 04/08/04 1 1E-119 10687772 CMR ~p~- - 04/08/04 1 1 E-119 10687772 MDT 04/08/04 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Alaska, Inc. Subsidiary of PHiLliPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 June 13, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2A-15 (185-146 / 301-069) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the KRU well 2A-15. If there are any questions, please contact me at 265-6434 or Pat Reilly at 265-6048. Sincerely, J. Trantham Drilling Engineering Supervisor Phillips Drilling JT/skad RECEIVED JUN 1 5 ZOO/ Alaska 0il & Gas Cons. Commission Anchorage nplr'.lklA! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing X Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 122 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service Kuparuk Unit 4. Location of well at surface 8. Well number 3952' FNL, 5052' FEL, Sec. 13, T11 N, R8E, UM (asp's 498621, 5960748) 2A-15 At top of productive interval 9. Permit number / approval number 1214' FNL, 1250' FEL, Sec. 24, T11 N, R8E, UM 185-146/301-069 At effective depth 10. APl number ~ 50-103-20041 ~ i,~ At total depth 11. Field / Pool LUc::)c::) ~ 1438' FNL, 1081' FEL, Sec. 24, T11 N, R8E, UM (asp's 502593, 5957983) Kuparuk Oil Pool ~, N . ~ 12. Present well condition summary ~UJ ~o~-o ~' Total depth: measured 8130 feet Plugs (measured) ~(~ true vertical 6239 feet ~ ~ Effective depth: measured 7850 feet Junk (measured) junk @ 7111' [~ ~ true vertical 6025 feet ~. Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 104' 16" 210 sx CS U 104' 104' SURFACE 3251' 9-5/8" lOOO sx AS III, 350 sx Class G ** 3373' 2789' PRODUCTION 7320' 7" 5oo sx C~ass G 7442' 5715' LINER 900' 5" 15o sx Class G 8112' 6225' LINER ** and 80 sx AS I Perforation depth: measured 7691'-7444', 7857'-7906' true vertical 5902'-5943', 6029'-6067' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 7031' MD; 3-1/2', 9.3#, L-80 Tbg @ 7179' MD; 2-7/8',6.5#, L-80, Tbg @ 7649' MD. 2-3/8', 4.7#, N-80 @ 7651'-7784' Packers & SSSV (type & measured depth) BAKER 7'X3' 'FHL' HYDROSTATIC PACKER @ 7054' MD; BAKER 'DB' PACKER @ 7761' MD; CAMCO 'DB' @ 496' MD. 13. Stimulation or cement squeeze summary Intervals treated (meaSured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 876 1543 3297 243 Subsequent to operation 544 3514 6827 262 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __ X Gas __ Suspended __ Service _Water Injector 17. I hereby1 certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Pat Reilly265.6048 Signed ~.~_~.-~ ,~.(~ ~ ._.~,,~ Title Drilling Engineering Supervisor Date James Tra'~fffam Prepared by Sharon Ails up-Drake 263-4612 ORIGI¢',JAL Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Operations Summary 2A-15 Rpt Date 04/12/01 Comments PUMP 1000 LBS 20/40 SILICA SAND - FREEZE PROTECT WELL WITH 15 BBLS DIESEL TO 2500' - ANTICIPATE SAND TOP AT 7785' RKB 04/13/O 1 04/15/01 04/19/O 1 04/21/01 12:00 AM 04/22/01 12:00 AM 04/23/01 12:00 AM TAGGED SAND PLUG @ 7820' RKB, PULLED DV @ 6982' RKB, PULLED 2.25" AVA TPI @ 7124~ [Tag, GLV, Open-Close C Sand] ATTEMPT TO CHEMICAL CUT 2-3/8" TUBING BELOW BLAST JOINTS - COULD NOT GET PAST 7526' MD - CHEMICAL CUT 2-3/8" TUBING AT 7505' MD IN THE MIDDLE OF THE 11TH JOINT BELOW THE 2-7/8"X2- 3/8" XO - 4-1/2 JOINTS TUBING BETWEEN THE CUT AND THE TOP BLAST JOINT - CHEM PULLED E-LINE TOOL STRING & CHEMICAL CUTTER @ 6970' SLM(7006' ELM). SET BPV, TESTED GOOD.i [Fish] Turn Key rig move f/1R to 2A pad a 15 mile move. Moved f/1R to KCS 'Y'. Wait on Philllips crew change. Continue turn key rig f/KCS 'Y' to 2A pad. Lay rig mats. Move rig over 2A-15. Set cutings & boiler tanks. Lay out Hand. Y-Berm around cellar. Accept rig @ 1600 hrs 4/21/2001 Continue to R/U hard lines- circulating lines. Modify Kill line. Lay plywood around well house on hercilite. Test hard lines to 120 psi w/air, to 2500 psi hot oil. Continue Modification of Kill line. Pull BPV & VR plug. R/U kill lines. PJSM w/crews Hot oil and DSO. Hot pumped 65 bbl of 140 deg Diesel down tubing out cut @ 7006'. Followed by 400 bbl's of 70 deg sea water. SITP 690 psi SICP 620 psi. Condition mud to 11.0 ppg. Pump 11.0 ppg mud down tbg taking returns to kill tank. with mud to surface bring back to pits. Mud coming back @ 10.5 Weight up surface volume to 11.0 ppg Circulate and maintain weight @ 11.1 ppg. Monitor well tbg & annulus dead. Set BPV. N/D Tree. N/U 11" 5M triple gate BOPE. Continue N/U 11" 5M triple gate BOPE. Change bottom pipe rams f/3 1/2" to 2 7/8" Test BOPE 250-4000 psi Hydril 250-3000 psi Pull BPV '0' psi on tbg. M/U landing jt. Bleed off 60 psi on annulas. Pull tbg to rig floor. Tbg came free @ 70K up wt 55k. Pump down tbg 80 spm 1500 psi. Returns gas and water cut. Maintain 11.2 ppg down tbg returns continue to come back 11.1 ppg. Chech outer annulus 1200 psi R/U Bleed trailer & bleed O/A. Continue circulating while blleding annulus. Bleed annulus down to 50 Monitor well. Pump dry job. Break down landing joint. POOH L/D 2 7/8" tbg & jewelry. Camco spooled up control line. Recovered 33 SS bands. R/D Camco unit. Continue to POOH L/D a total of 224 jts 2 7/8" 6.5# J-55 Eue 8rd PIC tbg. 6 Camco 2 7/8" x 1" KBMG GLM. 1 Merla 2 7/8" x 1 1/2" TGPD GLM & SSSV. Wait on Schlumberger Off load ppipe shed. Operations Summary 2A-15 04/24/01 12:00 AM 04/25/01 12:00 AM 04/26/01 12:00 AM 04/27/01 12:00 AM R/U Schlumberger Run USIT log for Evaluation of 7" 26# J-55 BTC csg f/ 7000' to 0' Run USIT log from 7000' to surface & rig down sws. Change out side kill line & change rams from 2 7/8" to 3 1/2"-test to 250- 4000 ok. RIH w/bridge plug & retdev-o- matic packer picking up 3 1/2" dp-testing csg. to 2500# @ 1996' & 5008'. Circ. complete circ. Set packer @ 6946'-test csg. 2500# 30 mins.-Iost 70# to 2430. Unseat packer-rig up hot oil-pump diesel down 9 5/8"X 7" annulus- pressure to 1450#-hold for 30 mins. no bleed off. Pump pill & poh. Finish poh w/bp & packer. Make up bha #2 fishing assembly=pick up 14 4 3/4" dc,s=rih & to 7000'- make up top drive. Technical limits meeting. Tag & catch fish @ 7008'-work loose w/jars. CBU-gas to surface after 2300 strokes-circ out gas-well flowing-check 7" X 9 5/8" annulus-1600# on same-bleed off-well flowing-circ & raise mud wt. 11.4#-monitor well-well dead. Pump pill & poh w/fish slow. (Note) bleed off 75# on annulus. Lay down fish recovered everything from 2 7/8" cut off to 2 3/8" cutoff. Pick up fishing bha #2. RIH w/fishing assembly. Finish trip in w/4 1/8" overshot w/2 3/8" basket grapple. Wash down to fish @ 7505'-engage same & work to 20k over string wt.- attempt to hydraulic fish from seal assemby w/1500#-pumped thru sand plug to 'A' sand & lost pressure to 500#. Release from fish & cbu-gas on bottoms up. Circ. out-well stable. Latch fish & work same-w/no jarring. Release from fish to make up pup to work wireline close to floor-while rigging up sws-well started flowing-circ & build mud wt. 11.4# & pump same around. Attempt to latch fish-grapple slipping off. Monitor well-pump pill & pull 15 stds.-hole fill not right-rih to 7500'. Pump out gas bubble & pump 11.6# mud around=monitor well 30 mins. well stable. Pull 15 stands-well stable but not taking right amount of hole fill-monitor same-rih. Circ.=build mud wt. to 11.9# & pump same. Monitor well. POH for grapple change. Finish poh to change grapple. Change grapple & add extension. RIH w/fishing assembly. Service rig-crown-& crown-o-matic. Repairs to hydraulic spinner. Finish rih to top of fish @ 7505'. CBU prior to latching fish. Latch fish & pull 20k over string wt. PJSM-rig up sws & rih w/chemical cutter-tie in & cut tbg. @ 7758'. poh & rig down sws. Make up top drive & work pipe-would not circ. or work free. Operations Summary 2A-15 04/28/01 12:00 AM 04/29/01 12:00 AM 04/30/01 12:00 AM 05/01/01 12:00 AM 05/02/01 12:00 AM Set string in slips w/20k over string wt.-PJSM-rig up sws & run chemical cutter in hole-cut @ 7643' dpm & poh-rig down sws. Work pipe free @ 7643'. Work pipe & circ. out sand while cbu-monitor well. POH 15 stands-pump pill-poh & lay down fish-recovered 3 jts. 2 3/8" 4.7# n- 80 eue 8rd & 2 cut off pieces. RIH & lay down 12 jts. 2 7/8" ph-6-12 4 3/4" dc,s. Make up 4jts. washpipe & pick up 15 3 1/8" dc,s. & rih. M/U top drive-circ. & wash from 7643' to 7692'. Washover pipe would not go past 1' into perforations. (Note) lost 9 bbls. mud instantly when opening perf,s. Slowed pump to 2 bpm & losses slowed. POH 15 stands-pump pill-poh. Lay down washpipe & make up new bha. RIH w/overshot. Finish rih w/overshot. Wash from 7563 to 7651' Engage fish & work same-full circulation. Work fish while cutting mud wt. due to possible differential stuck pipe-from 11.9 to 11.0. Spot 150 bbls. water down annulus & flow back same. No success on pipe release. Release from fish & pull 15 stands-improper hole fill-rih to bottom. Circ.-build mud wt. Circ. while increased mud wt. to 11.5# due to flow back w/70# dpp. POH for bha change to assist I 11/16" chemical cutter. Lay down 15 3 1/8" dc,s & fishing tools. Weekly bope test-250-4000#. Make up bha & rih to 7630'. Break circ.-wash down to fish @ 7651'-latch same & circ. sweep. PJSM-rig up sws & rih w/string shot. Continue to RIH w/string shot- Wireline stuck @ 7650' WLM. Circulate long way & Reverse to free wireline. Came free POOH L/D string shot and R/D Schlumberger W/L. Release from fish @ 7651' and stand back 3 1/2" DP Slip and cut drilling line 48.75' Check Crow-O-Matic. Continue to POOH stand back 3 1/2" DP POOH w/BHA #6 L/D P/U BH^ #7 skirted 1.9" mill. Continue RIH w/BHA #7 on 3 1/2" DP taged fish @ 7651'. Up wt 120k Rt wt 90k Rotate and circulate over top of fish @ 7651' Polish 2 3/8" fish top. Circulate @ I 1/4" bpm 590 psi. Pump dry job. Drop bar open circulating sub. POOH stand back 3 1/2" DP. POOH L/D BHA #7. Good indication tool was over fish and inside 2 3/8" tbg w/Mill. No junk in basket. M/U BHA #8 Overshot dressed w/2 3/8" Grapple RIH on 3 1/2" DP to 7645'. Circulate bottoms up. Latch on to Fish @ 7651' Pull 35K over string wt. R/U Schlumbger to Run I 11/16" drift. Continue to engage 2 3/8" tbg Fish @ 7651'. Pull 30K over string weight 150k and set slips. R/U SOS. PJSM w/crew & Schlumberger on chemical cutters and wireline safety. RIH w/1 11/16" Drift. Tag @ 7850' WLM Sand. POOH & RIH w/13' single strand primer cord to clean pryer chemical cutter residue. Fired across 7746' - 7759' POOH Operations Summary 2A-15 05/03/01 12:00 AM 05/04/01 12:00 AM 05/05/01 12:00 AM M/U Chemical cut SOS had wrong safety firing head. Wait on parts. M/U 1 11/16" cutter RIH and cut top 2' pup @ 7756' MLM. Could not see any movement in pipe. POOH R/D SOS. Circulate & Work pipe and jar on fish. 28 spm 750 psi. Work and jar up 50k over string weight. Could not see any movement of fish. Release f/ fish. Pull 6 stands. Wait on storm packer. Load 4 1/2" tbg while waiting on packer. M/U 7" storm packer RIH & set. Continue setting Baker 7" storm packer 35' below rotary table. Overshot @ 6775' PJSM. N/D 11" 5M BOP @ tubing spool. Remove 7 1/16" 5M X 11" 3M tubing spool. Change out 9 5/8" X 7" Packoff. Cut 7" casing to fit new FMC GEN IV 11" 3M X 11" 5M tubing spool. Install same. Test packoff to 2500 psi O.K. N/U 11" 5M Triple gate. Test all breaks 250-4000 psi O.K. Pull test plug set wear ring. Ingauge Baker 7" Storm packer. Release and L/D. RIH to top of fish @ 7651' Latch on w/overshot. Circulate bottoms up @ 1.5 bpm @ 800 psi. PJSM w/Schlumberger. M/U free point tool not working right wait on pads f/Dead hores. M/U and run I 11/16" Drift w/Gamma Ray RIH to 7765' Tool stoped. Log up to 7400' POOH L/D. M/U Free point tool. Continue running Schlumbergers free point tool. Checking free ponit of 2 3/8" 4.7# N-80 FL4S tbg w/Blast rings. Top of fish 7651' and bottom of Seal assy @ 7765'. 