The URL can be used to link to this page

Home My WebLink About186-004Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#12AͲ04 50Ͳ103Ͳ20026Ͳ00 909593518 Kuparuk River Plug Setting Record FieldͲFinal 29ͲSepͲ24 0 122AͲ05 50Ͳ103Ͳ20030Ͳ00 909524907 Kuparuk River Plug Setting Record FieldͲFinal30ͲAugͲ24 0 132AͲ11 50Ͳ103Ͳ20057Ͳ00 909594128 Kuparuk River Multi Finger CaliperField & Processed 4ͲOctͲ24 0 142AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Multi Finger CaliperField & Processed 22ͲAugͲ24 0 152AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Packer Setting Record FieldͲFinal 24ͲAugͲ24 0 162GͲ10 50Ͳ029Ͳ21140Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 23ͲAugͲ24 0 172MͲ07 50Ͳ103Ͳ20178Ͳ00 ALSL765Ͳ008 Kuparuk River Multi Finger CaliperField & Processed 15ͲSepͲ24 0 182NͲ329 50Ͳ103Ͳ20257Ͳ00 909593520 Kuparuk River Packer Setting Record FieldͲFinal 20ͲSepͲ24 0 192ZͲ10 50Ͳ029Ͳ21378Ͳ00 909593519 Kuparuk River Multi Finger CaliperField & Processed 25ͲSepͲ24 0 110 3IͲ09 50Ͳ029Ͳ21561Ͳ00 909619414 Kuparuk River Leak Detect Log FieldͲFinal 5ͲOctͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39689T39690T39691T39692T39692T39693T39694T39695T39696184-053184-067186-003186-004184-106192-080198-067185-137186-055T3969710/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:49:24 -08'00'2AͲ1250Ͳ103Ͳ20058Ͳ00909524545KuparukRiverMultiFingerCaliperField&Processed22ͲAugͲ240152AͲ1250Ͳ103Ͳ20058Ͳ00909524545KuparukRiverPackerSettingRecordFieldͲFinal24ͲAugͲ2401T39692T39692186 003186-004184 106 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7125'feet None feet true vertical 6168' feet 6941' feet Effective Depth measured 6979'feet 6154', 6315', 6564', 6584', 6806' feet true vertical 6058'feet 5418', 5543', 5739', 5754', 5926' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-3/8" N-80/ L-80 6822' MD 5938' TVD Packers and SSSV (type, measured and true vertical depth) 6154' MD 6315' MD 6564' MD 6584' MD 6806' MD N/A 5418' TVVD 5543' TVD 5739' TVD 5754' TVD 5926' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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 Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2860' 2794' Burst Collapse Production Liner 1918' 4715' 680' Casing 1946' 5816' 5" 1948' 6663' 7115' 6161' 2827' 106'Conductor Surface Prod w/Tieback 16" 9-5/8" 76' measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-004 50-103-200580-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025570 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2A-12 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 218 Gas-Mcf MD 1268 Size 106' 635 1160109 43 1842900 195 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 32 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Packer Packer: Baker FHL Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker Perm Packer SSSV: None Jaime Bronga jaime.bronga@conocophillips.com (907) 265-1053Senior Well Integrity Engineer 6734-6787', 6820-6830', 6837-6864' 5871-5912', 5937-5944', 5950-5970' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov N/A By Grace Christianson at 4:13 pm, Sep 18, 2024 DTTMSTART JOBTYP SUMMARYOPS 8/22/2024 OPTIMIZE WELL LOGGED CALIPER FROM 6,820' RKB TO SURFACE, DRIFTED W/ 20' x 1.875" DOWN TO XO @ 6,393' RKB, BRUSHED W/ 1.60" GUAGE RING, 3- 1/2" BRUSH DOWN TO XO @ 6,393' RKB, DRIFTED W/ 20' x 1.81" OD TTS AND BRUSHED DOWN TO 6,600' RKB. READY FOR RELAY/E- LINE. 8/23/2024 OPTIMIZE WELL RAN 1.81" LOWER PACKER UNABLE TO PASS PACKER @ 6312' RKB, WLEG SLIGHTLY DAMAGED FROM ATTEMPTING TO WORK THROUGH, CLEAN DRIFT W/ 1.875" STEM 2-3/8" BRUSH & 1.74" GAUGE RING TO 6600' RMD. IN PROGRESS 8/24/2024 OPTIMIZE WELL SET 1.81" LOWER P2P @ 6586' RKB (ME) (OAL 3.73' / SN: CPP23801), SET UPPER 1.81" P2P SPACER & ANCHOR LATCH @ 6566' RKB (ME) (OAL 20.96' / SN: CPP23802 / CPAL238002), MIT TBG 2000 PSI W/ 1.81 TTS TEST TOOL IN UPPER PACKER @ 6566' RKB (PASS). JOB COMPLETE. 9/6/2024 ACQUIRE DATA (AC EVAL) TIFL (PASS) 2A-12 Patch Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 6,979.0 2A-12 7/9/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch 2A-12 8/24/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 4/19/2010 ninam NOTE: *** SURFACE ANNULUS CEMENTED FROM 1948' TO SURFACE ***4/8/2010 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 30.0 106.0 106.0 62.50 H-40 SURFACE 9 5/8 8.92 33.0 2,859.9 2,793.9 36.00 J-55 Buttress PRODUCTION w/7" Tieback 7 6.28 30.1 1,948.0 1,946.5 26.00 L-80 TC2 PRODUCTION Original 7 6.28 1,947.3 6,662.8 5,816.1 26.00 J-55 BTC LINER 5 4.28 6,434.7 7,115.1 6,161.3 18.00 L-80 LTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.0 Set Depth 6,279.0 Set Depth 5,515.2 String Max No 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE 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) 31.0 31.0 0.09 HANGER 6.125 TUBING HANGER - FMC GEN III TUBING HEAD & CASING PACKOFF REPLACED 2.992 491.0 491.0 0.08 NIPPLE 4.520 CAMCO DS NIPPLE 2.875 2,617.3 2,580.3 25.28 GAS LIFT 5.390 CAMCO KBMG CAMCO KBMG 2.920 3,915.1 3,645.8 36.88 GAS LIFT 5.390 CAMCO KBMG CAMCO KBMG 2.920 4,925.3 4,454.3 36.43 GAS LIFT 5.390 CAMCO KBMG CAMCO KBMG 2.920 5,682.4 5,051.6 39.42 GAS LIFT 5.390 CAMCO KBMG CAMCO KBMG 2.920 6,091.1 5,369.2 39.22 GAS LIFT 5.390 CAMCO KBMG CAMCO KBMG 2.920 6,146.2 5,412.0 39.12 SEAL ASSY 4.490 LOCATOR SEAL ASSEMBLY w/ 20.84' STROKE w/ 7' SPACE OUT 2.990 6,153.6 5,417.6 39.10 PACKER 5.960 BAKER FHL PACKER w/ 80-40 PBR 2.940 6,225.1 5,473.2 38.95 NIPPLE 4.520 CAMCO DS NIPPLE 2.812 6,270.6 5,508.6 38.82 OVERSHOT 4.000 BOT POORBOY OVERSHOT 3.620 Top (ftKB) 6,277.3 Set Depth 6,822.1 Set Depth 5,938.4 String Max No 2 3/8 Tubing Description TUBING Original 3.5x2.875x2.375 Wt (lb/ft) 4.70 Grade N-80 Top Connection EUE8rdABM OD ID (in) 2.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,301.3 5,532.6 38.72 PBR 3.500 BAKER PBR 3.000 6,315.1 5,543.4 38.65 PACKER 6.125 BAKER FHL PACKER 3.000 6,353.8 5,573.6 38.43 PRODUCTION 5.390 CAMCO KBUG 2.920 6,389.8 5,601.9 38.23 NIPPLE 4.484 AVA BPL PORTED NIPPLE 2.750 6,392.7 5,604.2 38.21 XO Reducing 3.500 XO 3.5 x 2.875 2.875 6,393.2 5,604.6 38.21 XO Reducing 2.875 XO 2.875 x 2.375 2.375 6,707.7 5,850.8 39.49 BLAST RING 2.375 BLAST RINGS (2)1.901 6,804.1 5,924.7 40.38 SEAL ASSY 3.000 BAKER LOCATOR SEAL ASSEMBLY 3.250 6,805.9 5,926.1 40.39 PACKER 4.156 BAKER PERMANENT PACKER 3.250 6,818.3 5,935.6 40.42 NIPPLE 3.000 CAMCO 'D' NIPPLE 1.812 6,821.4 5,937.9 40.43 SOS 2.875 CAMCO SHEAROUT SUB - ELMD @6818' ON SWS PERF JOB 9/5/2005 1.995 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,389.8 5,601.9 38.23 SLEEVE - CLOSED AVA 2.75" BPI Sleeve 7/15/2024 2.313 6,563.6 5,738.6 38.33 PACKER - PATCH - UPR 2-3/8" UPR P2P PKR MID- ELEMENT AT 6566' RKB W/ SPACER PIPE AND ANCHOR LATCH, OAL 20.07' TTS P2P CPP2 3802 8/24/2024 1.000 6,566.9 5,741.2 38.35 SPACER PIPE SPACER PIPE 8/24/2024 0.950 6,577.0 5,749.1 38.40 LEAK TBG LEAK IDENTIFIED AT 6577' RKB VIA LDL 7/21/2024 1.995 6,583.6 5,754.3 38.44 PACKER - PATCH - LWR 2-3/8" LWR P2P PKR MID- ELMENT AT 6586' RKB, OAL 3.73' TTS P2P CPP2 3801 8/24/2024 1.000 6,941.0 6,028.8 40.54 FISH 1 1/2" GLV Lost in Hole 3/30/1989 0.000 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) 2,617.3 2,580.3 25.28 1 GAS LIFT GLV BK-5 1 1,266.0 2/27/2011 0.156 3,915.1 3,645.8 36.88 2 GAS LIFT GLV BK-5 1 1,305.0 2/27/2011 0.188 2A-12, 9/17/2024 1:54:22 PM Vertical schematic (actual) LINER; 6,434.7-7,115.1 FISH; 6,941.0 IPERF; 6,837.0-6,864.0 APERF; 6,820.0-6,830.0 PACKER; 6,805.9 IPERF; 6,734.0-6,787.0 PRODUCTION Original; 1,948.0 -6,662.8 PACKER - PATCH - LWR; 6,583.6 LEAK; 6,577.0 SPACER PIPE; 6,566.9 PACKER - PATCH - UPR; 6,563.6 SLEEVE - CLOSED; 6,389.8 PRODUCTION; 6,353.8 PACKER; 6,315.1 PACKER; 6,153.5 GAS LIFT; 6,091.1 GAS LIFT; 5,682.4 GAS LIFT; 4,925.3 GAS LIFT; 3,915.1 SURFACE; 33.0-2,859.9 GAS LIFT; 2,617.3 PRODUCTION w/7" Tieback; 30.1-1,948.0 7'' Tieback (plug); 1,935.0 ftKB 7'' Tieback; 30.1 ftKB NIPPLE; 491.0 CONDUCTOR; 30.0-106.0 KUP PROD KB-Grd (ft) 31.01 RR Date 1/19/1986 Other Elev 2A-12 ... TD Act Btm (ftKB) 7,135.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005800 Wellbore Status PROD Max Angle & MD Incl (°) 40.63 MD (ftKB) 6,900.00 WELLNAME WELLBORE Annotation Last WO: End Date 4/7/2010 H2S (ppm) 40 Date 12/24/2013 Comment SSSV: LOCKED OUT 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) 4,925.3 4,454.3 36.43 3 GAS LIFT GLV BK-5 1 1,301.0 2/27/2011 0.188 5,682.4 5,051.6 39.42 4 GAS LIFT OV BK 1 0.0 4/8/2022 0.250 6,091.1 5,369.2 39.22 5 GAS LIFT DMY BK-5 1 0.0 4/9/2010 0.000 6,353.8 5,573.6 38.43 6 PROD DMY BK 1 0.0 6/13/1999 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) 7,015.2 6,085.2 40.40 LANDING COLLAR 5.000 4.276 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,734.0 6,787.0 5,871.1 5,911.7 C-4, 2A-12 3/12/1986 12.0 IPERF 69 deg. phasing; SOS 3 3/8" Csg Gun 6,820.0 6,830.0 5,936.8 5,944.4 A-4, 2A-12 9/3/2005 6.0 APERF 1-11/16" EJ, 0 deg phase 6,837.0 6,864.0 5,949.8 5,970.3 A-3, 2A-12 3/12/1986 6.0 IPERF 60 deg. phasing; SOS 3 3/8" Csg Gun Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) Scale Inhibitor 12/31/1995 0.0 0.00 0.00 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 30.1 1,948.0 30.1 1,946.5 7'' Tieback RU Schlumberger Cement Equip. Pressure test lines to 3900 psi. Bled off. Pressure up to 3500 psi and opened 'ES' cementer. Est. circulation w/seawater 325 psi @ 5.0 BPM. SD, Batch mixed 15.7 ppg Arctic Set-1 cement, start downhole @ 2.2 BPM w/122psi. With 20 bbls away, increase rate to 3.0 BPM w/150 psi. At 50 bbls away 140 psi 2.8 BPM. 75 bbls away 142 psi w/2.4 BPM. End cement w/ total of 91.6 bbls pumped. Dropped closing plug. Start SW displacement @ 5.0 BPM w/105 psi. Catch up with cement column with 22 bbls, 375 psi 4.9 BPM. After 39 bbls away 630 psi 4.9 BPM slowed down to 3.0 BPM @ 490 psi returns still all seawater. 58 bbls displacement away 3.0 BPM w/697 psi start to get interface returns, PH coming up. 70 bbls displacement away 714 psi w/2 BPM still contamenated cement returns. Bumped plug w/75.2 bbls SW. press came up from 750 psi to 1000 psi. Slowly brought pressure up to 2000 psi ,closed 'ES' tool. Held pressure no bleedoff. Bled pressure off casing verified no flowback. Plug down and closed @ 12:40 hrs. Returns still contamenated cement weighing 9.1 ppg. 4/3/2010 2A-12, 9/17/2024 1:54:24 PM Vertical schematic (actual) LINER; 6,434.7-7,115.1 FISH; 6,941.0 IPERF; 6,837.0-6,864.0 APERF; 6,820.0-6,830.0 PACKER; 6,805.9 IPERF; 6,734.0-6,787.0 PRODUCTION Original; 1,948.0 -6,662.8 PACKER - PATCH - LWR; 6,583.6 LEAK; 6,577.0 SPACER PIPE; 6,566.9 PACKER - PATCH - UPR; 6,563.6 SLEEVE - CLOSED; 6,389.8 PRODUCTION; 6,353.8 PACKER; 6,315.1 PACKER; 6,153.5 GAS LIFT; 6,091.1 GAS LIFT; 5,682.4 GAS LIFT; 4,925.3 GAS LIFT; 3,915.1 SURFACE; 33.0-2,859.9 GAS LIFT; 2,617.3 PRODUCTION w/7" Tieback; 30.1-1,948.0 7'' Tieback (plug); 1,935.0 ftKB 7'' Tieback; 30.1 ftKB NIPPLE; 491.0 CONDUCTOR; 30.0-106.0 KUP PROD 2A-12 ... WELLNAME WELLBORE ORIGINATED TRANSMITTAL DATE: 7/24/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4943 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4943 2A-12 50103200580000 Leak Detection Log 21-Jul-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 186-004 T39272 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.24 11:27:08 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /2~- ~/ Well HistoryFileldentifier Organization (done) .[~Two-Sided RESCAN TOTAL PAGES: ORGANIZED BY: DIGITAL DATA Color items: [] Diskettes, No. Grayscale items: [] Other, No/Type Poor Quality Originals: X~~~ Other~ t- /~ ("/ NOTES: BEVERLY BREN VINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Ma ps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: IS/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~si PAGES: ~ I (at the time of scanning) SCANNED BY.' BEVERLY BREN VINCEN~MARIA LOWELL RESCANNED BY.' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd WELL L®G 'TItA1~1Sl~ITTAL To® Alaska Oil and Gas Conservation Comm, Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2A-12 Run Date: 7/23/2010 August 4, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-103-20058-00 Production Profile Log 50-103-2005 8-00 t 1 CD Rom 1 Color Log 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: ~!~ ~ ~ ~ OD`'~ ~g~ l ~~~ Signed: ~o>s.,,q, ~ ~-~ '~ STATE OF ALASKA ALASKP~ AND GAS CONSERVATION COMMIS~J REPORT OF SUNDRY WELL OPERATIONS RECEIVED MaY ~ ~ '~mn ~. operations Pertormed: Abandon ~' Alter Casing ~` Repair w ell ~ Rug Perforations ~"' Pull Tubing ~ Perforate New Pool `-"; Stimulate ~ Otghe~r ~"""" , Waiver ("" Tir~l ~~ Change Approved Program Operat. Shutdown -°", Perforate "` Re-enter Suspended W 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory "-" 186-004 3. Address: ~. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-103-20058-00 7. Property Design 'on: 8. Well Name and Numl~r: ADL 25570 2A-12 9. Field/Pool(s): ~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7125 feet Plugs (measured) None true vertical 6169 feet Junk (measured) 6941' Effective Depth measured 7064' feet Packer (measured) 6154', 6315', 6806' true vertical 6122' feet (true vertucal) 5418', 5543', 5927' Casing Length Size MD ND Burst Collapse CONDUCTOR 106 16 106 106' SURFACE 2834 9.625 2860 2794' PRODUCTION 6637 7 6663 5816' LINER 680 5 7115 6161' Perforation depth: Measured depth: 6734'-6787', 6820'-6830', 6837'-6864' True Vertical Depth: 5871'-5912', 5937-5945', 5950'-5970' ,~~ ~;~n~~;~ ,I~,,I ~~ `'~' ~~'~ Tubing (size, grade, MD, and TVD) 3.5", L-80, 6279' MD 5515' TVD and 2.375", N-80, 6822' MD 5939' TVD Packers & SSSV (type, MD, and TVD) 2 PACKERS - 2 BAKER'FHL' PACKER @ 6154' MD / 5418' and 6315 MD / 5543 TVD; PACKER -BAKER 'DB' PACKER @ 6806 MD and 5926 TVD CAMCO 'DS' nipple @ 491 MD and 491 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 SI Subsequent to operation 2163 2265 1876 -- 235 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 XXXX_ 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 NiA if C.o. Exempt: 310-031 Contact J~ Ennis 265-1544 Printed Name nIS Title Wells Engineer Signature Phone: 265-1544 Date ~~ t a O l o Form 10 '~~4 Revised 7/2009 RBDMS MAY 12 ZQ'~F 'S~ ~' ~ ~ ~ ~D Subm~it~Ori final Only ,l'~ iGr ~ORCKO~'ll~fl~'J5 1 ~5.::t, II Y:,. HANGER. 31 colvDUCroR. 30-106 NIPPLE. 491 PROOUCnoN wm rebach. 30-1,908 GAS LIFT, 2,61T SURFACE, 33-2,860 GAS LIFT, 3,915 GAS LIFT, 0.525 GAS LIFT 5.682 GAS LIFT. 6.091 SEAL ASSV, 6.'146 PACKER. 6,150 NIPPLE, 6.225- OVERSHOT 6 271 PBR. 6,301 PACKER, 6,315 - PROOUCnoN, 6.354 NIPPLE. 6,390 SLEEVE~C, 6.390 PROOUCnoN original, -- 1,968b-663 (PERF. _ 6,734-6 ]87 SEAL ASSY, _._ ___ 6,800 PACKER, 6.806- ---- NIPPLE. 6,818 -- sos, s.ezl APERF, 6.820~6.fl30 (PERF, _ 6.837-6.864 F 1511. fi W 1 • KU P • 2A-12 Max Angle 8 MD TD ~ Well Attributes _ 'Welltwre APUU WI Field Name Well Status Inc! (°) MD (HKB) (Act Btm (HKB) SU10s20f15800 KUPAHUK RIVER UNIT PROD 40.63 ~ 6,900.00 ~ 7,125 0 ''Comment M25 (ppm) Date Annotation End Date KB-Grd (H) Rig Release Data SSSV'. LOCKED OU f 225 7/10/2009 Last WO' I 4/7/2010 31.01 I 1!19/1986 Annotation Deplh HKB End Date Annotation Last Mod... Entl Dafe ) 4/12/2010 (Rev Reason WORKOVER Imosbor_ ~ 4/19!2010 Last Tag' SLM 6.848.0 i Casin~c SStrings 'Casing Description String 0... 1String ID ._ Top (HKB) Sel Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd (CONDUCTOR 16 15.060 30.0 106.0 106.0 62.50 H-40 (,Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd ~ISURFACE 9518 8.765 33.0 2,859.9 2,793.7 36.00 J-55 Butlress (Casing Description :String 0... String ID ... Top (HKB) Set Depth (f... Bat Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION w(7" I 7 6.276 30.1 1,948.0 1,946.4 26.00 L-80 TC2 Tieback Casing Descdption String 0... String ID ... Top (kKB) Set Depth (1... Set Depth (ND) ... String Wt. String ... String Top Thrd PRODUCTION 7 6.151 1,947.3 6,662.8 5,816.0 26.00 J-55 BTC Original Casing Description String 0... String ID ... Top (HKB) Set Oepth (t... Sat Depth (ND) ... String Wt... String ... String Top Thrd LINER 5 4.276 6.434.7 7,115.1 6,161.3 18.00 L-80 LTC Tubing Strin gs _ . Tubing Description String 0... String ID ... Top (HKB) Bet Depth (t... Set Depth (ND) ... String Wt... String _. String Top Thrd (TUBING I 31/2 2992 310 6,279.0. 5,515.2 9.30 L-80 Srtl EUE_~ ( Completion Details _ _ _ _ ' Top Depth I (ND) ' Top Inc! Nomi... Top (HKBI'~ (ftK8) (°) ' Item Description Comment ID (in) 31.0' 31 0~ 0.37 HANGER TUBING HANGER 2.992 491.0 491.0. 0.08 NIPPLE 2.875" CAMCO "DS" Nipple 2.875 6,146.2 5,412 0 ~ 39.72 SEAL ASSY Seal Assembly Locator w/20.84' stroke w/T Space Out. 2.990 6,153.6 5,417.7I Ijj 39.10 PACKER BakerFHL Packer w/80-40 PBR 2.940 --- 6,225.7 5,473.5 39.15 NIPPLE 2.812" Camco "DS" Nipple 2.812 6,270.61 5,508.71414 38.89 OVERSHOT BOT Poorboy Overshot 3.620 (Tubing Des cnption (String O ... String lD ._ Top (HKB) Bet Depth (f...Set Depth(ND).. String Wt... Str g...String Top Thrd ' TUBING O r ginal ~ 2 3/8 1.901 _I 6,277.3 I 6,822.1 S 938.7 4 60 ~ N 80 ~ EUESrdABMOD - I Comple tion Details Top Depth (ND) Top Inc! Nomi... ~TOp (HKB) (ftK8) (°) Item Description i Comment ID (in) 6,301.3 5,532.6 38.72 PBR BAKER PBR 3.000 6,375.1 5,543.4 38.65 PACKER BAKER FHL PACKER 3.000 6,389.8 5,601.9 38.23 NIPPLE AVA BPL PORTED NIPPLE ~ 2.750 6,392] 5,604.2 38.21 (X0 3.5x2.875 2.875 6,393.2 5,604.6 3821 X0 2.375 '. 2.875x2.375 6,707.7 5,850.8 39.49 16LAST RING 1.901 6,804.1 5,925.1 40.85 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.250 6,805.9 5,926.5 40.85 PACKER BAKER PERMANENT PACKER 3.250 6,818.3 5,935.8 40.82 NIPPLE CAMCO'D' NIPPLE 1.813 6,821.1 5,937.9 40.81 XO 2.875 2.375x2.875 6,827.4 5,93821 40.81 SOS CAMCO SHEAROUT SUB - ELMD @6818' ON SWS PERF JOB 1.995 ~ Other I I I ~ n Hole Wirelin I e retrievable9 s/zoos plugs, valves, pumps, fish, etc.} --- _ Top Depth - i ~! (TVD) Top Inc! I ~ Top (HKB) (HKB) (°) Descdption !1 Comment Run Date ID (in) I 6.390 5.6020 38.23I SLEEVE-C JAVA 2.75"BPC SLEEVE 4/72/2010 2.313 6.941 6028.8 4454 FISH ~;,71/2"GLV Lost in Hole 3/3011989 Perforations ~ Slots __._-- -. Shot Top (TVD) Btm (TVD) Oens Top (HKB)'.. Btm (HKB( (HK8) (ftK8) Zone Date lsh... Type Commerrt -_-- 6,734 6,787 5,871.0 5.971.7 C-4, 2A-12 3/12/1986 12.0 (PERF 69 deg. phasing; SOS 3 318" Csg Gun 6,820 6,830 5,937.1 5,944.6 A-0, 2A-12 913!2005 6.OIAPERF 1-11/76" EJ, 0 deg phase 5,949.9 5 970.3 A-3, 2A-12 3112/1986 6.011PERF 60 deg. phasing; SOS 3 3J8" Csg 6,837 6864, : - -. I 1 __.. __ Gun_ __ Notes: General 8 Safety End Date Annotation __ 14/19/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details __ ----- Top Depth Top Port (TVDI Inc! j OD Valve Lateh Size TRO Run Btn Top (HKeI', (HKB) (°) Make Model linl Serv Type Type (in) (psi) Run Date Com... 1 2,617.3 2,579.6 25.72 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.156 1,266.0 4/10/2010 2 3,915.1 3645.8 36.58 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,305.0 4/1012070 3 4,925.31 4,454.3 36.43 CAMCOKBMG 1 GAS LIFT GLV 8K-5 0.188 1,301.0 4/70/2010 4 5,6824 5057.6 39.46 CAMCO,KBMG 1 GAS LIFT OV KB-5 0.250; 0.0 4/9/2010 5 6,091.1 ~1 5,369.2 39.22 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0 0 4/9/2010 6 6,353.81 , 5,573.7 38.43 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 6/13/1999 LINER, 6.435-7.115 \ TD, 7.125 - 2A-12 Well Events Summary DATE SUMMARY 3/23/10 PERFORMED TUBING CUT WIT .5" RADIAL CUTTING TORCH @ DEPTH 6279'. TOOL BECAME STUCK AFTER CUT BUT JARRED FREE BY EVANS JARS. ONCE OUT OF HOLE, OBESERVE EXPENDIBLE ANCHOR ARMS BENT; APPEARS THAT ELECTROMAGNETIC ANCHOR SYSTEM ARMS DID NOT RELEASE AFTER CUT. 3/24/10 ON STANDBY TO RUN PDS 40-ARM CALIPER AT THIS TIME. 3/25/10 PERFORMED CALIPER LOG WITH PDS 40 ARM CALIPER FROM WRP TO SURFACE. PERFORMED GYRODATA GYRO SURVEY FROM TUBING CUT TO SURFACE. RCBL IN PROGRESS. ~o:~w 3!26/10 PERFORMED RADIAL CEMENT BOND LOG FROM 3220' TO SURFACE. FOUND FREE JOINT r AT 1942'. SHOT 240 GR/FT OF STRING SHOT OVER COLLAR AT 1942' 3/28/10 STANDBY FOR NORDIC THREE RIG. DAILY COSTS CAPTURED IN DAILY DRILLING REPORT. 3/29/10 PERFORMED CALIPER SURVERY FROM SURFACE TO 2050'. PERFORMED GYRO SURVEY ~P FROM SURFACE TO 2000'. COST CAPTURED IN DAILY DRILLING REPORT. 4/2/10 ON NORDIC 3: LOGGED CCL & 40 ARM CALIPER f/ 1935' SLM TO SURFACE; GOOD DATA. ('~~. 4/9/10 PULL BALL/ROD FROM 6225' RKB, PULL SOV AND REPLACE W/ DMY VLV @ 6091' RKB, PULL DMY VLVS FROM 5682', 4925', 3915' RKB, SET OV @ 5682' RKB. IN PROGRESS. 4/10/10 PULL DMY VLV FROM 2617' RKB, SET GLV @ 4925', 3915', 2617' RKB PER PROCEDURE, PULL ~o l~~''°~. RHC FROM 6225' RKB, ATTEMPT TO PULL CATCHER ON WRP @ 6335' RKB. IN PROGRESS. 1 4/11/10 PT TBG TO CONFIRM GLV'S SET. BAIL RUBBER/ MUD OFF CATCHER ON TOP OF WRP @ 6335' RKB, PULL CATCHER FROM SAME, PULL WRP @ 6335' RKB. IN PROGRESS. 4/12/10 PULL CA-2 PLUG FROM 6818' RKB, TAG @ 6848' SLM SAMPLE OBTAINED, REPLACE BPI W/ BPC @ 6390' RKB. COMPLETE ~onocoPhillips Time Log & Summary lNeUview 4Yeb Reporting Report Well Name: 2A-12 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/22/2010 5:00:00 AM Rig Release: 4/7/2010 9:30:00 PM TLme Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 3/21/2010 2a hr summary Pulled off of Well 2A-16. Lost hydraulics on rig moving system. 20:30 00:00 3.50 COMPZ MOVE MOB T Rig has been moved off of Well. However, unable to continue rig move to the next well due to problems with ri movin s stem. 3/22/2010 MIRU. Circulate Well with 9.6 Ib/gal Brine. Monitor Well static. Install BPV. Nipple Down Tree. Nipple up BOP Stack. 00:00 04:00 4.00 COMPZ MOVE RURD T Make repairs to moving system. Move Ri from 2A-16 to Well 2A-12. 04:00 05:00 1.00 COMPZ MOVE MOB P Move rig f/ 2A-16 to 2A-12 and spot rig over well. Accept Nordic Rig 3 @ 05:00 hrs on 3-22-10 05:00 09:00 4.00 COMPZ MOVE RURD P Berm and spot rig aux. equipment. Lay hardline to kill tank and load pits with 9.6 KWF. 09:00 10:00 1.00 COMPZ WELCTL MPSP P Lubricate out BPV and la down lubricator 10:00 10:30 0.50 COMPZ WELCTL SFTY P PJSM with rig crew on killing well 10:30 19:00 8.50 COMPZ WELCTL CIRC P MU kill lines in the cellar to tree - Blow down line to kill tank. PT kill lines @ 250/3,500 psig. Pump down TBG @ 3 bpm @ 140 psig ICP w/ 80 psig Back pressure @ choke. Pumped 258 bbls by pump strokes and recovered 250 bblsin kill tank - FCP 210 psig and 150 psig choke back pressure with 9.5 ppg heavy returning. Circulate to rig pits w/ small amount of gas break out circulating @ 5 bpm @ 520 psi for 100 bbls. Let stand for 1.5 hrs allowing fluid to swap as signs show circulating point @ 2,686'. Pressure built up to 40 psig and fell back to 10 psig. Open up well and begin to circulate @ 5 bpm -took 8.5 bbls to fill hole and get returns, circulate @ 5 bpm @ 520 psig for 100 bbls. Monitor well for 1 hr with no pressure build. However, still slightly out of balance. Circulated 100 bbls. Shut down um s. Monitor Well static. 19:00 19:30 0.50 COMPZ WELCTL MPSP P Set Blanking Plug. Page 1 of 19 i ' Time Lo s ...Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 19:30 21:30 2.00 COMPZ WELCTL NUND P Nipple down Production Tree. Inspect Tubing Hanger threads. Good. Install Blanking Plug. Check Lock-down Screws. 21:30 00:00 2.50 COMPZ WELCTL NUND P Ni le u BOPE. 3/23/2010 Perform initial BOPE test. Witness of test waived by AOGCC Jeff Jones. Pull Blanking plug &BPV. Make up landing joint. Attempt to pull tbg free. Repeat attempts pulling to 114K. No success. Circulate a total of 328 BBLS of 9.6 brine. Verify well static. Observed tbg hanger would not reland at 7.5' high. Rig HES E-line crew. Rehead line. Wireline in hole with radial cutter assembl . 00:00 01:00 1.00 COMPZ WELCTL NUND P Nipple up BOPE,completed. 01:00 08:00 7.00 COMPZ WELCTL PRTS P Perform the initial BOPE test per CONOCOPHI LLIPS/AOGCC requirements at 250/3,500 psi. Good. Perform Koomey draw-down test. Good. The State's right to witness the test was waived by J. Jones. 08:00 08:30 0.50 COMPZ WELCTL MPSP P Pull blanking plug and BPV 08:30 10:00 1.50 COMPZ WELCTL OTHR P PU and MU Landing jt -check IA and had pressure, RU to kill tank and bleed off -BOLDS. Tie OA into Kill Tank -let continuous) bleed. 10:00 10:30 0.50 COMPZ WELLPF SFTY P Held PJSM w/ Rig crew on unlanding TBG Han er and ullin to ri floor. 10:30 17:00 6.50 6,301 6,301 COMPZ WELLPF PULL X Unland hanger @ 50k and pull to 150k work between 60k and 150k, put 1/2 round of right hand rotation in string and work pipe between 60k to 150k, put 1 full rotation of right hand torque and work in between 60k and 150k with no luck pulling from PBR @ 6,301'. Begin circulating @ 6 bpm @ 730 pstg. Continue to work pipe from 60k to 150k -with no luck. Attempt to reland hanger - no luck - 7.5' off seat -set slips and break off TD and blow down. 17:00 17:30 0.50 COMPZ FISH SFTY X Held PJSM with rig crew and Eline on RU of eline sheaves. 17:30 19:00 1.50 COMPZ FISH ELNE X RU Eline sheaves in derrick. 19:00 20:30 1.50 COMPZ FISH ELNE X Re-Head wireline. 20:30 23:30 3.00 COMPZ FISH ELNE X Make up and test wireline tools. Make up pump in sub on top of tubin . 23:30 00:00 0.50 COMPZ FISH ELNE X Wireline in hole with radial cutter assembl to 2700' WLM. 3/24/2010 Continue WLIH from 2700' to correlate & position cutter at 6279' WLM. Fire cutter, with no indication at surface of cut. Log to verify cut. All indications on unit -good. WLOH. Lay down assembly. Inspect cutter. CBU @ 4 BPM - 180 PSI. Pull tbg hanger to rig floor. Up weight 85K. Good free movement in tubing string. POOH, lay down 3 1/2" tubing and CL. Recovered 32 SS Bands. Observed bentjoints #8-9, #26, #68, and # 80. Strap and tally all tubing and jewelry.MU 6 1/8" bit & scraper assembly. RIH to tag up at 257'. POOH, drop the bit. RIH with scarper to lightly tag tbg stump at 6266' DPM. REV Circulate @ 5 BPM - 750 PSI. POOH to 4658'. No fluid losses. Page 2 of 19 i • `T"rme Lo s Date From To Dur S. De th E. De th Phase .Code Subcode T Comment 00:00 01:30 1.50 COMPZ FISH ELNE X Continue wireline in hole form 2700'. Correlate & position radial cutter at 6279' WLM. Fire cutter. No indication at surface of cut with 25K overpulf on tbg. Log through cut. Unit indications all ood. 01:30 02:30 1.00 COMPZ FISH ELNE X WLOH with radial cutter assembly. 02:30 02:45 0.25 COMPZ FISH SFTY X Held PJSM with crew &HES reps. Discuss safety & hazard recognition issues. Discuss procedure to remove & ri down wireline cutter assembl . 02:45 03:15 0.50 COMPZ FISH ELNE X Pull tools to surface. Rig down sheaves & line. 03:15 03:30 0.25 6,279 6,279 COMPZ WELLPF PULL P Pull on tubing observing free movement with 85K Up weight. Pull hanger to rig floor. Observed well - static. 03:30 04:00 0.50 6,279 6,279 COMPZ WELLPF RURD P Continue rig down HES wireline crew. RU to circulate & prep to lay down tubin . 04:00 05:00 1.00 6,279 6,279 COMPZ WELLPF CIRC P CBU at 4 bpm @ 180 PSI. No Losses or as at surface. 05:00 16:00 11.00 6,279 0 COMPZ WELLPF PULL P Lay down hanger and landing jt. BDTD. Continue to POOH laying down de completion found jts 8.9. 26, 68, 80 bent. All TBG had no exterior corrosion found on any of the pipe. The cut jt showed signs of possible fill around top of Seal assy. Control line was parted @ jt 15. 32 SS Bands recovered of the 29 reported to be run. Load Scraper BHA in pipe shed for next run. 16:00 17:00 1.00 0 0 COMPZ WELLPF OTHR P Clean and Clear rig floor and change over to DP equipment. Performed NORM inspection on control line as er SWS. 17:00 17:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM on Building BHA #1 w/ Rig crew and Baker Fishing Tool su ervisor. 17:15 19:00 1.75 0 257 COMPZ WELLPF PULD P PU and MU BHA #1 - 7" Scraper assy to 257'. Set down all string , wei ht. 19:00 20:00 1.00 257 0 COMPZ WELLPF TRIP P POOH w/ BHA #1 f/ 257' to Surface. Breakout and lav down bit. Make up oil 'ars. 20:00 22:00 2.00 0 6,266 COMPZ WELLPF TRIP P Trip in hole with BHA #1 to pass through 257' slowly with 2-3K down drag. Pull back through to verify. Continue trip in hole to lightly tag tubing stump at 6266' DPM. UP WEIGHT = 125K, SO WT = 95K. 22:00 23:00 1.00 6,266 6,266 COMPZ WELLPF CIRC P Rig up and reverse circulate well clean at 5 BPM - 750 PSI. No Losses. Page 3 of 99` ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:00 00:00 1.00 6,266 COMPZ WELLPF TRIP P Blow down Top Drive. POOH with BHA #1 to 4658' DPM. 3/25/2010 Continue POOH with BHA #1 from 4658'. Install 7" Shooting nipple. RU HES wireline crew. MU and run casing caliper log to 6345' WLM. Log up at 35 fUmin. MU & WLIH with Gyro assembly. STandby for HES unit swa . MU CBL assembl . WLIH to 3200'. Lo comin u at 35 - 50 fUmin. No losses. 00:00 02:30 2.50 4,658 0 COMPZ WELLPF TRIP P Continue POOH with BHA#1 from 4658' to surface. Inspect scraper and la down BHA. 02:30 03:00 0.50 0 0 COMPZ WELLPF RURD P Clean & Clear rig floor area. Install 7" shootin ni le for wireline run. 03:00 03:30 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM with crew and HES reps. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run tali er to in run. 03:30 05:30 2.00 0 0 COMPZ WELLPF RURD P Spot HES units and rig up sheaves and line for logging runs. Make up tali er to in assembl . 05:30 09:00 3.50 0 0 COMPZ EVALWE PLT P RIH w/ Caliper to 6,345' ELM. Log out of the hole to surface. 09:00 17:00 8.00 0 0 COMPZ EVALWE ELOG P PU and RIH w/ Gyro Tool on E line to 6,266' ELM. Log out of the hole to surface. Observed .5° to 3.6° @ 257' to 262' with ro. 17:00 20:00 3.00 0 0 COMPZ EVALWE OTHR T RD HES. Waiting on large wire E line unit. Unable to get truck & tools on location timely. Decision to run CBL with HES unit on location. 20:00 22:00 2.00 0 0 COMPZ EVALWE OTHR P Rig up unit, sheaves & wire, MAke u CBL to in assembl . 22:00 00:00 2.00 0 0 COMPZ EVALWE ELOG P WLIH logging down to 3200'. Continue logging up from 3200' at 35-50 ft/min. 3/26/2010 Continue with CBL logging run. Verify cement top at 2020'. MU 240 GR stringshot assembly to shoot collar at 1942' WLM. Rig down HES. MU IBP on 3 1/2" DP. TIH to set at 2537'. Test packer to 2500 PSI. POOH lay down setting tool. MU 4 3/4" DC's and RIH to top of IBP. RU & dump 1200 tbs of sand. Wait 1 hr to tag top of sand at 2473'. POOH. MU Baker storm packer with DC's hanging for weioght. Set packer at 63' from rotary table. Test same to 1500 PSI. ND BOP's. ND tubin head. Pre for removal installin Ion threaded bolts. 00:00 02:30 2.50 0 0 COMPZ EVALWE ELOG P WLIH logging down to 3200'. Continue logging up from 3200' at 35-50 ft/min. Verified tip of cement at 2020' W ecision to back off collar at 1942' WLM. 02:30 03:00 0.50 0 0 COMPZ EVALWE ELOG P Breakout & lay down CBL assembly. 03:00 03:15 0.25 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew &HES reps. Discuss safety & hazard recognition issues. Discuss procedure to make up and run 240 grain string shot assembl . 03:15 05:15 2.00 0 0 COMPZ RPEQPI ELOG P Make up 240 grain string shot assembly. WLIH to verify depths and locate collar at 1942' WLM. Fire strin shot, WLOH. 05:15 09:00 3.75 0 2,537 COMPZ RPEQPI MPSP P MU and RIH w/ Baker 3.375" OD IBP to 2,537'. RU to test pump and Set IBP and Release off. Page 4 of 19 l ~ J Time L s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 09:30 0.50 2,537 2,537 COMPZ RPEQPI PRTS P Pressure test IBP @ 2,500 psig for 5 minutes - ood test. 09:30 10:30 1.00 2,537 0 COMPZ RPEQPI TRIP P POOH with DP f/ 2,537' and lay down IBP settin tool. 10:30 12:00 1.50 0 680 COMPZ RPEQPI PULD P PU and RIH w/ 13 - 4 3/4" OD DC's and RIH w/ 9 DC's f/derrick to. Up Wt-65k /Down Wt=50. Hanging Wt=58k 12:00 13:00 1.00 680 2,520 COMPZ RPEQPI TRIP P RIH w/ DC's on 19 stds of DP f/ 680' to 2,520' - 8' above To of IBP. 13:00 13:30 0.50 2,520 2,520 COMPZ RPEQPI CIRC P Circulate hole over @ 5 bpm / 400 ICP - 420 FCP. 13:30 17:30 4.00 2,520 2,474 COMPZ RPEQPI OTHR P Start w/sand dumping operation. Estimated - 24 sacks or 1200# of sand fora 50' sand plug on top of IBP.Let Sand settle for 1 hr and to ed TOS 2473.59'. 17:30 19:00 1.50 2,474 712 COMPZ RPEQPI TRIP P Pull up hole to 712' and MU Storm Packer &RIH to a set depth of 63' below rotary table. UP WT = 65K, SO WT = 50K. Test packer to 150 PSI - 15 minutes. Good test. 19:00 21:00 2.00 0 0 COMPZ RPEQPI NUND P Nipple down BOP stack. 21:00 00:00 3.00 0 0 COMPZ RPEQPI NUND P Nipple.down tubing head. Prep and install long threaded bolts for casing ex ansion. OA & IA = o PSI. 3/27/2010 Continue install long thread bolts on tbg head. Remove remaining bolts and slowly allow casing to expand to 10". Remove packoff. MU Spear and pull stretch in 7" casing. observing 15 more inches in stretch. Attempt to weld tack emergency slips onto 7" Casing. Gas sniffer indicated up to 100 PPM LEL levels, even after flushing and allowing to breathe. Decision to pull slips after casing is cut and repulled. NU BOP's and spool. Shell test same to 1500 PSI. MU tools, retrieve storm valve, continue POOH lay down 4 3/4" DC'S. MU 7" Casing cutter, RIHto locate collars at 1904' and 1948'. Locate & cut 7" at 1928' with 100 SPM - 730 PSI, 80 RPM's. Circulate 150 BBLS of 170 Deg, seawater around to verify gas free and well bore partially cleaned u .With casin cutter, confirmed the cut. POOH la down cutter assembl . 00:00 02:00 2.00 0 0 COMPZ RPEQPI OTHR P Continue install long treaded bolts. Remove reamining flange bolts, and loosen long threads to allow casing to grow 10 inches. Remove long threaded bolts, spool and packoff as er FMC. 02:00 02:30 0.50 0 0 COMPZ RPEQPI OTHR P MU 7" spear assembly. RIH engage 7" casing stump. Slowly pull to 170K beating emergency slips back into place. The 170K pulled accomodated expected 7" string when cut plus 4 3!4" DC in hole to gain stretch. The casing stretch observed was 15 more inches. Release spear, breakout & la down same. Page 5 of 19 ~~ `Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:30 05:00 2.50 0 0 COMPZ RPEQPI OTHR P Clean 7" slip bowl. Obtain Hot work permit for tack welding slips. Held PJSM with crew, FMC and welder. Discuss safety & hazard recognition issues.Using gas sniffer, observed up to 100 PPM LEL levels, even after flushing with water, and allowing to breathe. Welder recommended not welding. Decision to not weld tack slips into place, and pull slips after cut was made and casing was re ulled. 05:00 09:00 4.00 0 0 COMPZ RPEQPI NUND P Nipple up BOP stack and spacer s ool. 09:00 09:30 0.50 0 0 COMPZ RPEQPI BOPE P Perform Bodv test on BOP stack and spacer spool to 1500 PSI. AOGCC was notified. Chuck Sheve waived witness of test. 09:30 09:45 0.25 0 0 COMPZ RPEQPI PULD P PU Storm packer retrieval tool 09:45 10:15 0.50 0 64 COMPZ RPEOPI TRIP P RIH to 64' and latch up 10:15 10:30 0.25 64 64 COMPZ RPEQPI PACK P Release Packer.U 65k / 55 Dn 10:30 11:00 0.50 787 712 COMPZ RPCOM PULD P Pooh & Layed down Packer & stand back 1 stand of drill i e 11:00 11:30 0.50 712 622 COMPZ RPEQPI TRIP P Stand back 3 stand of drill collars 11:30 13:00 1.50 622 322 COMPZ RPEQPI PULD P Continue POOH and layed down 10 drill collar. 13:00 14:30 1.50 322 322 COMPZ RPEQPI OTHR P RU kil- line to circulate to open top tank and test to BOP psi of 250/3500 si. 14:30 15:30 1.00 322 322 COMPZ RPEQPI CIRC P Circulate Diesel cap off well w/Seawater. 15:30 16:30 1.00 322 0 COMPZ RPEQPI PULD P Lay down remaining 3 drill collars. 16:30 18:00 1.50 0 0 COMPZ RPEQPI TRIP P MU 5" Multi-string cutter BHA #5 & RIH w/20 stands of DP to 1935' DPM. 18:00 20:00 2.00 0 0 COMPZ RPEQPI SLPC P RU & Slip & cut 84' of Drilling line. Ins ect brakes & Drawworks. 20:00 22:00 2.00 0 1,928 COMPZ RPEQPI CPBO P Locate the 7" collars with pump pressure @ 140 PSI. Verify collar depths at 1904', DPM and 1948' DPM with good set down. Position knives and cut 7" ca_sin9 at 19 R' DPM with 80 RPM's 100 SPM - 730 PSI until observed good pressure dro to 250 PSI. 22:00 23:00 1.00 1,928 1,928 COMPZ RPEQPI CIRC P Observed fluid swapping in hole with arctic pak in OA. Pump 150 BBLS of 170 Degree seawater down drill string with annular closed taking returns through choke to outside open top tank @ 3 BPM - 200 PSI, 4 BPM - 300 PSI. Open up annular monitor well -static. Page6of19 l I Time Lo s Date From To Dur S. De th E. De th Phase Code. Subcode T .Comment 23:00 23:30 0.50 1,928 1,928 COMPZ RPEQPI CPBO P With multi string cutter, pumped to have 300 PSI DP pressure and slackoff to confirm good cut as per BOT re . 23:30 00:00 0.50 1,928 1,361 COMPZ RPEOPI TRIP P Blow down Top Drive & lines. POOH with cutter to 1361'. 3/28/2010 Continue POOH, breakout & lay down Multistring cutter. Knives indicated good cut. Make up Spear &packoff assembly. RIH engage 7" casing stub. Pull to 100K verifying free movement in casing. Move pipe 2'. Pump 200 BBLS of 90 Deg diesel down casing to flush arctic pak, followed with 150 BBLS of 170 Deg Seawater to clean up. Monitor well -static. ND BOP's stack & spool to remove emergency slips. NU BOP stack & spool. Circulate another 150 BBLS of hot seawater to clean up casing. POOH lay down 44 jnts and a cut off joint. Clean & clear rig floor. Install tesdt plugTest annular to 250 / 3500 PSI on chart. MU 9 5/8" casing scraper on DP, and RIH to to at 258' DPM. POOH la down BHA. Called for HES. 00:00 00:45 0.75 1,361 0 COMPZ RPEQPI TRIP P Continue POOH racking back DP. 00:45 01:45 1.00 0 0 COMPZ RPEQPI PULD P Breakout & lay down multistruing cutter assembly. Inspect knives. Knives indicated ood cut. Make up 7" Spear and packoff assembly. RIH o en a e 7" casin st b. Pull to 110K to verify free movement in casing moving string 2'. Hold up wei ht. 01:45 02:15 0.50 0 0 COMPZ RPEQPI RURD P Rig up to displace well. Blow through lines. RU trucks. Held PJSM with crew. Discuss rodecure to dis lace. 02:15 05:30 3.25 0 0 COMPZ RPEQPI CIRC P Pum 200 bbls of 90 De diesel down 7" casing. at 2 BPM on the OA to flush and clean up arctic pack in OA. Continue with 150 BBLS of 170 Deg seawater at 4 BPM to displace diesel. Monitor well -static. 05:30 08:30 3.00 0 0 COMPZ RPEQPI NUND P Nipple down BOP stack & spool to remove emer enc sli s. 08:30 10:00 1.50 0 0 COMPZ RPEQPI NUND P NU Bop's 10:00 10:30 0.50 0 0 COMPZ RPEQPI PULD P Pull 7" csq @ 115k - 125k for 29'. Attempt to PT Flange break. Pack-off on spear failed. Drop back down 18' had metal vibration both up & down. had ood break out. 10:30 11:00 0.50 0 0 COMPZ RPEQPI CIRC P Circulate 150 bbls @ 5bpm @ 280 si. 11:00 12:00 1.00 0 0 COMPZ RPEQPI PULD P Pull 1joint of 7" casing & release s ear. 12:00 12:30 0.50 0 0 COMPZ RPEQPI PRTS P Shell test BOPE's @ 1500 psi for 5 mins. 12:30 13:00 0.50 0 0 COMPZ RPEQPI EQRP P Change out to 7" casing equipment. 13:00 13:15 0.25 0 0 COMPZ RPEQPI SFTY P PJSM w/ GBR & Rig Crew on Pulling & La in down 7" casin . Page 7 of 19- • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:15 17:30 4.25 1,928 0 COMPZ RPEQPI PULD P POOH Laying down 7" Casing. Observed no Arctic Pack build up on the Pipe. Recovered 39' top jt, 43 full joints, and 22' Mechanically cut joint. Inspect cut as per BOT Rep. Good cut. Observed Sinusoidal Buckling @ Joint 7 - 44 17:30 20:00 2.50 0 0 COMPZ RPEQPI OTHR P RD CSG equipment. Clean and Clear ri floor. 20:00 21:30 1.50 0 0 COMPZ RPEQPI ROPE P Rig up, install test plug and test Annular with 7" test joint to 250/3500 PSI. Record on chart. Rig down test e ui ment.. 21:30 22:00 0.50 0 0 COMPZ RPEQPI PULD P Pull Baker tools to rig floor. Strap same. 22:00 23:00 1.00 0 258 COMPZ RPEQPI PULD P Make up 9 5/8" casing scraper assembly on drill pipe for a flexible assembly. RIH to tag at 258' DPM. Repeat attempts to pass through or ain hole with no success. 23:00 00:00 1.00 258 0 COMPZ RPEQPI PULD P POOH, breakout & lay down scraper assembly. Observed marks on 6 3/8" bullnose indicating tag up. Call for HES wireline crew. 3/29/2010 Wait on HES 1 hour. Rig up HES with caliper logging tools, and WLIH to casing stump at 1928'. WLOH & lay down tools. MU Caliper logging tools. WLIH obtianing caliper log while logging up. Logs looked good. RD HES. MU Casing back of tool assembly. RIH to locate & back off casing stub at 1948'. POOH, lay down tools. Install wear bushing. MU tandem milling assembly with a 8 3/8" Mill and 8 1/2" Mill. RIH to tag at 256'. Mill casin from 221' - 225'. Visc u s stem to 50. 00:00 02:00 2.00 0 0 COMPZ RPEQPI ELOG P Wait on HES crew 1 hour. Timed out. 02:00 08:00 6.00 0 0 COMPZ RPEQPI ELOG P Rig up HES wireline crew. Held PJSM with Crew. Discuss safety& hazard recognition issues. Discuss procedure to rig up and run caliper 08:00 08:30 0.50 0 0 COMPZ RPEQPI PULD P RD & Release HES. Good Data On Lo . 08:30 09:00 0.50 0 0 COMPZ RPEQPI SFTY P Get Plan forward from town. PJSM 09:00 10:00 1.00 0 310 COMPZ FISH TRIP P MU Bha #7 (Back-off tool string ) 10:00 13:00 3.00 310 2,248 COMPZ FISH TRIP P Start tripping w/Bha #7 filling DP W! fresh water. Page 8 of 19 r • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 14:00 1.00 2,248 2,248 COMPZ FISH BKOF P Set Lower slips @ 1,972' @ 620 psig and pressure up to 1,200 psig. Hold pressure and slack off 10k. Pressure up to 1,700 psig and set upper slips and pressure up to 3,500 psig. Slack off 10k and set slips @ 1,948' ,landing wt in rotary table. 1) Pressure up to 600 psig - 3,840 ft/Ibs and break 7" BTC connection - continue to Pressure up to 1,100 psig. recovered 1/4 of a turn. 2) Pressure up to 530 to 700 psig and recover 3/4 of a turn = 1 full turn to the left. 3) Pressure up to 410 to 550 psig and recover 1/4 of a turn 4) Pressure up to 330 to 525 psig and recover 1/2 of a turn 5) Pressure up to 300 to 370 psig and recover 1/2 of a turn = 2.25 turns to the left 6) Pressure up to 380 to 420 psig and recover 1/2 of a turn 7) Pressure up to 300 to 380 psig and recover 1/4 of a turn = 3 full turns to the left 8) Pressure up to 300 to 450 psig and recover 1/4 of a turn 9) Pressure up to 440 to 610 psig and recover 1/4 of a turn 10) Pressure up to 870 psig - no cycle 11) Pressure up to 400 to 480 psig and recover 1/2 of a turn = 4 full turns to the left 14:00 16:00 2.00 2,248 0 COMPZ FISH TRIP P PU and release Back off tool, POOH and la down BHA. 16:00 17:30 1.50 0 0 COMPZ FISH OTHR P Offload back off tools and bring on Millin BHA 17:30 18:00 0.50 0 0 COMPZ FISH OTHR P Set wear ring 18:00 18:30 0.50 0 0 COMPZ FISH SFTY P Held PJSM with Crew and Fishing re 's. 18:30 23:00 4.50 0 256 COMPZ FISH PULD P PU and MU Tandem Milling BHA # 8. RIH to tag up at 256'. Set down al wei ht. Visc u fluid in s stem to 50. 23:00 00:00 1.00 256 260 COMPZ FISH MILL P Make up top drive and mill from 221' - 225' lower mill depth. (Upper mill is tailing behind by 16' and Bullnose is 36' ahead of Lower mill) UP WT - 58K, SO WT - 50K, 40 RPM's, TQ - 3K, with 5 BPM - 50 PSI. Observed ood iron cuttin s return. Page 9 of 19 r ~. `Time Lo s Date From To Dur S. th E. De th Phase Code Subcode T Comment 3/30/2010 24 hr Summary Continue milling ID of 9 5/8" casing from 225' - 282' (56' total milled.). POOH with assembly, oberved the lower mill had twisted off below the carbide section, leaving approximately 37.21' of fish in the hole. Obtained pictures, posted on folder in S drive. RU stack washer tool & wash iron cuttings out of BOP stack, set test lu and be in testin BOP's. AOGCC re Chuck Sheve waived witness of test. 00:00 20:00 20.00 260 282 COMPZ FISH MILL P All depths referenced to lower mill! (Upper mill is tailing behind by 16' and Bullnose is 36' ahead of Lower mill) Continue_mill from 225' - 238'. Lower Mill Depth UP WT - 58K, SO WT - 50K, 40 RPM's, TO - 3K,with 5 BPM - 50 PSI. Observed good iron cuttings return. Fluid system viscosity at 50. 10:15 hrs Lower Mill @ 238' and lost WOM and Continue to rotate @ 50 rpm's w/ 5k torque, circulating @ 10 bpm @ 110 psig. Ream in the hole to 247' Lower mill depth and begin milling again w/ 5k WOM. 13:10 hrs Had signs of cmt and formation - 251' Lower Mill depth. Milled down to Lower mill depth @ 255' -torque fell off from 5 to 6k torque to 2k -Continue to mill down to 262' Lower mill depth. Back ream to 217' Lower mill depth. Ream back down to 262' Lower mill depth @ 2k torque. -Make connection and ream down to 266' Lower depth, before taking wt and torque increased to 5 to 6k torque. Continue to mill down to 282'. Wash & ream through tight spots to clean up. Could not straight slack off. Assembly took 2-3K WOB. Decision to POOH with assembly for scheduled BOP test. 20:00 23:00 3.00 291 0 COMPZ FISH TRIP P Blow down Top Drive and lines. POOH. Lay down BHA. Observed lower mill had twisted off and left 37.21' of fish in hole includes Bullnose -.65', XO - 1.47', 6 1!4" DC - 30.22', XO sub -1.87', XO sub - 2.00' and the twisted off piece of 1.00' -5 3/4" OD. Obtained pictures, loaded in file on the S drive. 23:00 23:30 0.50 0 0 COMPZ RPEOPI ROPE P Held PJSM with crew. Discuss rig up and safety during BOP test. Set out high pressure signs. RU stack washing tool. Wash out excessive iron cuttings from BOP's at 6 BPM while reciprocate joint. RU test e ui ment. Pull Wear bushin . Page 10. of 19 ""Time Lo s Date From To Dur S. De th E De th Phase. Code Subcode T Comment 23:30 00:00 0.50 0 0 COMPZ RPEQPI BOPE P Test BOP's. Begining with choke manifold and floor valves. Set test lu . 3/31 /2010 Continue test BOP's. Perform Koomey test. Witness of test waived by AOGCC rep Chuck Sheve. RIH with tandem mills to clean up hole, tagged fish top at 289' DPM. POOH lay down mill assembly. MU 8 1/8" OS, RIH to tag & engage fish. POOH with 37.21' of recovered fish. Lay down same. MU BHA #10, tandem milling assembly. Tag up at 244' lower mill depth. Drop a collar and continue milling through tight spots and down to next casing collar at 312'. Mill through collar, continuing to wash & ream through to midnight depth of 325'. No fluid losses. Observed considerable iron cuttin s ,minimal cement and formation returns. 00:00 06:00 6.00 0 0 COMPZ RPEQPI BOPE P Continue test BOP stack, choke manifold and valves. HCR's and manuals, including all floor valves. Tested with 3 1/2" and 7" test joints. Perform Koomey test. Firest 200 PSI - 13 sets/ Full 3000 PSI in 1 Min 27 secs, 4 Bottles of nitrogen with avg PSI of 2300. RD test a ui ment. 06:00 06:30 0.50 0 0 COMPZ RPEQPI OTHR P Pull test plug and set wear ring @ 29' 06:30 07:00 0.50 0 0 COMPZ RPEQPI OTHR P Bring Milling BHA tools to rig floor. 