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186-001
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-07-03_21151_KRU_2A-09_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21151 KRU 2A-09 50-103-20059-00 Caliper Survey w/ Log Data 03-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 186-001 T37808 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.07 08:45:00 -08'00' WELL LOG TRANSMITTAL #905696714 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2A-09 Run Date: 5/16/2019 186001 3 105 7 July 19, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 2A-09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20059-00 RECEIVED AUG 0 5 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: y l� Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUN 17 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ 9 p ra' ns upwg, O Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Chan e o 'V[i.]PAL?' Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing Patch ❑� 2. Operator ConocoPhlllips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: DevelopmentEx ❑ Exploratory ry ❑ Stratigraphic ❑ Service ❑ 186-001 3. Address: P. 0. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20059-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025570 ICRLI 2A-09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,535 feet Plugs measured None feet true vertical 6,204 feet Junk measured None feet Effective Depth measured 8,272 feet Packer measured 9, 7436, 7587, E feet true vertical 6,026 feet true vertical 4, 5468, 5567, E feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 feet 16 110' MD 110' TVD SURFACE 3,374 feet 9 5/8 " 3,409' MD 2772' TVD BACK - WO 2015 7,515 feet 5 1/2 " 7,551' MD 5543' TVD PRODUCTION 5,719 feet 7 7,954' MD 5813' TVD Perforation Depths Measured depth 8136'-8304' feet True Vertical depth 5935'-6048' feet Tubing (size, grade, measured and true vertical depth) 3.5" and 2 3/8" L-80 and J-55 8,217' MD 5,989' TVD Packers and SSSV (type, measured and true vertical depth) SEAL ASSY - BAKER 80-40 SPACE OL 7,429' MD 5,464' TVD SEAL ASSY - BAKER 80-40 SPACE OL 7,436' MD 5,468' TVD PACKER - CAMCO 2.875" X 7" HRP -1-: 7,587' MD 5,567' TVD PACKER - BAKER DB PACKER 8,196' MD 5,975' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: I N/A N/A N/A N/A N/A 14. Attachments (required per 20 AAC 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development ❑Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑I 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: N/A Authorized Name: Dusty Freeborn Contact Name: Dusty Freeborn/Jan Byrne Authorized title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com Authorized Signature: Date: 13 June 19 Contact Phone: 907-659-7224 Form 10-404 Revised 4/2017 k -7—t— 4,12 0// `/ A 0'01 /0 /`� Submit Original Only b(/ (/ �BDMS� JUN 1 B 9n19 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 13`h Day of June, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7�h 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-09 (PTD 186-001). Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Supervisor ConocoPhillips Alaska, Inc. Date Event Summary 06/09/19 06/05/19 05/17/19 05/16/19 02/10/19 2A-09 DESCRIPTION OF WORK COMPLETED SUMMARY W/ DPU SET UPPER SECTION OF PATCH: 2.72" P2P #CPP35202, SPACER PIPE, POGLM (W/ RETRIEVABLE 1" INT -DV), SPACER PIPE, & ANCHOR LATCH #CPAL35107 (18.08' FROM TOP OF P2P TO VLV / 25.57' OAL) W/ MID ELEMENT @ 4648' RKB; W/ TTS TEST TOOL IN UPPER P2P @ 4648' MITT & CMIT TAA TO 2500 PSI (BOTH PASSED); PULLED DV & SET OV IN POGLM @ 4664'; DDT ON IA PASSED. JOB COMPLETE. MITT TO 2500. PRE T/1/0= 400/800/25, PSI UP W/ 0.7 BBLS START= 2550/800/25 15 MIN= 2375/800/25 (-175/-0) **FAIL**. PSI BACK UP W/ LESS THAN 0.1 BBLS START= 2575/800/25 15 MIN= 2550/800/25 (-25/-0) 30 MIN= 2525/800/25 (-25/-0) **FAIL** 45 MIN= 2525/800/25 (-0/-0) **PASS** BLEED IA F/ 800 TO 550. RU LRS TO IA FOR CMIT IA x T TO 2500. PRE T/I/0= 2475/525/25, PSI UP W/ 13.3 BBLS START= 2675/2525/25 15 MIN= 2650/1800/25 (-25/-725) **FAIL** PSI BACK UP W/ 0.3 BBLS START= 2700/2600/25 15 MIN= 2700/2525/25 (-0/-75) 30 MIN= 2700/2525/25 (-0/-0) **PASS** BLEED BACK. RD AND RELEASE LRS. POOH. IA DDT RESULTS PRE T/I/0= 600/500/25, START= 600/225/25,15 MIN= 600/225/25, 30 MIN= 600/225/25 SET TTS TEST TOOL IN UPPER P2P @ 4655' RKB; MITT TO 2500 PSI (PASS); PULLED TEST TOOL @ SAME & PULLED OV FROM INSIDE POGLM @ 4633' RKB (APPEARS TO BE FULLY FUNCTIONAL); PULLED UPPER P2P POGLM ASSEMBLY @ 4655' RKB; SET TEST TOOL IN LOWER P2P @ 4673' RKB. CMIT TBGxIA TO 2500 PSI (PASS); PULLED TEST TOOL @ SAME. READY FOR EXTENDED POGLM ASSEMBLY. MIT -T 2500 PSI, PRE MIT T/1/0=975/775/0 INITIAL T/1/0=2500/775/0 15 MIN T/1/0=2375/775/0 30 MIN T/1/0=2350/775/0 (PASS) 1.5 BBLS TO PRESSURE UP. CMIT T X IA. PRE MIT T/1/0=350/775/0 INITIAL T/1/0=2550/2550/0 15 MIN T/1/0=2525/2525/0 30 MIN T/1/0=2525/2525/0 (PASS) 20 BBLS TO PRESSURE UP. PULLED GLV @ 3156' RKB, SET GLV @ SAME (3/16" PORT / 1304 TRO), GOOD TBG TEST TO 1000 PSI W/ GAS, PULLED 3 1/2 TTS TEST TOO FROM 2.72 P2P PACKER @ 4655' RKB COMPLETE GOOD CMIT TBG x IA TO 1100 PSI W/ HOLE FINDER @ 4792' RKB, PULLED 2.78" CATCHER @ 7532' RKB, BRUSH n' FLUSH TBG TO 4700' RKB, GOOD 2.72 x 21' PATCH DRIFT TO 4800' RKB, SET LOWER 2.72" P213 @ 4673' RKB (ME) ( CAL 4.01'/ SN: CPP35195), RAN 3 1/2 TTS TEST TOOL TO LOWER 2.72 P2P @ 4673' RKB CMIT TBG x IA 2500 PASS, SET 2.72 P2P POGLM ASSEMBLY @ 4655' RKB (ME) (OAL 18.88'/ 10.75' FROM TOP OF PACKER TO OV (.25" PORT) / SN: CPP35115 / CPAL35102), SET 3 1/2 TTS TEST TOOL IN UPPER 2.72 P2P @ 4655' RKB. IN PROGRESS. CMIT TAA (2nd attempt) pre TIO: 300/12/40. Initial TIO: 2550/150/40. 15 min TIO: 2525/150/40. 30 min TIO: 2515/150/40. DRIFTED DMY LDL STRING (2.72" OD) TO CATCHER @ 7527' RKB. PERFORM LDL: IDENTIFY TBG LEAK @ 4667' RKB. LOG UP / DOWN PASSES ACROSS LEAK AND STATION STOPS @ 4670'& 4660' RKB. CORRELATE TO TBG TALLY 5/27/2015. PULLED EXT PKG MODIFIED DV @ 4660' RKB. READY FOR Ultra -Clean CIRC -OUT. ConocoPhillips KUP PROD WELLNAME 2A-09 WELLBORE 2A-09 AaSkd,inc. `1 F— Lh LWA PP KER 1.1 fret CmM', 1.91 s UFT, U.ER I RRoo�rnoNN, NIPP : NIPPLE NIWLE', UMR-ORIUIN 7.115& asu 9L— Originated: Schlumberger PTS - PRINT CENTER 6411A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: pi AOGCC ATTN: Natural Resources Technician II y-� Alaska Oil & Gas Conservation Commision rl 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 186001 t TRANSMITTAL DATE TRANSMITTAL# , to -04A 2A-09 1R-07 50-029-20621.01 50-103.20059-00 50-029-21332-00 EBNL-00001 EOSH-00041 EOSH-00042 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WIL WL Caliper Revl P Caliper Caliper FINAL FIELD FINAL FIELD FINAL FIELD 4 -Apr -19 17 -Apr -19 18 -Apr -19 1 1 1 2A-08 1y-11 50-103-20049-00 50-029.20926-00 DWUJ-00092 EBNL-00016 KUPARUK RIVER KUPARUK RIVER WL WIL (PROF LDL FINAL FIELD FINAL FIELD 28 -Apr -19 28 -Apr -19 1 1 2B-07 1A-01 2X-10 50-029-21080-00 50-029-20590-00 50-029-21187.00 DWUJ-00093 EBNL-00018 DWUJ-00094 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL (PROF PPROF PPROF FINAL FIELD FINAL FIELD FINAL FIELD 29 -Apr -19 30 -Apr -19 30 -Apr -19 1 1 1 3H-21 25-315 50-103-20094-00 50-103.20776-00 EBSI.00004 EBNL-00020 KUPARUK RIVER KUPARUK RIVER WL WL Caliper PPROF FINAL FIELD FINAL FIELD 3 -May -19 5 -May -19 1 1 10 Please return via courier or sign/scan and email a copy Date Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Atte.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 2A-09 Run Date: 2/10/2019 18 b0® 1 30 37 4 February 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-09 Digital Data in LAS format, Digital Log file RECEIVED 1 CD Rom 50-103-20059-00 FEB 19 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: nZeInNiq Signed: STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COFi.v.1SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r.; Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well E Other: (- 2.Operator Name 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory E 186-001 3.Address. 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20059-00 7.Property Designation(Lease Number). 8.Well Name and Number. ADL 25570 KRU 2A-09 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11 Present Well Condition Summary: Total Depth measured 8535 feet Plugs(measured) 7609 true vertical 6204 feet Junk(measured) none Effective Depth measured 8424 feet Packer(measured) 7506, 7587, 8196 true vertical 6128 feet (true vertical) 5514, 5567, 5975 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 3374 9.625 3409 2772 PRODUCTION 5719 7 7954 5813 LINER 8625 5.5 8525 6197 Perforation depth: Measured depth: 8136-8182, 8242-8252, 8271-8304 - 271 8304 %WED .J U! 2 S 2O�, True Vertical Depth: 5935-5966, 6006-6013,6026-6048 Tubing(size,grade,MD,and TVD) 3.5 x 2.375,J-55/L-80, 8218 MD, 5990 TVD Packers&SSSV(type,MD,and TVD) PACKER - BAKER PACKER @ 7506 MD and ND PACKER-CAMCO 2.875"X 7"HRP-1-SP RETRIEVABLE PACKER @ 7587 MD and 5567 TVD PACKER-BAKER DB PACKER @ 8196 MD and 5975 TVD NO SSSV 12.Stimulation or cement squeeze summary Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations I✓ Exploratory r Development I✓ Service r Stratigraphic IT Copies of Logs and Surveys Run r 16 Well Status after work: Oil 17 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r- VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-252 Contact Travis Smith @ 26 450 Email Travis.T.Smith(a conocophillips.com Printed Name T avis Smit Title Wells Engineer Signature // f Phone:265-645a,i t., 4 g•v k D- Date//� rri 7-/t4-1(5- JUN 2Gi R C JUL - 1 2015 Form 10-404 Revised 5/2015 "" / /� 3Submit Original Only 2A-09 WELL WORK SUMMARY PRE-RIG WELL WORK DATE SUMMARY 3/15/2015 (PRE RWO)T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; FUNCTION TESTED ALL LDS-ALL FUNCTION PROPERLY. 3/17/2015 (SUB/PRE-RWO): MITOA-PASSED @ 1800 PSI. 4/25/2015 DRIFT 2.5" CENT., S-BAILER THROUGH TIGHT SPOT FROM 233' SLM TO 261' SLM RAN LIB TO 7,525' SLM, IMPRESSION OF G FN PULLED RK-DGLV @ 7,518' RKB FIRE STRING SHOT OVER INTERVAL FROM 7,541' RKB TO 7,549' RKB 4/26/2015 LRS CIRCULATED 100 BBLS SEA WATER AND FP TBG AND IA W/70 BBLS DIESEL CUT TUBING W/2-5/8"CHEM CUTTER @ 7,545' RKB POST-RIG WELL WORK 6/2/2015 PULLED SOV& SET DV @ 4660' RKB; MITIA(PASS). IN PROGRESS. 6/3/2015 PULLED DV'S @ 4660' &3155' RKB; SET OV @ 4660' RKB &GLV @ 3155' RKB; MITT (PASS); TAG &WORK THRU OBSTRUCTION FROM 7520'-7543' SLM (RECOVERED METAL BAND, METAL CHUNKS, SCALE, & SAND). IN PROGRESS. 6/4/2015 BAILED METAL, SCALE, & SAND f/7545'-7571' SLM; PULLED CATCHER @ 7604' RKB. IN PROGRESS. 6/5/2015 RAN MAGNET& BAILED PIECES OF BANDING OFF WRP; PULLED WRP @ 7609' RKB; TAGGED @ 8277' SLM (EST.4' RAT HOLE); MEASURE BHP @ 8210' RKB (2404 PSI). JOB COMPLETE. CanocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2A-09 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 5/10/2015 4:00:00 PM Rig Release: 5/28/2015 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/09/2015 24 hr Summary Move rig and equipment from 2U pad to 2A pad 12:00 00:00 12.00 MIRU MOVE MOB P Mobilize equipment from 2U pad to 2A pad. spot camp and shop on pad. set pits out of the way for sub. 05/10/2015 Continue to MIRU. Rig accepted @ 16:00. Continue to R/U aux equipment.Take on sea water. Begin well Kill with 8.5 sea water. 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move Sub Base towards 2A-Pad. Lay rig matts over flow line on 2B-Pad. Continue to prep 2A-09 well slot(removing slush and adding more gravel). Move Sub Base from 2B-Pad to 2A-Pad. 04:00 06:00 2.00 MIRU MOVE MOB P Lay rig mats and Herculite. Hang Tree in Cellar. 06:00 12:00 6.00 MIRU MOVE MOB P Spot sub and pits. 12:00 16:00 4.00 MIRU MOVE RURD P RU Pits and lines. Rig accepted @ 16:00 hrs 16:00 21:30 5.50 MIRU MOVE RURD P Continue to rig up rig and aux. equiment and lines 21:30 22:30 1.00 MIRU WELCTI MPSP P Checked well preesure IA=300 psi. Install and test lubicator to psi. pull BPV.Tbg=200 psi. 22:30 00:00 1.50 MIRU WELCTI KLWL P PJSM. PT lines to 3000 psi. Bled off IA pressure to 20 psi. Broke convetional circulation @ 4 BPM @ 630 psi. 35/11/2015 Attempted to test BPV with rolling test.to 1000 psi. Bled off pressure. BPV began to leak Pulled valve.well now flowing.Weighted up to 8.9#brine and circulated in. Flow check.well still flowing @ 2 psi on IA. Build New KWF to 9.2 ppg 00:00 01:00 1.00 MIRU WELCTI KLWL P Continue to circulate in 8.5#sea water thru open GLM @ 7518 ft @ 4 BPM @ 630 psi.. Check returns @ 284 bbls 8.5 to surface.Turned inside. @ 3 BPM @ 350 psi. Thru GB. 01:00 01:30 0.50 MIRU WELCTI OWFF P Flow check 30 min's Page 1 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:00 2.50 MIRU WELCTL MPSP P PJSM. Install BPV&test to 1000 psi rolling test @ 2 BPM. Bled off pressure. Pumped 15 bbls got 13 bbls back. Check for flow BPV leaking. Pull BPV small amount of grit on plug. Note: Sent FMC after new BPV.Also discussed with Eng.testing options on BPV. 04:00 06:00 2.00 MIRU WELCTL OWFF T Monitor well for flow. Small flow up IA. and Tbg. IA stopped.Tbg still has small flow after 30 min's. Continue to Monitor well. Flow stopped monitor 30 min's Note OA pressure increased from 340 psi to 1260 psi after test. Bled off OA. 06:00 08:00 2.00 MIRU WELCTL OWFF T Monitor Well. Continue with slight flow from the IA and the OA. Shut in the OA. Pressure builds up to 20 psi. 08:00 08:15 0.25 MIRU WELCTL SFTY T PJSM. Discuss the plan forward with the Crew. 08:15 11:00 2.75 MIRU WELCTL CIRC T Leave the OA shut in. Circulate Well again with Sea Water at 1.0 bpm/74 psi(skim off the diesel cap). Weight in 8.6 lb/gal...8.6 lb/gal out. Increase pump rate to 2.0 bpm/156 psi. Total volume pumped 285 bbls. Final 2.0 bpm/168 psi. Weight=8.6 lb/gal in/out. (SIMOPS=load and begin to process 3 1/2" Drill Pipe). 11:00 11:30 0.50 MIRU WELCTL OWFF T Blow down flare line. Blow down kill line. Open casing...dribble. Open Tubing...very slight vacuum. Bleed- 20 lb gas cap from the Outer Annulus to the Bleed Trailer. 11:30 12:30 1.00 MIRU WELCTL OWFF T Monitor Tubing and Casing dead. Outer Annulus very slight gas fumes observed at the Bleed Trailer. However, after 5 minutes the IA started to dribble...then a very small stream. Continue to monitor. Shut in the OA to see if the IA changes. Stream appeared to increase slightly and the returns changed to straight diesel in-10 minutes. Bleed minimal pressure from the OA with and observe gas to the Bleed Trailer. Discuss options and a plan forward with Anchorage Engineering. 12:30 15:00 2.50 MIRU WELCTL COND T Weight up. Build 8.9 lb/gal Brine in the Pits. Page 2 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 19:00 4.00 MIRU WELCTL CIRC T Swap wellbore over to 8.9 Ib/gal Brine at 2.0 bpm/133 psi. 19:00 20:00 1.00 MIRU WELCTL OWFF T Monitor well 1 hr. I A began to flow again. 20:00 21:30 1.50 MIRU WELCTL KLWL T Shut well in place low PSI gauge on IA 2 lb's increase during shut in. Cal new KWF with 125 psi safety factor included. =9.2 NKWF. Discussed with Eng. 21:30 00:00 2.50 MIRU WELCTL COND T Weight up brine to 9.2 05/12/2015 Kill well. Install BPV. ND tree. NU BOPE. Test BOPE 250/3000 psi. Pull completions free. Circulate well clean. Lay Down 3.5"EUE8rd completion. COntrol line broke after 22 joints laid Down. Contact CPAI engineer. 00:00 02:30 2.50 MIRU WELCTL KLWL T Establish circulation @ 2 BPM @ 120 PSI with 9.2#Brine. 9.2 in/out. 02:30 03:00 0.50 MIRU WELCTL OWFF T Monitor well for 30 min's 03:00 03:30 0.50 MIRU WELCTL MPSP T Install BPV. Not tested as per Anchorage Engineering. 03:30 05:00 1.50 MIRU WHDBO NUND P ND tree and adaptor.Adaptor took 10 K to pull free. unable to pressure up on SSSV control line appears to have a hole. Trapped gas in it when bled off. 05:00 08:00 3.00 MIRU WHDBO NUND P NU BOP Stack. 08:00 09:00 1.00 MIRU WHDBO RURD P Rig up test equipment. 09:00 13:30 4.50 MIRU WHDBO BOPE P Test BOPE as per ConocoPhillips/AOGCC requirements at 250/3,000 psi with the 3 1/2"and the 7"test joints. Perform the Koomey draw down test. Test Gas Alarms. Record all pressure tests on chart. The State's right to witness the test was waived by M. Herrera. 13:30 14:30 1.00 MIRU WHDBO RURD P Rig down test equipment. 14:30 15:00 0.50 MIRU WHDBO MPSP P Pull the Blanking Plug and the BPV. Lay down same. 15:00 15:45 0.75 COMPZ RPCOM RURD P Rig up GBR tubing handling equipment. Bring Spooling Unit to the Floor. Ready floor. 15:45 16:00 0.25 COMPZ RPCOM SFTY P PJSM. Discuss safety concerns pulling the Tubing Hanger. 16:00 17:15 1.25 7,515 COMPZ RPCOM PULL P Pick-up Landing Pup Joint Assembly. Screw in Top drive. BOLDS. Pulled Hanger free at 90K. Pulled Tubing free at 130K. Pull Hanger to the Floor at 100K dragging. Terminate Control Line. Lay down Tubing Hanger. 17:15 18:30 1.25 7,515 7,515 COMPZ RPCOM CIRC P Circulate Well with 9.2 lb/gal Brine at 5 bpm 640 psi. Page 3 of 23 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 22:00 3.50 7,515 6,837 COMPZ RPCOM PULL P Pull 3.5"EUE8rd completion. Control line pulling tight(but not string)for joint 3-10. String worked until control line loose enough to pull freely. Control line flattened in areas. Continue to pull completion.joint 15-22 control began to pull freely. once Joint 22 pulled control line end emerged. Stack drained and no control line end observed in stack. Contact CPAI Engineer. Hanger/pup, two space out pups and 22 joints laid down(9 Stainless Steel bands recovered). Total footage pulled 702' 22:00 22:30 0.50 6,837 6,837 COMPZ RPCOM SVRG P Service Rig. Inspect Top Drive. Discuss plan forward with CPAI Engineer. 22:30 00:00 1.50 6,837 6,837 COMPZ RPCOM WAIT T Due to 7"casing damage caused by well subsidence decision made to mobilize deployment sleeve and stop pulling completion. Contact Baker Hughes Through Tubing for Downhole Deployment Sleeve and IBP. SIMOPS: Rig Down and release SLB Spooling Unit. Contact Baker Hughes fishing. 35/13/2015 SIH on Drill Pipe with remaining 3.5"completion on deployment sleeve and deploy at 727'dpmd. TOOH. PU BHA#1 (Rope Spear)and TIH. POOH and LD BHA#1, cannot pass 265'dpmd. TOOH. PU BHA#2 Rope Spear(no Stop Ring)and TIH, cannot pass 275'dpmd.TOOH. PU BHA#3(Muleshoe)and RIH to 720'.TOOH. PU and TIH with IBP. Set IBP—700'. TOOH with setting tool. PU and TIH with Muleshoe and dump 50'sand on top of IBP. TOOH and LD Muleshoe. Nipple Down BOPE. RIG ON HIGHLINE @ 13:00 00:00 03:15 3.25 6,837 6,837 COMPZ RPCOM WAIT T Contact CPAI Engineer. Rig Down GBR power tongs.Change to Drill Pipe Elevators. 03:15 03:30 0.25 6,837 6,837 COMPZ RPCOM SFTY T PJSM for picking up Baker Hughes deployment sleeve and components. 03:30 04:15 0.75 6,837 6,852 COMPZ RPCOM BHAH T Pick Up Deployment sleeve BHA components. Overall length: 15.45' 04:15 05:45 1.50 6,852 727 COMPZ RPCOM PULD T Single in with Drill Pipe from pipe shed. Observed weight indicator bobbles starting at 275'dpmd. continue into hole until contacting tubing stub. Up Wt= 110k; Dn Wt= 55k. set down 5k. Pump 2 bpm @ 640 psi. Released form deployment sleeve. Top of deployment sleeve @ 726.74' 05:45 06:15 0.50 727 0 COMPZ RPCOM TRIP T Trip out of hole standing back 7 stands of Drill Pipe. 06:15 06:45 0.50 0 27 COMPZ RPCOM BHAH T Make up BHA#2...Rope Spear Assembly. 06:45 07:30 0.75 27 270 COMPZ RPCOM TRIP T Trip in with BHA#2 slowly, looking for tight spot. Progress came to a halt at 270-ft(265-ft...5 7/8"Spear Stop)dpmd. Unable to rotate. Pick up a foot...now able to rotate gently. Page 4 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:15 1.75 270 0 COMPZ RPCOM TRIP T Trip out with BHA#2 to inspect. Nothing significant. Discuss a plan forward with anchorage and Baker Fishing Tools. 09:15 09:45 0.50 0 27 COMPZ RPCOM BHAH T Make-up BHA#3...Rope Spear(no stop ring). Max BHA OD 5.00". 09:45 10:30 0.75 27 275 COMPZ RPCOM TRIP T Trip in with BHA#3. Set down at the same spot(265-ft) Working to get through with negative weight. Made a very slow 10-ft(getting worse). End further attempt. 10:30 11:00 0.50 275 27 COMPZ RPCOM TRIP T Trip out with BHA#3. 11:00 11:15 0.25 27 0 COMPZ RPCOM BHAH T Lay down BHA#3 11:15 11:30 0.25 0 7 COMPZ RPCOM BHAH T Make-up BHA#4...4 7/8"OD Mule Shoe(on 3 1/2"Drill Pipe). 11:30 12:15 0.75 7 720 COMPZ RPCOM TRIP T Trip in hole with BHA#4. Set down at 269-ft with the 4 7/8"od Mule Shoe(5.0"o.d. drill pipe tool joint at 265-ft).. Turn angle of Mule Shoe several time while attempting to work past damaged 7"Casing area. Finally got through with 7K Top Drive set down weight. Continue in the hole 720-ft with no further problems. 12:15 12:45 0.50 720 7 COMPZ RPCOM TRIP T Trip out with BHA#4. 12:45 13:00 0.25 7 0 COMPZ RPCOM BHAH T Lay down BHA#4. 13:00 15:30 2.50 0 0 PROD1 WELLPF WAIT T Wait on third party tools(IBP and additional fishing tools). 