100% free @ 7666' - 5% free @ 7681'- 100% stuck @ 7712'. POOH R/D Schlumberger. Change bai Pump dry job. POOH stand back 3 1/2" DP. Service rig. Bleed outer annulus pressure to '0' psi f/75 psi. Continue POOH w/3 1/2" DP & L/D BHA. RIH w/2 7/8" pac DC's L/D Same. Clear floor and change handling equipment. M/U RR 6 1/8" bit on 7" casing scraper RIH on 3 1/2" DP to 7150' Circulate 3.0 bpm @ 550 psi. Load shed w/completion equipment strap- drift & identify all change over subs. Camco loaded 'DS' nipple w/dcr plug and left ball rod in dog house. POOH stand back 3 1/2" DP f/Move. L/D scarper and bit. Pull wear ring. PJSM & R/U to run Completion P/U 3 3/4" Bowen overshot dressed w/2 3/8" grapple & packoff. RIH w/16 jts of 2 7/8" 6.5# L-80 Hyril 511 tbg. I jts 3 1/2" slotted tbg Baker 7" x 3" 'FHL' pkr & 4 1/2" 12.6# L-80 IBT tbg Service rig & top drive. Continue RIH w/completion to 7630' Check string weight 105K up and 65k down 23k for blocks. Drop setting ball. Engauge overshot over 2 3/8" tbg stub @ 7651' Test pull w/15k over string weight. R/U circulating hose place FHL packer in neutral position. Set 'FHL packer and test tubing to 2500 psi & hold for 30 min. O.K. Bleed pressure to 1500 psi Shear PBR w/115k N/D BOPE N/U Adapter flange, test packoff to 250-5000 psi- N/U tree test tree 250- 5000 psi O.K. Operations Summary 2A-15 05/06/01 12:00 AM 05/07/01 12:00 AM Test 7" X 4 1/2" Annulus to 2500 psi f/30 min O.K. Bring annulus pressure up to 3000 psi to shear DCK-2 circulating valve @ 6987' No shear bleed off repete up 3400 psi w/no shear. Wait on wireline. Wait on wireline. R/U wireline unit. RIH to pull DCK valve. Continue wireline operation. While RIH Kick over tool tripped & pulled DV f/ GLM #3 @ 5668'. Made three runs and was unable to pull GLM #1 DCR-2 shear valve @ 6987'. Made I run & pulled DV @ 6436'. Made 4 runs trying to put DV back in GLM #3 @ 5664'. POOH R/U circulating lines & cellar manifold. Pump Seawater down 7" X 4 1/2" annulus thru both open GLM's at 5664' & 6436' 3 bpm while holding pressure on tubing. Finial cir¢ pressure 980 psi csg 710 psi tbg. Returns 9.3 ppg after 290 bbl's pumped. Pump 5 bbl PJSM w/new Halliburton wireline crew. R/U Wireline unit & lubricator. RIH w/DV & installed in GLM #3 @ 5664' POOH R/U W/L R/U circulating lines. Displace well w/290 bbl's clean 8.5 ppg Seawater down annulus and take returns f/tubing @ 3 bpm thru GLM @ 6436'. Pump freeze protection 80 bbl's diesel down annulus taking returns f/ tubing. Continue to freeze protect w/80 bbls diesel by pumping down 7" X 4.5" annulus. Let diesel 'u' tube to balance with tubing and annulus in communication. Finial SITP 900 psi- SICP 900 psi. 9 5/8" X 7" annulus 75 psi. P/U lubircator and set BPV. R/D lubircator & L/D same. Secure cellar and prepair to move rig. Release rig @ 0330 hrs 5/7/2001 upcoming NOrOIC ;3 vvorKovers ~-~_ Subject: Upcoming Nordic 3 Workovers Date: Thu, 29 Mar 2001 13:44:12 -0900 From: "Patrick Reilly" <preilly@ppco.com> To: tom_maunder@admin.state.ak, us Tom, Here is the information we discussed for the two wells 2A-13 & 2A-15 Updated General Procedures with BOPE test pressures Proposed Schematics (in WORD) Current Schematics Updated Sundry (See attached file: 2A-13 Gen Proc for state.doc)(See attached file: 2A-13 WORD schematic.doc)(See attached file: 2A-13.pdf)(See attached file: 2A-13 Integrated Workup.xls) (See attached file: 2A-15 Gen Proc for state.doc)(See attached file: 2A-15 WORD schematic.doc)(See attached file: 2A-15.pdf) The 2A-13 schematic has an error that is in the process of being corrected. The top of the SBR is at 7,179', not 7,159'. The cut will be made @ 7,179' -15'=7,164'. Thanks for all your help, Pat Reilly 265-6048 WORK 244-5558 CELLULAR 265-1535 FAX _~2A-_13 Gen Proc for state.doc Name: 2A-13 Gen Proc for state.doc Type: WINWORD File (application/msword) Encoding: base64 3 WORD schematic.doc Name: 2A-13 WORD schematic.doc Type: WINWORD File (application/msword) Encoding: base64 i 1 Name= 2A,13.pdf ~A-13.pdfI Type: Acrobat (application/pdf)1 ~ _ \ tEncoding: base64 1 of 2 4/12/01 8:14 AM Upcoming Nordic 3 Workovers '~-13 Integrated Workup.xls, Name: 2A-13 Integrated Workup.xls Type: EXCEL File (application/msexcel) Encoding: base64 2A-15 Gen Proc for state.doc Name: WINWORD File (application/msword)[ Type: 1 ~2A-15 Gen Proc for state.doc t Encoding: base64 I ~,2A-15 WORD schematic, doc Name: 2A-15 WORD schematic.doc Type: WINWORD File (application/msword) Encoding: base64 j ~2A-15.pdf 1 Name: 2A-i5. pdf Type: Acrobat (application/pdf)1 Encoding: base64 2 of 2 ..................... 4/12/01 8:14 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _X Vadance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 122 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface V/ ~ "~ 8. Well number 1326' FSL, 227' FWL, Sec. 13, T11 N, R8E, UM 2A-15 At top of productive interval 9. Permit number / approval number 1214' FNL, 1250' FEL, Sec. 24, T11N, R8E, UM 85-146 ~ At effective depth 10. APl number 50-103-20041-00 At total depth 11. Field / Pool 1437' FNL, 1079' FEL, Sec. 24, T11N, R8E, UM Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary V~ Total depth: measured 8130 ~" feet Plugs (measured) true vertical 6237 feet Effective depth: measured 8034 feet Junk (measured) true vertical 6163 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 104' 16" 210 sx CS II 104' 104' Surface 3373' 9.625" 1000 sxAS III & 350 sx Class G & 3373' 2789' 80 sx AS I Production 7442' 7" 500 sx C~ass G 7442' 5715' Liner 900' 5" 150 sx C~ass G 8112' 6225' Perforation depth: measured 7691'-7444', 7857'-7906' true vertical 5902'-5943', 6029'-6067' ~,~ J~ 2 3 ~ 0 Tubing (size, grade, and measured depth 2-7/8", 6.5#, J-55 to 7158', 2-3/8", 4.7#, N-80 from 7158'-7784' Alaska Oil & Gas Cons, Commissior~ Anchorage Packers & SSSV (type & measured depth) Camco HRP-1 packer @ 7047', Baker DB @ 7761', Camco 'TRDP-1A-SSA' SSSV @ 1820' 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch __ Schematic .I Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic -- 14. Estimated date for commencing operation 15. Status of well classification as: April 5, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service __ 17. I hereby c,ertify that the foregoing is true and correct to the best of my knowledge. Questions? Call Pat Re/lly265-6048 FOR COMMISSION USE ONLY Conditions of approval: PlugN°tify Commission so representative may witheSSintegrity__ BOP Test _~ Location clearance _ J Approval n~.~/~(~ Mechanical Integrity Test __ Subsequent form required 10- ~"~"~ - ¢/7.o/ Approved by order of the Commission | M ~l~e~ Commissioner Date ORiGiNAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 9-5/8" 36~ J-55 @ 3,373' 7" 26# J-55 @ 7,442' C4 Sand Perfs 7,691 '-7,744" MD A-5 Sand Perfs 7,857'-7,906' MD 2A-15 Workover Schematic 4-1/2" 5M McEvoy Gen IV tubing hanger with 4.5" L-80 12.6# BTC AB Mod pin down. GLM's w/DV's spaced out as follows. GLM # M._..~D TVD I TBD TBD 2 TBD TBD 3 TBD TBD 4 TBD TBD 5 TBD TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. 4-1/2", L-80, 12.6# BTC AB Mod Tubing to the tubing hanger. 4-1/2" Camco DS Landing Nipple with 3.875" ID No-Go profile set @ +/- 500' MD. 4-1/2", L-80, 12.6~ BTC AB Mod Tubing to the 'DS' Nipple with 4-1/2" x 1" Camco 'KBG-2' 5", 15#, J-55 @ 8,112' 4-1/2" x 1" Camco 'KBG-2' GLM w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 4-1/2", L-80, 12.6# BTC AB Mod Tubing. XO 3-1/2", 9.3~, L-80 EUE 8rd Pin to 4-1/2", L-80, 12.6# BTC AB Mod Box 6' Handling Pup 3-1/2", 9.3#, L-80 EUE 8rd. Baker '80-40' PBR 3-1/2" Baker FHL Retrievable packer @ +/- 6,976'. 6' 3-1/2", 9.3#, L-80 EUE 8rd. Pup Joint 3-1/2" Camco DS Nipple w/2.875" ID 6' 3-1/2", 9.3~, L-80 EUE 8rd. Pup Joint 2-7/8" OverShot with 3-1/2", 9.3#, L-80 EUE 8rd top threads. 1 Joint 2-7/8" 6.5#, J-55 8rd EUE (Chemical Cut in Half) 2-7/8" Pup Camco OEJ 2-7/8" x 5" Sheared Off Camco HRP-1SP Retrievable Pkr (rotate or straight pull) 2-7/8" x 7" 2-7/8" Tubing Camco GLM #8 2-7/8" Tubing 2-7/8" AVA 'BPL' Ported Nipple w/BPI Sleeve ID 1.87" 2-7/8" Tubing 2-7/8" x 2-3/8" 8rd EUE XO 2-3/8" 4.7#, N-80 8rd EUE Tubing 2-3/8", 4.7#, N-80 Blast Jt 8rd EUE Box x FL4S Pin (FL4S has total of 63' of carbide rings) 2-3/8", 4.7#, N-80 Blast Jt FL4S 2-3/8", 4.7#, N-80 Blast Jt. FL4S Box x 8rd Pin 2-3/8", 4.7#, N-80 8rd EUE Pup 2-3/8" Pup Baker Loc. Sub w/5.5' Seals for Pkr Loc. Sub Spaced Out above Pkr Baker 5" 'DB' Pkr Fill Baker Seal Bore Extension XO to 2-7/8" Tubing 2-3/8" Pup Camco 2-3/8" 'D' Nipple w/1.812" Profile 2-3/8" Pup Otis Shear Out Sub - Pinned for 3500 psi shear Otis Wireline Re-entry Guide PBTD @ 7,880'- Fill tagged on 6/23/00 TD @ 8,130' Alaska Oil & Gas Cons. Commissior~ Anchorage 3/23/01 PJR PHILLIPS AlasKa, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (1820-1821, 00:2.875) Gas Mandrel/Valve 1 (201&2014, 0D:4.750) GasL~ Ma~dreUValve 2 (3831-3832, 0D:4.750) 4 (5649-5650, OD:4.750) FISH left in hole; Localion (6977-7024, OD:2.875) SBR (7029-7O30, 0D:2.875) PKR -- (7047-7048, 0D:6.156) SLEEVE (7124-7125, 00:?_250) TUBING (7158-7784, 0D:2.375, ID:1.995) PKR (7761-7762, 0D:4.156) NIP (7778-7779, OD:Z375) Pelf (7857-7g06) KRU 2A-15 APl:. 1501032004100 SSSV Type: CAMCO TRDP Annular Fluid:11ASSA Reference L .o~: ] Last Tag: J 7880 Last T~q Date: 16/2'3/00 Casing String ' CONDUCTOR 18.000 0 Casing Stdng- SURFACE 9.625 0 Casin~ ,$~ng - PRODUCTION 7.000 0 Casing SWing - LINER Size I Top 5.000 7212 Size Top ?-875 0 ?- 375 7158 Pe~n; Summary Well Type: PROD Odg Completion: 8/9/85 Last W/O: I Ref Log Date:I TD: 18130 flKB Max Hole Angle: 146 deg, ~ 3900 Angle @ TS: 140 deg @ 7693 Angle @ TD: 40 deg @ 8130 Rev Reason: I Set BPI, lock out I TRDP by ImO La~t. Update: 17/8/00 I Bottom TVD Wt GradeI Thread 104 104 j 62.50 . H-.40 Bottom TVD Wt Grade' Thread 3373 2789 36.o0 J-55 Bottom 'rVD ' Wt Grade Thread 7442 5715 28.00 . J-55 Bottom I ~ Wt Grade Thread 8112I 6225 15.00 J-55 ~ I Tw I wt I oradeJ Mr, ad 7158I 5511 I 6.50 J-55 I 8RD EUE 7784 5973 I 4.70 N-80 ] 8RD EUE ~,~a TV~ Zone ISt~s~Fe~ISPFI De, el Type I C~me~ / I 7~-7~ ~-~7 A-3 { 49 6 10~/~ IPERF SOS 3 ~8" U lffa de~ ~ d~. phasing ~u~s & ~' =~ I~1 T~ t C~m~ ' . b- 0 41~7 ~le Inhi~ ~ Pump 10.7 BBIs SW & SS52~ Pmflush ~ ~ M~~v~ ~ MD I~ M~ M~ VMff VT~ VOD ~Po~ ~O ~ ~v ~ M~ T~ . , Run C~me~ 1 ~13~ 1837 Ca~ ~M(; GLV 1.0 BK 0.0~ 12~ 6/24/~ 3 4~ 3915 Cam~ ~M(~ DMY 1,0 BK 0.~ 0 ~6/~ 4I ~] ~51 ~m~ I ~(~ ~LV ~.O~ BK 0.2~I ~42~S/24/~ I 5 I ~ 475~lCam~l ~; ,] ~ DMY I 1.0 J BK'I0.~] 01 5/6~8 ~ ~1~1 ~l~m~l ~M(~ I I DMY I 1.0 I BK 10.~1 01 5/6~B ~ 7 I ~1 ~71 ~a I TGPC I I OV.. I ~.~IRK 10J~l 01 S/24/~'1 ~n Ma~a~s ~ M~ [~l M~ t M~ '1VM~ } VT~ 'lvool~lPo~[~OI ~e I Vlv I ~ ~ ~ ~ T~ I ~ I ~ / I I Run ]Comme~ 8 ] ~1.~1 ~m~l ~MG I , I DMY I 1.0 I BK J0.~0[ 0J 1~2~ ]CLOSED ~ (~u~ ]~ ~u~., ~.) - 18201 16! 70291 54; 71241 54~ 7124~ 54t 77611 59,, 7778~ 59~ 7783[ 59; 77831 59; 77841 59~ Fish - FiSH Delhi Type Description sssv ]CAMCO ,tTclp iassa LOCKED OUT 7/7/94 SBR I Camco 'OEJ' PKR I Camco 'HRP-I~SP' NIP JAVA BPL PORTED NIPPLE set 7/6/2000 SLEEVE I BPI sleeve 2.25" SET 7/6/2000 PKR IE~KE~ 'DB' NIP JCamco 'D' Landing Nipple NO GO sos /O~s wI~EUNE /O~s REENTRY / 2.312 2.297 2.344 2.250 1.875 3.250 1.813 2.000 2.000 2.000 Description [ Comment JUNK LEFT IN HOLE; From 9/16/90 Location Unknown. 6977 FISH left in hole; Location ] Unknown ~ Notes Date Note ,5/6~.98 WDRP 2 1/2" CAMCO on B-7 lock removed ~ 1820 KRU 2A-15 GENERAL WORKOVER PROCEDURE pRE-RIG WORK: 1. Get bottom hole pressure reading. 2. RU Slick Line Unit. RIH and tag bottom. Dummy offall GLM's except the GLM ~ 6,982', pull the valve and leave open. 3. Place a plug in the sliding sleeve ~ 7,124'. 4. RU E-line and chemical cut the tubing in the c, enter of the first full joint above the SBR ~ 7,006'. 5. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with kill weight mud. A plug is in the sliding sleeve. There should be no pressure at the surface. Displace tubing and annulus with kill weight mud through cut in tubing. Set BPV. 3. ND / NU and test BOPE to 4000 psi. 4. Screw in landing joint. POOH laying down tubing and spooling up SSSV control line. Lay down SSSV and continue POOH laying down tubing and jewelry. 5. Load, strap and drift 3-1/2" drill pipe. 6. R]H with cleanout assembly. 7. Set storm packer 8. Replace well head. 9. Retest any breaks in the BOPE. 10. Cleanout to below the new packer setting depth of 6,976', and POOH standing back 3-1/2' drill pipe in the derrick. 11. Load, strap and drift 4.$" tubing. 12. RIH with 4.5" completion assembly as per schematic. 13. Spaceout with tubing pups and land tubing hanger. 14. RU slickline and set plug in nipple just below top packer. 15. Set packer. 16. Shear PBR. 18. 17. Pressure test tubing and annulus. ND / NU and test tree. 19. Displace Well to seawater and ~eeze protect with diesel to +\- 2000' TVD. P JR 12-Apr-01 PRE-RIG WORK: KRU 2A-15 GENERAL WORKOVER PROCEDURE Get bottom hole pressure reading. / / RU Slick Line Unit. RIH and tag bottom. Dummy off all GLM's e~pt the GLM @ 6,982', pull the valve and leave open. / /. Place a plug in the sliding sleeve @ 7,124'. / 4. RU E-line and chemical cut the tubing in the center of the full joint above the SBR @ 7,006'. 5. Set BPV in tubing. Install VR plug in annulus valve. Location for Nordic 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull and VR plug. 2. Load pits with seawater. Displace tubing annulus with seawater. SI well and monitor pressure to determine kill weight. 