07:00 11:30 4.50 0 289 COMPZ RPEQPI PULD P PU and MU milling BHA #9 and RIH U 264'. Obtain Parameters: 57k up wt, 50k do wt, 55k Rot wt. 60 rpm @ 2k free torque, circulating @ 10 bpm @ 110 psig. RIH to 289' and set down on fish. Slack off 10k and rotate with for ue. 11:30 12:00 0.50 289 289 COMPZ RPEQPI OTHR P Swap out 1,200 tongs with 1,500 ton s. 12:00 14:00 2.00 289 0 COMPZ RPEQPI TRIP P POOH and lay down BHA #9 14:00 16:00 2.00 0 294 COMPZ RPEQPI FISH P Load and Dress overshot w/ 6.375" Basket Grapple. RIH w/ BHA #10 289' and work over to 294'. Pickup and bleed jars -pull fish from tight s of 10k OSW. 16:00 17:30 1.50 294 0 COMPZ RPEQPI TRIP P POOH and lay down fish. Recovered 37.21' of fish. 17:30 18:00 0.50 0 0 COMPZ RPEQPI OTHR P Off load rig and prepare for BHA #9 run 2. 18:00 20:30 2.50 0 244 COMPZ FISH MILL P Make up BHA # 10, Tandem Mill assembly, RIH to tag at 244' DPM. D 1 DC from assembl . 20:30 00:00 3.50 244 325 COMPZ FISH MILL P Mill to clean up hole from 244' continuing down to hard tag at 312' with lower mill depth. Mill through the collar at 310' with 50-60 RPM's - 10 BPM - 150 PSI until fell off and worked down to 325' DPM. NOTE: From Bullnose, lower mill behind 35', and upper mill behind 50'. Continue work mills through collar depth sections. Page 11 of 19 Time Lo s Date From To Dur S. D th E. De th Phase Code Sutx:ode T Comment 4/01/2010 za hr Summary Continue milling washing & reaming down to 391' Bullnose depth. Lower mill depth = 356'. Work mills through hole cleaning up overpulls, and set downs to obtain free movement with straight slack off. Continue trip in hole with assembly to tag 7" casing stump @1928' DPM.CBU. POOH, lay down milling assembly Upper mill in gauge at 8.5", Lower mill gauged at 8 1/8". Make up Dummy run includes 7" triple connection sub, pup and ES cementer with magnets on DP to TIH and tag at 269'. Attempt to work through with no success. POOH, lay down assembly. MU milling assembly includes 2 - 8 1/2" mill back to back, TIH to tag at and mill from 271'-276'. Wash & ream to 306', continue milling from 306' -332', when WOB fell off. Continue work string mills throu h trouble areas to ain free movement. 00:00 07:00 7.00 325 356 COMPZ FISH MILL P Continue milling washing & reaming down to 391' Bullnose depth. Lower mill depth = 356'. Work mills through hole cleaning up overpulls, and set downs to obtain free movement with straight slack off. 70 RPM, 6K TDTO, 5K WOB, 10 BPM, 120 psi, ROT wt 55K. Ream thru to cleanup, attempt to slide, took 10K. Resumed reaming, hang up while backreaming @ 362' Lower mill depth w/50K overpull. ROT down, resume reaming 70 RPM 3-4K TDTQ, 55 up wt, 50K dwn wt. 10 BPM 120 si. 07:00 08:00 1.00 356 COMPZ FISH MILL P RIH f/389' tagged top of 7" stub w/xover to 4 3/4" collar 1928'. 08:00 08:30 0.50 COMPZ FISH CIRC P CBU @ 10BPM w/ 400 psi. 08:30 11:00 2.50 COMPZ FISH TRIP P Blow down top drive. POOH, LD BHA. Guage two Watermelon mills. Upper gauged full @ 8 1/2" Lower 8 3/8"mill au ed at 8 1/8". 11:00 12:00 1.00 COMPZ FISH TRIP P Cleaned and organized rig floor. MU BHA #12 for drift run as follows: 8 3/8" OD Tripple connect tool, 7" x 10' casing pup, HES Type H ES cementer (8 1/4" OD), xover and two 4 7/8" strin ma nets. 12:00 12:30 0.50 COMPZ FISH TRIP P RIH with drift and stacked out at 269'. Attempted to rotate thru and 10K wt but would not o. 12:30 13:00 0.50 COMPZ FISH TRIP P POOH, LD two magnets separately. LD Tripple connect and H ES cementin tool all to ether. 13:00 14:00 1.00 COMPZ RIGMNT SVRG P Change out saver sub and grabber dies. Service ri . 14:00 16:00 2.00 COMPZ FISH TRIP P MU BHA #13, tandem watermelon mills stacked one on top of the other. Both mills 8 1/2" OD. Page 12 of 19 • l `Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:00 00:00 8.00 COMPZ FISH MILL P RIH tagged @ 250' (lower mill depth). Est. circulation 10BPM w/120 psi. up wt 60K Dwn wt 50K. 60 RPM TDTO 3K. Milled from 250' to 271' easy, torqued up to 4K @ 271'. Continue mill from 271' to 276', wash & ream from 276' - 306'. Took weight, and milled form 306' - 332' with above parameters until WOB fell off. Continue work tandem mills through trouble spots to gain free movement. Observed set downs at depths of 260',283',and 307'. Observed weight set down quickly and when bumper sub closed it would knock assembly throu h. Reamin at midni ht. 4/02/2010 Continue working tandem 8 1/2" mills through trouble area at 260', 283', and 306'. Observed cleaned up some, but still seeing these area on weight indicator. No improvement after 2 hours. POOH lay down & gauge mills. MU 7" dummy run assembly includes triple connection sub, and ES cementer with pup and magnets. TIH through trouble spots with no issues. Observed only 4K set down and fell off at 283' DPm. Continue TIH to 1920'. CBU pummping super sweep. POOH. MU and run Spear assembly to the 7" Casing stump. Tag & engage. Rackoff stump. Pull above collar, and circualte to clean up connection area. POOH. Lay down recovered fish. RU HES slickline crew. MU & run PDS memory caliper log. RD HES. RU GBR casing equipment. Chnage out lower rams to 7", and test same to 250 /3500 PSI. Notified AOGCC. Bob Noble waived witness of test. H3eld PJSM with crew, BOT &HES reps. MU 7" Screw in collar with pup and ES cementer. Continue RIH with 7" casing working string to get joints 6,7,8,& 9 down past trouble area. Obtain up & down weights every 5 joints. Circulate after 10 joints, observing fluid coming over collar every joint last 15'. 00:00 03:00 3.00 250 366 COMPZ FISH MILL P Continue working tandem 8 1/2" mills through trouble area at 260', 283', and 306'. Observed cleaned up some, but still seeing these area on weight indicator. No improvement after 2 hours. POOH lay down & gauge mills to 8 1/2". Observed cemment in between-mill blades. 03:00 04:30 1.50 0 0 COMPZ FISH PULD MU 7" dumm run assembly includes triple connection sub, and ES cementer with u and ma nets. 04:30 06:30 2.00 0 1,920 COMPZ FISH TRIP P TIH through trouble spots with no issues, Observed 4K set down and immediately fell off. Continue TIH to 1920'. CBU. 06:30 08:30 2.00 1,920 0 COMPZ FISH TRIP P POOH, LD drift assy. 08:30 10:00 1.50 0 1,948 COMPZ FISH TRIP P MU BHA #14, spear for fishing 7" casing stub. RIH, engauged fish @ 1928, swallowed 8'. Up wt 65K dwn wt 67K. PU to confirm, set spear twice with 15K overpull. Slackback to neutral. Backed off 9 rnds, came free. PU 3', est. circulation 10BPM /360 si. to wash off to of 7" casin . Page 13 of 19 l~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:00 14:00 4.00 1,948 0 COMPZ FISH TRIP P POOH to top of 1st drill collar. Circulate 20 bbl. Super Sweep to clean up stack. Continued POOH laying down 6" drill collars, jars, bumper sub, spear and 20.28' 7" casing stub. Out of hole with 7" collar leavin in lookin u 1948'. 14:00 16:30 2.50 0 0 COMPZ EVALWf SLKL P Install 7" shooting nipple. PJSM w/HES Slickline crew and PDS logging Eng. RU slickline and PDS Caliper/Gamma Ray/CCL. Ran Caliper log from 1935' to surface. RD HES. 16:30 18:00 1.50 0 0 COMPZ RPEQPI RNCS P RU GBR casing running tools. 18:00 21:00 3.00 0 0 COMPZ RPEQPI ROPE P Chan a out lower rams to 7" solid body. Test same to 250 / 3500 PSI. . Record on chart.. AOGCC notified and Bob Noble waived witness of test. 21:00 21:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with crew, BOT &HES reps. Discuss safety & hazard recognition iassues. Discuss procedure to make up and run 7" 21:30 00:00 2.50 0 1,518 COMPZ RPEQPI RNCS P MU 7 screw in collar with cut lip, pup joint and ES cementer assembly with baker-loc connections. Continue RIH with 7" casing crossing over form BTC to TC II pipe installing centering guides on each joint as per well plan. Work string through trouble spots from 260' - 315' to get joints 6,7,8 and 9 down. Bump casing to the right when tagged up to get through spots. After joint 10, circulate 30 BBLS to clean up, as we observed fluid running over collars every joint last 15' while run in hole. 4/03/2010 Continue RIH with 7" TC2 Casing installing centereing guiides on each joint. RU Schlumberger cementers, and vac trucks. Tag and screw into 7" casing at 1948' with 10K MU Torque. Verify integrity with 2500 PSI test. RU cement head and lines. Held PJSM. Wlth Schlumberger, pump to open ES cementer, 100 BBLS of seawater, and a total of 91.6 BBLS of 15.7 PPG Arctic Set @ 5 BPM. Observed only interface returns to surface - 9.1 PPG. Drop plug to displace and bump plug. Press & hold at 2000 PSI. Bleed off pressure - no flow. CIP @ 12:40 HRS. RO Schlumberger. WOC 3:45 HRS. ND BOP's. Install emergency slips with 50 K overpull. RU Wachs cutter and cut casing as per FMC rep. Install packoff, test same. Set back BOP's. Ni le down 11"double studded ada ter. Page 14 of 19 - Time Lo s ..Date From To Dur S. De th E. De th Phase Code Subcode _T Comment 00:00 08:00 8.00 1,518 1,948 COMPZ RPEOPI RNCS P Continue RIH with 7" TC2 Casing installing centering guides on each joint. RU Schlumberger cementers, and vac trucks. Tag and screw into 7" casing at 1948'. Make up torque = 10000 ft/Ibs. Overpull 25K, slack off to neutral, overpull 50K. Slack off to 5K over, Pressure test to 2000 psi held for 5 min. increased to 2500 psi and held solid for 15 min. Bled ressure off. 08:00 10:30 2.50 COMPZ RPEOPI NUND P RD casing casing crew. Change out bails. NU TC-II x BTC xover and cement head w/ 'ES' closing plug loaded. 10:30 11:00 0.50 COMPZ CEMEN' SFTY P PJSM w/HES, Schlumberger, all vac truck drivers and rig crew. Covered pumping procedure, salty & hazard issues and 'ob assi nments. 11:00 13:00 2.00 COMPZ CEMEN" CMNT P RU Schlumberger Cement Equip. Pressure test lines to 3900 psi. Bled off. Pressure up to 3500 psi and opened 'ES' cementer. Est. circulation w/seawater 325 psi @ 5.0 BPM. SD, Batch mixed 15.7 ppg Arctic Set-1 cement, start downhole @ 2.2 BPM w/122psi. With 20 bbls away, increase rate to 3.0 BPM w/150 psi. At 50 bbls away 140 psi 2.8 BPM. 75 bbls away 142 psi w/2.4 BPM. End cement w/ total of 91.6 bbls um ed. Dropped closing plug. Start SW displacement @ 5.0 BPM w/105 psi. Catch up with cement column with 22 bbls, 375 psi 4.9 BPM. After 39 bbls away 630 psi 4.9 BPM slowed down to 3.0 BPM @ 490 psi returns still all seawater. 58 bbls displacement away 3.0 BPM w/697 psi start to get interface returns, PH coming up. 70 bbls displacement away 714 psi w/2 BPM still contamenated cement returns. Bum ed plug w/75.2 bbls SW. press came up from 750 psi to 1000 psi. Slowly brought pressure up to 2000 psi ,closed 'ES' tool. Held pressure no bleedoff. Bled pressure off casing verified no flowback. Plug down and closed @ 12:40 hrs. Returns still contamenated cement 13:00 16:00 3.00 COMPZ CEMEN" CMNT P ND cement head. RD Schlumberger um in a ui ment. WOC 3:45 hrs. 16:00 17:30 1.50 COMPZ RPCOM NUND P ND BOPE and lift. Page 15 of 19 l ''Time Lo s Date From To Dur S. De th E. De th Phase Code Subcade T Comment: 17:30 19:30 2.00 COMPZ Install emergency slips with 50K overpull on casing. RU cutter, cut 7" casing with WACHS pneumatic cutter. POOH lay down pups and 8.57' of cut off ~oint # 45. 19:30 00:00 4.50 COMPZ Set back BOP stack. Nipple down cement cross and 11" x double studded ada ter . 4/04/2010 Install packoff, and NU Tubing head. RU & test packoff to 3000 PSI. NU BOP's, change out lower rams to VBR's and test same 250 /3500 PSI. AOGCC rep Lou Grimaldi waived witness of test. Install WB. MU BHA #15- 6 1/8" Mill tooth bit, & JB's. TIH to tag @ 1931'. Dril cement & plug from from 1931-1941'. WOB -fell off. RIH to tag top of sand at 2461' and dry drill. UP WT - 74K, SO WT - 70K. CBU until clean. POOH lay down BHA. Recovered iron shavings in JB's. MU BHA #16 -Wash shoe with inside catch baskets spaced out 8' above shoe. TIH to tag at 2471'. Close annular, attempt to reverse circulate down and packed off immediately @ 2472'. Circulate long way to clear screen. Attempt to reverse circualte down and repeated packoff. BD TD. POOH, breakout & lay down screen. Clean junk baskets recovering iron & rubber debris. MU assembly without screen. TIH to to at 2472 00:00 02:00 2.00 COMPZ RPEQPI NUND P Install packoff & test same to 3000 PSI - 10 minutes. Install tb head. 02:00 03:30 1.50 COMPZ RPEQPI NUND P NU BOP stack & lines. Change out lower rams to 2 7/78" x 5" VBR's. 03:30 07:00 3.50 COMPZ RPEQPI BOPE P Ru test equipment. Test VBRS' and 250 / 3500 PSI. and perform Body test on BOP breaks. AOGCC rep Lou Grimaldi waived witness of test. 07:00 08:30 1.50 COMPZ RPEQPI NUND P C/O Tongs. Pull test plug. Set wear rin . 08:30 10:00 1.50 0 1,933 COMPZ FISH DRLG P MU BHA #15 consisting of 6 1/8" Mill Tooth Bit, 2-Boot Baskets, Bumper Sub, Jars, 6-Drill Collars on 3 1/2" drillpipe. RIH and tagged TOC @ 1931'. 10:00 13:30 3.50 1,933 COMPZ FISH DRLG P Up wt 65K dwn wt 65K. Wash dwn tag hard cmt @ 1933'. Drill cmt to 1935', start drill on plucl to 1937'. Tq - 4K, Up wt 65K dwn wt 65K, ROT 65K. Continue to drill to 1941', drilling free. 13:30 14:00 0.50 COMPZ FISH CIRC P CBU @ 8 BPM 470 psi. Blow down To Drive. 14:00 14:30 0.50 COMPZ FISH DRLG P RIH from 1941' to 2461' tagged up. U wt 74K, Dwn wt 72K. 14:30 15:00 0.50 COMPZ FISH DRLG P Dry drill @ 2465' to 2465' to break up cement or trash. 15:00 16:00 1.00 COMPZ FISH CIRC P Circulate hole clean to clean up trash off of sand to . 16:00 17:00 1.00 COMPZ FISH TRIP P POOH standing back drillpipe and LD BHA #15. Clean out junk baskets, a few small pieces of metal and trace of sand. 17:00 18:00 1.00 0 322 COMPZ FISH DRLG P MU BHA #16 consisting of wash shoe, ~unk basket and screen. 18:00 19:00 1.00 322 2,471 COMPZ FISH TRIP P Trip in hole with BHA #16 to tag at 2471' DPM. UP WT 74K, SO WT 70K. Page 16 of 19 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T _ Comment 19:00 20:30 1.50 2,471 2,472 COMPZ FISH FISH P Close annular, Reverse circulate @ 3 BPM - 250 PSI wash down to 2472' Observed screen packoff. Pump long way to clear screen. Attempt one more time to wwash down reversing, and screen immediate) acked off. 20:30 22:30 2.00 2,472 0 COMPZ FISH TRIP P Blow down Top Drive. POOH from 2472' DPM. Remove screen from assembly. Pull baskets and observed packed off with rubber & iron cuttin s. 22:30 00:00 1.50 0 2,472 COMPZ FISH TRIP P Make up assembly for rerun without screen. TIH to tag at 2472' DPM. UP WT 74K, SO WT 70 K 4/05/2010 Close annular, Reverse circulate from 2472' - 2528'. Observed sand returns on shakers. Tag at top of IBP 2528'. Suspect junk on top of IBP, Attempt to wash over. RU and displace well to 9.6 PPG. Washover IBP ~"" suspecting junk, tag & release IBP. Chase down hole 10'. Observed 25-30K overpull when pull up. POOH, Observed junk in baskets , no IBP. MU IBP retrieving tool, RIH to top of tbg stump @ 6264' DPM, tag and recover IBP. POOH. lay down same. MU Washover shoe assembly. TIH to tga tbg stump wash down to 6279' DPM. CBU. POOH lay down BHA. Held PJSM. MU FHL packer assembly with SBE & PBR along with 2.812" DB ni le & u s as er Ian. RIH on DP. 00:00 01:30 1.50 2,472 COMPZ FISH CIRC P Close annular, reverese circulate from 2472' - 2528' -hard tag. Suspect junk on top of IBP. Element de th at 2537. 01:30 02:00 0.50 COMPZ FISH CIRC P Displace well with 9.6 PPG at 5 BPM - 240 PSI. 02:00 02:30 0.50 COMPZ FISH FISH P Attempt to washover IBP fishing neck with 7 RPM's - 1 K TQ. 3 BPM - 200 PSI. With 2-4K WOB observed weight falling off indicating "junk", continuing down to 2537, with no tag. Indications IBP released and fell. Slack off 10 more feet to 2547'. When pull up, observed 25-30K overpull, UP WT 74K, SO WT 70K. Allow IBP to relax. Pull slowly to observe drag and finally free movement. IBP hung in inside catch basket fin ers. 02:30 03:00 0.50 COMPZ FISH OWFF P Monitor well -static. Blow down top drive & lines. 03:00 06:00 3.00 COMPZ FISH TRIP P POOH slowly observing hanging up every 40' or so on casing collars. Out of hole with no IBP. Empty junk basket, hand full of metal chunks and small amount of rubber. 06:00 09:30 3.50 COMPZ FISH FISH P MU BHA # 18, sure catch retrieving tool. RIH and chased IBP to bottom (tubing stub). Screw in TD. Pumped 2 BPM 2 130 psi. Lowered and tagged IBP @ 6253'. Pressure increased to 360 psi indicating going over fishing neck. SD pump. PU 10', no drag. Kicked on pump and pressured back up to 300 psi to confirm IBP en a ed. SD um . Page 17 of 19 .~ s s Time Lo s Date .From To Dur S. De th E. De th; Phase Code Subcode T Comment 09:30 13:30 4.00 COMPZ FISH TRIP P Bleed off pressure. LD iwo singles. Drop dart to open pump out sub, let fall. Pressured up to 1890 to shear. POOH. 13:30 17:00 3.50 0 6,279 COMPZ FISH TRIP P MU BHA # 19, Shoe and washpipe to wash over and clean out around tubing stub. RIH tagged top of stub 6264' washed down free to 6279'. 17:00 17:30 0.50 6,279 6,279 COMPZ FISH CIRC P PU off of stub and CBU. 17:30 21:00 3.50 6,279 0 COMPZ FISH TRIP P POOH standing back drillpipe. Crew Chan e. New Crew. 21:00 22:00 1.00 0 0 COMPZ FISH PULD P Breakout & lay down BHA.CIean & clear rig floor area. Send out tools. Pull tools to floor for next run. RU ower ton s. 22:00 22:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make up FHL packer assembly &RIH s eeds. 22:30 23:30 1.00 0 229 COMPZ RPCOM PULD P Make up lower completion FHL packer assembly with SBE &PBR, including 2.812" DB nipple with pus as per well plan. MU Torque = 2000 ft/Ibs. MU crossover to DP, RIH with one stand. 23:30 00:00 0.50 229 229 COMPZ RPCOM RURD P Rig down tubing running equipment. Clean & clear floor. 4/06/2010 Continue RIH with lower completion, FHL packer assembly from 229' to tag tbg stump at 6264'. Pump 15 BBLS of corrosion inhibitor to spot on annulus. Set packer @ 6,153'. POOH and lay down 3 1/2" Drill Pipe. Pick up and run final 3 1/2" Completion. Space out Completion. Reverse circulate Inhibited 9.6 Ib/gal Brine. Land Tubin Han er and RILDS. 00:00 05:00 5.00 229 6,264 COMPZ RPCOM TRIP P Continue RIH with lower completion. FHL packer assembly from 229' to to tb stum at 6264'. Locate stump and shear screws with 10K set down to verify depth. Running s eed 60-90 Ft/min. as er BOT re . 05:00 06:00 1.00 6,271 6,271 COMPZ RPCOM CIRC P Install DP pup. RU & pump 15 BBLS of corrosion inhibitor to spot on annulus. 06:00 07:00 1.00 6,271 6,271 COMPZ RPCOM PACK P Drop 1 1/4" ball & rod. Allow to seat. Pressure to 2500 PSI to set FHL acker 61 'Top of the PBR = 6153.55'. PU sheared PBR w/13K over utl. BO head in and hoses. 07:00 14:00 7.00 6,271 COMPZ RPCOM TRIP P Prep rig floor for laying down drill pipe. POOH laying down DP and DC's. 14:00 15:00 1.00 COMPZ RPCOM OTHR P Clear out pipe shed from DP and DC's. RD equipment for drill pipe. RU equipment on floor for running com letion. Page 18 of 19 ~~ Time Lo s Daie From To Dur S: De th E. De th Phase Code Subcode T Comment 15:00 22:00 7.00 0 6,153 COMPZ RPCOM RCST P PU and RIH with final Completion String as per program. Up weight = 83K. Down Weight = 75K. Bring pump on line at 0.6 bpm/60 psi. Seal Assembly entered PBR. Pressure increased to 250 psi. Shut down pump and continue down to "No-Go". Pick up 7-ft above No-Go. Mark pipe and measure for space-out pups. Add required space out pups, 1 full Joint, and make up Tubing Han er. 22:00 23:00 1.00 6,153 COMPZ RPCOM CIRC P Reverse circulated in with 130 bbls of Inhibited 9.6 Ib/gal Brine and a 10 bbl 9.6 Ib/ al s aver at 4.0 b m/360 si. 23:00 00:00 1.00 COMPZ RPCOM RCST P Drain Stack and land Tubing Hanger. Up Weight = 85K. Down Weight 75K. Block Wei ht = 35K. RILDS. 4/07/2010 Test Tubing and Casing. Nipple down BOP Stack. Nipple up Production Tree and test. Freeze protect Well with Diesel. Set BPV. Secure Cellar. RDMO. 00:00 02:00 2.00 COMPZ RPCOM PRTS P Rig up test equipment. Pressure test Tubin at 2 500 six 15 minutes. Good. Bleed pressure down to 1,500 psi. Pressure test the Annulus at 2 500 Good. Bleed pressure down to "0" on both sides. Pressure up on the Annulus and shear open the SOV at 1,600 psi. Good. All test recorded on chart. 02:00 08:30 6.50 COMPZ RPEQPI NUND P PJSM. Set Two Way Check. Nipple down Riser. Replace Hydril Element in 11"annular. Continue to nipple down remainin BOP Stack. 08:30 16:00 7.50 COMPZ RPCOM NUND P NU tubing adaptor and 3 1/8" 5M tree. Trouble lining up adaptor. Ensured tree orientation same as at the beginning of workover. Presure test tree to 250/2500 psi. Test ackoff to 250/2500 si. 16:00 18:30 2.50 COMPZ RPCOM FRZP P Rig up Lil' Red Hot Oil Unit and freeze protect WeII with 93 bbls of Diesel. U-Tube to equalize Tubin /Annulus. 18:30 19:30 1.00 COMPZ RPEQPI RURD P Rig down lines. Set BPV. Secure well and cellar. 19:30 21:30 2.00 COMPZ RPEQPI RURD P Prep miscellaneous equipment for Rig move. Jack up Rig and move off of 2A-12 Well Slot. Rig released at 21:30 hrs. Page 19 of 19 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Apri123, 2010 RE: Cement Bond Log: 2A-12 Run Date: 3/26/2010 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-12 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20058-00 Cement Bond Log 1 Color Log 50-103-20058-00 `'''.s. `:'~~°' ..»w i ~ ~,~, ., ~ Wk's ,, 5 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 ~ ~~ ~ p0~ Office: 907-273-3527 Fax: 907-273-3535 rafael.barretohallib .' 5 r Date: „~?~ ~~ ft ? ~ ~.': 1 glob l Signed: ;, ~, • 1F~~~~ L ~~A~1/~fT~~4L ~~. PROACTIVE DAAGNOSTIC SERVItES~ INt. 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 ~,., ,~.~'r' ~_ ~ a~ f ~, .x ~,Y.~ Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 2] 02 Apr-10 2A-12 l ~~ -6v c/ Signed Print Name: 1 Report / EDE 50-103-20058-00 l°~5~~ °~,', ,e ~ ~,~ ,~. .ice ~r ~ Date : ~ ''~` .. ~'r¢ PROACTIVE DIAGNOSTIC SERVES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsan~~atara~~la~aT~e~car~t~~q.~~rn WEBSITE : s.~roeraa®r~Bmg.~~rrra C:\Documentr and Settings\Diane WitiamslDesktop\Transmit_Conoco.docx WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch (RCT) Record: 2A-12 Run Date: 3/24/2010 • Apri12, 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-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20058-00 -~.~~~ AFB k `' ~01~ ~~... w. L u~4rt, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto ha ibu on.com ~~ ~~~ Date: ~ ~~ ~. ~ 20";~~ ~ 610 -bo`a ~ S4 ~ Si ed: 8~ i~ L • • Memory Mufti-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-12 Log Date: Apri12, 2010 Field: Kuparuk Log No.: 7396 State: Alaska Run No.: 3 API No.: 50-103-20058-00 Pipet Desc.: 9.625" 36 Ib. J-55 Top Log Intvl1.: Surface Pipet Use: surtace Casing Bot. Log Intvl1.: 1,925 Ft. (MD) i ~ Inspection Type : Buckling & Restriction Inspection ' COMMENTS This caliper data is correlated to a PDS caliper log dated March 29, 2090. This log was run to assess the condition of the 9.625" surtace casing following milling operations to alleviate ' I.D. restrictions due to bends in the surface casing. A minimum I.D. of 8.57" is recorded in joint 6 (264'). Pre- and post-milling comparison log plots of the centered and off-center caliper recordings of the top 500', and a graph illustrating the minimum recorded diameters on a joint-by joint basis are included in this report. ' This is the third time a PDS caliper has been run in this well and the second time the 9.625" surtace casing has been logged. A comparison of the current and previous log (March 29, 2010) indicates a decrease in I.D. restrictions due to bends and indications of mill wear, which have increased the diameters recorded in the ~ vicinity of the bends. MAXIMUM RECORDED WALL PENETRATIOI'~3:~~~~~° `€ iE.