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Home My WebLink About186-0031. 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:Tubing 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 6675'feet None feet true vertical 6257'feet None feet Effective Depth measured 6322'feet 5563', 5692', 6302'feet true vertical 5959'feet 5325' 5431', 5941'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" 3-1/2" 3-1/2" L-80 L-80 L-80 5554' 5641' 6324' 5317' 5389' 5960' Packers and SSSV (type, measured and true vertical depth)5563' 5692' 6302' 5325' 5431' 5941' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 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: N/A Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 151 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 Retrievable Packer: CAMCO HRP-1 Packer: Baker DB Packer SSSV: None Jaime Bronga jaime.bronga@conocophillips.com (907) 229-8282Well Integrity Engineer 6244-6273', 6332-6342', 6355-6380' 5891-5916', 59661-5975', 5986-6007' 813'5" 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) 162 Gas-Mcf MD 1336 Size 106' 5506 1347712 128 1904098 213 measured TVD 7" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-003 50-103-20057-00-00 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 Oil Pool KRU 2A-11 Plugs Junk measured Length Production LINER 1987' 4101' Casing 2013' 6114' 2013' 6114' 6670'6670' 2747' 106'Conductor Surface Tie Back 16" 9-5/8" 71' 2782'2782' Burst Collapse Fra O s 6. A PG , h Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Jaime Bronga DN: OU=Conoco Phillips Alaska, CN=Jaime Bronga, E =jaime.bronga@conocophillips.com Reason: I am the author of this document Location: Date: 2025.02.06 13:57:01-09'00' Foxit PDF Editor Version: 13.0.0 Jaime Bronga DSR-2/18/25 S By Gavin Gluyas (gavin.gluyas@alaska.gov) at 2:15 pm, Feb 06, 2025 SFD 3/25/2025JJL 2/27/25 RBDMS JSB 021925 Page 1/15 2A-11 Report Printed: 2/6/2025 Well History API / UWI 5010320057 Legal WellName 2A-11 Field Name KUPARUK RIVER UNIT Well Type Development Original KB/RT Elevation (ft) 123.00 Well Status PROD Left START DATE is from Daily Ops and Right Start Date represents the Job Start Start Date Last 24hr Sum Network/Order Number Rig Supervisor Job Type Start Date Primary Wellbore Affected 1/12/2025 (AC EVAL) TIFL PASSED. 10459473 RICHWINE, BRUCE,DHD Field Supervisor REPAIR WELL 8/25/2024 2A-11 11/14/2024 CLEAN UP RESIDUAL RESIN FROM ISEALATE PATCH @ 5414' RKB w/ GAUGE RINGS. MAX DRIFT OD WAS 2.65'' G -RING. JOB COMPLETE 10459473 CLAYTON, GREG,Wells Supervisor REPAIR WELL 8/25/2024 2A-11 11/12/2024 TAG ISEALATE PATCH @ 5414' RKB, DRIFT W/ 2.60'' RBP DRIFT THROUGH ISEALATE PATCH @ 5414' RKB, RDMO FOR SLKL MAINTENANCE. IN PROGRESS 10459473 CLAYTON, GREG,Wells Supervisor REPAIR WELL 8/25/2024 2A-11 10/4/2024 LOGGED TUBING & ISOLATE PATCH w/ 1.69'' 24 ARM CALIPER FROM 5515' RKB TO 4366' RKB, GOOD DATA. PERFORM DDT ON IA , BLED I/A FROM 350 PSI- 0 PSI, WATCHED IA 30 MIN, NO GAIN, JOB COMPLETE. 10459473 FERGUSON, SID,Wells Supervisor REPAIR WELL 8/25/2024 2A-11 10/3/2024 ATTEMPT TO DRIFT THRU ISEALATE PATCH @ 5414' RKB w/ 2.60'' ME DRIFT W/O SUCCESS, DRIFTED PATCH W/ 10' 2.25'' FOR DMY CALIPER DRIFT. LOGGED THRU PATCH W/ 1.69'' CALIPER ( BAD DATA ), SUCCESSFULLY DRIFTED ISOLATE PATCH W/ 2.57'' & 2.60'' x 12'' DRIFT BUT WAS TIGHT.IN PROGRESS 10459473 FERGUSON, SID,Wells Supervisor REPAIR WELL 8/25/2024 2A-11 8/27/2024 ***JOB CONTINUED FROM 26-AUGUST*** PATCH SET, PULL OUT OF HOLE SLOWLY NOTING INCREASED TENSION. FIND THAT PACKER NOT FULLY DEFLATED CAUSING DRAG. JOB COMPLETE. 10459473 WORTHINGT ON, BRYCE,Wells Supervisor REPAIR WELL 8/25/2024 2A-11 8/26/2024 ***JOB CONTINUED FROM 25-AUGUST*** CONTINUE STANDING BY FOR PATCH SETTING. ***JOB IN PROGRESS*** 10459473 WORTHINGT ON, BRYCE,Wells Supervisor REPAIR WELL 8/25/2024 2A-11 8/25/2024 RIG UP FOR SLB ELINE CONVEYED WELLTEC ISEALATE PATCH. BRUSH PATCH INTERVAL WITH WELLTEC WISHBONE HONER FROM 5408' - 5430', AND CONTINGENT PLUG SETTING DEPTH FROM 5575' - 5585'. POOH TO SWAP TO SETTING TOOL AND ISEALATE PATCH. TIE IN TO GLM AT 5133'. LOG CORRELATION PASS FROM 5437' TO 5332' CORRELATING TO HALIBURTON LDL. LOG SETTING RECORD PASS FROM 5437' TO STOP DEPTH OF 5381.5'. STANDBY FOR WELLTEC TO SET PATCH. ***JOB IN PROGRESS*** 10459473 WORTHINGT ON, BRYCE,Wells Supervisor REPAIR WELL 8/25/2024 2A-11 8/23/2024 PULLED 2.81 CA-2 PLUG @ 5615' RKB. READY FOR E- LINE 10459473 WORTHINGT ON, BRYCE,Wells Supervisor ACQUIRE DATA 7/5/2024 2A-11 7/13/2024 SET 1-1/2'' DUMMY IN ST# 5 @ 5475' RKB. PT TBG TO 2500 PSI, 40 PSI LOSS AFTER 15 MINS, GOOD TEST. PULL CATCHER @ 5616' RKB. RUN HES 24 ARM CALIPER FROM 5616' RKB TO SURFACE.', (GOOD DATA). JOB COMPLETE, WELL TO REMAIN SECURED UNTIL NEW PATCH ARRIVES. 10459473 FERGUSON, SID,Wells Supervisor ACQUIRE DATA 7/5/2024 2A-11 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,322.0 2A-11 7/2/2018 Jhansen8 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Isealate Patch 2A-11 8/26/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Slickline discovered tbg leak between 5337'-5464' RKB 4/8/2019 zembaej NOTE: TUBING STUB @ 5638 RKB 11/11/2011 ninam 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 35.0 106.0 106.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.4 2,782.4 2,782.2 36.00 J-55 BTC TIE BACK 7 6.28 26.2 2,013.0 2,012.9 26.00 L-80 TC-II PRODUCTION 7 6.28 2,013.0 6,113.9 5,781.0 26.00 J-55 BTC LINER 5 4.28 5,857.0 6,670.0 6,252.5 18.00 L-80 LTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 24.3 Set Depth … 5,553.7 String Max No… 3 1/2 Set Depth … 5,316.9 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD 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) 24.3 24.3 0.02 HANGER 8.000 FMC TUBING HANGER FMC 82-748- 145E 3.500 493.8 493.8 0.47 NIPPLE 4.500 CAMCO DS NIPPLE Camco PN 1342871 , HT G2657, PO C10300 620A, SO 4301 2.875 2,495.6 2,495.4 0.54 GAS LIFT 5.968 3-1/2" x 1-1/2" Camco 'MMG' GLM, CAMCO MMG 2.920 3,680.0 3,678.4 10.50 GAS LIFT 5.968 3-1/2" x 1-1/2" Camco 'MMG' GLM, CAMCO MMG 2.920 4,445.3 4,397.9 28.24 GAS LIFT 5.968 3-1/2" x 1-1/2" Camco 'MMG' GLM, CAMCO MMG 2.920 5,133.7 4,970.0 34.17 GAS LIFT 5.968 3-1/2" x 1-1/2" Camco 'MMG' GLM, CAMCO MMG 2.920 5,474.7 5,251.8 34.48 GAS LIFT 5.968 3-1/2" x 1-1/2" Camco 'MMG' GLM, CAMCO MMG 2.920 5,531.6 5,298.7 34.53 LOCATOR 4.000 LOCATOR Baker PN: H683-19 -4115, control No: 1029239 96 3.000 5,532.6 5,299.5 34.53 SEAL ASSY 4.500 80-40 PBR SEAL ASSEMBLY w/ 1.2 MULE SHOE Baker PN: H683-19 -4115, control No: 1029239 96 3.000 Top (ftKB) 5,540.4 Set Depth … 5,641.4 String Max No… 3 1/2 Set Depth … 5,389.1 Tubing Description TUBING WO OVERSHOT ASSY Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-mod 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) 5,540.4 5,305.9 34.54 PBR 7.000 BAKER 20', 80-40 POLISHED BORE RECEPTICLE Baker PN: H683-19 -4115, control No.:102 923996 2.990 5,563.4 5,324.9 34.56 PACKER 7.000 BAKER FHL RETRIEVABLE PACKER Baker FHL, size 47B2, PN: H781-20 -3595, Control No: 1031 2.930 5,615.9 5,368.1 34.61 NIPPLE 4.540 DS NIPPLE w/ COLLAR Top Oil Tool 2.812 TDS, 1342811 , SN: T070813 2.812 5,627.3 5,377.5 34.62 XO Reducing 3.500 CROSSOVER, 3.5" x 2-7/8" 2.380 5,634.9 5,383.8 34.63 OVERSHOT 7.000 BAKER POORBOY TUBING STUB OVERSHOT Baker 2.380 5,635.2 5,384.0 34.63 OVERSHOT 7.000 BAKER POORBOY TUBING STUB OVERSHOT Baker Two sets of 4 each shear screw @ 14260 lbs 3.000 5,640.4 5,388.3 34.63 MULE 7.000 1/2 MILE SHOE, BAKER LOCKED TO OVERSHOT Baker 3.500 2A-11, 2/6/2025 9:25:25 AM Vertical schematic (actual) LINER; 5,857.0-6,670.0 IPERF; 6,355.0-6,380.0 APERF; 6,332.0-6,342.0 PACKER; 6,301.8 PATCH; 6,252.0 IPERF; 6,244.0-6,273.0 PRODUCTION; 2,013.0-6,113.9 SLEEVE; 5,774.4 GAS LIFT; 5,735.0 PACKER; 5,692.4 PACKER; 5,563.4 GAS LIFT; 5,474.7 SPACER PIPE; 5,414.0 LEAK - TUBING; 5,418.0 GAS LIFT; 5,133.7 GAS LIFT; 4,445.3 GAS LIFT; 3,679.9 SURFACE; 35.4-2,782.4 GAS LIFT; 2,495.5 TIE BACK; 26.2-2,013.0 TIEBACK; 31.0 ftKB NIPPLE; 493.8 CONDUCTOR; 35.0-106.0 KUP PROD KB-Grd (ft) 34.71 RR Date 1/30/1986 Other Elev… 2A-11 ... TD Act Btm (ftKB) 6,675.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005700 Wellbore Status PROD Max Angle & MD Incl (°) 35.67 MD (ftKB) 4,700.00 WELLNAME WELLBORE2A-11 Annotation Last WO: End Date 10/31/2011 H2S (ppm) 60 Date 12/19/2017 Comment SSSV: NIPPLE Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 5,640.0 Set Depth … 6,324.2 String Max No… 2 3/8 Set Depth … 5,959.5 Tubing Description TUBING Original Wt (lb/ft) 4.00 Grade J-55 Top Connection EUE-8rd ID (in) 2.04 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) 5,674.8 5,416.6 34.66 SBR 4.750 CAMCO OEJ SBR CAMCO OEJ 2.312 5,692.4 5,431.0 34.67 PACKER 6.156 CAMCO HRP-1 PACKER CAMCO HRP-1 2.344 5,735.0 5,466.1 34.63 GAS LIFT 5.460 CAMCO KBMG CAMCO KBMG 2.875 5,774.4 5,498.5 34.57 NIPPLE 3.668 AVA PORTED NIPPLE AVA 2.250 6,233.0 5,882.0 31.75 BLAST RINGS 3.000 BLAST RINGS (2) 2.041 6,301.2 5,940.0 31.93 LOCATOR 5.000 BAKER LOCATOR w/5' SEALS BAKER 2.041 6,301.8 5,940.5 31.93 PACKER 6.000 BAKER DB PACKER BAKER DB 2.041 6,316.2 5,952.7 32.03 NIPPLE 4.000 CAMCO D NIPPLE CAMCO D 1.813 6,323.6 5,959.0 32.09 SOS 2.375 CAMCO SHEAROUT SUB - ELMD @ 6308' ON PERF 11/3/1986 CAMCO 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) 5,414.0 5,201.7 34.44 SPACER PIPE ISEALATE PATCH OAL 10', THEORETICAL MIN ID 2.70" ISEALAT E N/A N/A 8/26/2024 2.700 5,418.0 5,205.0 34.44 LEAK - TUBING Tubing Leak Identified at ~5418' 4/18/2019 0.000 5,774.4 5,498.5 34.57 SLEEVE AVA, 2.25" BPC 2/9/2001 1.875 6,252.0 5,898.2 31.80 PATCH MERLA TUBING PATCH 3/16/1986 1.399 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) 2,495.6 2,495.4 0.54 1 GAS LIFT GLV RK 1 1/2 1,218.0 10/12/2018 Camco Shlumb erger 0.188 3,680.0 3,678.4 10.50 2 GAS LIFT GLV RK 1 1/2 1,228.0 10/12/2018 Camco Shlumb erger 0.188 4,445.3 4,397.9 28.24 3 GAS LIFT OV RK 1 1/2 0.0 10/12/2018 Camco Shlumb erger 0.250 5,133.7 4,970.0 34.17 4 GAS LIFT DMY RK 1 1/2 0.0 4/5/2023 Camco Shlumb erger 0.000 5,474.7 5,251.8 34.48 5 GAS LIFT DMY RK 1 1/2 0.0 7/13/2024 Camco Shlumb erger SCG- 7498 0.000 5,735.0 5,466.1 34.63 6 PROD DMY BK 1 0.0 9/16/1991 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) 1,915.3 1,915.2 0.75 XO THREAD 7.000 Crossover jt 7" TCII box x 7" BTC pin 6.276 1,959.5 1,959.4 0.84 Collar 7.000 7" HES Type "H" ES cementer w/ 6 shear pins (3300 psi to open) BL HES Type "H" 6.171 6,569.7 6,167.2 31.84 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 6,244.0 6,273.0 5,891.4 5,916.0 C-4, 2A-11 3/16/1986 12.0 IPERF 60° phasing, 3 3/8" Csg Gun 6,332.0 6,342.0 5,966.1 5,974.6 A-4, 2A-11 11/3/1986 4.0 APERF 0° phasing 1 11/16" TBG Gun 6,355.0 6,380.0 5,985.6 6,006.7 A-3, 2A-11 3/16/1986 6.0 IPERF 60° phasing, 3 3/8" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 31.0 2,013.0 31.0 2,012.9 TIEBACK 10/26/2011 2A-11, 2/6/2025 9:25:26 AM Vertical schematic (actual) LINER; 5,857.0-6,670.0 IPERF; 6,355.0-6,380.0 APERF; 6,332.0-6,342.0 PACKER; 6,301.8 PATCH; 6,252.0 IPERF; 6,244.0-6,273.0 PRODUCTION; 2,013.0-6,113.9 SLEEVE; 5,774.4 GAS LIFT; 5,735.0 PACKER; 5,692.4 PACKER; 5,563.4 GAS LIFT; 5,474.7 SPACER PIPE; 5,414.0 LEAK - TUBING; 5,418.0 GAS LIFT; 5,133.7 GAS LIFT; 4,445.3 GAS LIFT; 3,679.9 SURFACE; 35.4-2,782.4 GAS LIFT; 2,495.5 TIE BACK; 26.2-2,013.0 TIEBACK; 31.0 ftKB NIPPLE; 493.8 CONDUCTOR; 35.0-106.0 KUP PROD 2A-11 ... WELLNAME WELLBORE2A-11 Originated: 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 -08'00'2AͲ1150Ͳ103Ͳ20057Ͳ00 909594128KuparukRiverMultiFingerCaliperField&Processed4ͲOctͲ2401T39691184 067186-003186 004 Originated: Delivered to:12-Sep-24 Alaska Oil & Gas Conservation Commiss 12Sep24-NR ATTN: MeredithGuhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24 CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24 CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24 2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39555 T39556 T39557 T39558 T39559 T39560 T39561 T39562 T39564 T39565 T39566 T39567 T39668 T39563 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.13 08:31:59 -08'00' 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 T39559 Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1Q-22 50-029-22595-00 909470221 Kuparuk River Leak Detect Log Field- Final 1-Aug-24 0 1 2 1Q-22 50-029-22595-00 909470221 Kuparuk River Multi Finger Caliper Field & Processed 1-Aug-24 0 1 3 2A-11 50-103-20057-00 909443804 Kuparuk River Multi Finger Caliper Field & Processed 13-Jul-24 0 1 4 2C-12 50-029-21222-00 909469468 Kuparuk River Packer Setting Record Field- Final 23-Jul-24 0 1 5 2M-25 50-103-20152-00 909509189 Kuparuk River Multi Finger Caliper Field & Processed 10-Aug-24 0 1 6 2X-05 50-029-20985-00 909469473 Kuparuk River Leak Detect Log Field- Final 26-Jul-24 0 1 7 2X-05 50-029-20985-00 909469473 Kuparuk River Packer Setting Record Field- Final 28-Jul-24 0 1 8 2Z-06 50-029-20957-00 909460858 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 9 WSW-05 50-029-20838-00 909490893 Kuparuk River Multi Finger Caliper Field & Processed 2-Aug-24 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39442 T39442 T39443 T39444 T39445 T39446 T39446 T39447 T39448 195-140 186-003 184-206 191-021 183-107 183-077 182-164 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:42:09 -08'00' 32A-11 50-103-20057-00 909443804 Kuparuk River Multi Finger Caliper Field & Processed 13-Jul-24 0 1 186-003 1850:3 WELL LOG TRANSMITTAL #905645108 30 9 3 0 To: Alaska Oil and Gas Conservation Comm. June 3, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 IRECOVED Anchorage, Alaska 99501 JUN 2 7 2019 AOGCC RE: Multi Finger Caliper (MFC), Leak Detect Log, and Packer Setting Record: 2A-11 Run Date: 04/18/2019, 04/19/2019, and 05/13/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-11 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20057-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: O(-rG LV l Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 2 2 20,13 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operajlpn 4Fat f'jn ❑ Performed: Suspend ❑ Perforate Other Stimulate s-, ❑ ❑ Alter Casing ❑ Change ApproveCFogram ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑_Tubing Patch Q 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ Stratigraphic ❑ Service ❑ 186-003 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20057-00 7. Property Designation (Lease Number): 8. Well Name and Number: Ki�U 2A-11 ADL0026570 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6,675 feet Plugs measured None feet true vertical 6,257 feet Junk measured None feet Effective Depth measured 6,322 feet Packer measured 5,540 feet true vertical 5,959 feet true vertical 5,306 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 feet 16 106' MD 106' TVD TIE BACK 1,987 feet 7 2,013' MD 2013' TVD SURFACE 2,747 feet 9 5/8 " 2,782' MD 2782' TVD PRODUCTION 4,101 feet 7 6,114' MD 5781' TVD LINER 813 feet 5 6,670' MD 6253' TVD Perforation depth: Measured depth 6244-6273, 6332-6342, 6355-6380 True Vertical depth 5891-5916, 5966-5975, 5956-6007 Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 5627' MD 5378' TVD 2.4 " J-55 6324' MD 5959' TVD Packers and SSSV (type, measured and true vertical depth) PBR - BAKER 20', 80-40 POLISHED BC 5,540' MD 5,306' TVD NIPPLE - CAMCO DS NIPPLE 494' MD 494' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments (required per 20 AAC 25.070, 25.077, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil E] Gas El WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: contact Name: Dusty Freeborn/Jan Byrne Authorized Name: Dusty Freeborn Contact Email: N1617@conocophillips.com Authorized Title: Well Integrity Supervisor - Contact Phone: 907-659-7224 Authorized Signature: Date: vTc 6/4/l9 Form 10-404 Revised 4/2017 RBDms "'/MAY 2 3 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 18`h day of May 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 2A-1 I (PTD 189-003). Please contact Jan Byrne or me at 659-7224 if you have any questions. Sincerely, x�w Dusty Freeborn Well Integrity Supervisor ConocoPhillips Alaska, Inc. 2A-11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/17/19 TIFL POST PATCH (PASS) 05/13/19 05/12/1 04/19/19 04/18/19 04/08/19 04/07/1 SET 2.725' P2P (#CPP35191) MID-ELEM @ 5430' RKB WITH EDPU. CORRELATED TO LDL 4-18-2019. CMIT T x IA TO 2500 (PASS) W/ TEST TOOL. SET 2.725" P2P (#CPP35028), SPACER PIPE, ANCHOR LATCH (#CPAL35033) MID-ELEM @ 5410' RKB. MITT TO 2500 (PASS), CMIT IA x T (PASS) W/ TEST TOOL. JOB COMPLETE. PULLED CATCHER & CA -2 PLUG @ 5616' RKB. BRUSHED AND FLUSHED TBG FROM 5368' TO 5388' RKB. DRIFTED TBG TO 5518' RKB WITH 2.73" x 21.3' DUMMY PATCH. IN PROGRESS. SET DV @ 5474' RKB, LOGGED 24 ARM CALIPER FROM CATCHER @ 5610' RKB. GOOD DATA. IN PROGRESS. PERFORMED LDL FROM CATCHER @ 5610' RKB FOUND LEAK @ —5418' RKB WITH SPINNER TEMP LOG, PULLED DV @ 5474' RKB. IN PROGRESS. SET DV @ 5475' RKB; LEAK DETECT W/ HOLEFINDER AND DETERMINE LEAK IN TBG BETWEEN 5337'-5464; JOB SUSPENDED FOR PLAN FORWARD (PLUG & CATCHER REMAIN IN HOLE). 9 BRUSH n' FLUSH DOWN TO DS -NIPPLE @ 5616' RKB; SET 2.81" CSA -2 PLUG @ 5616' RKB & UNABLE TO OBTAIN TBG TEST; W/ HOLEFINDER IDENTIFIED LEAK BETWEEN 5468'-5127' RKB (STA# 4 @ 5333' RKB); DEPLOY 2.79" CATCHER W/ 2.5" GUTTED JD & PULLED DV @ 5475' RKB; LRS ON LOCATION PERFORMING CIRC OUT W/ CISW & DIESEL U -TUBE FP, ALONG WITH CMIT TBG X IA. PASS Ajwftk KUP PROD WELLNAME 2A-11 ConoeoPhillips Alaska. IRC. 0ISSSV:NIPPLE IAtWbutes Max Angle3MD TD FkM Nam° We,la°rc A111UW1 Wsxrffe 81,Wa roH') M."KB) Acl fi[m(XKBI KUPARUK RNER UN IT 501032 0 0 5]00 PROD 5.67 4]00.00 6,6]5.0 L°mmeon H35 (ppm/ 60 Oasa Mn°ta,ion Ena Gate KBGra(X) re.palease Gale 1211&201] Le IWO: 1013112011 34]1 1/3011988 Last Tag .. . - _. AK All Wellbores Sehem Anne,a„°, Gap,„(aKn, Ena Da,e �a„3m By We„hire Ictal Tag: RKB 6322.0 ]/22010 JhanaenR 2A-11 Last Rev Reason 9Vsupslsphern r.4J:mu. vmiuleo„.m.tiehem0 anr°tarer Era mre la., Motl By wen5ere HRNGER a4.9- CONOUCTORI39.0 posts NPPLE:e9s.e BESACK31.0hK0 TIE BPGK: N+3-9,013.0 GAS LIFT; 248£9 3URFALE; 3S4 ,7(x.4- GPS LIFT: A6i9.9 GASUFT:4.4453 GAS ul5.13n Felop 841x0 Teete leek£41A0 sa", Pie; Paalr.£49O.G GAS UFO Sna.] Lap ATOR:S531.6 BEµ ABsy;5Di PSR: e5bA PACKER: Saudi terPLEeare. WEhapop5,s 04ER8XOT;SBR.9 MUUaea.A mAaSra.e Cas uFl: s.nsOk252A x,P1 Ga. 77445n4.4 PROOUDROK 2ma0 Dias IPERF; S244.0£93E PATLH;e=0 L . . . R BA01.9 PACKER;B,NtA N,PP,E;£a18.9 Bos; a325e APERF£3390£]4l /PERF: 8.385.0$]M.O� LINED; 5,851.06,a]ne-� Rev Reason: PUII PIu9. set Patch511312019 'erne, Notes: General & Sai End Gare Annmm,on Wclihc,e 4/8/20,9 NOTE: Slickline discovered thg leak between 533]'-5467 RKB 2A-11 Casing Strings S Dap,„(TVD) wuLao art;Des 00(inl hadd Top(XKB) Set Depth d1K. IXKBI 11LJX) Sued. I T°pTMeatl Wellb°m CONDUCTOR 16 15.06 35.0 106.0 106.0 62.50 Hd0 WELDED 2411 SURFACE 95/8 8.92 35.4 2,782.4 2,782.2 36.00 JSS JBIRC 2411 TIEBACK 7 6.28 26.21 2,013.0 2,012.9 26.00 L-80 TC -II 2--11 PRODUCTION 7 6.28 2D130 I 6.113.9 5.]81- 26.00 J-55 IBTC 2A-11 LINERS 4.28 5,651.0 6,670.0 62525 18.00 1 L-80 I LT C 2A-11 Tubing ing Stings Sort max Neutral Des DoBI IG(inl Top(RKB) Set Depth Set Depth Rural (al talent W111.4 Gentle Top Threat Wellhme TUBINGWO 312 .2.99 24.3 5,553.] 5,3165 9.30 L-80 EUEtIol 2A-11 TUBINGWOOVERSHOT 31rz 2.99 5,540.4 ASSY 5,641.4 5,389.1 9.30 L-80 EUE-mod 2411 TUBING Original 2318 2.0< 5.640.01 8.32421 5,9595 4.00 J-55 EUE-Rud 2-11 completion newls Top(ftn) T°Ipal((rv81) rO11 c1 Icor Des LOm 10(in) we„bore 21.3 24.3 0.02 HANGER FMC TUBING HANGER .3.500 2--11 493.0 493.8 0.47 NIPPLE CAMCO DS NIPPLE 2.875 2M11 5,531.6 5,298.7 34.53 LOCATOR LOCATOR 3.000 2411 5,532.6 5299.5 34.53 SEALASSY W40 PER SEAL ASSEMBLY Sal 1.2 MULE SHOE 3.000 2A -it 5,540.4 5,305.9 34.54 PER BAKER 20', 8040 POLISHED BORE RECEPRCLE 2.9902A-11 5,563.4 5324.9 34.56 PACKER BAKER FHL RETRIEVABLE PACKER 2.9302A-1, 5,815.9 5,368.1 34.61 NIPPLE OS NIPPLE WI COLLAR 28122A-11 5,627.3 5,3]].5 34.62 XO ReEutlng CROSSOVER, 3.5' x2-718" 2.3802A41 5,634.9 5,303.8 34.63 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT 2.380 2--11 5635.2 5,384.0 34.63 OVERSHOT BAKER POORBOY TUBING SNB OVERSHOT 3-00 2A-11 5.640.4 5388.3 34.63 MUtE 112 MILE SHOE, BAKER LOCKED TO OVERSHOT 3.500 2411 5,6]4.8 5,416.6 34.66 SBR CAMCO OEJ SBR 2.312 2A-11 5,6924 6,431.0 34.67 PACKER CAMCO HRR, PACKER 2.344 2A-11 5774.4 5,498.5 34.57 NIPPLE AVA PORTED NIPPLE 2250 5 11 6233.0 5,882.0 31.75 SUWRINGS BLASTRINGS(2) 2041 2h11 6,301.2 5,940-0 31.93 LOCATOR EAKERLOCATORvxB'SEALS 2041 2A41 6,301.8 5,9405 31.93 PACKER BAKER OB PACKER 2.041 M-11 6316.2 5,9527 32.03 NIPPLE CAMCO DNIPPIE 1.813 2A41 6323.6 5,959.0 32.09 SOS CAMCO SHEAROUT SUB -ELMO@ 6308' ON PERE 1 IIWI986 1.9952--11 Otter In Hole (Wireline retrievable plugs, valvae, pumps, fish, etc.) Top(rvGl T°p(XK6, (XK0) Top Incl l') Des Co. Run Gate aI1Pare 5,410.0 5,198.5 3444 PalCh PZP CPP36028 w/ Spacer Pipe and Anchor 511312019 11 Latch CPAL35033. OAL21' Max OD Z]T 54/4.0 5,201.7 34.44 Spiatuppe 5.'G 2-1/16 P-110TUbing 511312019 11 J..� 5418.0 5,205.0 34.44 Tubing leak Tubing Leak ltlentnetl at -54,8' 4/1812019 115,430.0 5,214.9 34A5 Patch P2P CPP35191 GAL4'Max OD 2]2' wariat19 1157]4.4 5,488.5 34.5] SLEEVE AVA, 225"BPC - &9!2001 1 5,898.2 31.80 PATCH MERLA TUBING PATCH 3116N986 1 Liner Details Top (NGI Namin) Top(IINB) (XKB) Top Incl ('j Item Des Com (in) WeIIWre 35.0 0.02 CONDUCTOR 15.080 2411 35.4 35.4 0.02 HANGER 9.625 ?A-11 W. 1.959.5 1,959.4 0.84 Carer 7HES Type "H" ES comemer M 6 sheer pins 6.171 2Mi1 (3300 psi to open) BL 2,013.0 2.012.9 0.93 PRODUCTION 6.276 2A-11 5,857.0 5,566.6 34.62 HANGER BAKER LINER HANGER 5.000 2A-11 6,029.5 5,710.0 32.96 PRODUCTION 6.276 2A41 P*dOmuons i slots Top MKS)Btm (flKBt Tap jNO) (XKS) elm (PN) (XKGj LInkN2°ne Gate Shot Gena IBMIa t 1 lip.Com WMGare 6244.0 8,273.0 5,891.4 5,918.0 C4, 2A-11 311 fil1886 12.0 (PERE W deg.phasing,3310"Csg Gun 2--11 6,332. 6,342- S,gfifi.i 5,9]4.6 Ad,?A-1, 111311986 4.0 APERE Zero Deg. Phasing, l 11116"TBGGUN M-11 6355.D fi.36D.0 6985.6 &DDfi.] A-3, 2A-11 3/1611986 6.0 IPERP 60 Deg. phasing, 33/0" Cag Gun 2A-11 MNdtallMelts S, ad IPo„ Valve IvrcM1 Sao TRORun No Top aNGINaXe M°tle, DID (to, sery Typ° Type (IrI (psi) Rpn Dale Com WeNbere 2495.6nMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,218.0 101122018 d4,397.9 tDB l 2 3,6811.0AMCO MMG 112 GA LIFT GLV RK 0.180 1,220.0 1N1211B18 2A-il 3 4,445.3AMCO MMG1112 AS LIFT V RK 0.250 0.0 10/122010 2--114 5133]AMCA Mi11/2 GAS LIFT DMY PK OA00 0.0 101112010 2--11 - KUP PROD WELLNAME 2A-11 ConocoPhillips rt'3c Alaska, Inc. Yanard�PEseE�` AK All Wellbom Schem 91 a8 POR TOp (NOI MO Top (XNBI (Xl(aI Make Motlel OO Qn) Bery Valve T, Type Type Blas (in) TRO qun (pail Run Oale c. mlI . 70.11, 511dmlf9 Td]61AM veniwl ufiemano {atlmp 6,d]4.J 5,251.8 CAMCO MMG 112 GAS LIFT OMV RK 0.000 0.0 4/192019 2M11 """""""" ............._.._....._.._..._....._...__...__._.. U1 5.M.0 5,46&t CAMCO IKBNlU I 1P.Q. JUMY JUK I U.000 1 0.0 911511901 70. -11 Top jNOI 9[m (NO) Top(ItKO) Blm ((1K¢) (NKBI (hN0) On type SOR OaR V/eIlCe�e �*;} ;:A 0.0 0.0 Cemenl8queeze Squeezb Z1Z1992 20.-11 LONOULTOR:3S0. 1W0 HIPPIE; 4... TEBACIC 3I.OM1N6 TIE RACK 232-20130. GAS LIFT; 2dSi5 6UPFACE; 9.42]@.4— GA6 uFT:357aa GAs L1Fr; e,a&3 G SUF`n:.V33.7 PeCF; 5,I1QG Tubing lnk, i41&0 9pcer Pµr,;41d.0 Pack SUOO GAS UFT: 5, 470.] LOWOR: 5531.6 I SEN.ASSV: 5,5328 PSk 55 W.5 PACKER UMA NIPPLE; 5815,9 OVERSHOT:'{83q,9 pVER6Hoi: 8635.E MULES.UM4 R: Sna e PACKEKER; S693.< GPS LIFT: S.mo NIPPLE: SP4,4 sLEWE:APaA PROOUCTION:2013.0 MI. (PERF; fi.2M,66,P3.0 PATCH: fi.R52G LOCATOR;b 13 PMKER 6]Of.e NIPPLE; 6.31G3 ' 906: 43T1.6 MERF; 6,33208,3420 " IPERP.4W5.0$360.0� LINER s,9n.o M..0— STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well I" Plug Perforations r Stimulate r Other [ Alter Casing );�' Pull Tubing 1 Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r° Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r,," Exploratory r ` 186 - 003 3. Address: 6. API Number: Stratigraphic r Service J-" f QQ P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20057 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25570 " e 2A -11 9. Field /Pool(s): . Kuparuk River Field / Kuparuk River Oil Pool • 10. Present Well Condition Summary: Total Depth measured 6675 feet Plugs (measured) None true vertical 6257 feet Junk (measured) None Effective Depth measured 6621 feet Packer (measured) 5563, 5692, 6302 true vertical 6210 feet (true vertucal) 5325, 5431, 5941 Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 106 106 SURFACE 2747 9.625 2782 2782 PRODUCTION 6083 7 6114 5781 LINER 813 5 ° Et 1 - 31- :f: (/ 9 21 3 a'M C Perforation depth: Measured depth: 6244' 6273', 6332' 6342', 6355' - 6380' +ECE4 /ED True Vertical Depth: 5891'- 5916', 5966'- 5975', 5986' -6007' NOV 14 2011 Ash Oil & Gas Cons. Commission Tubing (size, grade, MD, and TVD) 3.5, L - 80, 5554 MD, 5317 TVD AnCnoragge Packers & SSSV (type, MD, and ND) PACKER - BAKER FHL RETRIEVABLE PACKER @ 5563 MD and 5325 TVD PACKER - CAMCO HRP -1 PACKER @ 5692 MD and 5431 TVD PACKER - BAKER DB PACKER @ 6302 MD and 5941 TVD NIPPLE - CAMCO DS NIPPLE @ 494 MD and 494 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 289 1043 2543 -- 226 Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory 1 Development f , Service r Stratigraphic a " 15. Well Status after work: • Oil f;7 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR E WINJ r WAG r GINJ E SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -284 Contact Erik Nelson ( 263 -4693 Printed Name I' N- -.