3. Load pits with kill weight mud. and monitor pressure to ensure well is 4. ND / NU and test BOPE. 5. Screw in landing joint. POOH 1: continue POOH laying down 6. Load, strap and drift 3-1/2" pipe. 7. RIH with cleanout ~. 8. Cleanout to below the derrick. 9. Load, strap and tubing. 10. RIH with 4.5" assembly as per schematic. 11. Spaceout with pups and land tubing hanger. 12. RU slickline set plug in nipple just below top packer. 13. Set packer. 14. Shear PBI 15. 16. ND/ tubing and annulus with kill weight mud through cut in tubing. SI well Set BPV. down tubing and spooling up SSSV control line. Lay down SSSV and and jewelry. setting depth of 6,976', and POOH standing back 3-1/2" drill pipe in the tubing and annulus. and test tree. ORIGINAL M/ R 2, ?, Alaska Oil & Gas Oon.~ ".'. ..... "'~' ' Anchom ;~ 17. Displace well to seawater and freeze protect with diesel to +\- 2000' TVD. ., .: / ,, · · · PJR 23-Mar-01 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner ·THRU' ~~'~ DATE: T°m 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, 21 wellhouse inspections Attachment: SVS KRU 2A Pad 1-4-01 CS 1- failure 4.1% failure rate 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 Submitted By: Chuck Sch~ve Date: 1/4/01 Operator Rep: 'Eamie Barndt Field/Unit/Pad: 'Kupan~ / KRU / 2A Pad AOGCC Rep: Chuck Scheve . Separator psi: LPS 96 HPS Well Permit Separ Set L/P Test Test. Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLe. 2A-01A 1840570 2A-02 1840500 2A-03 1840510 2A-04 1840530 2A-05 1840670 2A-06 1840640 2A-07 1840650 2A-08 1852480 ;~A-09 1860010 96 70 50 P P OIL 2A-10 1860020 96 70 55 P P OIL 2A-11 1860030 96 70 50 P P OIL 2A- 12 1860040 96 70 70 P 4 OIL 2A-13 1851440 96 70 50 P P OIL 2A-14 1851450 96 70 70 P P OIL 2A-15 '-1851460 96 70 70 P P OIL 2A-16 1851470 96 70 70 P P OIL 2A- 17 1931400 96 70 50 P P OIL 2A-18 1950590 96 70 60 P P OIL 2A-19 1931520 2A-20. 1931510 5~A-21 1931330 2A-22 1950680 96 70 70 P P OIL 2A-24 1931440 96 70 60 P P OIL 2A-25 1960620 Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1% E]90 var Remarks: Surface Safety on 2A-12 had slow leak, valve to be serviced and retested STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF-SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: .5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 122' RKB 3. Address: Exploratory _~. 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1326' FSL, 227' FWL, Sec 13, T11N, R8E, UM 2A-15 At top of productive interval: 9. Permit number/approval number: 1214' FNL, 1250' FEL, Sec 24, T11N, R8E, UM 85-146 At effective depth: 10. APl number: 1388' FNL, 1115' FEL, Sec 24, T11 N, R8E, UM 50-103-20041-00 At total depth: 11. Field/Pool: 1437' FNL, 1079' FEL, Sec 24, T11N, R81=, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 8130 feet Plugs (measured) None true vertical 6237 feet Effective Deptt measured 8034 feet Junk (measured) Unknown type fish in rathole true vedical 6163 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 210 Sx AS II 104' 104' Surface 3338' 9-5/8" 1000 Sx AS III & 3373' 2789' 350 Sx Class G w/80 Sx AS I top job Production 7409' 7" 500 Sx Class G & 7442' 5715' 250 Sx AS I Liner 900' 5" 1 50 Sx Class G 8112' 6225' Perforation Depth measured 7691'-7744', 7857'-7906' true vedica. 5902'-5943', 6029'-6067' Tubing (size, grade, and measured depth) ~j~ O,~.~u~~)~ ~9~9~~''L 2.875", 6.5 Ib/ft, J-55 @ 7158' & 2.375", 4.7 lb/fi, N-80 @ 7158'-7784' Packers and SSSV (type and measured depth) Packers: Camco HRP-1-SP @ 7047' & Baker DB @ 7761" SSSV: Otis Series 10 @ 1798' ' 13. Stimulation or cement squeeze summary Fracture stimulate "A'" sands on 5/8/98. Intervals7857,_7906treated (measured) 0J~/G~ Treatment description including volumes used and final pressure Pumped 158,461 lbs of 20/40, 12/18, and 10/14 ceramic proppant into formation, fp was 8550 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 715 712 548 1369 314 Subsequent to operation 799 1065 689 1325 231 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended_ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~/ Title: Production Engineering Supervisor Date ~'/~/~ ~::~ Form 10-404 Rev~ E~ SUBMIT IN DUPLICATE~~ · AR O Alaska, Inc. (UPARUK RIVER UNIT ?-WELL SERVICE REPORT K1(2A-15(W4-6)) WELL. JOB SCOPE JOB NUMBER 2A-15 FRAC, FRAC SUPPORT 1221971056.4 DATE DAILY WORK UNIT NUMBER 05/08/98 A SAND REFRAC ,, DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 O Yes ~r~ NoI (~ Yes (~) No DS-GALLEGOS JORDAN . FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE KD1632 230DS28AL $124,895 $145,521 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 470 PSI 0 PSI 1089 PSI 500 PSII 10 PSI 0 PSI DALLY SUMMARY A SAND REFRAC NEAR WELLBORN SCREENOUT. PLACED 158,461 LBS PROPPANT IN FORMATION WITH 9.2 PPA AT THE PERFS. LEFT 16.050 LBS PROPPANT IN WELL. LEFT 50% OF TREE SAVER CUPS IN TREE. TIME LOG ENTRY 06:00 MIRU DS FI:lAC UNIT - GALLAGOS. ERGONMICS AUDIT BY SAFETY DURING RIG UP. TGSM. PT LINES TO 10,323 PSI. 09:39 BEGIN BD AND SCOUR STAGES. ISlP AT SHUTDOWN 1845 PSI. PUMP TWO PULSE TESTS. 10:45 BEGIN DATA FRAC. GEL XLINKING IN BLENDER. SD DATA FRAC AND FLUSH XLINK GEL FROM TUBING. HOOK UP ACTIVATOR TO DISCHARGE SIDE OF BLENDER. SB TO RESTART DF. 11:42 RESTART DF. ISIP 2074. ADJUST PAD SIZE TO 310 'BBL. 13:38 START FRAC PAD WITH 50~ GEL. CUT TO 40# FOR PROPPANT STAGES. LOST #4 PUMP. SD AND ISOLATE, CONTINUE FRAC. : 14:05 LOST #2 PUMP. SD AND ISOLATE, CONTINUE FRAC. RAMP UP REMAINING PUMPS #1 AND #3. 14:33 ACTIVATOR TANK REPORTED EMPTY-25 GAL REMAINING IN LINE AT 4 GPm. CREW MIXING MORE ACTIVATOR. SAMPLE FLUID BAD. 15:14 NEAR WELLBORN SCREEN OUT WITH 19:.I~PPA AT PERFS. PEAK PRESSURE SPIKE 8550 PSI. 158,561 LBS ' PROP IN FORMATION, 16,050 LBS PROP LEFT IN TUBING. LOST 50% OF TREE SAVER CUPS IN WELL. PLACED HEATER ON TREE AND RDMO DS FRAC UNIT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,295.00 APC $8,000.00 $8,000.00 DOWELL $112,095.00 $112,095.00 HALLIBURTON $0.00 $11,531.89 LITTLE RED $4,800.00 $12,600.00. TOTAL FIELD ESTIMATE $124,895.00 $145,521.89 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIgN REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Other m 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X 122' RKB J{~et ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1326' FSL, 227' FWL, Sec. 13, T11N, RSE, UM, 2A-15 At top of productive interval 9. Permit number/approval ,number 1214' FNL, 1250' FEL, Sec. 13, T11N, R8E, UM 85-146/,~,~.-~=,~.~"'~," ~'-~.-~/ · At effective depth 10. APl number 1326' FSL, 1326 ' FEL, Sec. 13, T11N, R8E, UM 5Q-103-20041 At total depth 11. Field/Pool 1437' FNL, 1079' FEL, Sec. 13, T11N, R8E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 81 30 feet Plugs (measured) true vertical 6237' feet Effective depth: measured 8034' feet Junk (measured) true vertical 6163 feet Casing Length Size Cemented Measured depth True vertical depth Structural 1 04' 1 6" 210 Sx CS II 1 04' 1 04' Conductor 3373' 9 5/8" 1000 Sx AS III & 33 73' 2 78 9' Surface 350 Sx Class G, 80 Sx ASI Intermediate Production 7 4 4 2' 7" 500 Sx Class G 7 4 4 2' 5 71 4' Liner 900' 5" 150 Sx Class G 81 1 2' 6 22 4' Perforation depth: measured 7691'-7444' 7857'-7906' RE( EIVED true vertical 5902'-5943' 6029'-6067' NOV 2 8 1990 Tubing (size, grade, and measured depth) 2 7/8" J-55 x 2 3/8" N-80 set at 7784' Alaska 0il & Gas Cons. C0mm~S$ Packers and SSSV (type and measured depth) Anchorage Camco HRP-1 ~ 7042', Baker DB @ 7756'. Camco TRDP-1A-SSA @ 1815' 13. Stimulation or cement squeeze summary Hydraulically fracture stimulated the A Sand with 21400 lb of 16/20 mesh ceramic proppant. Intervals treated (measured) A Sand, 7857'-7784' Treatment description including volumes used and final pressure Pumped 425 bbl of fluids, with sand concentrations ranging from 2 to 12 ppg. FTP=6900psi. 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6 8 0 4 3 1 - 0 - 1 1 2 5 2 2 0 Subsequent to operation 1 2 4 7 8 2 5 - 4 2 - 1 2 0 0 2 3 9 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector m Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby_ certify that the foregoing is true and correct to the best of my knowledge. Signed ,. Title ~ Or~~J~"~'~ ~,~ Date SUBMIT IN DUPLICATE Form 10-404 Rev 09/12/90 .A~ RCO Alaska, I ,~r,~ ~ Subsidiary of Atlantic Richfield Corn, WELL '"ONTRACTOR REMARKS IpBDT I FIELD-DISTRICT' STATE /4,,, p,:, ,",,t/~ IOPERATION ~T REPORT TIME cc, ~p ie t'~ WELL SERVICE REPORT DAYS iDAT~ I -3o- ?o 0'730 toq5" il2"7 l f3o IZZO i7_3~ t2.3q ~z35- ~z~ 12-32 Izqo Pc& /-~ '79~-o oK 7&oo o,; ! ~%LI ¥ '_,f/~7 NOV 2 8 19§0 Anchorage L_J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK °F oF milesI I knots Isigned STATE OF ALASKA - A,_ ...x,A OIL AND GAS CONSERVATION COM,, ....... ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate ~ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~X ARC° Alaska. InC. Exploratory _ RKB 122 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK' 99510 Service _ Kuparuk River Unit 4. Location of well at sudaCe 8. Well number 1326' FSL, 227' FWL, Sec 13, T11N, R8E, UM 2A-15 At top of productive interval 9. Permit number 1214' FNL, 1250' FEL, Sec. 24, T11N, R8E, UM 85-146 At effective depth 10. APl number 1326' FNL, 1326' FEL, Sec.24, T11N, R8E, UM so-103-20041 At total depth 11. Field/Pool Kuparuk River Field 1437' FNL, 1079' FEL~ Sec. 24, T11N~ R8E~ UM o Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 81 3 0' feet Plugs (measured) true vertical 6 23 7' feet -Effective depth: measured 8034' feet Junk (measured) true vertical 61 6 3' feet NOlle Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 04' 1 6" 210 SX AS II 1 04' 1 04' Surface 3373' 9 5/8" 1000 SX ASIII& 3373' 2789' Intermediate 350 Sx Class G, 80 Sx ASl Production 7442' 7" 500 Sx Class G 7442' 571 4' Liner 9 0 0' 5" 150 Sx Class G 81 1 2 6 2 2 4' Perforation depth: measured 7691'-7444' 12 SPF 120 degree phasing R E(~ 7857'-7906' 6 SPF 60 degree phasing true vertical 5902'-5943', 6029'-6067' TVD JUN 1 4 1990 Tubing (size, grade, and measured depth 2 7/8" J-55 x 2 3/8" N80 set at 7784' .aJas. ka0il.& Gas C0nsoC0rambsl0a Packers and SSSV (type and measured depth) ~ ~nch0ra~ Camco HRP-1 ~ 7042', Baker DB ~ 7756'. Camco TRDP-1A-$SA ~ 1815. 13. Attachments Description summary of propoSal _ Detailed operation program ~ BOP sketch _ Refrac A.Sands with 31,000# Carbo,Lite Proppant. (Wellbore schematic and procedure attached). 14. Estimated date for commencing operation 15. Status of well classification as: June 1990 Oil m Gas __ Su.spended _ 16.' If proposal was verbally approved Name of approver Date approved Service P r o d u c e r 17. Iher~ycertifythat~ngistrueandcorrecttothebestofmyknowledge. Signed~'~)~4. Title ,~!~... 0~~1'~$ .Date FOR COMMISSION USE ONkY Conditions of approval: Notify Commission so representative may witness IApproval N~/,) Plug integrity ~ BOP Test~ Location clearance ~ JI"' Mechanical Integrity Test_ Subsequent form require 10-'~q- ORIGINAL SIQNEO BY Approved bi/the order Commission 1.0NNIE C.' SMITH Commissioner Date ~9/j~/c:~(--). , SUBMIT IN TRII ~LICATE Form 10-403 Rev 5/03/89 Approved Copy Returned KUPARUK WELL 2A.15 APl #: 501032004100 SPUD DATE: 07/31/85 ORIGINAL RKB: 122 ADL LEASE: 25570 COMPLETION DATE: 09/27/85 PERMIT #: WORKOVER DATE: SURFACE LOCATION: 1326'FSL.227'FWL.SEC13.T11N.RSE TOP OF KUPARUK: 1214'FNL,1250'F EL. SEC24.T11N.RSE TD LOCATION: 1437'FNL.1079'FEL. SEC24.T11N.RSE PAD ELEVATION: TUBING SPOOL: 22 , CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5e H-40 104 9.625' 361 J~55 3373 7' 26# &55 7442 2.875' 6.5e J-55 7778 WELLTYPE: PRODUCER LINER DETAILS SIZE WEIGHT GRADE TOP BTM S' 15~ K-5~ 7212 8112 FrEM sssv SBR CAMCO oEJ PKR CAMCO HR AVA AVA BPL NIPPLE PKR BAKER DB NOGO CAMCO 'D SHRouT: OTIS TUBING jEWELRY 'TYPE ID CAMCO TRDP~IA-SSA ?_312' ?_297- 1.812' DEPTH 1815 7O24 7O,42 7119 L STN 1 2 3 INTERVAL 76~1-7744 7857-7g06 MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 46 deg HOLE ANGLETHRU KUP: 40 deg LAST TAG DATE: 04/15/88 RATHOLE: 28 It FISH/OBSTRUCTION: 8OO :::::::::::::::::::::: :-.,:..~.' -:.:.-::.'::-.'.:::...::::.:::.:::. ........ ?':':'~"'::':~'~'"" ',I ........... GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 20O7 CAMCO KBMG 1' 3826 CAMCO KBMQ 1' 495~ CAMCO KBMG 1' 5644 CAMCO KBMG 1' 6088 CAMCO KBMG 1' 6562 CAMCO KBMG 1' 6977 M ERLA TGPD 1.5' 7080 CAMCO KBMG 1' PERFORATION DATA ZONE FT SPF PHASE C234 53 6 60 A3 49 6 6O REVISION DATF~ 01117/89 REASON: UPDATE 85-146 PORT SIZE .DV 0.15625 .DY .DY 0.15625 .DY 0.1875 .DV COMMENTS 3-3~' ULT JET 3-3/8' ULT JET · . . , Attachment 2 Kuparuk Well 2A'15 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K81077 SI Well 2A-15, MIRU pump truck and freeze protect the well (60% 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. Pull AVA commingling sleeve at 6957'. Set AVA blanking Sleeve at 6957'. Pull GLV's at 3826', 6088', and 6977. Run DV's at 3826' and 6088'. RIH with a 1,812" standing valve or blanking plug and displace the casing with diesel, 7042' x 0.0302 bbl/ft = 2i2 bbl annular volume. 7. RIH with.a 1.5- DV and set in GLM at 6977'-. . . 10, 11. 12. 13. Pressure test tubing. Also, pressure test the 7" annulus, while monitoring the 9-5/8" casing pressure. RIH and pull the standing valve, RDMO slickline unit. Perform seVeral A Sand only production tests to establish a base line pre-frac rate. 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. Pump the 100 Bbl pre-pad at 20 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). This high volume of perforations might explain the zero perf friction that was observed during the previous Micro-Frac. pump fracture treatment per the attached schedule. pressures following the ISIP. WHTPE = Fracture Gradient = Frac Fluid Gradient = Tubing Friction = Record the 2, 5, 10, and 15 minute Expected wellhead treating pressure: 4843 psig 0.80 psi/ft (6038' TVD) 0.44 psi/ft 320 psi/1000' @ 20 BPM (2-7/8") = 600 psi/1000' @ 20 BPM (2-3/8") · If excessive treating pressures are experienced, redUce the rate in small increments adjusting additive rates as appropriate. With diesel on the backside, the maximum recommended treating pressure is 6500 psi based on analysis of tubing strength between the packers. The maximum treating pressure during Ih, initial fracture treatment was 5800 psi with diesel based fluids. Attachment 2 continued Kuparuk Well 2A-15 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. Rig dOWn fracture stimulation eqUipment. Follow attached flOwback schedule. Sundry NOtice - Kuparuk Well 2A-15 · No BOP's will be utilized during this Procedure. · Bottom Hole Pressure (6200' SS) = 3642 psi · No workover fluid will be used during this process. ARCO Alaska, In~'~ .- Post Office oox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 8, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 'Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Actiorl Anticipated Start Date 2 X- 1 2 Scale Sqz. June, 1989 2A- 1 5 Scale Sqz. June, 1989 2A-09 Scale Sqz. July, 1989 3 H- 0 3 Acidize June, 1989 3H~ 14 Acidize June, 1989 2 U ~ 1 2 Scale Sqz. June, 1 989 2 W- 0 7 Scale Sqz. June, 1989 3J-06 Fracture June, 1989 3J-02 Fracture June, 1989 3A-10 Perforate June, 1989 1 E- 0 6 Acidize June, 1989 1 E- 1 1 Acidize June, 1989 1 E- 1 5 Acidize June, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. 13. Smallwood Senior Operations Engineer RECEIVED A/aska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary ol AllanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X.~ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1326' FSL, 227' FWL, Sec. 13, T11N, R8E, UM, At top of productive interval 1214' FNL, 1250' FEL, Sec. 24, T11N, R8E, UM At effective depth 1326' FNL, 1164' FEL, Sec. 24, T11N, R8E, UM At total depth 1437' FNL, 1079' FEL, Sec. 24, T11N, R8E, UM !12. Present well condition summary Total Depth: measured true vertical 8130' feet Plugs (measured) 6237' feet 6. Datum elevation (DF or KB) RKB 122 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-15 ~/~o 9. Permit number 85-146 10, APl number 50-1 03-20041 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical Casing Length Structural Conductor 1 0 4' Surface 3 3 7 3' Intermediate Production 7 4 4 2' Liner 900' 8034' feet Junk (measured) 61 6 3' feet Size Cemented Measured depth I 6" 210 Sx AS II 104' 9 5/8" 80SxASI& 3373' 1000 Sx AS III & 350 Sx Class G 7" 500Sx ClassG &250SxAS I 7442' 5" 150 Sx Class G 81 1 2' True vertical depth 104' 2789' 5714' 6224' Perforation depth: 13. Pump Scale Inhibitor into perfs at 7691'-7744'. (Wellbore 14. Estimated date for commencing operation July, 1989 16. If proposal was verbally approved measured 7691 '-7744', 7857'-7906' MD true vertical 5902'-5943', 6029'-6067' TVD A ,. J~/] Tubing (size, grade, and measured depth -ia~Ka Oil & Gas uo 2-7/8" X 2-3/8" set at 7784' Packers and SSSV (type and measured depth) ,AnChorage. Camco HRP-1-SP @ 7042', Baker DB @ 7756'. Camco TRDP-1A-SSA SSSV @ 1815. Attachments Description summary of proposal X Detailed operation program _ BOP sketch schematic attached). 15. Status of well classification as: Oil X Gas __ Suspended _ Date approved Name of approver Service 17. I hereby certify that the foregoing is flue and correct to the best of my knowledge. Si~lned ,~ r.j~ ~.~ ~ .~,~c~.~ j TifloFORSr.cOMMiSSioNOperatiOnSuSEEngineerONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 '~RIGINAL SIGNED BY LONN)E ~. SM!T.u. IApproval · Approved COpy ~Returned Commissioner Date ~ ~/'-~'"~:~::~"~ SUBMIT IN TRIPLICATE Application for Sundry - Well 2A-15 C Sand Scale Inhibitor Squeeze Treatment No BOP's are used during the treatment. The squeeze treatment will be pumped through a manifold on surface. C Sand Pressure (6200' SS) = 3400 psi Estimated. No workover fluid will be used during this process. Oil & Gas Cons, Commission ~C~rage KUPARUK WELL 2A-15 APl #: SPUD DATE: 501032004100 07/31/85 ADL LEASE: 25570 COMPLETION DATE: 09/27/85 PERMIT #: WORKOVER DATE: SURFACE LOCATION: 1326'FSL,227'FWL,SEC13,T11N,R8E TOP OF KUPARUK: 1214'FNL,1250'FEL,SEC24,T11 N,R8E TD LOCATION: 1437'FNL,1079'FEL,SEC24,T11 N,R8E All depths are MD-RKB to t~p of equipment unless otherwise noted ORIGINAL RKB: 124 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5# H-40 104 9.625" 36# J-55 3373 7" 26# J-55 7442 2.875 6.5# J-55 7778 LINER DETAILS SIZE WEIGHT GRADE TOP BTM 5" 15# K-55 7212 8112 TUBING SPOOL: 22.3 WELLTYPE: PRODUCER ' i. PAD ELEVATION: 94 STN 1 2 3 5 7 8 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2007 CAMCO KBMG 1.0" 3826 CAMCO KBMG 1.0" 4958 CAMCO KBMG 1.0" 5644 CAMCO KBMG 1.0" 6088 CAMCO KBMG 1.0" 6562 CAMCO KBMG 1.0" 6977 MERLA TGPD 1.5" 7080 CAMCO KBMG 1.0" 85-146 PORT SIZE DV 10/64" DV DV 10/64" DV 3/16" DV TUBING JEWELRY ITEM TYPE ID DEPTH sssv CAMCO TRDP-1A-SSA 2.312" 1815 SBR CAMCO OEJ 2.297" 7024 PKR CAMCO HRP-1SP 7042 AVA AVA BPL NIPPLE 7119 PKR BAKER DB 7758 NOGO CAMCO 'D' 1.812" 7772 SHROUT OTIS 7777 INTERVAL 7691-7744 7857-7906 PERFORATION DATA ZONE FT SPF PHASE C234 53 6 60 A3 49 6 60 COMMENTS 3-3/8" U LT J ET 3-3/8" ULT JET MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 800 MAX HOLEANGLE: 46 deg 2000 HOLE ANGLETHRU KUP: 40 deg LAST TAG DATE: 04/15/88 7934 RATHOLE: 28 ft FIS H/OBSTRU CTION: PBTD: 8034 PBTDSS: 6041 .:.:.:.:.:.:.;.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .................................. .:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:-:.:.:-:.:.:.:.:-:.:.:.:.:.:.:-:.: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: . .........,............................................... R'ECEIVED Alaska Oil & Gas Cons. CommiSsion Anchorage REVISION DATE: 01/17/89 REASON: UPDATE ~-"'-' STATE OF ALASKA ~--'- ~ ALASK~ OIL AND GAS CONSERVATION b~MMISSION ~( ~.~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OIL I~l GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ,~ ARCO Alaska, Inc. 85-146'~ i 3. Address 8. APl Number P. 0. Box 100:360, Anchorage, AK 99510-0:360 50- 10:3-20041 4. Location of well at surface 9. Unit or Lease Name 1:326' FSL, 227' FWL, Sec.13, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1214' FNL, 1250' FEL, Sec.24, T11N, R8E, UM 2A-15 At Total Depth 11. Field and Pool 14:37' FNL, 1079' FEL, Sec.24, T11N, R8E, 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. I 15. Water Depth, if offshore 116. No. of Completions 07/:31/85 08/07/85 08/09/85*I N/A feet MSLI 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 81:30'MD, 6237'TVD 8034'MD, 616:3'TVD YES~] NOEl 1820' feetMDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/Cal/SP/GR/FDC/CNL, CET/GR, CBL/GR, 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 ' 104' ' '24" 210 sx AS II 9-5/8" :36.0# J-55 Surf :3:373' 12-1/4" 1000 sx AS III & 350 s; Class G Performed top .lob w/80 sx AS I 7" 26.0# J-55 Surf 7442' 8-1/2" 500 sx Class G & 250 s~ AS I 5" 15.0# K-55 7212' 8112' 6-1/8" 150 sx Class G 24. Perforations open t° 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"/2-3/8" 7784' 7047' ~, 77~;1 ' 7906'-7857' w/6 spf, 60° phasing 7744'-7691' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 11/1/85, for fracture da';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 GAS-OIL RATIO TEST PERIOD ~ FioTM 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. None ,--,,---,-, /, !:~ t "'.i" i~' ('i ~-~ -. :J; -~:]as~a 0il & Gas rd0,qs. O0mmissit,'? *Note: Tubing was run and well perforated 9/27/85. '" ' ~.~0~ Form 10-407 WC3/57 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MAR Ki:R's ' -. Top Upper Sand Base Upper Sand Top Lower Sand' Base Lower Sand MEAS. DEPTH TRUE VERT. DEPTH 7691' 7744' 7804' 7974' 5900' 5941' 5987' 6117' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 11/1/85) 32. hereby certify that the foregoing is true and correct to the best of my knowledge 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". Form 10407 ADDENDUM WELL: 10/17/85 2A-15 Frac well in 5 stages w/total of 144 bbls diesel & 4000# 20/40 sand. - Drilling ~Superint endent Date ARCO Alaska, Inc/'-'--6 Post Office ...,~; 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK ~ 99510-0360 DATE 01-14-86 TRANSMITTAL # 5517 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ CBL/Var. Den. 2A-15 09-23-85 Run #1 7195-8016 Please note--The API serial # on the log face is incorrect. It should read 50-103-20041. Alaska 0il & Gas Cons. Comm/ssio. Anchorage Receipt Acknowledged: State of AK*bl/se Vault*film Drilling*bi NSK Clerk*bl Date: ARCO Alaska. Inc. is a Subsidiary o! AtllnticRichfielclCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 12- 0 5- 85 TRANSMITTAL NO: 546'9 ETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING P,E CO~S CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ~J~NSMITTED JCEIPT AND ~_NAL PRINTS/ SCHL/ CEMENT LOGS/ ONE * OF LACH %-1 ~ CE~'/CEL 09-09-85 ~-2~''' CET/CEL 09-08-85 %-24'',, CET/CEL 10-19-85 ~-3~''''' SQUEEZE/ CEMENT }{TNR i~ECORD 10-09-~5 ~-3~, CET/CEL 09-22-85 -~-3 (POST SQUEEZE#2) CET/CEL 10-1!-85 ~.-14-'' SQUEEZE/ CEMENT RTNR RECORD 10-12-85 ~A-!5~'' CET/CEL 09-23-85 ~-i2 ,r- SQUEEZE/ CEMENT RTNR RECORD 09-24-85 ~Z-i2'~'SQUEEZE/ CEMENT RTNk RECORD 09-26-85 :EASE NOTE--THIS LOG SHOULD nE LABELED AS _RUN %2. HE1QLD~ITH AF.E THE FOLLO~ING ITht~S. PLEASE ACKNOWLEDGE RETU~ ONE SIGNED COPY OF THIS TRANSMITTAL. BE WRITTEN IN. -!2~''' CET/CEL .-12~ CET/CEL -!~'~ CET/CEL THAlq K YOU. 09-26-85 09-2~-85 09-30-85 09-30-85 09-22-85 09-29-85 10-17-85 09-19-85 10-19-85 -3w'' CET/CEL -4~-----~ CET/CEL -16~- CET/CEL -3*"" CET/CEL -i~-"' CET/CEL -8 ~-'" CET/CEL RUN %1 7 RUN %1 7 RUN ~2 8 RUN ~1 7 RUN %1 5 RUN ~3 6 RUN t%1 8 RUN# 1 6 RUN #1 8 RUN # 2* 8 THE CORRE RUN %2 RUN %3 RUN #1 RUN %1 RUN #1 RUN #1 RUN #1 RUN #1 RUN %1 288-~429 988-9183 439-8830 050-7250 331-7402 740-7164 800-9000 530-8016 750-9000 700-9000 CTION CAN 8550-8999 8550-8900 6351-8160 6250-7966 3708-7531 2995-3692 6300-7751 7686-9510 5700-6950 iEIPT' ~ACKNOWLEDGED: CURRIER' VRON' M DRiLLING*BL L. JOHNSTON MOBIL NSK CLEPd<*BL DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHM~LL DATE: OF SOHIO .UNION ... Alaska 0il & G~s Cons. Commission Anchora.o.e VAULT/~qO*FILMS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2A-15 Dear Mr. Chatterton: Enclosed is a copy of the 2A-15 Well History (completion details) to include with the Well Completion Report, dated 10/22/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L89 Enclosure cc: 2A-15 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany RECEIVED · ~,laska Oil & Gas Corls. Commissior~ Anchorage ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 904341 Nordic #1 County. parish or borough North Slope Borough ILeaseorUnit ADL 25570 Imitle Completion Istate AP1 50-103-20041 Operator ARCO Alaska, Inc. Spudded er W.O. begun Complete 9/10/85 9/11/85 9/12/85 9/13/85 9/14/85 thru 9/16/85 Date and depth as of 8:00 a.m. RECEIVED- ~. 91.1~,18 5 . Alaska Oil & Gas Uon$. Commission Anchorage 9/18/85 IDat. 9/9/85 I"°ur Complete record for each day reported The above is correct Signature For form preparation and diStribution,- see Procedures Manual, Section 10, 2230 hrs. IARCO W.I. Prior status if a W.O. 5" TeL @ 7212' 7957' TIH , Brine Move rig to 2A-15, Accept rig @ 2230 hrs, 9-9-85. & tst BOPE; OK. RIH w/6-1/8" bit. ND tree, NU 5" TOL@ 7212' 7957', TIH Wt. 11.2, PV 16, PH 8, WL -, Sol 16 TIH to 2500', displ brine to 11.2 ppg mud, C&C mud, TIH to 5182'. C&C mud, TIH to 6200', tag bridge. 