15:30 16:00 0.50 0 15 PROD1 WELLPF MPSP T Make-up Baker Setting Tool and Inflatable Bridge Plug. 16:00 18:00 2.00 15 700 PROD1 WELLPF TRIP T Trip in with IBP on 3 1/2"Drill Pipe. "Delicately bobble"through the damaged section from 265'-275'. Continue in. 18:00 19:00 1.00 700 700 PROD1 WELLPF MPSP T Set IBP @ 700'dpmd(center of element)and top of Fish neck @ 694'dpmd. Observed IBP begin to set @ 500 psi. Pressure up to 1750 and observe pressure drop off.Try again with same results. Contact BH. Pressure up to release and pull up, released from IBP after set. Up Wt=47k. 19:00 19:30 0.50 700 0 PROD1 WELLPF TRIP T Trip out of hole with Setting tool. 19:30 19:45 0.25 0 0 PROD1 WELLPF BHAH T Lay Down setting tool and make up Muleshoe BHA#4(second run) 19:45 20:15 0.50 0 575 PROD1 WELLPF TRIP T Trip in hole. 20:15 21:45 1.50 575 575 PROD1 WELLPF CIRC T Dump 21 sacks of 20/45 sand on top of IBP. 21:45 22:15 0.50 575 0 PROD1 WELLPF TRIP T Trip in and tag sand @ 651'dpmd. Trip out of hole. 22:15 23:45 1.50 0 0 PROD1 CSGRC'NUND P Nipple Down BOP Stack and set back on stand. 23:45 00:00 0.25 0 0 PROD1 CSGRC'SFTY P PJSM for growing 7"casing. Page 5 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/14/2015 24 hr summary Grow/Stretch 7"casing. Nipple Up BOPE. PU BHA#6(Drift)and TIH. Circulate well to heated water.TOOH. PU BHA#7(Multistring cutter)and TIH. Cut 7"casing @ 635'dpmd. Circulate out Arctic Pack. Deal with Gas and crude from OA sump below cut. 00:00 00:30 0.50 0 0 PROD1 CSGRC'RURD P Rig Up Hydratite. 00:30 08:00 7.50 0 0 PROD1 CSGRC'CUTP P Grow 7"casing. Casing growth: 26.25". Remove Packoff. Spear 7in with BHA#5 7in Spear and stretch 7"casing relanding in slips with 20,000#over string weight (80/100K). Lay Down BHA#5 and Cut off excess casing(total length of cut-off= 37 inches). 08:00 12:30 4.50 0 0 PROD1 CSGRC'NUND P Nipple up BOP Stack. 12:30 13:00 0.50 0 27 PROD1 CSGRC'BHAH T Make-up BHA#6...5 5/8"Swage. 13:00 14:15 1.25 27 649 PROD1 CSGRC'TRIP T Trip in with BHA#6. Passed through the original damaged section at 265-ft dpmd with no problems. Continue in hole. Tagged the top of sand at 649-ft. 14:15 14:45 0.50 649 556 PROD1 CSGRC'CIRC T Set back one stand. Circulate out Arctic Pack fluid invasion from the OA to IA communications path with 9.2 lb/gal Brine at 1.25 bpm/64 psi. Total volume pumped=20.0 bbls. Final 9.2 lb/gal in...9.2 lb/gal out. Blow down Top Drive. 14:45 15:00 0.25 556 27 PROD1 CSGRC'TRIP T Trip out with BHA#6. 15:00 15:15 0.25 27 0 PROD1 CSGRC'BHAH T Lay down BHA#6. 15:15 15:30 0.25 0 4 PROD1 CSGRC'BHAH T Make-up BHA#7...5 1/2"Multi-String Cutter. 15:30 16:15 0.75 4 640 PROD1 CSGRC'TRIP T Trip in with BHA#7. 16:15 17:00 0.75 640 635 PROD1 CSGRC'CPBO T Pre to cut 7"Casing. Locate 7" Casing Collars at 627-ft dpmd and at 583-ft dpmd. Drop down to 635-ft dpmd. Free spin Torque= 1,000 ft/lbs at 80 RPMs. Bring top drive on at 40,60 80 spm. Bring RPMs on at 40, 60,80 RPMs. Start"cut"...end "cut"in 5 minutes. Good signs. 17:00 19:45 2.75 635 635 PROD1 CSGRC'CIRC T Circulate out Arctic Pack from the 7" IA x 9 5/8"OA. Clean returns out the OA at 3bpm 260 psi. Once 290 bbls of hot water circulated chase with 9.2 Brine to fill backside with KWF. THen close OA and pump hole volume of 9.2 ppg Brine. 19:45 20:00 0.25 635 635 PROD1 CSGRC'OWFF T Gas bubbles at surfaces. 9.2 ppg Brine swapping with Arctic Pack and crude in OA Sump. 20:00 20:15 0.25 635 635 PROD1 CSGRC'CIRC T Pump 9.2 ppg Brine at 5 bpm 640 psi. 20:15 21:00 0.75 635 635 PROD1 CSGRC'CIRC T Circulate 9.2 ppg Brine at 1 bpm 80 psi. Page 6 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:15 0.25 635 635 PROD1 CSGRC'OWFF T Gas bubbles at surfaces. 9.2 ppg Brine swapping with Arctic Pack and crude in OA Sump. 21:15 22:00 0.75 635 635 PROD1 CSGRC'CIRC T Fill well with 9.2 ppg Brine with hole fill while returns taken out OA port to cuttings bin. 22:00 22:15 0.25 635 635 PROD1 CSGRC'OWFF T Gas bubbles at surfaces. 9.2 ppg Brine swapping with Arctic Pack and crude in OA Sump. 22:15 23:00 0.75 635 635 PROD1 CSGRC'CIRC T Continue to fill hole with hole fill and take returns out OA port to cuttings bin. 23:00 00:00 1.00 635 635 PROD1 CSGRC'CIRC T Circulate hole at 1 bpm 70 psi taking returns to pits. SIMOPS: Mix Hi Vis hole volume in pill pit. 35/15/2015 Continue to deal with gas and crude from OA sump below cut. Reverse down OA with Hi Viz 9.2 ppg brine, then 9.5 brine,then 12.0 brine. Gas and Crude Arctic pack returns continue at surface. 00:00 01:00 1.00 635 635 PROD1 CSGRC'OWFF T Gas bubbles at surfaces. 9.2 ppg Brine swapping with Arctic Pack and crude in OA Sump. SIMOPS: Mix Hi Vis hole volume in pill pit. 01:00 01:45 0.75 635 635 PROD1 CSGRC'CIRC T Close Bag and Pump 180 Hi Vis 9.2 ppg OA volume taking returns out OA port to cutting bin. Returns dirty with gas breakout. Open Bag and close OA port and continue pumping 180 Hi Vis 9.2 ppg through IA taking returns to pits and dumping dirty returns. Stop once hole full of Hi Vis 9.2 ppg Brine. 01:45 02:15 0.50 635 635 PROD1 CSGRC'OWFF T Monitor well/Gas bubbles at surface through Hi Vis 9.2 ppg Brine at surface. 02:15 03:15 1.00 635 635 PROD1 CSGRC'CIRC T Circulate OA volume to Cuttings Tank. Returns dirty with gas and crude cut. Circulate remainder of hole volume taking Hi Vis 9.2 ppg Brine to pits. Continue to circulate hole at 1 bpm 70 psi. 03:15 04:00 0.75 635 635 PROD1 CSGRC'OWFF T Gas bubbles at surfaces. 9.2 ppg Brine swapping with Arctic Pack and crude in OA Sump. SIMOPS: Line up to Reverse down OA taking returns to the pits up the IA.Also build 50 bbls of 9.5 ppg Brine in pill pit. 04:00 04:45 0.75 635 635 PROD1 CSGRC'CIRC T Reverse Circulate Hole Volume of 9.2 ppg Brine down OA taking returns to pits. SIMOPS: Continue to build 50 bbl of 9.5 Brine in pill pit. 04:45 05:15 0.50 635 635 PROD1 CSGRC'OWFF T Monitor Well, Gas bubbles and returns with crude at surface. SIMOPS: Blow Down Top Drive, PJSM for reverse in 9.5 hole volume. 05:15 06:00 0.75 635 635 PROD1 CSGRC'CIRC T Reverse Circulate in 48 bbls 9.5 ppg Brine at 1.5 bpm 70 psi taking returns back to the pits. Page 7 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 635 635 PROD1 CSGRC'OWFF T Monitor Well. Order out 12.0 Brine from 1-B Tank Farm. Occasionally pump 5 bbls of 9.5 lb/gal Brine down the OA to displace the Arctic Pack and Crude Oil from the 9 5/8"x 7" Annulus below the 7"cut at 635-ft. Trapped Arctic Pack and Dead Crude continue to perculate out of the Annulus from the cut down to the top of cement. Skim the light returns in the 7"to the Cuttings Bin. (Continue to wait on 12.1 Brine...Vac Truck shortage). 12:00 15:15 3.25 635 635 PROD1 CSGRC'CIRC T !2.11b/gal finally arices. Pump 12.0 lb/gal brine down the 9 5/8"7" Annulus from surface to the 7"cut at 635-ft dpmd. (20 bbls). 15:15 15:45 0.50 635 635 PROD1 CSGRC'OWFF T Observe good amount Artic Pack and Dead Crude flow to the cutting Bin. Continue to monitor and allow displaced OA fluids to rise to the top of the 7"x 3 1/2"Annulus. Allow heavy Brine to sink. 15:45 16:00 0.25 635 635 PROD1 CSGRC'CIRC T Slowly pump 5 bbls. Shut down. Once again recovered thick AP/DC. Estimate 4-5 bbls returned. 16:00 16:30 0.50 635 635 PROD1 CSGRC'OWFF T Monitor returns. 16:30 17:00 0.50 635 635 PROD1 CSGRC'CIRC T Slowly pump 10 bbls. Shut down. Recovered— 10 bbls. Cumulative total 12.0 lb/gal pumped=35. 17:00 18:00 1.00 635 635 PROD1 CSGRC'OWFF T Monitor returns. Fluid level in the Stack now showing signs of very slow drop. 18:00 18:15 0.25 635 635 PROD1 CSGRC'CIRC T Pump 10 bbls 12.0 ppg brine down OA at 0.75 bpm 50 psi. Returns include crude cut 12.0 ppg brine. 18:15 19:00 0.75 635 635 PROD1 CSGRC'OWFF T Monitor returns. Fluid level in the Stack now showing signs of very slow drop. 19:00 19:15 0.25 635 635 PROD1 CSGRC'CIRC T Pump 10 bbls 12.0 ppg brine down OA at 0.75 bpm 50 psi. Returns include crude cut 12.0 ppg brine. 19:15 20:15 1.00 635 635 PROD1 CSGRC'OWFF T Monitor returns. Fluid level in the Stack shows signs of very slow drop. Bleed—2.5 bbls of crude and gas out OA to cuttings bin. Fluid in stack continues to have significant rolling gas breakout. 20:15 20:30 0.25 635 635 PROD1 CSGRC'CIRC T Pump 10 bbls 12.0 ppg brine down OA at 1.5 bpm 75 psi. Returns include crude and 12.0 ppg brine indicating swapping with crude and arctic pack in OA sump. 20:30 21:30 1.00 635 635 PROD1 CSGRC'OWFF T Monitor returns. Gas break out of fluid at flow line continuous. Fluid level in the stack shows signs of very slow drop after 25 minutes. Page 8 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 21:45 0.25 635 635 PROD1 CSGRC'CIRC T Pump 10 bbls 12.0 ppg brine down OA at 1 bpm 60 psi. Returns 4 bbls pure crude followed by 6 bbls of crude cut brine. Indications of good swapping with crude and arctic pack in OA sump. 21:45 22:45 1.00 635 635 PROD1 ,CSGRC'OWFF T Monitor well. Rolling breakout of gas at flowline. Crude cap continues to be at top of fluid while gas breaking out. 22:45 23:00 0.25 635 635 PROD1 CSGRC'CIRC T Pump 10 bbls 12.0 ppg brine down OA at 1 bpm 60 psi. Returns 4 bbls pure crude followed by 6 bbls of crude cut brine. 23:00 23:45 0.75 635 635 PROD1 CSGRC'OWFF T Monitor well. Gas breakout and crude at top continues. 23:45 00:00 0.25 635 635 PROD1 CSGRC'CIRC T Pump 10 bbls 12.0 ppg brine down OA at 1 bpm 60 psi. Returns—3.5 bbls pure crude followed by 6 bbls of crude cut brine. 05/16/2015 Continue reverse down OA with 12.0 brine in 10-20 bbl increments. Gas and Crude Arctic pack returns continue at surface.Well died. TOOH and LD cutter BHA.. PU BHA#8(7"Spear). Spear Casing. Casing should not come free. LD Spear and PU Cutter BHA and TIH. Complete cut. TOOH and LD Cutter. PU 7" casing spear and spear casing. Break stack and pull slips. NU Stack. LD spear and 7"casing. 00:00 00:45 0.75 635 635 PROD1 CSGRC'OWFF T Monitor well. Gas breakout and crude at top continues. 00:45 01:15 0.50 635 635 PROD1 CSGRC'CIRC T Pump 20 bbls 12.0 ppg brine down OA at 1 bpm 60 psi. Returns—4 bbls pure crude artic pack followed by 16 bbls of crude cut brine. 01:15 06:00 4.75 635 635 PROD1 CSGRC'OWFF T Monitor well. Gas breakout and crude at top continues. Slight losses over time monitoring. SIMOPS: Dispatch truck for another load of 12.0 brine. 06:00 07:30 1.50 635 635 PROD1 CSGRC'CIRC T Pump 10 bbls of 12.0 bbls and recover 4 bbls of Dead Crude. Monitor. Repeat with same result, however, return appear to be mostly "black water". Suck stack down to ground level. 07:30 09:00 1.50 635 635 PROD1 CSGRC'OWFF T Monitor Well with fluid level at ground level. Observe some bubbles still breaking out. However, no fluid rise or fall. Discuss finding with Anchorage Engineering. Discuss a plan forward. 09:00 10:00 1.00 635 635 PROD1 CSGRC'CIRC T Close Pipe Rams. Circulate down the Drill Pipe with 12.0 lb/gal Brine at 1.0 bpm/62 psi...taking returns from the 9 5/8"x 7"Annulus. Close the OA. Open the Pipe Rams. Circulate down the Drill Pipe...taking returns from the 7"x 3 1/2"Annulus at 1.0 bpm/65 psi. 12.0 lb/gal returns from both sides Page 9 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 635 635 PROD1 CSGRC'OWFF T Monitor Well in the Stack x 30 minutes. Observe a steady tiny bubble break out. Fluid level dropped 3/4"...Well is static. Suck out Stack down to ground level(removed 15 psi of hydrostatic from the fluid column). Observe Well x 30 minutes. No rise in fluid level noted. Report results to Anchorage Engineering. 12:00 12:30 0.50 635 635 PROD1 CSGRC'SFTY T PJSM...discuss resuming operation. 12:30 13:00 0.50 635 4 PROD1 CSGRC'TRIP T Blow down Top Drive. Remove Blower Hose. Trip out with BHA #7...5 1/2"MS Cutter, standing back 3 1/2"Drill Plpe in the Derrick. 13:00 13:15 0.25 4 0 PROD1 CSGRC'BHAH T Lay down BHA#7. Observe normal expected wear on the blades. 13:15 13:45 0.50 0 0 PROD1 CSGRC'WWWH T Pick-up Swizzle Stick. Wash Stack. Lay down same. 13:45 14:00 0.25 0 0 PROD1 CSGRC'BHAH T Make-up BHA#8...5 3/4"ITCO Spear. Plant Spear in the 7"Casing. 14:00 14:30 0.50 0 0 PROD1 CSGRC'FISH T Attempt to pull 7"Casing. Casing not completely severed. Tried several attempts to break cut free...N o-Joy. 14:30 14:45 0.25 0 0 PROD1 CSGRC'BHAH T Release Spear and lay down same. 14:45 15:00 0.25 0 4 PROD1 CSGRC'BHAH T Pick-up BHA#9...5 1/2"MS Cutter (re-run). 15:00 15:30 0.50 4 635 PROD1 CSGRC'TRIP T Trip in with BHA#9 on 3 1/2" Drill Pipe from the Derrick. Set down at 265-ft dpmd in the damaged 7" Casing section. Work to get through. Continue in hole. Locate first cut attempt groove at 635-ft dpmd. 15:30 15:45 0.25 635 635 PROD1 CSGRC'CPBO T Complete 7"Casing cutin 2 minutes at 80 rpm,4.5 bpm/525 psi. Casing jumped and pressure dropped off to 200 psi. 15:45 16:00 0.25 635 4 PROD1 CSGRC'TRIP T Blow down Top Drive. Trip out with BHA#9 on 3 1/2"Drill Pipe standing back in the Derrick. 16:00 16:15 0.25 4 0 PROD1 CSGRC'BHAH T Lay down BHA#9. 16:15 16:30 0.25 0 15 PROD1 CSGRC'BHAH P Pick-up BHA#10...5 3/4"ITCO Spear. 16:30 17:30 1.00 36 635 PROD1 CSGRC'PULL P Plant spear and engage in 7"casing. Pickup 1'. 17:30 18:30 1.00 635 635 PROD1 CSGRC'NUND P Break BOP stack and lift off of Wellhead. 18:30 18:45 0.25 635 635 PROD1 CSGRC'SFTY P PJSM removing the casing slips. 18:45 21:00 2.25 635 635 PROD1 CSGRC'NUND P Remove Casing Slips. Set BOP stack back onto wellhead and tighten connections and turnbuckles. 21:00 21:30 0.50 635 598 PROD1 CSGRC'BHAH P Lay Down BHA#10 and joint of Drill Pipe. Page 10 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 598 0 PROD1 CSGRC'PULL P Lay Down 7"casing. cut joint at surface 34.73', 13 full joints(with 4 centralizers recovered), and cut joint at bottom 9.31'. 05/17/2015 Test BOP break. PU BHA#11 (RCJB),TIH and clean out sand on IBP. TOOH and LD BHA#12. PU IBP retrieval tool. TIH and Retrieve IBP. TOOH and LD IBP. PU BHA#13(Sleeve Retrieval Tool). and TIH. Retrieve and TOOH. LD Remaining 3.5"completion. 00:00 00:45 0.75 0 0 PROD1 CSGRC'RURD T Clean and Clear rig floor. Rig Down Power Tongs. SIMOPS Set test plug and Rig Up test equipment. 00:45 01:30 0.75 0 0 COMPZ CSGRC'BOPE P Test BOPE Stack Break(from previous casing and wellhead work) to 250/3000 psi 5 min each. Charted 01:30 02:00 0.50 0 0 COMPZ CSGRC'BOPE P Pull Test Plug. Set Wear Ring. (9" ID). Lockdown screw mistakenly backed out of Casing Head. Call out FMC Rep. 02:00 03:15 1.25 0 0 COMPZ CSGRC'WAIT T Wait on FMC wellhead hand to check lockdown screws. 03:15 04:45 1.50 0 0 COMPZ CSGRC'NUND T FMC Rep arrive and checks lockdown and threads. TTap needed to clear Threads. Mobilize second FMC Rep to ToolHouse to check for correct sized tap. Threads cleared and Lockdowns secured. 04:45 05:00 0.25 0 0 COMPZ WELLPF SFTY T PJSM for picking Up BHA. 05:00 05:30 0.50 0 40 COMPZ WELLPF BHAH T Pick Up BHA#11 RCJB. 05:30 06:00 0.50 40 650 COMPZ WELLPF TRIP T Trip in with BHA#11 to the top of sand at 650-ft dpmd. 06:00 07:30 1.50 650 693 COMPZ WELLPF CIRC T Displace 12.0 lb/gal Brine with 9.3 lb/gal Brine. Circulate and clean out sand at 1.9 bpm/1,150 psi from 650-ft dpmd down to 693-ft dpmd Circulate Well clean. 07:30 08:00 0.50 693 40 COMPZ WELLPF TRIP T Trip outwith BHA#11, standing back 3 1/2"Drill Pipe in the derrick. 08:00 08:30 0.50 40 0 COMPZ WELLPF BHAH T Lay down BHA#11. 08:30 09:00 0.50 0 39 COMPZ WELLPF BHAH T Make-up BHA#12...Retrieving Head 09:00 09:15 0.25 39 694 COMPZ WELLPF TRIP T Trip in with BHA#12 on 3 1/2"Drill Pipe from the Derrick to the top of the IBP at 694-ft. 09:15 09:45 0.50 694 694 COMPZ WELLPF MPSP T Release IBP. Allow elements to relax. 09:45 10:15 0.50 694 50 COMPZ WELLPF TRIP T Trip out with BHA#12 and the IBP. 10:15 10:45 0.50 50 0 COMPZ WELLPF BHAH T Lay down BHA#12 and the IBP. Recovered Baker IBP complete. 10:45 11:00 0.25 0 37 COMPZ RPCOM BHAH T Make up BHA#13...G-Spear. 11:00 11:30 0.50 37 727 COMPZ RPCOM TRIP T Trip in with BHA#13 on 3 1/2"Drill Pipe from the Derrick to 727-ft dpmd. Page 11 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:15 0.75 727 727 COMPZ RPCOM FISH T Up Weight=40K. Down weight=40 K. Wash the top of the Deployment Sleeve at 1.25 bpm/305 psi. Work to plant G-Spear. Latch and engage Deployment Sleeve. Up weight= 95K. 12:15 13:00 0.75 727 0 COMPZ RPCOM TRIP T Start tripping out with BHA#13 to the Deployment Sleeve with caution. Deployment Sleeve at surface. 13:00 13:15 0.25 0 0 COMPZ RPCOM BHAH T Lay down G-Spear and Deplloyment sleeve 13:15 16:00 2.75 6,818 6,818 COMPZ RPCOM CIRC P Well out of balance. Circulate in with 9.3 lb/gal Brine at 3.1 bpm/168 psi. Pump dry job. Blow down Top Drive. (SIMOPS Rig up GBR equipment. Rig up Control line Spooler). 16:00 16:15 0.25 6,818 6,818 COMPZ RPCOM SFTY P PJSM....discuss pulling the remainder of the completion. 16:15 18:00 1.75 6,818 5,743 COMPZ RPCOM PULL P Resume planned operations as per the program. Continue to single down the 3 1/2"Tubing to the SSSV...looking for the end of the Control Line. Up weight=85k. COntrol line mangled and wrapped on area beneath the SSSV. 18 total SS bands recovered. 18:00 18:30 0.50 5,743 5,743 COMPZ RPCOM RURD P Rig Down SLB spooling unit. 18:30 23:30 5.00 5,743 0 COMPZ RPCOM PULL P Lay Down Remainder of 3.5" EUE8rd completion. Light corrosion noted(on collars only)from 4433'to 6417'. Cut joint: 14.29' 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Rig Down power tongs. Clean and clear rig floor. 35/18/2015 PU BHA#14(Dressoff and 7"Scraper)and RIH. Dressoff cut joint. Single out of hole to 3100'.TOOH and LD BHA#14. PU , RIH and set RBP @ 3003'. 00:00 00:30 0.50 0 0 PROD1 WELLPF SVRG P Service Rig.Top Drive Inspection and service. 00:30 02:00 1.50 0 232 PROD1 WELLPF BHAH P Make Up BHA#14(3.5"Dress Off Shoe and 7"Casing Scraper)with 6 drill collars. Total Length 231.65 02:00 02:30 0.50 232 894 PROD1 WELLPF TRIP P Trip in hole with 7 stands from derrick. 02:30 08:30 6.00 894 7,537 PROD1 WELLPF PULD P Single in hole with Drill Pipe from Pipe Shed. Tag the top of the 3 1/2" Tubing stump at 7,537-ft dpmd. Page 12 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:45 1.25 7,537 7,553 PROD1 WELLPF MILL P Establish parameters as follows: Up Weight= 150K. Down weight=90K. Free spin torque=8,300 ft/lbs at 60 RPMs, Pump Rate=5.0 bpm/757 psi. Tag top of the 3 1/2"Tubing Stump. Mill down 3-ft to 7,540-ft dpmd. Pull off. Slide back over with no rotation. Good. Pull off. Rotate back over and continue down to 7,553-ft dpmd. Pull back off. Slide back over to 7,553-ft with no problem. Pull back off. Rotate back down one more time. Pull back off. Slide back down with no problem. Pull back off to 7,536-ft 09:45 12:30 2.75 7,536 7,536 PROD1 WELLPF CIRC P Rig floor to reverse circulate. Reverse in with a 30 bbl. Hi-Vis Sweep. Continue to reverse circulate with 9.2 lb/gal Brine at 3.8 bpm/775 psi. Total volume pumped=285 bbls. Pump dry job. 12:30 16:00 3.50 7,536 3,356 PROD1 WELLPF PULD P Single down 3 1/2"Drill Pipe to the Plpe Shed to 16:00 17:45 1.75 3,356 231 PROD1 WELLPF TRIP P Stand back the remaining 3 1/2"Drill Pipe in the Derrick. Set back Drill Collars. 17:45 19:00 1.25 231 0 PROD1 WELLPF BHAH P Lay down the remaining BHA#14 19:00 20:00 1.00 0 0 PROD1 WELLPF RURD P Clean and Clear Rig Floor. 20:00 20:30 0.50 0 0 PROD1 WELLPF SVRG P Service Rig 20:30 21:00 0.50 0 20 PROD1 WELLPF MPSP P PU RBP and Running tool. 21:00 23:30 2.50 20 3,008 PROD1 WELLPF TRIP P Trip in with RBP. Up Wt=73k, Dn Wt=60k 23:30 00:00 0.50 3,008 2,950 PROD1 WELLPF MPSP P Set RBP with center of element @ 3003'per BH Rep. 05/19/2015 TOOH and LD setting tool. PU Muleshoe and RIH. Dump Sand on RBP.TOOH.Test BOPE w/3.5"and 7" joints.All test PASS. Koomey draw test: 5 bottle avg 1975 psi. Pressure after all rams functioned 1700 psi. 200 psi recovery in 17 sec, full system pressure 90 sec. RU E-Line. Cement Bond Log 7"Casing. 00:00 00:30 0.50 2,950 2,950 PROD1 WELLPF MPSP P Test RBP 500 psi 5 min. 00:30 02:00 1.50 2,950 11 PROD1 WELLPF TRIP P Trip out of hole with RBP running tool. Up Wt=73k, Dn Wt=60k 02:00 02:15 0.25 11 7 PROD1 WELLPF BHAH P Lay Down running tool for RBP. PU Muleshoe. 02:15 03:30 1.25 7 2,848 PROD1 WELLPF TRIP P Trip in hole with Muleshoe. Up Wt= 68k, Dn Wt=59k 03:30 03:45 0.25 2,848 2,848 PROD1 WELLPF RURD P ,Rig Up Hopper and Circulating Equipment. 03:45 06:45 3.00 2,848 2,953 PROD1 WELLPF CIRC P Dump 20 sacks of course sand on top of RBP. Tag top of sand @ 2953'. 06:45 08:15 1.50 2,953 0 PROD1 WELLPF TRIP P Trip out of hole with Muleshoe. 08:15 09:00 0.75 0 0 PROD1 WELLPF WWWH P Wash Stack with jetting tool. 09:00 10:00 1.00 0 0 PROD1 WHDBO RURD P Pull Wear Ring. Set Test Plug. Fill Stack with Water. Rig Up test Equipment. Page 13 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 14:30 4.50 0 0 PROD1 WHDBO BOPE P Test BOPE. Perform weekly BOPE test per ConocoPhillips/AOGCC requirements at 250/3,000 psi with 3 1/2"and 7"Test Joints. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector, Bob Noble.All pressure tests PASS.All tests recorded on a chart. Koomey draw test,good. 5 bottle avg 1975 psi.Accum Pressure 2950 psi, Manifold Pressure 1550 psi,Annular Pressure 1450 psi. Pressure after all rams functioned 1700 psi.200 psi recovery in 17 sec, full system pressure 90 sec. 14:30 16:00 1.50 0 0 PROD1 WHDBO RURD P Rig Down Test Equipment. Lay Down Test joints and TIW valves. Blow down test lines. Pull test plug. Install Wear Ring. (9"ID) 16:00 18:00 2.00 0 0 PROD1 WELLPF QEVL P Rig Up Dutch Riser. Rig Up HES E-Line. 18:00 21:00 3.00 0 0 PROD1 WELLPF WAIT T Wait on E-Line Cement Bond Log equipment on flight from Deadhorse due to Bridge out conditions and inability to truck equipment across field. 21:00 00:00 3.00 0 0 PROD1 WELLPF QEVL P PU and RIH with Cement Bond Logging tool. Log from 2800'up. 35/20/2015 Cement Bond Log 7"Casing. RD E-Line. PU BHA#15(MSC). Cut 7"Casing. TOOH and LD BHA#15. PU BHA#16(7"Spear), TIH and Spear casing. Circulate out Arctic Pack. POOH, LD 7'Spear. LD 7"Casing. PU BHA#17(9-5/8"Casing Scraper)and RIH.Tag up at 265'.TOOH and LD BHA#17. PU BHA#18(RCJB). 00:00 02:15 2.25 0 0 PROD1 WELLPFQEVL P Continue E-Line Cement Bond Log. _POOH. Lay Down CBL Tool String. 02:15 03:15 1.00 0 0 PROD1 WELLPF QEVL P ,Rig Down E-Line. Rig Down Dutch Riser. 03:15 03:45 0.50 0 5 PROD1 CSGRC'BHAH P Pick Up BHA#15(Multi String Cutter). SIMOPS: Contact CPAI Engineer. Decision to cut at—2222' dpmd. 03:45 06:00 2.25 5 2,228 PROD1 CSGRC'TRIP P Trip in hole. Up Wt=63k, Dn Wt= 55k. Locate Collars above(2218') and below(2263')cut location. Cut 10'below top of joint. Cut at 2228' dpmd. 06:00 06:45 0.75 2,228 2,223 PROD1 CSGRC'CPBO P Cut 7"casing at 2228'. 80 RPM, Free Tq 1 k, 2.3 bpm at 275 psi,4.6 bpm at 860 psi. Observe psi drop to 370 psi. Pumps off. Pick up 5'above cut. 06:45 07:00 0.25 2,223 2,223 PROD1 CSGRC'OWFF P Monitor well. 07:00 08:00 1.00 2,223 4 PROD1 CSGRC'TRIP P Trip out of hole with BHA#15. 08:00 09:00 1.00 4 220 PROD1 CSGRC'BHAH P Lay Down BHA#15. Pick Up BHA #16(Spear with Packoff).All per Baker Rep. Page 14 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:30 0.50 220 598 PROD1 CSGRC'TRIP P Trip in hole with BHA#16. See Tight Spot when tag up at 265'.Work through and continue in hole to 598'. Up Wt=43k. 09:30 10:00 0.50 598 2,223 PROD1 CSGRC'FISH P RIH and plant spear in casing stub @ 635'(Stop Ring Depth). Engage Grapple, pull 105k and observe 7" _ free. 10:00 12:45 2.75 2,223 2,223 PROD1 CSGRC'CIRC P Pump 290 bbls of Hot Freshwater 3.5 bpm at 220 psi. Chase with hole volume of 9.2 Brine at 4 bpm 100 psi. 12:45 13:00 0.25 2,223 2,223 PROD1 CSGRC'OWFF P Monitor Well. Blow Down Top Drive. 13:00 14:00 1.00 2,223 1,593 PROD1 CSGRC'TRIP P Trip out of hole with Speared 7" casing. 14:00 15:00 1.00 1,593 1,593 PROD1 CSGRC'RURD P Rig Up Power Tongs. 15:00 17:30 2.50 1,593 0 PROD1 CSGRC'PULL P Lay Down Cut 7"casing. Lay Down 35 full joints and 2 cut pieces. Top cut Joint: 34.80'; Bottom cut joint: 10.47' 17:30 18:00 0.50 0 0 PROD1 CSGRC'RURD P Rig Down Power Tongs. 18:00 19:00 1.00 0 0 PROD1 CASING RURD P Clean and Clear Rig Floor. 19:00 20:00 1.00 0 216 PROD1 CASING BHAH P Pick Up BHA#17(9-5/8"Surface Casing Scraper). 20:00 21:00 1.00 216 265 PROD1 CASING TRIP P Observe BHA Stack out at 265'. Attempt 3 times, no progress. Make Up to Top Drive and try 3 times with Top Drive Weight, no progress. 21:00 22:30 1.50 265 265 PROD1 CASING SFTY P Meeting with CPAI leadership. SIMOPS: Monitor Well 22:30 23:00 0.50 265 0 PROD1 CASING BHAH P Lay Down BHA#17. 23:00 23:30 0.50 0 213 PROD1 CASING BHAH P Pick Up BHA#18(RCJB). 23:30 00:00 0.50 213 742 PROD1 CASING TRIP P Trip in hole with BHA#18. 05/21/2015 RIH with BHA#18. Circulate hole to hot water. Slip and Cut Drilling Line. Circulate out hot water and sand on top of RBP. TOOH and LD BHA#19. PU and TIH with RBP Retrieval Tool. Release RBP. POOH and LD RBP. PU BHA#19(Junk Basket).TIH and SIH with Drill Pipe. 00:00 02:15 2.25 742 2,860 PROD1 CASING TRIP P Trip in hole with BHA#18 to 2860'. Up Wt=73k, Dn Wt=60k. 02:15 02:30 0.25 2,860 2,860 PROD1 CASING SFTY P PJSM Circulating well over to Hot freshwater. 02:30 03:30 1.00 2,860 2,860 PROD1 CASING CIRC P Circulate 285 bbl hot freshwater with Deep Clean. 5 bpm 640 psi. 03:30 03:45 0.25 2,860 2,860 PROD1 CASING SFTY P PJSM for Slip and Cut of Drilling Line. 03:45 05:00 1.25 2,860 2,860 PROD1 CASING SLPC P Slip and Cut 102' Drilling Line. 05:00 05:30 0.50 2,860 2,860 PROD1 CASING SVRG P Service Drawworks and Top Drive. 05:30 06:30 1.00 2,860 2,680 PROD1 CASING RURD P Rig Up to Circulate taking first 180 bbls out to Open top tank and taking reminder across shakers and back into pits. Page 15 of 23 Time Logs —Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:30 08:00 1.50 2,680 2,680 PROD1 CASING CIRC P Circulate Hot Freshwater and arctic pack out of hole to Open top tank, 3 bpm 330 psi. 08:00 09:00 1.00 2,680 2,984 PROD1 CASING CIRC P Circulate out sand on top of RBP with RCJB from Top of Sand at 2951' to 2984'at 7 bpm 1180 psi until shaker clean. Up Wt=73k, Dn Wt= _ 60k. 09:00 10:00 1.00 2,984 213 PROD1 CASING TRIP P Trip out of hole with BHA#18. 10:00 11:00 1.00 213 0 PROD1 CASING BHAH P Lay Down BHA#18. 11:00 13:00 2.00 0 2,950 PROD1 CASING TRIP P Trip in hole with RBP Retrieval tool. 13:00 14:30 1.50 2,950 3,003 PROD1 CASING CIRC P Circulate down onto RBP clearing remaining sand 6 bpm 390 psi. J onto RBP and release. Shakers clean up.263 bbls pumped. Up Wt= 72k, Dn Wt=60k. 14:30 17:30 3.00 3,003 24 PROD1 CASING TRIP P Trip out of hole with RBP.second single out of hole observed RBP pull tight. Kelly Up and pump 1.5 bpm 80 psi. RBP free. Pull out on elevators with no problem after 2 stands. Decision made to Trip out standing back Drill Pipe and start loading shed with 150 joints Drill Pipe to run Boot Basket to ensure tubing stub is clear. 17:30 18:00 0.50 24 0 PROD1 CASING BHAH P Lay Down RBP and Retrieval Tool. 18:00 19:30 1.50 0 0 PROD1 CASING WWWH P Pull Wear Ring. Flush stack with Jetting tool. Install Wear Ring. 19:30 22:45 3.25 0 226 PROD1 CASING BHAH P Pick Up BHA#19(Boot Basket and Dress Off Mill). Pick Up 6 Drill Collars and BHA components. 22:45 00:00 1.25 226 2,404 PROD1 CASING TRIP P Trip in hole. Observe tight spot at 265'. Takes 4k down to move through. 05/22/2015 SIH BHA#19 with Drill Pipe. Dress tubing stub and ensure clean. Pump BU. Change out BOP Rams. Test BOP with 5.5"test joint. PU and RIH with 5.5"casing. 00:00 00:30 0.50 2,404 3,351 PROD1 CASING TRIP P Trip in hole. Observe tight spot at 265'. Takes 4k down to move through. 00:30 04:30 4.00 3,351 7,530 PROD1 CASING PULD P RIH with BHA#19 picking up Drill Pipe from Pipe Shed. 04:30 05:15 0.75 7,530 7,530 PROD1 CASING CIRC P Establish parameters: Up Wt= 153k, Dn Wt=88k, Rot Wt= 112k, Free Tq=7k. 6bpm©920 psi. Circulate and rotate down over stub. Top @ 7537'dpmd. Page 16 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 06:00 0.75 7,530 7,530 PROD1 CASING CIRC P Circulate 570 bbls until shakers clean up. 10 bpm @ 2400 psi. sand and artic pack across shakers and then cleans up. Take SPRs. SPRs Pump 1: 2 bpm = 155 psi; 3 bpm = 290 psi Pump 2: 2 bpm = 160 psi;3 bpm= 290 psi 06:00 06:15 0.25 7,530 7,530 PROD1 CASING OWFF P Monitor Well. 06:15 12:30 6.25 7,530 226 PROD1 CASING PULD P POOH laying down Drill Pipe. 12:30 13:30 1.00 226 0 PROD1 CASING BHAH P Lay Down BHA#19. 13:30 14:00 0.50 0 0 PROD1 CASING BOPE P Pull Wear Ring. 14:00 15:00 1.00 0 0 PROD1 CASING BOPE P Wash BOP Stack with Jetting tool. 15:00 15:30 0.50 0 0 PROD1 CASING BOPE P Install Test Plug. 15:30 17:00 1.50 0 0 PROD1 CASING BOPE P Change out lower Pipe Rams to 5.5" solid Body Rams. 17:00 17:30 0.50 0 0 PROD1 CASING BOPE P Fill stack with Water and Rig Up Test equipment. 17:30 19:30 2.00 0 0 PROD1 CASING BOPE P Test BOP with 5.5"test joint.Test 5.5"Solid Body Rams in LPR, 3.5"x 6"VBR in UPR and Annular.All passed. Charted. 19:30 20:30 1.00 0 0 PROD1 CASING BOPE P Drain BOP Stack. Pull Test Plug. Rig Down Test Equipment. 20:30 21:00 0.50 0 0 PROD1 CASING RURD P Rig Up Casing Running Equipment and Power Tongs. 21:00 21:30 0.50 0 0 PROD1 CASING SFTY P PJSM with crew, BOT reps, and GBR for Running 5.5"Casing String. Discuss safety and hazard recognition isues. Discuss procedure to run 5 1/2" Liner tieback string. 21:30 00:00 2.50 0 735 PROD1 CASING PUTB P Run 5.5"Liner tieback string. 35/23/2015 RIH with 5.5"casing. Break Stack and set 5.5"slips and packoff. Nipple Down BOPE. Nipple Up Tubing Head.Test Packoff to 3000 psi. Nipple Up BOPE. 00:00 10:30 10.50 735 7,728 PROD1 CASING PUTB P Run 5.5"Liner tieback string. Up Wt: 133k, Dn Wt=80k. Observe overshot go over stub and indicator shear screws shear. Confirm with pumps by swallowing stub and observing pump pressure increase. 10:30 12:30 2.00 7,728 0 PROD1 WHDBO NUND P Drain BOP Stack. break DSA bolts and Raise Stack. Set Slips on 5.5" pipe in wellhead profile. 12:30 14:00 1.50 0 0 PROD1 CASING CUTP P Rig Up Wachs cutter and cut off excess 5.5"pipe. 15.46' left in hole, 22.43'Laid Down on joint#174. 14:00 18:00 4.00 0 0 PROD1 CASING NUND P Stand Back BOP Stack. Install Packoff. Break Down DSA and spacer spool. Remove Spacer Spool from cellar. Put 2-7/8"x 5"VBR Ram sets in cellar. Page 17 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:15 2.25 0 0 PROD1 CASING NUND P Nipple Up new Tubing head and torque bolts. 20:15 20:45 0.50 0 0 PROD1 CASING WWSP P Pressure test packoff to 3000 psi for 10 min. 20:45 23:00 2.25 0 0 PROD1 CASING NUND P Nipple Up BOP stack and torque bolts. 23:00 00:00 1.00 0 0 PROD1 CASING BOPE P Change out Upper Rams from 3-1/2" x 6"VBR and Lower Rams from 5.5" Solid Rams to 2-7/8"x 5"VBRs (both cavities). 05/24/2015 Change BOP Rams. Test BOPE w/3 1/2"and 2 7/8"joints. One F/P due to flange leak on line from HCR to choke manifold.ALL other test PASS. Koomey draw test: 5 bottle avg 1970 psi. Pressure after all rams functioned 1700 psi.200 psi recovery in 19 sec,full system pressure 99 sec. PU and RIH with 2-7/8"Work String. 00:00 01:30 1.50 0 0 PROD1 CASING BOPE P Continue to change out Upper Rams from 3-1/2"x 6"VBR and Lower Rams from 5.5"Solid Rams to 2-7/8" x 5"VBRs(both cavities). 01:30 02:15 0.75 0 0 PROD1 CASING NUND P Nipple Up Riser. 02:15 03:00 0.75 0 0 PROD1 WHDBO RURD P Rig Up Test equipment. Fill Stack with water. 03:00 09:00 6.00 0 0 PROD1 WHDBO BOPE P Test BOPE. Perform weekly BOPE test per ConocoPhillips/AOGCC requirements at 250/3,000 psi with 3 1/2"and 2 7/8"Test Joints. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector,John Crisp. 09:00 10:00 1.00 0 0 PROD1 WHDBO BOPE T Mobilize FMC for to redress test plug rubber. 10:00 10:30 0.50 0 0 PROD1 WHDBO BOPE P Koomey draw test, good. 5 bottle avg 1970 psi. Accum Pressure 2800 psi, Manifold Pressure 1650 psi,Annular Pressure 1100 psi. Pressure after all rams functioned 1700 psi.200 psi recovery in 21 sec, full system pressure 99 sec. 10:30 12:30 2.00 0 0 PROD1 WHDBO BOPE T Redress rubber on test plug. Plug still bleeding off. Change out test plug. 12:30 17:30 5.00 0 0 PROD1 WHDBO BOPE P Continue to test BOPE. Continue weekly BOPE test per ConocoPhillips/AOGCC requirements at 250/3,000 psi with 3 1/2"and 2 7/8"Test Joints. Perform the Koomey draw down test. Test Gas Alarms. The State's right to witness the test was waived by AOGCC Field Inspector John Crisp. 17:30 18:30 1.00 0 0 PROD1 WHDBO RURD P Rig Down BOPE testing equipment and blow down lines. 18:30 19:30 1.00 0 0 PROD1 CEMEN-RURD P Pull test plug. Set Wear Ring (6-7/16" ID). Rig Up GBR equipment. Rig Up to run 2-7/8"HYD511 work string. Page 18 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 19:45 0.25 0 0 PROD1 CEMENT SFTY P PJSM for running 2-7/8"HYD511 ,work string. 19:45 00:00 4.25 0 3,013 PROD1 CEMENT PULD P Make up BOT Cup Inflation tool assembly and continue RIH with 2-7/8"HYD511 work string picking up singles from pipe shed. X5/25/2015 PU and RIH with 2-7/8"Work String and Cup Inflation tool assembly. Set Packer. Pump 22.5 BBLS of Lead and 31.1 BBLS of tail Cement in the st Stage Cement Job. CIP @ 11:30 HRS. Ensure HMCV valve is closed and tested. POOH and LD Work String#1. PU Work String#2 with TAM port collar assembly. 00:00 03:45 3.75 3,013 6,577 PROD1 CEMENT PULD P Continue RIH with 2-7/8"work string picking up singles from pipe shed. 03:45 04:00 0.25 6,577 6,577 PROD1 CEMENT SFTY P Kick While Tripping Drill. 04:00 04:30 0.50 6,577 6,577 PROD1 CEMENT SVRG P Service Rig. Inspect and service Top Drive. 04:30 06:30 2.00 6,577 7,513 PROD1 CEMENT PULD P Continue RIH with 2-7/8"work string picking up singles from pipe shed. Install 10'pup and tag crossover at 7513'as planned. Set down 3K. Obtain string weights-UP WT-75K, SO WT-50K. 06:30 08:00 1.50 7,513 7,513 PROD1 CEMENT RURD P Pick up. Breakout&lay down 10' pup joint. Install 5'pup joint. Make up crossover and FOSV with head pin and crossover to 3 1/2"elevators to hang sting on Top drive.Attach hoses,valves to head pin. Line up to pump. 08:00 08:45 0.75 7,513 7,513 PROD1 CEMENTCIRCP With the rig, locate on the crossover again at 7513'. Begin circulating to obtain a 1 1/2 bottoms up. Pumps at 3 BPM-770 PSI. 08:45 09:30 0.75 7,513 7,513 PROD1 CEMENT CIRC P Break connection. Install dart as planned. Position cups across the packer. Line up on Schlumberger, load lines and pressure test lines to 4900 PSI. Record on chart.With rig, pump down cement string at 3 BPM -770 PSI to observe dart land at 721 stks. Turn over to Schlumberger and pressure down cement string to 4800 PSI to allow S-3 Packer to set. Hold 15 Minutes. Bleed pressures to 0 PSI. 09:30 10:00 0.50 7,513 7,513 PROD1 CEMENT CIRC P Pull up to locate in the indicator sub at 20', and with 5K overpull. Stop. Pressure down cement string to burst the HMCV valve open at 2000 PSI. Observed fluid returns through the OA as planned. Establish circulating rates at 1 BPM-240 PSI, 2 BPM-595 PSI, 3 BPM-940 PSI, and 4 BPM-2000 PSI. Continue pump 10 BBLS verifying good circulation. Page 19 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:30 0.50 7,513 7,513 PROD1 CEMEN-SFTY P Held PJSM with crew, BOT reps, Truck drivers, and Schlumberger cementing crew. Discuss safety and hazard recognition issues. Discuss procedure to mix and pump cement job. 10:30 11:45 1.25 7,513 7,513 PROD1 CEMEN'CMNT P Turn over to Schlumberger. Pump cement job as follows. Pump 15 BBLS of 8.5 Freshwater. Followed with 22.5 BBLS of 13#Lead cement, and the 31.1 BBLS of 15.8#Tail cement. Chase with 10 BBLS of 8.3# Fresh water, and displace the cement with 33.3 BBLS of 9.2 Brine. Observed good lift pressure keeping pump pressure below 3000 PSI. ICP -3 BPM-770 PSI, and FCP-2800 PSI.With pumps off, record stabilized pressure at 110 PSI. CIP at 11:30 HRS 11:45 12:00 0.25 7,513 7,513 PROD1 CEMEN-CMNT P With cement in place. Holding 1100 PSI, Pick up string to 10K over weight to snap through the indicator, continuing to pull 5'until second 10K overpull recognized,to close the HMCV valve permanently. Bleed pressure and observed no returns, indicating valve closed. 12:00 12:30 0.50 7,513 7,513 PROD1 CEMEN-CIRC P Observed no flow,valve closed, rig up and reverse circulate 2 cement string volumes observing no cement returns. Rates at 4 BPM-1200 PSI. 12:30 12:45 0.25 7,513 7,513 PROD1 CEMEN PRTS P Slack off to reposition the cups, and ported sub. Pressure test the HMCV valve last time to 2100 PSI. Record on chart. Good test. once again indicating valve permanently closed. 12:45 13:30 0.75 7,513 7,420 PROD1 CEMEN'PULD P Rig down circulating lines. POOH lay down 3 joints of cement string to allow ported sub to be in the 5 1/2" string. 13:30 14:00 0.50 7,420 7,420 PROD1 CEMEN-CIRC P Rig up lines again and reverse circulate 2 string volumes observing no cement returns 4bpm at 980 psi, and balanced fluid at 9.2 PPG. Rig down surface lines and valves. Blow down same. 14:00 22:00 8.00 7,420 0 PROD1 CEMEN'PULD P POOH, breakout and lay down the 2 7/8"cement string. leave 75 joints of pipe in shed for BHA change out, and second stage cement job. 22:00 22:15 0.25 0 0 PROD1 CEMEN BHAH P Visual inspect and lay down Cup Inflation BHA.All componenets looked good. 22:15 22:45 0.50 0 0 PROD1 CEMEN RURD P Clean and clear rig floor Page 20 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 23:15 0.50 0 0 PROD1 CEMEN-BHAH P Pick Up TAM port colar BHA for Work String#2. Observe the tool dogs snag or catch on wellhead near bottom of wear ring. POOH 23:15 23:45 0.50 0 0 PROD1 CEMEN-RURD T BOLDS. Pull Wear Ring. No significant indications observed on wear ring. 23:45 00:00 0.25 0 0 PROD1 CEMEN-BHAH T Attempt to work Tam Port Work String through Wellhead. No success. 05/26/2015 PU and RIH with TAM port collar work string assembly on 2 7/8"HYD 511 pipe. Locate and verify opening and closing of valve. Repeat process. RU and pump 115.4 BBL Cement job as planned with 19 BBLS of cement observed at surface. Clos TAM port collar and test same to 1500 PSI,to verify. Reverse circulate clean, and POOH, lay down 2 7/8"pipe. RU and run 3 1/2" IBTM completion string as planned. 00:00 01:00 1.00 0 0 PROD1 CEMEN-BHAH T Lay Down Work String for Tam Port collar. Pickup back up work string. Observe work string dogs go through wellhead. Cups on BHA catch on tubing head ledge or top of 5.5"liner cut joint.Work cups through with weight and slight turning. SIMOPS: Schlumberger Cement crew rigging up. 01:00 03:45 2.75 0 1,707 PROD1 CEMEN-PULD P RIH with TAM port collar work string picking up 2-7/8"HYD511 singles from pipe shed. Locate the inside shifting collar with opening dogs at 1707' DPM. Locate closing dogs at 1708' in the up stroke. Locate the channel to allow shifting tool dogs through the collar. 03:45 04:00 0.25 1,707 1,707 PROD1 CEMEN-SFTY P PJSM with crew, Mud Engineer, PESI rep, and Schlumberger reps. Discuss safety&hazard recognition issues. Discuss procedure to rig up and pump stage 2 cement job. 04:00 05:15 1.25 1,707 1,707 PROD1 CEMEN-RURD P 1 Rig up floor lines and valves to pump cement. 05:15 07:30 2.25 1,707 1,707 PROD1 CEMEN-CIRCP Locate TAM collar with shifting tool. Pressure test TAM port collar. Confirm closed. Open TAM port collar and check flow path. Put work string in position to close TAM Port collar. Initially,we had trouble getting the TAM collar to open. Continue to repeat attempts with pressure testing and pumping each way.The collar opened fiannly with 15K set down weight.We verified with returns,and pumping. Repeat opening and closing procedures to ensure all is well before cement is pumped. Page 21 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 1,707 1,707 PROD1 CEMEN-SFTY P Held PJSM with rig crew, mud engineer, drivers, Sch;umberger cementers, and PESI rep. Discuss safety and hazard recognition issues. Discuss procedure to pump cement job as plannned. Designate a Spill champion. 08:00 09:30 1.50 1,707 1,707 PROD1 CEMEN-CMNT P With Schlumberger, pump 10 BBLS of 8.3#Fresh water at 3 BPM-220 PSI. Shut in, and pressure test lines to 3000 PSI-good test. Perform pump stall exercise, and check for leaks. Bleed pressure. Batch up, and pump 10.2 BBLS of 15.7 PPG NEAT AS!cement. Continue pump 93 BBLS of Pressure Net Cement, and the 12.2 BBLS of 15.7#NEAT AS! cement. Continue with schlumberger to displace well with 12.2 BBLS of fresh water. Observed cement at surface at 96 BBLS pumped away and a total of 19 BBLS of cement to surface. Observed good lift pressure with FCP at 3 BPM-875 PSI. Hold pressure at 650 PSI. CIP @ 0920 HRS 09:30 10:15 0.75 1,707 1,707 PROD1 CEMEN-CIRCP CIP @ 0920 HRS. Pull up to close TAM Collar with 10K overpull. Presure test to 1000 PSI,the 1500 PSI to verify closed position. Good test-No flow. Continue pick up to clear dogs from the tool. Repeat pressure test to 1500 PSI to verify once again,that the collar is closed and no flow observed. Pull up 20' more. Line up and reverse circulate 2 bottoms up to verify no cement in string, and all fresh water clear. No cement observed at surface.Well balanced at 9.2 PPG. 10:15 11:15 1.00 1,707 1,707 PROD1 CEMEN-RURD P Blow down lines, and remove valves and lines form string. NOTE: String was not lowered back in the hole to prevent the cups form dragging on collar.All tools and equipment including Schlumberger cementers blown down and rigged down.Well- static. Prep pipe shed for laying down 2 7/8" Hydril pipe. Rig up GBR tongs. 11:15 13:30 2.25 1,707 0 PROD1 CEMEN-PULD P POOH, breakout and lay down the 2 7/8" Hydril 511 cement string. Observed proper displacement. Inspect, breakout and lay down the TAM port Combo tool assembly. 