- -ar Title Workover/Wells Engineer �� Signature \ /r Phone: 263 -4693 Date / / 'v ( / °��// • DM S � Form 10 -404 Revised 10/21 I* NO V 1 4 zo� / /,.3ID,1( Subm f riginal Only KU P 2A -11 ConocoPudtips , ' :: Well Attributes Max Angle & MD TD , ,' Wellbore APUU WI Field Name Well Status Inc! () MD (ftKB) Act Bim (ftKB) ° ,, • 81, 501032005700 KUPARUK RIVER UNIT PROD 3567 l 4 _6675.0 H _ 25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Dare vggpconrg 211 SSSV NIPPLE 50 1/17/2010 1LastWO 10/31/2011 34.71 1/30/1986 "` "^" ` SOW,A5s A8914I A notation Depth (itKB) 'End Date Annot tion T Last Mod .. E d Date .... _.. Scale ulhia6m Last Tag 6,369.0 2/10/2000 Rev Reason: WORKOVER ninam 11/7/2011 Casin• Strin•s HANGER, 24- - - : Casing Description String 0... String ID .. Top (ftKB) Set Depth (i Set Depth (TVD) ... String Wt... String String Top Thrd CONDUCTOR 15 060 35.0 106.0 106.0 62 -50 H -40 - Casing Deudptbn String 0... String ID ... Top (ftKB Set ) Set Depth (T... Set Depth (TVD) . String Wt... String ... String Top Thrd I SURFACE 95/8 8.921 35.4 2,782.4 2,782.2 36.00 J - BTC ' Casing Description String 0... String ID ... Top flKe) St Depth (f... Set Depth (TVD) . String Wt... String ... String Top Thrd ItHI, I TIE BACK 7 6.276 26.2 2,013.0 2,012.9 26.00 L TC - II Cas Description String 0... String ID ... ToP (ftl(B) St DepM (f... Set DBPth (ND) ... S/ing Wt... String ... String Top Thrd PRODUCTION 7 6.276 31.0 6,113.9 5,7810 26.00 J - BTC _ Casing Description Str ng 0... String ID .. Top (kK6) Set D pth (f... Set Depth (ND) . String Wt... String ... Strtng Top Thrd CONDUCTOR, . LINER 5 4.276 .. 5,857.0 6,670 -0 6,2525 18.00 L -80 LIC 35 - 106 ._ -. _.._ _ _._ - -- - __.. _. Liner Details Air. Top Depth NIPPLE, 494 xt!•r.:_ (ND) Top Inc! Nomi... . .T (MB) (ftKB) Vp 9) Item Description Comment _.- ID(in) 5,857.0 5,566.8 34.85 HANGER BAKER LINER HANGER 5.000 J Tubing Strings Tubing Description 'String O .. String ID Top (ftKB) Set Depth (f Set Depth (ND) . String Wt... Str ng .. String Top Thrd TUBING WO ' 3 1/2 2 992 1 24 3 5 553 7 5,316.9 9 30 L 80 EUE mod TIE BACIK ,. GOnipletoetaiI5 26 -2013 Top Depth (TVD) Topincl Nomi... GASLIF7, Top(SKB) (kK6) (°) kem Description Comment ID(In) 2,496 24.3 24.3 -0.09 HANGER FMC TUBING HANGER 3.500 Mk SURFACE „__ _ 493.8 493.8 0.47 NIPPLE CAMCO DS NIPPLE 2.875 rl 5,531.6 5,2987 34.53 LOCATOR LOCATOR 3.000 EA 5,532.6 5,299.5 34.53 SEAL ASSY 80-40 PBR SEAL ASSEMBLY w/ 1.2 MULE SHOE 3.000 35 - 2.782 - . Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (7VD) ... String Wt... String ... Siring Top Thrd OVERSHOT ASSY 31/2 I 2.992 5,540.4 5,641.4 5,389.1 9.30 L-80 EUE-mod ME GAS LIFT. �" 5 '` F yr 3.680 ' I eUon Details _ _ �. `' .° > , Top Depth ,. (ND) Top Intl Norm_. Top (MB) (ftKB) (°) kern Description _ C mment ID (in) GAS LIFT, ._._ 5,540.4 5,305.9 34.54 PBR BAKER 20', 80 -40 POLISHED BORE RECEPTICLE 2.990 4.445 °sc _ _ +,- , 5,563.4 5,324.9 34.56 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 5,615.9 5,368.2 34.81 NIPPLE DS NIPPLE w/ COLLAR & RHC PLUG INSTALLED 2.812 GAS LIFT,____ 5,621.3 5,377.6 34.79 XO Reducing CROSSOVER, 3.5" x 2 -7/8" 2.380 5,134 E'` - -5,634 - - - - - - - -9 5, 383.8 34.78 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT 2.380 5,635.2 5, 384.0 34.78 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT 3.000 GASLIF,475 T._ 5,6404 5,388.3 34.77 MULE 1/2 MILE SHOE, BAKER LOCKED TO OVERSHOT 3.500 5 , - _. Tubing Dosaription _ Stnng 0... String 10 Top (ftlC8) ISet Depth (i Depth (160) _ . Stn g Wt... Siring Siring Top Thrd MILE TUBING Original 1 2 3/8 2.041 5,640.0 , 6,324.2 1 Set D 5,959.5 4 00 J-55 EUE -8rd T _ completion Details LOCATOR. _ u,•;b ?., �, ?.. -.. .., .z.: ... . ,- < , ., K i nq 1 f "..: r,- '- k, -,'.`r �.FSy 5,532 - -- L- -.j, Top Depth' SEAL ASSY, (ND) Top Inc! Nomi. 5,533 - -' -,, Top MKS) ( (°) Item Description Comment ID (in) P139,5,540-- 5,674.8 5,416.6 34.72 SBR CAMCOOEJSBR 2.312 5,692.4 5,431.0 34.69 PACKER CAMCO HRP -1 PACKER 2.34.4 illt 5,774.4 5,498.5 34.57 NIPPLE AVA NIPPLE IIIIIV 6,233.0 5,881.8 31.44 BLAST RINGS 2.041 NIPPLE, 5,616 - - -- - - - -- tit 6,301.2 5,940.0 31.93 LOCATOR BAKER LOCATOR wIS SEALS 2.041 INV 6,301.8 5940.5 31.9 PACKER BAKER DB PACKER 2.041 OVERSnoT, 6,316.2 5952.7 32.03 NIPPLE CAMCO D NIPPLE 1.813 5.635 - __._ .• . 6,323 -6 5,959.0 32.0 CAMCO SHEAROUT SUB - ELMD @ 6308' ON PERF 11/3/1986 1.995 OVERSHOT ,. .� 5.635 ' f;1 a. Other In Hole (Wireline retrievable plugs,_valves pumps, fish, e tc.) MULE, 5,640 -- Top Depth �v TUBING, 5,640 (TVD) Top Ind SBR, 5,675 - -- Top (ftKB) MKS) (°) Description Comment Run Date ID (in) PACKER, 5,692 - -- _ 5,774 5,498.5 34.57 SLEEVE AVA, 2.25" BPC 2/9/2001 1.875 6,252 5898.1 3158 PATCH MERLA TUBING PATCH 3/16/1986 1.399 GAS 57T t _ Perforations $.4 Slots ilE shot I Top (ND) Btm (TVD) Dens SLENIPEVPLE,5,774 74 - To jfK (ftKB) _ (ftKB) (6K6) _ _ _ _ Zone Date (sh... r,. Comment ._ E. 5.7 6,244 6,273 5,891.2 5,916.T C:47 3/16/1986 12.0 IPERF 60 deg. phasing, 3 3/8" Csg Gun 6,332 6,342 5,974.5 A -4, 2A -11 11/3/1986 4.0 APERF Zero Deg. Phasing, 1 11/16" TBG GUN 1.994.6.114 6,355 6,380 5,985.5 6,006.7 A -3, 2A -11 3/16/1986 6.0 IPERF 60 Deg. phasing, 3 3/8" Csg Gun IPERF, -- 6,244-Q273�_ . -. LOCATOR, Mandrel Details 6,301 _ __.. ..Top Depth Top S �...._ _... -. PACKER, 8,302 » (TVD) Intl OD Valve Latch TRO Run Stn Top (6U(B)_ _ (MKS) 1 ° ) Make _Model (in) Serv�, TYPe___ Type (in) (psi) Run Date Com... NIPPLE, 6.316 1 2,495.6 2,495.4 0.52 CAMCO MMG 1 1/2 GAS LIFT DMY RIO 0.000 0.0 10/31/2011 % - SOS, 6,324 2 3,680.0 3,678.4 11.09 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/31/2011 - --- _ 3 4,445.3 4,397.2 26.81 CAMCO MMG 1 1/2 GAS LIFT DMY RIC 0.000 0.0 10/31/2011 APERE. 6,332 -6,342 - 4 5,133.7 4,969.9 33.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 10/31/2011 IPERF, 5 5,474.7 5,251.8 34.47 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 10/31/2011 6,355 - 6,380 6 5,735.0 5,466.1 34.63 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 9/16/1991 ■ LINER, ` 5.1-607,1:063;1 \__, _" i KUP 2A -11 ConocoPhillips r'Ltrs 11Y KB (k) Rig Release Date 0 5on 2A-11, 11 .7/2911.5.19;1049 34 71 1/30/1986 . Scale InhOilOn Tre, 0 I Cement Squeezes HANGER. 24 - - -- - Top Depth Btm Depth Top(Po(B) Ben (0K6) ( Ke (666) I�soi tion Start Date -__ Comment ( (TV ) 0.0 0 Cement Squeeze 2.121992 Notes: General & Safety • End Date Annotation 10/7/2010 NOTE: View Schematic wi Alaska Si hernauc9 0 CONDUCTOR, 35-106 NIPPLE, 164 Sal TIE BACK, 26-2,013 GAS LIFT,_s. 2,496 SURFACE, J 1 35 -2,782 GAS LIFT, 3,680 GAS LIFT, {,K5 5,13{ GAS LIFT, 5,175 LOCATOR. 5,532 T_.. -3 SEAL ASSY, _ .. 5,533 P89, 5,540 PACKER, 5,563 -.- NIPPLE, 5,616 -- - --,. OVERSHOT, 5.635 - -- r;_ OVERSHOT, 5,635 IE ,.. MULE,5,640 TUBING. 4640 086, 5,675 - - -- - -- GAS LIFT,_ -___.. __ .... 5,735 NIPPLE, 5,774 - SLEEVE, 5,774 — PRODUCTION, 1,9944,114 IPERF, 6.2444.273'N PATCH,6,252— ®' LOCATOR. r 6,301 PACKER, 6,902 NIPPLE, 6,316 - ' IF SOS, 6,324 — APERF, 6,3326,312 - IPERF, 6,3554,380 LINER. 5,857 -6,670 TD, 6,675 • 2A -11 Pre -Rig Well Work DATE SUMMARY 9/30/11 DRIFT TBG 1.68" TO 5822' SLM. MEASURED SBHP @ 5750' SLM (WELL STATIC FOR 1 DAY, WILL PERFORM AGAIN TOMORROW). ATTEMPT 5' X 1.875 X 10' OF 1.75" DRIFT TO 1030' SLM, UNABLE TO WORK FURTHER. IN PROGRESS. 10/1/11 DRIFT TBG DMY KOT TO 5700' SLM. PULL 1.5" DV @ 5634' RKB. COMPLETE. 10/2/11 PRE RWO T -POT (PASSED), T -PPPOT ( PASSED) 10/3/11 PRE RWO IC -POT ( PASSED ), IC -PPPOT ( PASSED ). FT -LDS ALL NORMAL. 10/4/11 MEASURED BHP @ 5750' SLM: 2226 PSI. COMPLETE. ConocoPhillips Time Log & Summary Wellview Web Repotting Report Well Name: 2A - 11 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 10/9/2011 9:00:00 PM Rig Release: 11/1/2011 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/08/2011 24 hr Summary Move camp from 1J- Pad to 2A pad, spot and RU same. Move power pack modules to 2A pad. 09:00 12:00 3.00 MIRU MOVE MOB P Prep Camp for move. Lift camp put on trucks. Move camp form 1J -pad to 2A pad. 12:00 15:00 3.00 MIRU MOVE MOB P Continue mobilize camp to 2A pad. Set camp, sewer plant and shop on matting boards, and rig up stairs. Prep modules on 1J pad for move. 15:00 00:00 9.00 MIRU MOVE MOB P Mobilize trucks back to 1J. Sow off of road with trailer at 1D pad. Pulled back up and continued to 1J. Load power pack modules onto trucks, prepare trailers with equipment. Notify Security. Move power pack (4 modules) to 2A pad. 10/09/2011 Continue move Power pack modules. Mobilze trucks to 1J pad. Load up Pipe shed modules and Sub base. Move to 2A pad. Spot rig. Spot power pack modules, rockwasher and pipe shed. Rig up attaching all interconnect lines. Rig Accepted at 2100 HRS. Make up lines in cellar. Build berm and spot tank and rig up hardlines. Run COM line from ri• to cam•. 00:00 01:00 1.00 MIRU MOVE MOB P Continue move power pack modules to 2A pad. SPot same on location. 01:00 06:00 5.00 MIRU MOVE MOB P Mobilize trucks to 1J pad. Load up pipe shed modules, rockwasher, and Sub Base. 06:00 13:00 7.00 MIRU MOVE MOB P Move Rig to 2A pad. Spot sub base over 2A -11. 13:00 16:00 3.00 MIRU MOVE MOB P Spot all power pack modules, rockwasher and pipe shed. 16:00 21:00 5.00 MIRU MOVE RURD P Attach all interconnect lines. Steam, Hydraulic, air and water. Work on Rig acceptance checklist. set all stairs. Rig accepted at 2100 HRS. 21:00 00:00 3.00 COMPZ RPEQP1 RURD P Rig up circulating lines in cellar to kill well. Build berm containment and spot tank. Make up hardlines with choke house to tank. Run COM line from rig to camp. 10/10/2011 Complete RU of hardlines. Pick up Lubricator and pull BPV as per FMC. test lines to 2500 PSI. Open well and kill well, bleedingh 1200 PSI of gas off down to 500 PSI. Pump 200 BBLS of seawater, and then bullhead 165 BBLS. Nipple down tree. Install adapter flanges and nipple up BOP's. Bullhead 10 BBLS down IA every hr. Page 1 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 COMPZ WELCTL RURD P Complete rig up of hard lines. Pull lubricator to floor. Pull BPV as per FMC Rep. TBG Pressure = 1300 PSI. Inner Annulus Pressure = 400. OA = 700 PSI. Load pits with 8.6 PPG seawater. 03:00 03:30 0.50 COMPZ WELCTL PRTS P Load lines with seawater. Pressure test lines to 2500 PSI. 03:30 06:00 2.50 COMPZ WELCTL KLWL P Open well to choke. Bleed gas off off tbg down to 500 PSI. Bleed IA gas down to 450 PSI. Circulate well at the GLM at 5735' @ 2.5 BPM pumpiong a total of 200 BBLS. Shut in. FCP = 50 PSI. Final choke pressure = 30 PSI. Blow down hard lines & choke to slop tank. 06:00 07:30 1.50 COMPZ WELCTL KLWL P Monitor well - static. Pump down annulus bullheading 165 BBLS of 8.6 PPG seawater. Pumps from 1 -3 BPM - 100 PSI. 07:30 08:00 0.50 COMPZ WELCTL OWFF P Monitor well. Pressures = 0 PSI. 08:00 09:30 1.50 COMPZ WHDBO RURD P Make up Lubricator, and set ISA BPV. RD Lubricator. 09:30 11:00 1.50 COMPZ WHDBO NUND P Hels PJSM. Nipple down Tree. Inspect hanger threads - good. 11:00 12:00 1.00 COMPZ WHDBO NUND P Niplple up 7 1/16" x 11" Adapter flange. SIMOPS: Change out Link Tilt bolts on Top Drive. Crew Change 12:00 19:00 7.00 COMPZ WHDBO NUND P Continue NU adapter flanges. NU BOP stack. Make up Kill and choke lines. SIMOPS: Load pipe shed with 174 jntrs of 4" DP. 19:00 00:00 5.00 COMPZ WHDBO NUND P Open BOP doors. Install 2 7/8" x 5" _ VBR's in both Too and bottom set of rams. Instal Blind rams. Pull flanges off of spacer spool fo installation of 3 1/8" x 5K valves. Crew Change 10/11/2011 Continue nipple up valves on spacer spool. Install test joint Test BOP's as permit. Witness of test by AOGCC rep Matt Herrera. Testes to 250 / 3000 PSI as per permit. Observed blanking plug in hanger failed and needed to be replaced. Observed Choke manifold valves #4, #5 failed and were rebuilt, tested - passed. 10.5 HR BOP test. RD equipment. Establish fluid losses of 100 + BPH. Pumped 25 BPH down annulus. Pull Blanking plug. RU landing jnt ( 3- 10' Pups). BOLDS> Pull hanger, and tubing to upweight, and in 10K increments to 100K Max pull. Repeat, verify tbg not free. Call for HES E -line. Continue work tbg string, monitor well - losses. Total fluid loss for the day = 675 BBLS. 00:00 01:00 1.00 COMPZ WHDBO NUND P Continue nipple up BOP's installing 3 1/8" x 5K valves on spacer spool. Notify AOGCC. 01:00 02:00 1.00 COMPZ WHDBO BOPE P Rig up to test BOP's installiong 2 7.8" test jnt. Rig up chart & lines. Page 2 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 14:00 12.00 COMPZ WHDBO BOPE P Test BOP's as Der permit. Test pressure 250 / 3000 PSI. Witness of fp test by AOGCC rep Matt Herrera. Observed blanking plug failed in y/ hanger. Pulled same, redressed & installed. Observed choke manifold vavles #4, #5 failed initial test and were rebuilt. Test resumed, completing testing Annular, Upper and Lower rams ( 2 7/8" x 5" VBR's), Blind Rams, and HCR's. Test choke manifold and all valves. Test all rig floor safety valves. All test recorded on chart. Perform Koomey test with initial 200 PSI in 43 seconds, and fill 3000 PSI in 3 min - 9 seconds. Observed 5 Nitrogen bottles with avg 2100 PSI. Continue pump 25 - 30 BPH down annulus. 14:00 15:00 1.00 COMPZ WHDBO BOPE P Rig down test equipment. Make up FMC tools, RIH to check poppit for gas. Observed some gas under BPV. 15:00 16:15 1.25 COMPZ WELCTICIRC P Close Blind rams, and bullhead 40 B$LS down tbg at.1 BPM - 550 PSI. Bull head 20 BBLS down IA. Observed well on vaccuum. 16:15 18:00 1.75 COMPZ WHDBO RURD P Make up FMC BPV retrieving tools, with centralizer and bumper sub. Close annular and pull BPV as per FMC. No gas. Breakout and lay down retrieving tools, and BPV with blanking plug. 18:00 19:30 1.50 COMPZ WELCTI OWFF P Pump 8.6 PPG fluid down tbg and establish losses at 100 plus BPH. Discuss with engineer, and pump 25 BPH, with continuous monitoring of well. Top off at 3 hrs. Pull tools to rig floor. 19:30 20:15 0.75 COMPZ RPCOM PULL P Make up landing joint consisting of 3 - 2 7/8" x 10' pups. Make up to tbg hanger, with Top Drive. Back out Lock down screws. 20:15 21:00 0.75 COMPZ RPCOM PULL P Pull on tbg, observing free movement on hanger, and continue in 10K increments to finally max pull of 100K. repeat working tbg string, verifying tbq not free. Continue work string from 60K - 100K. Call for HES E -line crew. 21:00 00:00 3.00 COMPZ RPCOM CIRC P Mix & Spot 30 BBLS Flozan pill in tubing, for losses. Continue pump 25 - 40 BPH down annulus, monitoring well. Total losses for the day = 675 BBLS. Bullheaded a total of 270 BBLS Page 3 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/12/2011 24 hr Summary Held PJSM with HES E -line crew. RU E -line with lubricator and drift assembly for 1 11/16" Drift. WLIH to 5750' WLM. Wireline drift to 5750 with 2.25" drift. RD E -line unit. Spot Slickline unit. Run 1.4" LIB, locate mandrel!. Repeat run to locate AV Nipple. RD Slickline. RU E -line. WLIH with 2 25" WRP. Continue with loading hole with 25 -30 BPH - monitor well. Total fluid losses for the day - 915 BBLS 00:00 00:30 0.50 COMPZ RPCOM PULL P Pull tubing in tension to 75K up weight. Continue fill IA with 25 -30 BPH. Monitor well 00:30 01:30 1.00 COMPZ RPCOM RURD P Rig down top pup on landing joint with crossovers. 01:30 02:00 0.50 COMPZ RPEQP1SFTY P Held PJSM with crew and HES E -line crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up E -line with sheaves and lubricator. 02:00 04:30 2.50 COMPZ RPEQPI ELNE P RU E -line unit. Make up Crossovers to lubricator. Assemble tool string for 1 11/16" drift. Install pump in sub with hose on Lubricator. 04:30 06:30 2.00 COMPZ RPEQPI ELNE P WLIH to 5750'. Continue fill IA with 25 - 30 BPH. Monitor well. POOH lay down assembly. 06:30 08:30 2.00 COMPZ RPEQP1 OWFF P Fill hole & establish loss rates while wait on tools. Loss rate pumping 240 BBLS plus and hour. Conitnue monitor well with 25 -30 BPH pumped in annulus. Spot 3 PPB Flozan pill down tbg at 3 BPM - 200 PSI. 08:30 09:30 1.00 COMPZ RPEQPI ELNE P Make up 2.25" Drift assembly and WLIH to 5750'. WLOH. 09:30 10:30 1.00 COMPZ RPEQPI ELNE P Rig down E -line unit. Wireline crew timed out. Sent to camp. 10:30 12:00 1.50 COMPZ RPEQP1SLKL P Move in and rig up HES slickline unit. Crew Change Total fluid loss for tour = 558 BBLS. 12:00 12:30 0.50 COMPZ RPEQP1SFTY P Held PJSM with crew and HES Slickline crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up with sheaves and lubricator. 12:30 14:30 2.00 COMPZ RPEQP1 RURD P Rig up Slickline sheaves and Lubricator assembly with grease head. Install pump in sub with hose. Continue fill hole with 25 -30 BBLS / HR. 14:30 18:15 3.75 COMPZ RPEQPI SLKL P WLIH with kick over tool and LIB to 5735'. Located mandrel, but no confident on depth of valave. POOH. Add Knuckle joint to assembly. Set down on Valve at 5674'. POOH, lay down tools. Good indication of OEJ on LIB. 18:15 20:00 1.75 COMPZ RPEQPI SLKL P Change out tools, make up 2.27" Swedge. WLIH to tie into AV nipple. Set down at 5742'. POOH, evaluate. 20:00 20:30 0.50 COMPZ RPEQPI RURD P Rig down Slickline unit. 20:30 21:30 1.00 COMPZ RPEQPI RURD P Move in and rig up HES E -line unit. Page 4 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 21:45 0.25 COMPZ RPEQPI SFTY P Held PJSM with crew and HES E -line crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up E -line with sheaves and lubricator. 21:45 22:30 0.75 COMPZ RPEQPI ELNE P Install crossovers on 2 7/8" stump, and rig up lubricator. Make up 2.25" WRP plug. 22:30 00:00 1.50 COMPZ RPEQPI ELNE P WLIH with 2.25" WRP to locate at 90 ft/min. Crew Change. Total losses for the tour = 357 BBLS. Total losses for the day = 915 BBLS. 10/13/2011 WLIH to set WRP @ 5615 WLM. Verify set. WLIH set junk catcher on top of WRP. Make up 2 7/8" tbg cutter, and WLIH to cut tubing @ 5660'. WLOH, RD E -line crew. Rig up and pull on tbg to verify free movement. POOH lay down 179 jnts and cut off jnt of 2 7/8" tbg. Rig up and test rams and annular with 4" test joint to 250 / 3000 PSI. Test WRP plug and casing to 3000 PSI - record on chart. Change out saver sub on Top Drive. Insatll WB. Make up BHA #1 - bit & scraper assembly, and single in hole with 4" DP. No fluid losses for the day. 00:00 00:30 0.50 COMPZ RPEQPI PLUG P Continue WLIH to locate & set WRP at 5615' WLM.,Verify set by setting down, and observing weight loss. 00:30 02:00 1.50 COMPZ RPEQPI ELNE P Make up 2.28" Junk Catcher, and WLIH to locate & set same above WRP at 5612'. WLOH. Verify Catcher set. 02:00 04:30 2.50 COMPZ RPEQPI ELNE P Make up 2 7/8" tbg radial cutter assembly. WLIH to locate cutter in the firsat full joint above packer at 5660' WLM. Fire cutter. Note: Tubing in tension @ 75K. Observed fired cutter on surface. POOH lay down E -line tools. 04:30 05:15 0.75 COMPZ RPEQP1CIRC P Circulate hole volume through pump in sub on surface. No gas. Pumps at 5 BPM - 840 PSI. 05:15 05:45 0.50 COMPZ RPEQP1 RURD P Rig down crossovers and pump in sub. Clear floor. 05:45 06:45 1.00 COMPZ RPCOM RURD P Held PJSM - rig up power tongs to pull tbg. Pull on tbg to verify free movement at 63K up weight. Block weight = 35K. 06:45 10:00 3.25 COMPZ RPCOM PULL P POOH to 3800',, breakout & lay down 2 7/8" tubing. Observed correct displacement. Stop and monitor well. 10:00 10:30 0.50 COMPZ RPCOM CIRC P Circulate S -S at 5 BPM - 650 PSI. Well out of balance. 10:30 12:00 1.50 COMPZ RPCOM PULL P Continue POOH to 3403', lay down 71 joints, 1 SSSV, 1 GLM recovering 35 SS bands. Observed proper displacement. Crew Change 12:00 16:00 4.00 COMPZ RPCOM PULL P Continue POOH to surface, breakout & lay down a total of 179 joints and a 14' cut off joint of 2 7/8" tubing. Take pictures of cut, and post on S drive. Good Cut. All tubing and jewelry strapped while POOH. Observed correct displacement. Page 5 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:30 0.50 COMPZ WELLPF RURD P Rig down power equipment, and clear floor. 16:30 17:00 0.50 COMPZ WELLPF PRTS P Close blind rams. Rig up chart recorder. Pump down kill line to test casing aciainst the WRP plug to 3000 PSI. Good test. Bleed pressure. 17:00 18:30 1.50 COMPZ WHDBO BOPE P Rig up with 4" test joint and test plug. Test 2 7/8" VBR's upper and lower rams, and annular to 250 / 3000 PSI for completion of BOP test. RD test equipment. 18:30 19:45 1.25 COMPZ WELLPF RGRP P Inspect and replace saver sub on Top Drive. 19:45 20:30 0.75 COMPZ WELLPF PULD P Install wear bushing with 3 1/2" test joint. RILDS 20:30 20:45 0.25 COMPZ WELLPF SFTY P Held PJSM with crew and BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make up BHA and run same. 20:45 21:15 0.50 16 COMPZ WELLPF PULD P Pull jets from bit to leave open. Make up BHA #1 with bit & scraper assembly. Total BHA length = 16.06'. 21:15 00:00 2.75 16 1,702 SURPRI WELLPF TRIP P Trip in hole with BHA #1 picking up singles of 4" drill pipe from shed to 1702'. Observed proper displacement. Crew Change 10/14/2011 Continue run BHA #1, Bit & scraper assembly picking up single of 4" DP from shed. Lightly tag top of tbg stump @ 5637' DPM. Circulate hole clean. POOH. RU HES E -line. Rehead. Service rig. WLIH with FastCast assembly. MU Stringshot assembly. WLIH fire in second collar above TOC @ 2100'. WLOH, RD HES E -line. MU BOT RBP and RIH to set same at 2650' DPM. Pressure test plug to 250 / 3000 PSI. Record on chart. Rig on Hi -Line power at 10:00 HRS. 00:00 03:45 3.75 1,702 5,637 COMPZ WELLPF TRIP P Continue trip in hole with BHA #1 picking up singles of 4" drill pipe from shed. Observed proper displacement. Lightly tag top of tubing stump at 5637' DPM, with 5K. 03:45 04:15 0.50 5,637 5,637 COMPZ WELLPF CIRC P Rig up and circulate bottoms up at 6 BPM - 400 PSI. Monitor well - static. 04:15 04:45 0.50 5,637 5,637 COMPZ WELLPF RURD P Monitor well, install air slips, adjust crown -o- matic. 04:45 08:30 3.75 5,637 0 COMPZ WELLPF TRIP P POOH racking back 4" DP, to BHA. Breakout & lay down BHA. Notify E -line at 0500 HRS. 08:30 09:15 0.75 0 0 COMPZ WELLPF PULD P Clean & clear rig floor. Blow down all lines. Monitor well. 09:15 12:00 2.75 0 0 COMPZ WELLPF OTHR P Wait on E -line unit. Rebuild Demco valves. Service rig. Crew Change 12:00 13:30 1.50 0 0 COMPZ WELLPF ELNE P Spot E -line unit and Rehead. Held PJSM with crew & E -line crew. Discuss safety & hazard recognition issues. Discuuss procedure to rig up and run tools. 13:30 14:30 1.00 0 0 COMPZ WELLPF RURD P Rig up E -line unit. Hange sheaves. Make up tool assembly. Page 6 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 17:30 3.00 0 0 COMPZ WELLPF ELNE P WLIH with CBL fasCast assembly at 100 ft/minute to 5600'. Evaluate logs to determine TOC 2100'. WLOH 17:30 20:30 3.00 0 0 COMPZ WELLPF ELNE P Lay down assemly. make up 240 Grain Stringshot assembly. WLIH to locate casing collar above op of cement at 2015' WLM. Fire WLOH lay down assembly. 20:30 21:00 0.50 0 20 COMPZ WELLPF PULD P Held PJSM with BOT Rep. Make up RBP on a joint of DP. Total BHA = 20.13'. 21:00 23:00 2.00 20 2,650 COMPZ WELLPF TRIP P Trip in hole with RBP BHA. Loacrte & set RBP with center of element at 2650' DPM. Top of RBP @ 2645'. 23:00 00:00 1.00 2,650 2,650 COMPZ WELLPF PRTS P RU and pressure test RBP to 0 / 250 / 3000 PSI. Hold 10 minutes on chart recorder. Crew Change. 10/15/2011 POOH with Retreiving tool. MU Bit sub on DP and TIH to above RBP. Dump 1200 lbs of sand down drill string. Allow to fall. Tag sand top at 2592'. POOH. Change out lower rams, install 7 ". ND BOP's. Perform body test on BOP's to 250 / 3000 PSI. Bleed OA to zero PSI. ND Spacer spools. Rig up Hydratite equipment. Work tbg spool free to observe 26" in casing growth. Pull casing in tension to 75K, for another 9" growth. Make up WACHS cutter assembly to cut off 35" casing stump. 00:00 01:15 1.25 2,650 0 COMPZ WELLPF TRIP P POOH with RBP retreiving tool. Inspect and lay down same. 01:15 03:00 1.75 0 2,580 COMPZ WELLPF TRIP P Make up 4 3/4" Bit sub up on DP. TIH to above top of RBP at 2600'. 03:00 08:45 5.75 2,580 2,580 COMPZ WELLPF OTHR P RU sand table on DP. Dump 1200 lbs of sand down drill pipe without packing off. Allow sand to fall. Pull DP and slack off to tag top of sand at 2592' DPM. Retag. 08:45 09:30 0.75 2,580 0 COMPZ WELLPF TRIP P POOH and lay down bit sub assembly. 09:30 10:15 0.75 0 0 COMPZ WELLPF RURD P Drain BOP stack. Pull wear bushing. Install test plug. 10:15 12:00 1.75 0 0 COMPZ WHDBO NUND P Change out lower rams from 2 7/8" x5" VBR's to 7" solid body rams. RU to test. Crew Change 12:00 13:00 1.00 0 0 COMPZ WHDBO BOPE P Pull test joint. Fill BOP stack. Close blind rams and perform body test to 250 / 3000 PSI.Record on chart. RD test equipment. Pull test plug, and drain stack. Blow down all lines. 13:00 14:30 1.50 0 0 COMPZ WHDBO NUND P Attch lines to bleed tanks. Bleed OA from 400 PSI, verify OA dead. Nipple down BOP stack, spacer spool & adapter flange. 14:30 17:30 3.00 0 0 COMPZ WHDBO NUND P Dissasemble tbg spool. Continue monitor OA. LEL @ 90, then bled off. Verify no gas and OA dead. 17:30 18:15 0.75 0 0 COMPZ WHDBO NUND P RU Hydratite equipment on tbg spool as per rep. BOLDS. Page 7 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 22:30 4.25 0 0 COMPZ WHDBO NUND P Function Hydratite equipment to allow casing expansion, observing a total of 26" of growth. Remove tubing spool from stump. SIMOPS: Make up 7" casing spear assembly on rig floor as per BOT rep. 22:30 23:15 0.75 0 0 COMPZ RPCOM CUTP P RIH with 7" casing spear, engage 7" casing. Pull to 75K over block weight, observing 9" more casing growth. Observed casing packoff and slips remained in place and set. release & pull spear. Lay down same. 23:15 00:00 0.75 0 0 COMPZ RPCOM CUTP P PJSM. Make up WACHS cutter as per FMC rep to cut 7" casing stump. Crew Change 10/16/2011 Complete casing stump cut. Nipple up spacer spool, and BOP's. RU & test same to 250 / 1500 PSI. Make up BOT Multi- string cutter. RIH to locate collars and perform cut @ 1994'. Take Arctic pack returns to slop tank. Attempt to gain circulation to OA. Packed off. Monitor well. POOH with Cutter. Make up Spear with Packoff. Attempt to circulate. Observed 7" casing not free. No circulation. Release spear. Perform gauge run through cut at 1994'. Drain stack. Nipple down at the spool. RIH with spear and engage 7" casing. Pull in tension to 140K, pull emergency slips. NU. Prep to test BOP's. 00:00 00:30 0.50 0 0 COMPZ WELLPF CUTP P Complete cut with WACHS cutter of 35" of 7" casing stump. RD cutter. 