5" TOL@ 7212' 7209' TOH, RIH Wt. 11.3, PV 18, YP 9, PH 9, WL 8.4, Sol 16 Cond mud, TIH to 7018'. Tag cmt contaminated mud, PU Kelly, wshout contaminated mud. Drl cmt f/7081'-7209', DPM - TeL. Circ hole cln, tst csg/TOL to 3000 psi; OK. LD Kelly, POOH, PU 3-1/8" BHA, & 2-3/8" DP. RIH w/3½" DP, LD 22 ]ts, RIH w/DP. 5" TeL @ 7212' 7209' TOH, RIH Wt. 11.2, PV 19, YP 9, PH 9.5, WL 8.8, Sol 14 Run in hole w/4-1/8" bit, drl cmt f/7203'-7246', & f/7848'-7920'. Circ, drl cmt f/7920'-7977', POOH, tight. 5" @ 7212' - 8112' · 7146 Fsh, POH w/mill over assy Wt. 11.3, PV 18, YP 7, PH 9.0, WL 8.8, Sol 15 Fin POH; 2-3/8" DP had parted (796' fsh consisting of 4-1/8" bit, 2 JB, 2 XO, (16) 3-1/8" DC's, (9 ]ts) 2-3/8" DP + 28' of jr. RIH w/fsh'g assy, attempt to latch onto fsh, M&P pill, POH; no rec'y. Redress fsh'g tl, RIH, attempt to latch onto · fsh, POH; no rec'y. Rn impression block; no readable impression. RIH w/fsh'g assy, mill over fsh w/2-7/8" hollow mill, POH. 5" @ 7212' - 8112' 7158' Fsh, Mill over fsh Wt. 11.1+, PV 18, YP 9, PH 9.5, WL 8.6, Sol 17 POH, LD fsh tls, rec'd 12' of 2-3/8" DP body. PU fsh'g tls, RIH, wrk over fsh; unable to catch w/3-1/8" grapple, POH. MU new fsh'g tl assy, RIH, mill over fsh @ 7172'. 5" @ 7212' - 8112' 7!58' Fsh, PU Kelly Wt. 11.1+, PV 17, YP 8, PH 9.5, WL 8.6, Sol 17 Mill on fsh @ 7i75~ ....... , ~u, POH. mu fsh'g assy #6, RZR, ~u Jelly. IDate I Title //~'~'~" I Drilling Superintendent Alaska Well no. 2A-15 56.24% ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently Ihan 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 string until completion. District Field Date and deptl~ 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 9/19/85 9120185 9/21/85 thru 9/23/85 9/24/85 9/25/85 9/26/85 JState Alaska Well no. 2A-15 5" @ 7212' - 8112' ±7977' Cmt/Fsh - TOF @ 7166', RIH w/FTA #9 Wt. 11.1+, PV 17, YP 8, PH 9.5, WL 8.7, Sol 17 Tag TOF @ 7166', engage & jar same free @ 7166', POOH w/FTA #7 & LD 775.3' fsh. MU & RIH w/FTA #8, tag TOL @ 7210', obtain impression (DP junk), POOH. MU & RIH w/FTA #9. 5" @ 7212' - 8112' 7941', Fsh & TOL @ 7210', Prep to mill Wt. 11.4, PV 18, YP 7, PH 9.0, WL 9.4, Sol 18 Fin RIH, PU Kelly, CBU, tag TOF @ 7210', burn over fsh, LD Kelly, POOH, LD FTA #9 & rec'd junk. RIH w/FTA #10 to 7930' tag up @ 7941', circ & prep to mill & rm @ 7941'. 5" Lnr: TOL @ 7210', LC @ 7958', FC @ 8034' 5" @ 7212' - 8112' 8034', TOH Wt. 11.2+, PV 11, YP 6, PH 11.5, WL 8.6, Sol 15 Rmw/mill assy f/7930'-7936', mill junk f/7936'-7937', POOH, LD FTA #10 TIH w/FTA #11, tag DP junk @ 7937' mill to 7952' POOH, LD FTA #11. RIH w/FTA #12, tag DP junk @ 7951', mill wiper plug & LC to 7953', mill & drl cmt f/7953'-8034', C&C, TOH. TIH w/4-1/8" bit & 5" csg scrpr to 8034' (top of FC), C&C, TOH. 5" @ 7212' - 8112' 8034' PBTD, TIH w/5" csg scrpr Wt. 11.3, PV 12, YP 7, PH 11.5, WL 8.8, Sol 15 Fin TOH. RU Schl, rn CET/GR f/8016'-6530'. Rn CBL 8016'-7195' Rn GCT 7957'-25'. TIH w/6-1/8" & 7" csg scrpr to 7212' TOL, TOH. 5" @ 7212' - 8112' 8034' PBTD, TOH 11.2 ppg NaCl/NaBr TIH w/4-1/8" bit, tag 8034' PBTD. Tst lnr & 7" Wt up brine to 11.2 ppg & circ, TOH. csg to 3000 psi. 5" @ 7212' - 8112' 8034' PBTD, RIH w/2-7/8" tbg 11.2 ppg NaC1/NaBr Fin POH, chg rams to 2-7/8". RU Schl, perf "A" sand w/3-3/8", 6 SPF, 60° phasing f/7857'-7906'. Perf "C" sands w/3-3/8", 6 SPF, 60° phasing twice f/12 SPF 7691'-7744'. Rn JB w/4.125" gauge ring, set Bkr 5" DP pkr w/tailpipe @ 7756' (WLM). RD Schl. Prep to rn 2-3/8" compl. The above is correct Signature For form preparation and distribut~n see Procedures Manual Section 10, Drilling, Pages 86 and 87 IOate [Title Ii-I~-z~ Drillin8 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 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 enlire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 904341 Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 9/27/85 9/28/85 County or Parish Lease or Unit Tte North Slope Borough Accounting cost center code State Alaska AUL 25570 Well no. 2A-15 Completion A.R.Co. Date Date and depth as of 8:00 a.m. Complete record for each day reported API 50-103-20041 W.I. rTotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well i IHour I Prlor status if a W.O. 9/9/85 ! 2230 hrs. 5" @ 7212' - 8112' 8034' PBTD, RIH w/i-I/2" dummy vlv 6.8 diesel in tbg & ann Rn 228 j ts, 6.5#, J-55 8RD EUE IPC tbg & Ind. Lnd tbg hgr, drop ball, set pkr, tst tbg, ball sheared out. RU WL, ck ball gone. Set std'g vlv & tst tbg. Shear off OEJ/Pkr. Tst ann. Tst SSSV. RIH, pull std'g vlv. ND BOPE, NU & tst tree. RU, displ well to orifice vlv; vlv plugged. RU WL, pull orifice vlv. Fin displ well to diesel. RIH w/I-i/2" dummy vlv. SSSV @ 1820', Pkr @ 7047', Pkr @ 7761', "D" Nipple @ 7778', TT @ 7784' . 5" @ 7212' - 8112' 8034' PBTD, RR 6.8 diesel in tbg & ann Set 1½" dummy vlv @ 6892', POH. SITP = 450 psi. Press tbg to 1200 psi w/slow bleed off. Press ann to 2500 psi w/immediate bleed-off. RU gauge on tbg & re-press ann to 1000 psi w/tbg press following. RIH, attempt to pull dummy @ 6892', POH; no rec'y. Rn impression block, shows vlv in GLM. RIH w/1½" gauge ring & jar dn on vlv. Tst ann to 2500 psi w/tbg @ 450 psi; good tst. POH, RD WL. Set BPV. RR @ 1445 hrs, 9/27/85. Old TO New TD PB Depth 8034 ' PBTD Released rig Date Kind of rig 1445 hrs. 9/27/85 Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date { Title For form preparation and d~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent October Z$, 19B5 Mr. C. ~j' chattertOn · ioner - Comm~s~ iklaska r~nserVat~°n stat.e oka~ & Gas S~BJtb~: ~. . ~d 9yr°SC~nlet~°~ Dear ~"" ,.,~l C°mp-~e~yla the ~e"~v to you. I{ you h~ve ~n~ ~_t Sincerel~ ' . Gruber~ ~n~neer ~s soC~ ~t: jG/t~ EnclOsures RECEIVED ~,,~ov o ~ 19~ Alaska Oil & Gas Cons, Commlsslo~ Anchorage ARCO Alaska, ~'~' ~'s ~ Subsid\a~¥ °~' AttanVtcRiCh~AetdC°r°P~n¥ ~-' STATE OF ALASKA ---. ALASKAL AND GAS CONSERVATION CC ~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-146 ,. 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20041 4. Location of well at surface 9. Unit or Lease Name 1326' FSL, 227' FWL, Sec.13, TllN, RSE, UM ~L~TIONS Kupaurk River Unit ~ VERIFI~ I At Top Producing Interval 10. Well Number 1214' FNL, 1250' FEL, Sec.24, TllN, R8E, UM . Surf.__.r~-~ 2A-15 At Total Depth lt~. H. ~ 11. Field and Pool 1437' FNL, 1079' FEL, Sec.24, T11N, R8E, UN~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 122' RKBI ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/31/85 08/07/85 08/09/85*I N/A feet MS LI 1 17. Total Depth (MD+TVD) i18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8130'MD, 6237'TVD 8034'MD, 6163'TVD YES E~[X NO []I 1820 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/Cal/SP/GR/FDC/CNL, CET/GR, CBL/GR, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 210 sx AS II 9-5/8" 36.0# J-55 Surf 3373' 12-1/4"! 1000 sx AS III & 350 sx Class "G" Top .iob performed w/BO ~x AS I 7" 26.0# J-55 Surf 7442' 8-1/2" 500 sx Class "G" 5" 15.0# K-55 7212' 8112' 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) 7906'-7857 1~/6spf, 60° phasing 2-7/8"& 2-3/8" 7784' 7047' & 7761' 7744'-7691' w/12spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 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 TEST PERIOD Press.Fl°w Tubing Casing Pressure 24-HouRCALCULATEDRATE ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-A/~(~,~rr,~} ,~, '" 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. '~Cho_ ' . Form 10-407 DRH/WC26 *NOTE: Tubing was run & well perforated 9/27/85. Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . , 29. - ~ .. , : .. ~: - 30.. ~ . . : .:. :GEoi~o~IC MARKERs' ~ :_- .-..- :.:., ..; .: . . TESTS NAME Include interva~ tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7691' 5900' N/A Base Upper Sand 7744' 5941' Top Lower Sand 7804' 5987' Base Lower Sand 7974' 6117' I 31. LIST OF ATTACHMENTS Wcl I ....... .~, Cy, ,,.,ec~,, ~,_ ..v~,,,.~) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (j//0 ~Z-~' ~~ Title ^ssocia'ce 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". Fnrm 1 N-~N7 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District J County, parish or borough Alaska Field Lease or Unit Kuparuk River ADL 25570 Auth. or W.O. no. ITitle AFE 904341 I Drill North Slope Borough IState Alaska JWell no. 2A-15 Parker 141 AP1 50-103-20041 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Spudded Complete record for each day reported Date and depth as of 8:00 a.m. 7/31/85 8/01/85 8/02/85 I Hour 7/31/85 0130 hrs. 16" @ 104' 510' (406'), Dyna Drilling Wt. 8.7, PV 12, YP 15, PH 10.5, WL 20, Sol 4 Skid Rig f/2A-14 to 2A-15. NU 20" diverter sys. hrs, 7-31-85. Drl surf hole to 510'. 16" @ 104' 1967', (1457'), TIH w/new bit Wt. 9.3, PV 21, YP 26, PH 10.0, WL 10.3, Sol 6 ADC: $85,550 DD & surv to 1967', TOH. 657', 5.2°, S46.7E, 656.84 TVD, 7.01VS, 1107', 20.8°, S52.2E, 1094.05 TVD, 108.68 VS, 1571', 34.2° 1912', 44.9° JARCO W.I. · 56 24% IPrior status if a W.O. Spud @ 0130 64.45S, E 5.44 67.49S, E 85.38 , S563.E, 1506.30 TVD, 319.41 VS, 188.77S, E257.72 , S54.2E, 1768.06 TVD, 537.32 VS, 310.83S, E438.30 9-5/8" @ 3373' 3393', (1462'), Bled press off 9-5/8" csg Wt. 9.7, PV 16, YP 15, PH 10.5, WL 9.6, Sol 8 TIH, tight spot @ 1730', wsh & rm f/1730'-1967'. Drl f/1967'-3393', short trip to HWDP, pmp hi-vis sweep to cln' hole, TOH. RU & rn 81 its, 9-5/8" csg w/FS @ 3373' & FC @ 3283'. Cmt w/1000 sx of AS III lead slurry, followed by 350 sx C1 "G" cmt. Bump plug w/3000 psi; OK. CI? @ 0600 hrs,. 2228', 45.5°, S53.2E, 1990.72, 761.51VS, N443.57, E 619.01 2981', 45.4°, S51.6E, 2521.12, 1294.32 VS, N774.23, E1038.94 3358', 45°, S52.6E, 2786.77, 1562.47 VS, S938.56, E1250.03 RECEIVED The above is correct ~.~_,~.~ 10/10/85 Dr±ll±ng Super'lntendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets unlil final completion. Report official or representative test on "Final" form. 1) Submit "Interim" 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 8/03~85 thru 8/05/85 8/06/85 8/07/85 IState Alaska Well no. 2A-15 9-5/8" @ 3373' 7470', (1469'), LD 5" DP Wt. 9.6, PV 15, YP 13, PH 9.5, WL 7.6, Sol 9.5 ADC: $417,5228 Perform top job w/80 sx AS I. ND diverter sys, NU & tst BOPE. TIH w/BHA, DO FC, cmt, FS + 10' new hole. Conduct formation leakoff tst; OK. Turbine drl & surv to 7470', C&C, TOH. 3715', 45.5°, S54.5E, 2038.10 TVD, 1816.05 VS, S1089.19, E1453.97 4211', 45 5147', 40 5648', 42 6019', 43 6581', 44 7125', 44 .4°, S58E, 3386.06 TVD, 2169.38 VS, S1285.57, E1747.87 .8°, S55.3E, 4075.70 TVD, 2801.87 VS, S1645.11, E1999.69 .2°, S55E, 4450.93 TVD, 3133.83 VS, N1834.92, E2540.63 .2°, S55.5E, 4723.58 TVD, 3385.41VS, N1978.33, E2747.35 .1°, S57.1E, 5130.23 TVD, 3773.17 VS, S2193.57, E3070.08 .5°, S59E, 5519.57 TVD, 4125.45 VS, S2394.63, E3392.46 7" @ 7442' 7470', (0'), Tst BOPE Wt. 11+, PV 17, YP 14, PH 9.0, WL 7.2, Sol 3 LD 5" DP. Chg rams to 7" & tst to 3000 psi; OK. RU & rn 173 its 7", 26# csg w/FS @ 7442', FC @ 7354'. Cmt w/500 sx CL "G" cmt & bump plug w/3000 psi. Instl packoff & tst to 3000 psi. NU BOPE & tst BOPE. 7" @ 7442' 7758', (288'), Drlg Wt. 10.9+, PV 17, YP 11, PH 9.0, WL 6.2, Sol 15 TIH, tst 7" csg to 3000 psi. DO FC, cmt, FS + 10' leak-off tst; OK. Drl f/7490'-7758'. new hole. mn The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 JOate ITitle 10/10/8..51 Drilling Superintendent ARCO Oil and Gas Company Daily ell History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Field Kuparuk River ADL 25570 Auth. or W.O. no. AFE 904341 Operator I Accountlng cost center code District ICounty or Parish I State Alaska ILease or Unit North Slope Borough I Alaska I Title IWell no. 2A-15 Drill Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Old TD Released rig Parker 141 IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% IOate 7/31/85 Complete record for each day reposed 8/08/85 8/09/85 0600 hrs. AP1 50-103-20041 I otal number of wells (active or inactive) on this est center prior to plugging and ~ bandonment of this well I our ]Prior status I! a W.O. 0130 hrs. 7" @ 7442' 8131' TD, (373'), TIH, Prep to CBU Wt. 11.0+, PV 19, YP 14, PH 8.5~ WL 7.6, Sol 16 Drl to 8131', short trip. Circ hi-vis sweep, POH. TIH. Rn logs. 7" @ 7442' 8034' PBTD, (0'), RR Wt. 11.2+, PV 17, YP 8, PH 8.0, WL 7.2, Sol 18 Prep hole f/5" lnr, TOH. Rn lnr on DP. Cmt same, TOH to 2000'. Displ hole w/10.3 ppg brine. ND stack, NU lower tree. RR @ 0600 hfs, 8-9-85. Classifications (oil, gas, etc.) Oil New TO I PB Depth 8131' (8/7/85) 8034' IDate Kind of rig · 8/9/85 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Si~,~ ~ ~:.