13:30 14:30 1.00 0 0 COMPZ RPCOM RURD P Change over handling equipment to 3.5" PJSM Page 22 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 00:00 9.50 0 7,430 COMPZ RPCOM RCST P Pick up&RIH W/new completion as per program. Up wt=85 K, Dwn wt= 58 K 05/27/2015 Spaced out and landed completion. PT IA to 2500 psi for 30 min's. Tested Tbg.to 3000 psi for 30 min's. Installed BPV. Completed BOPE BWM. ND BOPE 00:00 01:30 1.50 7,430 7,423 COMPZ RPCOM HOSO P Engage seal assembly with pump on. and calculate space out sub required. Install subs 01:30 02:00 0.50 7,423 7,423 COMPZ RPCOM THGR P Install hanger and landing jt on top drive. 02:00 03:45 1.75 7,423 7,423 COMPZ RPCOM CRIH P PJSM.Pump 90 BBLs of Congor 303 treated 9.2 brine displaced with 65 BBIs 9.2 brine. @ 3 BPM @ 400 PSI. 03:45 04:15 0.50 7,423 7,442 COMPZ RPCOM THGR P Engage seal assembly with pumps on. Pressure increase of 150 psi. SD pump. Land hanger RILDS 04:15 09:30 5.25 7,442 COMPZ RPCOM PRTS P Attempted to pressure up on tbg t 3000 psi. lost 200 psi in 10 min's. Bled pressure down to 1800 psi. Pressure up on IA to 2500 Psi. Good IA test. Retest Tbg. Good test. Shear SOV @ 3000 psi. 1400 psi to Circulate thru it @ 2BPM 09:30 10:00 0.50 COMPZ RPCOM OWFF P Flow check 30 min's. 10:00 10:30 0.50 COMPZ WHDBO MPSP P Install BPV. Test Both directions to 1000 psi. good test. 10:30 11:30 1.00 COMPZ WHDBO WWWH P Wash BOPE stack to prep for inspection 11:30 21:30 10.00 COMPZ WHDBO SVRG P Complete BWM inspection on BOPE 21:30 23:30 2.00 COMPZ WHDBO NUND P ND BOPE 23:30 00:00 0.50 COMPZ WHDBO NUND P NU Tree adaptor 35/28/2015 Freeze protected well. Install BPV. Rig Released @ 06:00 hrs 00:00 00:30 0.50 COMPZ WHDBO NUND P Continue to NU Tree adaptor and test to 5K for 10 min's good test. 00:30 02:30 2.00 COMPZ WHDBO NUND P Nu tree. Tree placement OK'd By DSO 02:30 03:00 0.50 COMPZ WHDBO PRTS P Set test plug and PT tree 250/5000 psi. Pull test plug 03:00 04:00 1.00 COMPZ WHDBO FRZP P PJSM: RU LRS to freeze protect well with 52 BBIs of Diesel. RD LRS 04:00 05:00 1.00 COMPZ WHDBO FRZP P Line up and U-tube well until dead. 05:00 05:30 0.50 COMPZ WHDBO MPSP P Install BPV. Check pressures. TBG =40 PSI, IA-40 PSI, and OA-0 _ PSI, 05:30 06:00 0.50 DEMOB MOVE RURD P Secure well and cellar. Rig Released at 0600 HRS. Page 23 of 23 AG- oo WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 27, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEWED RE: Radial Cement Bond Log: 2A-09 JUN 0 4 2015 Run Date: 5/20/2015 AOGCC 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-09 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20059-00 Radial Cement Bond Log (Field Print) 1 Color Log 50-103-20059-00 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 119A‘a-P144) 6 � OF 7•y� ap ,�\ I%%i so THE STATE Alaska Oil and Gas mw ':, --7-; ofA T ccl T k Conservation Commission _ 4014t-::=;_. 333 West Seventh Avenue larr:*h„ GOVERNOR BILL WALKER I Anchorage, Alaska 99501-3572 hq Main: 907.279.1433 FILA`-' p� Y B ZUIJ Fax: 907.276.7542 SCNED 4�,�• www.aogcc.alaska.gov Travis Smith © d 1 Wells Engineer ConocoPhillips �! Alaska, Inc. t 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A-09 Sundry Number: 315-252 Dear Mr. Smith: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, al4 &_ Cathy P. oerster Chair DATED this day of May, 2015 Encl. STATE OF ALASKA AL ..,KA OIL AND GAS CONSERVATION COMI :ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell F, Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing 1.7, Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing rd, Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development p , 186-001 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20059-00. 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p., KRU 2A-09-- 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): rEffective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8535 • 6204 • 7609' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110' 110' SURFACE 3374 9.625 3409' 2772' PRODUCTION 7919 7 7954' 5813' RECEIVED LINER 809 - 5 8525' 6197' AP 2 ^ 2015 S e iJ U CC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8136-8182,8242-8252,8271-8304 • 5935-5966,6006-6013,6026-6048 3.5 J-55 7587 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-CAMCO 2.875"X 7"HRP-1-SP RETRIEVABLE PACKER MD=7587 TVD=5567, PACKER-BAKER DB PACKER MD=8196 TVD=5975 SSSV -CAMCO TRDP-2SSA Non-Equalizing Safety Valve MD=1802 TVD=1682. 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work. Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r" Development F, Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/8/2015 Oil r , Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG I- 17. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Travis Smith @ 265-6450 Email: Travis.T.Smitht .conoco hillips.com Printed Namer is Smith Title: Wells Engineer Signature /J���iJ Phone:265-6450 Date L� L� �— /(� �J' Commission Use Only Sundry Number�1 Conditions of approval: Notify Commission so that a representative may witness 3 15– - 2- Plug Integrity r BOP Test VMechanical Integrity Test r Location Clearance r Other: 5,0F 7~cs t to O a 0 r,s ( � f t� Z o p5 4/-)v (.7 / p cvt� ft esI Spacing Exception Required? Yes ❑ No [] Subsequent Form Required: /b — 4 D G}- APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: S" S- l...5- V,T4_ 3 t./15— Approo dRicGNalA L 12 months t om the date of approval. Form 10-403(Revised 10/2012) 71' i Submit Form and Atta ents in Duplicate ,t. 11/2-1W RBDM MAY 1 1 2015 ConocoPhillips Alaska RECEIVED P.O. BOX 100360 APR 2 7 2 015 ANCHORAGE,ALASKA 99510-0360 AOGCC April 27,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: i ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk ylitrefor 2A- 09(PTD# 186-001). Well 2A-09 was drilled and fracture stimulated in 1986 as an A/C Sand selective single completion. The well was produced as an A-Sand only well with the selective closed from 1986 to 1988. The C-Sand was opened in 1988. In 1994, well work indicated that a GLM had been collapsed and a rig workover replaced the 2-7/8" completion string with a new 3-'/2"gas lift completion. Well 2A-09 has been diagnosed with leaks in the 7"production casing at 4,800 feet RKB and 4,940 feet RKB. The well was shut-in on 6/22/2014 after failing a mechanical integrity test of the inner annulus (MITIA) during routine subsidence surveillance. Per ConocoPhillips operating standards, the well will not be returned to production until a workover is successfully completed. The proposed workover plans are to pull the upper 3 %"tubing completion, cut and pull the 7"casing above the top of cement, and run a 5-'/2" casing string from the packer to surface, with cement in the 5-'h" x 7" and 7" x 9-%" annuli. A new 3 'h"upper completion will then be run. This Sundry is intended to document the proposed work on the production well because of the modification to the production casing and request approval to workover the well. If you have any questions or require any further information,please contact me at 265-6450. Sincer ,!, ar. a is math ells Engineer CPAI Drilling and Wells r i • 2A-09 Rig Workover Subsidence RWO (PTD #:186-001) Current Status: This well has been SI since July 2014 because of a production casing leak. The well is isolated from the reservoir with a wireline retrievable plug set at 7,609'. Scope of Work: The proposed workover plans are to pull the upper 3 'h" tubing completion, cut and pull the 7" casing above the top of cement, and run a 5-1/4" casing string from the packer to surface, with cement in the 5-1/4"x 7"and 7"x 9-%"annuli. A new 3 W'upper completion will then be run. General Well info: Well Type: Producer MPSP: 2,118 psi(calculated using reservoir pressure with a gas gradient to surface) Reservoir Pressure/TVD: 2,674 psi/5,564' TVD(9.2 ppg EMW)on 7/1/2014 Wellhead type/pressure rating: FMC Gen III(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-OA passed on 3/17/15 MIT-T passed on 7/3/14 IA has multiple known leaks Earliest Estimated Start Date: May 10,2015 Production Engineer: Deanna van Dam/Mike Balog Workover Engineer: Travis Smith(265-6450/Travis.T.Smith@cop.com) Summary Procedure Pre-Rig Work 1. Set Catcher and pull DV from lowest GLM for circulation 2. Chemical cut tubing at 7,545'RKB 3. Set BPV Rig Workover 1. MIRU RWO Rig 2. Pull BPV. Circulate seawater. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE&test. 4. Pull blanking plug&BPV, screw in landing joint,BOLDS's,unseat tubing hanger. 5. PU on tubing and pull hanger to the floor. POOH laying down 3-1/4"tubing. a. If tubing will not pull free, RU wireline. RIH to first full joint of tubing above K-22 anchor seal assembly and cut tubing. RD wireline. 6. TIH using drillpipe with casing scraper to packer,circulate well clean. TOOH racking back. 7. MIRU Wireline: a. Run cement bond log in 7"casing b. RIH w/jet cutter to cut the 7"casing above TOC. RD wireline. 8. NU BOPE to the 7" casing head. Change out Pipe Rams. (BOPE will be a diverter because of surface casing leak) 9. Spear 7"casing and PU to circulate out Arctic Pack from the OA using heated diesel&seawater. 10. TOOH sideways with 7"casing. Set test plug,change out Pipe Rams,PT BOPE,and pull test plug. 11. MU&TIH with 9-5/8"casing scraper to the top of the 7"stub and circulate well clean. Loepp, Victoria T (DOA) From: Smith,Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, May 06, 2015 10:42 AM To: Loepp,Victoria T(DOA) Cc: Aleshire, Lynn; Ruff, Chris A Subject: 2A-09 Workover(PTD 186-001, Sundry 315-252) Hello Victoria— Here are some comments on our justification for cementing the 5-%2" x 9-%" annulus in the 2A-09 rig workover(PTD 186- 001, Sundry 315-252). Please let me know if you need additional information. Thanks very much, Travis From: Aleshire, Lynn Sent: Wednesday, May 06, 2015 10:37 AM To: Smith,Travis T Cc: Ruff, Chris A Subject: 2A-09 Cemented OA Travis, I recommend that we cement the OA to mitigate the subsidence damage to the surface casing for the following reasons.: • The estimated total subsidence for 2A-09 is 70 inches. If TOC is around 2000 feet the strain on the production and surface casing is approximately 0.3%which exceeds the elastic limit of 0.2%.The well has a passing MITOA so the casing still maintains integrity though it has exceeded its elastic limit.A future surface casing leak is certain and cementing the OA mitigates that event. • Gyro offset plots from 2009 indicate surface casing damage between 250 and 300 feet. Cementing the OA will mitigate the failure at that depth. I'll be happy to answer any questions. Lynn Aleshire I GKA Subsidence Coordinator 907.265.6525 ATO 1364 1 , 2A-09 Rig Workover Subsidence RWO (PTD #:186-001) 12. MIRU casing crew&TIH with new 5-'/2" casing, TAM port collars,permanent packer,and poor-boy overshot and locate over tubing stub. Set packer. 13. ND BOPE,pull 5-'/2" casing in tension and land in the slips. Cut off excess 5-'/2" casing. NU new tubing head and PT POs.NU BOPE,change out Pipe Rams,and PT BOPE. PT the 5-'/2"casing. ✓ 14. RIH with TAM cementing tool on drillpipe and sting into lower port collar to open. MIRU SLB cementers and cement the 5-'/2"x 7"/9-%"annulus to above the cut of the 7"production casing. Un-sting and close TAM port collar,and TOOH standing back drillpipe. 15. Lay down 5"TAM cementing tool and MU 5-1/4"TAM cementing tool. RIH and sting into upper port collar to open. Pump cement from upper port collar to surface in 5-'/2" x 9-%" annulus. Close TAM port collar and POOH laying down drill pipe. 16. TIH with new tubing to just above seal bore receptacle and swap well to CI brine. 17. Space out with pups,stab into seal assembly,MU tubing hanger, land hanger,and RILDS. /� 18. PT the tubing and IA.Bleed the IA and then the tubing.Ramp up the IA pressure quickly to shear the SOV. y 19. Pull the landing joint and install two-way check 20. ND BOPE 21. NU and test tree.Pull two-way check. 22. FP well with diesel through the SOV 23. Set BPV 24. RDMO RWO Rig Post-Rig Work 1. Reset well house,re-attach flowlines. Pull BPV. 2. RU Slickline: a. Pull the SOV from the KMG-2-9 mandrel and run GLD b. Pull the WRP Plug 3. Turn well over to Operations KUP PROD 2A-09 ConocoPhillips m Well Attributes (Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl("I MD(ftKB) Act Btm(ftKB) o>,rocsitrlrrps 501032005900 KUPARUK RIVER UNIT PROD 51.09 7,050.00 8,535.0 ... Comment H2S(ppm) Date Annotation End Data KB-Grd(ft) 'Rig Release Date 2A-09,7/7/20142:1453 PM SSSV:LOCKED OUT 29 12/24/2013 Last WO: 3/11/1994 3540 2/19/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,282.0 7/15/2013 Rev Reason:NOTE,SET WRP,GLV C/O,H2S hipshkf 7/7/2014 P w HANGER,33.0r 111i''°D Casing Strings ' ii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 WELDED I Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.4 3,409.0 2,771.6 36.00 J-55 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.5 7,954.1 5,812.6 26.00 J-55 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 5 4.276 7,715.8 8,525.0 6,196.8 18.00 L-80 LTC ✓.A+'CONDUCTOR;36.0-110.0- Liner Details Nominal ID Top(ftKB) Top(TVD)(MKB) Top Incl c) Item Des Com lin) SAFETY VLV;1.801.5 t-r V 7,715.8 5,652.5 48.12 HANGER 5"LINER HANGER 4,276 it Tubing Strings Tubing Description (String Ma...'ID(re) (Top(ftKB) 'Set Depth(ft"Set Depth(ND)(...'Wt(Ib/ft) "Grade 'Top Connection TUBING WO 31/2 2.992 330 758691 , 5,567.1 9.30 J-55 EUE8RDMOD GAS LIFT;2,002.7 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 33.0 33.0 0.00 HANGER FMC GEN III TUBING HANGER 3.500 1,801.5 1,681.5 40.64 SAFETY VLV CAMCO TRDP-2SSA Non-Equalizing Safety Valve- 2.812 Locked Out 3/9/98 SURFACE;35.43,409.0-a _L� 7,569.6 5,555.6 48.61 PBR CAMCO REDRESSED 2.875"OEJ w/XO TO 3.5" 2.937 `Lj/ EUE8RDMOD ON TOP GAS LIFT;4,038.9 b' TubingDescription 'String Ma.'ID(In) Top(ftKB) Set Depth(ft..Set Depth ND Wt Ib/ft) Grade To Connection P " g I " P ( I1 3" ( " I P �� TUBING Original 2 3/8 1.995 7,586 9 8,218 1 5,990 4.70 J-55 EUE8RD GAS LIFT;5536.9 ., Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;6,725.0 7,586.9 5,567.1 48.66 PACKER CAMCO 2.875"x 7"HRP-1-SP RETRIEVABLE PACKER 2.347 7,663.2 5,617.4 48.46'NIPPLE AVA BPL PORTED NIPPLE w/BPI in place 1.875 8,123.9 5,926.8 47.70 BLAST RINGS RICKERT BLAST RINGS 1.995 GAS LIFT;7,518.1 8,195.0 5,974.7 47.70 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/5'SEALS 2.406 8,195.8 5,975.2 47.70 PACKER BAKER DB PACKER 2.347 V 8,198.8 5,977.3 47.70 SBE BAKER SEAL BORE EXTENSION 3250 PBR;7,569.6 III 8,209.5 5,984.5 47.70 NIPPLE CAMCO D NIPPLE,w/1.812 PACKING BORE ID,1.812" 1.812 NO GO PROFILE PACKER;7,586.9 - 8,216.6 5,989.2 47.70'SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PLUG.7,609.0 l �� Top(ND) Top incl • Top(ftKB) (ftKB) CI Des Com Run Date ID(in) 7,609.0 5,581.6 48.84,PLUG 2.25"WEATHERFORD WRP 7/1/2014 PRODUCTION;7,625.1 7,663.2 5,617.4 48.46 SLEEVE AVA BPI SLEEVE 7/18/2006 1.870 NIPPLE;7,663.2 SLEEVE;7,663.2, lit i_ Perforations&Slots Shot Dens p Top(TVD)5,95.0 Btm(190) (shotsR Top(ftKB) Eta,(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,136.0 8,142.0 3 5,939.0 C-4,2A-09 4/1/1986 6.0'IPERF 60 deg.ph;3 3/8" HyperJet 8,142.0 8,162.0 5,939.0 5,952.5 C-4,UNIT B, 4/1/1986 12.0 IPERF 60 deg.ph;33/8" 2A-09 HyperJet PRODUCTION.355-7,954.1 , 8,162.0 8,182.0 5,952.5 5,966.0 C-4,UNIT B, 4/1/1986 12.0 IPERF 60 deg.ph;33/8"Hyper 2A-09 Jet ! 8,242.0 8,252.0 6,006.3 6,013.1 A-4,2A-09 9/4/2005 6.0 APERF 1-11/16"EJ,0 deg phase IPERF;6136.08142.0 8,271.08,304.0 6,025.9 6,048.1 A-3,2A-09 4/1/1986 6.0 IPERF 60 deg.ph;33/8"Hyper IPERF;6142.0$162.0 1 I I Jet IPERF;6162.0-8.182.0 Stimulations&Treatments ,y', . Min Top Max Btm I Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (1168) (ftKB) Type Date Com 8,271.0 8,304.0 6,025.9 6,048.1 FRAC 4/18/1986 A-SAND FRAC w/GELLED DIESEL,32008 20/40 SEAL ASSY;8,195.0 11` MESH SAND PACKER;8,195.8 ' Mandrel Inserts AIR' SBE;SBE;8.198.8 1 ilk 1 St !_1 aS at en Top(TVD) Valve Latch Port Size TRO Run c o . No Top IRKS) (ftKB) Make Model OD(in) Sore Type Type (In) (psi) Run Date m NIPPLE;8.209.5 7' 2,002.7 1,829.1 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 7/4/2014 2 4,038.9 3,188.4 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 7/2/2014 sos;8,216.6L: 3 5,536.9 4,206.2 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 4/7/2007 4 6,725.0 5,012.7 CAMCO KBUG 1 GAS LIFT 'DMY BK 0.000 0.0 4/7/2007 5 7,518.1 5,521.8 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/7/2007 6 7,625.1 5,592.2 CAMCO KBMG 1 PROD DMY BEK 0.000 0.0 9/6/2006 D APERF;8.242.08.252.0 a a I P IPERF:8,271.08,304.0 I 0 FRAC;8271.01 I e 1 d Notes:General&Safety End Date Annotation 9/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 7/7/2014 NOTE:RESTRICTION AT 2444' LINER;7.715.85.525.0 iri ConocoPhillips _ - y 2A-09 110'MD,16"62.5#,H-40 _ Producer 'Willi As-Planned 5-1/2"TAM Cement Port Collar =Y2" 3-1/2"9.3#,L-80 Tubing ► i`a • 3409'MD,9-5/8"36#,J-55 i Camco KBG-2-9 GLMs(5) 4800'-4940'MD,7"Casing Leaks -► l. M1. I 11 11i i MO i I J =u I.: 3.112"x 5-1/2"Crossover 4-1/2"Baker Cement Collar : :: I jt.: f-- Baker Model S Permanent Packer I� I2.813"Camco D-Nipple 7545'MD,Tubing Cut ]` Baker Poor-Boy Overshot 7570'MD,Camco 2-%,"OEJ11 7587'MD,Camco 2-W'x 7"HRP-1-SP Retrievable Packer 7625'MD,Camco KBMG Production Mandrel _i 7663'MD,AVA BPL Ported Nipple(BPI) 2000'-7954'MD,7"26#,J-55 ` 2-%"4.7#J-55 Tubing 8136'-8182'MD,C Perforations 11 Ill 8196'MD,Baker DB Packer a I 8210'MD,1.812"Camco D Nipple 8217'MD,Camco Shear-Out Sub III 11119 8242'-8304'MD,A Perforations 7715-8525'MD,5"18#,L-80 ` bete: April 24,2015 ! D,'.wr,By: Travis$mXll Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday, May 05, 2015 10:10 AM To: Smith,Travis T(Travis.T.Smith@conocophillips.com) Subject: KRU 2A-09(PTD 186-001, Sundry 315-252) RWO Travis, Please provide a post RWO well bore schematic. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria Loepp(7a alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov 1 Loepp, Victoria T (DOA) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, May 05, 2015 5:13 PM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2A-09(PTD 186-001, Sundry 315-252) RWO Attachments: 2A-09 As-Planned.pdf Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria— Here is a proposed post-RWO schematic for 2A-09. I mentioned in a phone call today that we were considering changing the procedure and sundry for this well. We are not going to do that anymore, instead we are simply going to change the vendor of the cementing port collar. Thank you very much, Travis From: Loepp, Victoria T(DOA) [m i! n'victoria.loepp©alaska.gov] Sent: Tuesday, May 05, 2015 10:10 AM To: Smith, Travis T Subject: [EXTERNAL]KRU 2A-09(PTD 186-001, Sundry 315-252) RWO Travis, Please provide a post RWO well bore schematic. Thanx, Victoria SCANNED JUN 0 8 2015 Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 ConocoPhillips 2A-09 Producer 110'MD,16"62.5#,H-40 # `�. s 3 g. As-Planned 5-'h"TAM Cement Port Collar —111:;•'10 3-1/2"9.3#,1-80 Tubing ► #rLt .Y .�S s 3409'MD,9-518"36#,J-55 4,110. l y± il 11 1 ii it ii ti t Camco KBG-24 GLMs(5) F? i3 774-:4800'-4940'MD,7"Casing Leaks --0 ?# t a %':4-- 3-1"x 5-'/Y"Crossover 4-1/2"Baker Cement Collar ---.--112. i7 4 Baker Model S Permanent Packer If ..411-- 2.813"Camco D-Nipple 7545'MD,Tubing Cut —06- 1 •` ,"— Baker Poor-Boy Overshot a 7570'MD,Camco 2-'/."OEJ ► . a ...4—_ 7587'MD,Camco 2-'/."x 7"HRP-1-SP _ _ L._ I Retrievable Packer 7625'MD,Camco KBMG Production Mandrel --0 7663'MD,AVA BPL Ported Nipple(BPI) ® 2000'-7954'MD,7"26#,J-55 2-V."4.7#J-55 Tubing—44. 8136'-8182'MD,C Perforations irti 'I 8196'MD,Baker DB Packer f— 8210'MD,1.812"Camco D Nipple 8217'MD,Camco Shear-Out Subt i 1 8242'-8304'MD,A Perforations 7715-8525'MD,5"18# L-80 — I 0420 400124.2016 I Drawn ey Trnk&Mw Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /~)- ~.~_//' Well History File Identifier Organization {done) ~ded RESCAN DIGITAL DATA [] Color items: [] Diskettes, No, [3 Grayscale items: [3 Other, No/Type [] Poor Quality Originals: ,.J~' Other:~~/~e__. ~ TOTAL PAGES: NOTES: ORGANIZED BY; BE BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Ma ps: D Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other lei Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: i~ ~'~. (at the time of scanning) SCANNED BY.'