Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
180-133
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-02 KUPARUK RIV UNIT 1B-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 1B-02 50-029-20531-00-00 180-133-0 G SPT 6109 1801330 1527 2750 2750 2750 2750 80 85 85 85 4YRTST P Guy Cook 6/13/2025 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1B-02 Inspection Date: Tubing OA Packer Depth 640 2010 1960 1955IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612101351 BBL Pumped:1.1 BBL Returned:1 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Re gg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IB -02 KUPARUKRIV UNIT IB -02 Sre: Inspector Well Name KUPARUK RIV UNIT IB -02 API Well Number 50-029-20531-00-00 Inspector Name: Jeff Jones Permit Number: 180-133-0 Inspection Date: 6/29/2021 Insp Num: mitJJ210701131617 Rel Insp Num: Wednesday, August 11, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IB -02 Type Inj G -TVD 6109 - Tubing' 2590 -' 2580 -' 2570_ 2570 - - PTD 1801330 - "Type 'fest SPT Test psi I 1527 ]A 640 2000 - 1950 - 1930 BBL Pumped: I - BBL Returned: I - OA 150 - 170 170 170 interval Four Year Cycle PAF Pass Notes: I well inspected, no exceptions noted. Previous MIT early (Apr 2017) due to water header modifications in May 2017. Wednesday, August 11, 2021 Page I of I • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, February 13, 2018 10:26 AM To: Wallace, Chris D (DOA) Cc: NSK Well Integrity Supv CPF1 and 2 Subject: KRU 1B-02 (PTD 180-133) Follow up email Attachments: 1 B-02 90 day TIO trend 2-13-18.JPG; MIT KRU 1 B-02 diagnostic MITIA 1-14-18.xlsx Chris, KRU WAG injector 1B-02 (PTD 180-133)was reported for suspect IA pressure increase on January 12th, 2018. After passing an MIT-IA the well was placed on a 30 day monitor period during which the IA pressure exhibited stabilization and no indications of annular communication. The well is being returned to 'normal'status at this time, if at anytime in the future the well exhibits any indications of annular communication it will be reported and addressed at that time. A 90 day TIO trend and 10-426 are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELLS TEAM conocaligsps SCANNE® • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday,January 12, 2018 8:28 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU 1B-02 (PTD 180-133) Report of suspect IA pressure increase Attachments: 1B-02.pdf;'1B-02 90 day TIO trend 1-12-18.J PG Chris, KRU WAG injector 1B-02 (PTD 180-133) is exhibiting an unexplained increase in IA pressure. Operations has bleed the IA pressure down multiple times, but the IA has re-pressurized post bleeds. The plan is for DHD to perform initial diagnostics including an MIT-IA and pack off tests. Then the IA will be degassed and bled down prior to a 30 day monitor. If the MIT-IA fails the well will be shut in and freeze protected until a plan forward is developed. Attached is a 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 iliplIZELLS TEAM onocataips SCAtNE = • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg !� J DATE: Wednesday,May 03,2017 P.I.Supervisor \ ' I �I l 7 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-02 FROM: Lou Laubenstein KUPARUK RIV UNIT 1B-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,I NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1B-02 API Well Number 50-029-20531-00-00 Inspector Name: Lou Laubenstein Permit Number: 180-133-0 Inspection Date: 4/22/2017 Insp Num: mitLOL170423065758 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IB-02 Type Inj W ' TVD 6109 Tubing 2325 T 2316 - 2305 • 2306 - PTD 1801330 Type Test SPT Test psi 1527 IA 1340 3025 - 2970 ' 2965 • BBL Pumped: 2.1 - BBL Returned: 1.8 - OA 4251 485 - 485 - 485 - Interval 4YRTST P/F P ,/ Notes: SCANNED AUG 2 4 2017. Wednesday,May 03,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 1E�1 4'1(0!15 DATE: Monday,June 01,2015 P.I.Supervisor (( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-02 FROM: Lou Grimaldi KUPARUK RIV UNIT 1B-02 Petroleum Inspector Src: Inspector Reviewed B) P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IB-02 API Well Number 50-029-20531-00-00 Inspector Name: Lou Grimaldi Permit Number: 180-133-0 Inspection Date: 5/28/2015 Insp Num: mitLG150528211934 Rel lnsp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well -- -113-02 ' Type Inj N' 'TVD 61°9 Tubing 1700 - 1700 . 1700 1700 - PTD 1801330 ' Type Test SPT Test psi 1527 - IA i 920 2500 2450 2440 Interval INITAL — P/F P V OA 590 685 685 685 - Notes: 1 3 bbl's diesel pumped,allowed them to bleed back to adjacent flowline.Good solid test All required paperwork supplied prior to test $CANNED i.'t- 1 3 2 01 , Monday,June 01,2015 Page 1 of 1 STATE OF ALASKA ' AL,-....:A OIL AND GAS CONSERVATION CON .SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing p' Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Fool r Repair Well Re-enter Susp Well r Other: I- 2.Operator Name: 4 Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development r Exploratory r 180-133 3.Address: 6 API Number: Stratigraphic r Service r` P. O. Box 100360,Anchorage,Alaska 99510 50-029-20531-00 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 25648 KRU 1 B-02 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 8153 feet Plugs(measured) 7146 true vertical 6792 feet Junk(measured) None Effective Depth measured 8027 feet Packer(measured) 7062, 7277,7595, 7788 true vertical 6692 feet (true vertical) 5940, 6109,6353, 6503 Casing Length Size MD ND Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 2905 10.75 2934 2646 PRODUCTION 8089 7 8114 6761 RECEWED MAY 2 0 2015 Perforation depth. Measured depth: 7652'-7669', 7863'-7900' SCANNED i Ut 3 0 2015 3'�e �l O/"�C(� True Vertical Depth: 6397'-6410',6562'-6592' �.J Tubing(size,grade,MD,and TVD) 3.5, L-80/J-55, 7813 MD, 6522 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEVABLE PACKER @ 7062 MD and 5940 ND PACKER-BAKER HB-1 RETRIEVABLE PACKER @ 7277 MD and 6109 TVD PACKER-BAKER HB-1 RETRIEVABLE PACKER @ 7595 MD and 6353 ND PACKER-BAKER WIRELINE SET PERMANENT PACKER @ 7788 MD and 6503 ND SSSV-CAMCO TRMAXX5E @ 2188 MD and 2093 ND 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 0 428 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r' Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG p 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 315-138 Contact Jonathan Coberly Cad 265-1013 Email Jonathan.Coberly[a@conocophillips.com Printed Name Jonathan Coberly Title Sr. Wells Engineer Signature Phone:265-1013 Date c..2 0-1S V`rl- l.1.- 1, Form 10-404 Revised 5/2015 7/�/ Submit Original Only ,41t Orn---- RBDMS 1 MAY 2 9 2015 1 B-02 WELL WORK SUMMARY PRE-RIG WELL WORK DATE SUMMARY 10/25/2014 DRIFT W/ DMY GYRO W/2.77 CENT &TAG PLUG @ 7145' RKB. READY FOR E-LINE. 11/23/2014 LOG GYRO SURVEY FROM SURFACE TO TAG AT 7145' PLUG IN CONTINUOUS MODE. REPEAT LOG IN CONTINUOUS FROM TAG BACK TO SURFACE. DATA READY FOR FURTHER PROCESSING. JOB COMPLETE. 2/21/2015 (PRE-RWO)T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; OC POT- PASSED; OC PPPOT- PASSED; FUNCTION TESTED ALL LDS-ALL FUNCTIONAL. 