-~. ~. ::, ~-. ~* ~' ~ ~,.~ i.~.. :. IDate For form preparation and distribution, see Procedures Manual, Section 10, 10/10/85 ITM Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2A-15 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 2A-15. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, and geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well is completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L121 Enclosure RECEIVED ~"l~<a 0il & Gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~J'lcho~'~g~, ~' ~ -~ STATE OF ALASKA ALASKAL AND GAS CONSERVATION CC,. VllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED F~X ABANDONED [] SERVICE [] · 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 85-1~6 3. A~c~d~ess ....... 8.' APl Number P. 0. Box 100360~ Anchorage, AK 99510 50- 103-200z~1 , . . ..... 4. Location of well at surface 9. Unit or Lease Name 227' FWL, 1327' FSL, Sec.13, T11N, R8E, UM Kupaurk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 2A-15 At Total Depth 1 i[ Field and Pool To be submitted when gyro is received. Kuparuk River Field 5, Elevation in feet (indicate KB, DF, etc.) I 61 Lease Designation and Serial No. Kuparuk River Of 1 Pool 12~' RKBJ ADL 25570 ALK 2668 12. Date Spudded ' ' 13. Date T.D. Reached 14. Date Comp., susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 07/31/85 08/07/85 08/09/85 N/A feet MS L 1 17. Total Depth (MD+TVD) l'8. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8130'ND 803~'ND YES [] NO I~X N/A feet MD 1500' (approx} ....... . , 22. Type Electric or Other Logs Run D ! L/SFL/Ca 1/SP/GR/FDC/CNL 231 ..... cAsiNG, LiNeR AND CEMENTING RECORD '- SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1G" 62.5# H-~,0 surf ~0~' 2~" 210 sx AS" II · , 9-5/8" 36.~# ' J-55 Surf 3373' 12'1/4" 1000 sx AS III & 350 sx Class "G" Top job performed w/80 ~x AS I '~,', 26.0# ..... j.$5- . Surf 74~2'; '8.1/2,,' 500 sx Class ,,G,, - '" 5h '~5.0# K-55 ' 7212' 8112' 6-1/8" 15-0 sx C'lass "G" 2~. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH sET (MD) PACKE~ SET (MD) , . -- None N/A '26. ACID, FR/~CTURE, CEME~IT sQUEEZE, ETC. D'E'PTH INTERV~,'L (MD) 'AMOUNt' & KIN'D'OF MATERIAL USED' ' . N/^ ..... -- 27. ' N'/A PRODUCTION TEST ..... Date First Production I Method of Operation (Flowing, gas lift, etc.) D~te of Test Hours Tested PRODUCTION FOR OIL-BBI" GAS--MCF WATER-BBL CHOKE s'IZE ] GAS-OIL RATIO TEST PERIOD JJ~ I FIo~v Tubin'g Casing Pres;'ure CALCULATED OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (~o;r) ' ' Press. 24-HOUR RATE e ........ 28. CORE DATA ..... Brief' description of litho~J3gy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RE:CEIVED ;;.'-:s~.: ...... o Gas Cons, C0rlIlTIJSSI0P Anchorage ...... Form 10-407 DRH/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ; 30. ' GEOLOGIc MARK'ERS -- 'FORMATION TESTS , NAME Includerinterval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted wh ;n gyro is recei ~ed. N/A 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,'/~ ~ ~J--~ 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 DIRECFIONAI. SURVEY [~IUIDANCE [~ONTINUOU$ [~OOL Company Well Name' Field/Location ARCO ALASKA INCORPORATED NORTH SLO,PE, J,ol~ Reft, ,,enc,e No. 70850 MCBRIDE RECEIVED [~-~, Alaska Off & Sas torts. Date 07-OCTOBER-85 C0mgut~l 8z CUDNF.¥ SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING POR ARCO ALASKA, INC. 2A-15 KUPARUK NORTH SLOPE~ALASKA SURVEY DATE: 23 SEP 85 ENGINEER: MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 54 OEG 40 MIN EAST ARCO ALASKAt INC. 2A-15 KUPARUK NORTH SLOPEtALASKA COMPUTATION DATE: 4-0CT-85 PAGE 1 DATE OF SURVEY: 23 SEP 85 KELLY BUSHING ELEVATION: 122.00 ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -122.00: 0 0 N 0 0 E 100.00 100.00 -22.00 0 6 N 58 29 E 200.00 200.00 78.00 0 9 S 2 36 E 300.00 300.00 178.00 0 5 S 30 16 E 400.00 400.00 278.00 0 13 S 19 8' E 500.00 500.00 378.00 0 38 S 36 3 E 600.00 599.94 477.94 3 13 S 53 45 E 700.00 699.51 577.51 7 7 S 50 27 E 800.00 798.27 676.27 10 55 S 51 36 E 900.00 895.87 773.87 13 46 S 52 22 E 1000.00 992.38 1100.00 1087.20 870.38 16 44 965.20 20 15 1200.00 1180.03 1058.03 23 3 1300.00 1271.06 1149.06 26 5 1400.00 1359.54 1237.54 29 10 1500.00 1445.70 1323.70 32 6 1600.00 1528.50 1406.50 35 58 1700.00 1607.78 1485.78 38 56 1800.00 1683.98 1561.98 41 49 1900.00 1756.70 1634.70 44 41 2000.00 1826.84 1704.84 45 42 2100.00 1896.86 1774.86 45 26 2200.00 1966.88 1844.88 45 38 2300,00 2036,70 1914,70 45 35 2400.00 2106,77 1984.77 45 31 2500.00 2176.89 2054,89 45 26 2600.00 2247.10 2125.10 45 19 2700.00 2317.51 2195,51 45 20 2800,00 2387.62 2265.62 45 26 2900.00 2457,58 2335,58 45 50 3000,00 2527,24 2405,24 45 49 3100,00 2596,93 2474,93 45 46 3200,00 2666,72 2544,72 45 40 3300.00 2736,68 2614,68 45 30 3400.00 2806.88 2684.88 45 33 3500.00 2876,59 2754,59 45 57 3600.00 2946.03 2814,03 46 0 3700,00 3015.59 2893,59 45 52 3800.00 3085.20 2963.20 45 57 3900,00 3154,66 3032.66 46 3 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST./ ~ AZIMUTH FEET DEG/IO0 FEET FEET 0.00 0.00 O.OO N 0.00 E 0.32 0.39 0.09 S 0.33 E 0'37 0.23 0.18 S 0.33 E 0.54 0.29 0.36 S 0.41 E 0.77 0.26 0,71 S 0,44 E 1.26 1.15 1.17 S 0.72 E 4,14 3,83 2,93 S 3,00 E 13.12 3.53 8.53 S 10.03 E 28.69 4.01 18.35 S 22.16 E 50.38 2.36 31.68 S 39.29 E S 52 22 E 76,49 S 53 22 E 108,20 S 54 25 E 145,34 S 55 26 E 186,69 S 57 35 E 233,22 S 57 50 E 283.87 S 58 49 E 339.80 S 59 7 E 400.53 S 57 42 E 465.12 S 56 39 E 533,68 S 56 7 E 604,92 S 55 30 E 676,30 S 55 33 E 747,69 S 55 25 E 819,27 S 55 4 E 890.61 S 55 17 E 961.91 S 55 41 E 1033.11 S 55 54 E 1104.10 S 55 58 E 1175,39 S 55 58 E 1246.83 S 56 9 E 1318.54 S 56 14 E 1390.24 S 56 23 E 1461.83 S 56 18 E 1533.25 S 56 19 E 1604,44 S 56 19 E 1676.10 S 56 38 E 1748.03 S 57 10 E 1819.81 S 57 29 E 1891.53 S 57 43 E 1963.38 3.00 3,41 2,41 3,78 2,76 3,67 3,'77 3,02 3.12 2.47 0,33 0,46 0,26 0,90 0,33 0,31 0,35 0,93 0,22 0.54 0,14 0,41 0.54 0,49 0.68 0,29 0.32 0.26 0.35 0,22 FEET,:':!'' DEG MIN 'N o o E , 74 39 E 0.;, 61 57 E O~3 ,S 48 42 E 0'8, 'S 32 3 E 1~3,,7.' S 31 34 4,20,'~- S 45 4~ 13.17." 'S 49 28.77 S 50 22 E 50,47 S 51 6 E 47,64 S 59.99 E 76.61 S 51 32 E 66.86 S 85.23 E 108.33 S 51 53 E 88,69 S 115.28 E 145.45 S 52 25 E 112.42 S 149.15 E 186.77 S 52 59 E 138.16 S 187.93 E 233.26 S 53 40 E 165,12 S 230,92 E 283.88 S 54 25 E 194.64 S 278.55 E 339.81 S 55 3 E 225,71 S 330,95 E 400-59 S 55 42 E 259,69 S 386,04 E 465,26 S 56 4 E 296,78 S 443,79 E 533.88 S 56 13 E 336.33 S 503.08 E 605.15 S 56 14 E 376.46 S 562.12 E 676.54 S 56 11 E 416.91 S 620.95 E 747.93 S 56 7 E 457.38 S 680.00 E 819.51 S 56 4 E 498.15 S 738.55 E 890.85 S 56 0 E 538.88 S 797.08 E 962.15 S 55 56 E 579.23 S 855,74 E 1033,35 S 55 S 619,17 S 914,45 E 1104,35 S 55 5. . 659,06 S 973.57 E 1175,67 S 55 54 E 699.02 S 1032.80 E 1247.12 S 55 54 739.07 S 1092.32 E 1318.86 S 55 55 E 779.01 S 1151.89 E 1390.58 S 55 55 E 818.68 S 1211.52 E 1462.20 S 55 57 E 858.24 S 1271.02 E 1533,65 S 55 58 E 897.78 S 1330.26 E 1604.86 S 55 59 E 937.54 S 1389.92 E 1676.56 S 55 59 E 977.32 S 1449.88 E 1748.52 S 56 1 E 1016.52 S 1510.09 E 1820.35 S 56 3 E 1055.26 S 1570.53 E 1892.13 S 56 6 E 1093.78 S 1631.29 E 1964.04 S 56 9 E ARCO ALASKA~ INC. 2A-15 KUPARUK NORTH SLOPE~ALASKA COMPUTATION DATE: 4-0CT-85 PAGE 2 DATE OF SURVEY: 23 SEP 85 KELLY BUSHING ELEVATION: 122.00 F1 ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 4000.00 3224.10 3102.10 45 55 S 57 59 E 2035.23 4100.00 3293.71 3171.71 45 48 S 58 15 E 2106.89 4200,00 3363,51 3241,51 45 48 S 58 25 E 2178,34 4300.00 3433,12 3311,12 45 52. S 58 43 E 2249,98 4400,00 3502,76 3380,76 45 45 S 58 55 E 2321,55 4500.00 3572.78 3450.78 45 16 S 58 58 E 2392.74 4600.00 3644.31 3522.31 43 3 $ 55 50 E 2462.48 4700.00 3717.86 3595.86 42 30 S 55 4 E 2530.23 4800.00 3791.80 3669.80 42 7 S 55 8 E 2597.55 4900.00 3866.15 3744.15 41 51 S 55 7 E 2664.43 0.32 0.44 0.37 0.25 0.39 0.97 2.74 0.39 0.37 0.25 5000.00 3940.79 3818.79 41 33 5100.00 4015.80 3893.80 41 15 5200.00 4091.11 3969.11 40 59 5300,00 4166,40 4044,40 41 48 5400.00 4240,32 4118,32 42 25 5500,00 4314.15 4192,15 42 28 5600.00 4387.84 4265,84 42 33 5700,00 4461.49 4339,49 42 30 5800.00 4535.25 4413.25 42 25 5900,.00 4609,13 4487.13 42 19 S 55 7 E 2730.97 S 55 11 E 2797.11 S 55 15 E 2862.89 S 55 2 E 2928.69 S 54 53 E 2996.05 S 54 57 E 3063.49 S 55 7 E 3131.09 S 55 11 E 3198.72 S 55 16 E 3266.26 S 55 25 E 3333.65 0.30 0,23 0.25 1.89 0.19 0.26 0.22 0.12 0.15 0.16 6000,00 4682,75 4560,75 43 9 6100,00 4755,26 4633,26 43 35 6200.00 4827.67 4705,'67 43 42 6300,00 4899.84 4777.84 43 52 6400.00 4971.73 4849.73 44 8 6500,00 5043.38 4921.38 44 19 6600,00 5114.71 4992.71 44 35 6700.00 5185.92 5063.92 44 40 6800,00 5256.92 5134,92 44 51 6900.00 5327.68 5205.68 44 58 S 54 54 E 3401,31 S 54 57 E 3470,17 S 55 32 E 3539,14 S 55 49 E 3608,34 S 56 0 E 3677.84 S 56 22 E 3747.57 S 56 22 E 3817.63 S 56 44 E 3887,80 S 57 10 E 3958.17 S 57 33 E 4028.75 1.42 0.36 0.51 0.40 0.43 0.31 0.17 0.29 0.32 0.68 7000.00 5398.41 5276.41 45 3 7100.00 5469.01 5347.01 44 58 7200.00 5539.93 5417.93 44 43 7300.00 5611.11 5489.11 44 24 7400.00 5682.90 5560.90 43 46 7500.00 5755.48 5633.48 42 30 7600.00 5830.55 5708.55 40 26 7700.00 5907.35 5785.35 39 47 7800.00 5983.97 5861.97 40 7 7900.00 6060.50 5938.50 39 57 S 58 2 E 4099.34 S 58 29 E 4170.01 S 59 12 E 4240.32 S 59 50 E 4310.31 S 60 27 E 4379.60 S 57 21 E 4448.10 S 48 44 E 4514.05 S 39 53 E 4576.79 S 38 27 E 4638.62 S 37 36 E 4700.27 0.27 0.69 0.90 0.71 0.80 5.70 6.88 2.74 0.77 0.88 RECTANGULAR COORDINATES HORIZ,, DEPARTURE NORTH/SOUTH EAST/WEST DIS,T;:'~' I:: AZIMUTH FEET FEET FEET,~' DEG MIN 1132.06 S 1692.23 E 2035;~!':aili;'i S 56 13 e 1169.97 S 1753.20 E 2107'~3':~i,"5 56 17 E 1207,51 S 1814.17 E 2179','29:i: S 56 21 E 1244.97 S 1875.42 E 2251,'03:' '$ 56 25 E 1282.11 S 1936.83 E 2322.74 ..$ 56 29 E 1318.86 S 1998.04 E 2394,07S 56 34 E 1356o06 S 2057.16 E 2463-90': S 56 3f ~ 1394.81 S 2'112.73 E 2531.63 S 56 3~ / 1433.33 S 2167.94 E 2598.93 S 56 31 ~ 1471.55 S 2222.83 E 2665.79 S 56 29 E 1509.61 S 2277.42 E 2732.31 S 56 27 E 1547.40 S 2331.70 E 2798.44 S 56 25 E 1584.91 S 2385.73 E 2864.20 S 56 24 E 1622.45 S 2439.78 E 2930.00 S 56 22 E 1661.19 S 2494.88 E 2997.33 S 56 20 E 1699.95 S 2550.07 E 3064.75 S 56 18 E 1738.68 S 2605.48 E 3132.34 S 56 17 E 1777.32 S 2661.00'E 3199.96 S 56 15 E 1815.84 S 2716.47 E 3267.49 S 56 14 E 1854.16 S 2771.91 E 3334.87 S 56 13 E 1892.74 S 2827.50 E 3402.53 S 56 12 E 1932.43 S 2883.77 E 3471.37 $'56 10 E 1971.74 S 2940.45 E 3540.34 S 56 9 E 2010.71 S 2997.65 E 3609.55 S 56 8 E 2049.72 S 3055.18 E 3679.06 $ 56 8 E 2088.49 S 3113.17 E 3748.81 S 56 8 E 2127.32 S 3171.53 E 3818.91 S 56 ~ 2166.04 S 3230.09 E 3889.12 S 56 ". ~ 2204.42 S 3289.13 E 3959.53 S 56 10 E 2242.58 S 3348.60 E 4030.17 S 56 11 E 2280.19 S 3408.46 E 4100.84 S 56 13 E 2317.49 S 3468.65 E 4171.61 S 56 15 E 2353.94 S 3529.00 E 4242.03 S 56 17 E 2389.53 S 3589.56 E 4312.17 S 56 20 E 2424.18 S 3649.93 E 4381.63 S 56 24 E 2458.77 S 3709.37 E 4450.28 S 56 27 E 2497.96 S 3762.44 E 4516.17 S 56 25 E 2544.39 S 3806,42 E 4578,51 S 56 14 E 2594.42 S 3846.75 E 4539.88 S 56 0 E 2645.14 S 3886.37 E 4701.13 S 55 45 E 'ARCO ALASKA~ INC. 2A-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 4-0CT-85 PAGE 3 DATE OF SURVEY: 23 SEP 85 KELLY BUSHING ELEVATION: 122o00 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL OEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST D~ST°,,,~i,' ::AZ~M'UTH FEET DEG/IO0 FEET FEET FEET,~i~i', , DEG MIN 8000.00 6137.27 6015.27 39 50 8100.00 6214.05 6092.05 39 50 8130.00 6237.08 6115.08 39 50 S 36 23 E ¢761.28 S 36 23 E 4822o~2 S 36 23 E ~840.37 0.00 2696.43 S 3924.78 E S, 55 30 E 0.00 27~8.0! S 3962.80 E 48 S 55 15 E 0.00 2763.48 S 3974.21 E 48401b ,'S 55 11 E ~RCO ALASKA, INC. 2A-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 4-0CT-85 PAGE 4 DATE OF SURVEY: 23 SEP 85 KELLY BUSHING ELEVATION: 122.00 YT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -122.00 "0 0 1000.00 992.38 870.38. 16 44 ZO00.O0 1826.84 1704o84 45 42 3000.00 2527.24 2405.24 45 49 4000.00 3224.10 3102,10 45 55 5000.00 3940.79 3818.'79 41 33 6000.00 4682.75 4560.75 43. 9 7000.00 5398.41 5276.41 45 3 80'00.00 6137.27 6015.27 39 50 8130.00 6237.08 6115.08 39 50 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST.:' AZIMUTH FEET DEG/IO0 N 0 0 E 0.00 S 52 22 E 76.49 S 56 7 E 604.92 S 56 9 E 1318.54 S 57 59 E 2035.23 S 55 7 E 2730.97 S 54 54 E 3401.31 S 58 2 E 4099.34 S 36 23 E 4761.28 S 36 23 E 4840-37 0.00 3.0'0 0.33 0.14 0.32 0.30 1.42 0.27 0.00 0.00 FEET FEET. FE'ET.