00:30 00:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to nipple up spools and BOP's. 00:45 04:30 3.75 0 0 COMPZ WHDBO NUND P Nipple up spacer spools, and BOP's. 04:30 05:45 1.25 0 0 COMPZ WHDBO BOPE P RU and test BOP breaks with 250 / 1500 PSI. Rig down test equipment. OA = 0 PSI. 05:45 08:00 2.25 0 2,000 COMPZ WELLPF CUTP P Make up BOT Multistring cutter assembly. Trip in hole to 2000' 08:00 09:00 1.00 2,000 2,000 COMPZ WELLPF OWFF P Monitor well - observed slight flow of arctic pack to slop tank. 09:00 09:30 0.50 2,000 2,000 COMPZ WELLPF CUTP P RIH to locate 7" casing collars at 2014' and 1971'. Locate knives and make cut in 7" at 1994'. UP WT = 60K, SO WT = 60K. 09:30 11:00 1.50 2,000 2,000 COMPZ WELLPF CIRC P Monitor well, taking arctic pack returns to slop tank. Pump 10 BBLS seawater down 7" casing at 1.5 BPM, observing good returns initially to slop tank until flow stopped. 11:00 11:30 0.50 2,000 2,000 COMPZ WELLPF OWFF P Monitor well. Static. Blow down lines. 11:30 12:00 0.50 2,000 1,759 COMPZ WELLPF TRIP P POOH racking back DP. Crew Change 12:00 13:00 1.00 1,759 0 COMPZ WELLPF TRIP P Continue POOH racking back DP. Lay down Multi- string cutter. Inspect knives verifying good cut. Page 8 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:15 1.25 0 0 COMPZ RPCOM PULL P Make up 7" casing spear with packoff. Engage casing stump. Pull to string weight. Continue in 10K increments to 160K. Observed 7" casing not free. Close annular and break circulation @ .5 BPM. Pressure increased to 700 PSI. Minimal returns to slop tank. Bleed pressure. 14:15 14:45 0.50 0 0 COMPZ WELLPF CIRC P Rig up Little Red Services, pressure test lines to 2000 PSI. 14:45 15:30 0.75 0 0 COMPZ WELLPF CIRC T Attempt to break circulation with LRS with 90 Deg diesel, at .75 BPM. Once again, pressure to 700 PSI. Increased to 1000 PSI, and 1200 PSI. Held 10 Minutes. Minmal returns, and then pressure held. Bleed all pressures. Open annular. Pull 7" caisng to 180K. Observed 3.5" of total stretch. 15:30 16:15 0.75 0 0 COMPZ WELLPF RURD T Release spear, POOH lay down same. Blow down lines to slop tank. 16:15 19:15 3.00 0 0 COMPZ WELLPF TRIP T Make up Bit sub, XO. RIH with drill pipe to 2000' for gauge run. POOH lay down same. 19:15 19:45 0.50 0 0 COMPZ WELLPF PULD T Make up 7" spear assembly. RIH to engage 7" casing stub. Pull to tension at 50K. 19:45 20:00 0.25 0 0 COMPZ WELLPF SFTY T Held PJSM with crew and FMC rep. Discuss safety & hazard recognition issues. Discuss procedure to nipple down BOP's and pull emergency slips. 20:00 22:30 2.50 0 0 COMPZ WELLPF NUND T Nipple down BOP's at the spacer spool. Pull BOP's above casing head. Rig up, and tie into emergency slips. Pull casing in tension to 160K, allowing slips to travel up enough for dissassemble. Pull slips free from bowl. Slack off 7" casing and release spear assembly. Pull spear out of hole. 22:30 23:45 1.25 0 0 COMPZ WELLPF NUND T Nipple up BOP's at the spacer spool. 23:45 00:00 0.25 0 0 COMPZ WELLPF PULD T Breakout & lay down spear assembly. 10/17/2011 Continue NU BOP's. Pressure test spacer spool break to 250 /1500 PSI. Install test plug. Rig up test equipment. Perform weekly BOP test. Witness of test waived by AOGCC rep Chuck Sheve. Test BOP's to 250 / 3000 PSI on chart. Perform accumulator test. Observed first 200 PSI obtained in 42 Sec, and full 3000 PSI obtained in 2 Min - 29 seconds. Make up BOT Spear assembly. RIH engage 7" casing fish. Pull on casing working up to 235K. Not free. Lay down spear assembly. RU HES E -line. Run Free point tools. Engage spear once again and pull to verify freepoint. E -line confirmed "Stuck" depth at 1970' WLM. RD E -line. Make up BOT Multistring cutter. TIH to locate collars and make a cut in the 7" at 1949' DPM. Page 9 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 COMPZ WHDBO NUND T Continue NU spacer spool and BOP's. Perform 250 / 1500 PSI test on spacer spool break. Observed charged up OA, and allow arctic pack to flow out to slop tank. 01:30 07:30 6.00 0 0 COMPZ WHDBO BOPE P RU test equipment. Install test plug. RU and test BOP's for weekly test. Witness of test waived by AOGCC rep Chuck Sheve. Test Upper & lower rams, Blinds and annular. Test choke manifold and all valves. Test all rig floor safety valves, with 4" and 7" test joints to 250 / 300 PSI.Record all test on chart. Performed Accumulator test, with first 200 PSI obtained in 42 seconds, and full 3000 PSI in 2 minutes, 29 seconds. Observed 5 Nitrogen bottles with an average 2100 PSI. Rig down all test equipment. 07:30 11:15 3.75 0 0 COMPZ WELLPF PULL T Make up BOT spear assembly with packoff. RIH engage casing. Pull on caising increasing up weight to finally pull to 235K working casing string approximately 18 ". Not free. Attempt to pump down 7" and observed pressured up to 1000 PSI. Total fluid pumped = 5 BBLS. Observed pressure would gradually fall to 300 PSI. 11:15 12:00 0.75 0 0 COMPZ WELLPF RURD T Breakout & lay down spear assembly. Crew Change 12:00 12:45 0.75 0 0 COMPZ WELLPFSFTY T Held PJSM - Rigging up HES E -line. 12:45 14:00 1.25 0 0 COMPZ WELLPF ELNE T Make up free point tool string, WLIH to 500'. Observed tool failure/ Trouble shoot. WLOH lay down tools. 14:00 16:45 2.75 0 0 COMPZ WELLPF ELNE T Trouble shoot tool. RIH to 200'. POOH. Wait on backup tool from Deadhorse. 16:45 18:45 2.00 0 0 COMPZ WELLPF ELNE T Make up tools. WLIH to 2120', magnetized tool string for correlation log. WLOH, lay down sheave. 18:45 19:15 0.50 0 0 COMPZ WELLPF FISH T Set back E -line tools. RIH with spear and engage casing. Pull' on casing working to 235K, repeat 2 times. release spear. Lay down same. RU E -line sheaves. 19:15 21:00 1.75 0 0 COMPZ WELLPF ELNE T MU Toolstring, WLIH to 2050' WLM. Log to verify "stuck" depth at 1970'. Post log on S Drive. WLOH, rig down E -line. 21:00 22:15 1.25 0 0 COMPZ WELLPF FISH T Make up Spear assembly with jars assembly. Observed we could not screw into Top Drive safely with jarring assembly because of the short joint. Breakout & lay down tools. . Page 10 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:30 0.25 0 0 COMPZ WELLPF RURD T Make up BOT Multi- string cutter assembly. 2 1/2" Knives on cutter. 22:30 00:00 1.50 0 1,913 COMPZ WELLPF TRIP T Trip in hole with Multi- string cutter assembly to 1913'. UP WT = 60K, SO WT = 60K. 10/18/2011 PJSM. Locate casing collars with Multi- string Cutter. Make cut in 7" casing at 1949' DPM. Observed fluid swapping. POOH, lay down cutter assembly. Make up casing spear assembly. Engage 7" Casing. Pull to 95K to observe casing pulled free with an upweight of 85K. Break circualtion to OA with 3 BPM - 300 PSI. RU Little Red services, pump 130 BBLS of 100 Deg diesel. Allow to soak in OA. Continue pump remaining 70 BBLS diesel, chase with 200 BBLS of 140 Deg Seawater at 5 BPM. Pump 100 bbls of brine, PJSM, RU, L/D 7" casing from cut @ 1949'. Clean floor. Make up Spear BHA, RIH to 1914', engage fish @ 1949', jar until free, circ 150 bbls seawater from /to pit #5, perform post jar derrick inspection, trip out w/ cut 7" casing. Lay down top cut 19.70' & bttm cut 23.57'. Removed 1971.56' of 7 ". With RKB of 2631', top of stub @ 1997.87'. 00:00 00:30 0.50 1,913 1,949 COMPZ WELLPFCUTP T Held PJSM. Locate casing collars with Multi - string cutter at 1929' and 1969' DPM. Locate knives to make cut at 1949'. UP WT = 60k, SO WT = 60k. Rotate drill string at 60 RPM's 1K TQ. Pumps at 5 BPM to open knives and make cut. Observed 300 PSI pressure loss when cut out. 00:30 00:45 0.25 1,949 1,949 COMPZ WELLPFOWFF T Monitor well, observed fluid dropping in 7" and flow to outside tank. Monior well until balanced. 00:45 01:45 1.00 1,949 0 COMPZ WELLPF TRIP T POOH. Breakout & lay down Multi- string cutter. Inspect knives. 01:45 02:15 0.50 0 0 COMPZ RPCOM PULL T Make up 7" Casing spear with Packoff. RIH to engage fish. Pull to 95K observing casing pulling free and 85K up weight. Pumps on, pump at 3 BPM to verify good circulation @ 300 PSI. SIMOPS: RU Little Red Hot Oil. 02:15 02:30 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew and Little red reps. Discuss safety & hazard recognition issues. Designate Spill Champion. Discuss procedure to pump hot diesel. 02:30 04:00 1.50 0 0 COMPZ RPCOM CIRC P With Little Red. Pressure test lines to rig floor to 1500 PSI. Close annular. Open up to LRS, pump 100 Deg Diesel down 7" taking returns to slop tank. Pump at max rate of 2 BPM - 650 PSI. Pump 130 BBLS. 04:00 04:30 0.50 0 0 COMPZ RPCOM CIRC P Allow diesel to soak in the OA. 04:30 05:15 0.75 0 0 COMPZ RPCOM CIRC P Continue pump remaining 70 BBLS of diesel from Little Red @ 2 BPM - 500 PSI. 05:15 06:00 0.75 0 0 COMPZ RPCOM CIRC P Continue pumping chasing Diesel with 200 BBLS of 140 DEG seawater to clean up 7" casing and OA © 4 BPM - 300 PSI. 06:00 06:30 0.50 0 0 COMPZ RPCOM CIRC P Pump another 100 bbls of cold brine from pits, pumping 5 bpm w/ 400 psi. Taking returns to the tiger tank. 06:30 06:45 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on rigging up tools to lay down 7" casing. Page 11 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:00 0.25 0 0 COMPZ RPCOM RURD P Rig up Doyon casing tools. 07:00 10:30 3.50 1,949 0 COMPZ RPCOM PULL P Pull 7" casing to the floor. Lay down spear and cut joint of casing (joint which was set on slips). Continue to lay down 7" casing. Calculated fill 18.75 bbls, actual 18 bbls. Note: Total joints pulled = first cut joint (27.90'), 44 full joints and the bottom cut joint (21.28'). A total of 16 joints appeared bent : joints # 2,3,6,8,12,15,21,22,25,28,29,30,31,3 4,37,and 42. 10:30 11:30 1.00 0 0 COMPZ WELLPF RURD P Clean and rig down casing tools. 11:30 12:00 0.50 0 0 COMPZ WELLPF OTHR P Clean rig floor. 12:00 12:15 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting 12:15 13:00 0.75 0 0 COMPZ WELLPF PULD P Pick up spear and cut joint. Break cut joint f/ spear. Redress grappel and packoff. 13:00 13:45 0.75 0 0 COMPZ WELLPF OTHR P Install 9" ID FMC wear bushing. 13:45 15:00 1.25 0 228 COMPZ RPCOM PULD T Make up BHA to spear casing © 1949'. 15:00 16:00 1.00 228 1,914 COMPZ RPCOM TRIP T RIH to 1914'. Make a top drive connection. PU wt 65k, SO wt 65k. 16:00 16:15 0.25 1,914 1,949 COMPZ RPCOM FISH T Break circulation, pumping 3 bpm w/ 75 psi. Wash down f/ 1914' to casing stub @ 1949'. Observed pressure increase @ 1945'. Shut down pumps. Pick up 5'. open bleeder line. Slack off into stub, set down 10k to engage spear. 16:15 19:15 3.00 1,949 1,949 COMPZ RPCOM JAR T Start jarring on 7" casing. Pulling to 160k to jar (95k over), then straight pull to 225k (160k over) with 500 psi casing. Increased pressure to 1000 psi. Observed slight movement of 7 ". 19:15 20:15 1.00 1,949 1,949 COMPZ RPCOM JAR T Continue to jar until free. 20:15 21:00 0.75 1,949 1,881 COMPZ RPCOM TRIP T Rack back a stand. Monitor well. Pick up 10' well swabbing. 21:00 21:30 0.50 1,881 1,881 COMPZ RPCOM CIRC T Break circulation @ 7 bpm w/ 250 psi. Circulate two bottom's up. Sim ops: performing derrick inspection. 21:30 22:00 0.50 1,881 1,881 COMPZ RIGMN1OTHR T Perform derrick inspection after jarring. 22:00 22:45 0.75 1,881 228 COMPZ RPCOM TRIP T Pull out of the hole w/ 7" casing on 4" drill pipe from 1881' to 228'. 22:45 00:00 1.25 228 0 COMPZ RPCOM PULD T Work BHA. stand back 2 stands of 4 -3/4" DC's, UD intensifiers, oil jars and bumper jars. Release spear from 7" cut off joint. Top joint 19.70', bottom cut 23.57'. Calculated fill 13 bbls, actual 13.25 bbls. Note: Removed a total 1971.56' of 7 ". With RKB of 2631', top of stub @ 1997.87'. Page 12 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/19/2011 24 hr Summary Change lower pipe rams to 2 -7/8" x 5" VBR's, test to 250 and 3000 psi, install wear bushing, slip and cut drill line, MU 9 -5/8" scraper assembly, RIH to 1973' (tagged up), circ, POOH and UD scraper, MU tandem milling assembly, RIH to 1920', mill cement, tag stump @ 1992.48', circ, POOH, UD tandem mill assembly, RU HES f/ Gyro Data gyro and PDS caliper log, RIH to 1986' Gamma Ray depth f/ caliper, POOH, lay down tools, MU BHA to wash over cut joint @ 1992.48' RKB. 00:00 00:30 0.50 0 0 COMPZ WELLPF PULD P Lay down 7" casing equipment, Baker tools, and clean floor. 00:30 00:45 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting 00:45 02:30 1.75 0 0 COMPZ WHDBO OTHR P Pull FMC 9" ID wear bushing. Set test plug. Change out lower pipe rams from 7" to 2 -7/8" x 5" variables. Rig up to test. 02:30 02:45 0.25 0 0 COMPZ WHDBO BOPE P Fill stack. Test lower pipe rams to 250 psi low and 3000 psi high. Hold each test f/ 5 minutes. Record on chart recorder. 02:45 03:00 0.25 0 0 COMPZ WHDBO RURD P Rig down testing equipment. Install 9" ID FMC wear ring. 03:00 03:15 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting. 03:15 04:15 1.00 0 0 COMPZ RIGMNT SLPC P Slip and cut 45' of 1/1/4" drilling line. 04:15 04:30 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting. 04:30 05:15 0.75 0 18 COMPZ WELLPF PULD P Make up 9 -5/8" scraper asseembly. 05:15 06:30 1.25 18 1,973 COMPZ WELLPF TRIP P Run in the hole w/ scraper assembly on 4" drill pipe, tagged up @ 1973'. Calc displ 11 bbls, actual 10.5 bbls. 06:30 06:45 0.25 1,973 1,973 COMPZ WELLPF WASH P Make a top drive connection, attempt to wash down (no -go). Washing /pumping 5 bpm w/ 100 psi. PU wt 60k, SO wt 60k. 06:45 07:30 0.75 1,973 1,973 COMPZ WELLPF WASH P Pump 150 bbls of 150 deg 8.6 seawater. Pumping 4 bpm w/ 75 psi. Reciprocate pipe while circulating. PU wt 60k, SO wt 60k. 07:30 07:45 0.25 1,973 1,973 COMPZ WELLPF OWFF P Monitor well- static. 07:45 08:30 0.75 1,973 18 COMPZ WELLPF TRIP P Pull out of the hole w/ 9 -5/8" scraper. Calc fill 11 bbls, actual 10.75 bbls. 08:30 09:00 0.50 18 0 COMPZ WELLPF PULD P Lay down scraper assembly per Baker rep. 09:00 09:30 0.50 0 0 COMPZ RIGMNT SVRG P Clean and clear rig floor. Service rig equipment. 09:30 10:00 0.50 0 0 COMPZ WELLPF PULD P Pick up Baker tools from Beaver slide. 10:00 10:15 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting 10:15 12:30 2.25 0 327 COMPZ WELLPF PULD P PU /MU Baker tandem milling assembly. 12:30 13:30 1.00 327 1,920 COMPZ WELLPF TRIP P Run in the hole w/ milling assembly to 1920'. Page 13 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 1,920 2,029 COMPZ WELLPF MILL P Make a top drive connection @ 1920'. Wash down from 1920' (6 -1/8" tapered mill), pumping 3 bpm w/ 75 psi. Tag cement w/ lower watermelon mill (8 -3/8" @ 1966'). Picked up 5'. Rotate 40 rpm to mill up cement f/ 1966' to 7" casing stump @ 1942.48' (8 -3/8" watermelon mill). Upper watermelon mill (8 -1/2 ") @ 1976.75'. Set down 3k w/ mill. 14:30 15:00 0.50 2,029 2,029 COMPZ WELLPF CIRC P Pump 30 bbl hi vis sweep and chase w/ 35 bb of 150 deg 8.6 seawater f/ vac truck. Pump failed on truck. Chased w/ 170 bbls of 8.6 seawater f/ pits, pumping 8 bpm w/ 400 psi. 15:00 15:15 0.25 2,029 2,011 COMPZ WELLPF OTHR P Shut down pumps, rack back a stand. Blow down the top drive. 15:15 16:00 0.75 2,011 327 COMPZ WELLPF TRIP P Pull out of the hole f/ 2011' to 327'. 16:00 17:00 1.00 327 0 COMPZ WELLPF PULD P Work BHA, rack back 4 -3/4" drill collars. Lay down BHA. 17:00 17:30 0.50 0 0 COMPZ WELLPF PULD P Lay down mills, clear floor. 17:30 17:45 0.25 0 0 COMPZ EVALWE RURD P Rig up Halliburton e line. 17:45 18:00 0.25 0 0 COMPZ EVALWE SFTY P Pre job safety meeting. 18:00 18:30 0.50 0 0 COMPZ EVALWE PULD P Make up tool string, test- OK. 18:30 21:15 2.75 0 0 COMPZ EVALWE ELOG P Run in the hole w/ GyroData gyro survey and PDS 40 arm caliper in memory mode. Ran caliper to 1975' rig 141 RKB adjusted to 1986' Nabors 26E RKB and Gamma Ray (1986') , and Gyro to 1950' Doyon 141 RKB. Pull out of the hole with tools 50' /min. Note: PDS initial results of caliper looked like buckling starts @ 300', ends @ 1450'. Results will be ready appox noon 10- 20 -11. Will e mail to Brett, Erik, John Condio and company man. 21:15 22:30 1.25 0 0 COMPZ EVALWE RURD P Rig down HES wireline. Lay down tools. Move E line unit. 22:30 23:00 0.50 0 0 COMPZ WELLPF SFTY P Pre job safety meeting. 23:00 00:00 1.00 0 0 COMPZ WELLPF RURD P Rig up to run in and wash over the cut joint (top @ 1992.48', bottom @ 2012.3', joint length left in the hole 19.82'. Make up BHA to wash over cut joint in the hole. Note: Could not get past 262' with 12k. Rotated w/ 30 rpm w/ up to 9k torque. Decision to POOH and run backoff assembly. Page 14 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/20/2011 24 hr Summary MU washover BHA, RIH tag up @ 258', work to 262', decision to POOH, UD BHA, service rig, MU back off BHA, RIH to 2218'. Attempt to back off 7" stub @ 1992.48'- no go. POOH, redress top anchor, RIH to 2218', attempt to back off again, no go. POOH. MU dressing mill assembly to dress stub f/ patch. RIH to 264', took weight, attempt to go / -- no go. Decision to POH to make a tandem 8 -1/2" mill run. POOH UD BHA. 00:00 01:15 1.25 0 258 COMPZ WELLPF PULD P Make up BHA to wash over cut joint in the hole. Note: The cut joint (top @ 1992.48', bottom @ 2012.3', joint length left in the hole 19.82'. 01:15 01 :30 0.25 258 258 COMPZ WELLPF OTHR P Tag up @ 258'. Try to rotate through. PU wt 44k, SO wt 44k. Rotate w/ 40 rpm w/ up to 7k ft Ibs of torque. 01:30 02:00 0.50 258 262 COMPZ WELLPF TRIP T Stand back a stand. Pick up a single. Break circulation, pumping 2 bpm w/ 50 psi. Rotate 30 rpm w/ 500 ft Ibs of torque. While slacking off, torque went up to 3k ft Ibs. At a depth of 262' torque went to 8k ft Ibs. Set down 5k weight, repat several times- no go. Note: Could not get past 262' with 12k slack off. Rotated w/ 30 rpm w/ up to 9k torque. Decision to POOH and run backoff assembly. 02:00 02:15 0.25 262 262 COMPZ WELLPF OTHR T Confirm with Anchorage Engineer. Decision to POOH, UD washover assembly. Will MU backoff assembly. 02:15 03:00 0.75 262 33 COMPZ WELLPF TRIP T Pull out of the hole with the washover BHA assembly from 262' to 33'. 03:00 03:30 0.50 33 0 COMPZ WELLPF PULD T Lay down assembly per Baker rep. 03:30 04:00 0.50 0 0 COMPZ WELLPF PULD P Clear floor of tools. Pick up tools f/ the back off assembly. 04:00 04:30 0.50 0 0 COMPZ RIGMNT SVRG P Service rig. 04:30 04:45 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting. 04:45 06:45 2.00 0 225 COMPZ WELLPF PULD P Make up back off assembly to 225'. 06:45 09:00 2.25 225 2,218 COMPZ WELLPF TRIP P Run in the hole w/ assembly f/ 225' to 2218. Filled last stand of drill collars w/ diesel, and fill every 3rd stand of 4" drill pipe w/ fresh water.Calc displacement 34.4 bbls, actual 33.25 bbls. Page 15 of 41 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:00 10:00 1.00 2,218 2,218 COMPZ WELLPF BKOF P At depth of 2218.36', pressure to 600 psi to set bottom anchor. Slack off 10k, bleed pressure to zero. Pick up with indication of bottom anchor not set. Repeat with same results. Set down 15k, bleed to zero, PU 5k overpull- bottom anchor is set. slack off 2 ", then pressure up to 1500 psi 1 to set top anchor. Slack off 5k on top anchor. Bleed off pressure. Pressure to 3000 psi to start back off. Did not get any turn. Pressure up to 3500 psi, still no turns. Note: 3500 psi = 21000 ft Ibs of torque. 10:00 11:15 1.25 2,218 2,218 COMPZ WELLPF CIRC T Decision made to POOH. Drop ball and rod to open circ sub. Pressure to 2100 psi to open sub. Circulate bottom's up to get diesel out of the hole. Pumping 7 bpm w/ 180 psi. 11:15 12:00 0.75 2,218 2,188 COMPZ WELLPF OTHR T Lay down single of 4" drill pipe. Blow down top drive. Prepare to POOH. 12:00 12:15 0.25 2,188 2,189 COMPZ WELLPF SFTY T Pre job safety meeting. 12:15 13:00 0.75 2,189 225 COMPZ WELLPF TRIP T Pull out of the hole f/ 2189' to 315'. Rack back a stand of 5" drill collars to 225'. 13:00 13:45 0.75 225 200 COMPZ WELLPF OTHR T Redress upper anchor and pump out sub. 13:45 16:00 2.25 200 2,189 COMPZ WELLPF TRIP T Trip back in the hole f/ 200' to 2189'. Fill pipe w/ fresh water. top off every 3 stands. Calc displacement 30.7 bbls, actual 30 bbls. 16:00 17:00 1.00 2,189 2,218 COMPZ WELLPF BKOF T Pick up a single of 4" drill pipe, RIH to 2218'. Fill and mark pipe, putting middle of power section @ 2013'. Make a top drive connection. Pressure up to 500 psi on drill pipe, slack off and set lower anchor @ 2027'. Bleed off pressure, set down collar weight on anchor. Set upper anchor @ 2001', close annular, pressure up to 800 psi on annulus to recycle tool, Baker rep verified tool recycled, bleed off pressure, pump down drill pipe to 3500 psi and attempted to back off casing stub with no success. Bleed off and attempt again w/ 3500 psi. No success. Note: 3500 psi = 21 k ft lbs of torque. 17:00 17:30 0.50 2,218 2,218 COMPZ WELLPF CIRC T Drop ball and rod. Make a top drive connection. Pressure to 2300 psi to shear circ sub. Circulate out the water in drill string and discard to the rockwasher. 17:30 18:00 0.50 2,218 2,189 COMPZ WELLPF OTHR T Lay down a single and blow down the top drive. Page 16 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:45 0.75 2,189 315 COMPZ WELLPF TRIP T POOH w/ back off assembly f/ 2189' to 315'. 18:45 19:45 1.00 315 0 COMPZ WELLPF PULD T Rack back drill collars, then lay down BHA. Calculated fill 15.1 bbls, actual 15 bbls. 19:45 20:15 0.50 0 0 COMPZ WELLPF OTHR T Clear floor and blow down the kill line. 20:15 21:00 0.75 0 0 COMPZ WELLPF PULD T Pick up and break out the drive sub from washover assembly that was layed down earlier today. 21:00 22:30 1.50 0 224 COMPZ WELLPF PULD T Make up BHA to dress casing stub for 7" Bowen casing patch (8 -3/8" OD). 22:30 23:00 0.50 224 268 COMPZ WELLPF TRIP T Make up first stand of 4" drill pipe. Run in the hole and took weight. Pick up, then 5' in to determine depth of 264' w/ 5k, 268' w/ 10k weight. Make a top drive connection, break circulation, pumping 3 bpm w/ 50 psi. Rotate down to 259' w/ 1 k weight and 2k ft lbs of torque, ream to 264'. 23:00 00:00 1.00 268 224 COMPZ WELLPF TRIP T Pull out a stand, blow down the top drive. 10/21/2011 UD 7" dress off assembly, MU tandem 8 -1/2" string mill assembly, tag @ 258', work to 330', trip in to 1912', work down to 1999.48', PU, pump a sweep, POOH, UD tandem 8 -1/2" mills, MU 7" stub dressing assembly, RIH to 311'- tagged up, work some, POOH, UD dressing assembly, MU tandem 8 -1/2" string mills, RIH tag @ 255' work to 348', POOH, UD string mills, MU 7" stub dress assembly, RIH to 314', went through w/ 7k drag, con't RIH to top of stub @ 1993', dress stub f/ 1993' to 1997'. 00:00 00:15 0.25 224 0 COMPZ WELLPF PULD T Lay down dress off BHA. 00:15 00:30 0.25 0 0 COMPZ WELLPF OTHR T Clean floor. Bring tools to the floor f/ next BHA (Tandem 8 -1/2" string mills). 00:30 00:45 0.25 0 0 COMPZ WELLPF SFTY T Pre job safety meeting. 00:45 02:00 1.25 226 COMPZ WELLPF PULD T Pick up/ Make up tandem 8 -1/2" string mill assembly to 226'. 02:00 02:15 0.25 226 226 COMPZ WELLPF MILL T Make a top drive connection. Establish parameters. PU wt 42k, SO wt 44k, Rot wt 43k. Rotate 60 rpm w/ 1 -2k ft lbs (rotary limit set @ 8k ft lbs). Pumping 252 gpm w/ 100 psi. 02:15 04:15 2.00 226 315 COMPZ WELLPF MILL T Taking weight @ 258'. Start milling w/ dual 8 -1/2" string mill's. Rotate w/ above parameters. Work down and up. After working numerous times: taking 5k weight @ 255', then 10k @ 267', with 2k @ 275'. Slacked off to next place in hole being 315' before taking weight again. Page 17 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:45 1.50 315 330 COMPZ WELLPF MILL T Reamed down to 315' and took weight. Picked up a single and reamed through to 330'. Reamed between 310' and 330' taking 7K excess down weight. Weight did not reduce with reaming. Laid down single and blew down Top Drive. 05:45 06:45 1.00 330 1,912 COMPZ WELLPF TRIP T RIH on elevators to 1,912'. Took 2K to 3K @ 1900' cleaned up. 06:45 07:45 1.00 1,912 1,999 COMPZ WELLPF WASH T Made up Top Drive and broke circulation @ 6 BPM 200 psi. Observed Tapered Mill enter the casing stub @ 1,994'. Washed down to stub with 8.5" mill @ 1,999.48'. Pumped and circulated out Flozan /Supersweep pill @ 10 BPM 450 psi 40 RPM While working pipe. 07:45 09:15 1.50 1,999 0 COMPZ WELLPFTRIP T Monitored well. POOH with Tandem Mill BHA. Noted 5K drag from 270' to 260'. 09:15 09:45 0.50 0 0 COMPZ WELLPF PULD T Laid down tools. 09:45 11:15 1.50 0 0 COMPZ WELLPF PULD T PJSM. Picked up 7" Dress Off BHA. 11:15 11:45 0.50 0 311 COMPZ WELLPFTRIP T RIH with 7" Dress Off BHA to 311'. Took 5K from 256' to 267'. Took 7K @ 311'. 11:45 12:00 0.25 311 0 COMPZ WELLPFTRIP T POOH to change BHA. 12:00 14:00 2.00 0 226 COMPZ WELLPF PULD T Laid down 7" Dress Off BHA and Made up Tandem Mill BHA. 14:00 14:15 0.25 226 255 COMPZ WELLPFTRIP T Make a top drive connection. RIH, tight spot @ 255'. Pumping 6 bpm w/ 110 psi, rotate 60 rpm w/ 1 k ft Ibs of torque. PU wt 40k, SO wt 43k, Rot wt 43k. 14:15 15:00 0.75 255 280 COMPZ WELLPF MILL T Ream w/ dual tandem 8 -1/2" mills f/ 255' to 280'. Rotate 60 rpm w/ 2-4k ft Ibs of torque. Weight on mills 1 k. Pumping 6 bpm w/ 110 psi. Made three attempts to slide through after reaming- Set down 10k @ 268'. Continue to ream w/ 80 rpm 2 -3k ft Ibs of torque. Slack off w/ 7k drag @ 266'. Ream f/ 260' to 275' w/ 1 -2k ft Ibs of torque. 