~ ~~ ~< ~~~ Mill Wear on Bend (100%) Jt. 8 ~ 315 Ft. (MD) Mill Wear on Bend (100%) Jt. 6 @ 257 Ft. (MD) Hole due to Mill Wear (100%) Jt. 5 @ 222 Ft. (MD) Hole due to Mill Wear (100%) Jt. 7 @ 275 Ft. (MD) Mill Wear /Apparent Erosion (53%) Jt. 2 @ 86 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Mill Wear on Bend (89%) Jt. 8 @ 317 Ft. (MD) Mill Wear on Bend (88%) Jt. 6 @ 251 Ft. (MD) Hole due to Mill Wear (59%) Jt. 5 @ 224 Ft. (MD) Hole due to Mill Wear (55%) Jt. 7 @ 275 Ft. (MD) Apparent Erosion (30%) Jt. 9 @ 360 Ft. (MD) MAXIMUM RECORDED ID RESTRICTIONS: Milled Bend Milled Bend Minimum I.D. = 8.57" Jt. 6 @ 264 Ft. (MD) Minimum I.D. = 8.58" Jt. 8 @ 320 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. Field Engineer: 8. McCrossan Analyst: HY. Yang Witness: R. Overstreet ProActive Diagnostic Services, Inc. / P.Q. Box 1369, Stafford, TX 77497 Phone: (281) or (888} 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 r ~~ -c~~( 1~5~~ • • PDS Multifinger Caliper 3D Log Plot ~~ ._. ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-12 Date : April 2, 2010 Description : Detail of the Centered Caliper Recordings Across Bends in Surface Casing Pre- 8 Post-Milli • • PDS Multifinger Caliper 3D Log Plot L-, Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-12 Date : April 2, 2010 Description : Detai! of the Off-Centered Caliper Recordings Across Bends in Surface Casing Pre- ~ Post-~ Comments Depth Max. I.D. (03/29) 3-D Log (03/29) Image Map (03/29) Max. I.D. (04/02) 3-D Log (04/02) Image Map (04/02) ~ 1ft:800ft 7.7 9.7 0° 0° 90° 180°270° 0° 7 7 9.7 0° 0° 90° 180° 270° 0° Min. I.D. (03129) Min. I.D. (04/02) 7.7 9.7 7.7 9.7 Nominal I.D./ O.D. Nominal I.D./ O.D :............................ i............................ 7.7 9.7 7.7 9.7 Tree Pup Joint r . --- ~ -a.~...~.. 50 ` Joint 1 a ~- ? i s _.:z Joint 2 , Mill Wear 100 - Joint 3 Mill Wear is 150 Joint 4 ~- Mill Wear Joint 5 200 ~= _ - Holedue to '~' Mill Wear °.,~ ; n ~ '~ 1_ ~ ~ { Mill on 6 . a Min. LD. = 250 : , y ~ 8.57"~Zfi4' .: .- `~ 88% XSec. Loss . , Joint 7 . i f: a ~~ ~~ ~ =-'' _ - Holedue to ~ y '- ~ ~ MITI Wear 300 I I i Joint 8 _ __ Mill Wear on Bend Min. LD. _ ' 8.58"320' ~ ~~ .~ _: 89 % XSec. 350 ,'~"..._ _ ~', _ M~ : I loss t Joint 9 '«. i;,.__... ' ; _ 400 - Joint 10 _ ` . - ---°. ' Joint 11 450 - ,: Joird 12 -- _ ~r~ ;_ ter; - - - .,. _ ~ ;; 3 i I • ~~ Minimum Diameter Profile Well: 2,A-12 Survey Date: 4/2/2010 Field: Kuparuk Tool: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: '2.75 inches Country: USA Tubing I.D.: 8.765 inches • Correlation of Recorded Damag Pipe 1 9.625 in (30.4' - 1912.0') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 2 A-12 Ku paru k ConocoPhillips Alaska, Inc. USA April 2, 2010 A pprox. Tool De viation ~ A pprox. Boreho le Profil e ~I ~~ 35 6 230 12 465 18 699 D ~ a~ .n _ z 24 934 •~ c ~ n. °' o O 30 1169 3b 1403 42 1638 4fi 1873 4`~ 1912 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 49 • • PDS Report Overview ~,,. Body Region Analysis Well: 2A-12 Survey Date: April 2, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: HY. Yang Tubing: Nom.OD Weight Crade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 36 f -55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body - -~- metal loss body 50 40 30 20 10 0 0 to 1 to 10 to 20 to .40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 50 pene. 0 0 0 42 4 4 loss 0 0 0 46 2 2 Damage Configuration (body ) 50 40 30 20 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 50 0 46 0 0 4 Damage Profile (% wall) ~ penetration body ~ :,;., metal loss body 0 50 0 Bottom of Survey = 49 __ 100 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2A-12 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.765 in Country: USA Survey Date: April 2, 2010 Joint No. Jt. Depth (Ft.) Pen. U)~set (Ins.) Pen. Body (Ins.) Pen. % Metal loss °4~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 30 U.14 0.14 33 ?-) 8.93 A arent Erosion. 1 35 0. I I 0.14 ;2 ' > 8.93 A arent Erosion. Sli ht Oval Deforrnation. 2 75 U.1 ' 0.23 53 ~' 8.91 Mill Wear. A arent Erosion. 3 114 U. I 1 0.18 42 2~-1 8.92 Mill Wear. A arent Erosion. 4 153 O.ZO 0.21 48 2b 8.90 Mill Wear. A arent Erosion. 5 192 U.12 0.65 100 (,0 8.92 Hole due to Mill Wear. 6 230 U.24 0.87 l0U tSt) 8.57 Milled bend. Hole due to Mill Wear. 7 269 O. ~;_' 0.45 100 ib 8.90 Hole due to Mill Wear. 8 308 ! ).60 0.88 1 UO t>~) 8.58 Milled bend. Hole due to Mill Wear. 9 347 U.14 0.19 44 31 8.91 A arent Erosion. Sli ht Oval Deformation. 10 386 (t.12 0.14 33 2G 8.91 A arent Erosion. 11 425 (t.12 0.14 32 ?4 8.92 A arent Erosion. 12 465 (t. L3 0.14 32 2 S 8.93 A arent Erosion. 13 504 i ).12 0.14 S "3 ! 5 8.91 A arent Erosion. 14 543 U. I _' 0.16 38 ~') 8.92 A arent Erosion. Sli t Oval Deformation. 15 582 tt. 17 0.14 33 3(( 8.76 Bend. A arent Erosion. 16 621 (t. 14 0.16 38 27 8.89 A arent Erosion. Sli ht Oval Deformation. 17 660 U. I4 0.15 34 ~' i 8.89 A arent Erosion. Sli ht Oval Deformation. 18 699 U. i 2 0.16 38 '~) 8.89 A arent Erosion. Sli ht Oval Deformation. 19 738 tt.16 0.16 38 - 8.89 A arent rosion. Sli ht Oval Deformation. 20 777 1). I "~ 0.17 3~) 8.88 A arent Erosion. Sli ht Oval Deformation. 21 816 0. I .~ 0.17 39 8.84 A arent Erosion. Sli ht Oval Deformation. 22 856 U. 13 0.15 36 _"I 8.89 A arent Erosion. Sli ht Oval Deforrnation. 23 895 U.12 0.15 34 ~i, 8.90 A arent Erosion. 24 934 0.12 0.16 3t3 ~'(, 8.89 A arent Erosion. Sli ht Oval Deformation. 25 973 (?.l ~ 0.16 37 26 8.89 A arent Erosion. Sli ht Oval Deformation. 26 1012 U."12 0.16 38 29 8.83 A arent Erosion. Sli ht Oval Deformation. 27 1051 t). 12 0.16 38 26 8.88 A arent Erosion. Sli ht Oval Deformation. 28 1090 0.12 0.15 ;S ' S 8.89 A arent Erosion. Sli ht Oval Deformation. 29 1 129 U. I 1 0.14 3 ~ ~ 8.87 A arent Erosion. Sli ht Oval Deformation. 30 1169 O. I i 0.15 ,4 ~''i 8.88 A arent Erosion. Sli ht Oval Deformation. 31 1208 i 1.14 0.15 15 _'.5 8.89 A arent Erosion. Sli ht Oval Deformation. 32 1247 O.12 0.16 3i ' ~ 8.88 A arent Erosion. Sli ht Oval Deforrnation. 33 1286 (t. l2 Q17 38 ?LS 8.84 A arent Erosion. Sli ht Oval Deformation. 34 1325 U 14 0.16 37 ?~ 8.86 A arent Erosion. Sli ht Oval Deformation. 35 1364 1t.1 3 0.16 38 ~'!~ 8.88 A arent Erosion. Sli ht Oval Deformation. 36 1403 U. I S 0.16 38 <(> 8.89 A arent Erosion. Sli ht Oval Deformation. 37 1442 U. 12 0.15 3(i 2 5 8.85 A arent Erosion. Sli ht Oval Deformation. - 38 1482 U.1 1 0.13 31 _' S 8.90 A arent Erosion. 39 1520 O.1 ~ 0.13 i 1 "~ 8.92 A arent Erosion. 40 1559 0.1 1 0.15 '~_i ~~4 8.87 A arent Erosion. 41 1598 0.1 1 0.15 36 ,~ 8.85 A arent Erosion. Sli ht Oval Deformation. -- 42 1638 U.12 0.15 34 <`~~ 8.87 A arent Erosion. Sli t Oval Deformation. 43 1677 U. 13 0.15 S6 '~ 8.89 A arent Erosion. Sli ht Oval Deformation. 44 1716 0.1 i 0.15 34 ~' S 8.89 A arent Erosion. - 45 1755 0.1 3 0.15 36 ~'4 8.87 A arent Erosion. Sli ht Oval Deforrnation. 46 1794 0.13 0.15 34 ~'? 8.89 A arent Erosion. Sli ht Oval Deformation. - 47 1833 tl.l 3 0.15 i4 Z3 8.89 A arent Erosion. 48 1873 0.12 0.14 ;~ , s 8.81 A arentErosion. 49 1912 tt.l 1 0.14 , 3 ' s 8.84 A arent Erosion. Sli ht Oval Deforrnation. Penetration Body Metal Loss Body Page 1 ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ,, ~ r ~ ~ ~ PDS Report Cross Sections Well: 2A-12 Survey Date: April 2, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: HY. Yam Cross Section for Joint 8 at depth 314.56 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 24 Tool deviation = 1 ° Finger 31 Penetration = 1.223 ins Mill wear on Bent Pipe 1.22 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 rr r rr r r~ rr ~r r r ^r r rr rr r r rr r rr ~w -- PDS Report Cross Sections Well: 2A-12 Survey Date: April 2, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 iris 36 f J-55 Anal st: HY. Yan Cross Section for Joint 6 at depth 257.04 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 28 Tool deviation = 1 ° Finger 37 Penetration = 1.184 ins Mill wear on Bent Pipe 1.18 ins = 100% Wall Penetration HIGH 51DE = UP • • Cross Sections page 2 Well: Field: Company: Country: 2A-12 Kuparuk Conoco Phillips Alaska, Inc. USA 9.625 ins 36 ppf J-55 PDS Report Cross Sections Survey Date: April 2, 2010 Tool Type: UW MFC 40 Ext. No. 218451 Tool Size: 2.75 No. of Fingers: 40 Analyst: HY. Yang Cross Section for Joint 8 at depth 317.39 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 11 Tool deviation = 1 ° • Finger 13 Radius = 5.058 ins Mill wear on Bent Pipe 89% Cross-sectional Wall Loss HIGH SIDE = UP Cross Sections page 1 ~w ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ Well: Field: Company: Country: 2A-12 Kuparuk Conoco Phillips Alaska, Inc. USA 9.625 ins 36 ppf J-55 PDS Report Cross Sections Survey Date: April 2, 2010 Tool Type: UW MFC 40 Ext. No. 218451 Tool Size: 2.75 No. of Fingers: 40 Analyst: HY. YdnQ Cross Section for Joint 6 at depth 251.3 ft Tool speed = 43 Nominal tD = 8.765 Nominal OD = 9.625 Remaining wall area = 12 Tool deviation = 1 ° • Finger 33 Radius = 5.086 ins Mill wear on Bent Pipe 88% Cross-sectional Wall Loss HIGH SIDE = UP Cross Sections page 2 ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ! ~ ~ ~ ~ ~ ~ PDS Report Cross Sections .~ Well: 2A-12 Survey Date: April 2, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: HY. Yan Cross Section for Joint 6 at depth 264.24 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 15 Tool deviation = 1 ° Finger 23 Projection = -0.258 ~~~~ Milled Bend Minimum I.D. = 8.57 ins. HIGH SIDE = UP ~~ Cross Sections page 3 ~ PDS Report Cross Sections ~. Well: 2A-12 Survey Date: April 2, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: HY. Yan Cross Section for Joint 8 at depth 320.06 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 16 Tool deviation = 1 ° Finger 21 Projection = -0.218 ~~~~ Milled Bend Minimum I.D. = 8.58 ins. HIGH SIDE = UP L_J Cross Sections page 4 I C.OIl0001''lli~~lpS 1A ttributes An le&MD TD ~ -,i.'.,...~ ~~ ~ - ... WNlbore APWWI 501032005800 FlAtl Name WNI alas Intl(°) KUPARUK RIVER UNIT PROD 40 fi3 MD IRI(B) 6,900.00 Ad Bbn IRKB) 7,125.0 I weu one -u-1z vzoi olki i as o4 pM _ _-- Comment N2S (ppm) SSSV: LOCKED OUT 225 Date Arcot on End Date 1!10!2009 Last WO: KB-Grtl IRI 31.01 Rlg Release Dffie 1!19/1986 Ic-Artuel Amotatlon Dep th ) EAtl Dffie Amo[atlon Last Mal By tlDffie Last Tags SLM 6,830.0 10/242009 Rev Reason: Set Catcher on top of WRP Imosbor 2/20/2010 s~a,e inn~o~mr, Casin Strin s .h` c _ - ' String OD String ID Set OepN Set Depth (TVD) Stdng Wt Strr g Casing Description Ilnl Pnl Top pmBl piKB) (DKB) (Ibs/R) Ga tle Stdng TOp Thrtl coNDUCroR, tos ~ CONDUC TOR 16 15.060 0.0 106.0 106.0 62.50 H-00 SURFAC 9 5/8 8.765 0.0 2,860.0 2,793.8 36.00 J-55 SPFETVVLV PRODUC TION 7 6.151 0.0 6.663.0 5.816.1 26.00 J35 1,eos O LINER 5 4.151 6,435.0 7;115.0 6.161.2 18.00 L-80 Tobin Strin s suRFACE, nrdrg Desaiptlon String OD Iinl Stnng ID PM ToP ry1K8) Set Depth CBI Set Depfh ) 181 Stdng WI (Ibs/R) Strin Dratl g e String Tap Thrtl 2eso TUBING 3 1/2 2.867 0.0 6.393.0 5,604.4 9.30 J-55 EUE8rtlAB TUBING 23/8 1.901 6,393.0 6,822.0 5,938.6 4.70 N-80 AB MOD GAS LIFE. Oth I H l A ll J 6,261 er n o e ew el : Tubin Run 8 Retrievable Fish etc. Top Depm ITVDI Top Ind ToP (N(B) (IbCB) (ry Descdptlon Comment Run Date ID pn) 1,806 1.805.5 5.69 SAFETY VLV Camco TRDP-IA-SSA' (Locked Out 9/11/90) 12/28/1995 2.813 P 6,261 5.501.2 38.95 GAS LIFT CAMCOlMMG-211.5/0V/RKl.251/ Comment STA 1 3/25/2006 2.920 eR,saot 6,301 5;532.3 38.72 PBR Baker 3/12/1986 3.000 6,315 5,543.3 38.65 PACKER Baker'FHL' PACKER 3/12/1986 3.000 6,327 5,552.7 38.58 CATCHER 2.71"CATCHER (OAL=88")SET ON TOP OF WRP 11/2010 0.000 FACK[R, 6.375 6,335 5,558.9 38.53 PLUG 3.5" WRP 10/26/2009 0.000 6;354 5,573.8 38.43 PRODUCTION CAMCO/KBUG/1/DMV/BK///Cammenc CLOSED STA2 6/13/1999 2.875 6,390 5,602.0 38.23 NIPPLE AVA BPL ported nipple 3l12I1986 2.750 6.390 5,602.0 38.23 SLEEVE-C Set AVA 2.75" BPI SLEEVE set 11/12/2005 11/12/2005 2.313 cATCNER. 6,az7 6,393 5,604.4 38.21 XO 3!12/1986 2.375 ~ 6,806 5,926.5 40.85 PACKER Baker'DB' PACKER 3/12/1986 3.250 PLUG, s,335 4 ~i~ , // ' 1n 6.818 5,935.6 40.82 NIPPLE Camrn'D' Nipple, NO-GO 3/12/1986 1.813 6.818 5.935.6 40.82 PLUG 1.81" CA-2 PLUG 10/24/2009 0.000 6,821 5,937.8 40.81 SOS Camrn 3/12/1986 1.995 PRODUCTION 6.822 5,938.6 40.81 TTL ELMD ~ 6818' ON SWS PERF 9/5/2005 3/12!1986 1.995 , s.3sa 6.941 6;028.8 40.54 FISH 1 1/2" GLV Lost in Hote 3/30/1989 Pertora tions 8 S lots NIPPLE. 6390 Top ITYD) Blm (7VD) Der1a sLEEVEC, 6 390 I' ToP1~B1 ~1~1 (~~ I~B) Zorc Date (~~•• Type Co mment . 6,734 6.787 5,871.0 5.911.7 C-0. 2A-12 3/12/1986 12.0 IPERF 69 deg. phasing; SOS 3 3!8" Csg Gun 6.820 6,830 5,937.1 5.944.6 A-4, 2A-12 9/32005 6.0 APERF 1-11/16" EJ, 0 deg phase 6,837 6,864 5,949.9 5,970.3 A-3, 2A-12 3/12!1986 6.0 IPERF 60 deg. phasing: SOS 3 3!8" Csg X0, 6 393 Gun PRODUCTIDN ~ 6,663 ) 1 IPERF, 6,734 787 PACKER, 6.806 NIPPLE. 6.818 PLUG, 6,618 -_$ 505, 6 X21 ~ ~_ TTL, 6, 822 --~ - - =-T APERF, -_ 6, 820 830 - (PERF. E, 83]6,864 FISH, 6,941 LINEP. ] 115 TD, 7,125 ~~< PROAerive DiagNOSric SeRVicES, INC. • ~~~ +L.~V To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 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 t"~~` ~~~[? ;~ 4- L~ Fax: (907) 245-8952 °::°~~~,:;:. 1 j Caliper Report 2j 29-Mar-10 2A-12 l~s~r~Cl ,1 qj ~L~ Signed Print Name: • 1 Report / EDE 50-103-20058-00 ~~ ~~~ ~Oi 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 : ~dsancl~oreae@rnernorylog nom WE9sITE : w+~rwi.~aeemoa-vloc~.corra C:1Documerts and Settings\Diane Williams\Desktop\Tiansmit_Conoco.doar • Memory MuitrFnger Gasper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-12 Log Date: March 29, 2010 Field: Kuparuk Log No.: 6788 State: Alaska Run No.: 2 API No.: 50-103-20058-00 Pipet Desc.: 9.625" 36 Ib. J-55 Top Log Intvl1.: Surface Pipet Use: Surtace Casing Bot. Log Intvl1.: 1,921 Ft. (MD) Inspection Type : Buckling & Restriction Inspection COMMENTS This caliper data is correlated to a PDS caliper log dated March 24, 2010. This log was run to assess the condition of the 9.625" surface casing. The caliper recordings indicate bends in the surface casing at -252' to -262', -312' to -317', and 583', with a minimum I.D. of 7.4$" at 261'.No other significant I.D. restrictions are recorded throughout the casing logged. 3-D log plots of the centered and off-center caliper recordings across the logged interval, and a graph illustrating the minimum recorded diameters on a joint-by joint basis are included in this report. The caliper recordings indicate the 9.625" surface casing is in fair condition with respect to corrosive and mechanical damage. Wall penetrations ranging from 28% to 38% wall thickness and cross-sectional wall loss from 24% to 28% metal volume are recorded throughout the casing logged. Recorded damage appears as apparent erosion. This is the second time a PDS caliper has been run in this well and the first time the 9.625" surtace casing has been logged. MAXIMUM RECORDED WALL PENETRATIONS: Apparent Erosion (38%) Jt. 32 @ 1,276 Ft. (MD) Apparent Erosion (38%} Jt. 33 @ 1,291 Ft. (MD) Apparent Erosion (38%) Jt. 25 @ 971 Ft. (MD) Apparent Erosion (37%) Jt. 20 @ 802 Ft. (MD) Apparent Erosion (37%) Jt. 27 @ 1,061 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Apparent Erosion (28%) Jt. 32 @ 1,276 Ft. (MD) Apparent Erosion (28%) Jt. 33 @ 1,291 Ft. (MD) Apparent Erosion (27%) Jt. 34 @ 1,339 Ft. (MD) Apparent Erosion (27%) Jt. 35 @ 1,395 Ft. (MD) Apparent Erosion (27%) Jt. 25 @ 995 Ft. (MD) MAXIMUM RECORDED ID RESTRICTIONS: Bend Minimum I.D. = 7.48" Jt. 6 @ 261 Ft. (MD) Bend Minimum I.D. = 7.75" Jt. 8 @ 312 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. i~ Field Engineer: N. Kesseru & D. Sparks Analyst: C. Waldrop Witness: R. Dolcater ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~ ~i.0 ~ D~~ / g 5 ~ • • PDS Multifinger Caliper 3D Log Plot ~~ ~_.__~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-12 Date : March 29, 2010 Description : Detai- of Centered Caliper Recordings Across Bends Recorded in 9.625" Casing. Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Centered) 1ft:700ft 7.7 9.7 145° 0° 90° 180° 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. / O.D. '.7.7 9.7 0 i i , _ _ I Pup Jt. _-__- - : ; Joint 1 - ---~- _ Slight Oval Deformation 50 --~ ~ 1 _ - • Joint 2 10 i 0 - - . i Joint 3 i ~ Joint 4 Slight Oval 150 ,~ ~, ,_ Deformation _ Joint 5 200 .- .. ~; -_ , Joint 6 Bend ~ F° Min.1.D. = 7.48" 250 ~~ ,, ~ ~• ~~ ~,.,,~.,,~ ,-_~ Joint 7 Slight Oval Deformation ~ . _ _ i i ~ ~ ..r - = - ~._ ... _ _ . - _, 300 ~ _ Joint 8 Bend Min. LD. = 7.75" -- _, -. _ -~ ; <~ _ ~• I i Joint 9 Slight Oval Deformation 350 a .-~ ~¢ : Joint 10 400 . :_ C~ Joint 11 ~ ' ~' m 450 - -: j - Joint 12 ~ _ . ~ ~ y '` ~:~ ~~ ~ . ~~ 500 ~ ~ . Joint 13 . - _. -. -.-k! ~z _ f ~~ . z t 14 J i o n 550 a ' Slight Oval ~ Deformation i ~ Joint 15 Bend Min. LD. = 8.87" 600 Joint 16 Slight Oval Deformation I + I ~ 650 ~ Joint 17 Slight Oval Deformation _ i _ _ _ '' I ~ - ~ i, i ~ I I Joint 18 ht O l Sli 700 - _..z . ...,._., .: -. . , ,,. va g Deformation ! _j Joint 19 _ II Slight Oval Deformation 750 S 4. _ _ ' Joint 20 Slight Oval - Deformation 800 - - ~ Joint 21 I (-~ I ~ _ ~;~ I Slight Oval Deformation I I Joint 22 Slight Oval Deformation 850 - - :_ _ , ~- - _ I ~ ~~ I I Joint 23 900 ~ ~ Joint 24 I ~ Slight Oval Deformation 950 g Joint 25 Slight Oval D f ti I ,p § I e orma on ~ QQQ - _ ... - I t Slight Oval ~ hf Deformation - - - i `'-~,,`°'.. Joint 27 1050 - Slight Oval - Deformation Joint 2s 1100 Slight Oval Deformafion Joint 29 --_ : slight oval Deformation 1150 Joint 30 Slight Oval ~'` Deformation 4 1200 ' Joint 31 ° _ j ~ i ~ i Slight Oval ~~ Deformation ~ i ,. _, . _i _ 1250 : Joint 32 , ~ Slight Oval ;- ~' ~. Deformation J t 33 i -- o n Slight Oval 1300 Deformation - Joint 34 - ~ Slight Oval Deformation 1350 Joint 35 ~ ' : Slight Oval _ __ ~ Deformation - ' '' 1400 Joint 36 _ ~_ Slight Oval - Deformation Joint 37 1450 _ - Slight Oval - Deformation Joint 3s f _ Light Deposits 1500 ~_ Joint 39 - ----~ ~ : - - r 1550 7 ~ ~ - _ Joint 40 Light Deposits ~ ~f ~ ~ ;- 2 - ,~_ ' i .... .. , 7 ,^ I 1 Slight Oval Deformation. Light Deposits Joint 42 ' _ ~ `~`~ Slight Oval 1650 "", ~$'~:? u_„ , ' Deformation ~ ~~~' ~•-s z~ r_ t 43 J i ~ 1 'a `~ x ~ '' o n - ~ a 'rR'~-: ~~ ~ ~ %` Slight Oval - a ~~~Z - z ~M1' ~ w - * Deformation 1700 , J i t 44 o n ' ' 1750 • Joint 46 ~. c ~ c _~_ Slight Oval ~ Deformation - Joint 46 0 _ I Slight Oval 180 i I _ Deformation. i - - . Light Deposits ~ + _ ~ : - Joint 47 ~ _ Deposits Min. LD. = 8.33" 1850 ' .. . Joint 48 1 - .. __ - _. ..; Light Deposits _ ~ - I I 1900 ~ I _ _ .._ Joint 49 , , I r ~ _ . _ I 7" Production _ _ _ _ ~ -~ ' ~y~ ~ Casing Stub ~ ; ~ I I Nominal LD. / O.D. 7.7 9.7 Min. LD. (ins.) ~ 7.7 9.7 Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Centered) ___...._ ~ 1ft:700ft ~ 9.7 145° 0° 90° 180° 270° 0° 7.7 • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-12 Date : March 29, 2010 Description : Detail of Off-Center Caliper Recordings Across Bends Recorded in 9.625" Casing. Comments Depth Max. I.D. (ins.) 3-D Log Image Map (Off-Center) 1ft:700ft ~ 7.7 9.7 282° 0° 90° 180°f ~' 270° 0° Min. I.D. (ins.) 7.7 9.7 Nominal I.D. / O.D. 7.7 9.7 0 ~ . ;_ , '. Pup Jt. Joint 1 50 Slight Oval Deformation Joint 2 100 Joint 3 Joint 4 Slight Oval Deformation 150 _~ Joint 5 200 Joint 6 Bend 250 Min. I.D. = 7.48" Joint 7 Slight Oval Deformation 300 Joint 8 Bend Min. I.D. = 7.75" _, Joint 9 Slight Oval 350 - Deformation ~ Joint 10 400 ~ :_;-__ _~~-., ~, 'q ~.. I . <..~ ~ ~V •... ~ 4 _, ... _. . .. ., „fi-~~.. _ ' ~~ur ~.~ : ~ I ~~ J_ • Slight Oval Deformation. Light Deposits Joint 42 1650 Slight oval Deformation Joint 43 Slight Oval 1700 Deformation Joint 44 --~ 1750 Joint 45 Slight Oval Deformation Joint 4s 1 00 Slight Oval 8 Deformation. Light Deposits -~ Joint 47 Deposits 85 Min. I.D. = 8.33" 1 0 Joint 48 Light Deposits 1900 Joint 49 7" Production Casing Stub Nominal I.D. / O.D. :.....................................................................: 7.7 9.7 Min. I.D. (ins.) 7.7 9.7 Comments Depth Max. I.D. (ins.) 3-0 Log Image Map (Off-Center) 1ft:700ft 7.7 9.7 282° 0° 90° 180° 270° 0° • • Correlation of Recorded Damage to Borehole Profile Pipe 1 9.625 in (30.4' - 1921.3') Well: 2A-12 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: March 29, 2010 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 35 6 229 12 463 1 t3 696 ~ 24 931 ~ .S Z t c °- v o p 3t1 1164 36 1398 4"~ 1632 4H 1866 49.1 1921 0 5 0 1 00 Dar nage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 49.1 • • ~r.ti Minimum Diameter Profile Well: 2A-12 Survey Date: March 29, 2010 Field: Kuparuk Tool: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA Tubing I.D.: 8.765 inches • • PDS Report Overview L-~.. ~ S,. Body Region Analysis We-I: 2A-12 Survey Date: March 29, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 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. 9.625 ins 36 f -55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body -.- metal loss body 60 50 40 30 20 10 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 50 pene. 0 0 0 50 0 0 loss 0 0 0 50 0 0 Damage Configuration (body ) 60 50 40 30 20 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of'oints dame ed total = 50 0 50 0 0 0 Damage Profile (% wall) -penetration body rnetal loss body 0 50 100 0 10 20 I - 30 40 -- Bottom of Survey = 49.1 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2A-12 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 8.765 in Country: USA Survey Date: March 29, 2010 Joint No. Jt. Depth (Ft) I'c~n. lllrsc~t (Ins.) Pen. Body (Ins.) Pen. % Mc~rrl Ions °,4> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 30 0. i 2 0.12 2c) 14 8.94 PUPA arentErosion. 1 35 U. I I 0.14 3_' _' i 8.92 A anent Erosion. Sli ht Oval Deformation. 2 74 0.1 1 0.13 3i) ? 5 8.91 A anent Erosion. - 3 113 tt. I I 0.12 ~'t3 '3 8.87 A anent Erosion. 4 152 (1.12 0.14 s_' 8.88 A anent Erosion. Sli ht Oval Deformation. 5 191 U.12 0.14 32 '(~ $.93 A anent Erosion. - - - 6 229 U.13 0.13 31 ?C~ 7.48 Bend. A anent Erosion. - - - 7 268 0.12 0.14 33 2;' 8.93 A~ anent Erosion. Sli ht Oval Deformation. 8 307 U.1 1 0.15 34 25 7.75 Bend. A anent Erosion. 9 346 U.12 0.15 36 ~(~ 8.89 A anent Erosion. Sli ht Oval Deformation. 10 385 0.1 1 0.15 34 2b 8.93 A anent Erosion. 11 424 U.11 0.13 31 2 ; 8.92 A anent Erosion. 1 463 tl.ll 0.14 32 2L 8.92 A anent Erosion. 