~, OEGMIN 0.00 N' O.O0'E 0:.00,':" N 0 0 E 47.64 S 59.99 E 76, ) ..... ::S 51 32 E 1132.06 S 169Z.23 E 203S.97. S 56 13 E 1509.61 S 2277.42 E Z73Z.31 S 56'Z7 = 1892.74 S 2827.50 E 3402.53'S 56 12 l 2280.19 S 3408.46 E 4100.84 S 56 13 ~ 2696.43 S 3924.78 E 4761.79 S 55 30 E 2763.48 5 3974.Z1E 4840.57 S 55 11 E ^~rn ~I._~SKA. INC. 2A-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 4-0CT-85 PAGE DATE DF SURVEY: 23 SEP 85 KELLY BUSHING ELEVATION: 122o00.F ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA, COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -122.00.. 0 0 N 0 0 E 22.00 22.00 -100.00 0 20 S 83 59 E 122.00 122.00 0.00 0 3 S 77 4 E 222.00 222.00 100.00 0 9 S 14 31 E 322.00 322.00 200.00 0 B S 12 59 E 422.00 422.00 300.00 0 12 S 26 55 E 522.01 522.00 400.00 0 56 S 43 47 E 622.10 622.00 500.00 4 4 S 52 41 E 722.69 722.00 600.00 7 54 $ 50 3,4 E 824.21 822.00 700.00 11 50 S 51 50 E 926.94 922.00 1031.01 1022.00 800.00 14 28 900.00 17 48 1137.25 1122.00 1000.00 21 27 1245.78 1222.00 1100.00 24 13 1357.21 1322.00 1200.00 28 2 1472.21 1422.00 1300.00 31 10 1591.99 1522.00 1400.00 35 40 1718.31 1622.00 1500.00 39 28 1851.70 1722.00' 1600.00 43 24 1993.07 1822.00 1700.00 45 42 2135.85 1922.00 1800.00 45 32 2278.94 2022.00 1900.00 45 40 2421.73 2122.00 2000.00 45 30 S 52 22 E S 52 30 E S 53 54 E S 54 57 E S 56 33 E S 57 52 E S 58 42 E S 58 49 E S 57 18 E S 56 gE S 55 27 E S 55 30 E S 55 6 E VERTICAL DOGLEG RECTANGULAR COORDINATES HO,RIX,. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DZST6,~L: AZIMUTH FEET DEG/IO0 FEET FEET ,FEE'T""~:~,,':' BEG MIN 0.00 0'00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.32 0.48 0.07 S 0.34 E 0.42 0.19 0.24 S 0-34 E 0.57 0.38 0.40 S 0.42 E 0.84 0.17 0.78 S 0.48 E 1.51 1.96 1.37 S 0.88 E 5.55 4.03 3.78 S 4.12 E 16.13 3.40 10.45 S 12.36 E 33.44 3.56 21.30 S 25.89 E 56.94 2.75 85.68 3.80 121.48 3.11 163.62 2.85 212.71 3.12 269.38 3.23 335.13 3.86 412.02 3.19 500.12 3.10 599.96 0.29 701.86 0.49 804.19 0.41 906.11 0.38 35.69 S 44.49 E 57.04 S 51 15 E 53.25 S 67.28 E 85.80 S 51 38 E 74.72 S 95.93 E 121.60 S 52 5 E 99.26 S 130.20 E 163.72 S 52 40 E 127.04 S 170.67 E 212.77 S 53 20 E~ 157.38 S 218.63 E 269.39 S 54 15 E 192.20 S 274.55 E 335.14 S 55 0 E 231.63 S 340.85 E 412.10 S 55 48 E 278.52 S 415.60 E 500.30 S 56 10 E 333.57 S 498.95 E 600.19 S 56 1¢ E 390.96 S 583.18 E 702.10 S 56 9 E 448.85 S 667.57 E 804.44 S 56 5 E 507.03 S 751.26 E 906.35 S 55 59 E 2564.26 2222.00 2100.00 45 23 2706.40 2322.00 2200.00 45 22 2849.02 2422.00 2300.00 45 34 2992.48 2522.00 2400.00 45 49 3135.91 2622.00 2500.00 45 43 3279.03 2722.00 2600.00 45 35 3421.62 2822.00 2700.00 45 41 3565.39 2922.00 2800.00 46 1 3709.20 3022.00 2900.00 45 51 3852.94 3122.00 3000.00 46 0 3996.98 3222.00 3100.00 45 56 4140.54 3322.00 3200.00 45 42 ¢284.03 3422.00 3300.00 45 53 4427.56 3522.00 3400.00 45 38 4569.31 3622.00 3500.00 43 ~9 4705.61 3722.00 3600.00 42 28 4840.66 3822.00 3700.00 41 59 S 55 32 E 1007.67 S 55 55 E 1108.66 S 56 0 E 1210.32 S 56 9 E 1313.15 S 56 20 E 1415.95 S 56 21 E 1518.28 S 56 20 E 1619.89 S 56 29 E 1723.14 S 57 12 E 1826.41 S 57 38 E 1929.54 S 57 58 E 2033.06 S 58 22 E 2135.86 S 58 39 E 2238.55 S 58 58 E 2341.23 S 57 5 E 2441.41 S 55 4 E 2534.03 S 55 9 E 2624.78 0.39 0.78 0.49 0.13 0.19 0.34 0.60 0.33 0.27 0.25 0.31 0.33 0.31 0.48 4.38 0.39 0.23 564.87 S 834.75 E 1007.91 S 55 54 E 621.72 S 918.24 E 1108.92 S 55 53 E 678.59 S 100Z.54 E 1210.61 S 55 54 E 736.06 S 1087.84 E 1313.46 S 55 5 ~ 793.28 S 1173.29 E 1416.29 S 55 5. .. 849.95 S 1258.56 E 1518.68 S 55 58 E 906.34 S 1343.12 E 1620.32 S 55 59 E 963.59 S 1429.10 E 1723.61 S 56 0 E 1020.09 S 1515.64 E 1826.95 S 56 3 E 1075.66 S 1602.66 E 1930.17 S 56 7 E 1130.91 S 1690.39 E 2033.81 S 56 1Z E 1185.21 S 1777.91 E 2136.74 S 56 18 E 1239.02 S 1865.63 E 2239.58 S 56 24 E 1292.29 S 1953.73 E 2342.45 S 56 31 E 1344.41 S 2039.58 E 2442.81 S 56 36 E 1396.98 S 2115.84 E 2535.42 S 56 33 E 1448.89 S 2190.29 E 2626.15 S 56 30 E ARCO ALASKA, INC. 2A-15 KUPARUK NORTH SLOPEsALASKA COMPUTATION DATE: 4-0CT-85 PAGE . 6 DATE OF SURVEY: 23 SEP 85 KELLY BUSHING ELEVATION: 122.00 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH 'DEPTH DEG MIN' DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET' DEG MIN 4974.88 3922.00 3800.00 41 38 5108.25 4022.00 3900.00 41 14 5240.89 4122.00 4000.00 4! 4 5375.17 4222.00 4100.00 42 '26 5510.65 4322.00 4200.00 42 29 5646.40 4422.00 4300.00 42 34 5782.05 4522.00 4400.00 42 Z6 5917.41 4622.00 4500.00 42 21 6054.07 4722.00 4600.00 43 32 6192.16 4822.00 4700.00 43 40 6330.77 4922.00 4800.00 43 58 6470.13 5022.00 4900.00 44 16 6610.24 5122.00 5000.00 44 34 6750.78 5222.00 5100.00 44 45 6891.97 5322.00 5200.00 44 58 7033.42 5422.00 5300.00 45 5 7174.71 5522.00 5400.00 44 50 7315.23 5622.00 5500.00 44 19 7454.07 5722.00 5600.00 43 29 7588.71 5822.00 5700.00 40 36 7719.06 5922.00 5800.00 39 52 7849.73 6022.00 5900.00 40 3 7980.11 6122.00 6000.00 39 50 8110.36 6222.00 6100.00 39 50 8130.00 6237.08 6115.08 39 50 S 55 6 E 2714.30 S 55 12 E 2802.55 S 55 14 E 2889.68 S 54 52 E 2979.29 S 54 58 E 3070.69 S 55 9 E 3162.49 S 55 14 E 3254.15 S 55 23 E 3345.36 S 54 48 E 3438.50 S 55 29 E 3533.72 S 55 49 E 3629.69 S 56 19 E 3726.73 S 56 23 E 3824.82 S 56 58 E 3923.51 S 57 30 E 4023.07 S 58 8 E 4122.96 S 59 3 E 4222.54 S 59 56 E 4320.92 S 59 48 E 4416.76 S 49 49 E 4506.71 S 39 4 E 4588.55 S 37 58 E 4669.34 S 36 23 E 4749.17 S 36 23 E 4828.42 S 36 23 E 4840.37 0.31 0.23 0.74 0.16 0.23 0.33 0.16 0.39 0.26 0.52 0.36 0.28 0.24 0.42 0.61 0.26 0.92 0.61 2.58 6.64 0,.85 0.55 0.00 0.00 0.00 1500.07 S 2263.74 E 2715,64;::' S 56 28 E 1550.50 S 2336.17 E 2803':~.8 '$ 56 25 E 1600.17 S 2407.75 E 289~99 S 56 23 E 1651.56 S 2481.17 E 2980'58 S 56 21 E 1704.08 S 2555.97 E 307!~95 S 56 18 E 1756.62 S 2631.25 E 3163.?'3 S 56 16 E 1808.94 S 2706.52 E 3255.38 S 56 1~' 1860.81 S 2781.56 E 3346°59 S 56 1914.20 S 2857.88 E 3439.71 S 56 11 E L968.68 S 2935.98 E 3534.92 S 56 9 E 2022.70 S 3015.32 E 3630.90 S 56 8 E 2076.95 S 3095.81 E 3727.97 S 56 8 E 2131.30 S 3177.51 E 3826.10 S 56 8 E 2185.58 S 3260.01 E 3924.84 S 56 9 E 2239.52 S 3343.81 E 4024.49 S 56 11 E 2292.70 S 3428.56 E 4124.50 S 56 13 E 2344.80 S 3513.69 E 4224.23 S 56 17 E 2394.88 S 3598.77 E 4322.80 S 56 21 E 2442.58 S 3682.44 E 4418.88 S 56 26 E 2493.27 S 3756.76 E 4508.84 S 56 25 E 2553.83 S 3814.15 E 4590.18 S 56 11 E 2619.62 S 3866.54 E 4670.39 S 55 52 E 2686.17 S 3917. Z2 E 4749.75 S 55 33 E 2753.35 S 3966.74 E 4828.66 S 55 14 E 2763.48 S 3974.21 E 4840.57 S 55 11 E AoKn nl arK&. TNC. :~A-1. 5 KUP~RUK NORTH SLOPE~ALASKA HARKER TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND BASE LOWER SAND PBTD TO COMPUTATION D.4TE: 4-0CT-85 PAGE 7 DATE OF SURVEY: 23 SEP' 85 KELLY BUSHING ELEVATION: [2Z.,O0 .Fl ENGINEER: MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB SURFACE 'LOCATION ,AT':', ORIGIN= 1326' FSLe,227' FWL,SEC 13~TII!.N~R8E,UM TVD RECTANGULAR' COORDINATES SUB-SEA 7691.00 5900.~3 5778.43 .7744.00 5941oll 5819.11. 7804.00 5987.03 5865.03 7974°00 6117o3! 5995o31 8034.00 6163.38 6041.38 8130.00 6237.08 6115.08 N 0 R T H / S 0 UTH'% ,,:',: E ~ $ T / W E S T Z 539.93 S:!;":':, '"3~i~:02.78 E 2.566.30, S' ': ~'BZ4,. 19-;- E 2596.'' S' 38" '~: 8.3~ E 2683.02 S 391'.90 E ALASKA, INC. 2~-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 4-0CT-85 PAGE 8 DATE OF SURVEY: 23 SEP 85 KEL'L¥ BUSHING ELEVATION: 122.00 FT ENGINEER: MCBRIDE **~**~****** STRATIGRAPHIC SUMMARY MARKER TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND BASE LOWER SAND PBTD TD MEASURED DEPTH BELOW KB 7691.00 7744.00 7804.00 7974.00 8034.00 8130.00 SURFACE LOCATION ORIGIN= 1326 FSL~227 FWL,SEC .AT'. . . A~:~,TIi'N,R8E,UM TVD RECTANGUL ~:::::CO'ORDINATES FROM KB SUB-SEA NORTH/SOU~fi:.':t~.&$T/NEST 5900o~3 5778.~3 2539.93 $ 3'802.78 5941.11 5819oll 2566°30 S.3824.19 5987.03 5865.03 Z596.4& S 3848o.34 6117.31 5995.31 2683.02 S 39.~4.90 6163.38 60¢1.38 2713o97 S~ 3.937o71 6237.08 6115.08 2763.48 S 3'974o21 FINAL WELL LO'CATION ~T TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8130.00 6237.08 6115.08 4840.57 S 55 11 E SCHLUMBEROER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC WELL 2A-1S FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 0000708~0 WELL NAME: 2A- ~ SURFACE LOCATIOI~. 1326' FSL, 227' FWL, S13, Till,_ R8E, UM HORTZONTAL PROJECTION N01~rH ~000 REF 0000708~0 $Ci:ILE = ]/]OOO IN/FT i---~---t'--r--t-'-m**--~-"f ...... t-!'"?"t"{"*:--i'-'r"+.-" ...~_4...~...;...l..x...:...~., ...... ~-+ ~---~.--t--.~.--~-..~--+-- ...... . . : .... - . . · ~_.~.~...~.. 2000 *.-,-.+--~...~*.~.4-..~--4.+.~-- ";'+--~-'~-.i.-~..; ....... 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I' ':: '-: 'llA'I"IFII'I: ::, ~ : : :' } .~ PROJECTION ON VERTICAL PLANE 12S. - 30S. SC~-ED IN VERTICAL DEPTHS HORIZ SCALE = 1/ lO00 IN/FT 6000 125. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'O~P[E~TOR, ~;~E'LL(/NAMF~ ANIJ NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report SampleS _ Core Chips ..... . . .- Core Description /~, Registered Survey Plat 'Directional Survey~.:~ ? Drill Stem Test Reports Production Test Reports Digitized Data ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 13, 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 August monthly reports for the following wells' 2A-15 3C-7 1R-14 6-9 (workover) L1-2 L3-5 2A-16 3J-1 1R-15 6-10 (workover) L1-14 WSP-4 3A-1 3J-2 1R-16 9-30 L2-20 WSP-6I 3C-4 1R-1 2Z-9 9-31 L2-24 WSP-20 3C-5 1R-2 2Z-10 11-9 (workover) L2-26 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L62 Enclosures R£cE VED AlasV, a Oil & Gas Goos. Gommissioo Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany , -- STATE OFALASKA ALASKA O'~L AND GAS CONSERVATION COk..41SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-146 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20041 4. Location of Well at surface 227' FWL, 1327' FSL, Sec.13, TllN, R8E, UM (approx) :5. Elevation in feet (indicate KB, DF, etc.) 124' RKB I 6. Lease Designation and Serial No. ADL 25570 ALK 2668 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2A-15 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. August ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0130 hrs, 7/31/85. Drld 12-1/4" hole to 3393'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7470'. Ran, cmtd, & tstd 7" csg, Drld 6-1/8" hole to 8130'TD (8/7/85). Ran logs. Ran, cmtd, & tstd 5" csg. PBTD = 8034'. Secured well & RR ~ 0600 hrs, 8/9/85. 13. Casing or liner rgn and quantities of Cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 104'. Cmtd w/210 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3373'. Cmtd w/lO00 sx AS Ill & 350 sx Class G. Top job performed w/80 sx AS I. 7", 26. O#/ft, J-55, BTC csg w/shoe @ 7442'. Cmtd w/500 sx Class G. 5", 15.0#/ft, K-55, FL4S csg f/7212' - 8112'. Cmtd w/150 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/Cal/SP/GR/FDC/CNL f/8125' - 7428' 6. DST data, perforating data, shows of H2S, miscellaneous data None · -¢ r !985 Alaska 0il & Gas Cons. 60mmissi0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repo(~/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska OiI and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/MR02 Submit in duplicate ARCO Alaska· Inc.~", Post Office _.x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-30-85 TRANSMITTAL NO: 5317 RETUHN TO: ARCO ALASKA, INC. KUPA'RUK OPERATIONS ENGINEERING. RECORDS CLEkK ~{Yt)-i 11SS P.O. SOX 100360 ANCHOkAGE, AK 99510 TICANSMITTUD itEkE~ITI/ ARE kECEIPT AND KETURN ONE SIGNED OPEN HOLE LIS TAPES AND LISTI 2Z-9 08-11-85 hUN %1 34 2Z-10 0~-04-85 kUN #1 37 TlJL FOLLOWING ITEMS. PLEASE ACKNt)~{LEDGE COPY OF THIS TRANSMITTAL. NG/SCHL/ONE COPY' OF EACH 87.0-7357.0 REF # 70730 90.0-7t]06.0 REF # 70712 3L-8 07-23-~5 HUN ~1 5184.0-10065.5 REF # 70683 1R-16 08-19-~5 RUN #1 4062.5-8463.5 REF # 70754 1R-15 08-12-85 RUN #1 3788.0-7442.5 REF # 70738 1R-14 08-06-85 RUN Ii2 4602.0-9158.0 REF # 70726 2A-16 08-18-85 RUN #1 8979.0-9789.5 REF # 70753 2A-14 07-28-85 RUN #1 7170.5-7871.5 REF # 70705 2A-15 0~-08-85 RUN #1 7420.0-8142.0 REF # 70731 RECEIPT ACKNO~LEDGED: DISTRIBUTION: UPAE DRILLING W. PASHER CURRIER L. JOHNSTON L'XXON CI~EVRON . [,~OB1 L PHILLIPS OIL [,] NSK CLEI<K J. RATIlMELL · , ~-K' ~1 &_G~s Cons. commission SOIlIO UNION K. TULIN/VAULT "MiE'MORAN DUM .. State of Alaska ALASKA OIL AND G~ CONSERVATION COM~4ISSION f~ ,.--:~ . TO: cC~aV..