15:00 15:30 0.50 280 318 COMPZ WELLPF TRIP T Slack off f/ 260' to 270' w/ 4k drag. Continue to RIH f/ 270' to 320' w/ 1 -2k drag @ 318'. 15:30 15:45 0.25 318 320 COMPZ WELLPFTRIP T Pick up/ Make up a single of 4" drill pipe. RIH f/ 318' to 348' with no problems. Pick up to 256' w/ 4k overpull @ 273' -266'. RIH f/ 666' to 348' w/ 1 -2k drag. Drag @ 318' -320' was 1 -2k. Lay down a single. 15:45 16:30 0.75 320 320 COMPZ WELLPF MILL T Mill f/ 255' to 275', same parameters w/ 1 -2k ft Ibs of torque. Page 18 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:00 0.50 320 320 COMPZ WELLPF TRIP T Slack off w/ 3k drag f/ 264' -266', 1 -2k drag f/ 318' -320'. Ream again to 406'. Pick up to 320' with no overpull. 17:00 17:30 0.50 320 226 COMPZ WELLPF TRIP T Blow down the top drive. Stand back a stand of 4" drill pipe to 226'. 17:30 18:00 0.50 226 39 COMPZ WELLPF TRIP T Stand back 2 stands of 4 -3/4" drill collars to 39'. 18:00 19:00 1.00 39 0 COMPZ WELLPF PULD T Lay down BHA f/ 39'. 19:00 19:15 0.25 0 0 COMPZ WELLPF SFTY T Pre job safety meeting on picking up wash over milling assembly (Dress 7" stub). 19:15 20:15 1.00 0 236 COMPZ WELLPF PULD T Pick up/ Make up wash over BHA to 236'. 20:15 20:30 0.25 236 329 COMPZ WELLPFTRIP T Make a top drive connection, slack off while measuring w/ 5' stick, tag w/ 5k @ 313'. Pick up and slack off with more weight- fell through, run stand #1 in the hole to 329'. 20:30 21:45 1.25 329 1,993 COMPZ WELLPF TRIP T Trip in the hole f/ 329' to tag top of 7" cut off @ 1993'. 21:45 22:00 0.25 1,993 1,993 COMPZ WELLPF MILL T Pick up 10' to 1983', establish parameters: PU wt 63k, SO wt 67k, Rot wt 63, Rot w/ 60 rpm w/ 1k ft lbs of torque. Pumping 6 bpm w/ 220 psi. 22:00 00:00 2.00 1,993 1,997 COMPZ WELLPF MILL T Mill over casing stub top @ 1993' to 1997'. Rotate w/ 2k ft Ibs. Weight on mills 3 -5k then 5 -7k. 10/22/2011 finish milling over casing stub to 1998', cic, test 9 -5/8" casing -no test, POOH UD assembly, change rams to 7 ", test rams, RU /Run 7" casing to 397.69', POOH UD casing, RD casing tools, fish piece of thin iron f/ top of blind rams, set test plug, change rams tO 2 -7/8" x 5" variables, test rams, set wear bushing, RIH w/ 8- 3/16" lead impression block to 1334' @ midnight. No indications of setting on anything to this depth. 00:00 00:45 0.75 1,997 1,998 COMPZ WELLPF MILL T Mill over casing stub top @ 1997' to 1998'. Rotate w/ 2k ft lbs. Weight on mills 3 -5k then 5 -7k. 6 BPM 225 psi 60 RPM 1 -2K Torque. Picked up and rotated on stub. Went over stub without rotary no problem either way. 00:45 01:15 0.50 1,998 1,988 COMPZ WELLPFCIRC T Picked up 10' and Circulated around Super Sweep / Flozan pill. 10 BPM 300 psi 60 RPM. 01:15 02:15 1.00 1,988 1,898 COMPZ WELLPF PRTS T Stood back 1 stand and blew down Top Drive. Rigged up and tested 9 5/8" casing. Pumped in with 134 psi @ 7 SPM. Bled back to 25 psi in 1 min. Total pumped 4.25 Bbls. Rigged down Test Equipment. 02:15 03:00 0.75 1,898 280 COMPZ WELLPFTRIP T POOH to 7" Dress off BHA. 03:00 04:30 1.50 280 0 COMPZ WELLPF PULD T Stood back DC's and laid down Tools. 04:30 05:30 1.00 0 0 COMPZ WELLPF PULD T Cleared fishing tools from Rig Floor and made up Stack washer. Washed out stack. 05:30 06:00 0.50 0 0 COMPZ WELLPF PULD T Pulled wear ring and set test plug. Page 19 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 COMPZ WELLPF SEQP T PJSM. Changed VBR to 7" casing rams and tested 250/3000. 08:00 09:30 1.50 0 0 COMPZ WELLPF RURD T Rigged up to run 7" casing. 09:30 09:45 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on running 7" 26 ppf L -80 TC-Il casing. 09:45 13:00 3.25 0 397 COMPZ RPCOM RNCS P Make up 7" casing: Remove collars f/ BTC connections, clean, then baker lock BTC connections. Make up Bowen 7" casing patch, 1 jt of 7" BTC casing, HES Type "H" cementer, 7" BTC pup joint, crossover joint, 7" TC-Il pup joint, then tagged a tight spot @ 314.31' (20.40' in on joint # 6 TC -II). Worked pipe. Set down 7k- no go. Turned pipe, pushed w/ 10k. PU wt 39k, SO wt 40k. Continued to run casing. Tagged up @ 397.69' (22.4' in on jt #8). Worked pipe three times- no go. Attempted to push w/ 18k- no go. Turned pipe- attempted again- no go. Note: Ran Weatherford ridgid Full Body staight blade centralizers PN 1130279 (8.25" OD, actual 8- 3/16" to 8 -1/8" OD) slipped over TC -II joints. The first centralizer would have been below collar of jt # 1. Collar top was @ 261.60'+ length of collar .88 + length of centralizer .90 = 263.38' was the bottom of centralizer. Centralzier showed marks on two of the six ribs. 13:00 13:15 0.25 397 397 COMPZ RPCOM OTHR T Decision made to lay down 7" casing f/ 397.69'. 13:15 14:00 0.75 397 92 COMPZ RPCOM PULD T Pull out of hole laying down 7" casing f/ 397' to 92'. Note: layed down 8 jts of TC -II casing and 4.79' TC -II pup joint. 14:00 14:15 0.25 92 0 COMPZ RPCOM TRIP T Stand back 91.98' of 7" casing in the derrick. Left together- did not need to break baker lock connections. Note: No noticeable signs on casing collars, centralizers, or jewelry items. 14:15 14:30 0.25 0 0 COMPZ WELLPF RURD T Rig down casing equipment. 14:30 14:45 0.25 0 0 COMPZ WELLPF OTHR T Drain stack to set test plug. Noticed a piece of iron in blind ram cavity. Notified company man and Baker rep. 14:45 17:00 2.25 0 0 COMPZ WELLPF OTHR T Clean and clear floor. Called Baker shop f/ a magnet to fish the piece of iron at the blind rams. 17:00 17:30 0.50 0 0 COMPZ WELLPF PULD T Pick up magnet. MU 8" magnet, bit sub, x -o and 1 joint of 4" drill pipe. 17:30 17:45 0.25 0 17 COMPZ WELLPF FISH T Retrieved a 6" x 8" piece of scale /thin iron from blind ram cavity. POOH, lay down magnet. Page 20 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 18:00 0.25 0 0 COMPZ WHDBO OTHR T Set test test plug 18:00 18:15 0.25 0 0 COMPZ WHDBO SFTY T Pre job safety meeting. 18:15 19:00 0.75 0 0 COMPZ WHDBOOTHR T Change out 7" solid body rams to 2 -7/8" x 5" variables. 19:00 19:30 0.50 0 0 COMPZ WHDBO BOPE T Test lower pipe rams to 250 psi low and 3000 psi f/ 5 minutes each. Chart test. 19:30 19:45 0.25 0 0 COMPZ WHDBO RURD T Rig down test equipment. 19:45 20:00 0.25 0 0 COMPZ WHDBO OTHR T Set the FMC 9" ID wear bushing. 20:00 20:30 0.50 0 0 COMPZ WELLPF PULD T Pick up tools from Beaver slide. 20:30 20:45 0.25 0 COMPZ WELLPF SFTY T Pre job safety meeting. 20:45 21:15 0.50 0 210 COMPZ WELLPF PULD T Make up 8- 3/16" impression block BHA to 210'. 21:15 00:00 2.75 210 1,334 COMPZ WELLPF TRIP T Trip in the hole w/ 8- 3/16" lead impression block. to 1334' @ midnight. Did not notice anything to this depth. 10/23/2011 Con't RIH w/ 8- 3/16" lead impression block to 1994', POOH, UD BHA, MU BHA to mill 9 -5/8" casing clean (Triple 8 -1/2" string mills), RIH to 234', cleanup casing to 325', trip in to 1984', circ, POOH, UD BHA, PU /MU dress 7" casing stub BHA, RIH, dress the 7" top @ 1994' to 1995'. Circ sweep, POOH to 35'. Clean magnet. 00:00 00:30 0.50 1,334 1,994 COMPZ WELLPF TRIP T Trip in the hole w/ 8- 3/16" lead impression block from 1334' to 1994'. Tag stump w/ 3k weight. 00:30 01:30 1.00 1,994 0 COMPZ WELLPF TRIP T Pull out of the hole w/ 8- 3/16" lead impression block from 1994'. and laid down tools. 01:30 03:00 1.50 0 239 COMPZ WELLPF PULD T Picked up and made up Milling BHA (Triple 8 -1/2" string mills). 03:00 07:00 4.00 239 325 COMPZ WELLPF MILL T Made connection and established paramaters. Up wt 40K SO wt 45K 60 RPM 110 psi @ 6 BPM. RTq 1K Washed down to 258' . Worked mills in casing from 258' to 325' multible passes. Could not go down with out rotating. Worked Mills back to 313' then back to 325'. Blew down Top Drive. 07:00 08:30 1.50 325 1,984 COMPZ WELLPF TRIP T RIH on Elevators from 325' to 1984'. Calc displacement 13.4 bbls, actual 12.75 bbls. 08:30 09:00 0.50 1,984 1,994 COMPZ WELLPF CIRC T Make a top drive connection. Break circulation. Pump a hi -vis sweep. Pumping 10 bpm w/ 425 psi. Rotate 60 rpm w/ 1 k ft Ibs of torque. Reciprocate pipe. PU wt 63k, SO wt 67k. 09:00 09:15 0.25 1,994 1,921 COMPZ WELLPF OTHR T Stand back a stand. Blow down the top drive. 09:15 09:45 0.50 1,921 515 COMPZ WELLPF TRIP T Pull out of the hole w/ triple 8 -1/2" OD string mills. Calculated fill 7.8 bbls, actual 9.25 bbls. Page 21 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:15 0.50 515 234 COMPZ WELLPF REAM T Make a top drive connection @ 515'. Back ream f/ 515' to 234'. Observed 2 -4k ft lbs of torque @ 314' and @ 265' 2k overpull. 10:15 10:30 0.25 234 234 COMPZ WELLPF OTHR T Blow down the top drive. Change elevators. 10:30 11:00 0.50 234 27 COMPZ WELLPF TRIP T Work BHA. Rack back 2 stands of 4 -3/4" drill collars, Lay down milling assembly. 11:00 11:15 0.25 27 0 COMPZ WELLPF PULD T Lay down milling assembly. 11:15 12:00 0.75 0 0 COMPZ WELLPF OTHR T Clear floor of string mills. PU BHA componets to the floor for the next run. Next run will be a magnet run to top of stub @ 1994'. 12:00 12:15 0.25 0 0 COMPZ RPEQP1SFTY T PJSM 12:15 13:00 0.75 0 1,994 COMPZ WELLPF TRIP T RIH w/ 8" magnet. Tagged up @ 1994'. Set down 7k. PU wt 56k, SO wt 60k. 13:00 14:45 1.75 1,994 COMPZ WELLPF TRIP T Pull out of the hole w/ 8" magnet f/ 1994'. 14:45 15:00 0.25 0 0 COMPZ WELLPF PULD T Lay down magnet. Retrieved 1/2 gallon of fine metal shavings. Calculated fill 11.34 bbls, actual 14.25 bbls. 15:00 15:15 0.25 0 0 COMPZ WELLPF SFTY T PJSM 15:15 16:30 1.25 0 0 COMPZ WELLPF PULD T Pick up tools f/ beaver slide f/ BHA to dress off 7" casing stub. 16:30 17:30 1.00 0 0 COMPZ WELLPF OTHR T Change out shoe and mill extension (bushing). Bring tools to the floor. 17:30 18:45 1.25 0 236 COMPZ WELLPF PULD T Continue to pick up/ make up BHA. 18:45 20:00 1.25 236 425 COMPZ WELLPF REAM T Make up top drive to 1st stand of 4" drill pipe. Five foot measure in. Observe 2 -3k drag starting @ 260'. Continued to have 2 -3k drag until reaching 314'. At 314' drag was 4 -5k for 4', then all was good. 20:00 20:15 0.25 425 1,994 COMPZ WELLPF TRIP T Run in the hole w/ dress off assembly f/ 425' to 1994' (top of stub). Calculated displacement 13.92 bbls, actual 12.5 bbls. 20:15 20:30 0.25 1,994 1,994 COMPZ WELLPF TRIP T Tagged up @ 1994'. Picked up 6'. PU wt 62k, SO wt 65k, Rot wt 63k. Rotate @ 60 rpm w/ 900 ft lbs of torque. Pump 6 bpm w/ 210 psi. 20:30 21:15 0.75 1,994 1,998 COMPZ WELLPF MILL T Slack off, go over 7" stub (top @ 1994'). Saw 1 -2k torque. After slacking off 2', torque increased to 3 -4k. Once on stub, apply 5 -7k weight and milled to 1995'. 21:15 21:45 0.50 1,998 1,998 COMPZ WELLPF CIRC T Pumped 27.2 bbl hi vis super sweep pill. Pumping 10 bpm w/ 500 psi. Observed mostly fiber from sweep and small amount of fine metal shavings. Page 22 of 41 Time Logs 9 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:00 0.25 1,998 1,902 COMPZ WELLPF OTHR T Stand back a stand. Blow down the top drive. 22:00 22:45 0.75 1,902 236 COMPZ WELLPFTRIP T Trip out w/ dressing mill f/ 1902' to 236'. 22:45 23:15 0.50 236 49 COMPZ WELLPFTRIP T Change elevators to 3 -1/2 ". Stand back two astands of 4 -3/4" drill collars. 23:15 23:30 0.25 49 35 COMPZ WELLPF TRIP T Pull magnet to floor and clean off. Pictures on the "S" drive. 23:30 00:00 0.50 35 35 COMPZ WELLPFTRIP T Pick up single f/ pipe shed, RIH w/ magnet to try and retrieve any metal f/ stack. Recovered a little bit of shavings. 10/24/2011 Finish UD 7" stub dressing assembly, change bottom pipe rams to 7 ", test same, RU /Run 7" 26 ppf L -80 TC -II casing to 1994', attempt to engage stump of 7" (top @ 1994 - 1995') w/ Bowan patch- unable, POOH UD 7" casing, change bottom rams to 2 -7/8" x 5 ", clean out all ram cavities, RU/Test BOPE. Witness of test waived by AOGCC rep Bob Noble. 00:00 00:15 0.25 35 35 COMPZ WELLPF SFTY T Pre job safety meeting. Lay down the 7" dress off BHA. 00:15 00:45 0.50 35 0 COMPZ WELLPF PULD T Lay down the 7" dress off BHA. 00:45 01:45 1.00 0 0 COMPZ WELLPF PULD T Clear floor of all Baker tools. 01:45 02:00 0.25 0 0 COMPZ WELLPF SFTY T Pre job safety meeting. 02:00 02:45 0.75 0 0 COMPZ WHDBO OTHR T Pull FMC 9" ID wear bushing. Set test plug. Change out lower pipe rams f/ 2 -7/8" x 5" variables to 7" casing rams. Rigging up to test. 02:45 05:30 2.75 0 0 COMPZ WHDBO BOPE T Test 7" rams to 250 psi low and 3000 psi high. Could not get a test. Open doors, inspect rams and cavities, clean out metal shavings. Pull test plug. Change seal ring on test plug. Set test plug. Fill hole w/ water, work out the air. Test. Charted tests. Held each test 5 minutes. 05:30 05:45 0.25 0 0 COMPZ WHDBO RURD T Rig down testing equipment. 05:45 07:00 1.25 0 0 COMPZ RPCOM RURD T Rig up casing equipment. 07:00 09:45 2.75 0 1,998 COMPZ RPCOM RNCS P Ran Patch assembelly from derrick followed by 48 Jts of 7" Casing 26# L -80 TC -II connection. 09:45 11:00 1.25 1,998 1,998 COMPZ RPCOM RNCS P Obtain parameters: PU wt 76k, SO wt 74k. Ty to engage 7" stub top @ 1994' per Baker rep.- no go. Pick up 10', start pumps @ 4 bpm w/ 100 psi. Set down 20k on stub, no change in pump pressure. Decision made to POOH w/ 7" casing. 11:00 12:00 1.00 1,994 1,759 COMPZ RPCOM PULL T Pull out of the hole w/ 7" 26 ppf L -80 TC -II casing g/ 1994' to 1759'. 12:00 12:15 0.25 1,759 1,759 COMPZ RPCOM SFTY T Continue to pull out and lay down 7" casing. 12:15 14:00 1.75 1,759 97 COMPZ RPCOM PULL T Continue to pull out and lay down 7" casing. Page 23 of 41 1 Time Logs j Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:15 0.25 97 0 COMPZ RPCOM PULL T Continue POOH Baker locked equipment f/ 97'. Attempt to break off the Bowan casing patch -no go (applied steam to attempt to break baker locked connection). Racked back in the derrick. Note: What's in the derrick: 7" Bowan casing patch, joint of BTC casing bakerlocked, HES cementer baker locked, BTC pup joint, w/ baker locked pin, x -o joint w/ TC -II Box x BTC pin, TC -II pup joint= 96.77'. 14:15 14:45 0.50 0 0 COMPZ WELLPF RURD T Rig down casing equipment. 14:45 15:30 0.75 0 0 COMPZ WHDBO CIRC T Pick up a single of drill pipe. Make up stack washing tool. Flush stack pumping 600 gpm w/ 60 psi. 15:30 16:00 0.50 0 0 COMPZ WHDBO OTHR T Drain stack, set test plug. 16:00 16:15 0.25 0 0 COMPZ WHDBO OTHR T Pre job safety meeting on changing rams from 7" to 2 -7/8" x 5 ". 16:15 16:45 0.50 0 0 COMPZ WHDBO OTHR T Open all doors of bottom pipe rams, clean out cavity. Change bottom pipe rams f/ 7" to 2 -7/8" x 5" variables. Sim Ops: Rigging up to test BOPE. 16:45 19:45 3.00 0 0 COMPZ WHDBOOTHR T Open doors on blinds and top rams. Clean out cavities. 19:45 20:00 0.25 0 0 COMPZ WHDBO SFTY P Pre job safety meeting on testing BOPE 20:00 20:15 0.25 0 0 COMPZ WHDBO RURD P Finish rigging up to test BOPE. Fill stack w/ water, work air out of system. 20:15 00:00 3.75 0 0 COMPZ WHDBO BOPE P Weekly BOPE test with 4" test joint. Witness of test waived by AOGCC rep Bob Noble. Test to 250 psi low and 3000 psi high, hold each test f/ 5 minutes. Charted tests. Test top pipe, annular, kill and choke valves, mud line valve, floor safety valves, all valves in the choke manifold. 10/25/2011 Finish Test of BOPE. Witness of test waived by AOGCC rep Bob Noble. MU Baker washover BHA, washover the 7" stub @ 1995', washed to 2013.4', circ, POOH, UD BHA, MU Baker back off BHA, RIH f/ 318' to 2220'. Note: With tapered mill @ 2220' -- Middle of upper anchor @ 2005', lower anchor @ 2028'. PU wt 67k, SO wt 70k. Collar of 7" @ 2013.4', top of stub @ 1995'. Note: Tool worked as planned. Broke connection initially w/ 1550 psi =9300 ft lbs of torque. 00:00 00:15 0.25 0 0 COMPZ WHDBO SFTY P Pre job safety meeting 00:15 01:00 0.75 0 0 COMPZ WHDBO BOPE P Continue testing BOPE: Test lower rams 2 -7/8" x 5" VBR, perform Koomey test (51 seconds) (3 min 48 seconds), test blind rams. All tests charted 250 psi low and 3000 psi high. Witness of test waived by AOGCC insp Bob Noble. 01:00 02:00 1.00 0 0 COMPZ WHDBO RURD P Rig down testing equipment. Pull test plug, install FMC 9" ID wear ring. Blow down lines. Page 24 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:30 2.50 0 0 COMPZ WELLPF OTHR P Inspect saver sub, change out saver sub. 04:30 06:45 2.25 0 0 COMPZ WHDBO BOPE P Test upper and lower IBOP on the top drive. Re test accumulator: Initial 3000 psi, pressure after closing 1900 psi. 200 psi build up in 35 seconds, full charge attained in 170 seconds (2 min 50 seconds). 5 bottles of nitrogen BU average 2050 psi. Tested gas alarms. 06:45 07:00 0.25 0 0 COMPZ WELLPF PULD T Pick up 7" tools from beaver slide. Change elevators to 7 ". 07:00 07:15 0.25 0 0 COMPZ WELLPF SFTY T Pre job safety meeting 07:15 08:00 0.75 0 0 COMPZ WELLPF PULD T Rig up power tongs. Latch onto stand of 7" casing from the derrick.With blinds closed, hot work permit issued, rig welder heated up connection to break the bakerlock. Remove Bpwan patch f/ stand. Rack back stand in the derrick. 08:00 09:00 1.00 0 0 COMPZ WELLPF PULD T Rig down, then lay down 7" casing tongs. Remove centralizers from the floor. clear floor of bad saver sub. Lay down Baker tools. Pick up Baker tools for the next BHA (Wash over sub). 09:00 09:15 0.25 0 0 COMPZ WELLPF SFTY T Pre job safety meeting. 09:15 11:15 2.00 0 240 COMPZ WELLPF PULD T Make up washover assembly per Baker rep to 240'. 11:15 12:00 0.75 240 268 COMPZ WELLPF TRIP T Trip in w/ washover assembly f/ 240' to 268'. Set down 10k. Make a top drive connection. Rotate 20 rpm w/ 2 -3k ft Ibs of torque. Pumping 3 bpm w/ 50 psi. 12:00 12:15 0.25 268 333 COMPZ WELLPF REAM T Work past 268' to 333'. Blow down the top drive. PU wt 40k, SO wt 43k. Rotate 15 rpm w/ 1k ft Ibs of torque. Worked through w/ 2-4k ft Ibs of torque. Pumping 3 bpm w/ 50 psi. 12:15 12:45 0.50 333 1,926 COMPZ WELLPF TRIP T Continue trip in the hole w/ washover BHA f/ 333' to 1926'. 12:45 13:00 0.25 1,926 1,926 COMPZ WELLPFCIRC T Pump 6 bpm w/ 175 psi. Rotate 60 rpm w/ 1 k ft Ibs of torque. PU wt 63k, SO wt 65k. 13:00 14:00 1.00 1,926 2,008 COMPZ WELLPF WASH T Slack off to 1995' (top of 7" stub) and tag twice. . Pick up rotate 15 rpm get over stub. Shut down, then slack off to tag @ 1998' (Furthest previous dress over mill had cleaned down to). Wash over 7" casing, milling cement f/ 1998' to 2008'. Pumping 6 bpm w/ 250 psi, 60 rpm w/ 2 -4k ft Ibs of torque. WOB 7 -9k. Slocwed down @ 2008', torque dropped off to 1.5k ft lbs. 14:00 14:15 0.25 2,008 2,008 COMPZ WELLPFCIRC T Circulate with out rotation. Recip f/ 2007' to 1996'. Page 25 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 14:45 0.50 2,008 2,013 COMPZ WELLPF MILL T Continue to clean cement from around 7" f/ 2008' to 2013.4'. Saw a pressure increase and stacked weight on collar © 20013.14'. Work to 2013.4' twice. 14:45 15:15 0.50 2,013 1,990 COMPZ WELLPF CIRC T Circulate 10 bpm w/ 500 psi, Rotate and reciprocate to 2013.4' twice. Pick up over stub @ 1995. 15:15 16:30 1.25 1,990 240 COMPZ WELLPF TRIP T Blow down the top drive. Trip out of the hole w/ washover BHA f/ 1990'. Saw 7k overpull @ 268'. Continued to POOH w/ BHA to 240'. 16:30 16:45 0.25 240 0 COMPZ WELLPF PULD T Lay down washover BHA. 16:45 17:30 0.75 0 0 COMPZ WELLPF OTHR T Clear and clean rig floor. 17:30 18:00 0.50 0 0 COMPZ WELLPF PULD T Pick up handling tools from the beaver slide. 18:00 18:30 0.50 0 0 COMPZ WELLPF RURD T Rig up cellar cement line to take returns to the outside tank. 18:30 18:45 0.25 0 0 COMPZ WELLPF SFTY T Pre job safety meeting on making up BHA to back off 7" casing stub. 18:45 20:15 1.50 0 318 COMPZ WELLPF PULD T Pick up/ Make up Back off BHA to 318'. 20:15 20:30 0.25 318 596 COMPZ WELLPF TRIP T Run in the hole to 596'. 20:30 21:15 0.75 596 596 COMPZ WELLPF TRIP T Fill pipe w/ diesel. (191' to 596' = 405', '4 bbls 21:15 22:45 1.50 596 1,995 COMPZ WELLPF TRIP T Continue trip in the hole w/ 4" drill pipe, filling every 3rd stand w/ fresh water. Run in the hole f/ 596' to 1995'. 22:45 23:00 0.25 1,995 2,001 COMPZ WELLPF TRIP T Slack off entering stub top w/ tapered mill (10' up on stand 18). PU wt 63k, SO wt 67k. Pick up a single run in the hole 28' to 2220'. Fill every 3rd stand w/ fresh water. 23:00 23:15 0.25 2,001 2,220 COMPZ WELLPF TRIP T Continue trip in the hole f/ 2001' to 2192'. Pick up a single run in the hole 28' to 2220'. Note: With tapered mill @ 2220'- - Middle of upper anchor © 2005', lower anchor @ 2028'. PU wt 67k, SO wt 70k. Collar of 7" @ 2013.4', top of stub @ 1995'. 23:15 23:45 0.50 2,220 2,220 COMPZ WELLPF RURD T Fill pipe w/ fresh water. Rig up to pump w/ 2" cement hose. 23:45 00:00 0.25 2,220 2,220 COMPZ WELLPF BKOF T Pressure up to shear lower anchor, indications @ 200 psi. Slack off to 50k, PU to 65k. Pressure up to 1550 psi (9300 ft Ibs of torque at tool). Indications of string turning counterclockwise at surface, 1/4 turn. Slack off to 50k, set in slips. Turned some more counter - clockwise when set in the slips. Let tool cycle. Page 26 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/26/2011 24 hr Summary 7" casing connection initially broke w/ 1550 psi = 9300 ft Ibs of torque. Continue to cycle, back off 4 turns, open circ sub, "U" tube diesel and water f/ DP, rev circ string volume, POOH, UD 5" DC's, UD back off BHA, H f/ 221' to 1907' engage fish. Finish back off of 7" casing stub, POOH. UD BHA & fish. PU spear BHA, RI g Change lower pipe rams to 7 ", test, RU /Run 7" casing, screw into collar @ 2013', torque to 10k, PJSM, PT to 2500 psi f/ 10 min -good. Pull in tension to 125k on wt indicator (50k over). Press up to 2500 psi -good, increase to open cementer w/ 3300 psi, circ 100 bbls seawater, Dowell pump 5 bbls water, PT to 3500 psi, pump cement job. 00:00 00:45 0.75 2,220 2,220 COMPZ WELLPF BKOF T Cycle Baker Back off tool: pressure to 800 psi (1/2 turn) bleed off pressure, pressure to 800 (1/2 turn) bleed off press, 650 (1/2 turn) bleed off press, 650 (1/4 turn)bleed off press, 550 (1/4 turn) bleed off pressure, 550 (1/2 turn) bleed off pressure, 650 (1/4 turn) bleed off press, 500 (1/4) turn bleed off press, 550 (1/4 turn) bleed off press, 700 (1/8 turn) bleed off press, 500 (1/8 turn) bleed off press, 600 (1/8 turn) bleed off press. Note: It does not matter if the above turns add up to 4. A total of 4 turns at surface were observed. 00:45 01:00 0.25 2,220 2,220 COMPZ WELLPF RURD T Break off headpin, Drop 1.88" OD ball and rod to open circ sub. Re- connect headpin and 2" hose. 01:00 01:30 0.50 2,220 2,220 COMPZ WELLPF CIRC T Pressure up to 2200 psi to open circ sub. Open bleeder on drill pipe, allow to "U" tube. Use trip tank to fill hole w/ seawater. 01:30 01:45 0.25 2,220 2,220 COMPZ WELLPF CIRC T Reverse circ 22 bbls of seawater, taking returns f/ drill pipe to rockwasher. Pumping 26 2.2 bpm w/ 50 psi. 01:45 02:00 0.25 2,220 2,220 COMPZ WELLPF CIRC T Pump down drill pipe to get any diesel f/ annulus out of the hole. 02:00 04:00 2.00 2,220 0 COMPZ WELLPF TRIP T Pull out of the hole w/ Baker Back -off BHA. Lay down 5" drill collars on way out of the hole. Rack back 4 -3/4" collars. 04:00 04:15 0.25 0 0 COMPZ WELLPF RURD T Connect hydraulic hoses back up to the rotary table. 04:15 04:30 0.25 0 0 COMPZ WELLPF PULD T Pick up jars f/ pipe shed, lay down 6 -3/8 " jars. 04:30 05:00 0.50 0 0 COMPZ WELLPF OTHR T Clean and clear rig floor. Pick up tools to the floor. 05:00 06:30 1.50 0 221 COMPZ WELLPF PULD T Pick up / MU spear BHA to 221'. 06:30 07:15 0.75 221 1,938 COMPZ WELLPF TRIP T Run in the hole w/ spear assembly f/ 221' to 1938'. Calc displacement 15.3 bbls, actual 12.5 bbls. 07:15 07:30 0.25 1,938 1,938 COMPZ WELLPF OPNW T Make a top drive connection. Obtain parameters: PU wt 62k, SO wt 65k. Circulate 9 bpm w/ 400 psi. 07:30 08:00 0.50 1,938 1,938 COMPZ WELLPF CIRC T Make a top drive connection. Pump 30 bbl Flozan pill @ 10 bpm w/ 400 psi. Page 27 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:15 0.25 1,938 2,005 COMPZ WELLPF FISH T Slack off and spear 7" casing stub (Top @ 1995'). Slack off to 2005'. PU wt 62k, SO wt 65k. Set down 4k on spear stop. ring @ 1995'. Pick up 8k. Turn 6 left hand turns while holding 5 -8k upwt. Observed 7" stub free up. PU wt 64k. 08:15 09:15 1.00 2,005 221 COMPZ WELLPF TRIP T Trip out of the hole w/ 7" casing stub & spear assembly f/ 2005' to 1938'. Lay down a single. Blow down the top drive. Continue to pull out of the hole f/ 1938' to 221'. Calculated fill 15.3 bbls, actual 14 bbls. 09:15 10:00 0.75 221 0 COMPZ WELLPF PULD T Rack back 2 stands of 4 -3/4" drill collars. Lay down BHA, jars and 7" stub 18.43' threads off. Threads looked good. Top of joint was sliced on one side for 3'. 10:00 10:30 0.50 0 0 COMPZ WELLPFOTHR T Clean and clear rig floor. 10:30 10:45 0.25 0 0 COMPZ WHDBO SFTY T Pre job safety meeting on changing bottom pipe rams f/ 2 -7/8" x 5" VBR's to 7" solid body. 10:45 12:15 1.50 0 0 COMPZ WHDBO BOPE T Drain stack, Pull FMC 9" ID wear bushing. Set test plug. Change rams. Sim Ops: rigging up to test. 12:15 12:30 0.25 0 0 COMPZ WHDBO SFTY T Pre job safety meeting. 12:30 13:00 0.50 0 0 COMPZ WHDBO BOPE T Test 7" casing rams to 250 psi low and 3000 psi high. Chart test. Hold each test f/ 5 minutes. 13:00 13:15 0.25 0 0 COMPZ WELLPF RURD T Rig down testing equipment. 13:15 14:00 0.75 0 0 COMPZ WELLPF RURD T Rig up casing running equipment. 14:00 14:15 0.25 0 0 COMPZ RPCOM SFTY T Pre job safety meeting. 14:15 15:15 1.00 0 0 COMPZ RPCOM RNCS T Run 7" 26 ppf L -80 TC -II casing. Pick up a 7" BTC 9.77' long pup joint. Remove collar, clean and baker lock collar to joint. Pick up stand of 7" in the derrick. Baker lock pup to bottom of a joint of BTC below the HES cementer. Run stand of 7" 26 ppf L -80 casing the hole. Add a TC -II pup, 9.69' long above the 4.79' TC -II pup at the top of the stand. 