13 502 0.12 0.13 31 _' i ~ 8.93 A anent Erosion. - 14 541 11.11 0.16 3i ~(, 8.87 A anent Erosion. Sli ht Oval Deformation. 15 580 U.14 0.14 32 ''~ 8.87 Bend. A anent Erosion. 16 618 U. I Z 0.16 3;' - 8.90 A anent Erosion. Sli ht Oval Deformation. 17 657 0.13 0.15 3-1 ~'r 8.92 A anent Erosion. Sli ht Oval Deformation. 18 696 U. 1 I 0.16 36 i~ 8.92 A anent Erosion. Sli ht Oval Deformation. - 19 735 0.1 ~ 0.16 36 _'!, 8.90 A anent Erosion. Sli ht Oval Deformation. 20 774 0.1 _' 0.16 37 ~' ~ 8.92 A anent Erosion. Sli ht Oval Deformation. 21 813 n. I ~ 0.16 37 _'> 8.87 A anent Erosion. Sli ht Oval Deformation. 22 852 ~ t.12 0.15 3E~ -'t~ 8.85 A anent Erosion. Sli ht Oval Deformation. 23 892 i?. i 2 0.14 33 '(~ 8.93 A anent Erosion. 24 931 (a. I I 0.16 3~ '" 8.90 A anent Erosion. Sli ht Oval Deformation. 25 969 i.. I ; 0.16 3t3 - 8.90 A anent Erosion. Sli ht Oval Deformation. 26 1008 il. 13 0.16 3G 8.84 A anent Erosion. Sli ht Oval Deformation. 27 1047 11.12 0.16 37 ~' 7 8.88 A anent Erosion. Sli ht Oval Deformation. 28 1086 tl_ 12 0.15 35 '(~ 8.92 A anent Erosion. Sli ht Oval Deformation. 29 1 125 0. I ? 0.15 35 L5 8.88 A anent Erosion. Sli ht Oval Deformation. 30 1 164 C?.1 ~ 0.15 s6 8.88 A anent Erosion. Sli ht Oval Deformation. - 31 1203 (t.13 0.15 35 ~(~ 8.90 A anent Erosion. Sli ht Oval Deformation. 32 1242 0.1 ~ 0.16 38 't; 8.88 A anent Erosion. Sli ht Oval Deformation. 33 1281 O.1 Z 0.16 3t3 2~5 8.84 A anent Erosion. Sli ht Oval Deformation. 34 1320 O. I ~ 0.16 ;7 ' ° 8.87 A anent Erosion. Sli ht Oval Deformation. 35 1359 (1. 13 0.16 i(i _'-' 8.88 A anent Erosion. Sli ht Oval Deformation. 36 1398 U. 15 0.16 3; - 8.88 A anent Erosion. Sli ht Oval Deformation. - 37 1437 0.12 0.16 37 '(, 8.88 A anent Erosion. Sli ht Oval Deformation. 38 1476 U_12 0.14 33 _'(, 8.76 A anent Erosion. Lt. De osits. 39 1514 U.12 0.14 13 '(, 8.93 A anent Erosion. 40 1553 0.11 0.15 i4 'S 8.72 A anent Erosion. Lt. De osits. 41 1592 0.12 0.15 35 2G 8.79 A .Erosion. SI. Oval Deformation. Lt. De osit_ - 42 1632 0."14 0.16 36 2(~ 8.89 A anent Erosion. Sli ht Oval Deformation. 43 1671 1).13 0.15 36 2V 8.84 A anent Erosion. Sli ht Oval Deformation. 44 1710 U. 13 0.15 35 2U 8.89 A anent Erosion. 45 1749 0.12 0.15 3~ _' S 8.81 A anent Erosion. Sli ht Oval Deformation. 46 1788 U. 13 0.15 36 '(~ 8.71 A .Erosion. SI. Oval Deformation. Lt De osit_ 47 1827 U. 13 0.15 3S _'-1 8.33 A anent Erosion. De osits. - 48 1866 U.1 ~ 0.14 >3 ~' ~~ 8.63 A anent Erosion. Lt De osits. - 49 1905 U.12 0.15 ;5 !(, 8.90 A anent Erosion. Sli ht Oval Deformation. _ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2A-12 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: ConocoPhillips Alaska, Inc. !Nominal I.D.: 8.765 in Country: USA Survey Date: March 29, 2010 Joint Jt. Depth I'~~n. Pen. Pen. ~1c~i.il Min. Damage Profile No. (Ft.) UE~set Body % I cuss LD• Comments (%wall) (Ins.) (Ins.) ",~ (Ins.) 0 50 100 49.1 1921 U 0 0 U N A To of 7" Production Casin __ Penetration body Metal Loss Body Page 2 -- PDS Report Cross Sections Well: 2A-12 Survey Date: March 29, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: C. Waldro Cross Section for Joint 32 at depth 1276.3 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 72 Tool deviation = 2 ° Finger 40 Penetration = 0.164 ins Apparent Erosion 0.16 ins = 38% Wall Penetration / 28% Cross-Sectional Wall Loss HIGH SIDE = UP • • Cross Sections page 1 -- PDS Report Cross Sections Well: 2A-12 Survey Date: March 29, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: C. Waldro Cross Section for Joint 33 at depth 1291.4 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 72 Tool deviation = 2 ° Finger 38 Penetration = 0.174 ins Apparent Erosion 0.16 ins = 38% Wall Penetration / 28%Cross-Sectional Wall Loss HIGH SIDE = UP r1 LJ Cross Sections page 2 ~ ! ~ ~ ~ ~ ~ ~ ~ i ~ i~ ~ ~ ~ r ~ ! ~ ~-= PDS Report Cross Sections ~~, ~ ,,.,v - -- Well: 2A-12 Survey Date: March 29, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 irrs 36 f J-55 Anal st: C. Waldrop Cross Section for Joint 6 at depth 261.36 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 98 Tool deviation = 2 ° Finger 40 Projection = -0.984 ins Bend Minimum I.D. = 7.48 ins HIGH SIDE = UP • Cross Sections ~~age 3 ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~ ~ ~~ Well: 2A-12 Survey Date: March 29, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: C. Waldro Cross Section for Joint 8 at depth 311.77 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 97 Tool deviation = 1 ° Finger 26 Projection = -0.906 ins Bend Minimum I.D. = 7.75 ins HIGH SIDE = UP i • Cross Sections page 4 ..- ~~ ~ KUP ~ 2A-12 ConocoPhillips ` Vl~llttributes M le & MD TD ~~~'"~-' ~~" W¢Ilbore APWWI Field Name WellSntus Inc!(°) MD (flKB) Act Bim (flK8) 501032D05800 KUPARUK RIVER UNIT PROD 40.63 6,900.00 7,125.0 Comment H25 (ppm) Date Annotation End Dato KB-Grd (ft) Rig Release Date wet cmn:-zA-1z lvErzo os6zE o9 AM SSSV: LOCKEDOUT 225 1/10!2009 Last WO: 31.01 1/19/1986 Stliematic- Adu al Annotation DepM (ftK8) End Date Annotation Lesl Mod By Entl Date Last Tag: SLM 6.830.0 10/24!2009 Rev Reason: Cancel Well Waiver Imosbor 11/3/2009 wale lnnibno<. Casin Strin s ' SMng OD String 10 Set Dvpm Set Oep[h (TVD) String Wt String 1 Casing Descripton (in) (in) lop (f[KB) (ftKe) (ftKB) (Ibs/ft) Grade Stri Top Thrd coNO(1croR, toe CONDUCTOR 16 15.060 0.0 106.0 106.0 62.50 H~tO ii SURFACE 9 5/8 8.765 0.0 2,860.0 2.793.8 36.00 J-55 _ _ PRODUCTION 7 6.151 0.0 6,663.0 5,816.1 26.00 J-55 s^~T~v'LV~ LINER 5 4 151 6 435 0 7 115 0 6 161 2 18 00 L-80 1,806 0 . , . , . , . . Tubin Strin s String OD String ID Set Depth Set DepN (TVD7 String Wt String Tubin Descd lion (in) lin) Top (ftKB) (ftKe) (ftKB) (Ibslft) Gratl¢ Strin To Thrd suRFACE 2860 TUBING 3 112 2.867 0.0 6.393.0 5,604.4 9.30 J-55 EUESrdAB TUBING 23/8 1.901 6,393.0 6,822.0 5.938.6 4.70 N-80 AB MOD Gns uFT, Other I n Hole A ll Jew el :Tubin Run & Retrievable Fish etc. 6261 Top Deptl1 (ND) Top Intl Top (KKB) (BKB) (°) Description Comment Run Date ID (in) 1,806 1,805.5 5.69 SAFETY VLV Camco TRDP-IA-SSA' (LOdced Out 9/11/90) 12/28!1995 2.813 6,261 5,501.2 38.95 GAS LIFT CAMCO/MMG-2/1.5/OV/RIU.25// C(xnment: STA 1 3/25/2006 2.920 PaR,s3o1 Q301 5,532.3 38.72 PBR Baker 3/12/1986 3.000 6.315 5.543.3 38.65 PACKER Baker'FHL' PACKER 3/12/1986 3.000 6,335 5,558.9 38.53 PLUG 3.5" WRP 10/26/2009 0.000 e 4 6,354 5,573.8 38.43 PRODUCTION CAMCO/KBUG/l/DMY/BfV//Comment CLOSED STA2 6!13!1999 2.875 PACKER, x,315 ; t 6.390 5,602.0 38.23 NIPPLE AVA BPL posed nipple 3/12/1986 2.750 6,390 5,602.0 38.23 SLEEVE-C Set AVA 2.75" BPI SLEEVE set 11/12/2005 11/12/2005 2.313 6,393 5,604.4 38.21 XO 3/12/1986 2.375 6,806 5,926.5 40.85 PACKER Baker'DB' PACKER 3/1217986 3.250 PLUG, 6,335 6,818 5,935.6 40.82 NIPPLE Camco'D' Nipple, NO-GO 3/12!1986 1.813 6,818 5,935.6 40.82 PLUG 1.81" CA-2 PLUG 10/24/2009 0.000 6,821 5,937.8 40.81 SOS Camm 3/17/1986 1.995 PROOt1CTION, 6,822 5,938.6 40.A1 TTL ELMD @ 6818' ON SWS PERF 915/2005 3/12/1986 1.995 s,asa 6,941 6,028.8 40.54 FISH 1 1/2" GLV Lost in Hole 3/30/1989 Perforations & S lots NIPPLE, 8.390 Top (ND) Bbn (ND) sna Dens SLEEVEL, - 6 3.w " Top (flKB) Bhg (flKe) (ftKB) (ftKBI Znn¢ Dale (sA... TYPe Commetd , 6,734 6,787 5,871.0 5,911.7 C-0, 2A-12 3!1211986 12.0 IPERF 69 de g. phasing; SOS 3 3/8" Csg Gun 6,820 6,830 5,937.1 5,944.6 A<, 2A-12 9/3!2005 6.0 APERF 1-11/16" EJ, 0 deg phase 6,837 6,864 5,949.9 5,970.3 A-3, 2A-12 3!12/1986 6.0 (PERF 60 deg. phasing; SOS 3 3/8" Csg xo, 6a93 Gun Notes: General & Entl Date Annotation 3126/2006 NOT E: TBG PERFS for POGLMs Qa 2686', 4476', 5612' PROOUCrION. 6.663 IPERF 6,7346,787 1 F PACKER, 8,806 s NIPPIJ=. 6.818 PLUG, 6,818 805,6,821 _- ~ ~ -2 ~_ . .~.- L".::- TTL, 8,822 APERF, 6,8206.830 IPERF, 6.8376.86E FISH, 6,941 LINER, ],115 lD, ],125 . ~ ~~~ PeoAcmre DiayNOSric SeavicES, INC. • ~~` L~V To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 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 99518 Fax: (907) 245-8952 1) Caliper Report 24-Mar-10 2A-12 1 Report / EDE 2J ~~~..t!~i~~~ ~ ~ ~ ~ G' 2 ~ r C~ 1~ ~ -~~ l ~~~~ Signed Print Name: • 50-103-20058-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : I~dsaroc~aorag~Ct~merraorVlog.com WEBSITE : urxvn+.rnemorViog.com C:\Documents and Settings\Diane WilliamstDesktop\Transmit_Conoco.docx ~~ r i Memory Multi-Finger Caliper Log Results. Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-12 Log. Date: March 24, 2010 Field: Kuparuk Log No.: 6787 State: Alaska Run No.: 1 API No.: 50-103-20058-00 Pipet Desc.: 7" 26 Ib. J-55 Top Log intvl1.: Surface Pipet Use: Production Casing Bot. Log Intvl1.: 6,278 Ft. (MD) ' Inspection Type : Buckling 8 Restriction Inspection COMMENTS This caliper data is tied into the Baker PBR @ 6,301' (Driller's Depth). This log was run to assess the condition of the 7" production casing. The caliper recordings indicate bends ' in the production casing at 285' to 300' and 345' to -355', with no significant I.D. restrictions recorded throughout the production casing logged. Log plots of the centered and off-center caliper recordings across these bends are included in this report. ' The caliper recordings indicate the 7" production casing logged is in good to fair condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 24% recorded at an isolated pit in joint 104 (4,495'). Other recorded damage appears as apparent wear and shallow corrosion. No significant ~ areas of cross-sectional wall loss are recorded throughout the production casing logged. MAXIMUM RECORDED WALL PENETRATIONS: Isolated pitting (24%) Jt. 104 @ 4,495 Ft. (MD) Apparent Wear (24%) Jt. 134 @ 5,790 Ft. (MD) Apparent Wear (22%) Jt. 6 @ 287 Ft. (MD) Apparent Wear (22%) Jt. 11 @ 486 Ft. (MD) Apparent Wear (22%) Jt. 41 @ 1,763 Ft. (MD} MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 14%) are recorded throughout the production casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.p. restrictions are recorded throughout the production casing logged. Field Engineer: N. Kesseru Analyst: C. Waldrop Witness: R. Dolcater ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-90$5 Fax: (281) 565-1369 E-mail: PDSCa!memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot ~~ ~" Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-12 Date : March 24, 2010 Description : Detail of Centered Caliper Recordings Across Bends Recorded in 7" Casing. Comments Depth M ax. Pen. (%) Max. I.D. (ins.) 3-D Log (Centered) Image Map (Centered) 1ft:800ft 0 100 6 7 11° 0° 90° 180° 270° 0°' Min. LD. (ins.) 6 7 Nominal LD. (ins.) r 6 7 Tree 50 i F~ x,. Joint 1 _ ':_- _- -, ~__ l_ ~ .' •.}^ 100 Joint 2 Apparent Wear ' i ' _ "~ . 20°k Wall Pen. j _ ~ . _ 150 .- Joint 3 I ~I _, ~ ~. - ~ Joirrt 4 200 i ` a I r ~ ~ ~ 20°k W Pen ~ i - '~ - -~' ~-~ I I `~`-~ Joint 5 '' Apparent Wear 250 i 20% Wall Pen. j i Joint 6 ~". Bend I I i .. Min. LD. = 6.25 i ' ' ~ Apparent Wear 300 22°~ Wall Pen. I Joint 7 Bend Mi LD = 6 27" I n. . . - Apparent Wear i I ~ 20% wall Pen. 350 ' I i Joint 8 ~~ I-- 400 Joint 9 Apparent Wear ' °~ 21 % Wall Pen. --' _`- _ ,i'`_ 450 Joint 10 Apparent Wear _ _ 20% Wall Pen. ~ - - -- Joint 11 ~ I • PDS Multifinger Caliper 3D Log Plot ~°~__. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-12 Date : March 24, 2010 Description : Detail of Off-Center Caliper Recordings Across Bends Recorded in 7" Casing. • Correlation of Recorded Daman Pipe 1 7. in (63.9' - 6278.1') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 2A-12 Kuparuk ConocoPhillips Alaska, Inc. USA March 24, 2010 A pprox. Tool De viation ~ A pprox. Boreho le Profil e 1 1C 64 444 20 860 30 1291 40 1721 50 I 2150 60 2584 p ~ v ~ 7U 'x 3010 u ~ ~ Z t 0 80 3445 ~ 90 ~ ~ 3863 100 ! 4300 110 ,, ~ ~ 4728 120 ., Y 5157 130 54 5590 14U I ~ I 6018 146.1 62 78 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 146.1 • PDS Report Overview ~~,--ll- ~,.. Body Region Analysis Well: 2A-12 Survey Date: March 24, 2010 Field: Kuparuk Tool Type; UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: U5A 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 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 = 146 pene. 0 0 135 11 0 0 loss 0 137 9 0 0 0 Damage Configuration (body ) 150 100 50 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ihlehole Number of ~oints dama ed total = 146 1 19 126 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 1 51 .- 101 - Bottom of Survey = 146.1 Analysis Overview page 2 • PDS REPORT JOINT TABS 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 SHEEP 2 A-12 Kuparuk Conoco Phillips Alaska, Inc. USA March 24, 2010 Joint No. Jt. Depth (Ft.) I'en. Ut~set (Ins.) Pen. Body (Ins.) Pen. % Metal loss °,a Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 64 U.U6 0.07 19 i i 6.29 Shallow A arent Wear. 2 103 O 0.07 20 11 6.28 _ A arentWear. 3 147 O 0.06 17 1(? 6.28 Shallow A arent Wear. 4 190 t? 0.07 20 1 i) 6.29 A arentWear. 5 234 U 0.07 20 li? 6.29 A arentWear. 6 275 O.U(~ 0.08 22 I ~ 6.25 Bend. A arentWear. 7 319 U.U(~ 0.07 20 I t 6.27 Bend. A arent Wear. I 8 361 U.UC~ 0.07 19 1 1 6.29 Shallow A arent Wear. ' 9 403 ~).t)b 0.08 21 9 6.29 A arent Wear. 10 444 l) 0.07 ZO 1 U 6.30 A arentWear. 11 484 I1.U7 0.08 22 1 U 6.29 A arent Wear. 12 527 t).t)5 0.06 18 1 U 6.29 Shallow A arent Wear. 13 570 t).O6 0.07 19 1 ) 6.29 Shallow A arent Wear. 14 610 U 0.07 l0 1 C) 6.29 A arent Wear. 15 651 c) 0.07 19 ') 6.27 Shallow A areal Wear. 16 694 U 0.06 17 ') 6.29 Shallow A arent Wear. 17 733 U.US 0.06 17 6.29 Shallow A arent Wear. 18 776 U 0.07 19 I i? 6.29 Shallow A arent Wear. 19 817 U.U~~ 0.06 17 I it 6.28 Shallow A arent Wear. 20 860 l) 0. 7 2U I ~..) 6.28 _ A arentWear. 21 901 l).t)_i 0.07 1 ~) I t? 6.29 Shallow A areal Wear. 22 945 (1 0.07 19 '~ 6.25 Shallow A arent Wear. 23 989 U 0.06 17 . ~) 6.29 Shallow A arent Wear. 24 1032 U.t)6 0.08 21 I r~ 6.28 A arent Wear. 25 1075 U.l)6 0.07 20 IU 6.30 A arentWear. ~•. 26 1117 U.t)6 0.07 18 { U 6.29 Shallow A areal Wear. 27 1161 0.O6 0.06 17 1 U 6.29 Shallow A arentWear. 28 1204 O.O6 0.07 19 1(1 6.26 Shallow A arent Wear. 29 1248 U.Ub 0.07 19 1 1 6.30 Shallow A arent Wear. 30 1291 (LO6 0.07 19 i ~! 6.29 Shallow A arent Wear. _ 31 1334 l) 0.07 20 f9 6.25 A arent Wear. 32 1378 U.U(~ 0.07 19 ~) 6.27 Shallow A arent Wear. 33 1420 U 0.06 ! 7 ') 6.27 Shallow A arent Wear. 34 1464 U.US 0.06 1 r, ') 6.28 Shallow A arent Wear. 35 1506 U.US 0.07 19 1O 6.29 Shallow A arent Wear. 36 1549 t?.U5 0.06 1 b 10 6.29 Shallow A arent Wear. 37 1592 tt 0.07 19 ~> 6.25 Shallow A arent Wear. 38 1635 U 0.08 2 I ~? 6.28 A arent Wear. 39 1678 !) 0.06 17 'i 6.27 ShallowA arentWear. 40 1721 r).t)~ 0.07 2O lU 6.28 A arentWear. 41 1763 1).117 0.08 22 I ~ i 6.28 A arent Wear. 42 1805 U 0.06 17 '+ 6.27 Shallow A arentWear. 43 1848 O 0.06 17 't 6.26 Shallow A arent Wear. 44 1891 (J.t)b 0.07 18 ~) 6.27 Shallow A arent Wear. 45 1935 l).0 i 0.07 1 ~) 1 1 6.30 Shallow A arent Wear. 4 1978 (a 0.06 16 8 6.28 Shallow A areal Wear. 47 2021 O 0.06 1 7 8 6.26 Shallow A arent Wear. 48 2065 U 0.06 18 9 6.29 Shallow A arent Wear. 49 2107 t?.(-)(~ 0.07 1 ~) 9 6.28 Shallow A arent Wear. 50 2150 U.(15 0.06 17 '> 6.27 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: ELATION SHEET 2 A-12 Kuparuk ConocoPhillips Alaska, Inc USA March 24, 2010 Joint No. Jl. Depth (Ft.) Pc~n. llh,et (lns.) Pen. Body (Ins.) Pen. °~ Metal lost "-<~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 2194 t).05 0.06 17 ~~ 6.28 Shallow A arentWear. 52 2237 t).U5 0.08 2~ ~) 6.29 A arent Wear. 53 2280 U.US 0.05 15 fi 6.28 Shallow A arent Wear. 54 2323 a 0.06 16 ~~ 6.29 Shallow A arent Wear. 55 2367 U 0.06 1' i9 6.26 Shallow A arent Wear. 56 2410 t) 0.05 I -1 6.26 Shallow A arent Wear. 57 2454 U 0.07 1U i 6.26 A arent Wear. 58 2498 U 0.05 13 - 6.25 Shallow corrosion. 59 2541 0 0.06 16 ii 6.28 Shallow corrosion. 60 2584 0 0.05 i 5 t3 6.29 Shallow corrosion. 61 2627 t) 0.05 14 7 6.26 Shallow A arent Wear. 62 2670 t) 0.05 14 - 6.25 Shallow A arent Wear. - 63 2714 U.O 5 0.07 18 6.27 Shallow A arent Wear. 64 2757 t? 0.06 15 ti 6.26 Shallow A arentWear. - 65 2800 U 0.06 16 ~> 6.28 Shallow A arent Wcar. - 66 2843 0 0.05 13 - 6.27 Shallow A arent Wear. 67 2883 U 0.05 13 6.28 Shallow A arent Wear. 68 2926 U 0.05 15 t3 6.28 Shallow corrosion. 69 2968 0.0(i 0.08 21 ~> 6.27 A arentWear. 70 3010 U 0.05 13 (~ 6.25 Shallow corrosion. 71 3054 U 0.05 15 6.23 Shallow corrosion. 72 3097 U 0.05 1 3 5 6.25 Shallow corrosion. 73 3140 U 0.07 1 ~) ~) 6.28 Shallow A arent Wear. 74 3183 t).O(i 0.06 1 7 ~~ 6.28 Shallow A arent Wear. 75 3227 ~).t)6 0.07 i~~ !, 6.27 ShallowA arentWear. 76 3270 '?.i)5 0.06 1 ~s 6.28 Shallow A arent Wear. 77 3314 U 0.07 1') ~; 6.25 Shallow A arent Wear. 78 3358 U 0.07 1 ti . s 6.23 Shallow A arent Wear. 79 3402 t? 0.06 ! (i tr 6.28 Shallow A arent Wear. 80 3445 0 0.07 18 7 6.25 Shallow A arent Wear. 81 3489 (?.06 0.08 Z 1 9 6.27 A arent Wear. 82 3532 O.U6 0.07 1 t3 t? 6.25 Shallow A arent Wear. 83 3576 U.05 0.07 19 ~~ 6.29 Shallow A arentWear. 84 3613 U 0.05 15 ti 6.28 Shallow corrosion. 85 3656 0.06 0.06 16 ii 6.28 Shallow corrosion. 86 3696 O.UG 0.07 19 ~) 6.28 Shallow A arent Wear. 87 3739 U 0.07 2(1 8 6.25 Shallow corrosion. 88 3783 0.05 0.06 17 10 6.28 Shallow corrosion. 89 3825 i) 0.05 13 !, 6.27 Shallow A arent Wear. - 90 3863 t) 0.06 15 t, 6.25 Shallow A arent Wear. 91 3907 t).U6 0.06 1 i ~> 6.27 Shallow A arent Wear. 92 3951 O.U6 0.07 19 9 6.23 A arent Wear. - 93 3995 U.U6 0.06 17 7 6.24 Shallow A arent Wear. - 94 4039 O.OG 0.06 17 1 U 6.29 Shallow A arent Wear. 95 4082 0.06 0.07 1 ~) 10 6.28 Shallow A arentWear. 96 4124 O.O5 0.06 i 7 t! 6.27 Shallow A arent Wear. 97 4168 !? 0.06 17 r; 6.27 Shallow A arent Wear. 98 4212 t) 0.06 1 7 ti 6.29 Shallow corrosion. 99 4256 ~ ! 0.05 ' 'i ~ 6.25 Shallow corrosion. - 100 4300 !? ~' 0.06 - i 6.25 Shallow corrosion. - _ Penetration Body lvletal Loss Body 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 )CATION SHEET 2 A-12 Kuparuk ConocoPhillips Alaska, Inc USA March 24, 2010 Joint No. Jt. Depth (Ft.) Ne~n. Ul~x~i (Ins.) Pen. Body (Ins.) I'en. ~ Mel.~l less °-~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 4343 U 0.06 1 7 i 6.25 Shallow corrosion. 102 4381 U 0.05 15 i 6.25 Shallow A agent Wear. 103 4424 U 0.05 1 £i 6.27 Shallow A agent Wear. 104 4468 O.i)(, 0.09 24 Itr 6.29 Isolated ittin . 105 4512 ! t 0.06 1 5 6.25 Shallow A agent Wear. 106 4556 U_Ob 0.06 17 c 6.25 Shallow A agent Wear. 107 4598 U.06 0.06 1 b '~ 6.25 Shallow A agent Wear. 108 4641 U.t_)5 0.07 1l) 6.28 A agent Wear. _ 109 4685 U.Oi 0.07 19 ~i 6.26 Shallow A agent Wear. 110 4728 U 0.06 16 i 6.24 Shallow A agent Wear. 111 4771 l).U5 0.07 18 8 6.28 Shallow A agent Wear. 1 12 4814 t) 0.06 16 6 6.25 Shallow A agent Wear. 113 4858 t) 0.07 1 cs ~ 6.24 Shallow A agent Wear. 1 14 4900 U 0.06 I ~ - 6.24 Shallow A agent Wear. 115 4940 t) 0.05 13 ~1 6.21 Shallow A areni Wear. 1 16 4984 t?.t1t, 0.07 19 ~) 6.25 Shallow A agent Wear. 1 17 5026 U 0.07 18 7 6.24 Shallow A agent Wear. 118 5070 U 0.07 2U 6.24 A agent Wear. 119 51 13 U.05 0.06 16 i? 6.25 Shallow A agent Wear. 120 5157 0 0.05 14 i 6.23 Shallow A agent Wear. 121 5199 0 0.07 20 t~ 6.27 A agent Wear. 122 5242 U 0.06 16 - 6.26 Shallow corrosion. 123 5285 O 0.07 19 )i 6.23 Shallow A agent Wear. 124 5330 CLUS 0.06 1 G - 6.27 Shallow A agent Wear. 125 5374 ;) 0.06 i ~ 5 6.24 Shallow A agent Wear. 126 5417 t) 0.07 2t1 - 6.24 A agent Wear. 127 5460 U 0.06 i S 6.26 Shallow A agent Wear. 128 5504 0.0> 0.07 1 ~) ~) 6.27 Shallow A agent Wear. 129 5547 U.05 0.06 17 9 6.27 Shallow A agent Wear. 130 5590 0 0.06 16 6 6.21 Shallow A agent Wear. 131 5634 U 0.05 14 5 6.23 Shallow A agent Wear. 132 5679 0 0.06 16 7 6.27 Shallow A agent Wear. 133 5723 0.05 0.06 16 ~ 6.27 Shallow A agent Wear. 134 5762 i) 0.09 ?4 6.25 A agent Wear. 135 5805 0 0.05 14 i, 6.25 Shallow A agent Wear. 136 5849 t) 0.07 1 ~i ~ 6.25 Shallow A agent Wear. 137 5893 (J 0.06 1 ~ 7 6.25 Shallow A agent Wear. - 138 5933 U.O6 0.07 19 6.24 Shallow A agent Wear. 139 5975 l).i1S 0.06 1; t; 6.25 Shallow A agent Wear. 140 6018 U 0.07 1 t3 t~ 6.26 Shallow A agent Wear. - 141 6060 U.0(, 0.07 19 ti 6.27 Shallow A agent Wear. - 142 6103 U.US 0.07 i ~i tt 6.22 Shallow A agent Wear. 143 6146 0 0.07 1 t3 fi 6.25 Shallow A agent Wear. 144 6188 a 0.05 13 ~ 6.21 Shallow corrosion. - 145 6233 0 0.06 1 t; 6.24 Shallow corrosion. 146 6274 iLO~) 0.07 ZO ! 1 6.14 Corrosion. Lt. De osits. 146.1 6278 (! 0 0 n N A 3.5" Tubin Stub Penetration Body Metal Loss Body Page 3 ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~~:~ _s~e Well: 2A-12 Survey Date: March 24, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 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 104 at depth 4495.01 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 91 Tool deviation = 42 ° Finger 24 Penetration = 0.087 ins Isolated pitting 0.09 ins = 24% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 PDS Report Cross Sections Well: 2A-12 Survey Date: March 24, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin _ _ 7 ins 26 ppf J-55 Analyst C. Waldrop Cross Section for Joint 134 at depth 5790.23 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 94 Tool deviation = 44 ° Finger 2 Penetration = 0.087 ins Apparent Wear 0.09 ins = 24% Wall Penetration HIGH SIDE = UP J i Cross Sections page 2 i~ ii ~,. ~~' KUP ~ ZA-12 ConocoPhillips II At tributes An le 8 MD TD 11.f~~.1 I'i~ Wallbore A PWWI Field Name Wall Status Intl(°) MD (Po(B) Act Blm (ftKB) _ 501032005800 KUPARUK RIVER UNIT PROD 40.63 6,900.00 7,125.0 Comment M25 (ppm) Date Annotation E ntl Date KBGrd (ft) Rig Release Date wet coou:~zA-IZ lvaizso9 s.za os AM SSSV:LOCKEDOLIT 225 1/10Y2009 last WO: 31.01 1/19/1986 Srliemallc-A tual Annotation DepM (flKB) End Dale Annotation Last Mod By End Date last Tag: SLM 6,830.0 10/24!2009 Rev Reason: Cancel Well Waiver Imosbor 11!3/2009 sale Innibno<, Casin Strip s . ~ String O D String ID Set Depth Sef DepM (TVD) String Wt String Casing Description (in) (in) Top (ftKB) (RI(B) (ftKB) (IbsHt) Gratle String Tap ThM corlDUCrOR, 10G CONDUC TOR 1 6 15.060 0.0 106.0 106.0 62.50 H-40 SURFAC E 95 /8 8.765 0.0 2,860.0 2,793.8 36.00 J-55 PRODUC TION 7 6.151 0.0 6,663.0 5,816.1 26.00 J-55 sAFt rv vLV, LINER 5 4.151 6 435 0 7 115 0 6 161 2 18 00 L-80 1,~ O , . , . . . . Tubin Strip s String O D String ID Set Depth Set DepM (TVD) String Wl String Tubi D escription (in) (in) Ta (ftKB I~BI (ftKB) (IbsMt) Grade Senn To ThM suRFACE, z.aso TUBING 3 1 /2 2.867 00 6,393.0 5,604.4 9.30 J-55 EUESrtlA6 TUBING 2 31 8 1.901 6,393.0 6,822.0 5,938.6 4.70 N-80 AB MOD cAS uFr. Other I n Hole A ll Jewe l :Tubin Run 8 Retrievable Fish etc. 6,267 Top DepM (TVD) To lncl Top (itl(B) (~B) p (°) Description Comment Run Dam ID (in) 1,806 1,805.5 5.69 S AFETY VLV Carnco TRDP-IA-SSA' (Locked Out 9/11/90} 12/28!1995 2.813 6.261 5,501.2 38.95 G AS LIFT CAMCO/MMG-2/7.5/OV/RK/.25lI Comment: STA 1 3/25/2006 2.920 PBR, 6,307 6.307 5,532.3 38.72 P BR Baker 3!1211986 3.000 6,315 5,543.3 38.65 P ACKER Baker'FHL' PACKER 3/12/7986 3.000 6,J35 5,558.9 38.53 P LUG 3.5" WRP 10/26/2009 0.000 t I 6,354 5,573.8 38.43 P RODUCTION CAMCOIKBt1Gl1/DMY/BK/7/Comment: CLOSED STA2 6/13!1999 2.875 PACKER, Fi,31s a - I 6,390 5.602.0 38.23 N IPPLE AVA BPL ported nipple 3/12/7986 2.750 6,390 5,602.0 38.23 S LEEVE-C Set AVA 2.75" BPI SLEEVE set 11/12/2005 11/1212005 2.373 6,393 5,604.4 38.21 X O 3/12/1986 2.375 6,806 5,926.5 40.85 P ACKER Baker'DB' PACKER 3/12/1986 3.250 PLUG, x,335 6,818 5,935.6 40.82 N IPPLE Camco'D' Ngple, NO~O 3/12/1986 1.813 6,818 5,935.6 40.82 P LUG 1.81" CA-2 PLUG 10/24/2009 0.000 6,821 5,937.8 40.81 S OS Cameo 3!72/1986 1.995 PRODUCTION, 6.822 5,938.6 40.87 T TL ELMD@6878' ON SWS PERF 9!5/2005 3/12/1986 1.995 s,3sa 6,947 6,028 8 40.54 FI SH 1 1YY GLV Lost in Hole 3/30!1989 Perfora tions 8 S lots NIPPLE. 