~BEVERLY BREN VINc~MARIA LOWELL ReScanned (done) RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI PAGES: Quality Checked (done) RevlNOTScanned,wpd • • Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder - ~ ~ .E Alaska Oil & Gas Commission ~~ ` 333 West 7~' Avenue, Suite 100 u Anchorage, AK 99501 ~~ ~~ ~ ~ ~ ~~~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • • Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top aff date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12/14!2007 2A-02 1$4-050 SF na SF na 3.5 /211412007 2A-03 184-051 44" na 44" na 50 12/14!2007 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 12!5!2007 2A-06 184-064 25'5" 1.5 20" 12/12!2007 8.5 12!14!2007 2A-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.?5 12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9/24/2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5!2007 Œ 04/05/07 ScbIUßI,.pge.p RECEIVED NO. 4205 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth APR 0 6 Z007 4IæIœ 011 & Gas Coos. Commission Anchorage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 scANNED APR 1 0 2007 ii50 - CDI Field: Kuparuk Wel~ Log Description CD Date Job# BL Color 2M,12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02107 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1 H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H·02' 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A·26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331" N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . Schlumberger "",', z .'~~'t1, ª ß Schlumberger -DCS", 2525 Gambell Street, Suite 4~;fA:t~f.~?EX~, t Anchorage, AK 99503-2838\'¡;;~' A TTN: Beth Well 1 B-17 /94-045" 1 E-36 /98-:2/8 3H-07 /f\7-n7Q 3H-07 " '" 2A-09 IP>/n-ml 1A-10 ¡P'j- //~() 2M-14 /9¿;;-lJlo~ 1 E-05 /91')- /)5P. 2H-12 IB5-:A/J'). 1C-21 3G-18 Iq{)- /:J.z;- 1 E-119 2U-13 /S4-~4fp 1 Y -09 183- f'F:.:J. 1E-105 2C-08 IB3 -OC¡s 2C-02 IB?J- 09~ 1C-25 Iqq-D3 2C-14 184 - o'{D 2C-10 /!3..f-f:. It 1A-18 /90- /53 2C-01 /8~- DE?;; 1D-32 t2DD-/73 2C-12 IPd-~ 2C-15 /84 - ~Ó~ 1J-154 1 E-1 04 Job # 11216283 11216282 11217023 11166757 11154126 11213710 11154127 11166747 11154128 11154131 11154129 11217025 11166753 11213128 11162832 11141255 11213129 11144074 11166759 11144067 11144070 11213709 11141252 11141260 11141254 N/A 11217024 FEB 22 2006 ~"".. ,.,,,H.,j. yl)¡wm:>SIOt, ?JlcOOra-ge Log Description SBHP SURVEY SBHP SURVEY LDL STATIC SURVEY PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE WIDEFT/GHOST PRODUCTION PROFILE WIDEFT INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE MEMORY INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE GLS PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION LOG W/TRACTOR INJECTION PROFILE 02/21/06 NO. 3691 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk e Date BL Color CD 02/18/06 1 02/18/06 1 02/11/06 1 01/20/06 1 02/09/06 1 02/08/06 1 02/10/06 1 12/25/05 1 02/11/06 1 02/14/06 1 02/12/06 1 02/13106 1 01/14/06 1 02/06/06 1 01/28/06 1 e 01/28/06 1 02/07/06 1 02/02/06 1 01/25/06 1 01/26/06 1 01/29/06 1 02/07/06 1 01/25/06 1 02/02/06 1 01/27/06 1 02/05/06 1 02/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to'(907) 561-8317. Thank you. ~~ e Conocó'Phillips September 20,2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 I?I2C€ Sf? IV~D A/Ilk, Oil 2 6 2005 &G.,,.. 4n \1011,. Co 'Cho",.,~f." .. fie "'0/1 Subject: Report of Sundry Well Operations for2A-09(APD # 186-001) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk well 2A-09. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, k(¡¡¿~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad ,.-.-.".-......,....,--......;. SCANNfÐ) NOV (} 9 2005 e e RECEIVE.. SEP 2 6 2DD5 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Alllke Oil & Gas Cons. Commi... REPORT OF SUNDRY WELL OPERATIONS A h nc oraae 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D '..'t~.J. tit. 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20059-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 123' 2A-09 8. Property Designation: 10. Field/Pool(s): ADL 25570, ALK 2668 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8535' feet true vertical 6204' feet Plugs (measured) Effective Depth measured 8305' feet Junk (measured) true vertical 6048' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SUR. CASING 3369' 9-5/8" 3409' 2772' PROD. CASING 7914' 7" 7954' 5813' .- LINER 822' 5" 8525' 6197' Perforation depth: Measured depth: 8136'-8182',8242'-8252',8271'-8304' true vertical depth: 5935'-5966',6007'-6013',6026'-6048' Tubing (size, grade, and measured depth) 3.5"/2.875"/2-3/8", J-55, 7587'17668'/8218' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP'; BAKER 'DB' pkr= 7587'; 8196' SSSV= Cameo 'TRDP-2SSA' SSSV= 1802' 12. Stimulation or cement squeeze summary: RBDMS BFL SEP2 8 7005 Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubina Pressure Prior to well operation 220 1231 4600 -- 266 Subsequent to operation 229 1614 5487 - 253 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name M~j l0~Z Title Wells Group Team leader ,ii, Signature Phone Date ¿ ~ ~J Prl>nared b haron ~"-Drake 263-4612 N~ ~ (¡~ Form 10-404 Revised 04/2004 ORIGINAl Submit Original Only e 2A-09 Well Events Summary e Date Summary 08/24/05 TAG FILL @ 8305' RKB. EST l' RAT HOLE. JOB COMPLETE. [Tag] 09/03/05 DRIFT TBG W/1.75" X 10' DUMMY DRIFT TO 8311' RKB. WELL TO BE LEFT SHUT IN FOR UPCOMING PERF JOB. [Tag] 09/04/05 PERFORATE (A SAND) 8242 - 8252 FT MD (CORRELATION LOG - CBL 29MAR1986) WITH 1.63" EJ III STRIP GUN. 6 SPF/O DEG PH/17.96" PENETRATION/0.28" HOLE DIA. TOOLS HELD UP RIH AT 23/8" TUBING TOP. WORK UP/DN TO POP INTO TUBING. NO OVERPULL - GUN FIRED OK. ! to 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, 21 wellhouse inspections Attachment: SVS KRU 2A Pad 1-4-01 CS 1. failure 4.1% failure rate X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS .doc Alaska Oil and Gas Conservation COinmission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: ..Kupamk / KRU / 2A Pad Separator psi:' LPS 96 HPS 1/4/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed G^SorCYCLE 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 1860010i 96 70 50 P P OIL 2A-10 1860020 96 70 55 P P OIL 2A-11 1860030 96 70 50 P P OIL }A-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 OI~ 2A-16 1851470 96 70 70 P P OIL 2A-17" 19314001 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' 19314401 96 70 60~ P P OIL 2A-25 1960620 Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1% [] 90 Day Remarks: Surface Safety on 2A-12 had slow leak, valve to be serviced and retested 11(11i31 D,,,-.,:. I ,-,~' 1 q,/'q I~l~I I ')A Pnrl l_zl_t31 C'q ,.,lq 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: Pull tubing X 2. Name of Operator ARCO Alaska, IDC. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown__ Stimulate __ __ Alter casing Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ 99510 Service_ Plugging Perforate Other_ 6. Datum elevation (DF or KB)'~ 123' RKB, 92' PAD feet 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 1266' FSL, 53' FEL, Sec. 14, T11N, R8E, UM At top of productive interval 1532' FSL, 1300' FEL, Sec. 23, T11N, R8E, UM At effective depth 1390' FSL, 1345' FEL, Sec. 23, T11N, R8E, UM RECEIVED ~ 1 1 1994 8. Well number 2A-09 9. Permit number/approval number 86-1 10. APl number 50-103-20055 At total depth ¢4~ .~[~ ,UU & ..~iiS ~013tft~. ,.C~ ~1. Field/Pool 1248' FSL, 1390' FEL, Sec. 23, T11N, R8E, UM" ,,,,~, .... ' Kuparuk River Oil Pool 12. Present well condition summary ~ Total Depth: measured 8535' feet Plugs (measured) None true vertical 6202' feet Effective depth: measured 8424' feet Junk (measured) true vertical 6128' feet Casing Length Structural 1 1 0' Conductor Surface 3 4 0 9' Intermediate Production 7 9 5 4' Liner 8525' Perforation depth: measured Size Cemented Measured depth True vertical depth 16" 270 Sx AS II 110' md 110' tvd 9-5/8" 1000 sx AS III & 400 sx Class G 7" 200 sx G, 175 sx CSI 5" 200 sx Class G 8135' - 8182', 8271' - 8304' 3409' md 2629' tvd 7954' md 5812' tvd 8525' md 6197'tvd true vertical 5934' - 5966', 6026' - 6048' Tubing (size, grade, and measured depth) 3-1/2" X 2-7/8" X 2-3/8" J-55 @ 8218' Packers and SSSV (type and measured depth) Baker "DB" Perm Pkr @ 8196'MD, Camco "HRP-1SP" Ret Pkr @ 7587' MD, Camco "TRDP-2SSA" SSSV @ 1802'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 1 -404 Rev 05/17/89 Title Area Drilling Engineer D a t es U~M~i~i~N~DoU~p Li CATE ,KCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2A-09 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-103-20055 86-1 DAILY OPERATIONS PAGE: 1 ACCEPT: 03/07/94 09:00 SPUD: RELEASE: 03/12/94 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 03/08/94 (1) NORDIC 1 TD: 8435 PB: 8424 03/09/94 (2) NORDIC 1 TD: 8435 PB: 8424 03/10/94 (3) NORDIC 1 TD: 8435 PB: 8424 ND BOP STACK 5"8 8525' MW: 0.0 MOVE RIG TO 2A-09. ACCEPT RIG 8 0900 HRS 03/07/94. LEVEL RIG. KILL WELL. MONITOR-WELL DEAD. CIRC. SET BPV. ND TREE. NU BOP STACK & TEST. ATTEMPT TO PULL TBG HGR TO RIG FLOOR-CANNOT PULL TBG. PULL 85K ON STRING-80% OF J-55 TBG-EXPECTED PU 42K. SET BPV-PU BOP STACK & CONNECT CONTROL LINE TO TBG HGR TO OPEN SSSV FOR E-LINE TBG CUT. CALL OUT SCHLUMBERGER F/TBG JET CUT. POOH W/2-7/8" TBG 5"8 8525' MW: 0.0 NU CHOKE LINE & BOPE AFTER CONNECT CONTROL LINE TO HGR, OPEN SSSV & PULL BPV. BOLDS, PU TO 40K & SET SLIPS IN ORDER TO TAKE TBG OUT OF COMPRESSION 8 CUT LOC. RU SCHLUMBERGER EQUIP & MU JET CUTTER. RIH W/CUTTER. TOOL WOULD NOT PASS THROUGH SSSV. POOH & REMOVE CENTRALIZERS F/CUTTER. RIH & MAKE CUT 8 7470'. POOH & RD WL EQUIP. LD LANDING JT & TBG HGR. RU TO CIRC & CBU. PMP A BALANCED 40 BBL HI VIS PILL IN ATTEMPT TO CONTROL FLUID LOSS. RD CIRC EQUIP & MONITOR WELL. FLUID LOSS 8 6 BBL/HR. POOH W/2-7/8" TBG & LD SAME. RECOVER TOTAL OF 33 SS C-LINE BANDS. REPAIR BLOWER MOTOR & CHECK TRACTION MOTOR BRUSHES. CONT TO POOH W/2-7/8" TBG. LD TOTAL OF 157 JTS, 83 JTS STILL IN HOLE. RACK & TALLY 230 JTS 3-1/2" DP & 12 JTS 4-3/4" DC'S WHILE REPAIRING TRACTION MOTOR ON DRAWWORKS. MOTOR WENT DOWN WHILE POOH, NEED TO REPLACE BRUSHES. CONT TO POOH W/2-7/8" TBG & JEWELRY. LD TRI-STATE TOOLS 5"8 8525' MW: 9.7 NaCl/Br SERV RIG. SET TEST PLUG, TEST TOP FLANGE & CHOKE LINE. PULL TEST PLUG & SET WEAR BUSHING. MU TRI-STATE FISHING TOOLS & FISHING BHA. RIH W/3-1/2" DP & FISHING BHA. MAKE REPAIRS TO BLOWER ON DRAWWORKS MOTOR. CONT TO RIH W/3-1/2" DP. PU KELLY & SERV SAME. TEST UPPER & LOWER KELLY COCKS. MU KELLY & BREAK CIRC. TAG FISH 8 7452' & LATCH, PULL FREE W/170K, STRING WT l12K. CBU. BLOW DN KELLY & STAND BACK SAME. NORM TEST 2-7/8" TBG. REPLACE PROTECTORS & REMOVE TBG F/SHED. POOH W/lll STDS 3-1/2" DP & 6 STDS 4-3/4" DC'S. PULLED VERY TIGHT FIRST 6 STDS, HAD TO JAR OUT OF HOLE IN NUMEROUS PLACES, PULLING MAX OF 180K. CONT TIGHT THROUGHOUT TRIP, JARRING OUT OF HOLE IN SEVERAL SPOTS. RECEIVED APR 1 1 1994 Ai~s~<2 Uil & Gss Cons. Commission Anchorage .~ELL: 2A-09 API: 50-103-20059 PERMIT: 86-1 PAGE: 2 03/11/94 (4) NORDIC 1 TD: 8435 PB: 8424 03/12/94 (5) NORDIC 1 TD: 8435 PB: 8424 LOAD SHED W/TBG & TALLY SAME 5"@ 8525' MW: 9.7 NaCl/Br POOH W/ TRI-STATE TOOLS & FISH, BREAK FISH FREE FROM OVERSHOT. FISH CONSISTS OF 2 COLLAPSED MANDRELS, 3 JTS TUBING, & CAMCO OEJ. BREAK OUT FISHING TOOLS & L/D SAME. RU TO RIH W/3-1/2" DP. SET WEAR BUSHING. MU 6-1/8" BIT, BITSUB, & 12 4-3/4" DC'S, RIH, SLIP & CUT 50' OF DRILL LINE. PU CAMCO OEJ & BREAK SERVICE BREAKS IN ORDER TO REDRESS SAME. RIH W/BHA ON 3-1/2" DP. MU CIRC EQUIP. CBU, POOH W/BHA & LD SAME. PULL WEAR RING, RU TO RUN TBG, RACK & TALLY 3-1/2" TBG RIG RELEASED 5"@ 8525' MW: 9.7 NaCl/Br RACK, TALLY, & DRIFT 3-1/2" TBG, SERVICE RIG, PU CAMCO OEJ & TIGHTEN ALL SERVICE BREAKS. RIH W/3-1/2", 9.3#, J-55, EUE 8RD TBG & JEWELRY AS PER DETAIL., MU SSSV, ATTACH CONTROL LINE & TEST TO 5000 PSI, CON RIH W/3-1/2" TBG COMP & INSTALL SS BANDS ON 'C' LINE EVERY OTHER JT. RUN TOTAL OF 239 JTS 3-1/2" TBG & 30 SS BANDS. MU CIRC HOSE. VERFIY SEALS IN OEJ & SPACE OUT TBG W/6' & 8' PUPS. MU TBG HGR, ATTACH SSSV 'C' LINE TO HGR & TEST TO 5000 PSI, LAND TBG HGR & RUN IN LOCK DOWN SCREWS. RU OTIS SL, MU RUNNING TOLL & RIH W/SLICKLINE. SET PLUG IN D-NIPPLE @ 8,210, POOH, TEST ANN & TBG TO 3500 PSI F/15 MIN. TEST SBR SEALS BY BLEEDING ANN TO 1500 PSI & HOLDING TBG @ 3500 PSI. BLEED BOTH ANN & TBGPTO 1000 PSI, CLOSE SSSV, BLEED TBG TO 500 PSI, & TEST SSSV F/15 MIN, OPEN SSSV. RIH W/SLICKLINE & PULL PLUG F/D-NIPPLE. POOH & RD SLICKLINE. LD LANDING JT & INSTALL BPV, ND BOPE. NU 3-1/8", 5000 PSI TREE, PULL BPV. REMOVE NEEDLE VALVE F/TBG SPOOL, RETAP THREADS & REPLACE. OPEN SSSV. SET TEST PLUG, TEST TREE & PACK OFF TO 5000 PSI. PULL TEST PLUG. FREEZE PROTECT BY DISPLACING ANNULUS W/12 BBLS DIESEL & BULLHEADING TBG W/4 BBLS @ 1500 PSI. SET BPV & MOVE RIG OFF WELL. CLEAN AROUND WELLHEAD, PULL BPV, & SECURE WELL. SICP=0~ PSI, SITP=0 PSI. RIG RELEASE @ 0230 HOURS 3/12/94 SIGNATURE: DATE: ARCO Alaska, Inc. ~ost Office ibex 100360 A~.~chorage, A~aska 99510,-(i38© Telepho~'~e 907 276 !215 March 4, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action 80---01 2A-09 ~..~ 2X-1 5 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments Variance Repair Well G~s Cons. commission Anchorage AR3B-6003~93 ?42 Type of Request: Name of Operator STATE OF .ALASKA ALASKA OIL AND 'GAS ~RVATION COMMI~ON APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program _ Pull tubing _ Variance ..~ Perforate _ Other ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1266' FSL, 53' FEL, SEC.14, T11N, R8E, UM At top of productive interval 1532' FSL, 1300' FEL, SEC.23, T11N, R8E, UM At effective depth 1390' FSL, 1345' REL, SEC.23, T11N, R8E, UM At total depth 1248' FSL~ 1390' REL~ SEC.23~ T11N~ R8Er UM 2, Present well condition summary Total Depth: measured 7 6 3 0 true vertical 6229 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ feet Plugs (measured) feet 6. Datum elevation (DF or KB) 123' RKB feet 7. Unit or Property name ._ Kuparuk River Uni[/~.,~, 8. Well number 2A-09 9. Permit number 86-1 10. APl number 50-103-20055 11. Field/Pool Kuparuk River Fi'~ld Kuparuk River Oil Pool Effective depth: measured 7544 feet Junk (measured) true vertical 6154 feet 13. Casing Length Structural 1 1 0' Conductor 34 0 9' Surface Intermediate Production 7954' Liner 8 0 9' Perforation depth: measured 8135'-8182', Size Cemented Measured depth True vertical depth 1 6" 270 SX CS II 110' 1 1 0' 9 5/8" 1000 SX AS III & 3409' 2629' 400 SX CLASS G 7" 200 SX CLASS G & 175 SX CSI 7954' 5812' 5" 200 SX CLASS G 8535' 61 9 7' 8271'-8034' MD RECEIVED true vertical 5934'-5966-, 6026'-6048' TVD Tubing (size, grade, and measured depth) 2 7/8" X 2 3/8" SET AT 8225' Packers and SSSV (type and measured depth) CAMCO HRP-1-SP @ 7587', BAKER DB ~ 8196'. CAMCO TRDP-1A-SSA SSSV ~ 1910' Attachments Description summary of proposal _ Detailed operation program _ BOP sketch !',,~,,~ -'9 199z~ Gas Cons. Commission Anchorage 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~( Gas _ Suspended Service 17. I hereb~i~at..the Signed s true and correct to the best of my knowledge. Title Senior Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity B BOP Test_ Location clearance Mechanical Integrity Test_ Subsequent form require 10-~/Oq Approved by order of the Commission Original Signed David W. J0hnst0 Commissioner Form 10-403 Rev 06/15/88 IApproval No. Approved Copy Returned Date ',,~,/'/'~,/~' (/' SUBMIT IN TRIPLICATE ATTACHMENT Description Summary KRU WELL 2A-09 Based on recent well work we have determined that a GLM in Well 2A-09 has collapsed, and tubing casing communication now exists. To fix the problem a workover with the Nordic workover rig has been scheduled in March 1994. We request approval to continue to produce this well in it's existing condition until that time. Risk is minimized by keeping the well on production and the pressure drawn down. The well is only capable of producing 600 BOPD at a 5% water cut and a total gas oil ratio of 3200 scf/bbl. Reservoir pressure is estimated at about 3100 psi. RECEIVED A~chorag~ STATE OF ALASKA /-~ASKA OIL AND GAS ~SERVATION COM,v~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate -- Other ;x; 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1266' FSL, 53' FEL, Sec. 14, T11N, R8E, UM, At top of productive interval 1532' FSL, 1300' FEL, Sec. 23, T11N, R8E, UM At effective depth 1390' FSL, 1345' FEL, Sec. 23, T11N, R8E, UM At total depth 1248' FSL, 1390' FEL~ Sec. 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7 6 3 0' feet true vertical 6229' feet Plugs (measured) 6. Datum elevation (DF or KB) 123' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-09 9. Permit number/approval number 86-1/ ¢~-~,e'b 10. APl/number 50-103-20055 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 5 4 4' feet true vertical 6154' feet Junk (measured) 7523 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 1 10' 16" 270 Sx CS II 1 10' 3409' 9 5/8" 1000 Sx AS III & 3409' 400 Sx Class G 7954' 7" 809 5" 200 Sx Class G measured 8135'-8182', 8271 '-8304' MD true vertical 5934'-5966', 6026'-6048' TVD' Tubing (size, grade, and measured depth) 2-7/8" X 2-3/8" set at 8225' Packers and SSSV (type and measured depth) True vertical depth 110' 2629' 200 Sx Class G &175 Sx CSI 7954' 5 81 2' NOV 2 B 1990 Alaska 0il & Gas Cons. 60mm~ss'tot~ Anchorage Camco HRP-1-SP @ 7587'~ Baker DB ~ 8196'. Camco TRDP-1A-SSA SSSV ~ 1910'. 13. Stimulation or cement squeeze summary Hydraulically fracture stimulated the A Sand with 24,840 lb of 16/20 mesh ceramic proppant. Intervals treated (measured) A Sand, 8271-8304' Treatment description including volumes used and final pressure Pumped 411 bbls of fluid with 2 to 10 ppg sand stages. Final treating pressure = 5727 psi. 14, Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 453 519 0- 1420 223 1767 2493 0- 1400 254 15, Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as' Water Injector__ Oil ~ Gas Suspended Service 17. I here/~ certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 BMIT IN DUPLICATE FIELD- DISTRIC~r- STATE OPERATION AT REPORT TIME ,JO5 COMPUSTE WELL.~ERVICE REIIORT IDAY~ 1DATE' /o/590 FRAC "A" SAND. 13Z~ RIG LIP. T'~$T LINE5 T~ T,~OO PSI, 67~... 1,4.lc) PUMP 17..5 68L PR_C-PAD (GW). ZSZP 1950 P,~l. PUMP ?.08 8B/,. PAD FOLLOWED 8y 150 E, SL SLURRY ~ 44 BBl. FU, JSH DSL. WELL F:kAC'4 17oo CC' K 81o51 544MMARY' WELL FRAC'4 ~ 2.6114.#CAESOLITE; 5:~6 SE, i. ~EL WI'R, ~ DSL. Anchorage [-'J CHECK THiS BLOCK IF SUMMARY CONTINUED ON BACK W"ther Temp' I Chill F'ct°r I Vl"lblllty tW'ndVel'Report 'F 'F mil.. knot. tSigned STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1326' FSL, 53' FEL, Sec. 14, T11N, R8E, UM, At top of productive interval 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UM At effective depth 1428' FNL, 1352 ' FEL, Sec. 23, T11N, R8E, UM At total depth 1487' FNL, 1388' FEL~ Sec. 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7 2 6 0 feet true vertical 6247' feet Plugs (measured) 6. Datum elevation (DF or KB) 123' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number I,,, 2A-10 9. Permit number/approval number 86- 2 / ?~ - ~.¢~ 10. APl ~umber 5o-lo3-20056 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 1 5 0' feet true vertical 61 62 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 116' 16" 2828' 9 5/8" 6655' 7" 813' 5" measured 6783'-6837' true vertical 5874'-5917' Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 310 Sx CS II 106' ' 1 06' 810 Sx AS III & 2863' 2773' 290 Sx Class G 200 Sx Class G &175 Sx CSI 140 Sx Class G 669O' 5799' 6437'-7250 5597'-6239' 6892'-6902' 6918'-6950' 5961'-5969' 5981'-6006' RE( EIVE N OV 2 8 1996 3-1/2" (199 jts), J-55 & 2-3/8" (13 jts) N-80, tbg w/tail @ 6884' Packers and SSSV (type and measured depth) FHL pkr ~ 6300'~ Baker DB ~ 6851'. Camco TRDP-1A-SSA SSSV ~ 1793'. Alaska 0ii & Gas Cons. C0; 13. Stimulation or cement squeeze summary Anchorage Two attempts to hydraulically fracture stimulate the A Sand, screended out in 2ppg stage both times. Intervals treated (measured) A Sand, 6918'-6950' Treatment description including volumes used and final pressure Placed a total of 4,200 lb of 16/20 ceramic proppant. Final treating pressure = 7274 psi. 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 241 177 -0- 1100 190 Subsequent to operation 592 506 -0- 1400 225 15. Attachments 16. Copies of Logs and Surveys run Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to~ the best of my knowledge. Form 10-404 Rev 09/12/90 Status of well classification as: W~ater Injector __ Oi~ X Gas Suspended Service SUBMIT IN DUPLICATE ]missi0[ A'RCO Alaska, Ir'~ {) Subsidiary of Atlantic Richfield Company £LL WELL SERVICE REPORT ,NTRACTOR REMARKS /PS~o e ~/ IFIELD - DISTRICT . STATE /t',,~,,,,,,,, k IOPERATION ~T REPORT TIME Lt. /z//~' Cq ~' ~0 / To~ ! T,:, k t 2 ;o ()yzz/IL Kl2to6? CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK NOV ~ 8 1998 ., _,_ ,.,:, & ,'._,,~ c, nns. Anchorage Weather ITemp.Report,ii°F ,I Chifl Faet°r I VisJbi~ity °F miles ,! Wind Vel. i Stgned knots, CONTRACTOR . . . QPERA~ AT REPORT TIME " REMARKS· I -' : fill Io05 ~C, '(ESTE~bAY/,~ ~EL. TEST LINES I'D $100P51. ALL. OK. 1014 IZO0 No ,c/..u.