15:15 18:30 3.25 0 2,013 COMPZ RPCOM RNCS T Run 48 joints of 7" 26 ppf L -80 TC -II casing to 2013'. Torque turn. Torque to 10,100 ft Ibs of torque. Used Run -N -Seal jet lube dope. Ran a total of 4 solid 8 -1/4" centralizers on jts # 44, 45, 46 and 47. 18:30 19:15 0.75 2,013 2,013 COMPZ RPCOM RURD T Tighten up floor safety valve and crossover to 7" BTC. Install into the crossover already in the top of last joint. Torque to 10k ft Ibs. PU wt 75k, SO wt 75k @ 2013'. Page 28 of 41 Time Logs 9 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 19:30 0.25 2,013 2,013 COMPZ RPCOM RNCS P While circulating @ 2 bpm w/ 50 psi, slack off to collar in the hole. Top of collar @ 2013'. Rotate to the right w/ the top drive 8 rounds w/ 3 rpm's. No torque increase. Pick up, then rotate while slacking off w/ 7 rpm. Saw a bobble, indicating we are in the collar. Put 6 turns into pipe and saw a torque increase. Worked 10k ft Ibs of torque into the pipe. Worked pipe three times w/ 5k overpull. Set down 5k. Pipe quit turning. Let torque out at surface. Picked up 20k over, set down to neutral weight of 75k. Pressure tested casing to 1000 psi f/ 5 minutes- good test ( did not chart test). 19:30 20:30 1.00 2,013 2,013 COMPZ RPCOM RURD P Rig down top drive crossovers, change bales to the long casing running bales. 20:30 21:15 0.75 2,013 2,013 COMPZ CEMEN" RURD P Rig up Dowell crossover, load cement head w/ closing plug, attatch cement head 2" lines. Line up in the cellar to take returns f/ annulus valve to vacum truck for cement returns. 21:15 21:45 0.50 2,013 2,013 COMPZ CEMEN" SFTY P Pre job safety meeting on cementing 7" casing. 21:45 22:00 0.25 2,013 2,013 COMPZ CEMEN" PRTS P Put string in tension, pull up to 125k on weight indicator (50k over). Pressure test lines to the cement head to 3500 psi- good. Line up, then presure test casing to 2500 psi f/ 10 minutes- good test (charted). 22:00 22:15 0.25 2,013 2,013 COMPZ CEMEN" OTHR P Line up, then increase pressure to open HES cementer. Opened w/ 3300 psi. 22:15 22:45 0.50 2,013 2,013 COMPZ CEMEN" CIRC P Rig pumped 100 bbls of 90 deg seawater. Pumped @ 6 bpm w/ 250 psi, slowed to 5 bpm w/ 175 psi. Confirmed 100 bbls returns to the pits prior to shutdown. 22:45 23:00 0.25 2,013 2,013 COMPZ CEMEN" PRTS P Line up for Dowell to pump. Dowell pump 5 bbls of water @ 5.1 bpm w/ 360 psi. Shut down. Shut valves on cement head. Pressure test to 3500 psi.. 23:00 23:30 0.50 2,013 2,013 COMPZ CEMEN" PUCM P Dowell batch up 15.7 ppg AS1 cement. Dowell pump 15 bbls of AS1 15.7 ppg neat cement @ 3.2 to 4.7 bpm w/ 320 to 820 psi, Dowell then added CemNet @ 1.5 ppb into 65 bbls of AS1 cement 15.7 ppg while pumping 4.8bpm w/ initial 725 psi, final 730 psi, follow w/ 14.8 bbls of neat 15.7 ppg AS1. Pumped a total of 94.8 bbls of cement. Page 29 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 2,013 2,013 COMPZ CEMEN' DISP P Drop top plug, kick out plug w/ 5 bbls of water, then follow w/ heated seawater pumping initially 5.2 bpm w/ 350 psi. Pumped a total of 52.7 bbls (includes fresh water) behind plug @ midnight. Note: Started taking fluid to the vac truck after pumping 20 bbls behind plug. Truck was not keeping up. Slowed rate to keep cement out of BOP's. 10/27/2011 Finish 7" tieback cement job, WOC 4 hrs, PU stack, check cement (14' 9" below casing head. Clean out, then mix and pour .416 bbls (2.5 sx) of AS1 cement to leave 18" below casing head. Set FMC emergency slips on 7" w/ 50k overpull (125k on weight indicator). Cut w/ Wach pipe cutter, lay down cut joint (jt #48), Nipple down BOPE, install new tubing spool, test packoff to 3000 psi, NU BOPE, change bottom rams to 2 -7/8" x 5" (clean out cement), open bliinds (clean out cement), open top rams (clean out cement). 00:00 00:23 0.39 2,013 2,013 COMPZ CEMEN' DISP P Continue pumping seawater from a total of 52.7 bbls (includes fresh water) behind plug to 54.6 bbls. Pump rate was .5 bpm to try and keep cement f/ coming up the stack while vac truck was sucking off the annulus valve. Cement returns weighed 15.7 bbls. Shut down after pumping a total of 54.6 bbls behind the plug (includes 5 bls fresh water), close annulus valve. Disconnect vac truck. Close bottom pipe rams. Note: Started taking fluid to the vac truck after pumping 20 bbls behind plug. Truck was not keeping up. Slowed rate to keep cement out of BOP's. 00:23 01:14 0.86 2,013 2,013 COMPZ CEMEN' SQEZ P Dowell squeeze cement, pumpining initially .3 bpm w/ 653 psi with final rate of 1 bpm w/ 841 psi. Bumped closing plug @ 0050 hrs. Bleed off pressure, bled back 9 bbls. Re- pressure pumping 1 bpm, final pressure 750 psi. Continue to H ,,� observe the HES cementer close w/ �` 1805 psi, continued to pressure up to 2280 psi. Dowell BBI counter showed 79.1 bbls pumped behind plug ( Volume was 75.3 bbls). Held f/ 4 minutes, bleed off pressure. HES cementer tool is closed. CIP @ 0115 hrs. 10/27/2011 01:14 05:14 4.00 2,013 2,013 COMPZ CEMEN' WOC P Wait on cement f/ 4 hrs. Sim Ops: Clean and clear rig floor, clean cement valves, pumped Bio zan pill and let soak in stack f/ 2 hrs. Continue to flush stack w/ 25 bbl of bio zan, followed w/ 25 bbls brine. 05:14 05:29 0.25 2,013 2,013 COMPZ WHDBO SFTY P Pre job safety meeting on nipple down /Pick up stack. Page 30 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:29 05:59 0.50 2,013 2,013 COMPZ WHDBO NUND P Drain stack. Pick up stack. Measure to top of cement, 14' 9" below casing head. 05:59 06:59 1.00 2,013 2,013 COMPZ CEMEN" RURD P While cement is being brought over to do a top job, rig up 3/4" conduit to flush out and suck out the 9 -5/8" x 7" annulus. 06:59 07:59 1.00 2,013 2,013 COMPZ CEMEN" OTHR P Flush out the annulus w/ fresh water, suck out annulus to top of cement 14' 9" below top of 7" casing spool. 07:59 08:59 1.00 2,013 2,013 COMPZ RIGMNI SVRG P Service rig. 08:59 09:29 0.50 2,013 2,013 COMPZ CEMEN" CMNT P Mix cement in 5 gallon bucket, took .41 bbls (2.51 sx) (yield .93 cuft/sx) to fill to 18" below 7" casing flange. 09:29 10:59 1.50 2,013 COMPZ WHDBO CPBO P Set emergency slips w/ 50k over string weight. Rig down Dowell cement head f/ 7" casing jt # 48. Vacuum out fluid f/ the inside of the joint of 7 ". Cut off 7" casing w/ Wach's cutter. Cuttoff length of joint # 48 was 30.48'. Leaving 8.31' of joint # 48 below the lower lockdown screws. Cutoff 7 -1/4" above casing flange. 10:59 11:59 1.00 COMPZ WHDBO NUND P Nipple down BOPE. 11:59 12:14 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on nippling down BOPE. 12:14 13:14 1.00 COMPZ WHDBO NUND P Continue to nipple down BOPE, set BOP back out of the way, set down. 13:14 13:59 0.75 COMPZ WHDBO NUND P Nipple down 11" 3m x 13 -5/8" 5m adapter flange, remove old tubing spool. 13:59 15:14 1.25 COMPZ WHDBO NUND P Install FMC packoff for the 7 ". Pick up/ Make up 11" 5m Gen 4 FMC tubing head. Torque bolts. 15:14 15:29 0.25 COMPZ WHDBO PRTS P FMC test packoff to 3000 psi f/ 15 minutes. Driller witnessed test. Good Test. 15:29 17:59 2.50 COMPZ WHDBO NUND P Nipple up adapter flange 7- 1/16" 5m x 13 -5/8" 5m. 17:59 18:14 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on changing lower pipe rams f/ 7" to 2 -7/8" x 5" variables. 18:14 20:29 2.25 COMPZ WHDBO OTHR P Open up lower rams, Remove 7" rams, clean out cement f/ ram cavity, install 2 -7/8" x 5" variables, tighten doors. 20:29 22:29 2.00 COMPZ WHDBO OTHR T Due to cement in BOP stack while cementing 7" tie back string, opened up blind rams. Cement in cavities. Clean cement from rams and ram cavity. Remove choek line to open doors. Page 31 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:29 23:59 1.50 COMPZ WHDBO OTHR T Due to cement in BOP stack while cementing 7" tie back string, opened up top pipe rams. A little bit of cement in cavities. Clean cement from rams and ram cavity. 10/28/2011 Clean cement out of BOPE, RU, test top, bottom and annular to 3 -1/2" and 4 ", test choke line connection, test blind rams, MU 6 -1/8" bit BHA, RIH, clean up cement to 1939', CBU, test casing to 3000 psi f/ 30 min(Good), drill cement & HES cementer to 1962', RIH, ream as neccessary working past junk/cement to 2549'. Test 7" casing to 3000 psi f/ 10 minutes -good (charted). Pump a sweep, POOH, LD BHA, wash stack, MU 6 -1/8" concave mill assembly w/ boot baskets and magnet, RIH f/ 233' to 2482'. Mill f/ 2482' to 2602', circ 30 bbl sweep, POOH f/ 2602' to 2575', prep to POOH f/ BHA. 00:00 02:00 2.00 COMPZ WHDBO OTHR T Due to cement in BOP stack while cementing 7" tie back string, opened up top pipe rams. A little bit of cement in cavities. Clean cement from rams and ram cavity. Sim ops: Install riser, lay down elevatros, rig up short bales, rig up to test . 02:00 02:15 0.25 COMPZ WHDBO RURD P Rig up to test BOPE. 02:15 05:45 3.50 COMPZ WHDBO BOPE P Test BOPE. Test top pipe, bottom pipe and annular to 250 psi low and 3000 psi high. Test w/ 3 -1/2" and 4" test joint. Test blind rams. test choke line that was broke while cleaning ram cavities. Chart tests. 05:45 06:45 1.00 COMPZ WHDBO RURD P Rig down testing equipment. Set FMC 6 -3/8" ID wear bushing. Blow down choke manifold and kill line. Measured before stack was put on that the upper lockdown screws were @ 24.26' f/ rig floor. 06:45 07:00 0.25 COMPZ RPEQPI PULD P Pick tools up to the floor f/ BHA. 07:00 08:30 1.50 0 231 COMPZ RPEQPI PULD P Make up 6 -1/8" bit clean out BHA. 08:30 10:00 1.50 231 1,823 COMPZ RPEQP1TRIP P Trip in the hole f/ 231' to 1823'. 10:00 10:30 0.50 1,823 1,939 COMPZ RPEQP1DRLG P Make a top drive connection. Wash down and tag up on cement stringers @ 1902' , wash to 1932'. Drill cement stringers f/ 1932' to 1939'. 10:30 11:00 0.50 1,939 1,939 COMPZ RPEQPICIRC P Circulate bottoms up, pumping 6 bpm w/ 330 psi. 11:00 11:15 0.25 1,939 1,939 COMPZ RPEQP1RURD P Set back a stand, blow down the top drive. Rig up to test casing. 11:15 11:30 0.25 1,939 1,939 COMPZ RPEQPI PRTS P Test 7" casing to 3000 psi f/ 10 minutes. Chart test -good. 11:30 11:45 0.25 1,939 1,939 COMPZ RPEQPI RURD P Rig down testing equipment. 11:45 12:00 0.25 1,939 1,939 COMPZ RPEQP1DRLG P Make a connection. Pumping 6 bpm w/ 300 psi. Rotate 60 rpm w/ 700 ft lbs of torque. 12:00 14:00 2.00 1,939 1,962 COMPZ RPEQP1DRLG P Drill cement f/ 1939' to 1958'. Tagged up on closing plug. Increased rotary to 80 rpm. Drill plug, and HES cementer to 1962'. Ream stand twice, slow. Page 32 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:15 0.25 1,962 2,063 COMPZ RPEQP1TRIP P Trip in f/ 1962' to 2063'. Tagged up on junk w/ 10k. PU wt 73k, SO wt 70k, Rot wt 73k. 14:15 14:30 0.25 2,063 2,130 COMPZ RPEQPI REAM P Make a top drive connection, pumping 3 bpm w/ 75 psi, rotate 60 rpm w/ 1 -2k. Weight dropped off, wash and ream f/ 2063' to 2130'. 14:30 14:45 0.25 2,130 2,206 COMPZ RPEQP1TRIP P Trip in on elevators f/ 2130' to 2206', tagged up w/ 5 -7k. 14:45 15:00 0.25 2,206 2,289 COMPZ RPEQP1 DRLG P Make a connection, wash and ream /drill f/ 2206' to 2289'. 15:00 15:15 0.25 2,289 2,549 COMPZ RPEQP1TRIP P Trip in on elevators f/ 2289' to 2549', tagged up on junk. 15:15 15:30 0.25 2,549 2,551 COMPZ RPEQP1 DRLG P Make a top drvie connection. Drill on junk @ 2549' to 2551'. PU wt 70k, SO wt 73k, Rot wt 73k. Pumping 2 bpm w/ 75 psi, rotate 60 rpm w/ 1 -2k ft Ibs of torque. 15:30 15:45 0.25 2,551 2,480 COMPZ RPEQPI TRIP P Stand back a stand f/ 2551' to 2480'. Blow down the top drive. 15:45 16:00 0.25 2,480 2,480 COMPZ RPEQPI RURD P Rig up to test the 7" casing to 3000 psi. 16:00 16:15 0.25 2,480 2,480 COMPZ RPEQPI PRTS P Test the 7" casing to 3000 psi f/ 10 minutes. Chart test -good test. 16:15 16:30 0.25 2,480 2,480 COMPZ RPEQP1 RURD P Rig down testing equipment. Blow down the kill line. Line up to pump a sweep. 16:30 17:00 0.50 2,480 2,549 COMPZ RPEQP1CIRC P Make a top drive connection, pump a hi vis sweep, pumping 550 gpm w/ 1250 psi @ 2549'. 17:00 18:15 1.25 2,549 231 COMPZ RPEQP1TRIP P Blow down the top drive. Pull out of the hole f/ 2549' to 231'. 18:15 19:00 0.75 231 0 COMPZ RPEQPI PULD P Lay down BHA. 19:00 19:45 0.75 0 0 COMPZ RPEQP1OTHR P Pick up stack washing tool. Flush stack pumping 600 gpm w/ 60 psi. Lay down stack washing tool. 19:45 20:00 0.25 0 0 COMPZ RPEQP1SFTY P Pre job safety meeting on making up 6 -1/8" concave mill assembly w/ boot baskets and magnet. 20:00 20:45 0.75 0 233 COMPZ RPEQPI PULD P Pick up/ make up BHA to 233'. 20:45 22:00 1.25 233 2,482 COMPZ RPEQP1TRIP P Run in the hole w/ 6 -1/8" concave mill assembly w/ boot baskets and magnet from 233' to 2482'. 22:00 23:15 1.25 2,482 2,602 COMPZ RPEQPI MILL P Make a top drive connection. Wash down from 2482' to 2551'. Continue to work concave mill f/ 2551' to 2602', milling on cement/junk. PU wt 70k, SO wt 73k, Rot wt 70k. Pumping 252 gpm w/ 400 psi. Rotate 60 rpm w/ 400 ft Ibs of torque. 23:15 23:30 0.25 2,602 2,602 COMPZ RPEQP1CIRC P Circulate 30 bbl hi vis sweep, follow w/ new seawater. After sweep rounded bit, increase pump rate to 600 gpm w/ 1875 psi. 23:30 00:00 0.50 2,602 2,575 COMPZ RPEQPI TRIP P Rack back a stand f/ 2602' to 2575'. Blow down the top drive. Page 33 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/29/2011 24 hr S ummary Finish POOH w/ BHA #24, MU /RIH w/ BHA #25 (Rev circ JB) to 2617', circ, POOH, MU /RIH w/ BHA #26 (Rev Circ JB) to 2632', circ, POOH, MU /RIH w/ BHA #27 (3 string magnets) to 2637', circ, POOH, MU /RIH w/ BHA # 28 (3 string magnets) to 2638', circ, POOH, wash BOP stack, PU /MU RIH w/ BHA # 29 (3 string magnets) to 2639', circ, POOH to 1200' at midnight. Note: Goal is to clean up junk/iron /sand in the hole, then RIH & pull the RBP in the 7" casing (top @ 2645' DPM, center of element @ 2650'). 00:00 00:30 0.50 2,575 250 COMPZ RPEQPITRIP P POOH with 6 1/8" concave mill to 233'. Actual fill = 16.5 BBLS / Calculated fill = 16.6 BBLS. 00:30 02:00 1.50 250 0 COMPZ RPEQP1 TRIP P Rack back collars, Lay down concave mill BHA #24 // Baker Fishing Rep. 02:00 02:45 0.75 0 0 COMPZ RPEQP1 SFTY P Prejob safety meeting .// Make up BHA #25 // Reverse circulating basket. 02:45 03:30 0.75 0 2,581 COMPZ RPEQP1 TRIP P Trip in the hole with BHA #25 to 2581' MD. Actual displacement = 16 BBLS, Calculated displacement = 16.6 BBLS. 03:30 04:00 0.50 2,581 2,617 COMPZ RPEQP1CIRC P Make up top drive. P/U WT. =70k, S/O WT. =73k, Broke circ. @ 8 BPM, 785 psi. Shut down drop ball, pump 4 BPM @ 50 PSI. When ball seat pressure came up to 200 PSI, turned the flow up to 8 BPM, 1515 PSI. ROT @ 60 RPM. Reduce flow to 1 BPM, tag sand @ 2602'. Came down to 2605. Increase flow to 8 BPM. Rotate down to 2617'. Stop. Pick up off bottom. 04:00 04:15 0.25 2,617 2,617 COMPZ RPEQP1CIRC P Circulate high vis sweep. 600 GPM. 1650 PSI. Rack back one stand. Blow down top drive. 04:15 05:15 1.00 2,617 238 COMPZ RPEQP1TRIP P POOH to BHA # 25. Reverse circ. basket / boot basket / magnet / . Retrieved 2 large (2" x 3 ") pieces of the 9 5/8" casing. Magnet was full of shavings and junk. Actual fill =16.25 BBLS, Calculated 16.6 BBLS. 05:15 06:30 1.25 238 0 COMPZ RPEQP1TRIP P Rack back collars, Lay down and clean up BHA. 06:30 08:00 1.50 0 250 COMPZ RPEQP1 TRIP P PJSM / Make up BHA #26. Reverse Circ Junk Basket / 2 boot baskets / 2 string magnets. 08:00 08:45 0.75 250 2,632 COMPZ RPEQP1TRIP P Trip in the hole with BHA #26 to 2617' MD. Parameters. 1BPM =60 PSI, 60 RPM= 1k TQ, P/U WT. =72k, S/O WT. =75k, ROT WT =75k. RIH tag up on sand @ 2617. Rotate down 3' with 1 BPM, increase flow to 8 BPM. 1720 PSI. Rotate down 12 more feet to 2632' MD. P/U 15' off bottom. 08:45 09:15 0.50 2,632 2,632 COMPZ RPEQP1CIRC P Pump high vis sweep @ 10 BPM, 1800 PSI 09:15 10:15 1.00 2,632 250 COMPZ RPEQP1TRIP P Rack back one stand of collars. Blow down top drive. POOH with BHA# 26. Page 34 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 12:00 1.75 250 0 COMPZ RPEQPITRIP P Rack back collars, lay down reverse circ. junk basket. Clean up magnets 12:00 12:15 0.25 0 0 COMPZ RPEQP1SFTY P Prejob safety meeting. BHA #27. Tripple magnet run with mill tooth bit. 12:15 12:45 0.50 0 255 COMPZ RPEQP1 TRIP P Pick up BHA# 27. Mill tooth bit / 2 boot baskets / 3 string magnets 12:45 13:30 0.75 255 2,597 COMPZ RPEQP1TRIP P Trip in the hole. to 2597' MD. Calculated displacement = 16.66 BBLS. Actual displacement 16.5 BBLS. 13:30 13:45 0.25 2,597 2,637 COMPZ RPEQP1CIRC P P/U WT= 70K, S/O WT = 75K, ROT WT = 75K, 2 BPM 60 PSI, 1K TQ @ 60 RPM, TIH tag sand @ 2634' MD. Rotate down 3 feet of sand to 2637.46' MD. P/U 15 feet. 13:45 14:15 0.50 2,637 2,637 COMPZ RPEQP1 CIRC P Pump sweep around @ 600 GPM. 60 RPM. 1200 PSI. SPR's #1 pump, 30 SPM = 57 PSI, 40 SPM = 90 PSI, #2 pump, 30 SPM = 60 PSI, 40 SPM = 90 PSI. 14:15 15:30 1.25 2,637 255 COMPZ RPEQP1TRIP P POOH to BHA # 27 @ 254'. Calculated displacement = 16.66 BBLS, Actual displacement = 16.5 BBLS. 15:30 15:45 0.25 255 0 COMPZ RPEQP1TRIP P Clean junk baskets and magnets. Magnets 80% covered. Less than BHA #26, Descision made to run the assembly again. 15:45 16:15 0.50 0 254 COMPZ RPEQP1 PULD P MU 6 -1/8" bit w/ two JB, and three magnets to 254'. 16:15 17:15 1.00 254 2,597 COMPZ RPEQP1TRIP P RIH on 4" dp f/ 254' to 2597'. Calculated displacement 16.66 bbls, actual 16.5 bbls. 17:15 17:30 0.25 2,597 2,638 COMPZ RPEQP1CIRC P Make a top drive connection @ 2597'. Pump 2 bpm w/ 60 psi, no rotation. Run in the hole and tag sand @ 2638', set down 3k. Picked up off bottom. PU wt 70k, SO wt 75k. 17:30 17:45 0.25 2,638 2,638 COMPZ RPEQP1CIRC P Pumped hi vis sweep, pumping 600 gpm w/ 1250 psi. 17:45 18:00 0.25 2,638 2,619 COMPZ RPEQP1TRIP P Stand back a stand, blow down the top drive. 18:00 18:45 0.75 2,619 254 COMPZ RPEQP1TRIP P Trip out f/ 2619' to 254'. 18:45 19:15 0.50 254 0 COMPZ RPEQP1 OTHR P Stand back drill collars, pick up and inspect magnets. Still had small pieces of iron. (50 %) compared to last run. Decision made to lay down magnets, flush BOP stack. and run again. 19:15 19:45 0.50 0 0 COMPZ RPEQP1OTHR P Clean magnets, lay down magnets to the pipe shed. Clean and lay down junk baskets to pipe shed. 19:45 20:30 0.75 0 0 COMPZ RPEQPI CIRC P Make up a single drill pipe w/ stack washing tool. Flush stack, pumping 650 gpm w/ 15 rpm. Lay dowbn stack washer and joint. Page 35 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 0 254 COMPZ RPEQPI PULD P Pick up/ make up BHA #29 (6 -1/8" bit, two JB, three magnets) to 254'. 21:00 22:15 1.25 254 2,639 COMPZ RPEQP1TRIP P Run in the hole w/ BHA #29 f/ 254' to 2597'. Kelly up, pump 2 bpm w/ 70 psi. Slack off with out rotation f/ 2597' to tag up on sand. Set down w/ 3k @ 2639'. Picked up 1 foot to 2638'. PU wt 72k, So wt 75k. 22:15 22:45 0.50 2,639 2,638 COMPZ RPEQP1CIRC P Pump a high vis sweep @ 2638'. Pumping 600 gpm w/ 1150 psi, follow w/ 4 bottoms up while watching returns at the rock washer till clean. 22:45 00:00 1.25 2,638 1,200 COMPZ RPEQP1TRIP P Trip out of the hole w/ magnets f/ 2638' to 1200'. 10/30/2011 Finish POOH BHA #29 f/ 1200', MU /RIH w/ BHA #30 to 2639', circ, POOH, UD BHA #30, UD BHA, clear floor, PU BHA #31 to pull RBP @ 2645', RIH to 2648'. Retreive plug. POOH. UD plug. P/U Poor Boy Overshot/Packer assembly, TIH on 4" DP to 5576'. 00:00 00:15 0.25 1,200 254 COMPZ RPEQP1TRIP P Trip out of the hole w/ magnets (BHA #29) f/ 1200' to 254'. 00:15 00:30 0.25 254 0 COMPZ RPEQP1TRIP P Work BHA, clean off magnets, check boot baskets (small amount of iron). Still have iron on magnets. Will run same assembly again. 00:30 01:00 0.50 0 254 COMPZ RPEQP1 TRIP P Make up BHA #30 (triple magnets /dual boot baskets) to 254'. 01:00 01:45 0.75 254 2,597 COMPZ RPEQP1 TRIP P Run in the hole w/ BHA #30 f/ 254' to 2597'. 01:45 02:15 0.50 2,597 2,639 COMPZ RPEQP1CIRC P Obtain parameters. PU wt 70k, SO wt 75k. Slack off to 2639'. Pumping 84 gpm w/ 70 psi, pump hi vis sweep, once in the annulus, increase rate to 600 gpm w/ 1150 psi. Circ 100 bbls after sweep is back to surface. 02:15 02:30 0.25 2,639 2,597 COMPZ RPEQP1TRIP P Stand back a stand. Blow down the top drive. 02:30 03:15 0.75 2,597 257 COMPZ RPEQP1TRIP P Trip out of the hole w/ BHA #30 f/ 2597' to 257' 03:15 03:30 0.25 257 0 COMPZ RPEQP1TRIP P Change elevators. Work BHA f/ 257'. 03:30 03:45 0.25 0 257 COMPZ RPEQP1TRIP P Magnets are very clean. Just a little fuzz. Run 2 stands of drill collars in hole. 03:45 05:30 1.75 257 0 COMPZ RPEQP1 PULD P Lay down BHA #30. 05:30 06:30 1.00 0 0 COMPZ RPEQPI PULD P Clear floor, PU tools f/ beaver slide. 06:30 06:45 0.25 0 0 COMPZ RIGMNTSVRG P Service top drive. P/U Single from pipe shed, install head pin, and lay down joint. 06:45 07:45 1.00 0 0 COMPZ RPEQP1 PULD P Pick up, make up retrieval tool as per Baker Rep. 07:45 08:30 0.75 0 2,632 COMPZ RPEQPITRIP P Trip in the hole with retrieval tool to 2632. Actual displacement = 16 BBLS, Calculated displacement = 16.2 BBLS. Page 36 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:30 1.00 2,632 2,632 COMPZ RPEQP1 SFTY P Prejob safety meeting: Discussed the Well Control Issues. Possible gas below the bridge plug, also possibly could go South if the 2 7/8" plug is not holding. Rig up to reverse circulate. 09:30 10:45 1.25 2,632 2,648 COMPZ RPEQP1 CIRC P Reverse @ 6 BPM. W/ 330 PSI. Washed down to 2643'. CBU. Sand on the shakers. Washed down to 2648'. CBU. Sand on the shakers. Pressure increased to 1100 PSI. Set 10k down. No 'J' latch indication seen. 10:45 11:00 0.25 2,648 2,648 COMPZ RPEQP1RURD P Rig down the cement line used to reverse circ. and rig up to pump the long way. 11:00 12:00 1.00 2,648 2,648 COMPZ RPEQP1CIRC P P/U Single from the pipe shed. M/U top drive. TIH to 2648. Saw the % turn 'J' indication. Latched up to bridge plug. Slow rotation to the right to release slips. Saw release. Verify pipe was free. P/U WT. =75k, S/O WT. =72k. 12:00 12:15 0.25 2,648 2,648 COMPZ RPEQP1CIRC P Crew change/ Prejob safety meeting. / Good change out/ Pump high vis fiber sweep surface to surface @ 6 BPM 200 PSI. 12:15 12:30 0.25 2,648 2,648 COMPZ RPEQPITRIP P Blow down top drive, Kill line, Lay down single into pipe shed. 12:30 14:30 2.00 2,648 15 COMPZ RPEQP1TRIP P POOH on elevators from 2648 to 15'. 14:30 14:45 0.25 15 0 COMPZ RPEQP1 RURD P Lay down BHA, the bridge plug was covered with magnetized slivers of metal. 14:45 15:00 0.25 0 0 COMPZ RPEQP1 RURD P Clear and clean rig floor 15:00 15:15 0.25 0 0 COMPZ RPEQP1 PULD P P/U Casing tools from beaver slide. Double stack tongs. 15:15 15:45 0.50 0 0 COMPZ RPEQP1RURD P Rig up double stack casing tongs. 15:45 16:00 0.25 0 0 COMPZ RPEQP1SFTY P Pre job safety meeting on running poor boy overshot, completion assembly. 16:00 17:00 1.00 0 64 COMPZ RPEQP1 RCST P Make uo Door bov assembly to 64': Poor boy overshot, 2 -7/8" 6.4 ppf L -90 EUE pup jt, x -o, 3-1/2" 9.3 ppf L -80 EUE pup jt, 2.812" DS nipple, 3 -1/2" 9.3 ppf L -80 EUE pup joint, one joint of 3 -1/2" 9.3 ppf 1 -80 EUE -mod tubing. Page 37 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 64 108 COMPZ RPEQPI RCST P Remove collar on the joint of 3 -1/2" tubing, clean and baker lock to the tube. Make up assembly: 3 -1/2" 9.3 ppf L -80 EUE -mod pup joint, Baker "FHL" retrievable packer, Baker "80 -40" PBR (20' long) (4" bore), Seal assembly installed, 3 -1/2" 9.3 ppf L -80 EUE mod tubing. Note: Total length 107.64'. Will have 6.2' swallow over 2 -7/8" cut joint. All connections below the packer are baker locked. 18:00 18:15 0.25 108 111 COMPZ RPEQPI RCST P Make up crossover 3 -1/2" IF box x 3 -1/2" EUE pin and another crossover XT39 box x 3 -1/2" IF pin. 18:15 00:00 5.75 111 5,576 COMPZ RPEQPI RCST P Run in the hole w/ poor boy overshot assembly on 4" drill pipe f/ 110.46' to 5576' (58 stands and a single).PU wt 106k, SO wt 104k. 10/31/2011 Run and set Poor Boy Overshot and FHL Packer. POOH lay down PBR seal assembly. Rig up and run completion 3.5" gas lift string, land w/ 7.33' space out. RILDS, torque to 350 ftlbs. 00:00 02:00 2.00 5,576 5,643 COMPZ RPCOM CIRC P TIH tag up @ 5643' (mule shoe depth). PU to 5636'. Rev circulate @ 2 BPM. Pressure increased up to 1200 PSI. Stop pumping. Bleed off and open bag attempt to circulate thru the top drive. Pressure up to 500 PSI in 3 strokes. Plugged off. Prepare to Pull a stand. 02:00 02:30 0.50 5,643 5,579 COMPZ RPCOM CIRC P Rig down lines, blow down. Pull one stand wet. Pulled working single, and came dry. Pump thru TD @ 2 BPM @ 80 PSI. Obstruction was gone. 02:30 03:00 0.50 5,579 5,635 COMPZ RPCOM CIRC P P/U Single and one stand. Place overshot @ 5635'. Rig up to reverse circulate. P/U WT= 107k, S/O WT =103k 03:00 04:30 1.50 5,635 5,635 COMPZ RPCOM CIRC P Reverse circulate with clean 8.6 PPG brine. 3 BPM 210 PSI. Pumped 220 bbls. 04:30 05:00 0.50 5,635 5,635 COMPZ RPCOM CRIH P Pump down string, pumping 5 gallons of CRW132 in the first 8 bbls of fluid pumped @ 2 BPM, 80 PSI. Chase with 64.7 BBLS 8.6 PPG brine @ 3 BPM, 155 PSI. Total strokes pumped =855. This leaves 1.5 bbls in the string (162') and 6.5 bbls in the annulus (264'). Corrosion inhib in annulus f/ 5635' to 5371'. Corrosion inhib in string f/ 5635' to 5473'. 05:00 05:45 0.75 5,643 5,643 COMPZ RPCOM TRIP P Rig down/ lay down working single. Drop ball and rod (6.7' long, 1.38" OD fish neck, 1- 5/16" ball). Let fall for 30 mins. Page 38 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:00 0.25 5,643 5,641 COMPZ RPCOM RCST P TIH/ locate to NO GO position. Set down 5k. Pick up to 5641'. Pressure up and shear out @ 2000 PSI. Held for 5 mins. Continue to pressure up to 2500 PSI. Held for 1 min. Bleed off pressure. 06:00 06:45 0.75 5,641 5,641 COMPZ RPCOM PRTS P Rig up to test Baker "FHL" Packer, top set @ 5563.38' . Close annular, pump down kill line. Pumped a total of 27 strokes (2.3 bbls). Chart for 30 mins @ 3000 PSI. Good- lost 50 psi. 06:45 07:00 0.25 5,641 5,641 COMPZ RPCOM PRTS P Bleed off pressure. Rig up to pump down drill pipe. Pressure up to 1500 PSI. Pick up to 120k string weight, observe release. Equates to 15k over string weight. Open bleed off, and rig down surface lines, blow down. 07:00 07:30 0.50 5,641 5,641 COMPZ RPCOM TRIP P Put single back in drill pipe string. Monitor well, static. 