6.390 • Top (ND) Bbn (ND) shot Dens SLEE6 C~ ' I: Tap (itl(B) Bbn (flKB) (ftKB) (flKB) 7arro Dale (sh-- Type Comment 6,734 6,787 5,871.0 5,911.7 C-0, 2A-12 3/12/1986 12.0 IPERF 69 deg. phasing; SOS 3318" Csg Gun 6,820 6.830 5,937.1 5,944.6 A-4, ZA-12 9/3!2005 6.0 APERF 1-11!16" EJ.O deg Dhase 6 837 8,864 5.949.9 5,970.3 A-3, 2A-12 3/12/1986 6.0 IPERF 60 deg. phasing; SOS 3 3/8" Csg XO. 6,393 GUn Notes: General 8 Saf Ena wm MnMation 3/26/2006 NOTE: TBG PERFS for PO GLMs @ 2686', 4476', 5612' PRODUCTION, 6,683 IPERF, 6,1348,181 PACKER, 6,806 NIPPLE, 6,818 PLUG, s,s1e Tn, s,azz APERF, s,szob,s3o IPERF, 8,8376.863 FISH, 6,961 LINER, 1,115 TD, 1,125 ~- ,~ r ~~ ~ ~; ti ~_~~ ~ F ~ ALASKA OIL A1QD GAS COI~TSERQATI01`T CODII-IISSI011T Mr. Jim Ennis Wells Engineer ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-12 Sundry Number: 310-031 Dear Mr. Ennis: `~b,oo4 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel" . Seamount, Jr. Chair I~ DATED this ` < day of February, 2010. SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Encl. ~• C ',ALAS..++ILAND GAS CONSERVA ON COMMI~SI~/IU R~~~~VGD APPLI~TION FOR SUNDRY APPROV• S DEB ~ 2 2010 20 AAC 25.280 1. Type of Request: Abandon ~ Rug for Redrill `"' Perforate New Pbol ~"` Repair well ange roe o ram Suspend ]`°'` Rug Ft?rforations ~" Perforate PUII Tubing ~', ~~~~sion Operational Shutdown ~'' Re-enter Susp. Well ~ Stimulate Alter casin ~ ~- ~ 9 'Other: 2. Operator Name: 4. Current Well Class: 5. Permit. to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ; 186-004 _ 3. Address: Stratigraphic Service ~'"' 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-103-20058-00 ' 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 No ~` 2A-12 9. Property Designation: 10. Field/Pool(s): ADL 25570 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7125 ~ 6169. 7064' 6122' 6335', 6818' 6941' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16 106' 106' SURFACE 2834' 9.625 2860' 2794' PRODUCTION .6637' 7 6663' 5816' LINER 680 5 7115' 6161' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6734'-6787', 6820'-6830', 6837'-6864' 5871'-5912', 5937'-5945', 5950'-5970' 3.5 x 2.375 N-80 6393 / 6822 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -BAKER 'FHL' PACKER MD= 6315 TVD= 5543 PACKER -BAKER 'DB' PACKER MD= 6806 TVD= 5926 LOCKED OUT - CAMCO 'TRDP-1A-SSA' (LOCKED OUT 9/11/90) MD= 1806 TVD= 1806 12. Attachments: Description Sumrery of Proposal 13. Well Class after proposed work: Detailed Operations Program ~` BOP Sketch ~" Exploratory '"` Development ~' • Service ~"' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/15/2010 Oil Gas WDSPL T~° Plugged °" 16. Verbal Approval: Date: WINJ ~ GINJ ]""' WAG Abandoned Commission Representative: GSTOR ~'~ SPLUG . I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jim Ennis Signature ~/ Contact: Jim Ennis @ 265-1544 Title: Wells Engineer , Phone: 265-1544 Date O~ / ~ / ~ ~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test v Mechanical Integrity Test "" Location Clearance /~ /~ ~' Other: ~ 3 ~~ f'`~ ~ //~> O !" / ~~S Subsequent Form Required: f v 1.10 i°1 ~/ _ ~~/ APPROv~~ BY Approved by COMMISSIONER THE COMMISSION ~1(T~43.FZ~vi~ 9 ~ R I~ 1 NA L ~~~ ~.,~.;~ ry rvur~~r_ Date: ~ / S.u/bmit in Duplicate ~~~~ %'~b z~3•r~ • • 2A-12 General Workover Procedure 1-29-2010 1. Set catcher sub on WRP. Set BPV. ' 2. MIRU Nordic 3. 3. Pull BPV. Verify well is dead. Load hole with 9.6 ppg brine. Set BPV. ND tree. NU 11" 5M / BOP. Pressure test BOP including annular to 250/3000 psi. Maximum potential surface pressure is estimated at 900 si based on SBHP obtained on 10-23-09. 4. Pull blanking plug and BPV. Circulate hole clean. POOH laying down tubing. 5. RU E-Line. Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. RD E-Line. 6. Set retrievable bridge plug below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi. Dump sand on top of RBP. 7. Cut 7" casing with mechanical cutter above TOC. Circ 9-5/8" x 7" annulus clean. ND BOP and tubing head. NU 11" 5M BOP on casing head. Pressure test break to 3000 psi. 8. Spear and POOH laying down 7" casing. 9. Run 9-5/8" casing scraper to top of 7" stub. Circ clean. 10. RU E-Line. Run caliper log and gyro survey in 9-5/8" casing. RD E-Line. 11. Run back off tool and back off casing stub. 12. Spear and recover casing stub. 13. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. 14. Open ES cementer and pump cement into 9-5/8" x 7" annulus. Close cementer. 15. WOC. ND BOP and land 7" on slips. Cut 7" casing and install packoff. NU tubing head. 16. NU 11" 5M BOP and test break to 3000 psi. 17. Drill out cement and plug. Pressure test casing to 2500 psi. 18. RIH with wash shoe and circulate out sand on top of RBP. POOH. RIH w/ retrieving tool on work string. Release RBP and POOH. 19. RIH 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 2500 psi. Shear SOV. 20. Set 2-way check. ND BOP. NU tree and pressure test. 21. Pull 2-way check. Freeze protect well. Set BPV. 22. RDMO Nordic 3. 23. Pull ball and rod. Pull SOV and run new gas lift design. Pull RHC body. Pull catcher sub. Pull WRP. 24. Return well to production. ~~6Cb~'11~~l~35 .~ ~:~P:a 4nt7. _ _ WgIICOMg .PA-1 ~~91H/~ m° .._ _-- -.._ 3d1@matic.-Attu s I nnmaor. " U coNDUCioR,_ 106 SAFETV VLV,-__ _ ~.. 1,806 SURFACE, 2.660 GAS LIFT. PER, 6 301 - C PACKER. 6,315 a f PLUG, 6,335 PRODUCTION, -_-. -_. 6.354 NIPPLE. 6,350 SLEEVE-C, 6,350 xo,s.353- --- PRODUCTION, 6.663 (PERF, _.. 6,734-6,787 PACKER, 6,606 NIPPLE, 6.81fl~ PLUG, 6,818 SOS. 6,821 '-- - TTL. 6,822 _... - ~.. _-. APERF- -. __ _.'- ,_.. .. - 6,8206,830 _ _ - (PERF, - ,. - 6,837-6,864 FISH, 6,541 -- _ -- - - LINEP., ],115 TD, ],125 --- -- KUP - 2A-12 Well Attrib ~~ t s Max Angle & MD STD u 'Wellbore APUDWI e Field Name __ Wall St atus lncl (°) MD (ftK6) (Act Bim (kKBf 501032005800 KUPARUK FIVER UNIT (PROD 40.63 I 6,900.00 7,1250 Comment H2${ppni i Dafe Annotation End Date KB-Grd (ft( Rig Release Date SSSV: LOCKED OUT `.:. ~. 1/10/2009 (Last WO: 31 Ot 1/19/1986 Annotation Depth (kK8) End01 Annotation Last MOd By (End Date Last I age SLM ( ( 6,830.0 10124 IOOFi Rev Reason: Cancel Well Waiver Imosbor 11/3/2009 Casinn~c Strin gs -'-- _ - St o ' 9 SV zg 10 Set Depth -Set Dep[h (ND) String Wt Suing ton g rip (n1 1 hn) Top (kK6) (ftK6) (ftK6) (Ibs/ft( Grade Sfring Top Thrd CONDUCTOR 6 i ' SURFACE 95/8 GS F.'.~ 0.0 2,860-0 2,793.5 36-00 J55 PRODUCTION 7 6-751 0.0 6,663.0 5,816.1 26-00 J-55 6,1 6,301 6,315 6,335 Inc (Locked Out 9/11/90) 'RK/.25//Comment: STA 1 5,602.0 38.23~ NIPPLE AVA BPL ported nipple 3/12/1986 2.75 5,6020 38.23i SLEE'v Er`; Set AVA 2.75"BPI SLEEVE set 11/12/2005 11/12/2005 2.31 6,604.4 38.21 XO 3/12/1986 2.37 5,926.5 40.85 PAChI I_R I Baker'DB' PACKER 3/12/1986 ~ 3.25 5,935 6 40.82 NIPPLE Camco'D' Nipple, NO-GO 3/12/1986 1.87 5,935.6 40 82 PLUG 1.87" CA-2 PLUG 10/24/2009 0.00 5,937.8 40811 SOS Camco 3!12/1986 1.99 5,938 6' 40.81 -(7 L ELMD @ 6818' ON S WS PERF 9/512005 3112/1986 1 99 (,0288 DrIS 8r 4Q54 $IOtS FISH 'il/2"GLV LOSt in Hole 3/30/1989 - - - sna Top (TVD) Blln {TV01 Dens tm (ftK6)'. (ftKB) (ftKE Lone Date (sh.-, Typa Comment - 6,787 5 871.0 5.911 ~ C-4, 2A-12 3/12/1986 12.0 (PERF 69 deg. phasing; SOS 3 3!8" Csg Gun 6,830 5,937.1 S.:N45 A-0, 2A-12 19/312005 6.0 APERF 1-17176" EJ, 0 deg phase 6,864 5,949.9 5 9!0 ? A-3, 2A-12 113/12/1986 6.0 (PERF 60 deg. phasing; SOS 3 3/8 Csg 1 Gun eneral8_Safety _ _ _ Annotation _-- '~,NOiE~ I BG PER(-S for POGLMS @ 2686', 4476', 5612' • Page 1 of 2 Schwartz, Guy L (DOA) From: Ennis, J J [).).Ennis@conocophillips.com) Sent: Tuesday, February 09, 2010 2:10 PM To: Schwartz, Guy L (DOA) ., Subject: RE: 2A-12 RWO (PTD 186-004) Our whole two wells of experience to date, 2A-05 & 6, indicate we should expect the 7" to be corkscrewed also. No leaks on this well other than the tbg punches. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (VV) (907)632-7281 (C) From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.gov] Sent: Tuesday, February 09, 2010 1:58 PM To: Ennis, J J Subject: RE: 2A-12 RWO (PTD 186-004) Jim, Quick question on the casing replacement. IA X OA leak or do think it is buckling too? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ennis, J J [mailto:].).Ennis@conocophillips.com] Sent: Tuesday, February 09, 2010 1:24 PM To: Schwartz, Guy L (DOA) Subject: RE: 2A-12 RWO (PTD 186-004) Guy, The following is an excerpt from the AFE: Well 2A-12 was drilled and completed as an `A/C' sand single selective injector with 3-1/2" tubing, one GLM and 2-3/8" tubing tail. Following pre-production, conversion to injection was permanently deferred and the well produced `A' sand only from 1986 until 1988 when the `C' sands behind the selective were opened. In March 2006, the tubing was punched and three POGLM assemblies were installed to assist and optimize the unloading sequence of the only gas lift mandrel. Each of the three POGLM assemblies was 16' overall length with a max OD of 2.738". Well 2A-12 passed a MIT-OA and TIFL in November 2008. A baseline tubing drift run in May 2009 using a 2/9/2010 . ~ • Page 2 of 2 4' stem, 2.79" centralizer, and 2.8"swage encountered no restrictions above the POGLM's at 2,655' RKB. A gyro survey was completed in August 2009 to investigate the condition and severity of the suspected buckled tubing. Analysis of the gyro survey data indicated helical buckling in the tubing with local areas of high dogleg severity at 300' with an average buckling period of 66'. A follow-up drift run in October 2009 to simulafe the drift needed to remove the POGLM's encountered tight intervals at 290' with a 75' stem and 2.74" centralizers. Based on comparisons between the historical slickline drifts and the gyro data, it was evident that subsidence related buckling had worsened creating a tighter interval above the POGLM's at a depth around 300'. Based on this information, it was determined the POGLM's should be removed from the wellbore before full-bore tubing access was restricted from continued subsidence. The POGLM's were successfully pulled and the well was secured with a WRP set at 6,335' RKB on October 26, 2009. Please let me know if you need anything further. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (VV) (907)632-7281 (CJ From: Schwartz, Guy L (DOA) [mailto:guy.schwar~@alaska.gov] Sent: Wednesday, February 03, 2010 2:37 PM To: Ennis, J J Subject: 2A-12 RWO (PTD 186-004) Jim, Can you send me a quick blurb on the well history for 2A-12. I know this is a subsidence pad issue. Basically why is the workover being performed...., Email is fine. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/9/2010 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnlcen 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 2A-12 Run Date: 10/31/2009 November 9, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-12 Digital Data in LAS format, Digital Log Image file 50-103-20058-00 'v~~~~~, JAS ~.~ 201 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 FaY: 907-273-3535 rafael.barreto ~halliburton.com r\ ~~ Date: ~ ' ~-~-'~~ ~ ~9 ~g Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2A -12 Run Date: 10/26/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 20058 -00 n 2009 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. Cf Anchorage, Alaska 99518 115 to Office: 907 273 -3527 4 Fax: 907 273 -3535 rafael .barreto @hallaburtori,cbfti Date: NOV 3 20J Signed: L • Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK-99501 ~~~~~~ ~ ~ ~ ~. ~ 200 Dear Mr. Maunder: • _ -'~ k rrt _.. f..~x.~: _ 4,. ~ %'. ~, ~ ~~ ~ ~~~ Enclosed please find a spreadsheet with a list of wells from~theAKuparuk field (KRIS. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007- and the corrosion inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor __ _ _, __ • • Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant i'op-off Report of Sundry Operations (10-404) Date Kuparuk Field ~ are ~r~nm Well Name PTQ # 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-01 184-057 SF na SF na 1.5 12/14/2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44" na 50 12/14/2007 2A-04 184-053 9`6" 1.2 10" 9/24/2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 12/5/2007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14/2007 2A-OS 1$5-248 SF na SF na 3 12/5/2007 ZA-09 186-001 SF na SF na 1.75 12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12!5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5J2~7. 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12!14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9/24/2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 e ConocóÃ,illips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 September 20,2005 ~~Cs; 4/1. S('p I). IV~D 'oil, ~ (J ,J (¡'I ~ . <'005 é.)q,r c 411cl" 0111. c: Of¡¡~ o~: 'e 1t,IÒ" Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2Ä-12 (APD# 186-004) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk weIl2A-12. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, iit4-~ Wells Group Team Leader CPAI Drilling and Wells SCAI\.Iiì.IEf) Nt'\f n nìOD5 ",,1,'1 c...· .,J, U iJ i_ MM/skad ~CP 9. ~ 'Loa 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 v Õther g mrri",on Alter Casing 0 0 ~R" 0 .' Pull Tubing Perforate New Pool 0 Waiver 0 M.,~,~a,&ø; fa' . Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter suspend~~ 9tJ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Nurnl.f'": ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 ·~I 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchoraç¡e, Alaska 99510 50-103-20058-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 123' 2A-12 8. Property Designation: 10. Field/Pool(s): ADL 25570, ALK 2668 Kuparuk River Field I Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7125' feet true vertical 6169' feet Plugs (measured) Effective Depth measured 6858' feet Junk (measured) 6941' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 106' 106' SUR CASING 2834' 9-5/8" 2860' 2794' PROD CASING 6637' 7" 6663' 5816' LINER 680' 5" 7115' 6161' Perforation depth: Measured depth: 6734'-6787',6820'-6830', 6837'-6864' true vertical depth: 5871'-5912',5937'- 5944',5950'-5970' Tubing (size, grade, and measured depth) 3.5" 12-3/8", J-55 I N-80, 6393' 16822' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'DB' pkr= 6315'; 6806' SSSV= Cameo 'TRDP-1A'-SSSA' SSSV= 1806' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none RBDMS BFL SEP 2 8 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation 132 48 376 -- 259 Subsequent to operation 135 13 282 - 230 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name ;;~e¿oney Title Wells Group Team Leader ~ 0 Signature Phone Date ~ Z. 5, t/f , bv¥'\ PreDared bv Sharon AlIsu~Drake 263-4612 l / H:'ì e STATE OF ALASKA e VED ALASKA Oil AND GAS CONSERVATION COMMISSION RECE\ REPORT OF SUNDRY WELL OPERATIO~S 5 Form 10-404 Revised 04/2004 tJ,~\I/~L Submit Original Only e 2A-12 Well Events Summary e Date Summary 09/03/05 DRIFT TBG W/10' X 1.75" DUMMY GUN & TAG @ 6847' SLM. WELL TO BE LEFT SHUT IN FOR E-LlNE PERF WORK. [Tag] 09/05/05 1ST RUN WITH GR/CCL TO CONFIRM TUBING BTM - EOT OK (3 FT ABOVE TOP SHOT OF PERF ZONE). PERF A4 SAND FROM 6820 - 6830 FT MD.WITH 1.63" EJ III STRIP GUN. 6 SPF/O DEG PH/17.96" PENETRATION/0.28" HOLE DIA. COR LOG- 17JAN86 INDUCTION LOG. l g 60o¥0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~" DATE' Commissioner THRU: Tom Maunder, ~ P. I. Supervisor January 4, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 2A Pad Thursday, January 4, 2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2A Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2A-12 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2A Pad in the Kuparuk River Field. KRU 2A Pad, 12 wells, 24 components, 1. failure 4.1% failure rate 21 wellhouse inspections Attachment: SVS KRU 2A Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation COmmission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2A Pad Separator psi: LPS 96 HPS 1/4/01 Well Permit Separ Set L/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 2A-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 2A-21 1931330 2A-22 19506801 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% [] 9o my Remarks: Surface Safety on 2A-12 had slow leak, valve to be serviced and retested MICROFILMED 9/~ ~/00 DO NOT PLACE ANy' NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 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 1446' FSL, 53' FEL, SEC.14, T11N, R8E, UM At top of productive interval 1452' FNL, 1296' FEL, SEC.14, T11N, At effective depth 1241' FNL, 1355' FEL, SEC.14, T11N, At total depth 1202' FNL, 1341' FEL, SEC.14, T11N, Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6. Datum elevation (DF or KB) RKB 123 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-12 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: R8E, UM R8E, UM R8E, UM 9. Permit number 86 -4 10. APl number 50-103-20058-00 11. Field/Pool Kuparuk River Field/Oil Pool 12. Length 7125 6168 7O64 6122 Size feet feet Plugs (measured) 8066' feet Junk (measured) feet Cemented 80' 2834' I 6" 9 5/8" 6637' 7089' measured 6734'-6787', true vertical 5871'-5912', i! 315 SX CS I 8OO SX CS III & 310 SX CS II 200SXCLASSG& 1750SXCSI 6663' 140 SX CLASS G 71 1 5' 6837'- 6864' 5950'-5970' feet Measured depth True vertical depth 106' 106' 2860' 2789' ORIGINAL 5816' 6161' Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 6393', 2-3/8" 4.7# N-80 @ 6816' Packers and SSSV (type and measured depth) PKR: BAKER DB @ 6801', PKR: BAKER FH @ 6310', SSSV: CAMCO TRDP-1A-SSA @ 1806'i]]; '~ i~' i'~' i 13. Stimulation or cement squeeze summary 14. Fracture'stimulate 'A' sands on 6/8/97. Intervals treated (measured) ' ' 6837'-6864' Treatment description including volumes used and final pressure Pumped 127 Mlbs of 20/40 and 12/18 ceramic proppant into formation~ fp was /~ ~"~ ~;i'! ~ i ~',',-i : ; Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 876 791 180 1 194 312 Subsequent to operation 11 46 1 088 471 1 208 276 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ( //~.~.,~j'x/~~~!~,.,.~ Title Wells Superintendent Form 1~'~b4 v R~e~ (~/15'~8 ~ / Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4~ WELL SERVICE REPORT ~ K1(2A-12(W4-6)) WELL JOB SCOPE JOB NUMBER 2A-12 FRAC, FRAC SUPPORT 0525971916.6 DATE DAILY WORK UNIT NUMBER 06/08/97 PUMP"A" SANDS RE-FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O No (~) Yes C) No DS-GALLEGOS JOHNS , FIELD AFC# CC4f DAILY COST ACCUM COST Sig~e~ ~ ~) _,_~ ESTIMATE . KD1258 230DS28AL $114,000 $122,081 ~/'~,~~ Initial Tb.a PreSs Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann ~ Fi~Outer Ann 1000 PSI 0 PSI 800 PS! 1000 PSII 1000 PSII 700 PSI DALLY SUMMARY PUMPED 127037 # PROP IN PERFS W/10# 12/18 AT PERFS. PRESSURED OUT, LEFT 17,043 # IN PIPE. TOTAL 1201 BBLS FLUIDS PUMPED. TIME LOG ENTRY 06:30 MIRU DOWELL FRAC EQUIP, LI-I-i'LE RED PUMP AND APC SUPPORT. 08:30 HELD SAFETY MEETING 09:12 INITIAL WHP 1000 PSI, PRESSURE TEST TREATING LINES TO 7440 PSI. 09:15 PUMPING BREAKDOWN W/236 BBLS FLUIDS INCLUDING 2000# 20/40 PROP AT 1PPA FOR SCOUR. 15 BPM AND 3268 PSI. SHUT DOWN FOR ISIP AND PULSE TEST. 09:58 PUMPING DATA FRAC AND FLUSH AT 5 TO 15 BPM, SHUT DOWN 3226 PSI, FIGURE CLOSURE PRESSURE. 11:18 PUMPED 150 BBLS PAD, AT 5 TO 15 BPM AND 4400 PSI. 11:45 PUMPED 81444f 20/40 PROP AT 2PPA AND 4412 PSI. 11:52 PUMPED 150,000 # 12/18 PROP FROM 2 TO 10 PPA TO SCREEN OUT AT 5800 PSI. SHUTDOWN 12:36 PRESSURED OUT WITH 127037# PROP IN PERFS, 12/18 AT PERFS AT 10# PPA. LEFT 17,436 # PROP IN PERFS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,050.00 APC $7,000.00 $7,000.00 DOWELL $103,000.00 $103,000.00 HALLI BU RTO N $0.00 $3,281.00 LITTLE RED $4,000.00 $7,750.00 TOTAL FIELD ESTIMATE $114,000.00 $122,081.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Repair well ,., Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 1446' FSL, 53' FEL, SEC.14, T11N, R8E, UM At top of productive interval 1452' FNL, 1296' FEL, SEC.14, T11N, R8E, UM At effective depth 241' FNL, 1355' FEL, SEC.14, T11N, R8E, At total depth 202' FNL, 1341' FEL~ SEC.14~ T11N, RSE, UM Present well condition summary Total Depth: measured 7125 feet true vertical 6168 feet Effective depth: measured 7064 feet true vertical 6122 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 6. Datum elevation (DF or KB) RKB 123' 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-12 9. Permit number 86-4 10. APl number 50-103-20058 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool !12. Length Size Plugs (measured) 8066' Junk (measured) feet 13. 80' 16" 2834' 9 5/8" 6637' 7O89' measured 6734'-6787', true vertical 5871 '-5912', . 5" 6837'- 6864' 5950'-5970' Cemented Measured depth True vertical depth 315 SX CS I 106' 800 SX CS III 2860' 310 SX CS II 200SXCLASSG& 1750SXCS I 6663' 140 SX CLASS G 7115' 106' 2789' Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 6393', 2-3/8" 4.7# N-80 @ 6816' Packers and SSSV (type and measured depth) PKR: BAKER DB @ 6801'~ PKR: BAKER FH @ 6310', SSSV: CAMCO TRDP-1A-SSA @ 1806' Stimulation or cement squeeze summary Fracture Stimulate A Sands Intervals treated (measured) 6837'-6864' Treatment description including volumes used and final pressure 20.0 Mlbs, 72.0 Mlbs 16/20, 79.7 Mlbs 12/18, 0.7 Mlbs 10/14 LWCP. Max pressure 6400 psi. 5816' 6161' RECEIVED... o? 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 655 219 8 1 400 1915 1304 1 1 2 1029 Tubing Pressure 272 274 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~-~ ~'~ /_-~ Title Wells Superintendent Form 10-404 Rev 06/15/88 Date SUBMIt'IN DUPLICATE WELL 2A-12 DATE · 2/8/95 I)AY ARCO Alaska, Inc. A Subsidiary. of Atlantic Richfield Company 'DESCRIPTION OF WORK RE-FRAC "A" SANDS CONTRACTOR / KEY PERSON DOWELL YOAKUM PBTD (RKB) ILAST TAG (RKB) - DATE KUPARUK RIVER uN! ~ WELL SERVICE REPORT I AFC/CC#- SC~'#" 998383 80429 _ I FIEI~D COST EST. ACCUMULATED COST i $163,046 $163,782 SSSV TYPE / STATUS IFRAC SLEEVE INSTALLED I I 1CHECK'THIS BLOCK IF SUMMARY IS CONTINUED ON BACK IXI COMPLETE ] | INCOMPLETE 'Weather I Temp~" I Chill"Factor IVisibility Wind Vel. ]Signe~" Report ] [ ! miles mph TIME LOG ENTRY J HELD SAFETY MEETING ON JOB PROCEDURE 0700 MIRU FRAC EQUIP. AND HOT OIL PUMP 1010 PRESSURE TEST TO 7550 PSI 1024 PUMPED FRAC WITH 50 # GEL SYSTEM AT 15 BPM PUMPED CONDITION STAGE, DATA FRAC PUMPED 180 BBL PAD PUMPED STAGES W/- 20/40,16/20,12/18 AND 10/14 PROP. LWP FRAC. SCREANED OUT WITH 13 PPA 12/18 ON FORMATION 1444 RDMO SUMMARY: PUMPED "A" SAND FRAC. WITH 19980g-20/40,72040g-16/20,797344-12/18 AND 7120#-10/14 154000# TOTAL IN FORMATION AND 24874-g IN PIPE MAX. PRESSURE WAS 6400 PSI, MAINTAINED 3500PSI ON 3.5X 7.0 ANNUL. 