~ Pu~ ......... CC: K 8~069 EST: ~ 6Z~O0 .s~/a~aA£Y' 5c~E~N~_P out P£ESSU~E. EST 7960 # 6647 PS~ MAX Il I I If · A~'as~.oN.& Gas Cons. (;ommissioH A,chorage [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility lWInd Vel. Report °F 'F miles knots lSlgntd ARCO Alaska, Inc. ?ost ©ffice Bo× i003,50 ~"~:-~ ,~.~..p~,,~ ?e~..-'n~' 90'? 276 '1215 August 22, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 2A-09 Stimulate August, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS /pe of Request: Abandon _ Alter casing _ Change approved program_ Suspend _ Operation Shutdown _ Re-enter suspended well _ Repair well _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other m 6. Datum elevation (DF or KB) ~2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~ Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1266' FSL, 53' FEL, Sec. 14, T11N, R8E, UM, At top of productive interval 1532' FSL, 1300' FEL, Sec. 23, T11N, R8E, UM At effective depth 1390' FSL, 1345' FEL, Sec. 23, T11N, R8E, UM At total depth 1248' FSL, 1390' FEL, Sec. 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7630' feet Plugs (measured) 6 2 2 9' feet RKB 123 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-09 9. Permit number 86-1 10. APl number 5o-1 03-20055 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical Casing Length Structural Conductor 1 1 0' Surface 3 4 0 9' Intermediate Production 7 9 5 4' Liner 809' 7544' feet Junk (measured) 61 54' feet 7523' Size Cemented I 6" 270 Sx CS II 9 5/8" 1000 Sx CS III & 400 Sx CS II 7" 200 Sx Class G & 175 Sx CS I 5" 200 Sx Class G Measured depth True vertical depth 110' 110' 3409' 2 6 2 9' 7954' 5 81 2' 8525' 6197' Perforation depth: measured 8135'-8182', true vertical 5934'-5966', Tubing (size, grade, and measured depth 8271'-8304' MD 6026'-6048' TVD 13. Refrac A Sands with 16,500 lbs Carbo-Lite proppant. 2-7/8" X 2-3/8" set at 8225' Packers and SSSV (ty~ and measured depth) .~nrrm" ' ~ ......... Camco HRP-1-SP ~ 7587', Baker DB ~ 8196'. Camco TRDP-1A-SSA SSSV Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch _ (Wellbore schematic attached). 15. Status of well classification as: Oil ~ Gas ~ Suspended _ 14. Estimated date for commencing operation August, 1990 16. If proposal was verbally approved Name of approver Date approved Service 17. I h~~if,~t the fo, reg~oing is true and correct to the best of my knowledge. Signed ~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test_ Subsequent Approved Copy Returned ,'a/:41q-o Approved by the order of the Commission form require 10- ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner IAppr°valN°. ~~¢~ I Attachment 3 Kuparuk Well 2A-09 'A' Sand Re-Fracture Cost Tracking AFE #K81051 1. RU fracture equipment. Install "Tree Saver". Pressure up the 7" annulus to 3000 psi. . Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled water with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. 3. Pump the 100 Bbl pre-pad at 20 BPM. Shut down and determine the ISIP. . pressures following the ISIP. WHTPE = Fracture Gradient = Frac Fluid Gradient - Tubing Friction = Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute Expected wellhead treating pressure: 4689 psig 0.71 psi/ft (6024' TVD) 0.44 psi/ft 350 psi/1000' @ 20 BPM (2-7/8") -- 600 psi/1000' @ 20 BPM (2-3/8") * If excessive treating pressures are experienced, reduce the rate in small increments adjusting additive rates as appropriate. With diesel on the backside, the maximum recommended treating pressure is 6500 psi based on analysis of tubing strength between the packers. The maximum treating pressure during the initial fracture treatment was 5800 psi with diesel based fluids. Operations Engineer -- Obtain representative fluid samples from the pad, slurry, and flush stages. Place samples in hot water bath at 150° F to observe break time. 5. Rig down fracture stimulation equipment. Follow attached flowback schedule. KUPARUK WELL 2A-09 APl #: SPUD DATE: ORIGINAL RKB: 501032005900 ADL LEASE: 25570 PERMIT #: 02/08/86 COMPLETION DATE: 04/18/86 WORKOVER SURFACE LOCATION: 1266'FSL,53'FEL,SEC14,T11 N,RSE TOP OF KUPARUK: 1532'FSL,1300'FEL, SEC23,T11N,R8E TD LOCATION: 1248'FSL,1390'FEI.,SEC23,T11 N,R8E NI cleplhs are MD-RKB to top of equipment unless otherwise noted 123 TUBING SPOOL: 33 WELLTYPE: PRODUCER CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5~ H-40 110 9.625' 36# J-55 3409 7' 26# J-55 7954 2.875' 6.5# J-55 ABM 8218 LINER DETAILS SIZE WEIGHT GRADE TOP BTM 5" 18# LB0 7716 8525 1 2 3 DATE: 86-1 PAD ELEVATION: 92 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2616 CAMCO KBMG 1' 4901 CAMCO KBMG 1' 6316 CAMCO KBMG 1' 7209 CAMCO KBMG 1' 7491 CAMCO KBMG 1 · 7529 MERLA TGPD 1.5' 7625 CAMCO KBMG 1' PORT SIZE 0.1875 0.1875 0.1875 .DY .DV 0.1875 .DV TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-1A-SSA 2.312' 1809 SBR CAMCO OEJ 2.937' 7570 PKR CAMCO HR 7587 AVA AVA 'BPL' NIPPLE 7663 PKR BAKER DB N~ CAMCO 'D /. $1 Z. ~ 8210 SHROUT CAMCO 8217 INTERVAL 8135-8182 8271-8304 PERFORATION DATA ZONE FT SPF PHASE C234 47 12 A3 33 6 COMMENTS SOS 3 3/8' CSG SOS 3 3/8' CSG MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 700 MAX HOLE ANGLE: 5O deg 68OO HOLE ANGLE THRU KUP: 47 deg LAST TAG DATE: ~ ~./'Z ~/f~ ~ RATHOLE: 72 ft FISH/OBSTRUCTION: PBTD: 8424 PBTDSS: 6005 REVISION DATE: 01/16/89 REASON: UPDATE ARCO Alaska, in( Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 8, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Action Anticipated Start Date 2 X- 1 2 Scale Sqz. J u n e 2 A- 1 5 Scale Sqz. June 2 A- 0 9 Scale Sqz. July, 3 H- 0 3 Acidize J u ne 3 H- 1 4 Acidize J u ne 2 U- 1 2 Scale Sqz. J u n e 2 W- 0 7 Scale Sqz. June 3J-0 6 Fracture June 3 J-02 Fracture June 3 A- 1 0 Perforate June 1 E - 0 6 Acidize June 1 E- 1 1 Acidize June 1 E- 1 5 Acidize June , 1989 , 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. S'mallwood Senior Operations Engineer ARCO Alaska, Inc. is a Subsidiary ol AllanticRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. In(~, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1266' FSL, 53' FEL, Sec. 14, T11N, R8E, UM, At top of productive interval 1532' FSL, 1300' FEL, Sec. 23, T11N, R8E, UM At effective depth 1390' FSL, 1345' FEL, Sec. 23, T11N, R8E, UM At total depth 1248' FSL, 1390' FEL, Sec. 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 763 0' feet true vertical 6229' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 123 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-09 9. Permit number 86-1 10. APl number 50-1 03-20055 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7544' feet true vertical 61 54' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: 110' 3409' 7954' 809' measured 8135'-8182', true vertical 5934'-5966', Tubing (size, grade, and measured depth 2-7/8" X 2-3/8" set at 8225' Junk (measured) 7523' Cemented Measured depth 1 6" 270 Sx CS II 110' 9 5/8" 1000 Sx CS III 3409' & 400 Sx CS II 7" 200 Sx Class G & 175 Sx CS I 7954' 5" 200 Sx Class G 8 5 2 5' 8271'-8304' MD 6026'-6048' TVD True vertical depth 110' 2629' 5812' 6197' RECEIVF. 1 t98.,c Alaska Oil & Gas Cons. Cor~ Anchorage Packers and SSSV (type and measured depth) Camco HRP-1-SP @ 7587', Baker DB ~ 8196'. Camco TRDP-1A-SSA SSSV @ 1910'.' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch Pump Scale Inhibitor into perfs at 8135'-8182'. (Wellbore schematic attached). 14. Estimated date for commencing operation ~ 15. Status of well classification as: July. 1989 I Oil X Gas __ Suspended 16.If proposal was verbally approved Name of approver Date approved S e rvi ce 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :~"~&~('~-.~-~ Title Sr. Operations Engineer FOR COMMISSE)N USE ONLY Date ~/~/~ ~- Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Mechanical Integrity Test_ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Location clearance Subsequent form ORIGINAL SIGNED B'Y I fINNIF.- C. SMITH IApproval No. require 10-~///- I 7 ~pproved Copy Returned SUBMIT IN TRIPLICATE Application for Sundry - Well 2A-09 C Sand Scale Inhibitor Squeeze Treatment No BOP's are used during the treatment. The squeeze treatment will be pumped through a manifold on surface. C Sand Pressure (6200' SS) = 3300 psi Estimated. No workover fluid will be used during this process. RECEIVED · aska Oil & Gas Cons. Commission Anchorage KUPARUK WELL 2A-09 APl #: SPUD DATE: ORIGINAL RKB: 501032005900 ADL LEASE: 25570 PERMIT #: 02/08/86 COMPLETION DATE: 04/18/86 WORKOVER DATE: SURFACE LOCATION: 1266'FSL,53'FEL,SEC14,T11 N,R8E TOP OF KUPARUK: 1532'FSL,1300'FEL,SEC23,T11 N,RSE, TD LOCATION: 1248'FSL,1390'FEL,SEC23,T11N,R8E All depths am MD-RKB to top of equipment unless otherwise noted 123 TUBING SPOOL: 33 PAD ELEVATION: WELLTYPE: PRODUCER CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 2.875" 6.5~ J-55 8218 2.875 6.5 J-55 ABMOD 8218 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-1A-SSA 2.312 1809 SBR CAMCO OEJ 2.937 7570 PKR CAMCO HRP-1SP 7587 AVA AVA 'BPL' NIPPLE 7663 PKR BAKER DB 8196 NOGO CAMCO 'D' NIPPLE 2.25 8210 SHROUT CAMCO 8217 92 GAS LIFT and FLOW INFORMATION VALVE 86-1 STN DEPTH MANDREL SIZE 1 2616 CAMCO KBMG 1.0" 2 4901 CAMCO KBMG 1.0" 3 6316 CAMCO KBMG 1.0" 4 7209 CAMCO KBMG 1.0" 5 7491 CAMCO KBMG 1.0" 6 7529 MERLA TGPD 1.5" 7 7625 CAMCO KBMG 1.0" PERFORATION DATA INTERVAL ZONE FT SPF PHASE 8135-8182 C234 47 12 8271-8304 A3 33 6 PORT SIZE 0.1875" 0.1875" 0.1875" DV DV 0.1875" DV COMMENTS SOS 3 3/8" CSG SOS 3 3/8" CSG MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 50 HOLE ANGLE THRU KUP: 47 LAST TAG DATE: 12/31/87 RATHOLE: 72 FISH/OBSTRUCTION: PBTD: PBTDSS: deg deg DEPTH 7OO 6800 8376 8424 6005 RECE VE, 13 IS 9 Alaska l}jj .& Gas Cons. Commission REVISION DATE: 01/16/89 REASON: UPDATE ARCO Alaska, Ir, 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 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints' Schl' Open Hole' One * DIL/SFL-GR DIL/SFL-GR Den/Neu-GR Den/Neu-GR Den/Neu-GR Den/Neu-GR Cyberlook (poro) (poro) (raw) (raw) 02-17-86 02-17-86 02-17-86 02-17-86 02-17-86 02-17-86 02-17-86 3I-7 5" 2" 5" 3N-6 5" ~ 2TM DIL/SFL-GR DIL/SFL-GR Den/Neu Den/Neu Den/Neu Den/Neu Cyberlook LSS-GR LSS-GR DIL/SFL-GR DIL/SFL-GR Den/Neu Den/Neu Den/Neu Den/Neu Cyberlook (poro) ( poro ) (raw) (raw) ( poro ) (poro) (.raw) (raw) 02-19-86 02-19-86 02-19-86 02-19-86 02-19-86 02-19-86 02-19-86 02-20-86 02-20-86 02-28-86 02-28-86 02-28-86 02-28-86 02-28-86 02-28-86 02-28-86 Receipt Acknowledged: DATE 07-30-86 TRANSMITTAL # 5726 Please acknowledge receipt and of each Run #1 7939-8462 Run #1 7939-8462 Run #1 7939-8437 Run #1 7939-8437 Run #1 7939-8437 Run #1 7939-8437 Run #1 7939-8437 Run #2 0200-7506 Run #2 0200-7506 Run #2 5500-7480 Run #2 5500-7480 Run ~2 5500-7480 Run#2 5500-7480 Run ~2 6650-7457 Run #2 3287-7502 Run ~2 3287-7502 Run #1 1700-7736 Run #1 1700-7736 Run #1 6950-7710 Run #1 6950-7710 Run #1 6950-7710 Run #1 6950-7710 Run .#1 6950-7680 Date: State of Alaska*bi/se Drilling*bi Rathmell*bl D & M*bl ARCO Alask&. Inc. ~s a Subs,diary of AtlanticRichfieldCompanY NSK Clerk*bl Vault*films , ARCO Alaska, In(. 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 07-30-86 TRANSMITTAL # 5725 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints' Dresser Atlas' CBL' One * of each 2A-9 03-29-86 Run #1 7660-8410 Receipt Acknowledged: State of Alaska*bi/se Drilling*bi NSK Clerk*bl Vault*films Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION G,~MMISSION WELL COMPLETION OR-RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-1 · 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20055' ~ 4. Location of well at surface 9. Unit or Lease Name 1266' FSL, 53' FEL, Sec.14, T11N, R8E, UN ~ Kuparuk River Unit At Top Producing IntervalIL'"~"'v'--I1 VE?,[~_~/~ I 10. Wel'l Number 1532' FSL, 1300' FEL, 5ec.23, TllN, R8E, UN i Surf. '[~Y ,~__ 2A-9 AtTotal Depth I,, u ' ~y~' ! ll. FieldandPool 1248' FSL, 1390' FEL, Sec.23, TllN, RSE, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 123' RKBI ADL 25570 ALK 2668 , 12. Date Spudded 13. Date T.D. Reached 14. Date ComP., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 02/08/86 02/18/86 04/18/86' N/A feet MSLI 1 17. TotaiDepth(MD+TVD) 18.PlugBackDepth(MD+'l'VD) 19. DirectionaiSurvey I 20. Depth where SSSV set [ 21. Thickness of Permafrost 8535'MD,6202'TVD 8424'ND,6128'TVD YES~] NO [] 1816 feet MD 1500' (approx) ., 22. Type Electric or Other Logs Run D IL/SP/SFL/GR/FDC/CNL/Cal, GR/CCL/CBL, CCL/GR, (;CT ,. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16,, ~Z.5# H-40 ' surf ' 110, 24,, · . 270- sx CS Ii ..... ,,, 9-5/8" ;6.0# J-55 Surf 3409' 12-1/4" 1000 sx CS III & 400 sx :S II 7" !6.0# J-55 Surf 7954' 8-1/2" 200 sx Class G & 175 sx :S I 5" 8.0# L-80 7716' 8525' 6-1/8" 200 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) 8135' - 8182' w/12 spf 2-7/8"/2-3/8" 8225' 7594' & 8203 8271 ' - 8304' w/6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED .... See attached AddendJm for fracture data. 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift' etc.) I Date of Test .Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ 1 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 tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED MAY ".' Alaska 0il & Gas Anchorage Form 10-407 * NOTE: Drlg completed 02/19/86. Rmltubing & perf'd well 4/3/86. (WCl/010) Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ( 30. . GEOLOGIC MARKI~5 ~ '"' FORMATION TESTS '~,~,.. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8133' ;932 ' N/A Base Kuparuk C 8187' ;968' Top Kuparuk A 8218' 5989' Base Kuparuk A 8386' 5102' , 31. LIST OF ATTACHMENTS We]] History (completion detai]s)~ Addendum (dated ~,/28/86), Gyroscopic Survey (2 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . .. Signed t(/~ ~/~ ;~'~~ TitleAssOciate Engfneer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completior, 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 STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~4MISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~X ABANDONED [] SERVICE [] ./ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-1 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20055 4. Location of well at surface 9. Unit or Lease Name 1267' FSL, 53' FEL, Sec.14, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2A-9 At Total Depth 11. Field and Poop To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and SeriaI No. " Kuparuk River 0il Pool 123' RKBI ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 02/08/86 02/1 8/86 02/19/86I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8535 'MD 8424 'FID YES [] NO ~ N/A feet MD 1500' (approx) 22. Type Electric or Other Logs Run D I L/SP/SFL/GR/FDC/CNL/Cal 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 110' 24" 270 sx CS II 9-5/8" 36.0# J-55 Surf 3409' 12-1/4" 1000 sx CS Ill & 400 st CS II 7" 26.0# J-55 Surf 7954' 8-1/2" 200 sx Class G & 175 st CS I 5" 18.0# L-80 7716' 8525' 6-1/8" 200 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ,. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD II~ 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 APR0 4 1986 Form 10-407 DAM2/WC01 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. N/A GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered, and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer INSTRUCTIONS General: This form is designed for sUbmitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 [~ UIDANC [~ONTINU E~OOL Company Well Name Field/Location Job Reference NO; 71415 Lo_aaed By: WEST/BARBA SUB-SURFACE DIRECTIONAL SURVEY E OUS ARCO ALASKA, INCORPORATED WELL 2A-9 (1266'FSL, 53'FEL, S14, TllN, R8E) I i -- [ i [[ KUPARUK, NORTH SLOPE, ALASKA i ii i · Date, 16-APRIL- 1986 Computed By: ~OLAM SCT giREGTi]N6L SURV'"Y CJST3~IER LiSTIq~ M:THSDS OF TOOL LgC&TIDU: ZNTERP3L~TZDN: VERTICAL S-CTIDq: H.DRZZ. 2ZST. NJ.~T-~ SLOPE, ~L]SK2 :~VE'~'~C,r-]-- DEVZ6Tr~N~ aN-'. ~Z'VUTH &Z i"qUT H S:3UTrt 13 38 ~EST ARCO ~LASKA, 26-9 KUP6RU~. NORTH SLOPE, ALASKA COMPJTATIDN ME~SURE] DEPTH 0.00 100.00 ZO0.O0 300.00 400.00 500.00' 600.00 700.00 800.00 900.00 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 20QO 2100 2200 2300 2400 2500 2500 2700 2800 2900 3000 3100 3200 3300 3400 3500 3500 3700 3900 3900 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 .OO .OD .00 .OD .00 .03 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 TRUE VERTICAL DEPTH 0.00 100.00 200.00 300.00 399.96 ~99.73 599.18 697.31 795.77 892.33 987.34 10~0.32 1172.58 1262.82 1351.14 1437.45 1521.%9 1602.55 1680.53 1755.18 1827.28 1896.~7 1964.34 2031.71 2098.55 2165.18 2231.78 2298.72 2365.61 2432.49 2499.23 2565.B5 2632.42 2699.01 2765.60 2898.59 2954.29 3030.13 3096.17 DATE: INTERPOLATED V.~LdES FOR :VEN 100 Sg5-S E~ C ]JRS: VERTiCAL VERTICAL SEVI~TI:]N A'ZZMUTH S=CTi]N D~P/H J~G ~IN D~G HIki F=5T 0 0 N 0 0 ~. 0.00 0 3 S 33 50 W -I2.65 O 9 S 7 55 4 -12.53 0 39 S 15 31 W -i1.36 2 34 S 5 1¢ J -g.34 4 ~2 S 4 35 ',4 -2.~0 7 3~ S 4 45 W 7 5~ 10 27 S 7 35 N 23.1~ 13 1~ S 12 5 w ~3.53 16 3:3 S 12 22 W 69.59 -123.00 -23.00 77.00 177.00 275.~5 375.73 475.15 57¢.31 672.77 769.33 19 34 S 11 30 W 100.69 21 58 S il 7 W 135.14 24 32 S 11 34 W ' 175.62 26 ¢6 S 12 42 W 218.58 2'9 7 S 1Z 20 W 265.75 ~1 ?9 q 13 47 W ~15 ~ 34 lB S 9 35 W 370.28 37 11 S 7 57 W 42~.58 40 18 S 3 3 W 4'90.~5 42 56 S B 20 '4 557.08 854.]4 957.32 1049.63 1139,82 1229.t4 1314.46 139~.49 1479.55 1557.53 1632.1~ 44 57 S 8 ,5 W ,526.$5 47 8 S 7 2t W 697.85 47 21 S :3 40 W 770.91 47 51 S ~ 5~ '~ 34c.5:~ ~8 15 S 13 22 W 91~. 33 45 1~ S 10 15 W 993.30 48 9 S 10 15 W 1,367.77 4~. _P S lO 2 4 I*1q~ ~.09 48 3 S 10 5 w 1299.30 1704.28 1773.47 1~al.34 1908.71 1975.58 2042.1.3 2108.78 2175.72 22~2.61 230'~.4-? 45 11 S !3 11 4 1B64.53 43 i5 S lO 15 ~,l 1439.07 a8 13 S lO 24 ',,] 1513.57 ~+~ 15 q lO ~3 4 i~:3~.05 47 59 ~ 1~ ~2 W !552.~7 4~ 21 S 10 1a '4 1736.36 48 ~5 S i0 5 ;,1 IBl!.6'~ ';8 55 S ~ 45 w i~5.93 4~ ~6 S ~ 3'~ 4 1952.31 2375.23 2442.~5 2509.42 2575.01 2642.60 2702.40 2775.59 2841.2~ 2907.13 297~.17 DJGL~G SEVERiT 0.00 0.41 0.70 3.04 2.21 3 · ~ 5 c. I 'P 3.55 3.14 2.~2 2.38 ~.52 3.36. ~.61 2.55 £.01 2.73 0 · q3 ! .59 1.15 0.3~ 0 ~ ,r. 3.31 0.29 ']. 23, 3.14 0.37 3.32 3.26 1.27 J.51 0.13 3.25 PAGE DATE O~ SURVEY: 25-~R-86 KSLLY ~USHING ELEVATION: 123.00 ENGINEERS: BAR,a/WEST R ': C T A N S NORT~/S v. OO lO.O0 9.24 6.71 0.12 1 ~ 25.9~ 45. Z1 7! !02. 135. 175. 217. !63. ~13 · 366. 424. 436. ~52. 520. 592. 764. 337. ~10. 1357. 1130. 1204. 1277. 135,2. 1~2~+. 1497. 1570. 15~4. 1717. 17)I. la55. 1 ~3'~. Z ]I~. ~5 5¢ O! 36 21 19 O3 12 '90 34 75 {9 11 30 9EmTH :JLaR 3dTH COGRDIN&TSS E~ST/WEST FE=T HDRIZ. DIST. FEET 0.00 12.47 12.45 12.32 !1.97 11.41 I0 57 ~. 9 3 3.41 O.g.~ DEPARTURE ~ZIMUTH DEG MIN 6.54 13.55 21.32 30.~0 40.79 60.~2 69.26 77.95 ~7.~9 0.00 N 0 0 E 15.98 N 51 16 E 15.90 N 31 37 E 15.40 N 53 8 E 13.72 N 60 43 5 1!.41 N 89 2' ~ 14.75 S 45 4, ~_ 27.50 S 19 3 ~'~ 45.52 S 6 40 E 71.54 $ 0 13 W 97.37 107.34 115.~8 12~.92 142.32 155.63 168.9~ 181.93 194.78 207.79 W 102.22 W 137.47 W 176.~3 W 213.96 W 265.71 W 317.12 W 371.31 W 429.83 W 492.39 W 55~,91 1 S 3 S 1 S ~ S 3 S 4 S .~ S q~ S ! S 22 23 24 26 27 28 3O 31 32 33 0.90 4.10 7.51 1.06 4.91 8.41 1.71 4.74 7.41 9.~6 W 52~.19 W 700.35 W 7'13.7~ W B47.$7 W 322.00 W 996.57 W 1071.15 W 1145.43 W 1219.76 W 1294.10 1363.33 1443.12 1517.73 1592.32 1566.91 1741.31 1B16.27 1~91.66 1956.92 20~2.01 S 3 43 W S 3 39 N S 6 55 W S 7 56 W S 3 47 W S 9 14 M S 9 21 W S 9 16 W S '9 3 W S ~ 59 ~ S 8 55 W S 8 47 W S S 8 52 W S 8 59 s 9' S g 8 ;~ S 9 11 W S 9 14 W S 9 17 W S 3 20 W S 9 23 W S 9 26 W S 9 29 N S ) 32 W S 3 33 N S ) 34 W S 3 34 'N 3 3~ N ARCO 24-9 K ~jp4 R',JK NORTH SLODE, lqC. .4 C]qDUTATZ]~ ME4SURED DEPTH 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4500.00 4700.00 4800.00 4900.0O 5000.00 5100.00 5200.00 5300.00 5~00.00 5500.00 5600.00 5700.00 5800.00 5900.00 60DO .00 6100.00 6200.00 6300.00 6400.00 6500.00 6500.0D 6700,00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7500.00 7700.00 7800.00 7900.00 o TRUE VERTICAL DEPTH 3152.49 3229,29 3295,36 3353,32 3430.36 3497,99 3566.09 3533,33 3702,18 3770.50 3838,54 3906,$0 3975.5'7 4044.59 4180,84 ~249,10 &317,53 ~386.14 ~454.99 ¢524.55 4594,~2 ~663,45 ~73i.~7 4800.51 ¢866.90 ~932,07 4996.76 5061.06 5124.7~ 5i88,24 5251.96 5315.79 5380.12 5444.59 5509.36 5574.6? 5640.~ 5797.97 5775,14 O~r~: 15-4PR-85 · ZNT:~OOL~T=O VALUES FOR CGORSE VE~TIC&L 3']GLES D=VI&TZON AZIMUTH SECTION SEV~=RITY DE,3 ~llN .9~G M'i'~ ,~T 3-J/lO0 SJB-SE~ V~RTI"&L~ 48 16 S 9 51 W Z!I1,59 3,75 47 55 S 10 5 W 21~5,86 0,38 47 J~ S i0 8 d 2259,~9 3,22 47 53 S 10 26 ,4 ,P33~.0~ :3, 70 ~7 51 $ 11 1 W 1408,14 47 5 S I1 33 W £~1~ . 74 '~. 