~~terton DATE: FILE NO: THRU: Lonnie C. Smith '/ Co. is s loner TELEPHONE NO: August 7, 1985 D. HRH. 49 FROM: HaroId R. Hawkins~v;~--/:// SUBJECT: Petroleum Inspector ROPE Test ARCO, K.R.U. 2A-15 Permit No. 85-146 Kuparuk River Field Saturday, August 3, 1985: I left Pad IR Kuparuk River Unit, ~-u~~-of"an~tl{er report, to Pad No. 2A. I witnessed the ROPE Test on ARCO's 2A-15 well. There were no failures and I filled out an A.O.G.C.C. Report which is attached. In summary, I witnessed the successful B.O.P.E. tests on ARCO's Well No. 2A-15 K.R.U. perfomed by Parker Crew 141. Attachment 02-00IA(Rev. 10/79) STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Well JL/Y/ -'~LATOR SYSTEM Reserve Fjt_~ }!:j.d~i~!:~. v i g ua 1 Audio Tr~ p Tank Pt.t Gauge r_ow Monitor Gas Detectors gO~l: Stack Test Pressure A~nular Preventer Pipe Rams fiJ iud Rams ~.,,.ukt~ Lirte Valves H.C,R. Valve Kill L4ne Valves Check Valve Full ' ': ,:"~ Pre~,qure__ _~_.°_~__d~_....6:9__ Pressu .. .(ter (; 1 o s u re._W'__~_~_' .... Pump inet, clo? pres. 200 psig Full Charge Pressure Attained: ..... Gontro~: H~ster.__~~ Kelly_ and Floor Safety Valves Upper Kelly Lower Kei].y Ball Type Inside BOP Choke Manifold No. No. flanges_~/.,~ Repair or Replacement of failed equipment to be made within Commission office notified. / Test Pressure .... Test Pro$su re._. ~.~_.. Test Fress ~u_.~_.._~2_~ ................ Adjustable Chokes._ Hydrau~call! o erated choke Test Tlme _~____hrs. ~days and !nspe-ctot'/ Distribution orig. - A0&GCC cc - Operator cc -Supervjgor ,- , J ARCO Alaska, Inc. Post Office L 100360 Anchorage, Alaska 99510-0360 Teiephone 907 276 1215 Ak, 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 GRUlO/L86 Enclosure If RECEIVED JUL 0 Alaska Oil & Gas Cons. Commission · Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany · _ I [ Il I I WELL 1;5 : 5,960,867.69 Lot. 70° 18'15.5422" X= 498,620.82 Long. t50°00'40.220" O.G. Elev. 86.:5' Pod Elev. 91.5' -- -- FWL 227' FSL 1,446' j WELL 14 Y:5,seo,807.68 Lat. 70°18'14.9519" 12 © · 13 J X=498,620.83 Long. 150°O0'40.219" O.G. Elev. 86.7' Pad Elev. 91.8' : ii 0 · 14 FWL 227 FSLI,386' i ~o0 · ~5 WELL 45 Y:5,960,747.68 Lot. 70°18'14.3618" i 9 0 · 16 I X:498,620.75 Long. 150000'40.2.22" ' i [ ' cm.~,,. ~7,~' Po~ ~v. ~[.~' , FWL. 227 FSL t,526 WELL t6 Y=5,960,687.66 Lot. 70°18'1:5.7714 ~ X= 498,620.74 Long. 150°00'40.2 ?_l -- FWL 227' ' FSL 1,266' ! I i 80 ~ O~ 70 02 I 60 i O~ I 50 04 , I I I I i L'OCATED IN SECTIONS 13;14~23; 24, TttN,RSE. UMIAT MERIDIAN. " ' ] LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE 14 ~ UNDER MY DIRECT SUPERVISION AND THAT. ALL DETAILS ARE CORRECT AS OF D.S. 2-A,~ , , ' ARCO Alaska, Inc. ' : 'II'N' ' DRILL SITE ~-A ' ' ., ~ / } ~ lfili~ CONDUCTOR AS-BUILT lull LOCATIONS June 27, 1985 M~r. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2A- 15 ARCO Alaska, Inc. Permit No. 85-146 Sur. Loc. 227'FWL, 1327'FSL, Sec. 13, TllN, R8E, UM. Btmhole Loc. 1453'F~IL, l127'FEL, Sec. 24, TllN, R8E, UM. 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 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~zn Kupa~ak River Unit 2A- 15 -2- June 27, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing 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. ~ere 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 Bo._ ,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-15 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2A-15, 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 25, 1985. If you have any questions, please call me at 263-4970. Sincerely, .~B,~~E~/~ine~er .A~oa.Drllll g JBK/TEM/tw PD/LI08 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. 2. Name of operator ARCO Alaska, STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COIv,~v'llSSlON RERMIT TO DRILL 20 AAC 25.005 DR ILL [~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] ST]~Z~_ TI G R APH IC~,~) SINGLE ZONE [] MULTIPLE ZONE 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 227' FWL, 1327' FSL, $ec.13, T11N, R8E, UN (Approx.) At top of proposed producing interval 1264' FNL, 1399' FEL, Sec.24, T11N, RSE, UH At total depth 1453' FNL, 1127' FEL, See. 24, T11N, R8E, UN 9. Unit or lease name Kuparuk River Unit ..:.. '~1 10. Well number 2A-15 11. Field and pool Kuparuk River Fi eld 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. 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2A-14well 60' @ surface feet 16. Proposed depth (MD & TVD) 8112' ND, 6240' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 Distance and direction from nearest town 14. Distance to nearest property or lease line miles 1127' ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 44 o I (see 20 AAC 25.035 (c) (2) I 18. Approximate spud date 07/25/85 2913 psig@__8OOF Surface 3334 psig@ 5771 ft. TD (TVD) Proposed Casing, SIZE Hole J Casing L24" I 16" 12-1/4" 9-5/8" 8-1/2" 7" F6-1/8,, i 5,, Weight 62.5# 36. O# 26.0# 15.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-SS IBTCl HF-ERW /I ,I-55/HF-EI~WBTC j ,(-ss / FL4SJ Liner and Cementing Program Length 80 3292 7504' 780' SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 29' 29' I 29' I 29' I 28' I I 28' 7332'1 5680' I MD BOTTOM TVD 1091 109' 33211 2800' 7532~ 5824' 81121 6240' (include stage data) ± 200 cf 833 sx AS III & 348 sx Class G 149 sx Class G blend 100 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8112' MD (6240' TVD). A 20", 2000 psi annular diverter 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 3321' MD(2800' 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 weekly thereafter. Test pressure will be 3000 psig. Due to gas injection at 2A Pad, Kuparuk "C" Sand pressures are presently over 3500 psi (~ 6200'SS TVD) and still increasing. To drill the well safely, 7" casing will be set at 7532'MD (5824'TVD) (approximately 100' above the "C" Sand). The 13-5/8", 5000 psi, RSRRA BOPE stack equipped with 3-1/2" rams will be reinstalled and 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 2913 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space b~ ¢~is/n ~e ' ~' DATE Samples required Mud log required ~YES [~I~LO I--lYES ~AIO Permit number CONDITIONS OF APPROVAL APPROVED BY Form 10-401 Approval date 06/27/85 Directional Survey required J~Y-ES [] NO Submit in triplicate (TEM) PD/PDI08 ,COMMISSIONER DATE 3une 27, 1985 by order of the Commission SEE COVER LETTER FOR OTHER REQUIREMENTS IAPl number ~0-~o ~ - 'Z, oo ~/- PERHIT TO DRILL 2A-15 (cont'd) including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 2A-15 will be 60' away from 2A-14 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 6633'MD, approximately IO00'MD above the top of the Kuparuk Sands. The 5" liner will be cemented from TD through the liner lap. After WOC, the liner will be cleaned out and the lap tested to 3000 psi. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well may be fracture stimulated. ........ r'T. ...... i~'R'Oo ALASKA HORIZONTAL PROJECT iONi .... SCALE I IN - 1000 FEET ' I EASTHAN WHIPSTOCK, [NC, 1 000 ..... 1000 lO00 I WEST-EAST i 2000 SURFACE LOCATION, 1327' FSL,. 227' FVL I SEC, 13. TI1N. RSE 3000 TARGET LOCATION, ' .. 1320' FNL, 1320' FEL SEC. 24, TI1N. RgE S 54 DEG 40 HI N E 4576' (TO TARGET) i , ":- ~EAST D (LOOOINO PT). TAROET CENTER, TVD'$996 ,. TtlD'???2 ......... DEP'4$?6 J ...... _2~ ...... : .......... ~,. BASE PERMAFROST __ TVD=1485 TMD=1535 DEP=274 ....... -' ' ...... ~ TOP UGNU SNDS. TVD=1640 TMD=1722 DEP=378 -- ........ - ~ EOC TVD-1829 T~D~10~0 DEP~538 "~ -: ...... ' - ~ TOP. ~ SAK- SNDS TvD=2240 T,D=2542 DEP-93Z ....... ~ . ~ _: _~ _ : . '2 :TVD=2600-T~=3043 DEP=1285 . .~ -c _ : 9 5/8' 'CSO PT " ' .~'~--~ ..... ~.3000 - ' TVD=2800 TMD=3~22 DEP=1479 ................ ~ AVERAGE :ANGLE ...... 44-.DEO ..... 5 MI N ......... K-5 TVD=4475 T.D=S654 DEP=31.02.~_ 5000 ...... ~ ...... 7' CSO PT TVD=S824',T~-7533 DEP-4410 J//A/¢ ' : _ ~-~':' - ~ ":)-~O00.'-TOP UPPR SNDS :TVD=5896 TMD=7633 DE "'~-5 _. . -. 'TOF~ [OWR-- SNDS .... :TVD= 5963--T~=TZ26--DEP= 4544 ...... ,~. -. ........ TAROET CNTR -TVD=5996 -T~=FFF2 DEP=4576 · ......... ~ ....... r_ . BASE!KUP SNDS~ TVD'6096 THD=T912 DEP=4675 , : ' ~ TD-~4LOO -PT) ..... TVD=624~O-~-81 t 2--DEP=481 2 ................ --;'~ , - . 0 . 1000 -. ' 2000 ' 3000 4000 5000 ~ .......... ................. ~ .............. - ....VERTICAL-SECTION : ': ;. .1_700 ~ 1600~ __. ........................................... . _ . 700 800 ! 1 .............. ' - 1 623 . 249! 24t2 _ . ................... 1778 ........ 1~0- - - 1277 . ~ _0---:::: "::-: :::-' '" - :: ......... ~ . _ .: --~ , ..... 1000- 7 . 2503 25,95 2664, 274.0 ' . ..... :2~-5:~ot:_-'_:: :_! :L - ' ' i - _ . 2789 ......... :. __'__:,.__ ___ .~'~ ~ ....... :__:_.._: .... : ....... ARCO ALASKA. INC. , --. : ...... : -- _ _]_.~00_.. ........'-:--:--~ .... : .................. PAD 2A, WELL NO, 1 3-1 4-1 5-1 6 PROPO _. ................. ~ . _: ..... -:- _ . 271-~ .......... ~.. KUPARUK'.'FIELD_, "NORTH'-SLOPE, 'ALASKA _ . : ..... : :-i-4i~--- ....... ~. . _,_~' ..... ~ - EASTMAN' WHIPSTOCK, INC, ....... :- ~ ' : ......... ' ~ -'~ ..... 127'7; - ........... ~ ........... 2~4~ _ . . - NOTEs WELL PATHS EXTEND BEYOND _1_200_, ......................... THIS VIEWING WINDOW ................. ............... - - - 1 455 . $~r't',~ce D~ver'*.er $.vstem · i o .- . Me i nten~nce & Dmer~tt mn ' .. -.. Upton init~i ~ns~ll~ttmn clmse enn~lor preventer Cle~e ennular.preven:er an~ ~1~ ~r :brauch ~ve~er l~ne~ eve~ ~2 ~ur~. Close annular preventer in ~e event ~at ~es mr flu~ everr~e an~ ~lm~e bell v~lve ~ u~n~ ~i~e~er net s~t ~n-~11 un~r en~ circ~nmes. l&" ¢on~uctor 7 J 6 ~LL ai::P ST,MX ~ ~ 1,4:~FI:IJ) FLLLY ~ ..~_AT TEST PLLI(; IN HD.LJ-E~ ~ UP-TI3 ~5D PS2 AN::)I.O_D F~ ID 1,4:[N. ~N- ~ ~ TO ~ I~I -A.ND t,CLD L].N~ YA.V'f~ D.,.I::EE: TO:> PIPE ~ AND t4~ VALVI~ 1:~ KZLL AND D-E3~ ~ TO-Z SD PS] .AND ~ PSi: kS ]'N D:~ TOP P]:~ ~ and ~CS~ l~r'r~ ¢2.{3S~2 Ed.]ND ~ 4N:) 'TF.~T TO 250 F"SL FLED. '-SET ALL VALVES IN i:~I1~ PI~ITZ(3~ PIP[ ~ VN..V~.., ,~D 21~;Ii:3~ ~ TD ~_'JC~__. PSI. CHECK LIST FOR(NEW WELL-PERMITS Company (1) Fee /-~ 3~"~'~ 'l.:'Is the permit fee attached ........ ; ................ ; .............. .~ (2) Loc' '~-- ~-L~i~'-2. Is well.to be located in a defined pool ...~ ......................... (~ thru '8) 3. Is well located proper distance from property line ................. i-~ 4. Is well located proper distance from other wells ........... i~i~i~i~ii~~~~~i/~ . 5. Is sufficient undedicated acreage available in this pool ... ~ 6. Is well to be deviated and is wellbore plat included ....... '. 7. Is operator the 'only affected party ........................ __ 8. Can permit be approved before ten-day wait ........ ~ .................. ~ (3) Admin ~, ~ -1,~-~ f 9. - t 12) 10. (10 and 12) 12. (4) Cas~ ~$-~$*FJ' (13 thru 21) (22 thru 26) Does operator have a bond in force ........ ' ...... ~ Is a conservation order needed ....... i~i'ii'''i'~iii ..... - ~______~ Is the lease number appropriate .... [i 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in' surface and intermediate or production strings ... Will. cement cover all known productive~ horizons ............. , ....... Will surface casing protect fresh water zones ..................... .. Will all casing give adequate safety in collapse,~tension and burst.. Is this well to be kicked off from an 'existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ...... , ..................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to~~ ~ .. Does the choke manifold comply w/AP1 RP-53 (Feb.78) ......... ~J~'~.~. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ Additional Remarks: (6) Add :~.~M. ~ °~ '~$'' Geology: Engineering: HWK ~ LCS ~_~BEW WVA~ MTM~ HJH rev: 03/13/85 6.011 INITIAL OEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under AppENDIX. .. No special'effort has been made to chronologically organize this category of information. PROCB$S i 68 I 68 0o00o0000000o0 68 0o000000000000 I 68 000oo000000000 I 68 O00OOnO00OO000 1 68 00000000000000 1 ~8000nOO00000OO0 t 6B OnO00~O0000000 1. 68 O000000OO00000 I 68 OOOO(,)O00000OO0 1 ~8 gO000000000000 I 68 OOOOOnOOOOOOOn i 68 00000000000000 t 68 OnOOO000000ooo n ,') 33 ¢:~ '! 0 0 0 ~. ? 277 T L, rJ 2 ..'5.- b ~!, 90 t) 0 F' C N I..~ ! ."~ ,4, ~ '7 r~, 9 T b D 116.6875 ?,,. 8730 77.?... 5000 2.4 ...~ 73 16.6875 .?. 8't30 t.6230 97.8750 ~.9785 760,0000 9.0'781 75,8125 2.5508 1190.0000 3.7852 lu6.1250 2.7?49 43.46~a !.8175 23.7500 30?7 3.4!09 93~.3750 ~57.1250 3.8'111 36n.n:,)OU I 68 O00nOOOnOOOnO0 I !:.., ~ 2,54 !. 0 CALI 6,1172 ~,~A 3,1289 3,6289 6.2734 3,3789 !b~,l 9 1250 CALi. 6!1992 RNRA 2 71~9 CALl 6i2305 ~N~A ~ 97~7 I[,~' 50 I562 ~AY,I 6:347'1 RI..t~A ~,9980 TL~ 1 9082 CA~i 6~3203 R4RA 3,6563 T.b'~ 3,4902 CAI.,i 6.5352 Ib~' 2nO0,O000 CA[,I 6.2383 T'b~ 2,6445 C~[,,,I 6,1250 ~NRA ,3,I,,289