13# PPA OF 12/18 PROP AT PERFS. ARCO Alaska, Inc Posl Office ~ ;0360 Anchorage, Alaska 99510-0360 Telephone 907'276 1215 Date: March 18, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 5936 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2A-12 CET. 3-8-86 64].0-7007 3F-16 CET 2-13-86 7740-8443 2A-10 CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 3Q-7 CBL 2-25-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL 2-15-87 7843~9752 __iQ-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-10 CET 9-4-86 4700-81i8 Receipt Acknowledged' DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (fi]m) ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany STATE OF ALASKA ~-- ALASK,~d~L AND GAS CONSERVATION U,.~MMISSION 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. 86-4 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20058 4. Location of well at surface 9. Unit or Lease Name 1446' FSL, 53' FEL, Sec.14, T11N, R8E, UM yE,O, iFIED Kuparuk River Unit Top Producing Interval ~~ 10. Well Number At 1452' FNL, 1296' FEL, Sec.14, TllN, R8E, UM ]L~~'---~//~ 2A-12 At Total Depth '~'~ 1"1. Field and Pool 1202' FNL, 1341' FEL, Sec.14, TllN, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 123' RKB ADL 25570 ALK 2668 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 01/08/86 01/16/86 01/19/86*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7125'MD,6168'TVD 7064 'MD ,6122 'TVD YES [~X NO []I 1806 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, CET, 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 106' 24" 315 sx CS II 9-5/8" 36.0// J-55 Surf 2860' 12-1/4" 800 sx CS Ill & 310 sx CS II 7" 26.0# J-55 Surf 6663' 8-1/2" 200 sx Class G & 175 sx CS I 5" 18.0# L-80 6435' 7115' 6-1/8" 140 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) 6734' - 6787' w/12 spf, 120° phasing 3-1/2" 6822' 6315' & 6806' 6837' - 6864' w/6 spf, 60~' phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None i Form 10-407 '/~ NOTE: Tubing was run & well perforated 3/11/86. DAM2/WC41 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARK'ERS TRUE VERT. DEPTH MEAS. DEPTH 6733' 6788' 6803' 6964' 5869' 5912' 5923' 6046' 3o~ .. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well History (completion details), Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer ~te SB-b~o INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO 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 / parish or borough Alaska County. North Slope Borough Field I Lease or Unit Kuparuk River ADL 25570 Auth. or W.O. no, ~Title AFE 904317 I Completion IState Alaska no. 2A-12 Nordic 1 API 50-103-20058 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUncomplete IDate 3/5/86 JHour 1900 hrs. !Pri°rstatuaifaw'O' Date and depth as of 8:00 56.24% 3/06/86 3/07/86 3/08/86 thru 3/10/86 3/11/86 Complete record for each day reported 5" @ 7115' 7015' PBTD, RIH w/BP retrv'g tl Diesel/12.l ppg mud Accept rig @ 1900 hfs, 3/5/86. NU & tat BOPE & 7" csg to 3500 psi. RIH w/Model "L" retrv'g tl. 5" @ 7115' 6331' Cmt, POOH Diesel/12.1 ppg mud RIH w/BP retrv'g tl on 2-1/8" DP to 2000'. Wt up mud to 12.1 ppg. Displ out 2000' diesel w/mud. FIH w/DP, tag BP @ 6218', tel BP, CBU, TOH; no BP rec'd. RIH w/retrv'g tl, tag BP @ 6307', set BP, tel same & TOH; no rec'y. TIH to retrv BP. 5" @ 7115' 7023' PBTD, RIH w/perf gun 12.1NaBr POH, did not rec BP. Chg retrv'g tls, RIH, latch BP @ 6307', POH, rec'd. RIH w/bit & 7" csg scrpr, tag cmt @ 6326', drl to 6442', circ, tst csg to 1000 psi, POH. RIH w/4-1/8" bit & 5" csg scrpr, tag TeL & cmt @ 6442', drl cmt to 6500'. RIH, tag LC @ 7023', circ cln, POH. Tst csg to 1000 psi. RU Schl, rn CET log f/7007'-6410'. Rn GCT gyro f/6950'-20', RD Schl. RIH w/4-1/8" bit & 5" scrpr. Chg well over to 12.1 ppg NaBr, POH, LD DP. RU Schl to perf, tat lubr to 1000 psi. RIH w/perf gun. 5" @ 7115' 7023' PBTD, RIH w/3½" compl 12.1NaBr Perf 6837'-6864' w/6 SPF. Perf 6734'-6787' w/12 SPF. Make 4.125" gage ring/JB rn, stopped @ TeL, POH. Make 4.00" gage ring/JB rn to 6810', POH. MU 2-3/8" tailpipe assy & 5" DB pkr, set @ 6801' WLM, TT @ 6817' WLM, RD WL. RU & rn 2-3/8" x 3-1/2" compl, prep to lnd. The above is correct Signature For form preparation and ~stribution, see Procedures Manual, S~ction 10, Drilling. Pages 86 and 87. IDate -- Title Drilling Superintendent ARCO Oil and Gas Company Daily Welt 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 Js not required upon completion, report completion and represer~tative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State m.~aska Alaska North Slope Borough Field ILease or Unit IWell no. Kuparuk River ADL 25570 2A-12 Auth. or W.O. no. ~Title AFE 904317 I Completion Nordic 1 API 50-103-20058 Operator IA.R.Co. ARCO Alaska, Inc. 56.24% I Date Spudded or W.O. begun Complete 3/5/86 Date and depth as of 8:00 a.m. 3/12/86 Complete record for each day reported I otal number of wells (active or inactive) on this oat center prior to plugging and bandonment of this w~ll I our ~ Prior status if a W.O, 1900 hrs. 5" @ 7115' 7023' PBTD, RR Diesel RIH w/3½" x 2-3/8" compl. Stab into 5" DB pkr. Space out & t lnd. Set 7" FHL pkr @ 6315' DB pkr @ 6806', SSSV @ 1806', TT @ ~8Z~9~t4'. Tst tbg to 2500 psi. Shear out PBR. Tst ann to 2500 psi. Tst SSSV w/1500 psi. Open SSSV. Shear out ball. ND BOPE, NU &tst tree to 5000 psi. RR @ 1900 hrs, 3/11/86. Old TD New TD Released rig Date 1900 hrs. Classifications (oil, gas, etc.) Oil I PB Depth 3/11/86 IKind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7023' PBTD Rotary ~ell 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 For form preparation and distribu~ion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent STATE OF ALASKA ~'" ALASKA (J~L AND GAS CONSERVATION CO~v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~¢~ / OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-4 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20058 4. Location of well at surface 9. Unit or Lease Name 1447' FSL, 53' FEL, Sec.14, T11N, RBE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 2A-12 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 123' 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 01/08/86 01/1 6/86 01/19/86*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7125 'MD 7064 'MD YES E~TM NO []I 1806 feet MD 1500 ' ~ approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, CET, 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 106' 24" 315 sx CS II 9-5/8" 36.0# J-55 Surf 2860' 12-1/4" 800 sx CS Ill & 310 sx CS II 7" 26.0# J~55 Surf 6663' 8-1/2" 200 sx Class G & 175 sx CS I 5" 18.0# L-80 6435' 7115' 6-1/8" 140 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) 6734' - 6787' w/12 spf, 120° phasing 3-1/2" 6822' 6315' I~ 6806' I 6837' - 6864' w/6 spf, 60° 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.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ . Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE "I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None REC£1V[D APB 0 Z 1986 AIBska 011 & Gas Cons. Commission Form 10-407 Rev. 7-1-80 / NOTE: Tubing was run & well perforated 3/11/86. DAM2/WC21 Submit in duplicate r~ j~// CONTINUED ON REVERSE SIDE 29. NAME To be submitted wi GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 'ed. 30. FORMATION TESTS en gyro .S rece' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item .27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cOres taken, indicate "none". Form 10-407 ADDENDUM WELL: 2/03/86 2A-12 Arctic Pak well w/175 sx CS I, followed by 60 bbls Arctic Pak. Drilling SUperintendent Date ARCO Alaska, Inc, Post Office Box 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 02-19-86 TRANSMITTAL # 5569 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes plus Listings--Original computation SCM1/ One of each ., _ ~ ~ 3J-t4 '01-24-86 Run #1 1990-8114~D ~-~ 3J-15 02-03-86 Run 3N-Z 01-~8-86 Run Receipt Acknowledged: State of AK ARCO Alaska. inc. ~,, · Sul3s~diary o! AHartticRichfieldComl3any ARCO AlasKa. Inc. ...... Post Office B,._. 360 Anchorage. Alasi~a 99510-0360 Telephone 907 276 1215 RE%"JP~N TO: ARCO ALASKA, INC. ATTN: KuDaruk Records Clerk ATO 1119 P. O. Box 100360 Anchorage ~J( 99510-0360 DATE 02-26-86 ~"~RT~NSMI~ # 5579 Transmitted herewith are the following items. Please acknowledge receipt and ret.am one si.cned copy of ~his transmittal. Final Prints/ Schl/ Open Hole/ One * of each 3J,!2 ~ DIL/SFL-GR 01-01-86 DIL/SFL-GR 01-0'~-86 ~(D~ii ' Don/Neu-GR (poro) 01-01-86 Den/Neu-GR (poro) 01-01-86 \ ~" Den/Neu-GR (raw) 01-01-86 ~2" Den//{eu-GR (raw) 01-01-86 ~ Cyberlook 01-01-86 3F-16 ~5" DIL/S:-qL ~ 2" DIL/SFL Den/Neu ~2" Den/Neu ~ 5" Den/Neu ~ 2" Den/Neu ~Cyberlook 2 -6 01-07-86 01-0q-86 (pot°) 01-07-86 (poro) 01-07-86 (raw) 01-07-86 (raw) 01-07-86 01-07-86 12-28-85 5,] DiL/SFL-GR 12-28-85 Den/Neu-GR (poro) 12-28-85 ~2" Den/Neu-GR (_moro) 12-28-85 ~'5" Den/Neu-GR (raw) 12-28-86 ~2" Den/Neu-GR (raw) 1~-28-85 ~CCyberlook 12-28-85 2A-12 ~5" DiL/SFL-GR 0i-17-86 ~2" .DIL/SFL-GR 01-17-86 _ ~5" Den/Neu (poro) 01-17-86 ~C~:: Den/Nam (_moro) 0!-17-86 Den/Neu (raw) 01-17-86 ~ 2" Den/Neu (raw) 01-iq-86 ~yber!ook 01- ! 7- 86 R~n #1 2000-8283 Run #1 2000-8283 R~n #1 3991-8258 Run #1 3991-8258 Run #1 3991-8258 Rtnn #1 3991-8258 R~n #1 7550-8234 R~n #1 1800-8432 Run #! 1800-8432 Run #1 4400-8407 Run #1 4400-8407 Run #1 4400-8407 R~n #! 4400-8407 Run #1 7900-8400 Run #1 2300-9016 Run #1 2300-9016 Run #1 4000-8991 Run #1 4000-8991 Run #1 4000-8991 Run #1 4000-8991 Run #1 8250-9070 Run #1 6659-7110 Run #1 6659-7110 Run #1 6659-7084 Run #1 6659-7084 Run #1 6659-7084 Run #1 6659-7084 Run #1 6690-7050 state~O~ AK.*~/~e~/ NSK C!erk*b! RaW'nme~ l*bl D & M*bl Dri!ling*bl Vault*films ARCO Alaska. Inc. Post Office B.,,. .0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February ].9, 1986 Mr. C. V. Chatterton Cornm i s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are the Well Completion Reports for the following Wells- 2A-12 3I-1 DS i6-21 The bettomhole locations, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic surveys are run and the wells completed. If you have any questions, please call me at 263-4944. Sincerely, O. Gruber Associate Engineer J G/tw GRU13/L148 Enclosures STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COlv~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED;~ ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-4 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50 103-20058 4. Location of well at surface 9. Unit or Lease Name 1447' FSL, 53' FEL, Sec.14, T11N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2A-12 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 123' RKBJ ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/08/86 01/1 6/86 01/1 9/86 N/A feet MS L N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 71 25 'MD 7064 'MD YES [] NO ~ N/A feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, FDC/CNL 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 106' 24" 315 sx CS II 9-5/8" 36.0# J-55 Surf 2860' 12-1/4" 800 sx CS III & 310 sx CS 11 7" 26.0# J-55 Surf 6663' 8-1/2" 200 sx Class G & 175 sx CS 5" 18.0# L-80 6435' 7115' 6-1/8" 140 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, 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-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OI L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · , Form 10-407 DAM/WC21 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of .thy knowledge ~ ~ Associate Engineer Signed___ ~ _ . __ Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show 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 jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~407 AtlanticRichfieldCompany ~'~ Daily Well History-Initial Report 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. North Slope Borough IState Alaska iWell no. 2A-12 District I County or Parish I Alaska Field JLease or Unit Kuparuk River J ADL 25570 Auth. or W,O, no. ~Title AFE 703419 I Drill Nabors 26E API 50-103-20058 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Spudded I Date and depth as of 8:00 a.m. 1/08/86 1/09/86 1/lO/86 1/11/85 thru 1/13/86 Complete record for each day reported J Hour 1/8/86 0200 hrs. IA.R.Co's W.I. Prior status if a W.O. 56.24% 16" @ 106' 444', (298'), Drlg surf hole Wt. 8.7, PV 22+, YP 50, PH 10, WL 9.8, Sol 5 Accept ri~ @ 2230 hrs, 1/7/86. NU diverter sys. 0200 hrs, 1/8/86. Drl 12¼" hole to 444'. Spud well @ 16" @ 106' 2840', (2396'), Drlg Wt. 9.1, PV 18, YP 36, PH 8.5, WL --, Sol 6 Drl & surv 12¼" hole to 2840'. 458', Assumed vertical 1795', 5.0°, N32W, 1795 TVD, .1 VS, 3.8S, 1983', 10.0°, N22W, 1981 TVD, 24.3 VS, 18.0N, 2361', 21.0°, N29W, 2344 TVD, 125.3 VS, 108.1N, 2741' , 27.5°, 7.2W 18.4W 64.1W N30W, 2691 TVD, 279.8 VS, 239.2N, 147.1W 9-5/8" @ 2860' 2890', (50'), PU BHA Cln'g pits Drl to 2890', 16 std short trip, C&C, POH. RU & rn 73 jts, 9-5/8", J-55, 36#, BTC csg w/FC @ 2778', FS @ 2860'. Cmt w/800 sx CS III & tail in w/310 sx CS II. Displ using rig pmps, bump plug. ND diverter. NU & tst BOPE. PU BHA. 9-5/8" @ 2860' 6685', (3795'), Prep to rn 7" Wt. 9.6, PV 12, YP 9, PH 9.0, WL 6.4, Sol 8 TIH, tag FC @ 2778', tst csg to 2000 psi. DO FC, cmt, FS + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl, Navi-Drl & surv 8½" hole to 6064', start losing rtns, POH, LD Navi-Drl. TIH to csg shoe, att to circ w/10.2 ppg, only 20% r tns. 6685', 2835', 3433', 3990', 4719', 5344', 5877', 6187', 6650', Cut mud wt to 9.6 ppg & stage in hole. C&C mud. Drl to short trip, C&C, POOH. RU to rn 7". 30.6°, N31.8W, 2773 TVD, 325.3 VS, 278.2N, 170.8W 37.3°, N32.8W, 3260 TVD, 670.0 VS, 568.8N, 360.1W 36.9°, N29.8W, 3704 TVD, 1005.2 VS, 855.2N, 536.5W 37.5°, N27.8W, 4288 TVD, 1440.2 VS, 1240.0N, 739.6W 37.9°, N26.SW, 4788 TVD, 1815.8 VS, 1573.1N, 913.3W 38.7°, N22.8W, 5201 TVD, 2151.4 VS, 1882.3N, 1045.4W 39.0°, N19.8W, 5443 TVD, 2345 VS, 2063.5N, 1116 W 38.9°, Nll.8W, 5803 TVD, 2630 VS, 2343.3N, 1195 W The above is correct Signature z,,JM For form preparation and di{~ributi~n, see Procedures Manual, Sec'~ion 10, Drilling, Pages 86 and 87. DrillinK Superintendent 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 ali 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 "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 string until completion. District Alaska North Slope Borough State Alaska County or Parish Field ~Lease or Un t Kuparuk RiverI ADL 25570 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 1/14/86 IWell no. 2A-12 1/15/86 1/16/86 1/17/86 7" @ 6663' 6685', (0), Tst BOPE Wt. 9.7, PV 12, YP 8, PH 9.0, WL 6.9, Sol -- RU & rn 154 jts, 7", 26#, BTC csg w/FS @ 6663', FC @ 6571'. Cmt w/200 sx C1 "G". Displ using rig pmps, bump plug. ND BOPE & instl new tbg spool, tst to 3000 psi. NU & tst BOPE. 6650', 38.9°, Nll.8W, 5803 TVD, 2630 VS, 2343N, 1195W 7" @ 6663' 6695', (10), Drlg Wt. 11.0, PV 15, YP 9, PH 9.0, WL 5.9, Sol 9 Tst BOPE; unable to pull tst plug. ND BOPE, instl new tbg spool & instl new adapter spool. NU & tst BOPE. RIH to FC, tst csg to 3000 psi. DO FC, cmt, FS + 10' new formation. 6650', 38.9°, Nll.8W, 5803 TVD, 2630 VS, 2343N, 1195W 7" @ 6663' 6827', (142'), TIH Wt. 11.6, PV 22, YP 12, PH 9.0, WL 6, Sol 9 Drl & surv to 6695', C&C. Conduct formation tst to 13.5 ppg EMW. Drl to 6827', circ out gas cut mud, TOH f/BHA chg. TIH. 7" @ 6663' 7135', (298'), Logging Wt. 12.0, PV 22, YP 17, PH 9.5, WL 6, Sol 16 C&C mud, drl 6-1/8" hole to 7135', short trip, circ gas cut mud out & wt up to 12.0. Short trip, circ, TOH, LD 10 jts DP. RU Schl. The above is correct For form preparation and distribution see Procedures Manual Section 10, ' Drilling, Pages 86 and 87 Drilling Superintendent ARC° Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Field Alaska Accounting cost center code Kuparuk River Auth. or W,O. no. AFE 703419 County or Parish Lease or Unit Title North Slope Borough ADL 25570 Drill State Alaska Well no. 2A-12 Nabors 26E API 50-103-20058 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our ~Prior status if a W.O. 0200 hrs. I Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 1/8/86 Date and depth Complete record for each day reported as of 8:00 a.m. 1/18/86 thru 1/20/86 5" @ 7115' 7125' TD, 7115' FS, RR Diesel RIH to log, sand bridge @ 6680', POH. TIH w/DP, rm 6662'-7125', C&C, TOH. RIH w/SWS, rn OH Logs, Log w/DIL/SFL/SP/GR f/2860'-7118' FDC/CNL f/6577'-7118' RD Schl. TIH f/wiper trip, rm 6800'-7125', C&C, circ out gas cut mud. Wt up to 12.1 ppg, CBU, TOH. RU & rn 14 its, 5", 18#, L-80 LTC csg w/FC @ 7064', FS @ 7115' TOL @ 6435'. Cmt w/140 sx Cl "G" w/l% FL-19, .5% CD-31 & 3% A-2. Displ using rig pmps, bump plug. RIH w/bit/csg scrpr, tag @ 6331', TOH. PU Bkr RBP, TIH, set @ 6222', TOH, LD DP. Displ top 2000' well w/diesel. ND BOPE, NU & tst tree. RR @ 1800 hrs, 1/19/86. Moving to 2A-11. Top of hgr @ 6435' - BP in hole @ 6222' Old TD New TD PB Depth 7125' TD 7064' PBTD Released rig Date Kind of rig . . ::, 1800 hrs. 1/19/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s) Flowing I 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 For form preparation an~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Drilling Superintendent I SUB. SURFACE DIRECTIONAL SURVEY r~UIDANCE [~]ONTINUOUS ~-~ OOL o. Company Well Name Field/Location ARCO ALASKA INCORPORATED WELL 2,A-12 (1446,'FSL,, 53'FEL, S14,, TllN, R8E) ,KUP ,ARUK~ NO,RTH,SL, OPE~ ALASKA Job Reference No; 71383 Loomed By..' HALFACRE Oat,e 06-APRIL- 86 Computed By: HALSTEAD I II I S ~] T .~ "i? .- r T; = il :~ ' STM ~ V - Y K d P .~, :,! U K OF 26 W2ST ARCO ~LSS~A, ZiC. KUPARJ< NS~TH T~U~ SJ:-S, 'A M~ASUR-5 V~RTI:AL V'~T~C&L 3-PTd D-~T~ 3~PTH 3=VIATZ.'I' "1~.* N D .:..3 "! '_- '~ 0.33 0.33 -1:5.33 103.03 lO0.O0 ~00 O0 200 ~3 77 O0 300.00 3]0.3,3 177.00 ~0O.OO ~,30.;)3 ~77.00 30 0 :} 500 . .~0 377.00 JO.D0 ~00..30 ~77.00 /O3.OO 703.33 8DO.JO =00.,.30 577.30 ~00.33 900.00 777.3:3 I000.30 !OSO.OO 577.3" 1130.,)0 1100.]3 1200.33 1200.SJ 1377.03 1300.03 12)9.-) ~, 1173.~,~ 1530.00 149'~.)9 13 13. ~) 1530.03 1~9~.99 ZwTS. ~ ~ 1700.00 16')9.~3 1~75. ~ 1300.30 17~9.7f !57~.~¢ 1ROO.O3 13:)~.34 i77S.34 2000.00 1)97.t5 137;.75 2i00.00 2095.;5 2200.00 219!.}3 2330.0,3 2237.30 2~OO.OO Z3dO.sO 2257.55 2' 0.30 ~73 l~ 2 /.O.} 2554.53 Z~1.55 2BOO.DO 2742.22 2~i~.21 !O ~'J l! ' 5 15 7 ~',J 31 2'3 ? i '0 'I 3 J 12 - ~ ... '7 i: :,.I '{ 3000.00 2911.58 3100.00 3230 .DO 3373 3300.00 3153.~5 3333.6o 3400.03 3253.b2 3liJ.,sz 3500.03 3313.42 ~130.42 3630.03 J~)5.54 3270.~ 3700.00 3~73.~5 3300.00 3')00.00 3633.24 3610.i~ _V'".! 130 =SET *,, 4.--, 3. '' 55.52 2.7f: ., .~ !47.,3~ 1.E2 1~5.~ 1.77 ?25.56 g .23 !~=.07 2.5~ 31:.5~ 2.53 557 .70 2.01 -,21. 32 2,52 47 '9 · 3: '3 · 90 535.40 1.12 597.63 D. 12 7!7.27 ~.97 775.7{ 33~.5~ 3.17 ~5.30 0.10 48. 72. 98. I 2 ). 16! · 194 · 233. '~ 7 0 · 313 · 35,3 · 405. 4~5. 505. 555. 505. 555. 7 O ,5. 757. 808. ATE 3= SJqv'~:Y: 8 "LLY '3US~tING ~-L'=V&TiON: "UL ~R CO3qDiNATES SOUTH -:',ST/WEST -T FiST i9 N O. 31 W 33 S 0. ~ 5 W !4 S 1.13 w ~4 S 1.42 W 79 S 1.'72 14 30 S 1.96 W ~9 S 2.35 w ~9 S 3 ~3 W i3 :.1 5.72 N 54 N 12.26 W 16 :~ 1,~. 12 ~35 N 26.55 21 N 33.5t 45 N 55.0i O0 N 72.55 05 N :~2.4~ 23 N 115.00 15 ~q 14!.18 !4 N 167.33 05 N 195.55 :d3RIZ. .,DIST. FEET 0.00 0.40 0.79 0.93 £.12 1.31 1.23 1.16 1.06 0.gO 123.00 FT 0:3 '4 226.7 9 ,.5 :,~ 259. ,5 I1 N 29.3.2 0 t :'4 32 J . 9 34 t,,l 35S.7 58 N 391.5 17 N 4~3.' · 9 59 N ~+56.7 11 N 489.3 60 N 520.4 DEPARTURE AZiMJTM OEG MIN N 0 0 a N 74 46 W N 63 51 N N 59 40 W N 51 15 W N ~9 43 W N 50 37 W Iq 47 2.5 :,,.,I N 44 52 W N 53 1 ~,; 0.83 N 77 1 N 0.95 S 85 24 W 1.15 S 73 8 W 1.48 S 72 33 W 1.89 S 65 30 W 2.35 S 55 24 N 3.02 S 51 16 N 3.57 S 68 47 W 7.88 N 58 24 N t9.02 ,q 40 7 N 3~.55 55.55 81.88 112.78 !4~.00 185.72 225.23 270.0:1 317.77 35'9.27 ~23.84 4~!.87 541.42 501.07 561.12 721.33 781.23 ~41.34 901.50 961.59 N 32 42 '~ N 28 36 W N 25 7 W N 29 11 N ;4 29 21 W N 29 51 W ~4 30 50 W N 31 31 ~4 N 32 1 W N 32 20 W N 32 35 ,,4 N 32 47 W q 32 50 N ~4 32 51 W N 3'~ 52 W,, Nj 32 52 W N 32 52 W N 32 52 N N 32 45 ~ 2,:.1-12 N3qTd SLIP:," TRij: ]=PTH ,r.,. 3 O 0.9 O 3713.;.'31 ~lO0.O3 3793.5.5 ,:+200.00 BB73.7.J 4300.00 3954.20 ~433.03 4335.31 ,"-O0.Oj ~i15. i0 )0.,30 ~194.27 4~3,3.03 ~353.'5 5000.03 ~515.~2 5100.00 4594.7~ 5200.30 ~574.27 5300.30 :,753.17 5~00.00 4~32.35 5500.00 ~SlO.5~ 5600.00 5700.00 5~00.00 ~142.~0 5900.00 5220.51 6000.00 5298.24 6100.00 5375.51 5200.00 5453.17 6300.00 5530.~I ~400.30 5609.22 6~nO.O0 5637.~2 ~( ~ O0 5765. 51 ',-,J:O0 5344.37 6~00.00 7000.00 5073.35 71J9.00 5149.20 7125.03 5163.23 i NT '- :: j 3L 2, T - :3 v:-,'-~TI D:Vi :IT 35'~0 . 31 3573.55 .5730 ~12.01 399' .1J ~-" '7 ! . 2 {6 36 36 36 36 37 37 37 -- ~ 3.5 37 "57 !~ ? ~., 14 4.3 ~t 5'75.2~. ~252.51 -330.!7 J407.-~l 55 ~', '-,-. ') 2,_ 55~3.5i 5721. ?7 J79J.l~ 5 d 73 . 95 3 7 J 9 3 '5 32 ~O !2 43 5?.:. 595 ;', 50Z5.20 5345.2.3, 4O 4. :3 VL j" ) F,]-: _V- ~ i3<) C2JRS':. V- :.!Ti3.1L ",, 3:,,' v .-, 'i .... T N ~ ! W 2914.80 KELLY 3USHIN:3 ELc'VATiSN: 0.3) {60.!5 N .=5,3.93 w 1321.46 1.85 911.96 tN 58j.5_~ W 1081.06 ;3.2~ '~04.~3 N 60:~,.20 :4 1140.61 ,].42 I~17.75 N 535.67 W 1199.79 $.5a 10~9.77 N 552.94 W 125].53 0.37 1!22.~1 N 691.11 W 1313.29 3. ~?a 1175 . !7 N 7o0~ . 43 N 1379.28 0.73 1.!29.52 N 749.:~3 W 1440.11 3.4~ !:Z~2.59 N 778.76 ~.~ 1500.51 3.3~ 1334.93 N S07.62 W 1550.22 2.0~ i,38.~,0 N ~65.00 N 1675.37 1.2,~ 1491.!5 N ~94.49 W 173.3.95 3.~? 1545.:~9 N 923.35 W 180J.31 1.5~ 159~.35 'J ~52.14 ~{ 1951.32 2.,5~ 1655.37 N 979.58 W 192'3.49 ~.24 1714.33 N 100~.73 W 19~6.80 0.43 1772.5~ N 1029.35 W 2049.87 0.64 1{$0.75 N 1054.1i W 2112.54 o.p '97.9~ N 1079 06 W ~174.59 !.0i 1945.68 i"4 1103.49 W 22.35.82 3.$7 2004.59 N t12'7.18 W 2299.76 0 ...... 54 ~063 31 N I14~ 95 W ~36~=.1.$~ 1.13 2122.39 N 1171.53 N 2424.26 3.67 21~1.~9 N 1190.91 W 2~85.39 0.74 2240.55 N 1208.72 W 2545.80 1.27 2300.28 N I224.69 W 2605.93 i.13 2351.45 N 123B.70 W 2566.51 1.40 2424.13 N 1252.00 W 2728.35 2. SO ~448.03 ~] 1254.97 W 2791.14 3.00 2552.03 N 1275.51 N 2353.0~ O.O0 2516.05 N 1295.7~ W 2914.95 O.OO 26'~2. .06 N 1o83- .32 W 2930.44 1~3- · O0 FT OE?&RTURE AZIMUTH DES MIN N 32 38., W N 32 28 N N 32 13 W N 31 59 ;,/ N 31 47 W N 31 37 W N 31 29 ¢~ N 3i 22 W N 31 15 N N 31 10 W N 3 t 5 ;~ N 31 1 W N 30 57 W N 3O 51 W N 30 45 W N 30 36 N N 30 22 W N 30 8 W N 29 55 W N 29 44 W N £9 33 W N 29 20 N N 29 7 W ,~ 28 53 W N 23 37 W N 28 1 W N 27 40 W N 27 18 W N Z6 56 W N 25 33 N N 2.6 10 W N Z5 4 W , 2A-12 N3RTm 3L" Pt, AL :~ SK.~ ET,iT -4n-Lr~T''3 'v' ]L:V!~,T! 3,4 -~l 3-:3 ,Ii'~ F-- 0.03 0.00 1000.09 1000.03 20S0.03 1'~97. 75 3000.00 2911. 400 O. 3 ~ 3713. '~ ! : '90.03 4513. ~.l '~ ,~00. O0 :3073 · 7125.30 ~I~. -12: 377.00 1574 ~76:J .65 J 3,'~ .3.31 ~3')3'.92 0.33 ~2'1.