45 47 14 3 12 34 4 2554,93 1,2'3 47 11 S !3 9 W !523,4~ 46 43 S !3 25 J F701,49 0,47 a7 5 5 14 Z~ W 2774. 41 .},75 47 ~ S !~ 43 ~;' 22~7.78 3.3-) 46 47 S 14 ~.. W 29'0. ,~4 46 ZO S 15 i~ 'J ~993,41 0,20 &5 ~7 S !5 35 W $0.55,74 1,15 ~7 8 S !~ 2~ ',,~ 31~ 7~ 47 3 S I~ 45 ',~ 3211.9S 0,55 4A~ 51 S 1~. 55 N 32,3~. ~=. :~,22 45 &B S 16 55 W 3357,70 46 ~1 S 15 57 W S~30.37 ~,lS a~ 10 S 17 13 '4 3502.77 0,70 50 3g S :cO 2.~ ~J iS!5. ~5 S.31 50 iq. S ~_~J ~.5 W 4~}~.a°._, 0.~ ~0 12 S 19 ~9' ,4 ~5:3. ~7 0.99 ~2 ~ S 1~ ~2 ',i ~521.1i 0.35 49 29 S I~ ~3 W ~59v.15 9.65 ~ 5~ S 1~ 2& 'J ~772.58 ~7 ~2 5 17 ~4 '4 ~Zl.Z:~ S.}Z 47 ~2 S 17 44 'd 4~95 u 3039,~9 3106.2'9 .3173.35 3240.32 3307.36 3374.99 34~3.0 ~ 3310.~5 357 ?. 13 3647.50 3715.54 37~3,80 .3952,57 3921.59 39~,37 4057,34 ~125,10 4194,53 ~263,14 4331.79 ~40! .65 a471.92 ~540,45 ~+608,87 4671,51 4743. :~O 4309,07 ~$73.75 ~93~.05 5001,7'3 5055.2~ 5128.96 5192,79 5257,12 5321,69 53~5.36 5451 ,6~ 5517.$~ 5584.97 5652,24 9&T~ OF SURVEY: 25-~&R-85 KELLY ~USHING ELEVATION: 123.00 ~NGINEERS: 5ARB~/WEST 2357. 2150 · 2233 · 237~. 2~+51. '~-~ ~.. 25?5. 255 ~. Z716. 2&O :! . 297~. 315'~. 322~. 329H. 3369 · 3437. 3505, 357~, 3541, 3709. 3777. 3'~. 4 7. 3217. 39~9. '-. ~ ~0 · ~+i~2. 42.05. 4277. 4349, ~421. ~77~. J 9EOTH 3O 58 5O 57 ~5 13 18 9') UL4R OUT~. COORDINATES HORIZ. 9EPARTURE E~ST/WEST DIST. ~&ZI~UTH FEET FEET DEG MIN 352,53 W 2116,86 365,48 W 2191,27 379,~1 W 2255,45 391.~ W 2339.70 a05.51W 2~13,89 ~2],00 W 2~7,53 ~35.15 W 2f50.70 451,64 W 2534.14 ~6~3,~5 W 2707,02 495,'91 ~q 2779,7~ 50~.41 W 2352.94 523,11 W 2925,78 542,02 W 2993,13 531,10 W 3070.23 5~!.3~ ~ 3142.'~6 602.36 W 3215.92 623,62 W 32;~,59 644,83 W 3361,08 566,03 W 3~33,50 687.23 W ~505.$6 11 S 703.65 W 3577,01 77 S 730,55 W 3647,70 97 S 755,15 W 3719,64 94 S 7~2.34 W 3791,54 49 S ~09,51 W 3863,26 29 S 835,35 W 3937.14 )5 S 863.35 w 4J12,07 05 S 891,45 W 4037,45 62 S 918,73 W 4153,26 57 S 946,07 14 4233,58 03 S 973,23 W 4316,18 27 S 1000,06 W 4392,53 35 S 1026,53 W 4&59,05 50 S 1051,90 W 4545,20 03 S 1075,55 :'4 a521.20 23 S 1101,25 W 4697,15 O1 S 1125.33 W 4772.58 1~ $ I14~.81 W 4~47.28 ?~ S 1171.55 W 4921.26 ga $ ii9~.10 W ~95.07 S ') 35 W S 9 36 W S ~ 37 W S :~ 38 W S 9 40 ~ S 9 4' S 9 52 ~ S ) 57 W S 10 S 10 11 N S lO 17 W S 10 24 W S 10 31 W S 1 O 3 '9 '~ S 10 47 W S lO 55 W S 11 3 W S 11 11 w S 11 1~ W S 11 25 W S 11 33 W S 11 43 W S 11 54 W S 12 5 J S 12 15 ' S 1Z 26' } S 12 35 w S 12 ~4.N S 12 53 N S 13 1 W S 13 ? N S 13 15 W S 13 22 W S 13 23 ~ S 13 33 a S 13 33 W S 13 42 ~ $ 13 46 w S 13 49 '~ CO~PJTATiJN O~T~: t6-goR-36 ~C0 2~-9 KUP~RU< NORTH SLOPE, T 4E~SURED V~R DEPTH D 8OO0.OO 58 8100.00 59 8200.00 8300.00 8~O0.OD 51 8500.00 $1 8535.00 ,~L~SKa ZNT:R~gL~T~,3 V,&LUeS D&TE 3F SUqVEY: 25-M~R-85 q~LLY 3USHINS ELEVATION: 123.00 RU~ SJB-SEA CDJRS~ VERTICAL TiC~L V"qTICA'~ 3EVZaTZ~N~ AZi~JTW, $~rTlON,. EPTH D~PTH ,3E$ qIN D~G MZN ~E~T ~Z.53 5719.53 09.~1 5796.81 77.09 5S54.09 ~.37 5921.37 11.55 595~.55 7~.~4 5055.94 02.$~ 507~.4~ 9L-~C.L eS R E ~ T ~ NSUL.~ R S~:v-RZTY C03RglN&TES H]RIZ. OEP&RTURE EaST/NEST DIST. AZI~'UTH F'--T FE~T D=G MIN 596~. 83 51~+2.52 5216.41 5290.20 5363.99 5437.78 5 ~63.61 0.0O 4991.17 3.0} ~351.53 0.O0 5132.10 O.3C; 5202.56 0.00 ~'£73.03 0.0~ .,:297.59 12!6.$3 W 5063.98 S 13 53 W 1239.17 W 5142.59 S 13 56 W 1261.73 W 521,5.52 S 13 59 W 1~4~.. .~4 W 5~90.34~ . S 14 g N 1305.75 W 5364.17 S 14 5 W i329.3t W 5~3~.00 S 14 8 1337.20 ~ 5~63.B5 S l& $ ARCO ALASKA, KUP4RUq NDRTH SLOP: TR ~lE o, SUR ED VERT DEPTH D~- 0.00 1000.00 9'5 2000.00 192 3000.00 4000,00 315 5000.00 383 8000.00 7000.00 518 8900.00 8535.00 520 INC. COMDUTATZS~ 4L4SK4 UE IC4L 0.00 'l. 34 7.2'3 9.23 8.54 4.55 8.24 2.53 2.39 !NTEqPOL&TEO VALUES FOR SJ5-S~4 DE~TH O4T:: 16-ADR-~5 -123.00 B64.34 170~.28 2375.23 3039.49 3715.5~ 5065.24 571~.53 5079.~9 =VEN 10 C:]J~Si VERTICAL OJGL~G ]=VIATiJN AZIMUTH S~CTiOXl SeVeRiTY D=S MiN D=G MIN FEET 3EG/IO0 0.00 100.69 6~6 06 1364.5~ 211!.59 Z~47.7~ 3574.36 ~315.~5 50,53.~3 5463.61 2.71 J.lC 0.75 'J.3~ 0.41 0.3! 0.00 0.03 P~SE D~TF 3; SURVEY: 26-~aR-96 K~LLY BUSHING ELEVATION: 123.00 , SqGINEERS: 5~RS~/W~ST M~SUR~O D~OT ~=CT&NGi. JLaP C'~'*ROINaT~'S,.,,. ~. ~3RiZ. · DEPARTURE """'*RT"I/:~U'r~,',~-,, o'.,, .... =4qT/W~ST,.... DIST. ',,:.!ZZqUTH =~FT =EET FEET DEG MIN O.OO q 0.00 E O.O0 N 0 0 E 102.00 S 5.,5~+ W 102.22 S 3 43 W 620.5:~ S 97.37 W 52,~.19 S 9 .55 W 1353.51 S 220.~0 W 1~6.5.55 S 9 17 W 23,~,7.~0 S 352.53 W 211,5.35 S 9 35 W 2;~O:~.OO S 50~+.41 W 2352.94 S 10 1] 3~0.5.!1 S 70~.55 W 3577.01 S 11 25 } 4135.:]3 S 973.23 w 43!6.18 S 13 I W '~920.70 S 1216,63 W 5058.38 S 13 53 W 52~7.59 ,5 1337.20 W 5'~53.B5 ':, 14 9 W ARCO ALASKA, 2&-9 KUP~RUK NORTH SLOPE C gMPUT~TI DN MEASURED DEPTH 0.00 23.00 123.00 223.00 323.00 423.01 523.3,5 524.05 725.54 828.05 932.10 1037.95 1145.64 1255.59 1357.91 1483.05 1501.83 1725.77 1856.37 1993.93 2139.10 228?.01 2436.71 2586.83 2736.25 2885.81 3035.55 3185.85 3336.04 3¢85.86 3537.09 3789.18 3940.51 4090.61 4239.81 4389.00 4536.69 4684,00 4830.34 4977.13 TRUE V:RTtCAL DE~T~ 0.00 23.00 123.00 223.00 323.00 423.00 523.00 523.00 723,00 823.00 923.00 1023.00 1123.00 1223.00 1323.00 1423.00 1523.00 1623.00 1723.00 1.323.00 1923.00 2023.00 2123.00 2223.00 2323.00 2423.00 2523,00 2623.00 2723.00 2823.00 2923.00 3023'00 3123.00 3223.00 3323.00 3423.00 3523.00 3523.00 3723.00 3823.00 DaTF: 16-APP-85 iNT:?PJL~T~D VALUES FOR EvEN !00 O=VI~TiSN a Z !~aU T-t PEG 'qlN PEG SUB-SE~ VERTICAL DEPT~ 0 0 N 0 0 0 27 N 60 8 0 2 S lO 45 0 13 S 7 O 0 54 S 14 18 3 13 S 5 5 5 15 S 4 37 ~ 14 S 4 ~6 11 9 S ~ 47 14' 16 S 12 35 -127.00 -100.00 O.O0 200.00 300.00 4O0.0O 500.00 500.00 700.00 S:CTION S:VE~iTY ;'{~T JEG/IOS 890.00 900.00 lO00.OO 1100.00 1200.00 1300.00 1400.00 1500.00 1600,00 1700.00 0.00 O.OO -9.35 2.91 -I~.54_ 0.i~ -12.4~ :,. -11.57 1.53 -'~.18 2.70 -O.B1 ='.3'9 1'3.7,5 1.73 27.90 3.39 50.35 3.35 1800.00 1~00.00 200J.O0 2100.00 2200.00 Z303.00 240~.00 i500.00 2600.00 2700,00 7~.05 2.91 113.70 2.20 152.59 2.~ 199.24 2.07 ~50.~4 ~.~ 307.38 2.25 371.31 ~.3,? 444.13 ,~27.74 £.~ ~'~! 75 2 72 2~00.00 2900.00 3000.00 3100.00 3200.00 3300.00 ~4~.00 3509.00 3500. 3700 W 725. ~0 0.53 W B3~,,9~ !.27 W 1057. '97 9.1.5 :.4 116~.77 0,33 ~,1 I 27 9.77 O. 2~ w ! 3 ~ !. 15 S. O { w 1303.04 0.31 ,~ 1514.9 Z O. i 0 · J I '~ 26. ?.2 O. '35 1~39.57 1953.~'9 0.07 2057.20 217B.90 .3.43 '~2'~9.42 0.07 23~9.'9~ ~.34 259~.57 2516.72 J.51 L723.56 :3.73 2971.00 J.3C PAGE O~TE 0= SiJRV~Y: 25-M&R-86 K~LLY BUSHING ELeVaTION: 123.00 ~NGZNEERS: 5AR5&/W~ST SUS-Si~ DEPTH 'DEST~XW%IJL~ COu~DiN&TE:S HDRiZ DEPARTURE NSRTH/S!]JT~ E~ST/WEST 9IST, ~ZI~UTH =~ET Fi:T FEET OEG MIN 0.30 ",i 0.00 E 0.00 N 0 0 E 7.37 N 9.28 E 11.86 N 51 33 E g,'~3 N 12.46 E 15.97 N 51 1~ E 9.'79 ',i 12.45 ~_ 15. 34 N 51 49 ~ ~.'94 N 12.24 ~ 15.16 N 53 50 E 5.5~ N 1i.'~5 = 13.09 N 6~ 5~ '~ !.~) S 11.25 f 11.41 S >30 2~ . 13.59 S !0.29 5 17.05 S 37 8 m 30.72 S ~.30 ~ 31.82 S 15 6 5 52.80 S 3. ~4 E 52.95 S 4 16 E ?0.:50 S 2.27 W 80.,$3 S 1 36 W !1~.75 'S 9.22 W 115.13 S 4 35 W 153,'93 q 15.95 W 154.36 S 6 17 W 19a.57 S 25.15 W 200.39 S 7 29 ~ 24:~.52 3 37.43 W 251.32 S B 33 W 304.35 S 4'9.23 W 30,3.30 S 9 11 W 3~7.38 S 60.59 W 372.34 S 9 21 W 439.75 S 71.33 W ~45.51 S 9 13 W 522.~B S e, 3.11 W 529.45 S 9 1 W 616.33 S 96.75 W 623.88 S 8 55 W 720.61 S 110.69 W 729.07 S 3 43 W 823.32 S 127.24 W. 8Se.OW S 3 43 W ~37.91 S 147.23 W ~49.40 1948.08 S 167.18 W 1061.33 S 9 3 1157.~0 S 186.57 W 1172.34 S 9 9 W 1266.92 $ 205.93 W 1283.55 S 9 13 1'375.76 S 225.59 W 1395.12 1487.04 S 245.60 ~ 1507,19 S 9 22 1597.22 5 266.03 W 1612.22 S 9 27 1706.$~ S 285.51 W 1730.76 S 1~1:~.54 S 305.59 W 1844.20 S 9 34 1931.45 S 326.04 W 1959.78 S 9 34 W 2]43.44 S 345.03 W 2072.36 S 9 35 W 2153.71 S 364.26 W 21~4.30 S 9 35 2252.71 S 383.73 W 22~5.02 S '9 37 2S71.55 S 404.04 W 2~05.73 S 9 40 247~.11 S 425.42 W 2514.36 S 9 44 25~7.54 $ 473.60 27~I,77 S 500.14 W 2~36.2! .S 10 9 W .... NDRTH SLOPE T HEI~SURED VER DEPTH D 5123.65 B9 5168.63 ~0 5414.90 41 5561.80 42 5707.91 43 5853.68 ~4 5997.64 ~5 6140.65 46 6287-0~ 47 6~33.33 4~ 6586.05 49 6740.72 50 6897.20 51 7054.$2 52 7211.27 53 7366.36 54 75Z0.98 55 7573.17 56 7BZ2.35 57 7970.93 58 8119.61 59 8258.23 60 8416.86 51 8535.00 INC. 6LASK~ ~UE TIC~L EPTd 23.00 23.00 23.00 23.00 23.30 23.00 ~3.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 23.00 02.¢9 COMPUTATIDN OArE: 16-AP~-as INTERPOLAT:O V6LJES FOR :VEN lO0 FE~T 3F D:VI~TISN AZIHUTW SECTION SEV~'RITY DES ~IN OEG '417,1 ,::=T D=_:3/iOO SJ~J-SE~ V:RTIZ~L OCpTH 46 ?+1 S 15 2 W 293:3.97 46 23 S 15 20 w 3043.00 0.85 47 10 S 16 31 W 3149.65 0.35 46 56 S 16..,:5 W 3757_ .10 4~ 43 S 16 55 W 3363.45 0.13 aA_ _~? S 17 2 W 3~59. 45 34 S !7 31 W 3572.5;3 3.43 46 ~'3 3 20 23 W 3674. 52 46 ~0 .S 21 33 W .{7S0.54 0.39 4B 2 S 21 1 ,~ 3~95.27 ,2.35 3800.00 3900.00 ~100.00' ~200.00 ~400.00 ¢500.00 ~600.00 ~700.00 49 24 S 21 17 N 4000.70 0.37 49 56 S 20 54 W ~117.56 0.51 50 32 S 20 ~0 ~4'~237.08 0.43 50 2~ S ZO 22 W ~57.79 ~,. 50 8 S ~9 42 W ~477.59 l. Ol 49 ~ S 13 5~ W ~505.58 0.29 a~ 13 S 1~ 3,~ W ~713.03 ,3.63 4~ 19 S 15 iP H 0527.3~ 1.Z5 47 '~'~ S 17 44 w ~937.74 0.20 47 02 S 17 g~ W 59~7.4i 4800.00 ~900.00 5000.00 3100.00 5200.00 5~00.00~ 5403.00 5509.00 5600.00 5700.00 4~ ~2 S 17 ¢¢ w 5157.09 0.00 47 ~2 q 17 4~ w 5!55.76 O.3O 47 ~2 S 17 44 w 5375.43 0.00 47 ~£ S 17 44 '.4 5453.61 O.OO 5~00.00 5900.00 5000.00 607~.49 mag= OAT': g: S.'JqVEY: 26-'q~q-a, 5 KELLY :ZUSHiNg ELEV~TIQN: 123.00 EqGINEEqS: 5 a~i3 ~/'4 EST S!,JE-S:~ DE°TH 2395.!9 S 527.5B W 2942.96 S 10 19 W 2996.5'~ S 555.04 W 3947.56 S 10 29 W 3099.20 S 5~.4~ W 3153.33 S 10 40 W 3202.2~ S :315.43 W 3260.36 S 10 52 W 3304.15 S 646.50 W 3356.~0 S 11 4 W 3&05.6! S 677.~%2 W 3472.33 S 11 1r 3504.50 S 708.14 W 3575.33 S i1 2. , 3601.42 S 740.60 W 3575.73 S 11 37 N ~7]1.ii ~ 779.~9 W 57~2.28 5 11 53 W 3:300.45 S ~31~.36 W 3,5~7.56 S 12 9 ~ 330'9.10 S ~60.01 W 4001.60 S 1Z 24 W 4015.13 S 9,92.50 W 411'5.25 S 12 39 W 41'~C~ .55 S 945.30 W 42~7=, .43 S 12 53 W ~24¢.52 q ~'~7.93 W 4357.97 S 13 6 ,4 4357.71 S i029.47 W ~77.66 S 13 17 W 4~69.71 S 1058.32 W 4595.61 S 13 26 ~ 45~1.33 S 1105.36 N 47'13.33 S 13 34 W 4690.17 S 11~2.55 W 4E27.34 S 13 41 W 47~5.5~{ S 1175.60 W 4937.76 S 13 47 W 49~0.16 S 1ZlO.O'~ W 5947.46 S 13 52 W 5004.9~ S 1243.59 W 5157.17 S 13 57 5109.71 S 127'7.08 W 5255.89 S 14 1 5214.~4 S 1310.58 W 5376.62 S 14 6 N 5297 z~ · ~9 S 1337 20 W 5~53 ~5 S 14 9 C,:'D ARCO ~LASK~, 2~-9 KUP~R'UK Ng~TH SLOPE~ TOP KUP~RUK 3 B~SE KUPARU( C TOP KUP~RUK ~ BASE KUP~RU~ ~ PSTD TO I~C. ~LASK~ C3MPUTATI3N 04TE: 15-~R-8~ DEPTH TVD SJ ~.128:,c_,' =5L, 53' ,~-'iL, S RECTA S !J 3-S EA NORT ~31 3 3. O0 5932.01 5 $'.q. ). Ol ~l~T.OO 5~63.34 SE. 4~. 34 8218.00 :}:)Bg. 20 5 .~ 9.6.20 33~6.00 510E.24 S~7~.24 8535. O0 'q!O Z. 49 5 O 7 ~. ~9 50! 5O5 SI) 521 529 P;ACE L3C~TION ~T 14, TllN, R8E, H.SULAR COORDINATES' H/S3UTq E~ST/WEST 4.42 S 1245.50 2.47 S 1258.77 4.32 S 1255.75 2.70 S 1303.6~ 9.47 S 1312.1~ 7.6~ S 1337.20 UM ~RC8 ~L~SKA, 2&-9 K~P~RUK N]RTH SLOPE9 INC. ~L&SK6 C3~PUTATIDN D~TS: PAgE D6TE gF SURVEY: 26-M~R-$6 KELLY SUSHING ELEV~TZDN: 123.00 EtJSZN~ERS: ~AR~A/WEST TOP BASE TOP PBTO TD M~),KER KUP&RUK~" KUP&RUK C KUP&RUK 6 FSL, 53' SUR:.&CE LDC.&TION ~T F~L, SEC. 1~, TllN, R~E~ .JM RECT6NGUL6R COORDINATES Ni]RTH/S~UTq E6ST/WEST 5014.~2 S 1245.60 W' 5052.~7 S 1258.77 W 507a.32 S 1255.75 W 5192.70 S 1303.62 W 5219.~7 S 1312.1~ W 5297.59 S 1337.20 W FINAL '4ELL LDCATi~N '.iT Tg: MEASUREO VERTiCaL VERTi-~L DEPTH DEPTH OEPTH ,8535. O0 520Z.49 $079. 3I S T &NC ~': & Z l '4dT q =_z.::T_ DEL; vl q 5453.85 S 14 9 SCHLUMBEROER 0 ~ AEC T I ONAL SURV E Y COMPANY ARCO ALASKA INC, NELL 2A-9 F I ELO KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 26 - MAR - 86 REFERENCE 000071415 WELL 2A- 9 (1266'FSL, 53'FEL,f , TllN, R8E) HORIZONTAL PROJECTION ~O~TH go00 ] 000 - ! 000 -2000 -3000 -4O0O -SOOO REF SOUTH -4000 WEST -9000 -2000 - 1000 0 1000 2000 2000 4000 EAST WELL 2A-9 (1266'FSL,~ 53'FEL, ~-'~, TllN, R8E) VERTICAL PROJECTION ]9. - ! 000 0 0 ! 000 ,2000 3000 4O0O SO00 6000 7000 193. ---i-"i--..-.-f. i'---!'- ~--~ ....l...i .~...~..i....L ~. ~.:: . ~-.-.~-.--~-..-i....!...~....! .; ; ~ .~. "'~"'~'""" ~'"t"?"'~ ...... ;....i....i...~...~ ........ .~...~.. ....... ~-.~..;....~..:....~ ..... ~... iiii iii iii i iii ;;i iii PROJECTION ON VERTICRL PLP. NE ~93, - 19, ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough . State I Alaska North Slope Borough I Alaska Field Lease or Unit Well no. Kuparuk River ADL 25570 2A-9 Auth. or W.O, no. ~Title AFE 703427 I Completion Nordic 1 API 50-103-20055 Operator JARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun JDate JHour JPrior statu, if a W.O. Complete 3/23/86 2100 hrs. Date and depth as of 8:00 a,m. 3/24/86 3/25/86 3/26/86 3/27/86 3/28/86 thru 3/31/86 4/01/86 4/02/86 RECEIVE[ MAY 2 '~ ,:. 198~ Complete record for each day reported ~lll~ Accept rig @ 2100 hfs, 3/23/86. ND tree, NO & tst BOPE. RIH w/6-1/8" bit/scrpr to 1918'. Mx & wt up mud. ~sszs' 7688', Drlg hard cmt 12.6 ppg gel/mud Displ brine to 12.6 ppg mud. RIH w/3½" DP, tag up @ 7277', C&C mud, wsh to 7325'. Drl cmt to 7688'.. 7688', POOH f/CET 12.3 ppg gel/mud Drl to TOL @ 7714', tst to~ 1000 psi, TOH. PU 4-1/8" bit/3B, TIH on 3½" DP. Drl & wsh thru top of 5" lnr, wsh to LC @ 8427', C&C mud, TOH to rn CET. 8427' PBTD, C&C 12.1 ppg gel/mud POH w/7" scrpr. RU Schl, RIH w/CET; unable to get into lnr @ 7720', POH, RD Schl. RIH w/2-1/8" bit & 5" scrpr, wrk pipe dh. RIH to 8427', C&C. 5" ~ 8427' ?ST'D, ?err 12.2 ppg Brtdgesal RU Schl, rn CET, tl stopping ±5' into lnr, POOH, RD Schl. RIH w/2-3/8" x 4-3/4" tapered mill, mill f/7720'-7723', trip f/5" csg scrpr. RIH to PBTD, CBU, POOH. RU Schl, att to rn CET w/o success. RU DA, rn GR/CCL/CBL, RD DA. RIH to PBTD, displ well to 12.0 ppg brine., POOH. RU & perf f/8135'-8182' @ 12 SPF. Perf "A" sands f/8271'-8304' @ 6 SPF. ~SZ~' 5" ~ 8427' PBTD, Rn'g CCL/GR correlation 12.2 ppg brine Fin perf'g 8135'-8142'. Rn gage ring/JB to 8250'. Rn CA on WL, failed to go past lnr top. Rn CA on tbg. Rn'g CCL/GR correlation log to space out pkr. Tool failed. 5" f/7720 8427' PBTD, Ldn'g 2-7/8" tbg 12.2 ppg brine P,n correlation log, set pkr @ 8196', POH w/setting tl. Rn 2-3/8" x 2-7/8" compl string. Circ above btm pkr, space out & lnd 2-7/8" tbg. e ve's r act ~nature 7 ~'A For ~orm praparefion and dlstrib~ion, se~ ~rocedures Manual, Section Drilling, Pages 86 and 87. Drilling Superintendent AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District IC°unty or Parish I Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Tltle AFE 703427 North Slope Borough ADL 25570 Completion IAccounting State cost center code Alaska Well no. 2A-9 Nordic 1 AP1 50-103-20055 Date and depth ' as of 8:00 a.m. Operator I A.R. Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~ Date Complete I 3/23/86 Complete record for each day reported Old TD 4/03/86 4/04/86 1200 hrs. Released rig Classifications (oil, gas, etc.) Oil Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prlor status if a W.O. 2100 hrs. I 5tI ~ l~ ~,,,~u'-8530 8427' PBTD, Set dummy orifice mandrel Diesel in tbg & ann RIH w/std'g vlv, set pkr, shear PBR. Tst pkr & SSSV. ND BOPE, NU & tst tree. Displ well to diesel; orifice vlv plugged. RU S/L & pull orifice vlv. Fin diesel displm't. Prep to set dnmmy vlv in place of orifice vlv. (Rn 245 its 2-7/8", 6.5#, 8RD AB Mod & 16 its, 2-3/8", 4.7# 8RD EUE w/DB pkr @ 8203', HRP pkr @ 7594', SSSV @ 1816', "D" nipple @ 8217', TT @ 8225') 5" g530' 8427' PBTD, RR Diesel in tbg & ann Att to set dummy in 1-1/2" GLM w/o success, POOH. Rn impression block, tag 1" BK-2 latch @ 7498'. Rn impression block, tag T-2 latch @ 7536', POOH, RD S/L. Tst orifice vlv; OK. Set BPV. RR @ 1200 hrs, 4/3/86. RECEIVED MAY 2 2 1986 Alaska Oil & Gas Cons. Commission Anchorage rNew TD I PB Depth , 8427 PBTD IDate JKInd of rig 4/3/86 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval OII or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation and~listribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, IDate ~ ITItle Drilling Superintendent ADDENDUM WELL: 2A-9 FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1713 hrs, 4/18/86. Frac'd Kuparuk "A" sand perfs 8271'-8304' in 5 stages per 4/7/86 procedure using gelled diesel system. Press'd ann to 1500 psi with diesel. Tst ins to 7500 psi; OK. Stage 1: Pmp'd 80 bbls diesel w/5% Inflo 40 Musol. Stage 2: 46 bbls cln diesel @ 2.5 BPM, 3700 psi. Stage 3: 19 bbls gelled diesel pad @ 4.9 BPM @ 3460 psi. Stage 4: 14 bbls gelled diesel w/7 ppg 20/40 mesh sand @ I1.I BPM, 5970 psi. Stage 5: 46 bbls gelled diesel flush @ 19.6 BPM, 5370 psi. Pmp'd 3200# 20/40 mesh sand in formation leaving no sand (per frac procedures) in csg. Load to recover 145 bbls of diesel. Job complete @ 1720 hfs, 4/18/86. Turn well over to CPF 2 Production. RECEIVED MAY 2 2 1985 Alaska Oil & Gas Cons. Commission Drilling Supervisor Date I! ~.fl_~i W ..e(~. ~:l~ay aft. e.l' a .Wel! I~. spud.dad or. workover operations. Ire started. .??~:/;::?~?.:~ ~tO~. 17dqq!~Oe ~m~,l~m form giving inclusive) ~ltol only. Distrt~-. -- -'~-']%~¥~ ~, ~d.h or ~ro~h I State Alas~ ~ Notch SlOpe Borough I Alas~ Field ..... Le~ or unit Kup~k River ~L 25570 2A-9 Auth. or ~.O, ~o. Tiffs ~:. 703427 Drill . NaborS 26-E-- APT 50-103-20055 Operator. IARCO W.I. ., ARCO Alaska-, Inet,: 56.24% Spudded:0rW. O. begUnspudded IDate 2/8/86 [Hour 2330 hrs. Iprl°ratetullfew'°' Date and~lepth Complete record/or each day reported aa of 8:00 a.m. 2/08/86 2/10/86 2/11/86 2/12/86 2/13/86 2/14/86 16" @ 110' 2380', (2270'), POOH ~t. 8.9, PV 13, YP 12, PH 8.5, ~L 10.5, Sol 4 Accep~ rig @ 1630 hfs, 2/8/86. NU diverter sys. 2330 hfs, 2/8/86. Drl & surv 12¼" hole to 2380' 300', Assumed vertical 417', 2.9°, S 7.2~, 417 TVD, 2.9 VS, 2.9S, .4~ 960', 18.3°, S12.2~, 949 TVD, 98.3 VS, 97.1S, 16.6~ Spud well @ . 16" @ 110' 3450', (1070'), Rn'g 9-5/8" ~t.'9.4, PV 24, YP 36, PH 8.5, ~L 8.4, Sol 8 TIH to 2049', wsh to btm. Drl f/2380'-3450', short trip, ~ight f/1654'-2201'. C&C mud, POOH. RU & rn 9-5/8" csg. 2395', 48.2°, Sll.2~, 2093 TVD, 927 VS, 918S, 150~ 2737', 47.9°, S10.2~, 2321'TVD, 1181VS, 1168S, 197~ 3061', 48.3°, S12.2~, 2538 TVD, 1422 VS, 1404S, 244~ 3405', 48.2°, S12.2~, 2767 TVD, 1679 VS, 1655S, 298~ 9-5/8" @ 3409' 3460', (10'), CBU ~C. 8.8, PV 7, YP 3, PH 10.5, I~L --, Sol 3 Fin rn'g 86 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3409', FC @ 3327'. Cmr ~1000 sx CS III, followed by 400 sx CS II. Displ using rig pmps, bump plug. NU & Cst BOPE. TIH, tst csg Co 2000 psi. DO flt equip & cmt + 10' new formation. CBU. 9-5/8" @ 3409' 5538', (2078'), Drlg 8½" hole Wt. 9.0, PV 14, YP 11, PH 9.8, WL 7, Sol 5 Drl & surv 8½" hole to 5538'. 3524', 48.4°, S 9.2W, 2846 TVD, 1768 VS, 1743S, 315W 4501', 47.0°, Sll.2W, 3499 TVD, 2493 VS, 2460S, 436W 5438', 47.2°, S16.2W, 4141TVD, 3175 VS, 3120S, 607W 9-5/8" @ 3409' 7200', (1662'), Drlg 8½" hole Wt. 9.4, PV 15, YP 10, PH 9.5, WL 5.8, Sol 7 Drl & surv 8½" hole to 7200'. 5766', 46.7°, S16.2W, 4365 TVD, 3415 VS, 3351S, 674W 6162', 47.1°, S20.2W, 4635 TVD, 3703 VS, 3625S, 765W 6476', 49.7°, S20.2W, 4843 TVD, 3936 VS, 3846S, 846W 6802', 50.2°, S20.2W, 5053 TVD, 4184 VS, 4080S, 932W The above is correct Signature For form preparation ql~d distribution, see Procedures Manual:, 8ectlon 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem testa sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but nOt less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish ]State North Slope Borough Alaska ADL 25570 2A-9 Field Alaska Kuparuk River Date and deptl~ as of 8:00 a.m, 2/15/86 thru 2/18/86 2/19/86 Complete record for each day while drilling or workover in progress 7" @ 7954' 8479', (1279'), Drlg 6-1/8" hole Wt. 12.6, PV 25, YP 14, PH 9.5, WL 5.5, Sol trc Drl & surv 8½" hole to 7975', short trip, CBU, POH. RU & rn 185 its, 7", 26#, J-55 BTC csg w/FC @ 7865' & FS @ 7954'. Cmt w/200 sx C1 "G" w/l% FL-19, .5% CD-31, .3% A-2 & 1GHS FP6L. ND BOPE. Set 7" slips. NU & tst BOPE. PU BHA &3½" DP, TIH w/6-1/8" bit. DO FC, cmt, FS + 15' new hole. Conduct formation tst to 13 ppg. Drl & surv 6-1/8" hole to 8469', short trip, CBU, TOH. Log hole. RIH, drl to 8479'. 