07:30 09:30 2.00 5,641 28 COMPZ RPCOM TRIP P POOH with seal assembly and mule shoe f/ 5641'. 09:30 09:45 0.25 28 0 COMPZ RPCOM RURD P Lay down Baker seal assembly and locator. 09:45 10:15 0.50 0 0 COMPZ RPCOM RURD P Clear and clean rig floor. 10:15 10:30 0.25 0 0 COMPZ RPCOM SFTY P Prejob safety meeting on slip and cut drill line. 10:30 12:00 1.50 0 0 COMPZ RPCOM SLPC P Hang blocks, spool line off, remove dog knot, cut line, install tail, put on dog knot, spool on new line, tighten deadman, unhang blocks, inspect brakes, install guards ( 86' ). 12:00 13:00 1.00 0 0 COMPZ RPCOM RURD P Rig up casing running equipment. Pull wear bushing, M/U surface valve for well control. 13:00 13:15 0.25 0 0 COMPZ RPCOM SFTY P Prejob safety meeting on running 3 -1/2" 9.3 ppf L -80 EUE -mod tubing. 13:15 20:15 7.00 0 5,530 COMPZ RPCOM RCST P RIH with 3% Gas Lift Completion. Install jewelry items per detail. Run jt # 174 in the hole to 5530.83' 20:15 20:45 0.50 5,530 5,530 COMPZ RPCOM RURD P Pick up joint 175, make up headpin and 2" hose. PU wt 74k, SO wt 75k, blocks 35k. 20:45 21:00 0.25 5,530 5,561 COMPZ RPCOM RCST P Turn on charge pump, circulating w/ 43 psi, run in the hole f/ 5530.83 to 5540.37', saw pressure increase to 90 psi (mule shoe @ 5541.33'). Shut down charge pump, open bleeder line to atmosphere. Continue to slack off jt 175 in the hole. Make up joint #176 to locate w/ jt # 175 out of the hole .49', in 30.24', mule shoe depth 5561.07'. Set down 10k. 21:00 22:00 1.00 5,561 5,530 COMPZ RPCOM PULD P Lay down joints 176, 175, 174, and 173. f/ 5561' to 5530.83'.Figure space out. Page 39 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:45 0.75 5,530 5,540 COMPZ RPCOM HOSO P Change seal ring on jt #172', Replace joint #173 w/ 28.30' joint, replace joint # 174 w/ 28.72'. This will leave a space out of 7.33'. Make up FMC tubing hanger on top of joint #174. Run in the hole w/ charge pump and verify PBR, pick up 1' to 5540'. 22:45 23:00 0.25 5,540 5,540 COMPZ RPCOM SFTY P Pre job safety meeting on displacement to inhibited seawater (CRW132). 23:00 23:30 0.50 5,540 5,540 COMPZ RPCOM CIRC P Circulate inhibited seawater. Pumping 106 bbls @ 3.5 bpm w/ 225 psi, chase with 95 bbls of not inhibited seawater @ 7 bpm w/ 725 psi. 88 bbls inhibited in the hole. 23:30 00:00 0.50 5,540 5,554 COMPZ RPCOM HOSO P Run in hole w/ completion f/ 5540' to 5553.74' (mule shoe depth) Spaced out 7.33' from fully located. Land hanger, Run in lock down screws, torque to 350 ft Ib. 11/01/2011 Test Tubing x Annulus - 3100 PSI. pressure to 3600 PSI to shear valve. Install BPV. ND BOP's. NU Tree and test same. RU and pump 88 BBLS of diesel for freeze protection. Allow to U -tube until dead. Set BPV. Lay down Drill pipe. Secure well & cellar. Rig released at midnight. Prep to move. 00:00 02:00 2.00 5,554 5,554 COMPZ RPCOM PRTS P Test tuhing to 3100 psi f/ 30 . minutes -good- chart test. Bleed off pressure to 1700 psi. Preussure up on the 7" x 3 -1/2" annulus to 3600 psi - good -chart test. Bled IA to zero, bled tbg to zero. Pressure to shear the valve in the GLM. Sheared @ 2200 psi. Monitor well -ok. 02:00 03:00 1.00 5,554 0 COMPZ RPCOM RURD P Rig down circulating equipment. Lay down landing joint. Set BPV, Tet BPV to 1100 psi for 10 minutes. 03:00 05:15 2.25 0 0 COMPZ RPCOM NUND P N/D BOPE and adapter flange. Clean pits 05:15 06:45 1.50 0 0 COMPZ WHDBO NUND P Nipple up adapter flange and tree. CPF2 facility engineer on location to verify alignment 06:45 09:00 2.25 0 0 COMPZ WHDBO NUND P Attempt to pull BPV. Wait for second retrieving tool. Clear rig floor of tubing tongs and elevators 09:00 12:00 3.00 0 0 COMPZ WHDBO NUND P Pulled BPV. Set test plug. Test tree to 150/5000 psi. 12:00 12:15 0.25 0 0 COMPZ WHDBO NUND P Pull test plug 12:15 12:30 0.25 0 0 COMPZ WHDBO RURD P Rig up to freeze protect well 12:30 14:00 1.50 0 0 COMPZ WHDBO FRZP P Freeze protect weel with 88 bbl diesel by pumping down IA @ 2 BPM - 725 PSI. 14:00 15:45 1.75 0 0 COMPZ WHDBO FRZP P Allow well to U -tube diesel until dead. No pressure. SIMOPS: - Lay down 4" drill pipe form derrick. 15:45 17:00 1.25 0 0 COMPZ WHDBO RURD P Install BPV with lubricator. Annulus pressure read 20 PSI. Off Hi Line power at 1700 HRS. Page 40 of 41 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:45 0.75 0 0 COMPZ WHDBO NUND P Dress tree, nipple down secondary annulus valve. 17:45 21:00 3.25 0 0 COMPZ RPCOM PULD P Continue breakout and lay down 4" drill pipe form derrick. Clear rig floor of all XT -39 crossovers and equipment. 21:00 00:00 3.00 0 0 COMPZ MOVE RURD P Blow down all steam, air, and water lines form interconnects. Prep Tioga for move. Prep stairs and landings. Rig released at 23:59 HRS 11 -1 -2011. Page 41 of 41 • • S Alf E n1 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson Workover /Wells Supervisor Q .6 .e-- ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -11 Sundry Number: 311 -284 Dear Mr. Nelson:. ¢ p <<. 3 1 1'1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. h J Chair DATED this Z�day of September, 2011. Encl. � , 4 4.... STATE OF ALASKA , 01' ALASK. AND GAS CONSERVATION COMMISSIO• IFP 1 f t : APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon r Rug for Redrill f Perforate New Pool r Repair well p- • ChangeMenorkgegram F Suspend f Rug Perforations r Perforate r Rill Tubing Time Extension f • Operational Shutdown r Re -enter Susp. Well r Stipulate r Alter casing I✓ O ther: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 . Exploratory r 186 -003 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20057 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No ]d 2A -11 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25570 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6675 • 6257 • 6621' 6210' Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 106' 106' SURFACE 2747 9.625" 2782' 2782' PRODUCTION 6083 7 6114' 5781' LINER 813 5 6670' 6253' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6244' 6273', 6337 6342', 6355' - 6380' _5891' 5916', 5966 5975', 5986 2.875 / 2.375 J - 55 _ 6324 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP -1 PACKER MD= 5692 TVD= 5431 PACKER - BAKER DB PACKER MD= 6302 TVD= 5941 SSSV - CAMCO TRDP MD =1807 TVD =1807 12. Attachments: Description Summary of Roposal J;r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch ] Exploratory l` Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/1/2011 ° Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ j"" WAG r Abandoned r Commission Representative: GSTOR r SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson @ 263 -4693 Printed Name rik Nelson Title: Workover/Wells Engineer Signature if,•:,\ Phone: 263-4693 Date /Slip 77/ Commission Use Only i Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ")// >74 Plug Integrity r BOP Test IV Mechanical Integrity Test r Location Clearance r 3000 e s,: 8 "f" Other: ,w , € ,,, r t Z J S OO p sz A.,,w S� J Subsequent Form Required: / 6 ._.1.I 04 / APPROVED BY A roved by COMMISSIONER THE COMMISSION Date: t 1 PP Y f � 12.21 Form 10 -403 I7o iws SEP 2 2 20 ? , � ' Submit Duplicate l � b {S I N - mit i L 4, • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 S 14 September, 2010 Alaska Oil & s Co ��, e 4fCS* Ol>r OA Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2A -11 (PTD 186 -003). Well 2A -11 was originally drilled and completed in 1986. It is an A and C sand producer with a single selective completion. Well 2A -11 has had a history of inner annulus by outer annulus pressure communication since 2004 when an internal waiver was approved which allowed the well to continue producing, A slow thread gas leak is assumed to he the cause of this communication. 2A -11 passed both a TIFL and MIT -OA on 12 September 2011 and 05 March 2011, respectively. A gyro survey run on April 16, 2010 could only reach a depth of 266' RKB. As with many wells on the 2A and 2T drillsites, subsidence is assumed to be the root cause of the casing and tubing issues in this well. The purpose of this workover is to restore the integrity of the tubing and casing strings and provide a stronger wellbore to combat the effects of future / subsidence. This will be accomplished by replacing the current 2 -7/8" J -55 tubing with new 3 -1/2 L -80 tubing and also replacing the top —1,500 feet of 7" production casing. By cementing the replaced production casing to surface, this will effectively mitigate the surface casing leak and will provide a stronger wellbore. If you have any questions or require any further information, please contact me at 263 -4693. Rega ds, Erik Q - son' Wells Engineer CPAI Drilling and Well • IIP 2A -11 Expense Rig Workover PTD #: 186 -003 Current Status The well is currently on production and under an increased surveillance schedule due to restricted access through tubing while it awaits a workover to replace the corkscrewed tubing and proactively repair the T and 9 -5/8" casing strings. , Scope of Work Pull corkscrewed 2 -7/8" J -55 tubing, proactively cut & pull a portion of the 7" casing, re -run new 7" casing, cement the 9 -%" x 7" annulus, and install new 3 -l" L -80 tubing. General Well info MASP: 1982 psi Reservoir pressure/TVD: 2577 psi 15949' TVD Using SBHP measured on 20 July 2009 of 2389 psi at 5750' MD (5478' TVD and 2356 psi gradient stop at 5629' MD (5378' TVD) Wellhead type /pressure rating: FMC Gen III 111" 5M BOP configuration: Annular / Pipe / Blind 1 Flowcross / Pipe ' TIFL / MIT -IA / MIT -OA: TIFL passed 12 September 2011 MIT -OA passed 05 March 2011 Well Type: Producer Estimated Start Date: 01 October 2011 Production Engineer: Gavin Fleming RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 — 7407 E -Mail: Erik.Nelson @conocophil €ips.com Pre -Rip Work Request 1. Obtain updated SBHP 6 t b 7. � 2. Dummy off GLM #s 1 & 2 and pull dummy from GLM #5 and leave open fi 3. PT tbg and csg packoffs and FT LDSs 4. Cut tbg in 1st jt above OEJ 5. Set BPV Proposed Procedure 1. MIRU Nordic 3. Accept Rig, take on fluids, pull BPV, and insure well is dead. 2. Install BPV & blanking plug, ND tree, NU 11" 5M BOPE, function and PT to 250/3000 psi. 3. Pull blanking plug & BPV. Screw in landing jt, BOLDS's, and pull to the floor, 4. LD tbg hgr and TOOH sideways w/ 2 -7/8 ", J -55 AB -Mod tbg. 5. MU and RIH w/ csg scraper (7 ") on 3 -'h" IF DP. 6. RU HES E -line and run CBL log and shoot string shot at identified collar. RDMO E -line 7. MU and TIH w/ RBP or IBP and set below TOC. PT to 3000 psi and drawdown test same. Dump sand on top of plug. 8. ND BOPE and tbg head. Re -land 7" csg in tension. NU 11" 5M BOPE on 11" 3M casing head. Remove casing packoffs and slips. 9, Test break to 250/3000 psi. • 10. Cut 7" casing with multi- string cutter on drill pipe above TOC. Ciro 9 -5/8" x 7" annulus clean. 11. Spear and TOOH laying down 7" casing. • • • • --- Proposed Procedure Continued- - 12. Run 9 -5/8" casing scraper to top of 7" stub. Circ clean. 13. RU HES E -line and run gyro w/ GR and memory caliper log. RDMO E -line. 14. Run tandem string mill assembly to gauge casing for installation of new 7" csg string. Make dummy run for 7" csg and Halliburton ES cementer. 15. TIH w/ back off tool and back off casing stub. TOOH. 16. TIH spear and recover casing stub. TOOH. 17. C /out lower BOP ram to 7" and test ram to 250/3000 psi. 18. TIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing to 3000 psi. 19. Open ES cementer and pump cement (calculated plus — 25% excess) into 9 -5/8" x 7" annulus. After obtaining cement circulation to surface close cementer. 20. WOC. ND BOPE and land 7" on slips. Cut 7" casing and install packoff. NU tubing head. 21. NU 11" 5M BOPE and test break to 250/3000 psi. 22. Drill out cement and plug. Pressure test casing to 3000 psi. TOOH. 23. TIH w/ reverse circulating junk basket to clean out remaining debris. TOOH. 24. TIH with wash shoe and circulate out sand on top of RBP. TOOH. TIH w/ retrieving tool on work string. Release RBP /IBP and TOOH. 25. TIH with seal assembly, packer, and 20' PBR on 3 -'h" IF DP. Go over tubing stub. Circ in corrosion inhibited fluid. Set packer. TOOH laying down DP. 26. TIH with new 2 -7/8" tubing and seal assembly. Load tubing and IA with corrosion inhibited seawater. Stab into PBR and space out. Pressure test tubing and IA to 3000 psi. Shear SOV. 27. Set 2 -way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 28. Pull 2 -way check. Freeze protect well. Set BPV. 29. RDMO Nordic 3. Post -Riq Work: 1. PuII BPV 2. Pull DVs and SOV and run GL design 3. Pull ball / rod 4. Pull RHC body 5. Handover to Ops e r , , KUP • 2A -11 Cca�oct Well A _ _ M Angle & MD TD Welibore APW WI (Feld Name ell Status Intl (°) IND dtKB) Act Btm (ftKB) v.1- , t», no• _ 501032005700 KUPARUK RIVER UNIT PROD 35.67 4,700 00 6,675 0 Comment H2S (ppm) Date Annotation End Date KB (fy Rig Release Date SSSV: LOCKED OPEN I 110 I 1/10/2009 Last WO I_ 34.71 1/30/1986 WeexBS .,..i <.i�c. ",11,A mt Annotation Depth (ftKB) End Date Annotation IL t Mnd ... End Date Last Tag: _ 1 . 6,369.0 I. 2/10/2000 [ Rev Reason FORMAT UPDATE I Imosbor 1 10/7/2010 Scale Wittier, - _- - Tra, o Casing Strings - - Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt.. String ... String Top Thrd 16 15.060 35.0 106.0 106.0 62.50 H Casing Description String 0... String ID .. Top (NCB) Sat Depth If.. Set Depth (TVD) ... String Wt... String ... String Top ThN SURFACE CE 9 5/8 8.921 35.4 2,782.4 2,782.2 36.00 J BTC ill . � Casing Description String 0... String ID . Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... Str g .. String Top Thrd PRODUCTION 7 6 151 31.0 6,113.9 5,781.0 26.00 J BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f_. Set Depth (ND) .. String Wt... String ... String Top Thrd CONDUCTOR,__ LINER 5 4.276 5,857.0 6670.0 6,252.5 1800 L-80 LTC 3S -106 Liner Details Top Depth (ND) Top Intl Komi... SAFETY VLV. -: Top(7KB) ( B) (1 hers Description Comment ID(in) 1,807 - 5,857.0 5,566.8 34.85 HANGER BAKER LINER HANGER 5.000 Ili Tubing Strings i Stri ... - - 'Tubing Description String O._ String ID -. Top (ftKB) Set Depth (f... Set Depth (ND) . Wt... String .. I String Top Thiel TUBING 2 7/8 2. 441 31. 6.324.2 5,959.5 6.50 J -55 AB -MOD , GAS LIFT 2.875x2.375" 2 259 - - -- '- Completion Details Top Depth (ND) Top Intl Komi... Top (ftKB) (NCB) (°) Item Description Comment ID (in) 31.0 31.0 -0.07 HANGER FMC TUBING HANGER 2.875 1,806.9 1,806.9 0.53 SAFETY VLV CAMCO TRDP SSSV 2.313 SURFACE, - 5,674.8 5,416.6 34.72 SBR CAMCO OEJ SBR 2.312 35 - 2,782 5,692.4 5,431.0 34.69 PACKER CAMCO HRP -1 PACKER 2.344 ir 5,774.4 5,498.5 34.57 NIPPLE AVA NIPPLE 2.250 GAS LIFT, 6,233.0 5,881.8 31.44 BLAST JT _ -- 2.041 3,872 _ - - -. - 6,301.2 5,940.0 31.93 LOCATOR BAKER LOCATOR w/5' SEALS 2.041 - 6,301.8 5,940.5 31.93 PACKER BAKER DB PACKER 2.041 - ee 6,316.2 5,952.7 32.03 NIPPLE CAMCO D NIPPLE 1.813 tins u t . I 6,323 6 5,959.0 32 09 SOS CAMCO SHEAROUT SUB - ELMD @ 6308' ON PERF 11/3/1986 1 -995 4.994 lit Other In Hole ireline ev able plugs, valves, pumps, fish, etc.) Top Depth 111 (rVO) Top Intl Tap (ftl(B) (ftKB) ("i Description Comment Run Date ID (in) 5,774.4 5,498.5 34.57 SLEEVE AVA, 2.25" BPC 2/9/2001 1.875 GAS LIFT, 5,348 „- 6,252.0 5,898.1 31.58 PATCH Mena TUBING PATCH 3/16/1986 1.399 III ' Perforations & Slots Shot GAS LIFT, Top (TVD) Btm (TVD) Dens 5,635 _ :-: Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment i ll . 6,244.0 6,273.0 5,891.2 5,916.0 C-4, 2A -11 3/16/1986 12.0 IPERF 60 deg. phasing, 3 3/8" Csg Gun SBR, 5,675 - - - - - -- 6,332.0 6,342.0 5,966.1 5,9745 A-4, 2A -11 11/3/1986 , 4.0 APERF Zero Deg. Phasing, 1 11/16" TBG GUN PACKER, 5,692 6,355.0 6,380.0 5,985.5 6,006 7 A-3, 2A -11 2 13/16/1986 6.0 IPERF 60 Deg. phasing, 3 3/8" Csg Gun - .. __ -__ L __. _. _I - Ili Cement Squeezes GAS LIFT Top Depth Btm Depth 5.735 - (ND) �- - (ND) i... Top (ftKB) Btrn (ftKB) (ftKB) (ftKB) Description Start Date Comment _ I 0.0 0.0 Cement Squeeze 2/12 /1992 NIPPLE, 6,774 - ' Notes: General & Safety SLEEVE,5,774 - - End Date Annotation 4/13/2003 NOTE: TUBING IS CORKSCREWED. 1/6/2005 NOTE: WAIVERED WELL' IA x OA COMMUNICATION 10/7/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PRODUCTION.__ -_ 314,114 IPERF, 6,244 -6,273 PATCH, 6,252 , 1 LOCATOR,_- 6,301 PACKER. 6,302 - NIPPLE. 6.316- .. __... 305,6,324 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch S'ze TRO Run 6,332 °ERF, Stn Top (ftKB) (ftKB) el Make Model lint Sere Type Type (in) (Psi) Run Dab Can... -- 1 2,258.0 2,257.8 0.85 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,291.0 8/122004 2 3,872.2 3,866.4 12.88 CAMCO KBMG 1 - - -- IPERF, - GAS LIFT OV BK 0.313 0.0 81722004 43554,380 3 4,994.0 4,855.0 35.15 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/16/1988 4 5,348.2 5,147.4 34.35 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/24/1995 5 5,634.6 5,383.6 34.78 MERLA GPD 1 12 GAS LIFT DMY RK 0.000 0.0 4/13/2003 1 6 5,735.0 5,466.1 34.63 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 9/16/1991 j LINER, 5,857-6.670N T0, 6,675 , ■ • • Alaska P.O, BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 3 Mr. Tom Maunder °~ ~ ~ ~ ,, Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 10 ~ ~ ~ ~ - ~ ~ . Anchorage, AK-99501 ~~~~7 ~'~~ ~ ~ 2 ~~ `~~~-~ Dear Mr. Maunder: Enclosed. please find a spreadsheet with a list of wells from the Kuparuk 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 AOGCG, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion 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. ConocoPhillips Well Integrity Projects Supervisor __ __ _ _ _ _ __ __ • ~ ~C~~~~~s Asa e Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant i op-off Report of Sundry Operations (10-404) Kuparuk Field Date Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbfs 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 12114/2007 2A-03 184-051 44'° na 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.2 10" 9/2412007 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-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1..75 12!14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12!5/2007 2A-11 186-003 SF SF na 11 12/5'!07 2A-92 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 9.75 .12/1412007 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 $' 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: DATE: 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, GIN J, Number Number PSI PSI Trip Code Code Code Passed GASorC¥CLE 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 1950680 96 70 70 P P OIL 2A-24 1931440 96 70 60 P P OIL 2A-25 1960620 Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1% [] 9o my Remarks: Surface Safet7 on 2A-12 had slow leak, valve to be serviced and retested MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Pull tubing Alter casing . Repair well 2. Name of Operator 5. Type of Well: X ARCO Alaska, Inc. -- 3. Address Plugging Perforate __ Other P. O. Box 100360, Anchorage, AK 99510 Development Exploratory Stratigraphic Service 4. Location of well at surface 1387' FSL, 53' FEL, Sec. 14, T11N, RSE, UM At top of productive interval 1257' FSL, 1298' FEL, Sec. 14, T11N, R8E, At effective depth 1270' FSL, 1498' FEL, Sec. 14, T11N, RBE, At total depth 1274' FSL, 1526' FEL, Sec. 14, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 123 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-11 feet 9. Permit number/approval number 86-3 10. APl number 50-103-20057 11. Field/Pool Kuparuk River Field/Oil Pool 6675 feet Plugs (measured) None 6256 feet Effective depth: measured 6 6 21 true vertical 6210 feet Junk (measured) None feet 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 2756' 12-1/4" Cemented Measured depth Tubing (size, grade, and measured depth) True vertical depth 106' 2782' 270 SX CS II 106' 800 SX CS III & 2782' 290 SX CS II 6088' 8-1/2" 200SXG&175SXCSI 6114' 5781' , osxc ss measured 6224' -6273', 6355'-6380' true vertical 5874'-5916', 5986'-6007' JUL 07 7995 Final WHTP = 4900 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2-7/8", 6.5#/ft. J-55 @ 5774, 2-3/8" 4.7#/ft N-80 @ 6308' Packers and SSSV (type and measured depth) PKR: baker DB @ 6287'~ PKR: CAMCO HR @ 5678'~ SSSV: CAMCO TRDP-1A-SSA @ 1807' stimulation or cement squeeze summary Fracture Stimulate 'A' Sands Intervals treated (measured) 6355'-6380' Treatment description including volumes used and final pressure 17.6 Mlbs 20/40, 73.2 Mlbs 16/20, 84.1 Mlbs 12/18 ceramic proppant. Prior to well operation 3 0 3 123 15 890 280 1462 21 O9 1044 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~ i Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1430 270 Service Form 10-404 Rev 06/15/88 Title Wells Superintendent SUBMIT I1~ DUPLICATE ARCO Alaska, Inc. A Subsidiary of Atlantic Richfield Company WELL' Di~SCRIPTION OF woRK 2A- 11 A' .Sand Re-Fracture OXTE. kONTI;[ACTOR / KEY PERSON 3/29/95 Dowell-Gallegos DAY PBTD (RKB) ' [L'AST T,kC~"'iRKB)- DATE TIME 0600 1020 1115 1230 1430 1700 LOG ENTRY IFIELD COST'EST. SSSV $172,657 KUPARUK RIVER UNIT WELL SERVICE REPORT _ Initial Pressures: Tbg = 1050#, 7" = 1200g, 9-5/8" = 600# IAFC/CC# - SCA# ACCUMULATED COST $178,452 Report }X}cItECK, THIS BLOCK IF SUMMARY iS CON'¥iNUED ON BACK Weather Pump 8 bbls down well to warm up lines and set tree saver. PT to 7800#. Pump breakdown stage at 15 BPM and 5100g. Pump total to 240 bbls. Pump scour stage using 2295# @ 1 ppg. Flush away w/44 bbls non XL SW. Breakdown and scour stage was 50#, delay XL gel SW (YF150D). SD and monitor pressures. ISIP = 1478#, FG = 0.69 psi/ft. Pump DataFrac @ 15 BPM and 4900#. SD and monitor pressures and perform calculations. FG = 0.69 psi lft, Closure time = 4.4 min, closure press. = 4000#. Increase pad vol by 250 bbls based on calculations. Start frae. Pump YF150D at 15 BPM and average pressure of 4700//. Pressure increased 800g .when 12/18 prop hit perfs. Dropped back down alter +__20 bbls. Pressure dropped to 4000,9 85 bbls ~into 8 ppg stage. Pressure increasing rapidly to 4900~ during 15 ppg stage. Called flush 8 bbls into 15 ppg stage. Cut rate t° 10 BPM and continue flushing to completion @ 10 BPM and 4700g. Flush 4 bbls short of top perf. Total proppant in formation = 168,951# (17690g 20/40, 73240g 16/20, 84051# 12/18). Total of 1500g of 12/18 proppant left in wellbore. Concentration at perfs = 13 ppg. Total of 1998 bbls fluid pumped (22 bbls diesel pumped in flush. 12 bbls past swab). Start RD Dowell. Bled 7" casing to 1300//. Dowell rigged down. Turned well over to DSO to be left SI. TemP: j~hin Factor Visibilit'y " tXt' coMeI ETEI I INCOI~IPLETE .... tail line to ensure it is open to tank. Low Pressure Test against master valve to 1700#. PT line to 7" to 4000#. QC fluids and prop. Prime turbines and pumps. Pump thru tattle MIRU DS frac equipment, Hot Oil, vac truck. Held safety meeting (15 people on location). KUPARUK FLUID LEVEL REPORT Fluid Level Shot Down: Date -~-~ · : CC: DS Engr. NSK Files. OP Engrg. Files Prod. Foreman SSSV~ GLM DV or GLV Casing ' ~__ Tubing CSG Press During Shot =___.___ # TBG Press During Shot =~# Reason For Shooting FL: To Determine Operating Valve Well Status: On COntinuous GL Operating CSG Press Comments: GL Rate, If Available) On Interm,~t GL On Time =' '"~, Min. MCFD Off Time= Hr. Mira- Delta Time From End Of On Cycle = Min. No GL ARCO Alaska, ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal # 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lA-5 Static Well Pressure Report 6-8-87 2T-13 PBU Well Pressure Report 7-11-87 2A-11 PBU Well. PressUre. Report 4-16,18-87 2U-13 Pressure Buildup Survey 4-25-87 2C-16 GLM Survey & Temp Gradiemt Survey 4-13-87 Anchoraoe Receipt Acknowledged: DISTRIBUTION: Date: BP Chevron MObil SAPC State of Alaska D&M Unocal ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 Transmittal # 5933 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-16 2T-12A 2A-il 3A-9 lA-1 3A-9 1H-3 3K-13 3K-14 3I-1 3F-15 CET/CEL 9-15-86 8181-8720 CET/CEL 9-27-86 4595-6644 CET/CEL 3-14-86 5800-6564 CET 7-26-86 2000-6299 CEL/CET 8-29-86 2708-7255 CET/CEL (After Squeeze) 7-31-86 2128-6039 CET 7-16-86 6891-7617 CET/CEL 8-17-86 6849-8455 CET/CEL 8-18-86 7215-8844 ' CET/CEL 1-24-86 7588-8887 CET/CEL 1-13-86 6600-7384 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil .SAPC B Unocal Vault (film) . Chevron ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfieldCompany -'--~--' STATE OF ALASKA ---'- ALAS. _ AND 'GAS CONSERVATION COM, ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 123 Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, Alaska 99510 Kuparuk River Unit 4. L~c.,~t _of. w I.La sudace I36'TipnFS'L';e531 FEE, Sec. 14, T11N, R8E, UM At top of productive interval 1257' FSL, 1298' FEL, Sec. 14, T11N, R8E, UM At effective depth 1269' FSL, 1497' FEL, Sec. 14, T11N, R8E, UM ,~o~1 depth FSL, 1526 FEL, Sec. 14, T11N, R8E, UM 11. Present well condition summary Total depth: measured true vertical 7. Well number 2A-11 8. Ap~o_v§l number 9. APl n~ja~l~er_ 2OO57 50-- 10. Pool Kuparuk River Oil Pool 6675 feet Plugs (measured) None 6256 feet 6621 None Effective depth: measured feet Junk (measured) true vertical 6210 feet Casing Length Size Cemented Measured depth True Vertical depth Conduct(:~:-' ?.06' 16" 270 SX CS II 106' 106' Surface 2782' 9-5/8" 800 sxCSIII & 2782' 2782' 290 sxCSI I Productions.. 