~2 I016..05 1614.37 223~.1Z 0. O{ 5,.5! L.62 O.~O i .0! 0 · 0,3 3. O0 3!T~! O~ S,JRVEY: B MiR 36 NELLY 3USM!:qG ELEVAT!3N: O. 23. 753. ~ .50. 1 39 $. I :345. 2532. 2~.32. £0 D~PT PAS5 3 123.00 FT ]UU~R CO.3R3I>4ATES ~3RIZ. OEP~RTURE ST.JTq EAST/w~ST DIST. AZIMUTM T FEET FEET 0~:3 MIN O0 N 0.00 ~ 0.00 1~+ ~.~ o.~l w 0.83 i= '~ 13.72 w 34.65 o{ N 22~.76 w 15 "i 55,3.33 W 132!.~6 64 ~! ~36.37 W 1519.52 53 >'~ i!03.~) W 2236.82 03 N 1275.6Z ~ 36 N 1239.32 W 2930.44 N 0 0 E N 77 N 3.~_ 4~ ~ N 32 20 W N 32 35 W N 31 ,q 29 33 N N 25 33 N N 26 4 W 2~-12 KJP~RUK NO~,TH S' 3P~ ~' ~S<,' T RU ' qE;NSURE] v~ZRTIZ~L JZPTd 1 g 3.00 i 23 · 30 223. 30 223.30 323.03 323. jO "' 3. O O ~?. ~ · 00 3,00 523,j0 =23.30 523,0J 723.00 723.33 ~23 JO 3P3 J'~ 1323,03 1023.00 1123,33 11'23,05 122.3 . 00 I 223. O O 1323.01 1323.3~ 1~23.01 1423.30 1523.01 1523.0'3 1623.01 1~3= .0~ 1723. 1823,36 1~23.00 1924,21 1923,00 2025,73 2023,0J 212.3,43 2123,09 223!,47 2223.53 2333.35 2323.00 22i' '=.,60 ~..~)3,~0 .35 2523. O0 25'o~.81 2623. O~ 2777,91 2723,00 2894,21 2323,J3 3013,7~ 2923,33 3137,25 3023,J0 3261,71 3123,00 3385,70 3223.33 3511,)5 3323,30 3636,83 3423,00 3762,02 3525,00 33~7,1~ 3623.00 4012,05 3723,00 4136.76 3823.00 1230.05 i ~,53. )C i-3'~ ~'3 t 5,03.0 O iTOO.O,3 OAT= 3= SJ!~VEY: J ",IA:< 86 :<':LLY 5OSHIN:$ ~L=¥.~TiO.,'--I: -i, ') .~ . i _ '°33 3. },j -- b . 3 -- -' · .D C ! ,2~ 2 ~ O1 ,5 !..5 ~ 91.27 i2]. ~7 LO7. OZ ~.~q 305.72 : fl7 ~Zg. 52 531.30 640.40 7 '~ ~3. 7 9 a73.61 ~4~ J.!7 0.i1 0.i! 0.12 '~,44 0.25 5.27 O,9O ).19 1.47 i O~ ? O0 ~.~ O.~ !.7~ 5.04 !, 2~ 17.7~ 3,00 35,75 3.4,,} 55.28 2.77 30.20 1.99 109.35 i,30 143.33 ?,!5 179.95 ,!.73 261.00 2.0! 310.53 2.6! 354.48 0 · 90 424, ~3 0,79 435,7'3 9.25 543.53 3.65 61!.5~ 0.!$ 574.74 0.38 737.87 O. 19 ~0i .97 0.45 ~6 5.34 0.55 931.42 H]RIZ. giST. =e=T~ O. 3 0 '3 · 0 2 ,,.. 47 0.75 0.~2 }. a "3 1.0~ . O. 03 0.74 0.00 ] ,02 0,50 0,~5 0,98 t,16 !,31 1,21 1,13 ! ,03 0.73 0,84 0.99 !.18 1,49 !.78 2,05 2.45 3.53 7,96 !B, 72 20.45 29, 50 43,55 51.7i 81.14 10~.73 132.26 161.41 19~+.12 231.15 272.22 313.47 354.34 .3'95,41 435,03 477.03 515.50 554.59 590.80 0.35 0.~5 1.00 1.21 1.5~ 2.00 2.50 3.16 9.~9 22,~2 39.49 62.66 91.31 12~o00 154.75 Z07.43 054 I1 306.58 365.2! 431.51 504.06 578.14 653.11 728.53 ~03.37 878.54 953,90 1023.64 1102.99 ,: 123.00 FT DEO~,RTURE AZIqUTH DEG MIN ARC3 ZA-i2 TRU S J '5- '.; :,.I 3 d P T'"t :.3 -PT "-i :3 -s T'"i W25! .29 3523.90 w3S5.1, 4536.22 4223.30 4762.3 .J 'BT.DZ 4~23.33 ~,35.25 4523.30 5261.83 53~S.15 ~32~. 5516.23 45) 23.'50 4',35. 55~6.37 5023.30 5775.33 5i23.0;3 5:333.~3 5'903.43 5223.03 5i93 6032.0~ 5323. 30 1,2,53. 6161.1 ~ 5.23. O 3 5300 · 03 6239. a 5 5523.30 ' ~+:33 · 0,3 5417.53 5623..33 553').7:3 55~6.53 5725.30 55:30 6572.3') 5.323.03 5733.50 6 934.25 60 £3.30 5'40 3. '} 9 7065.60 6123.35 5953 .03 7125.00 616.~.23 5.345.!3 ~ -LLY SJS~IHG -'t -V~T!DN: :qG!q-':R: "t~' F~CRF- FiE ~ ') 7. ,-~ 002. ! 12'7. ii. · 1252. i~,2. !~55. 1524. 1 '2175. 73 '). 2 i ~9S. 2~54.48 3.05 1304. 2535.7) 3.95 2340. 1415. 23 1.53 2116. 2~)4.7~ ).77 21~i. !~71.72 i .2) 2266. 1549.33 2.I~ 234~. '3UL.'iR C"O2nT'~AT{S HDRIZ S2!JTd f.2. 5T/~{ £S T DIST. T FEET FEET · 24 ~,t o/'s.d8 ;4 1175.95 OZ '.I 65~. ~9 W 1249.81 ¢7 }4 ~Dllj'"'~' 33 x 1324.39 ~ ~ N 767,74 '4 !%717.67 17 q 603.:}9 W 1552.50 56 }4 ~13}.63 W 1626.17 6, N 875.37 W 169~.43 94 '.~ ~12.3~ W 1775.96 )4 N 94:{.7; W 1254.07 .~3 i ~83.7~ 08 ~.~ 1015.I1 4:5 ¢4 1047.9B 93 :I 1079,91 61 ~! 1111.15 4~ N !!~1.27 83 N 1194,13 97 N 1!16.11 }7 ~ 1234.95 123.00 FI 6S N 1252.32 9} I !258.91 02 N 1282.28 05 N 1283.3:2 DEPARTURE DEG MIN N 32 & W N 31 36 4 N 31Z$ H N 31 13 W N 31 11 W N 31 5 W N 31 0 w N 30 53 W N 30 46 W W 27Zg.87 N 27 1~ W ~ 2B12.45 ~ 26 49 ~ W 2~30.,4 q 26 4 N 1933.77 N 30 34 ~ 2315.8') N 30 16 W Z3~7.10 N 29 53 W 217~.70 N 29 44 W 2257.~7 N 29 29 W 2337.~6 N 29 13 W 2~17.99 N 23 55 W 2495.01 :>~ 25 34 W 25'72.56 N 2,3 1Z ~ 2649,75 ~ 27 46 W Z.~-12 KJPARU~, N]RTd 5LOP.~, AL.~SiA TOP 5 ~2'b 51TM h16'~.23 > 72. :--~. 30 5922.54 c: 345.23 "'AT_, .3': ..~U4¥;Y_ '. :3 .'.1~ 86 K:LLY ?.j~JiN~'.., . ,= El_ ~-VATTJN: ..~. · .-I~' =~CR= · 123.00 5FL, SOR=A-E LOCATION 53' FEL, SEC lO, TllN, RSE, 75CT~N'.ZULA~ COORDINAT~.S N3RTH/SSUTH EAST/NS'ST 233!.~$ N 1243,11 2415.52 N 1250,39 2~26,03 N 1252,40 2573.9~ N 1271.95 25~3.00 N 12~2.12 2532,05 N 128~,32 FT D~TE 3F SURVEY: .3 M,~ 85 Zfl-12 ~dP~qJ~ ~.:-LLY 3USH!qG ~LEVATION: ,.'.~ N ~: dA' 123.00 S R,:CT gRFA2E LOCATION ~T L, S2C I~ TllN, TM/S]UT~ EAST/N~ST 3T~ 23 24 25 25 25 ~!.~5 N 1243.11 16.52 N 1250.39 26.03 q 1252.40 28.93 N 1271.95 93.00 N 1282.12 32.06 N 1288.32 T2j: SJ,3-S- ~i DEPT~ 3~?T'~ 3 '~T~ 7125.03 Sl~ :3.23 ".-.0:~5. 2 ~ FT SCHLUMBEROER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC WELL 2A- 12 FIELD KUPARUK R!VER COUNTRY USA RUN ONE DATE LOOOEO 08 - MAR - 88 REFERENCE 71383 WELL 2A-12 (1446'~SL, 53'FEL, Sl4/--'~'llN, R8E) HORIZONTAL PROJECTION NORTH ~00 ~ooo 25OO ~000 1500 1 ooo SO0 REF 71~8~ 80UTH -500 -~SO0 WEST · . ...~...~...~....~...~..,~....;... : .....~....!-..~....L...i.-,.k.~ ~i: "**T'"T*"T'"T"*T'"T"'?"?'"T'" · .... ::~ .... ~' 'i*'*i ~ i .... .,..~...~ .,L..i...L.~...~....i..,~ ':~'~'~' ......... ...~.*.~....~...~.*-.I...~...~-...i....i ~ ........ ....L..!...~..~....L..~....L...L...~ .... .... !'"*!'"*!'"~'"~*-'F*'~"+'*~ .... i'ii' +'"i*"~'"~"t'*'?""r~'"~ .... i . · . , ...... ...... .... ~...;.4....i...~..~....; ....... ~-*.i...i-.-t.-~...-:----i*..i...i** ' --.~-..~*-i.4-.F~....i.. !.4 .... ~ ~ , -2000 - l SO0 - 1000 -SOO 0 soo l ooo l SOO EAST WELL 2A- 12 (1446'F.SL, 53'FEL, S14, TllN, R8E)/ VERTICAL PROJECTION SOUTH -SO0 0 0 SOO ]000 ISOO ZOO0 2500 3000 9SOO NORTH PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN VERTICAL DEPTHS HORIZ SCALE = I/SO0 IN/FT I~/NI OOS/[ = 39U3S ZI~0H SN£~30 9U2Ii~3^ NI 039U3S '6SI - '66E 3NU98 9U311~3^ NO NOI133P0~8 · E6E OOSE O00E . . . NOI.T. DM£OM~ ~lVO I.T.M.qA (MgM 'NII£ '~IS '~l.q~I,Eg '~iS.~,9~PI) 6'89[9 030 6'~6~ ±S3M 33N~±SIO H±~ON 33N~£SI0 Hi,BO ~3I±~3^ 3n~l Hid30 03WRSWBN NO I ±u30q HInNIZW 3swno3 HION39 3SWR03 390H HOllO8 i~ O' 0 ISW3 33NU/S I 0 1~ 0'0 HIWON 33NUISI0 i~ 0'0 H£830 9W3IIW3A 3RW/ i~ O' 0 H1830 OBW~SW3W NOIIU309 NI-3II OOHIBH 3WOIUAUQ3 ~0 SO lOUW i3UX3 · Suggested form tO be inserted in each "Active" wel! folder to chec~ for :timely compliance with ouz regulations° ' ':x* Reports and Haterials to be received by! ',~~~~_~.~ · Data °. Date Received Remarks Completion Report Nell'llistory Samples o- Hud Log "-Core Chips Registered Survey Pint Inclination Survey · · Direc tional .Survey Drtl! Stem Test Reporte Froductton Test Reports Log Run ~,~. Digitized Data ARCO Alaska, Inc. ~-.=~/_~ Post Office r ]60 Anchorage, Alaska, 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton' Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 ~Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED FEB 1 3 1986 Alaska Oil & bus Grins, 13un,mission Anchorage .~- .... STATE OF ALASKA ALASKA -. - .,ND GAS CONSERVATION CC .,,~ISSION , ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-4 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20058 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 1447' FSL, 5:3' FEL, Sec.14, T11N, R8E, UH 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 12:3' RKB ADL 25570 ALK 2668 10. Well No. 2A-1 2 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. January , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0200 hfs, 1/8/86. Drld 12-1/4" hole to 2890'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 6685'. Ran, cmtd, & tstd 7" csg. Drlg 6-1/8" hole to 7125'TD (1/16/86). Ran logs. Ran, cmtd, & tstd 5" csg. PBTD = 7015'. Set Bridge plug w/top ~ 6225'. Secured well & RR @ 1800 hfs, 1/19/86. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 106'. Cmtd w/:315 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 2860'. Cmtd w/800 sx CS Ill & 310 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 6663' Cmtd w/200 sx Class G. 5", 18.0#/ft, L-80, LTC csg f/64:35, - 7115'. Cmtd w/140 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/2860' - 7118' FDC/CNL f/6577' - 7118' 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report ~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. c~.m I n_~n~ DAM/MR16 Submit in duplicate ARCO Alaska, Inc. Post Office Box ,d0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 22, 1986 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 9- 12) 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, d. Gruber Associate Engineer JG/tw GRU13/L19 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JAN 2 7 ]98, Alaska Oil & Gas Cons. Commission Anchor~e ~" ~'~ WELL 9- , = 5,960,687.74 X = 498~340 70 -- ' LAT 70° 18' 13.7715" '"" '""i ! LONG. 150° 00'48.387': i ! O.G, 87.6' PAD 92. 1,2.66' FSL 53' FEL i~ · ~ 0~4 i WELL I0- ; ~ ! Y: 5~ 960,747.76 9 · O 16 ; x = 498,340.70 ' LAT. 70°18' 14.3619 [ ~ ~ON~. ~oooo'~.~8" i .... O.G. 88.0' PAD 9~.~' ~ ' 1,5~6' FSL 5~' FEL i I WELL II- , Y: 5~960~ 807.80 ~ X: 498,340.85 LAT. 70° 18~14.95~5 ' LONG. 150°00 80 ~ 0 I O.G. 88.3' PAD 92. 70 i ~ ~,~eT' FSL 53'F~ SO = 03 ~ = WELL 12- Y = 5~960~67.74 ~ X = 4~8~340.71 LAT. 70°18~ 15.54~0" ' ~ LONG. 150° 00'48.388" o.~. se. 5' PAD 9~.0' i ~446~ FSL 53' FEL ~OCATZO ~N P~OTRACTED SECTION ~4, T~N, ReE, ~ ~ ~ ~ m-~" ~~.~ UMIAT MERIDIAN. NOTES ~ ~ ~ ~ I. COORDINATES ARE A.S.R, ZONE 4. ~ Z ~ 2. SECTION LINE DISTANCES ARE TRUE. ~ ~ __ 3. HORIZONTAL POSITIONS BASEDON 2A-NORTH ~ 2A-SOUTH ~ ~ - 4. VE~ICAL POSITIONS BASEDON 2A-MIDDLE PER LH.D. ~ ASSOC. DWG. NO. NSK-6.201-dl. ~ 5.0. G. ELEVATIONS INTERPOLATED FROM S/CDWG. CED- BAO0- 3001 rev. ~ D.S. LICENSED TO PRACTICE LAND %URV~YING IN THE STATE OF A~ASKA AND THAT THIS PLAT ~EPR~S~NTS A SUrVEY'MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS 14 18 ARE CORRECT AS OF D.S. 2-A ~HIS/SURVEY t~, ~ ARCO Alaska, Inc. ~ i Kuparu~ Project o J ~, ~ ~ .~'~ DRILL SITE 2.A J ~ : ~,, ~~~ CONDUCTOR AS-BUILT January 6, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2A-12 ARCO Alaska, Inc. Permit No. 86-4 Sur. Loc. 1447.'FSL, 53'FEL, Sec. 14, T!IN, R8E, UM. Btmhole Loc. l149'FNL, !406'FEL, Sec. 14, TI/N, RSE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. 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. I~rhere a diverter system is required, please also notify this office 24 hours prior to commenc~.ng equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve ~tr-.~ ~ ~l?s~ l C. V. Ch-~CtefCtOn Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF ~E CO~ISSION Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA -- ALASKA ~JIL AND GAS CONSERVATION CO,vIMISSlON PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVIC~I--I DEVELOPMENT OIL ~X SINGLE la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1447' FSL, 53' FEL, Sec.14, T11N, R8E, UM At top of proposed producing interval 1384' FNL, 1288' FEL, Sec.14, T11N, R8E, UN At total depth 1149' FNL, 1406' FEL, Sec.14, T11N~ R8E~ UN 9. Unit or lease name Kuparuk River Unit 10. Well number 2A-1 2 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. RKB 123', PAD 92' ~ 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-13well 280' ~ surface feet 16. Proposed depth (MD & TVD) 7212' MD, 6246' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1641 feet. 21 Distance and direction from nearest town 14. Distance to nearest property or lease line miles 1149' @ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 37 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 01/06/86 2989 psig@___80° F Surface . 3436 ..psig@_ 5900 ft. TD (TVD) SIZE Hole Casing 24" 16" 12-1/4" 9-5/8" 8-1/2" 7" 22. Describe proposed Weight 62.5# 36. O# 26.0# program; CASING AND LINER Grade Coupling H-40 / Weld l -55/HF-EIW BTC Length SETTING DEPTH MD TOP TVD 80' 32' I 32' 2849' 31' I 31' l I 31' 31' ~ 71 81 ' M D BOTTOM TV D 112i 112' 2880 1 2795 , I 7212~ 6246' I QUANTITY OF CEMENT (include stage data) + 200 cf 810 sx CS III & 310 sx Class "G" 400 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7212'ND(6246'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Due to gas injection on 2A Pad, Kuparuk "C" Sand pressures are higher than normal. Expected maximum surface pressure is 2989 psi. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2A-12 will be 280' away from 2A-13 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. (continued on attached sheet) · 23. I hereby cer, t, i4~ that the foregoing is true and correct to the best of my knowledge _SIGNED //~/~, ~.,~ TITLE Th e space ~/~w~f~(f_,zCmfis~on use "~ - Regional Drilling Engineer DATE //..~~/_//_~.,)~, CONDITIONS OF APPROVAL Samples required Mud log required []YES ~NO []YES [~NO Permit number Approval date APPROVEDBY.( ~//~. ~ Form 10401 (JFB) ' PDYP~200 Directional Survey required J APl number ,I~JYES []NO J 50-/O ~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 6, 1986 by order of the Commission Submit in triplicate PERMIT TO DRILL 2A-12 (cont'd) The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. 300. 1.00 !. ;- · , 0.00. ..ii -'-- - · ~' :1:',." . i - N. , .... : · ', ~ ~ .. : , , : . . .I ' " ,~.,.' ~ : ~'": i ..... i .......... ~-'* '"," ' I ~ .... ~ : ! i ; : . ~' ' - - ~ ~ ' ' -~ ' . ~ i- i -"' t ~ ~ 't ' ' ' ..... ~ ' : ' ~ :] , ;. ,----. . . ~~ . . ; ..... . . _ · · ~ ~ , : . _ ;~ - , ', , . ~ ~ ....... ] ~ .... : , ~ . , ,:1 ,. - "'::'i" J ': ~ ~ ~~ .- ~-.- , ..... . ~~ ' : ~ : ' ,. ,~'- ..... .... ~ ~ .... i ~ . . ' 'z - I . - f ' ' ~ - ! ~ . T - ' ; ~ ' . ~ · 'i , ~ , ~ ~ ' '-~i *:' ; ..... ; .... i ~'~*~~~~-- ' ~ ' -'~~ . ,,* ; ~ - i .1 ' · '~ ' · , ' ,~* ' ~ ' ~ · ~ .... ;" I ~ i " . ...... ! . · [ -. / : ~ · , ' '' ' ,J ~ ,, . ] , ~ , ~ , ~ , ~ . ~ - ~ ' . .~ I ...... ; : : J . : : - . : ;... ' '~ ' : ~ ~ ~ t~, ~U ,_ : ,. ; ~ . · . · .._ : . , :~;' :~':.: ~,: i~.~ ~'~ "~ -~ Tr~-~: ~~0~ "-~ ;' -= 'l -1': ., ~_~ ................ ~ .............. , ~ ~ -~~-= ........ i ........... .., . [ ..~ . ~ F - ....... ~-~ .... i ~: I / .. · - ~ ....... ' { ' ' - [ · .~ -. .... , ~ : T i ' , ' ' ' ~ : { ~-~ ' - ; ....... : '- ' - · : ~ . , ' ' : ' t' ' .J .. ,. . / . · . =.:., _~ ..... _ . ...... ', . .- ~ , ~ . · ' - ' 2 . '-- J - --- -i - . . ~ : · ~ ' ~ , : - ,, · : "t 1 '. ''~ :~ : ' i ': ' . ~ ..... : i ' ~ { - ' : : ~ . I ' ' ' ~ , ' . ' , ; . , L ' . ' -'' ' ' ~ I ' ~ ~~ j .' " I " . J I ' , '"J ' ' : .. __ - ~ .~ .... ~.~.__~ ..... ... . ~ ._ ...... ~ .... :._, .......... _~ .... ' ~ ' · ' I ' · , , - · ~ , . ' I . I - · , ~ i = * ,-' , ; , , , ~ . _ _.[ , ~ ,' ...... :~ ~' ~ . ' ~ ' ~ . '- . : . : - -i .... ' ; . , ' ~ . . ; - ' ' ~ ~ k - -~ ' !. '~ .... ' -- ~' ' l- · ~'.~ ..... ~-: -~ .... ~ :'~ ..... ': ":' : ,. · ~ --~ : J --~W~---- : ~~- : · -- t ~ .......... ~ ~ T' - ~- , ,, ~ , , ,~ . . . , KUPAIRUK RIVER UNIT 20" -DIVEJ2TER SCHEMATIC · DE S CR I P T I ON i. I 6 · C~CT 2. TANIKO STARTER HEAD. 3. TANKO SAVER SUB. 4, TANKO LOWER QUICK-CONI~CT ASSY, 5. TANKO UPPER QUICK-C~CT ASSY, 20" 2000 PSI DRILLING SPOOL W/I0' OUTLETS, 7. I0" HCR BALL VALVES W/lO' DIVErTER LIt~So VALVES OPEN AUTOMATICALLY UPON CLOSURE OF A~AR PREVENTER. 8, 20" 20CX3 PS! Aha"~LAR PREVENTER, 4 . MA:I NTENANCE & OPERAT.] ON I. UPON INITIAL INSTALLATION. CLOSE PREVENTEr AND VErifY THAT VALVES " HAVE OPENED PROPERLY. 2. CLOSE AhaNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS, CLOSE ANI~JLAR PREVENTER IN THE EVENT 'THAT AN IhFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, IF NECESSARY, MADaJALLY OVERRID~ AND CLOSE · APPROPR I ATE VALVE TO ACHIEVE EX)~NWlND DIVERSION. DO NOT SHUT IN ~E~LL ii r,~:'r' ~ 4 5~g~ U~R' ANY C I RCUMSTANCES. . Alaska Oil & Gas Cons. C~{.~,, ....... 7 6 15-5/~" ~:X:X) PSI RSRRA BOP ~TACK i. 16' - 2~ r-.~.~ TAhKCO STARTINB I-F_AD 2. II' - ~ PSI CASING 5. I!' - ~ PSI X 1~--.~8' 4. I~~ - ~ ~I PI~ G. 1~8' - ~ ~I ~ ACCLIVldLATOR CAPACITY TE~T I. CI-ECX AhD F'/LL ACO. M. LATOR RESERVOIR TO LEVEL WITH HYERA~IC FLUID. ASSLRE THAT ACCLIVEJLATOR Pf~ IS 3000 P~I WITH 1500 PSI D~TREAM CF THE EEGU. ATC~. ~. ~~ TIIwE, ThEN CLOSE ALL Lt~TS AhD I~C01~ THE TII~ AhD PRESSLRE REMAINING AFTER ALL Ut~T$ ARE CLOSED WITH O'IARG]NG R.M=' CFF. ,4. RECOI~ ON NN~ I~-PCRT, THE ACtI~TABLE L0eL:'E LIMIT IS ,45 SE~ CLOSING TIM~ AhD 1200 PSI REMAIhDNG 5 4 iim ii 2 RECEIVE . 13-5/8" BOP ~TACK TEST I. F3LL BOP STACK At~D C~ MANIFCLD WITH ARCTIC DIESEL. 2. O.'ECK THAT ALL LOCK OO~ 5K=REWS IN VF_.LL~ ARE FLA.LY RETRACTED. SEAT TEST PLUG IN YF, LLPF_AD WITH RUINING JT AhD I~N IN L~ LIINE VALVES ADJACENT 'TO BCP STAO(. ALL 4. ~ UP TO 250 PS] AhD I'OJ:) FOR 10 MIN. IN-- OREASE PRESSLRE TO 3500 PS] AhD HOLD FOR IO MIN. BLEED I:~E~__.m:~E TO 0 PSI. .5. OPEN AhN.J_AJ~ PI~-VE~ AhD MAhLIAL KILL AhD CHO~ LINE VALVES. CLOEE TO° PIPE ~ AhD HCR VALVES O'J KILL Ah/:) O-10KE LINES. 6. TEST TO 250 PS~ AhD '~:~X:)~! AS IN s'rEP ,4. 7. CONTIN.E TESTING ALL VALVES, LINES° AhD WiTH A 250 PSI LOm~ AhD 3500 PSI HIGH. TE~9' AS IN STEP 4. DO hOT ppF'A'Ag_I~ TF'~'l' ANY CHO<l~ THAT IS h°T A FULL CLOS]N~ ?OS]TIrE SEAL CHCKE. ON.Y B. CPEN TOP PIPE RAMS AND CLOEE BOTTO~ PIPE TEST BOTTCIwt PIPE R~4S TO ;~O PS] AN:) 5500 PSI. 9. C~N BO?q'Dwl PIPE RAMS, BACX OJT ELtQ~NG J'T AhD I0. CLOSE BLIN:) EAN4S AhD TEST TO 2E:O PS] AhD 3500 PSI. II. OPEN BLII~D R/ilWIS AAD RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AhD LIhES ARE FLLL CF FLUID. SET ALL VALVES IN DRILLING POSITION. 12:. TEST STAhK:PIPE VALVES,. KELLY, KELLY COCKS° DRILL PIPE SAFETY VALVE, AhD IhSICE BOP TO 250 PSI AhD REO:RD TEST I~T~0N 04 BLOViO. rT PREVENTER TEST FOR~, $I(~g AhD SEhD TO DRILLING SLPEEVISOR. PERFORM COwPL~ BOPE TEST AFTER NIPPL]NG UP WEEKLY THEREAFTER FI.J~TICNALLY DPEP, ATE BOPE KUPARUI~SkI~ ~' & ~~~~' BOP STACK 5 ~ oo84oo !_ ARCO Alaska, Inc. =~ Post Office Bc ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2A-12 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill 2A-12, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on January 6, 1986. If you have any questions, please call me at 263-4970. SiI~cerely, ~ Regional Drilling Engineer JBK/JFB/tw PD/L200 Enclosures I ECEIVED Alaska Oil & Gas Cons. ARCO Alaska, Inc. is a Subsidiary of AtlaniicRichfieldCompany . _. ~- 'Loc 2. (2 thru 3. 4. 5. 6. ~ th:u 12), . ~ 10. :(10 and '12) ~" 12. ' ~13 thru ~1)/ 14, 15. 16. 17. 18. 19. 20. 21. (5) BO~E /~/ /~&7/~5~ 22. { 22' thru/26~ 23. 24. 25. 26. (6) Add: /~ ~~ 27. Is the pemtt fee attached' w 11 be loc d in deft ed p 1 ' ~ .Is e to ate a n oo ............................ Is well located prOper distance, from property line............ ......~;~ Is well located proper distance from Other wells ..'''''''''''' . ' , Is Sufficient undedicated acreage available in this pool. . Is well to be deviated and is wellbore plat included ..' it b b f d it ' *app d ore ten- ay wa ......................... ~ Can perm e rove e __ Does operator have a bond in force .................................. Is conservation order needed ' a eeeeeeeee®eeeeeeeeee®e®*e®eeeeeeeeeeee Is administrative approval needed ................................... Is the lease number appropriate ......................... 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 .... i]. ' ' Does BOPE have Sufficient pressure rating - Test to _~ ugrP psig~ ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: REMARKS o H o r.~ ,-] Geology. Eng~eero[ng: WVA ~_ M~ HJH JAL~ rev: 03/13/85 6.011 INITIAL '" GEO. 'UNIT O'N/OFF POOL CLASS STATUS AREA NO. SIIORE 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. LiS T~~:, -~ WSRI;iGATiON LISTING LV~ OlO.H02 VERI=IC4TIS~ LISTIN3 PASE i ~ qEEL HE~DER ~$ SEq,!CE NA~E :EDIT D~TE :B6/OZ/ S ~RI~iN : ~E~L N~E :14925B ~REV!DUS REEL : 5O~ENTS :LiBRarY T~PE =ILE N4ME :EDIT: .001 SERVICE N:4~E : VE.R SZON ~ : DA~E : MAXIMUM LENGTH : t02~ FILE TYPE : OREV~OUS ~ILE : ,-:;-~ iNFORMATIOD~ RECORDS CONTENTS SN : ARSO 4L~SKA ~N : 24-12 FN : K~P4Rg'K R4NS: 8E TOW~: 11~ SE~T:~ 1~ CO~: N.SLOPE ST~T: ~L4SKA STRY: US4 CONTENTS i N C 3NI T U N I T T Y P :_ 000 OOO OOO OOO 000 OOO 000 TYPE C4TE gO0 000 DOg 000 gOO O00 gO0 gO0 C~TE 300 O1B 0,05 008 002 00~ 002 012 005 OO3 SIZE 065 065 065 055 065 055 065 055 055 055 LVP ~IO,H02 VERZFZCATZD~ LISTiN~ PAGE ST~ JOB LOrn NU~DER .AT ACC: 71237 ~D~E, DATE ~GSED: I7-JAN-8$ SAS TY~ 9EN FLJ ZNG : 7,0DO" ~ 6552,0" --' FLJID : LSND WEZGHT~3 SZT¥ : COSZTY : 39.0 S : I0.0 ID LOSS : 3.8 RiX S ~,NOSTLIN E SIZE RM R MS : 6 · 1 Z 5" B HT T~ : 3-370 : 2. 800 : 3.8~+0 :' 1.906 75.0 75.0 135. DF DF DF LV~ OIO.~OZ VS~IFICaTI~ LiSTIN3 ~AG~ 3 -,- SSHL~~3=R 'LUGS ! LU:DED ~ , -,-.,. ~= D3AL INOU'T'I~N' SP~ERIS~LLY FDS:USSD L03 (OIL) ,- D~T~ ~V~ILA8.5: 711D.O f:3 5559.0 ~: F3RMATiON DENS~T'Y COMPENSATE~ LOG (FD~) ~' .,e C3MP~NS~TED N~UTRDN L~G (FDN) ¢ D&T& ~V&ILABLE: 708~.0' f3 5559.0 .... -,- ENTRY BLOCKS TYP~ SIZE R~ CD3E ENTRY Z. t 56 % t 66 9 4 65 .lin 15 1 66 3 I 86 9~TJM SPECIFICATION 5LD'KS MNEM SERVISE SERVICE jNIT &PI ~Pl &Pl &PI FILE SIZE S~: REPR PR'D'CESS LVO 310.M32 VE~I~i~!3~ LISTIN3 PAGE 4 lO DROER ~ LOG S~LJ OIL 3MMM O0 ILO OIL 3MMM O0 IL~ 3ZL 3~MM SP DZL ~V O0 SR ~L G~PI O0 3R FDN G~PI O0 CALl FON IN O0 RMD~ FDN $zC3 O0 RNq~ ~ON O0 ~PqI FDN PJ O0 NCNL F~N C~S O0 =CNL ~DN CPS 00 DEPT 7139,0000 SFLJ SP -33,2383 GR RH3~ 2,~319 DR~3 NPHI 43.7031 NCNL DEPT 7100.0000 SFLJ So -27,0889 RH3B 2,3535 DR53 N~I 45.4590 NC~L DE~T 7000,OOOO SFLJ SP -40.3533 SR RH3~ 2.~319 DRd3 NP~i 4~.3395 NCNL 3E~T 6gO0.O000 SFLJ SP -41.~9~5 RH]8 2.3518 ORq2 NPqI 32.5172 NCN. DE~T 5800.0000 SFLJ SP -40,3533 3R NPqI 35.2351 NCN~ DE~T 5709.0003 SmLJ SP -42,1758 SR ~H33 2.5~71 Dqq3 ~PiI ~7 ~121 NC~~ 95~T 5543.0000 SFLJ S° -35.5133 S~ RH]3 2,4709 ORq3 TYoE CLASS 000 O0 2.20 01 120 46 120 010 310 O! 310 01 280 350 02 356 Ol ~20 01 000 890 O0 33O ~ 1 330 30 3.3~01 132.5273 0.1196 2429.5300 2.2522 132.5273 0.0579 2~29.5000 2,8909 198.2148 2273.5000 ~.7525 ~6.9548 0.0171 2525.5000 3.6252' 84.5523 0.0557 2453.5~00 1.6710 121.8398 0.0559 2133.5000 7.8914 52.8555 -0.3789 1630.6375 0 0 O 0 0 9 0 O 0 IL3 GR NR~T ILD GR FCNL IL3 NRAT $CNL ILl 3R NRAT IL3 NR&T FCNL GR NRaT !LD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 . 102. 3. 550. . !02, 550. . 1DS. 3. 591, . 2, 935. · 84. 2, ~810. I 12!. 3. 574 · 17. 52. 351 · 4 4 4 4 4 4 4 4 83213 5273 4788 8125 2365 5273 ~788 8125 3733 2148 6928 8125 1101 954B 7578 8125 7559 5523 9531 3125 7313 8398 8125 2235 8555 8905 1 1 1 1 1 1 1 1 1 1 ! 1 1 1 58 58 58 5B 58 5 ~ 58 5~ 58 5~ ILM ~A:LI !L~I ~.ALI RNR ~ iLM CALl ILM CALI RN~& !LM C~LZ RNR~ ILM CALl CALI RNR& (OCTAL) 00000000000000 O0000000000OO0 O00000OO000000 OOO0000000000O 00000030000000 00000000000000 OOO00000000000 00000000000000 O000OOOOOOO000 00000000000000 00300000000000 O0000000OOOO00 O00000000000OO 00000000000000 OOO00OOO000000 2. 5225 6, 1257 3. 6760 2,26'98 6.3454 3.6760 2.5940 6. ~695 3. S 401 .4,3796 6,3250 2. ~349 3.7559 7.095~ 3.0393 !.8819 7.6062 3,7520 2030.6875 6.g250 LV~ OiO,HO°2 VERZFiC~TZg~ LISTiN.~ PAGE ~-,,- FiLE TR4IL=R. :iLE NAPE :EDIT SERCZCE NAME VEtS!ON ~ : ~AXZMUM LENGTH : 1024 ~iLE TYPE : NEXT FZLE NA~E : · ,-'~ T~PE TR&YLER. -,-.~ SEqVICE N~E :EDIT O~TE :85702! 6 O~I~IN TAPE N~ :1237 ~O~TINg'~T~gN ~ O1 NEKT T~PE NAME :O~MEN'TS :LIBRarY T~PE