7108', 50.3°, S20.2W, 5249 TVD, 4418 VS, 1013W, 4301S 7390', 49.8°, S19.2W, 5430 TVD, 4633 VS, 1086W, 4504S 7700', 48.4°, S17.2W, 5633 TVD, 4867 VS, 1159W, 4727S 7910', 45.6°, S18.2W, 5776 TVD, 5020 VS, 1206W, 4873S 5" @ 8525' 8535', (56'), TIH Wt. 12.7, PV 26, YP 14, PH 9.5, WL 5.5, Sol -- Drl 6-1/8" hole to 8535', CBU, TOH. RU & wn 17 Jts, 5", 18#, L-80 LTC csg w/FC @ 8474', FS @ 8525', LC @ 8424'. Cmt w/200 sx C1 "G" w/l% FL-19, .5% CD-31, .3% A-2 & 1GHS FP6L. WOC. TIH to circ mud out. The above is correct Signature For form preparation and ~listribution see Procedures Manual S~ction 10, Drilling, Pages 86 and 87 JO ate ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inatructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or weld is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I County or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE 7O3427 Nabors 26E Operator t A,R,Co. W.I, ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded Date and depth as of 8:00 a.m. 2/20/86 Complete record for each day reported Accounting coat center code State North Slope Borough Alaska ADL 25570 Drill IWell no. 2A-9 A?I 50-103-20055 rTotal number of wells (active or inactive) on this Icost center prior to plugging and 56,24% Jabandonment of this well i [Hour IPrlor status if a W.O. 2/8/86 ~ 2330 hrs. I 5" @ 8525' 8535' TD, (0'), RR 14.1 ppg TIH, circ out mud, leave 14.1 ppg, TOH, LD DP. Displ top 1900' to 9.7 ppg brine, TOH, LD DP. ND BOPE, NU &tst tree. RR @ 1600 hrs, 2/19/86. Arctic Pak w/175 sx CS I, followed by 60 bbls Arctic Pak. APR 0 4 ]9116 Alaska Oil & ~:-~s Cons~ Cornmi~sb~ Old TD Released rig 1600 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing INew TD Date PB Depth 8535 ' TD 2/19/86 Kind of rig Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Potential test data Well no. [~ate Reservoir !Producing Interval Oil or gas Test t'ime Production Oil on test ~Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Elfective date corrected The above is correct Signature I Date ITitle I For form prep-aration and (~stribution,- see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent Form to be inserted in each Active well folder to cec for timely compliance with our regulations. OPERATOR, WEL~-NAME 'AND NUMBEI~.T,~ Reports and Materials to be received by.'2~~~~~___ --Date Required Date Received Remarks Completion Report Well History Samples ~ ...... ,,~_ Mud Log Core Chips ~, ~___., _ Core Description Registered Survey Plat ~~ Inclination Survey Dr~ll Stem Test Reports Log Run .Digitized, Data , , ~~ 3 --/~--~A. _ 0~. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION ;1. Drilling well Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 1267' FSL, 53' FEL, Sec.14, T11N, R8E, UH 7. Permit No. 86-1 8. APl Number 50-- 103-20055 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2A-9 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 123' RKBI ADL 25570 ALK 2668 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of February , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2330 hfs, 2/8/86. Drld 12-1/4" hole to 3450'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7975'. Ran, cmtd, & tstd 7" csg. Drlg 6-1/8" hole to 8469'. Ran logs. Cont'd drlg 6-1/8" hole to 8535'TD (2/18/86). Ran, cmtd, & tstd 5" csg. Secured well & RR (~ 1600 hfs, 2/19/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 110'. Cmtd w/270 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe 8 3409'. Cmtd w/1000 sx CS III & 400 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7954'. Cmtd w/200 sx Class G. 5", 18.0#/ft, L-80, LTC csg f/7716' - 8525'. Cmtd w/200 sx Class C. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/SFL/GR/FD6/CNL/Cal f/8437' - 7939' 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED &~~ TITLE Associate Engineer DATE ~']'~'~/'~ NOTE--Report 4 this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate ARCO Alaska. inc. Post Office Box 100360 Anct~orage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, LNC. 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 items. Please acknowledge receipt and return one signed copy of this 'transmittal. OH Lis Tapes Plus listings/ SCHL/ One of each x'°3N-4 02-14-86 REF #71279 '~3N-~- 02~07-86 REF #71266~ '~3N-2 01-27-86 REF #71272~ '~3J-16 02-15-86 REF #71278_~~ ~3I-5 02-09-86 REF #?1273~. ~'~I-4~ 02-02-86 REF #71239~. 3I-3 01-26-86 REF #71242 ~2A-11 01-28-86 REF #71243~ ~2A-10 02-06-86 REF #712445 2A-9 02-17-86 REF #71280~ Receipt Acknowledged: STATE OF_. AK..... ARCO AII$ILi. Inc. is I Sul~$,a~lry of AtllfltlcRichtiel~Complfllp, ,MEMORAN 'UM State of Alaska TO- TH RU: FROM: ALASKA OIL AND GAS CONSERVATION O0~ISSIOI-~ C~laj_I~'~ FI LE NO.' ~e C. ~~ ~ TELEPHONE NO.: ~ss~oP~ ~e~ole~ February 19, 1986 BOPE Test on ARCO- F.R.U. - 2A-9 Permit ¢/86-1 Kuparuk River Field Tuesday, Feb~3ary 11, 1986: The BOPE test beggn at 9:45 p.m. and was ~nctuded at 10:45 p,mi:~-~ As the attached BOPE test report sho~s there were no failures. In s~, I witnessed the BO~ test on td~OO's 2A-9. Attac~nt 102-001 A ( Rev 10-84) ,- #4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date ~~ // ~ ~~ Representative~ ~ ~/~Casing~Set @,~V~9 ft. Rig (~~Representative Al- 'Zz~-~~ Location, General~~~~/Well Sign General Housekeeping O~ Rig ~~ Reserve Pit ~ ~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer '/ Pipe Rams' Blind Rams '/ . Choke Line Valves / H.C.R. Valve / Kill Line Valves Test Pressure Check Valve f- ACCUMULATOR SYSTEM Full Charge Pressure~/~ ~ psiR Pressure After Closure /~CP psi~ Pump incr. clos. pres. 200 psiK - mind'sec. Full Charge Pressure Attained: ~ mind'sec. Controls: Master RemoteT~ Blinds switch cover /.~t,~'.~/. , Kelly and Floor Safety Valves " Upper KellM / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold ~V ~-~ Test.Pressure No. Valves /%/ No. flanges ~ ~ Adjustable Chokes Test Results: Failures ~ Repair or Replacement of failed equipment to be made within Commission office notified. Remarks.. Hydrauically operated choke / Test Time - / 'hrs. day~ and Inspector/ Distribution orig. - AO&GCC cc - Operator - Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 22, 1986 Mr. C. V. Chatterton Commi s s i oner 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, . Gruber Associate Engineer JG/tw GRU13/L19 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JAN 2 7 Alaska 0it & Gas Cons. Commission Anchorage ~ WELL 9 Y = 5,960,687 74 ~ X = 498,:540 70 [ l_AT 70° 18' i r~[ ~' LONG 150°00'48.:587'' [ O.G. 87 6' 2' , PAD 92 [ ! ~ I 266' FSL 5:5' FEL ' ~o· i! WELL I0- , 015 I Y = 5,960,747.76 9 · i 0 16 ' X = 498,:540;70 · ' LAT. 70°18,14.3619 ! I LONG. 150o00 48.388" ' J : O.G. 88.0' PAD 92.:5' I,:526' FSL 53' FEL I i WELL II- ! Y= 5,960,807.80 X = 498, :540.85 ; LAT. 70° 18 ' I 4.9525 I LONG. 150° 00'48.:58:5" 80 ~ O~ I O.G. 88.:5' PAD 92.:5' 70 I,:587' FSL 5:5' FEL 60 O~ 50 , 04 i WELL 12- Y= 5,960,867.74 i X = 498,340.71 i LAT. 70°18' 15.5420" I I LONG. 150°00'48.388'' ! [ , O.G. 88.5' PAD 92.0' ~446' FSL 5:5' FEL 14._~ 3 23 I 24 J~ ,..~T OF LOCATED IN PROTRACTED SECTION 14, Til N, R8E, ~:> c~ ,,~ ~, ~.x~_... - UMIAT MERIDIAN. -- r,. 8 ~ ~'~49th · NOTES I.z.I cu ~ ~ ~....~.,......-., .... ,.,..,,I... I. COORDINATES ARE A.S.P., ZONE 4. U Z ~ ~-~.---,,~, ...... 2. SECTION LINE DISTANCES ARETRUE. '' ' < 't,"_'~ = :5. HORIZONTAL POSITIONS BASED ON 2A-NORTH 8~ 2A-SOUTH ~ -'3 4. VERTICAL POSITIONS BASED ON 2A-MIDDLE PER L.H.D. 1~ ASSOC. DWG. NO. NSK-6.201-~11. ~ ~'~, ...... 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. <~' '~t~'-~OF£.~,n,,~ ~__ ~i' ~.11 I,/."I ,~........,~,. CED- BAO0- 3001 rev. ~ .S. LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY'MADE UI$ ) Itil)(~UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS 14 13 I & ' ARE CORRECT AS OF D.S. 2'A ~--THIS/SURVEY ARCO Alaska, Inc. -- > : ro ~~...~'~' Kuporuk, Project North SIoDe Drmiting j ,~L__~,~'~ DRILL SITE 2.A i LOCATIONS .. Date 12:50 85 Scale AS SHOWN Drawn By' ~ J Dwg. No. NSK- 85-;.'58 January 17, 1986 Ms. JoAnn Gruber Associate Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: KRU 2A-9. Dear JoAnn: An incorrect API number (50-103-20055) was assigned this well. The correct AP1 number is 50-103-20059~ We apologize for an inconvenience this may have cause:- Sincerely yours, ?S~ohn A. Levorsen Senior Petroleum Geologist be: 2. JAL 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-9 ARCO Alaska, Inc. Permit No. 86-1 Sur. Loc. !267'FSL, 53'FEL, Sec. 14, TllN, RSE, Btmho!e Loc. 1048'FSL, !386'FEL, Sec. 23, TllN, R8E, 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 ?4 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~y~trulM.¥ours,' C. V. .hatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of EnVironmental Conservation w/o enc!. Mr. Doug L. Lowery STATE OF ALASKA --' ALASKA 0,~ AND GAS CONSERVATION CO,,,,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~x REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIG..R4PH lC SINGLE ZONE ~ MOLTIPLE ~,0NE [] 9. Unit or lease name 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1267' FSL, 53' FEL, Sec.14, T11N, R8E, UM At top of proposed producing interval 1447' FSL, 1289' FEL, Sec.23, T11N, R8E, UH At total depth 1048' FSL, 1386' FEL, Sec.23, T11N, R8E, UN 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 Kuparuk River Unit'~¢ ' CO4~. 10. Well number 2A-9 -% 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 2A-10well 60' ~ surface feet 18. Approximate spud date 02/04/86 2977 psig@___80°F . Surface 3422 _psig@ .5875 ft. TD (TVD) 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1048' 8 TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8663' MD, 6245' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 300 feet. MAXIMUM HOLE ANGLE 48 o (see 20AAC25.035 (c) (2) 21 SiZE Hole Casing Weight 24" 16" 62.5# 12-1/4"[ 9-5/8" 36.0# 8-1/2" / 7" 26.0# 6-1/8" I 5" 18.0# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling H-40 ! Weld 1-55/HF-EIW BTC . -55/HF-E~W BTC L-80 / LTC Length 80' 32' I ~ I 3447' 31' 7980' MD TOP I 31' 31' I SETTING DEPTH TV D MD BOTTOM TVD 32' 1121 112' 31' 34781 2775' 863' 7800'1 5667' 8011~ 5808' 86631 6245' QUANTITY OF CEMENT (include stage data) + 200 cf 1000 sx CS III & 360 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 8663'MD(6245'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 2977 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-9 will be 60' away from 2A-10 at the surface. (continued on attached sheet) 23. I hereby certi?J,y that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Regional Drilling Engineer DATE et~w o~ ¢ The spac '~ ~/m sion use CONDITIONS OF APPROVAL Samples required I--lYES /~NO Permit number Form 10401 (JFB) PD/PD1 Mud Icg required []YES ~NO Approval date ~ 01/06/86 Directional Survey required APl number I-'-~YES I-]NO 50-/C,~'- ?-- 0 O, ..'~.~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 6, 1986 by order of the Commission Submit in triplicate PERMIT TO DRILL 2A-9 (cont'd) There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumpin 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. RECEIVED ' ARCO ~ALASKA..~+lC. , ? ' t. 'i~.~ :71~ , ~, : KUPARUKcFlgLD,, NORTH S~PE. ALASKA' i/~~ :--~, ~- ,, , . ~ ~ ! ! ' !.} ... I ' ...i .... i ' ; ,:, ' - '- ~ ..... t ' ' ..... ........ ~ ................ ]3~ ............... ?- ~llla~,&~'~' ....... ~, i T ~' ~' : r--- ..... ~ .... -, -- -T ~ . · , ~ ~ , , ! , ................................... ~ .................... .~ .............~ .............. _ ........................ F ........... ~ .......... ~ ................................... ; ....................... ............................ : ; .......... ~ .......... L ......................... ~ ~ .............................. : ~ ........ ~ ............ ~ ......................... ~ ............................. ....... TMD~ : ~ , -EOC TV~1719- t900~EP=632 - - ~ ~- .......... ~ ................... ~ ....... ~ )P'2~:S-AK]~NDS;-]:" ~VD;22i ~:TMDA264 i: DEPA 1' 182 ........... ......................... ; ............ ~ ........... ~ ............. ~ ........................................................... ~ ................ : ....... - ~ ~ , ~ : , ~ , ....... ~- -; ....r ........... ~ ................. t ........................ ~ ..................... ~ --~ ~ . , .... ....... ~ ................... : .................... ~ .................... ~ ~.~ ........ ,. ................ ~ : . .. _.~ ,~__ . ,,. : . . .......... ~ ............ ~ ........... ~_.~~ ................................... ~ ~ ~ ' ............... ~ ..................... ~ ---~ ......... , ~ -- ........... o ................................................ ...................... ....... . :AVERA GLE .......... .......... > ........................................... ........ :'-::::-:GE A N . . ~ .... ~ ........................................... ~ .............. : .. ................. ..... ~ ............... ~ ...... ~ .... ~ ....... , ........ ~ ......................................... ~ ............ K-5 TVD 4445 T-MD ~974 DEP ~659--- : ...... ~ .... ................. : ................................ ~ ..................... I i · - - .............' ........................ r ............................................ .................... , .............. : ...................................... ~ ..................... . ..... ~ ............. . ......... .......... ? ............................................. ! ..................... 4 .............~ ........... ~ .................... 2 .................................... ~ ....... : ..... .... ~ .......................... ~ ~ ............. ~ .......... . ........ ~ .......................................................... ~ ......................... ' ' ~ ......... ~ ............. ~ .................... ~ .............. - ...... ]': ':' ~ ]:-]-.~.'-]-]:-]:..~..---~:.'-:--:]]---- ' T-/.-'ZONE]]C:]:--TVD~58ZS::TMD=8'I'i:I:.:DEP=524Z]'....:_/-:"- ' ...... ~ ................... ~ ~ ............. ........................... ._~:~: ............ :-:::: BASE--KOP '~NDS~-TVD=~ 11~ -~-e46~ DEP'~50~ .... ~ .......... "~. ............ ....... ~ TD .... iLO00 INO.-P~)':]]TV,~ '-=62~._:~MD=8663~...DEP=5658. :-.~":.::_T .:. ~ - ~ ~ ,: .... ; ,~, , ~, ~ ~ ~ ~ - ' ~ 'F ..............................~ -~ .......... ~ .............. .......... ~ ........................... ~ . '~ ...... T .......... ~ ..... ~ ................ ~~ ~ ........... ~ .........................., .............................. ~ .......................... ...... , .... ~. . ~ ....~ .. ~ · ~ ,_._..__~_~____~-,,~,~~-~.~~ , : - ....... ~ ...... :~ . ,.. _ ..... ~ .................. :. ...........~-:-- -+-- ..... · ...... ~ ~ ..... ~--~ ........ ~ ............. i..' .............................. ~ ~~ ....... ~ .......... ........ ~ ........ : .......................................... ~ ' ~ ...................... ~ ........ ~ .......... i .................. ~ .~ ...... ~ ~ - . .............................. L ......................... ] ............ ~ .... ' ........ ~ ...................... ~ ......................... ~ ............... ~ ......... i .......... ~, ..................... .~, ............................ ~ ......................... _ . ........................ · i- .... 4 ........................ i ................... · . . , I I I J I I I I KUPARUK R:[VER UNIT 20" 'D]ZVERTER SCHEMAT:[C P DE $CR I PT I ON i. 16' C~CTOR, 2, TANI(O STARTER HEAD, 5. TANKO SAVER SUB. 4, TANKO LOV~ER QUI CK-C~CT ASSY, 5. TAha(O UPPER QUI CK-C~CT ASSY, 6, 20' 2000 PSI DRILLING SPOOL W/I0' OUTLETS, I0' HCR BALL VALVES W/lO' DIVERTER LINES., VALVES OPEN AUTOMATICALLY UPON CLOSURE OF AAN.~AR PREVENTER, 8. 20" 2000 PSI AhI'~LAR PREVENTER. 5 4 MAI NTENANCE & OPERAT. I ON I. UP-ON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES -- HAVE OPENED PROPERLY, CLOSE AI~LAR PREVENTER AI~) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 5, CLOSE AI~LAR PREVENTER IN THE EVENT 'THAT AN IhFLUX OF WELLE~ ' FLUI DS OR GAS I S DETECTED, ! F .. NECESSARY, MA~ALLY OYERR:[DE AhD CLOSE .APPROPRIATE VALVE TO ACHIEVE ~II~ DIVERSION. RECEIVED ~o NOT SHUT IN ~LL ~(, 2~.~. ~.=D.:~ UD, E)ER ANY CIRCUMSTA~ES. Alaska Oil & Gas-conS.'-Oo.mI'n ssic}r~ 6 J !--SIS" ~-~,,300 PS! RSRRA BOP, S'FAC]< I. 16' - 2000 P~I TAN(CO START]hI~ t-F_AD 2. II' - ~ PSI CASING IF. AD 3. I1' - ~ PSI X 1~,-.~/8' - 5000 PSI 7. i~8' - ~ ~l .. ACCL~ATO~ CAPACITY TEST I. C{-ECK At, J) F'/LL ~TCR EESERVDIR TO ~ LEV'EL V~TH HYDRN~IC FLUID, 2. ~ THAT ACO. NU. ATOR ~ IS 3C00 PSI W~lH t500 PS] D3~NSTF~AM CF TPE R~U_ATC~. ~VE TIh~, TI'-EN I::::LC:E~ ALL LI~TS S]M.,LTANE~Y N~ RECORD TPE T]~ ~ ~ ~l~ ~ IS 45 ~~ ~I~ T~ ~ I~ ~I ~l~ --.5 iii 4 KUPAEUK 16' 13-5/8" BOP STACK TEST CONDUCTOR BOP ~,~.TA "~: '~ ....... I, F:[LL ~ STAC~ ~ ~ MANIFD_D WI~H ARCTIC DIESEL. 2' D-ECX THAT ALL LDSK ~ SSREWS IN VF_LL~F_AD ARE FLLLY EETEA~TED. SEAT TF_ST PLUG IN ~F_LLPF_AD W~TN RUNN]NG JT .AND ~ ]N L~ SCREWS, L]hE VALVES ~ 'rD Bt~ STACK. ~ O'T'f'EE 4. ~ LP TO 250 PS] AM) ~ FOR 10 MIN. IN-' ~ F:RESSLI~ TO 3500 PSI AND t-O,.D FOR lO MIN, BLEED F:'~A.J~E TD D PSI, 5. D::~EN At~I..LAR PEEVENTER AN3 ~ KILL AhD LINE VALVES. CLDSE TD:> PIPE RAMS AND MSR VALVES ~ KILL AND O-ICKE LIt,ES. 6. TEST TO 250 PSI AND ~ PSI AS IN STEP 4. ?. CDVTINJE TESTIN~ ALL VALVES, LIhE. So AND ~GTH A 250 PS! LO~ At~ 3~_:,00_ P~] HIGH. TEST AS ~ 4. E~) I~)T ~;ht'_mS'Ll:~ T_',~:iT Ah,h'~ THAT NgT ^ FLLL CLOSING ~CS]T]VF_ SEAL ~. CN.¥ F~71C)~ TF. S1 C~5 1 HA1 DO NDl F~Y CLOSe. 8. O~EN TC)~ PIPE ENVE AhD CL__rJC-~'_ BOTTC~ P]PE EAMS. TEST BOTTCI~4 PIPE P~ 'FO 250 PSI AhD' 3500 PSI. PLLL DJT OF HCLE. ID. CLOSE BLIND P~ AhD TEST TO 250 PS] AND 3500 PSZ. Ii. C~N BLIND R~ AND EETRIEVE TEST PLUG, MAKE MANEFCLD AhD LIhF. S AR~ FLt. L DF FLUID. SET ALL VALV~ IN DRILL]NG POSITION. TE$1 $1ANEPIPE VALVES,. K~'l /y, KELLY CC~, DP,~LL PIPE SAFETY VALVE, AhD INSIDE BOP TO 250 PSI AhD 3500 PSI. 15. R~CCRD T~ IhFCRMATIDN CN BLC~ Pl~ TEST FDRN, SION.. AND SEND TD DRILLING S;LI~RVISC:R. 14. PERF'~ CDvPLE'TE E~ TEST AF'fER NIPPLIN3 UP AND VlEF_KLY T~/:~I.~, TI~Y ~TE DQc:~ DAILY. 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-9 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill 2A-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on February 4, 1986. any questions, please call me at 263-4970. Sinfi~ely, Regional Drilling Engineer JBK/JFB/tw PD/L197 Enclosures If you have RECEIVED Alaska O, il & Gas ~mns. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany (i ~ ~:~:~. '(2) .oc thru .8) (3) Admil((8~~ /'2'''/""/'*3'''' (gthru 12) (10 and 12) / (13 thru L/l)/ /W// thru/26~ (6) Add: ///fi'// ./~/Jo/$./ , / / 3. 4. 5. 6. 7. '8° 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. emit fee taChed - ' ' the p. at ...................... t' ................ · Is well to be located in a defined pool ..... ' ..... - ................... Is well located proper distance from property line .................. Is well located proper distance from other wells ..... ,..- ............ Ia sufficient undedicated acreage available in this pool ............ 'I~ well to-be deviated and is wellbore plat included ..... ~ Can pemit be approved before ten-day wait ..~ ..... '... ' ~. Does operator have a bond in force .................................. ~ Is a conse~ation order needed ...................................... ~ Is adminiStrative approval needed ................................... ~ Is the lease number appropriate ....................................... ~ REMARKS Is conductor string provided .., ..................................... ~ . .. Is enough cement used to circulate on conductor and surface . Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... ~ __ Will surface casing protect £resh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on i0-403 ............ Is adequate wellbore separation proposed ............................ ~_~ .SElf Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ...... Does BOPE have sufficient pressure rating - Test to Y~Z~D p;ig Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: Geology: ncs ~VA 2~ · :ev: 03/13/85 :~.011 Engineering: · ' ' INITIAL 'GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. ,o ~m{mm{~mmm~mmm~mmmmmN{ ********************** RECEIVED MAR 1 2 1986 Alaska Oil & Gas Cons, Commission Anchorage 000 000 004 065 OOO 000 014 065 000 000 002 065 0o0 000 004 065 2.00 00o 002 065 0oo 000 012 065 000 000 006 065 (:~ o o 000 003 065 ! ,/[, 84t9,0' ....... ~ i~:: ~. PAGE 3 $t;'b[! DIL DHifi~ O0 220 0 1 0 0 4 S P [;:' l l, ~ V O 0 V 1 0 9 i 0 9 4 GR ElL GAP1 O0 310 gl 0 O 4 DRHO F" tJ ~'~ (1/C3 O0 356 Ot 0 0 4 ,~ R A { F'[3 i~ 0 0 x~ 2 0 0 I. C, 0 4 RaRA F()k Oo 000 Oo O 0 4 68 00000000000000 1 68 00000000000000 1 68 000000000000( 1 68 000000000000(~ 1 68 00000000000000 1 68 00000000000000 I 68 OOOO0000000000 I bg 00000000000000 1 68 00000000000000 1 6~ 00000000000000 1 6~ 00000000000000 1. 68 00000000000000 1 6~ 00o000o0000000 1 6~ 00000000000000 ! 68 O00uo000000000 ], 920~ IL~ 0 937;8125 ,9492 46,9:492CAb1 1601,480;7 R~iRA ;6875 6, ]:0:t 5 !LO , :4,9968 {:L~ ,..1.'!773 G~ ~. ?773 CALl 35't 1, bO(.,t~ FC~,L 1430.b875 2.4045 iLO 2,2366 iSM 3b.!A75 GR :136." 1~75 CAbI )5,50(}C, VC~,,;., 614.3125 ?0"30,687~ ILO 16,8799 ~b~ 132.5625 GR 132.5625 CALl -0 4h24 ~R~,] 3,6213 Ri'~b i624:6875 FCf'4L 4~3.3906 ~ r~ V I C E ~,¢670 ,i257 2,8889 996 _39~ ,9807 ,8770 125:;~t32 2,4417 §.4421 ,b882 ~,4534 ,043 3,J752 2.3577 5.0320 2000,6875 6,2625