6114 7" 200 sxCSG 6114' 5780' & 175 sxCSl Liner 813' 5" 120 sx Class G 5857'-6610' 5566'-6262' Perforation depth: measured 6244'-6273' ND 6333'-6343' MD (New Perfs) 6355'-6380' ND true vertical 5891'-5916' TVD 5966'-5975' TVD (New Perfs) 5985'-6006' TVD Tubing <siz~ _g~q, ar/cJ .kq;keaspre, d d,~p_tbb~ tz~ ,]~s), & 2-3/8" (16 jts) J-55, tbg w/tail @ 6309' Packers and SSSV (t~pe and measured depth) .~ HRP-1-SP pkr @ 5678', DP pkr @ 6287', & TRDP-1A-SSA SSSV @ 177,~C~!'~,_-[i 12. Stimulation or cement squeeze summary Intervals treated (measured) 6333'-6343' Treatment description including volumes used and final pressure Pe~f0Pate ~ith 4 ~-11/]6" thr~ fhg gt!n - }4 g~:;: pe?'~het 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 273 133 0 800 95 322 194 0 800 99 14. Attachments Daily Report of Well Operations Copies of Log,s and Surveys/~.~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-4'04 Rev.,-~-1-85 Title ? / Submit in Duplicate ARCO Alaska, Inc Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL .,ONTRACTOR REMARKS ~/~,._ 3 / IFIELD - DISTRICT - STATE OPERATION AT REPORT TIME //do /.2q$.-- Pood. [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ITemp' °F Chill Factor0F Visibility miles I Wind Vel. ARCO Alaska, Inc. Date- December 6 1989 Transmittal #: 7618 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk OperatiOns File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H- 1 4 Kuparuk Fluid Level Report 1 1 - 1 8 - 8 9 Casing 2 A - 1 1 Kuparuk Fluid Level Report 1 1 - 3 0 - 8 9 Tubing 1 G- 1 1 Kuparuk Fluid Level Report 1 2 - 2.8 9 Casing 1 Q- 13 Kuparuk Fluid Level Report I 1 - 3 0 - 8 9 Tubing 1 Q - 0 9 Kuparuk Fluid Level Report 1 1 - 3 0 - 8 9 Tubing Receipt DIST.RIBUTION: BP Chevron D&M Mobil ~'r State of Alaska Unocal STATE OF ALASKA ALA~,... ~,L AND GAS CONSERVATION COM, _.,,on APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~_ Alter casing ~- Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing '- Amend order ~_ Perforate _~ Other - 2. Name of Operator ARCO Alaska, Tnt_ 3. Address P.O. Box 100360, Anqhgrage: Ala_~ka 99.~10l 4. Location of well at surface 1387' FSL, 53' FEL, Sec. 14, TllN, R8E, UM At top of productive interval 1257' FSL, 1298' FEL, Sec. 14, T11N, R8E, UN At effective depth 11. 5. Datum elevation (DF or KB) ,~VD ~ 9'2 6. Uni or Property name Kuparuk River Unit 7. Well number 2A-II 8. Permit number 86-3 9. APl number 50-- 103 - 20057 feet 1269' FSL, 1497' FEL, Sec. At total depth 1274' FSL~ 1526 FEL. Sec. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14, T11N, R8E, UM 14. T11N. RP~F_ IIM 6675 feet 6256 feet 6621 feet 6210 feet 10. Pool Plugs (measured) None Junk (measured) None Casing Length Size Cemented Measured depth ~ue Vertical depth 16" 270 SX CS II 106' 106' 9-5/8" 800 sxCSIII & 2782' 2782' 290 sxCSII 7" 200 sxCSG 6114' 5780' & 175 sxCSl 5" 120 sx Class G 5857'-6610' 5566'-6262' ConduCtor 106' Surface 2782' Production 6114 Liner 813' Perforation depth: measured true vertical 6244'-6273' MD 6355'-6380' MD 5891'-5916' TVD 5985'-6006' TVD ~bing (size, grade and measured depth) 2-7/8" (182 jts), J-55 & 2-3/8" (16 jts) J-55, tbg w/tail @ 6309' Packers and SSSV (type and measured depth) HRP-1-SP nkr ¢ ~678' BP n~ m ~9~7' ~. TDnD la CCa ccc~t ~ 12.Attachments Dbscription sumr~a~ oF~;op~s~F~_' be~ailb~%pe~iio"'n~'pro~jr'"a~rr~ '-Z '~d~ sketch 13. Estimated date for commencing operation November 1, 1986 14. If proposal was verbally approved Name of approver R. Douglas 15. I hereby certify that the foregoing is true and correct to the besf}bf:'rny knowledge '~ "~ ~ Title Sr. Operations Engineer Date Conditions of approval Commission Use Only Notify commission so representative may witness I Approval No. ,~ Plug integrity L~ BOP Test ~ Location clearanceJ / by order of ' Commissioner the commission Date//- Form 10-403 Rev 12-1-85 * Submit in triplicate SUNDRY NOTICES INTENT It is proposed that t-he A Sand in Kuparuk Well 2A-11 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. PROPOSED INTERVALS (MD)- 6333' - 6343' SPF: 4 ANTICIPATED START DATE' November 1, 1986 " ~"~ .... STATE OF ALASKA ~ -~ ~ ALASKA u,- AND GAS CONSERVATION CL,,vIMISSlON 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. 86-3 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20057 4. Location of well at surface 9. Unit or Lease Name 1387' FSL, 53' FEL, Sec.14, TllN, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1257' FSL, 1298' FEL, Sec.14, T11N, RSE, UM 2A-11 At Total Depth 11. Field and Pool 1274' FSL, 1526' 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 01/21/86 01/27/86 01/30/86*I N/A feet MSL I · 17. Total Depth (MD+TVD) .118. PIug Back Depth (MD+ l-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 6675'MD,6256'TVD 6621 'MD,6210'TVD YES~ NO []I 1807 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, RFT, CET, Gyro 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" 270 sx CS II 9-5/8" 36.0# J-55 Surf 2782' 12-1/4" 800 sx CS Ill & 290 sx CS II 7" 26.0# J-55 Surf 6114' 8-1/2" 200 sx Class G & 175 s.~ CS I 5" 18.0# L-80 5857' 6670' 6-1/8" 120 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) 6244' - 6273' w/12 spf 2-7/8" 6324' 5692' & 6302' 6355' - 6380' w/6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production 1 Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ 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 ,. ....... Submit in duplicate~~~r Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & well perforated 3/17/86. WC1/011 CONTINUED ON REVERSE SIDE 29, NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A ,. GEOLOGIC MARKERS TRUE VERT. DEPTH 5891' 5918' 5949' 6087' 30. FORMATION TE .STS MEAS. DEPTH 6244' 6276' 6313' 6476' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. DEPTH HYDRO.PRESSURE SHUT-IN PRESSURE 6378.0' .... 6375'0' 4002.8 psi. 3594.4 psi 6366.0' 3994.0 psi 3556.0 psi 6363.0' 3995.0 psi 3555.6 psi 6337.0' 3978.0 psi 3543.8 psi 6322.0' .... 6269.0' 3943.1 psi 3582.8 psi 6259.0' 3941.8 psi 3587.6 psi 6249.0' 3937.0 psi 3928.4 psi 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. ItEm 27: MEthod of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: tf no cores taken, indicate "none". Form 10-407 Well Hi.tory - Initial Report- Dally Prepare and submit the "lniflM RM~I' on the first Wednesday after a well is spudded or workover operations are st-fred. Dally wo~ prior to spudding should be summarized on the form giving inclusive dates only. I County, Garish or borough I Notch Slope Borough Field Kuparuk Pul.var iL,,. or unit ADL 25570 I Au~. or W.O. no. [Title ~ 904309 I Completion Nordic L API 50-103-20051 State District Alaska Alaska IWell no. Ophir ]ARCO W.I. ARCO Alaska, Inc. $1=~ddld or W.O.. bl~ll~ IDItt JHou, P~tor Itltu. If · W.O. .. COmpZe~ 3/11/86 1930 hrs. 3713/86 3/14/86 Corollate meora for each day regorted 5" @ 6670' 5657' BP, TOC @ 5757', Ctrc Co bal sys 12.1 pp$ mud &ccepc ris @ 1930 hfs, 3/11/86. ND tree, ~ & Cst BOPE ce. 3500 psi. TsC 7" Co 3500 psi. RIR w/BP reCrv'$ Cl. Dtsp1 diesel co mud, circ co hal sys. 5" @ 6670' 5753' CmS, TOL @ 5857', Prep co drl cmo 12.1+ ppg gel mud RIH w/3½" DP & PB retrv'g el, tel BP & POH. RIH w/6-1/8" bic & csg scrpr, tag cmo @ 5743'. Prep co drl 114' cms on TOL. 5" @ 6670' 6563' LC, Ctrc well cln Wt. 12.1+, PV 12, YP 9, PH 10.5, Sol 18 Wsh cmo f/5750'-5756', drl cmc co 5853', tag TOL. Ctrc well cln, cst TOL Co 1000 psi, POOH. RIH w/eftA & 3~" DP, Cas TOL, drl cmC in lnr f/5853'-5856'. RIH, tag & drl cmo f/6507'-6563', Cas LC, circ well cln. 56.24% RECEIVED APR 1 7 19BB Nas~a Oil & Gas Cons. Com?ssion Anchorage The above il cormot For form preparltlon Ind di~%dbutlMt, Ne Procedurel Manual, Section 10, Drilling, P~# 8~ and 67. IT[tie Drtlltn$ Superintendent ARCO Oil and Gas ComPany Daily Well History-Final Report Inlmlctionl: Prepare and submit the "Flnll Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final RllN~rt" 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 ref3reaentetlve 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 Alaska Field North Slope Borough State Alaska I County or Parish Lease or Unit I Well no. Kuparuk River ADL 25570 I 2A-Il Auth. or W.O. no. ]Title AFE 904309 I Completion Nordic 1 AP1 50-103-20051 Operator ] A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun l Date Complete I 3/11/86 Date and depth es of 8:00 a.m. 3/15/86 thru 3/17/86 Complete record for each day reported I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well our I Prior status If a W.O. 1930 hrs. 5" @ 6670' 6563' PBTD, 6324' TT, RR 6.7 ppg Diesel Circ hole cln, tst lnr to 1000 psi, POE. RU SOS, rn CET f/6563'-5798', rn gyro f/6563'-surf. RIH w/4-1/8" bit & scrpr, displ mud in hole w/ 12.1 ppg NaBr, POH w/3½" DP. RU SOS, perf 6244'-6273' w/12 SPF & 6355'-6380' w/6 SPF. Rn gage ring/JB to PBTD. Rn 5" DB pkr on WL, set pkr @ 6287', RD SOS. RU & rn 2-3/8", 4.7#, J-55 EUE 8RD tab & 2-7/8", 6.5#, J-55 EUE, 8RD AB mod tbg. Chg out 2-7/8" 8-RD couplings to AB Mod as RIH. Tst tbg & ann w/2500 psi. Tst SSSV & orifice w/1000 psi. Shear out OEJ, re-lnd & cst hgr. Displ well to diesel.~ Set BPV. RR @ 0030 hfs, 3/17/86. SSSV @ 1807', HRP pkr @ 5692' DB Pkr @ 6302' 6317' TT @6324' , "D" Nipple @ RECEIVED APR 1 7 1986 ~laska 0il & Gas Cons. Commission Anchorage Old TD Released rig 0030 hrs. Classifications (oil, gas, etc.) Oil ProdUcing method Flowing Potential test data New TO ] PB Depth , 6563 PBTD 3/17/86 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gal per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected The above is correct Signature I Date ITitle I For form preparation and ~lletributlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent 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 04-01-86 TRANSMITTAL ~ 5612 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hole: One * of each 2A-1%5" DIL/SFL-GR ~2" DIL/SFL-GR '~5" Den/Neu-GR ~2" Don/Nou-GR ~5" Don/Neu-GR 2" Den/Neu-GR Cyberlook ~RFT Log - 5" DIL/SFL-GR 2" DIL/SFL-GR ~"5" Den/Neu 2" Den/Neu Den/Neu ~-2" Den/Neu ~rlCyberlook 3i_~-~'-~DiL/SFL_GR '~2" DIL/SFL-GR "~5" Den/Neu 2" Den/Neu ~-~ 5" Den/Neu '~'~" Den/Neu · "'~(Cyberlook 3I-2-.~'"5" DIL/SFL 2" DIL/SFL '~5" Den/Neu ~'~2" Den/Neu '~5" Den/Neu m'2" Den/Neu ~-~Cyberlook (poro) (poro) (raw) (raw) (poro) (poro) (raw) (raw) (poro) {poro) raw) raw) (poro) (poro) (raw) (raw) 01-28-86 Run #1 6113-6664 01-28-86 Run #1 6113-6664 01-28-86 Run #1 6113-6639 01-28-86 Run #1 6113-6639 01-28-86 Run #1 6113-6639 01-28-86 Run #1 6113-6639 01-28-86 Run #1 6113-6639 01-28-86 Run #1 6249-6378 02-02-86 Run #1 1000-8406 02-02-86 Run #1 1000-8406 02-02-86 Run #1 7550-8380 02-02-86 Run #1 7550-8380 02-02-86 Run #1 7550-8380 02-02-86 Run #1 7550-8380 02-02-86 Run #1 7550-8350 01-26-86 Run #1 2096-8076 01-26-86 Run #1 2096-8076 01-26-86 Run ~1 5600-8050 01-26-86 Run #1 5600-8050 01-26-86 Run #1 5600-8050 01-26-86 Run #1 5600-8050 01-26-86 Run #1 7400-7832 01-18-86 Run #1 1800-8546 01-18-86 Run #1 1800-8546 01-18-86 Run #1 8000-8521 01-18-86 Run #1 8000-8521 01-18-86 Run #1 8000-8521 01-18-86 Run #1 8000-8521 01-18-86 Run #1 8200-8500 Receipt Acknowledged: State of AK*bl/se Rathmell*bl Drilling*bi D & M*bl ARCO Alal~ka. inc. ~ · Subs~diar~f ot AtlanticRictl/ieldComl3an¥ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COiv~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. 86-3 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20057 4. Location of well at surface 9. Unit or Lease Name 1387' FSL, 53' FEL, Sec.14, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 2A-11 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi l Pool 123' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/21/86 01/27/86 01/30/86* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MEH-TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6675 'MD 6221 'MD YES ~X NO [Z] 1807 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CNL/Cal, RFT, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEiWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 106' 24" 270 sx CS II 9-5/8" 36.0# J-55 Surf 2782' 12-1/4" 800 sx CS III & 290 sx CS II 7" 26.0# J-55 Surf 6114' 8-1/2" 200 sx Class G & 175 sx CS I 5" 18.0# L-80 5857' 6670' 6-1/8" 120 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) 6244' - 6273' w/12 spf 2-7/8" 6324' 5692' & 6302' 6355' - 6380' w/6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST ,,, Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ I - Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIV,rr) APRO 4 ]986 Form 10-407 * NOTE: Tubing was run & well perforated 3/17/86. DAM2/WC03 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate~~ 29. NAME To be submitted w~ GEOLOGIC MARKE'RS MEAS. DEPTH .~n gyro is recei TRUE VERT. DEPTH /ed. 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RFT data to be submitted when received. 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 Signed I~b~ ~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 2/12/86 2A-11 Arctic Pak well w/175 sx CS I & 60 bbls Arctic Pak. r' ll~ng ~uperintendent z D~te ARCO AlasKa, Inc. Post Office Bo~ 100360 Anchorage. Alaska 99510-0360 Telepttone 907 276 1215 ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 03-04-86 TRANSMITTAL # 5588 Transmitted herewith are the following item~. Please acknowledge receipt and return one signed copy of this transmittal. OH Lis Tapes Plus listings/ SCHL/ One of each '"'~ 3N-4 "'3N-~ ' '"~ 3N-2 '"3J-16 ~3I-5 ~z-4 3I-3 ~2A- 11 ~2A-10 ~ 2A-9 02-14-86 REF #71279 02.-07-86 REF #71266:~ 01-27-86 REF #71272~ 02-15-86 REF #71278_- 02-09-86 REF #71273~ 02-02-86 REF #71239C. 01-26-86 REF #71242 01-28-86 REF #71243~ 02-06-86 REF #71244~ 02-17-86 REF #71280~ Receipt Acknowledged: ~ $~TE..OF - .__~.z. : .... ARCO AII$#I. Inc. ,I · Sut~stcltmry o! Atl·f~ticRichfiel~lCompen,f AtlanticRichfieldCompany .~, Dally Well History-Initial Report Inatructiorle: 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 I County or Parish Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no, ITitle / AFE 904309 North Slope Borough IState ADL 25570 Drill Alaska JWell no, 2A-11 Nabors 26E API 50-103-20057 Operator ARCO Alaska, Inc. Spudded or W.O, begun IDate Spudded I 1/21/86 1/22/86 Date and depth as of 8:00 a.m. 1/23/86 1/24/86 Complete record for each day reported I A.R.Co's W,I. J Hour IPrior status if e W,O. 1/21/86 0430 hrs I 16" @ 106' 225', (119'), Drlg 8.6 ppg Accept rig @ 2030 hrs, 1/20/86. NU diverter sys. Spud well @ 0430 hrs, 1/21/86. Drl 12¼" hole to 225'. 16" @ 106' 2800', (2694'), Rn'g 9-5/8" csg Wt. 9.1+, PV 11, YP 17, PH 9, WL --, Sol 6 Drl & surv 12¼" hole to 2800', 14 std short trip, CBU, TOH. RU & begin rn'g 9-5/8" csg. 971', .4°, S54.8W, 971TVD, 2.4 VS, 3.5S, 2.2W 1483', .7°, S55.8W, 1483 TVD, 6.6 VS, 6.38, 6.3W 1953', .7°, S22.8W, 1953 TVD, 10.4 VS, 10.7S, 9.9W 2487', .4°, S53.8W, 2487 TVD, 13.8 VS, 14.68, 13.0W 2780', .5°, S 8.8E, 2780 TVD, 14.7 VS, 16.7S, 13.8W 9-5/8" @ 2782' 2800', (0'), PU BHA Wtr in pits Fin rn'g 70 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 2782', FC @ 2701'. Cmt w/800 sx CS III & 290 sx CS II. Bump plug. ND diverter, NU & tst BOPE. PU BHA & TIH. ~ 2780', .5°, S8.8E, 2780 TVD, 14.7 VS, 16.7S, 13.8W 9-5/8" @ 2782' 4430', (1630'), Drlg Wt. 9.1, PV 11, YP 8, PH 8.5, WL 8.8, Sol 5 TIH, tst csg to 2000 psi. DO flt equip, cmt & 10' new hole. Conduct formation tst to 12.5 ppg EMW. RIH & Navi-Drl 8½" hole to 4430'. 3107', .3°, S 1.2 W, 3106.9 TVD, 14.7 VS, 18.9S, 13.7W 3518', 3.4°, N84.80W, 3517.8 TVD, 19.7 VS, 22.7S, 18.5W 3922', 14.3°, S80.20W, 3916.2 TVD, 82.6 VS, 28.2S, 81.2W 4333', 27.10°, S89.2 W, 4300.4 TVD, 225.3 VS, 39.9S, 223.7W 56.24% The above is correct Signature For form Creparation-,~rnd d~strib-~'~on, see Procedures Manu~l, Section 10, Drilling, Pages 86 and 87, Date Title Drilling SuperinteB~ent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during dritling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequen.~ially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final comlDletion. Report offimal or repr~esentative test on "Final" form, 1) Submit "lntert111" sheets when tilled 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 folrowing setting of oil string until completion. District County or Parish State Alaska North Slope Borough Field ILease or Un t Kuparuk River I ADL 25570 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 1/25/86 thru 1/27/86 1/28/86 1/29/86 The above is correct Signature For for~l pre~-aratTon and ~strib-utio'~ see Proceaures Manual SeCtion Drilling, Pages 86 and 87 Alaska Well no 2A-11 7" @ 6114' 6300', (1870'), Drlg Wt. 12.4, PV 29, YP 20, PH 9.0, WL 6.0, Sol 18 Drl & surv 8½" hole to 6130', short trip, C&C, POOH, LD 5" DP. Chg top rams to 7" & tst. RU & rn 143 jts, 7", 26#, BTC csg w/FS @ 6114', FC @ 6028'. Cmt w/200 sx Cl "G". Displ using rig pmps, bump plug. ND BOPE, instl 7-1/6" x 13-5/8" spool. Tst pack-off to 3000 psi. NU & tst BOPE. RIH to FC, tst csg to 3000 psi. DO FC, cmt, FS + 10' new formation. Conduct formation tst to 13.5 ppg EMW. Drl to 6215', cut mud f/ll.8 ppg to 11.2 ppg & circ around. Drl 6-I/8" hole to 6300'. 4555', 30.3°, N88.8W, 4495.1TVD, 331.9 V$, 39.5S, 330.3W 5121', 33.9°, S86.2W, 4962.9 TVD, 650.3 VS, 60.4S, 648.0W 5748', 34.8°, S86.2W, 5479.8 TVD, 1005.2 VS, 83.9S, 1002.1W 6045', 33.2°, S85.2W, 5726 TVD, 1171.2 VS, 96.4S, 1167.7W 7" @ 6114' 6675', (375'), Logging Wt. 12.7, PV 24, YP 14, PH 8.5, WL 5.4, Sol 26 Drl to 6675', short trip, C&C, POOH. RU Schl, begin logging DIL/SFL/GR/SP/FDC/CNL/CAL. 6045', 33.2°, S85.2W, 5726 TVD, 1171.2 VS, 96.4S, 1167.7 5" @ 6670'-5857' 6675', (0'), POOH Wt. 12.7, PV 24, YP 9, PH 8.5, WL 5.5, Sol 19 Rn DIL/SFL/GR/SP/FDC/CNL/CAL f/6675'-6114'. Rn RFT w/16 sets selected intervals. TIH, rm 6320'-6675', C&C, POOH. RU & rn its + 2 mkr its, 5", 18#, L-80 LTC lnr f/5857'-6670' w/FC @ 6621', FS @ 6670' TOL @ 5857'. Cmt lnr w/120 sx Cl "G" w/l% FL-19, .5% CD-31, .3% A-2. Rel rn'g tl & POOH. 6675', 33.2°, S85.2W, 6253.2 TVD, 1516 VS, 125.3, 1511.5 (Projected) Date ITiue I Drilling Superintendent AtlanticRichfieldCompany" Daily Well History-Final Report Inetrl~ctionl: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "FInel Rep~t" 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 "FInel Report" form may be used for reporting the entire operation if space is available. DistrictAlaska County or Parish Field Lease or Unit Kuparuk River ADL 25570 Auth. or W.O. no, T t e AFE 904309 Drill North Slope Borough Accounting cost center code State Alaska lWetl no. 2A-11 Nabors 26E Operator A.R.Co. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 1 / 21/86 Date and depth Complete record for each day reported as of 8:00 a.m. ]./30/86 API 50-103-20057 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior stetus if a W.O. 0430 hrs. 5" @ 5857'-6670' 6675', (0'), RR Diesel TIH w/csg scrpr, tag cmt @ 5757', TOH. PU BP, TIH, set BP @ 5657', TOH, LD DP. Displ top 2100' of well to diesel. ND BOPE, NU & tst tree. RR @ 0130 hrs, 1/30/86. Move rig to DS 2A-lO. Did TD New TD PB Depth 6675 TD 6621 PBTD Released rig Date Kind of rig 0130 hrs. 1/30/86 Rotary Classifications (oil. gas, etc.) Type completion (single, dual, etc.) 0il 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 % CDR 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 ARCO Alaska, Inc. Post Office B~.. ]100360 Anchorage, AJaska 99510-0360 Telephone 907 276 1215 February 20, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2A-11 Dear Mr. Chatterton. Enclosed is the Well Completion Report for 2A-11. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the well has been completed and the gyroscopic survey is run. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Eng~ineer JG/tw GRU13/L173 Enclosures ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION COMMISSION 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. 86-3 3. Address 8. APl Number P. 0. Box 100560, Anchorage, AK 99510 50-- 103-20057 4. Location of well at surface 9. Unit or Lease Name 12;87' FSL, 53' FEL, Sec.14, TllN, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2A-11 At Total Depth 1 1. 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' 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 16. No. of Completions 01/21/86 01/27/86 01/30/86I N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6675'MD 6221 'MD YES [] NO [z]XXI N/A feet MD 1500' (approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP/FDC/CNL/Cal , RFT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 106' 24" 270 sx CS II 9-5/8" 36.0# J-55 Surf 2782' 12-1/4" 800 sx CS Ill & 290 s> CS II 7" 26.0# J-55 Surf 6114' 8-1/2" 200 sx Class G 5" 18.0# L-80 5857' 6670' 6-1/8" 120 sx Class C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OIL RATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED.1~ 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 · Form 10-407 DAM/WC20 Submit in duplicate Rev. 7-1-80 . CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS 30. FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH 31. LIST OF ATTACHMENTS None Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each Phase. RFT data to be submitted when received. 32. i hereby certify that the foregoing is true and correct to the best of my knowledge Signed____ ~) ~.~ Title Associate Engineer Da~,~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Io§ 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 II III I III III I I I II SUB. SURFACE DIRECTIONAL URVEY I~UIDANCE [~ONTINUOUS [~OOL Company Well Name ARCO ALASKA INCORPORATED i iii i il iii WELL 2A-11 (1387'~SL~ 5_3'FEL, S14, Tll.N.~ RSE) _ 1, , Iii i i Field/Location ,~u~,~u~,, Ng~,~ ST,,O~,g, ,,AT,^SF,_A_ Job IRefer.,.ence No_. 71417 Loathed By; MURTLAND Date_ 20-APRIL-1986 Comp, uted By: BOLAM GCT OIRECTIgNAL SURVEY COSTOMER LISTING FOR ARCO ALASKA, INC. ZA-11 KUPARUK NORTH SLOPEgALASKA SURVEY DATE: 1~ MAR 86 ENGINEER: M~RTLAND METHODS OF.COMPUTATION TOOL LOCATION: TANGENTIA'L- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: MORIZ. DIST. r: i~CTEO ONTO A'T~ AZIMUTH OF SOUTH 86 DES 58 MI'N WEST COMPUTATION DATE: 20-APR-86 PAGE I ARCO ALASKA, INC. DATE OF SURVEY: 1~ MAR 86 2A-11 K~PAR~K NORTH SLOPEtALASKA KELLY BUSHING ELEVATION: =NGINEER: MURTLAND 123.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTIC6L VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HgRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 100.00 '~0. O0 ).oo ~uO.O0 500'00 600.00 700.00 BO0.O0 900.00 0.00 -123.00 0 0 99.99 -23.0'1 0 4 199.99 76.99 0 17 299.99 176.99 0 29 399.99 276.99 0 30 ¢99.98 376.98 0 18 599.98 4?6.98 0 18 699.98 576.98 0 17 ?99o97 6?6.9? 0 20 899.97 775.97 0 29 N 0 0 E N 68 29 E S 34 ~8 E S 63 19 E S 58 53 E S 61 2 E S 14 51 E 512 gE S 6 22 E S 68 11E 0.00 0.00 0.00 N 0.00 E 0.66 0.65 0.41 S 0.64 W 0.40 0.1¢ 0.65 S 0.37 W -0.13 0.04 1.03 S O.1B E -0.87 0.10 1.~6 $ 0.94 E -1.61 0.25 1.91 S 1.71 E -2.02 0.21 2.43 S 2.15 E -2.18 0.08 3.23 S 2.35 E -2.24 0.30 3.95 S 2.~5 E -2.57 0.14 4.37 S 2.81 E O. O0 N 0 0 E 0.76 S 57 28 W 0.7¢ S 29 47 W 1.05 S 10 3 E 1.74 S 32 54 E 2.57 S 41 48 E 3.14 S ~.! 36 E 3.99 S 36 3 E 4.65 S 31 47 E 5.19 S 32 42 E 1000.00 999.97 876.97 1100.00 1099.97 976.97 1ZO0.O0 1199-96 1076.96 1300-00 1299.96 1176.96 1400.00 1399.95 1276.95 1500.00 1499.94 1376.94 1600.00 1599.93 1476.93 lYO0.O0 1699-~2 1576.92 0 26 0.26 0 17 0 ¢0 0 49 0 46 0 42 0 40 1800.00 1799.92 1676.92~ 0 16 1900.00 1899.91 1776.91 0 ~3 S 59 2Z E S 66 35 E S 6~ ~4 E S 52 6 E S 62 30 E S 76 34 E N BZ 46 E S 69 22 E S 4~ 24 E S 41' 55 E -3.29 0.11 -3.94 0.17 -4.62 0.16 -5.41 0.31 -6.46 0.17 -7.80 0-51 -9.06 0.05 -10.28 0.89 -10.90 1.80 -11.65 0.10 4.75 S 3.55 E 5.09 S 4.22 E 5.39 S ~.92 E 5.88 S 5.73 E 6.61 S 6.82 E 7.18 S 8.19 E 7.17 S 9.~5 E 7'19 S 10.68 E 7.83 S 11.33 E 8.44 S 12.12 E 5.93 S 36 45 E 6.61 S 39 38 E 7.29 S ~2 22 E 8.21 S 4q 14 E 9.50 S 45 53 E 10.89 S ~8 45 E 11.87 S 52 48 E 12.87 S 56 3 E 13.77 S 55 20 E 14.76 S 55 B E ZO00.O0 1999.90 1876.90 2100.00 2099.89 1975.89 IZ On. O0 2199.87 2076.87 L ,00 2299.86 2176.86 Z ,.00 2399,85 2276.85 2500.00 2499.84 2376.84 2600.00 2599.83 2476.83 2700.00 2699'83 2576.83 2800.00 2799.83 2676.83 2900.00 2899.82 2776.81 0 55 S 33 ~ E I I S 43 4 E 0 59 S 45 16 E 0 ?,9 S 53 17 E 04.5 S 58 3 E 0 32 S 51 34 E 045 S 55 11E 0 21 S 46 21 E 0 14 S 14 46 E 0 39 S 28 21 E -12.39 0.21 -13.39 0.11 -1,6.55 0.31 -15.68 0.20 -16.79 0.12 -17.75 0-93 -18.69 0.12. -19.58 1.15 -19.66 0.25 -20.09 0.53 9.58 S 12.91 E 10.91 S 13.99 E 11.21 S 15.22 E 13.25 S 16.40 E 13.97 S 17.56 E 14.82 S 18.56 E 15.~3 S 19.54 E 16.21 S 20.47 E 16.63 S 20.57 E 17'25 $ 21-04 E 16.08 S 53 24 E 17.74 S 52 2 E 19.51 S 51 15 E 21.09 S 51 4 E 22.43 S 51 30 E 23.75 S 51 23 E 24.89 S 51 42 E 26.11 S 51 36 E 26.46 S 51 2 E 27.20 S 50 39 E 3000.00 2999.82 2876.82 0 16 3100.00 3099.81 2976.81 0 37 3200.00 3199.81 3076'81 0 37 3300.00 3299.80 3176,80 0 18 37.00.00 3399.80 3276.80 0 38 3500.00 3~99.77 3376.77 2 Z~ 3600.00 3599.34 3476.3~ 7 17 3700.00 3697.95 3574.95 11 16 3800.00 3795.76 3672.76 12 11 3900.00 3893.38 3770.38 13 27 S 53 47 E -20.29 0.77 S 13'56 E -20.74 0.33 S ZO 20 W -Z0.63 0.41 S 4 55 E -20-31 0,76 S 21 37 W -20.07 0.35 S 86 57. W -18.61 5.18 N 80 56 W -9.87 4.35 S 84 46 ~i 6.45 3.97 S 79 25 W 27.17 0.21 S 79 29 W 48.61 3.40 17.93 S 21.27 E 18.76 $ 21.77 E 19.88 S 21-71 E 20.53 S 21.43 E 21.55 S 21.24 E 22.27 $ 19-82 E 21.15 S 11.01 E 20.54 S 5.36 W 23.87 S 25.94 W 27.91 S ~7..19 W 27.82 S 49 52 E 28.74 S 49 14 E 29.~4 S 47 30 E 29.68 S 46 13 E 30.26 S 44 35 E 29.81 S 41 40 E 23.84 S 27 29 E Il. Z3 S 14 37 W 35.25 S 47 22 W 54.83 S 59 24 W COMPUTATION DATE: ZO-APR-86 PAGE 2 ARCO ALASKA, IqC. DATE DF SURVEY: 14 M~R 86 2~-11 KUPaRUK NORTH SLOPEtALASKA KELLY BUSHING ELE~'AT[gN: ENGINEER: MURTLAND 123.00 ~T INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DSPTH TRUE SO'B-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN. VERTICAL DOGLEG RECTANGULAR CDDRDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FE~T DEG MIN 4000.00 3990.14 3867.14 15 30 4100.00 4085.63 3962.63 19 22 4~nO.O0 4178.$0 4055.60 23 47 3.00 4268.81 4145.81 26 66 '~0'00 6357.67 4234.67 27 51 4500.00 6445.97 4322.97 28 63 4600.00 6532.23 4409,23 32 13 4700.00 6614.95 4491.95 35 60 4800.00 4696.28 6573.28 35 22 4300.00 6777,91 4654.91 35 10 S 80 15 W S 83 11W S 82 36 W S 87 5 W N 88 0 W N 87 1W S 88 56 W S 84 4~ W S 83 55 W 584 6 W 73.68 2.28 103.16 4.50 139.83 4.52 182.90 2.70 228.70 2.50 275.36 3.38 325.79 6.28 381.94 2.30 440.05 0.30 497.72 0.28 32.45 S 72.06 W 79.03 S 65 45 W 36.44 S 101.37 W 107.72 S 70 13 W 40.93 S 137.86 W 143.81 S 73 27 W 45,13 S 180.75 W 186.31 S 75 58 W 45.62 S 226.60 W 231.14 S 78 36 W 42.94 S 273.47 W 276.82 S ~1 4 W 42.28 S 324.01 W 326.75 S 82 33 W 45.29 S 380.07 W 382.76 S 83 12 W 51.28 S 437.95 W 440.94 S 83 19 W 57.35 S 495,38 W 498.69 S 83 23 W 5000.00 ~859.71 4736.71 35 9 5100.00 4941.69 6818.69 34 12 5200.00 5024.69 6901.69 34 6 5300.00 5107.35 4984,35 34'17 5400.00 5189.88 5066.88 34 ~6 5500.00 5272.33 5169.33 34 30 5600.00 5354.67 5231.67 3~ 36 5700.00 5436.91 5313,91 34 41 5800.00 5519.18 5396.18 34 32 5900.00 5601-57 5478.57 34 ZO S 84 15 W S 84 54 W S 85 25 W S 85 23 W S 85 6 W S 84 40 W S 84 33 W S 84 24 W 555.18 0.26 612.39 2.46 668.15 0.6% 724.40 0.29 780.85 0-30 837.40 0.24 894.09 0.18 950.93 0.58 0.48 0.30 S 83 51 W 1007.71 S 83 22 W 1064.29 63.16 S 552,61 W 556.21 S 83 28 W 68.72 S 609.60 W 613.46 S 83 34 ~' 73.18 S 665.20 W 669.21 S 83 43 W 77.72 S 721.30 W 725.47 S 83 51 W 82.36 S 777.57 W 781.92 S 83 57 W 87.44 S 833.93 W 838,50 S 86 0 W 92.74 S 890.43 W 895.24 S 84 3 W 98.14 S 947.05 W 952.t3 S 84 5 W 103.96 S 1003.61 W 1008.98 S 8~ 5 W 110'30 5 1059.94 W.'1065.66 S 84 3 N' 6000.00 5684.62 5561.62 33 8 S 82 57 W 1119.87 6100.00 5768.54 5645.64 32 33 S 83 I W 1173.95 6Z.on. O0 5853.13 5730.13 31 40 S 86 42 W 1227.37 63/ ,00 5938.30 5815.30 31 55 S 89 6 W 1279.76 0.90' 0.58 2.99 1.26 1.85 5.23 0.00 0.00 116.89 S 1115,24 W 1121.35 S 84 0 W 123.$2 S 1169.04 W 1175.56 S 83 57 W 128.85 S 1222.26 W 1229.03 S 83 58 W 130.57 S 1274.63 W 1281,30 S 84 9 W 130.46 S 1327.93 W 1334.32 S 84 23 W 127.15 S 1381.45 W 1387,29 S 84 44 W 119.15 S 1433.53 W 1638.67 S 85 14 W 113.05 S 1472.56 W 1476.87 S 85 36 W COMPUTATION DATE: 20-APR-8$ P~GE 3 ARCO ALASKA, INC. DATE OF SURVEY: 16 MAR 86 2a,-11 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: MURTLAND 123.00 FT INTERPOL&TED VALUES FOR EVEN 1000 FEET DF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MXN DEG MIN' VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET. FEET FEET DEG MIN 0.00 0.00 -123.00 0 0 1000.00 999.97 876.97 0 26 2oQO'O0 1999.90 1876.90 0 55 0.00 2999.82 2876.82 0 26 .~0.00 3990.14 3867.1¢ 15 30 5000.00 4859.71 4736.71 35 9 6000.00 5684.62 5561.62 33 8 6675.00 6256.05 $133.05 31 46 N 0 0 E 0.00 S 59 22 E -3.29 S 33 4 E -12.39 S 53 47 E -20.29 S 80 15 W 73.68 S 8~ 15 W 555.18 S 82 57 W 1119.87 N 81 6 W 1~76.~6 0.00 0.11 0.21 0.77 2.28 0.26 0°90 0.00 0,00 N 0,00 E 0,00 N 0 0 E 4,75 S 3,55 E 5,93 S 36 45 E 9,58 S 12,91 E 16,08 S 53 24 E 17,93 S 21,27 E 27,82 S 49 52 E 32,~5 S 72.06 W 79,03 S 65 45 W 63.16 S 552,61 W 556,21 S 83 28 W 116.89 S 1115.24 W 1121.35 S 84 0 W 113.05 S 1472.54 W 1476.87 S 85 36 W COMPUTATION DATE: 20-APR-85 PAGE 4 ARCO ALASKA, INC. DATE DF SURVEY: 14 MaR 86 2a-il KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: MURTLAND 123.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES H3RIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH. SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH DEPTH DEPTH DEPTH 3EG 4IN DEG MI4 FEET DEG/ZO0 FEET FEET FEET DEG MIN 0.00 23.00 ''3.01 ~3.01 423.01 523.02 $23.02 713.01 823.03 0.00 -123.00 0 0 23.00 -100.00 0 46 123.00 0.00 0 g 223.00 100.00 0 18 323.00 200.00 0 Zg 423.00 300.00 0 30 523.00 400.00 0 26 623.00 500.00 0 29 723.00 600.00 0 26 823.00 700.00 0 18 N 0 0 E S 53 48 W S 68 59 E $ 39 59 E S 62 11E S 58 37 E S 60 I E S 14 11 E S 9 15 E S 11 2 E 0.00 0.00 0.00 N 0.00 E 0.40 2.25 0.35 S 0.38 W 0.62 0.40 0.42 S 0.60 W 0.33 0.13 0.74 S 0.30 W -0.30 0.10 1.12 S 0.36 E -1.04 0.10 1.57 S 1.12 E -1.76 0.19 Z.O0 S 1.87 E -Z.06 0.12 2.62 S 2.Z0 E -2.20 0.19 3.41 S 2.39 E -2.25 0.19 4.08 S 2.47 E 0.00 N 0 0 E 0.52 S 47 32 W 0.73 S 54 54 W O.BO S 21 45 W 1.18 S 17 52 E 1.93 S 35 35 E 2.74 S 43 3 E 3.42 S 40 6 E 4.16 S 34 57 E 4.77 S 31 10 E 9Z3.03 923.00 800.00 1023.03 1023.00 900.00 1123.03 1123.00 1000.00 1223.04 1223.00 1100.00 1323.04 1323.00 1200,00 1423.05 1423.00 1300.00 ,1523.06 1523.00 1400.00 1623.07 1623.00 1500.00 1723.08 1723.00 1600'00 1823,08 1823.00 1700.00 0 30 0 26 0 25 0 Z9 0 43 050 0 45 0 ~,3 0 38 0 28 S 64 Z E S 60 55 E S 65 52 E S $2 19 E S 52 43 E $ 64 18 E S 84 35 E N 84 50 E S 57 20 E S 67 35 E -2.75 0.29 4.45 S 2.99 E -3.44 0.15 4.84 $ 3.71 E -4.10 0.10 5.16 S 4.38 E -4.79 0'17 5.47 S 5.08 E -5.62 0.20 6.05 S 5.95 E -6.75 O.lg 6.77 S 7.12 E -8.09 0.41 7.23 S 8.49 E -9.35 0.22 7.14 S 9.74 E -10.51 0.38 7.31 S 10.91 E -11.01 1.19 7.88 S 11.45 E 5.36 S 33 52 E 6.10 S 37 25 E 6.77 S 40 19 E 7.47 S 42 53 E 8.49 S 44 29 E 9.82 S %6 28 E 11.15 S 49 34 E 12.08 S 53 45 E 13.13 S 56 11 E 13.89 S 55 28 E 1923,09 1923,00 1800.00 2023.10 2023.00 1900.00 I~,'~.12 2123.00 2000.00 · 13 2223,00 2100.00 2 ~.14 2323-00 2200'00 2423.15 2423,00 2300.00 2523.16 2523.00 Z400.00 2523.17 2623.00 2500.00 ZT23.17 2723.00 2600.00 2823.18 2823-00 2700*00 0 0 57 I 1 0 55 0 48 0 66 0 32 0 0 14 S 38 58 E S 35 7 E $ 42 48 E S 46 29 E S 56 37 E S 55 18 E S 58 30 E S 53 31 E S 21 5 E 0 15' S 24 33, E -11.83 0.32 8.66 S 12.30 E -12.58 0-30 9.90 S 13.12 E -13.66 O.OB 11.21 S 14.27 E -14.82 0-32 12,48 S 15.50 E -15.93 0.34 13.44 S 16.67 E -17.04 0.23 14.14 S 17.82 E -17.91 0.74 14.93 S 18.73 E -18,93 0.09 15.61 S 19-79 E -19.64 0.69 16.29 S 20.54 i -19.69 0.29 16.73 S 20.61 E 15.05 S 54 52 E 16.44 S 52 58 E 18.15 S 51 50 E 19.90 S 51 9 E 21.41 S 51 7 E 22.74 S 51 34 E 23.95 S 51 26 E 25.20 S 51 44 E 26,21 S 51 34 E 26.54 S 50 55 E 2923,18 2923.00 2800'00 3023.18 3023,00 2900.00 3123.19 3123.00 3000.00 3223,19 3223'00 3100.00 3323-20 3323.00 3200'00 3423.20 3423.00 3300'00 3523.26 3523.00 3400.00 3623.89 3623.00 3500.00 0 37 0 32 0 38 0 36 0 33 0 39 3 41 8 26 3725.58 3723.00 3600,00 11 50 3BZ7.BB 38Z3.00 3700.00 12 16 $ 14 IO.E -20.18 S 41 17 E -20.43 S 6 21 E -20.78 S 31 46 W -20,51 $ 5 23 N. -20.29 S 26 57 W -19,95 N 86 58 W' -17'40 N 82 57 W -6.63 S 82 2 W 11,61 S 79 13 W 33.0.1 0.87 17.49 S 21.14 E 0.54 18.07 S 21.42 E 0.48 19.02 S 21.81 E 0.74 20.11 S 21.60 E 0.42 20.75 S 21.42 E 0.44 21-79 S 21.14 E 6.12 22.26 S 18.60 E 4.54 20.65 S 7.74 E 2.33 21.19 S 0.54 24.96 S 27.43 S 50 23 E 28.02 S 49 50 E 28.94 S 48 55 E 29.52 S 47 2 E 29.82 S 45 55 E 30.36 S 44 7 E 29.01 S 39 53 E 22.05 S ZO 32 E 10.50 W 23.64 S 26 21 W 31.73 W 40.37 S 51 48 W CO~P~TATIO~ DATE: 20-APR-86 P~GE 5 ARCO ALASKA9 INC. 2A-11 KUPARUK NORTH SLDPEtALASKA DATE OF SURVEY: 1, MAR 86 KELLY BUSHING ELEVATION: 123.00 FT ENGINEER: MURTLAND INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG -~[N DEG MIN 3930.53 3923.00 3800.00 14 19 ,034.18 ,023.00 3900.00 16 31 ,?'~.83 ,123.00 ,000.00 21 7 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 5077.33 ,923.00 ,800.00 34 ,0 5197.95 5023.00 ,900.00 34 6 5318.94 5123-00 5000-00 34 18 54,0.16 5223.00 5100.00 34 25 5561.53 5323.00 5200-00 34 36 5683.06 5423.00 5300.00 34 ,3 580,.63 5523°00 5400.00 34 32 5925.95 5623°00 5500.00 34 12 60,5.77 5723.00 5600'00 32 53 6164.,9 $823.00 5700°00 32 15 S 79 36 W 55.93 S 81 47 W 83o01 S 83 10 W 116.93 S 84 8 W 160.23 S 89 45 W 2.10.57 N 86 30 W 263.05 S 89 15 W 320.07 S 8, 31 W 387.75 S 83 55 W 458.98 S 8, 15 W 529.38 6281.97 5923.00 5800.00 31 ,8 6,00.11 6023.00 5900.00 32 38 651~ 50 6123o00 6000.00 31 '6 66~ ]12 6223.00 6100.00 31 '6 66- O0 6256.05 6133-05 31 '6 S 04 35 W 599.57 S 85 26 W 667.00 S 85 23 W 735.06 S 84 53 W 803.55 S 8, 38 W 872.26 S 84 31 W 9,1'29 S'83 49 'W 1010.33 S 83 17 W 1078.90 S 82 49 W 1144.73 $ 8, 54 W 1208.59 S 88 ¢2 W 1270.22 N 88 49 W 1333.04 N 81 6 W 1395.84 N 81 6 W 1456.44 N 81 6 N 1476.46 2.36 4.67 4.21 2.83 1.47 4.28 1.71 0.31 29.23 S 54.46 W 61.81 S 61 46 W 33.93 S 81.32 W 88.12 S 67 20 W 38.04 S 115.07 W 121.20 S 71 42 W 43.39 S 158.15 W 164.00 S 74 39 W 45.87 S 208.43 W 213.42 S 77 35 43.67 S 261.10 W 264.73 S 80 30 W 42.21 S 318.28 W 321.07 S 82 26 W 45.86 S 385.86 W 388.58 S 83 13 W 53.29 S 456.80 W ~59.90 S 83 20 60.57 S 516.91 W 530.38 S 83 26 W 2.13 0.70 0.32 0.32 0.25 0.35 0.45 0.97~ 0.69 3.16 67.53 S 596.83 W 500.64 S 83 32 W 73.09 S 664.06 W 568.07 S 83 43 W 78.57 S 731.92 W 735.13 S 83 52 W 84.34 S 800.20 W 804.63 S 83 59 W 90.68 S 868.6B W 873.40 S 84 2 W 97-21 S 937.45 W 942.48 S 84 4 W 104.24 S 1006.22 W 1011.60 S 84 5 9: 112.00 S 1074.47 W 1080.29 S 84 2 W 120.00 S 1139.97 W 1146.27 S 83 59 W 127-47 S 1203.52 W 1210.25 S 83 57 W 1.61 1.85 0.00 0.00 0.00 130.36 S 1265.09 W 1271.79 S 84 7 W 130.k6 $ 1327.99 W 1334.39 S 84 23 W 125.78 S 1391.13 W 1396.81 S 84 50 W 116.22 S 1452.32 W 1656.96 S 85 25 W 113.05 S 1472.54 W 1476.87 S 85 36 ARCO ALASKA, INC. 2A-11 KUPARUK NORTH SLOPE~ALASKA MARKER ?OP KUPARUK C ~SE KUPARUK C ,OP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: 20-APR-86 [NTERPOL6TED VALUES FOR CHOSEN HORIZONS PAGE 6 DATE OF SURVEY: 1~ MAR 86 KELLY BUSHING ELEVATION: 123.00 FT ENGINEER: MURTLAND HEASURED DEPTH BELOW KB 6244.00 6276.00 6313.00 6476.00 5621.00 6675.00 SgRFACE LOCATION' ~T ORIGIN: 1387' FSL~ 53' FEL, SEC. 14, TllN, ROE, UM TVD RECTANGULAR COORDINATES FROM KB S~J'B-S EA NORTH/SgUTt EAST/WEST 5890.67 5767°67 129.80 S 1245.18 W 5917.94 5794.94 130.29 S 1Z61.93 W 5949.33 5826.33 130.6~ S 1281.50 W' 6086.98 5963.98 128.51 S 1368.75 W 6210.14 6087.14 117.45 S 14¢4.45 W 6256.05 5133.05 113.05 S 1472.5~ W COMPUTATIONiDATE: ZO-APR-B6 PAGE 7 ARCO ALASKA, INC. !A-l! KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C ~SE KUPARUK C ,OP KUPARUK 6 BASE KUPARUK A PBTD TO DATE OF SURVEY: 16 M~R 86 KELLY BUSHING ELEVATION: 123.00 FT ENGINEER: MURTLAND ~~~,~, STRATIGRAPHIC SUMMARY MEASURED DEPTH BELOd KB SURFACE LOCATION ~T TVD RE~T&NGTLAR CODR N t FROM KB S~B-SEA NORTH/SOUTH EAST/WEST 6244.00 6276.00 6313.00 6676.00 6621.00 6575.00 5890.67 5767.67 129.80 S 1265.18 W 5917.94 5794.94 130.29 S 1251.93 W 5949.33 5826.33 130.64 S 1281.50 W 6086.98 -5963.98 128.51 S 1358.75 W 6210.14 6087.14 117.45 S 1¢66.45 W 6256.05 6133.05 113.05 S 1472.56 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6675.00' 6256.05 6133.05 HORIZONTAL DEPARTURE OISTANCE AZIMUTH FEET DEG MIN 1476.87 S 85 36 W SCHLUMBERGER · , 0 1REC T ~ ONAL SUR V E Y COMPANY ARCO ALASKA INC. NELL 2A- i 1 ~'- I ==O KUPARUK COUNTRY USA RUN ONE DATE LOGGED 14 - MAR - 86 REFERENCE 0000714]9 WELL 2A- 11 .... 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I : .... l : ........ ...... ~. [ .... } .... ~ ~ · ~ - : ~- ......................................................................................................... J : ........... ;.L[ ...... i..;..;_~ .; ....... · }..~....~ : - : .............. i i .... "' "i' 'l;i'-i .... L_ -2000 - 1 SO0 - 1000 -SO0 0 SO0 1000 1. SO0 EAST WELL 2A- 11 (~387'FSL, 53'FEL 14, TllN, R8E) VERTICAL PROJECTION 86. 2500 i266. Suggested fo£m to be inserted, in each "Active" veil [older to checl~ for timely compliance with our regulations, · Reports and Haterials to be received · oo Completion Report Required Date Received Remarks · o Ifad Log "-Core Chips , ;.,j,. , · ' .-' ~.~ -.-.~- '- ~ ...... / ........... g un ........... ; , ~ .~__-c~~ ~~ i ~ ~/~- 5~ I · i'll ~/ ~ ..... ARCO Alaska, Inc. Post Office E )0360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton: Enclosed are the 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 F E B 1 1986 AlasKa 0il & L~us C~ms. Gum~nJssion Anchorage .... ~-' STATE OF ALASKA --~-' ALASKA O._ .,ND GAS CONSERVATION CO,.,,,.,,SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~(~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-3 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20057 4. Location of Well atsurface 1387' FSL, 53' FEL, Sec.14, TllN, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 122,' RKB 6. Lease Designation and Serial No. ADL 25570 ALK 2668 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2A-11 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 ~ 0430 hrs, 1/21/86. Drld 12-1/4" hole to 2800'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 6130'. Ran, cmtd, & tstd 7" csg. Drld 6-1/8" hole to 6675'TD (1/27/86). Ran logs. Ran, cmtd, & tstd 5" csg. PBTD = 6621'. Secured well & RR ~ 0130 hrs, 1/30/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set 8 106'. Cmtd w/270 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ¢ 2782'. Cmtd w/800 sx CS III & 290 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe (~ 6114'. Cmtd w/200 sx Class G. 5", 18.0#/ft, L-80, LTC csg f/5857' - 6670'. Cmtd w/120 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/GR/SP/FDC/CNL/Cal f/6675' - 6114' RFT - depths to be submitted when received. 6. DST data, perforating data, shows of H2S, miscellaneous data None A~aska 0J~ & ~;as C(~s. C0mmissi0r~ 1 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ;~ ~~ TITLE Associate Engineer DATE ~-//-~L¢ NOTE--Report olYthis form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR13 Submit in duplicate MEMORANrUM State of Alaska TO: THRU: FROM' ALASKA OIL A~O GAS CONSERVATION COt~ISS~oN C. ?,~~t~rton Cha~~~ Lonnie C. Smith Commissioner Bobby D. Foster Petroleum Inspector DATE: FI LE NO.: TELEPHONE NO.' SUBJECT: January 30, 1986 D.BDF. 11 BOPE Test ARCO - KRU 2A-11 Permit No. 86-3 Kuparuk River Field Thursday~ January 23, 1986: The BOPE test began at 2:45 AM and was ~-6~clUde'~ at-'3'~:'~5 AM." A~ 'the attached BOPE test report shows, there were no failures. In s~ary, I witnessed.the BOPE test on ARCO's KRU 2A-11. Attachment O&G ~4 SI~,4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date · Representative ~_~, ~-7~,~/~ ~.~ Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors ' 95/~asing Set @ ~~3 .ft. Rig f/~ERepresentative~.C~/ /~~~---~ Location, General ._~~ Well Sign~/~ General Housekeeping~~Rig ~~ Visual Audio Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure ~f.v-~ psig Pressure After Closure /~?.5- psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master ! Remote ~ Blinds switch cover 7~~ Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP BOPE Stack ., Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure___~,~~ Test Pressure P ,~'~ Test Pressure. ~ ~'~0 Test Pressure 3~Po Choke Manifold ~~Test Pressure~'~"~ i No. Valves No. flanEas Adjustable Chokes Hydrautcally operated choke Test Time /' 'hrs. day~ and Inspector/ Test Results: Failures 0 Repair or Replacement of failed equipment to be made within Commission office notified. Remarks :' mi~-~P22_s e c. rain / ~ sec. Distribution orig. - AO&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc. Post Office Bo,, 100360 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, ~J. Gruber Associate Engineer JG/tw GRU13/L19 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JAN 2 ? 198, Alaska Oil & Gas Cons. Commission Anchorage /.~ I" iii i i ~: ~"~'~ -" WELL 9 ¥ -' 5,960,687 74 i~. X = 498,340 70 ! LAT 70° 18' 13.7715" --i j LONG· 150°00'48.387" i PAD 92 Z' ! O.G. 87.6' . I I 266' FSL 53' FEL II · ! WELL lO- I°· ! 0 t5 i Y: 5,960,747.76 i 9 · ; ' 0 16 ' X = 498,340.70 r . i LAT. 70°18 14.3619 · I --J i LONG. 150°00'48.388'' O.G. 88.0' PAD 92.3' : 1,326' FSL 55' FEL m,.m,m= mm~ I WELL il- ; Y: 5,960,807.80 i X: 498,340.85 ' LAT. 70° 18' I 4.9525 8 0 ! 0 I LONG· 150° 00'48.383" O.G. 88.3' PAD 9?_.3' i 70 : 02 I,:587' FSL 53' FEL 50 ~ 04 : I WELL 12- ' Y = 5,960,867.74 · I X = 498,340.71 i LAT. 70018' 15. 5420" '~ LONG. 150°00'48.588" , O.G. 88.5' PAD 9?..0' .__~446' FSL 53' FEL 14113 ~ ,..~.- OF 23 I 24 ~U.J ' cou~ & ,~,.~,.~?........... LOCATED IN PROTRACTED SECTION 14, TIIN, RSE, ~> cr~ ,~ ~ ~,/,.~..- j,-'~,~ UMIAT MERIDIAN. r,,. 8 NOTES ~ cu ~ ~ 49t ,. coo , ^t s ZOnE 4. u z o 2. SECTION LINE DISTANCES ARE TRUE· I.J.J c~ ~ '~ *"-~**'"'~ ...... 3. HORIZONTAL POSITIONS BASEDON 2A-NORTH 8~ 2A-SOUTH ~ '-3 0 PER L.H.D. 8~ ASSOC. DWG. NO. NSK-6.20, - dl. ~";~''1;~".~ =, ~m,=~ ---~'~" .~,"~""~ 4. VERTICAL POSITIONS BASED ON 2A-MIDDLE PER ~-~. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED- 8AO0- 3001 rev. ~ ' LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF , · . ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY'MADE UNDER MY DIRECT SUPERVISION AND' THAT ALL DETAILS 14 ARE CORRECT AS Of D.S. 2-A R ARCO AIosko, Inc. TilIll: . DRILL SITE 2-A zs. CONDUCTOR AS- DUI LT LOCATIONS --mill& Dote: 12.30.85 Scale' AS SHOWN ...... . Drawn By' ~ Dwg. No. NSK- 85-38 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- 11 ARCO Alaska, Inc. Permit No. 86- 3 Sur. Loc. 1387'FSL, 53'FEL, Sec. 14, TllN, RSE, UM. Btnnhole Loc. 1311'FSL, !496'FEL, Sec. 14, TllN, R8E, TIM. 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. Mere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~-r~, tr~ul~y~ yours, Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B(,~. ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 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-11 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill 2A-11, 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 13, 1986. any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/JFB/tw PD/L199 Enclosures If you have CEiVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA -- ALASKA OIL AND GAS CONSERVATION COIv,,vllSSlON PERMIT TO DRILL 20 AAC 25.O05 EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] DRILL [~]X REDRILL [] DEEPEN [] lb. Type of well SERVICE [] SINGLE ZONE 2. Name of operator ARCO Alaska, Inco 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1387' FSL, 53' FEL, Sec.14, T11N, R8E, UH At top of proposed producing interval 1324' FSL, 1254' FEL, Sec.14, T11N, R8E, UM At total depth 1311' FSL, 1496' FEL, Sec.14, T11N, RSE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 2A-11 11. Field and pool Kuparuk River Field Kuparuk River 0il 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 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 3784~ ~ TD feet 2A-12well 60' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 6651' MD, 6247' TVD feet 2560 01/13/86 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3500 feet. MAXIMUM HOLE ANGLE 20. Anticipated pressures 34 o (see 20 AAC 25.035 (c) (2) 2981 psig@ 8_~__ Surface 3427 ..psig@ 5884 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing -~4" 16" 12-1/4" 9-5/8" 8-1/2" 7" 6-1/8" 5" 22. Describe proposed Weight 62.5# 36.0# 26.0# 1 8.0# program CASING AND LINER Grade Coupling H-40 We1 d 1-55/HF-EF',W BTC r-55/HF-EF:W BTC -80 ,T_C Length SETTING DEPTH MD TOP TVD 80' 32' I 32' 2759' 31 ' 31 ' 6083' 31 ' I 31 ' 5900'1 5801 ' 5900' MD BOTTOM TVD 1121 112' 27901 2790' l 6114~ 5801' 66511 6247' QUANTITY OF CEMENT (include stage data) + 200 cf 800 sx CS III & 290 sx Class "G" 200 sx Class "G" 100 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6651'MD(6247'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. To maintain wellbore integrity and safety, the 7" casing will be set 100' above the top of the Kuparuk Sands. A 5" production liner will be run to TD. Expected maximum surface pressure is 2981 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-11 will be 60' away from 2A-~r at the surface. (continued on attached sheet) 23. I hereby cer~i~l~hat the foregoing is true and correct to the best of my knowledge SIGNED TITLE The space ~oe/f~-~ol~mi~i°~'uuse ~ Regional Drilling Engineer DATE Samples required []YES eNO Permit number APPROVED BY CONDITIONS OF APPROVAL t M ud log required ' Appr°~'aldate/0f/86-- 01 Directional Survey required I APl number [~ES I-]NO I 50-/0;-?_ 0 0 ~? SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 6, 1986 by order of the Commission Form 10-401 Submit in triplicate PERMIT TO DRILL 2A-11 (cont'd) 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. 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. .laFROST~I'~ -SNDS TVD, 'D-1'-485-7 -- ___ , TOP)-W--SA,K----S#DS~ TVD'-22.~,O.- --,~--~_,. __ ....................... ~ - , i-~wnnn-- KUPARUK IR,;[VER UN]:T 20" -D]:V TER SCHEMATIC ii, DE S CR I PT I ON 1. 16' COt,,EXJCTOR. 2. TAh/<:O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LO~R QUI CK-COt't~CT ASSY. 5. TAl'l<O UPPER QUI CK-C~CT ASSY. 6. 20' 2000 PSI DRILLIN~ SPOOL W/I O' OUTLETS. 7. !0' HCR BALL VALVES W/lO' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPCIN CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI AhINULAR PREVENTER. 4 IV~:[ NTENANCE & OPERAT.]: ON , I. UP-ON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. 2. CLOSE AhI~LAR PREVENTER AhD BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 5,. CLOSE ANNULAR PREVENTER IN THE EVENT 'THAT AN II, FLUX OF WELLBORE '- FLUIDS OR GAS IS DETECTED. IF . NECESSARY, MAFaJALLY OVERRIDE AI~ CLOSE APPROPR ! ATE VALVE TO ACHIEVE DOVINWlhD DIVERSION. DO NOT SHUT IN ~LL ~": ~'~' ~,'UNDER ANY CIRCUMSTA~ES. . I ~{llI~ h PSI RSRRA BOP STACiK I. 16' - 2U:XIO PSI TAN<~ STARTING lEAD 2. I1' - 3(300 PSI CA~IN~ 4. 15-5/8' - 5000 PSI PIPE ~ IE,-Ev'(~' - 5000 I~! ~Z~ ~ LI~S ACOJVULATOf~ CAPACITY TEST !. O-ECK AhD FILL ~TaR ~IR TO PROPER IFVEL WlTM HY~IC FLUID. 2, ASS~ THAT AC~TOR PRE~ IS 34300 PSI ~r~TH 15OO PS! DO~TREAM CF TIE REGLLATOR. ~. Q~"RVE TIldE, T~EN CLOSE ALL LI~T$ $II41TN~Y N~ RECC~ TIE TIH[ N~ ~ RB~INII~ AFl'ER ALL UNITS /kRE CLClsED WITH CHN~II~ ~ CFF. 4. RECORD ~ NN~ [~'P~T.. T~ A~I~ L~ LI~ 5 4 2 KUPARUK 13. 1~-5/8" BOP STACK TEST I. FILL BOP STACX AI~ CI~ IVlANIFO_D MITH AECTIC DIESEL. 2. O-E~ THAT ALL LOCK CXIMN SII~EiNS IN t~.LL~ ARE F1.LLY RETRACTED. SEAT TEST PLUG IN t'EJ. LI~,AD WITH RUNNING JT .AhD RUN IN L~ SCREWS. LIllE VALVES ADJACENT T0 BCP STACK. ALL 0TIER 4. ~ UP TO 250 PS~ CEEASE PRE~3~U~E TO 5500 PSI AhD I-O_D FOR IO WIN. BLEED ~ TO O PSI. L]IE VALVES. CLOSE TQm PIPE RNvlS AhD MC~ VALVES CN KILL AN) CHOKE LIhE$. 6.TEST TO 250 PSI AN~ 5500 PSI AS IN STEP 4. 7. C~NTIN. E TESTING ALL VALVES, LII~ESo ~TW A 250 PSI CO~ STEP 4. ~0 NDT ppr~ NDT A FULL (;l=OSIl~ P~ITIVE SEALO0(E. CN.Y 8. OPEN TOP PIPE EAHS AhD CLC~__ BOT'FCh~ PIPE RAIVlS. TEST BOTT(M PIPE I~ lO ZSO PSI ~ 35430 PSI. 9. (:PEN BOTTCM PIPE PJ~, BACX OUT i~NG JT AhD IO. CLOSE BLIN:) ~ AhD TEST TO ~ PS] AhD 35CX3 II. OPEN BLIhD RAMS AhD RETRIEVE TEST PLUG. MAKE SURE 14ANIFOLD AhD LIhF. S ARE FU.L OF k~l~ FLUID. ~ ALL VALVES IN DRILLII~ PQSZTION. IZ. TEST STAN:PIPE VALVF. S,.~'llY· KELLY COCKS· DRILL PIPE SAFETY VALVE, AhD IhBIDE BOP TO 250 PSI AhD 3500 PSI. TEST II~FORMAT!0N CN BLC~ I~EVE)~TE~ TEST · SION, AhD SEhD TO DRILLIhl3 SUPEEVISCR. C1:~~ BOPE TEb"F AFTER N]PPLII~ UP AND WEEKLY THEREAFTER FUNCTICI~LLY OPERATE BOPE DAILY. STACK 5 ~ OO84OO1 '(3) ~ cu 8) t. / ~eeee'. . '' eeee®.®ee®e®eeee®ee®ee®ee... . .. : . ?"::, ?./: ',"~:.-. . ~.. ' . . . to be located'in a defined pOol"..;i'. .... ':.. · . Is Well:loCated~proPer distance frOm'other wells .'. ~ . Is sufficient.undedicated acreage available in this pool . ts well to be deviated and'is wellbore-plat inCluded · Can Permit be approved~before ten'day wait ......... i 9~ :thru ' 12) : 10. /~.127If's'" ~ ~. (10 and 1Z) / 12. · '(,13 thru '(22' thru 26/) (6 > Ad d: .~ _ / / 13. 14. 15. 16. 17. 18. 19. 20. 21. Does perato have bond in fo' :o r a rte .... ...o... .............. .. Is a conservation order needed ................................ Is administrative approval needed ............... · ............. Is the 'lease number appropriate _ eeeeeeeeeeeeeeeeeeeeeeeeeee.~ee provided ' /7/~[// Is conductor string ........................................ . , Is enough cement used-to circulate on conduCtor and surface .... ~ Will cement tie in surface and intermediate or productmonstrln g .ii ' Will cement cover all known productive horizons ...................... ~/~ Will surface casing protect fresh water zones ....................... ~2~ Will all casing give adequate safety in collapse, tension and burst.. ~ Is this well to be kicked off from an existing welibore ............. ,,., ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ __ 22. 23. 24. 25. 26. 27. Is a diverter system required ...................... Are necessary diagrams of dtverter and ~ ;quipm~t att;ch~d'.l.l~ Does BOPE have sufficient pressure rating - Test to _.~/~ psig'' Does the choke manifold comply w/API RP-53 (Feb. 78) .................. Is .the presence of H2S gas probable ................................. __/Va 7- _v~/~/7--/-£D Additional requirements ............................................. #zY~ · . Geology: Engineering: . WVA~I ~ - - ~ RJR f~P-~ rev: 03/13/85 6.011 '" INITIAL GEO. UNIT ON/OFF" POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. ST 5 5.0 D ~ i~6.. DF TY-~ SZZ] 15 '7 3 ]. i~l ,] ] } :] 0 0 0 0 SiZ~ ! 1 1 i S~ 5S SS 5~ SS 5S iLq COCT~L) ~uOOOOOOOOOOOs 0300 O 0 JO:DO 0 O00 O30000OOOO0000 OD30OJD,]O0:O000 OO}O00OO000000 O000000000OO00 O:DOOO000003000 ODO0000OO00000 00000300000000 O~OOOO00000000 5.1257 3 E ~ T ,523'3. O 3'33 S = :_ j 3~ 75,. . 57j03 F-' 7 o .~ 255 i L - 3.93 i 5 ',i:: i i' 2. it3. ~3,:30 = 4~ ..... -.,..:;i~ : 2L3 'i ~+ ~ :7'. 5 ~ 7 5 =O"i- :.3 75 i31,2773 2.5311 I053o5~7: 2.617 ~ !07,0273 ",~. ~, I ," :.3, ~,5.5173 :55.S125 30.5 '39 ~ 33&.6'+35 15. 74. '3 ~ '=', 3 } ~9..:}};35 "&L i ILq tL'4 iL'4 -' 2 7 3.0051 5.i755 2.537~ 5. }031 2. a ) 53 i.5837 5, ,) 03 1 5.5-..¢': '~ 7 5.5.55'9