2/22/2015 (PRE RWO) : MIT-IA PASSED TO 3000 PSI, MIT-OA PASSED TO 1800 psi. 3/27/2015 PULLED 2.81" XX PLUG © 7,145' RKB RAN SBHPS FIRST STOP @ 7,595' RKB (P=2,569 PSI, T=145.8) SECOND STOP @ 7,465' RKB (P=2,524.8 PSI, T=141.8) 3/28/2015 DRIFT 2.69" DUMMY WRP TO 7,365' SLM BRUSH AND FLUSH TBG FROM 7,200' SLM TO 7,350' SLM SET 2.69"WFD WRP @ 7,304' RKB CENTER ELEMENT DUMP BAILED 20/40 SAND FROM WRP TO 7,295.6' RKB 3/29/2015 DUMP BAILED 20/40 SAND TO 7,289' RKB TOP OF SAND 4/1/2015 PULL DV @ 6995' RKB; TAG SAND & SET CATCHER SUB @ 7258' SLM; LOCKED OUT TRMAXX-CMT @ 1892' RKB. IN PROGRESS. 4/2/2015 PULLED CATCHER SUB @ 7258' SLM; BAILED 10' SAND FROM WRP (NEW TOP OF SAND @ 7287' RKB); SET 2.80" CATCHER SUB ON SAND @ SAME.. READY FOR BPV 4/11/2015 PULLED 2.80" CATCHER @ 7287' RKB. JOB COMPLETE. POST-RIG WELL WORK 4/30/2015 SET BAITED PULLING TOOL ON BALL n' ROD @ 7146' RKB; PULLED SOV @ 6975' RKB IN PROGRESS. 5/1/2015 SET 1.5" DV @ 6975' RKB; MITT & MITIA(BOTH PASSED); PULLED BAITED BALL N ROD' & 2.81" RHC PLUG @ 7146' RKB; BAILED SAND f/7267 - 7281' SLM, IN PROGRESS. 5/2/2015 BAIL SAND FROM 7281'-7286' SLM; ATTEMPT TO EQUALIZE WRP @ 7304' RKB. IN PROGRESS. 5/3/2015 BAIL SAND & PULLED 2.69" WRP @ 7304' RKB; MEASURED BHP @ 7595' RKB. JOB COMPLETE. CanocoPhillips Time Log & Summary 4Vellview Web Reporting Report Well Name: 1B-02 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 4/19/2015 10:00:00 AM Rig Release: 4/26/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/18/2015 24 hr Summary Mobilize Camp, Pits and shop to 1B pad. Move Rig to 1A pad turn off. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Prepare pit module and rig for move _ off pad and to 1B-02. 06:00 16:00 10.00 0 0 MIRU MOVE MOB P Move Camp, Shop and Pits from 3H pad to 1B pad. Move rig sub off well and move to Y intersection west of CPF-3 16:00 00:00 8.00 0 0 MIRU MOVE MOB P Move Rig Sub from Y intersection west of CPF-3 to 1-G intersection. 34/19/2015 Mobilize Rig to 1 B-02 and spot over well. Spot Pits. Rig Up and Berm Up.Accept Rig. Pull BPV. Kill well with 8.6 ppg seawater. Monitor well. Set BPV. N ipple Down Tree. 00:00 08:00 8.00 0 0 MIRU MOVE MOB P Move Sub from 1G intersection to 1B pad. Raise Derrick at entrance of 1B pad. Maneuver sub to spot over well. Lay Herculite for Pits and spot same. Lay Herculite for Fuel Tank and Cutting Tank. Set Cuttings Tank. 08:00 12:00 4.00 0 0 MIRU MOVE RURD P Berm up Sub Base and Pits. Hook up interconnect in the Pits. Hook up steam in the Cuttings Tank. Take on the first load of Sea Water in the Pits. Accept Rig at 10:00 hrs. Spot Kill Tank. Spot Choke House. Lay kill lines. 12:00 14:15 2.25 0 0 MIRU MOVE RURD P Raise Cattle Chute. Bridle down Blocks. Secure Rig Floor. Continue to take on Sea Water in the Pits. 14:15 15:45 1.50 0 0 MIRU WELCTL MPSP P Pick-up Lubricator. Test Lubricator at 1,500 psi. Good. Pull the BPV. Tbg=600 psi, IA-200 psi, OA= _ _240 psi. Lay down Lubricator. 15:45 18:00 2.25 0 0 MIRU WELCTL RURD P Rig Up circulating lines and squeeze manifold. Pressure test lines to 3000 psi. 18:00 18:30 0.50 0 0 MIRU WELCTL SFTY P PJSM with all hands for well kill. 18:30 21:00 2.50 0 0 MIRU WELCTL KLWL P Pump seawater down tubing taking returns out IA via choke shack to kill tank. Pumped 262 bbls @ 3 bpm down tubing out IA. ICP=540 psi, FCP=310 psi. Hold back pressure walking down through circulation. 275 bbls recovered in tiger tank. SIMOPS: Load Drill pipe into pipe shed. Page 1 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 0 0 MIRU WELCTI OWFF P Monitor well. Tubing Dead. IA slight trickle to dead. SIMOPS: Rig Down and Blow Down Circulating lines. Continue to load Drill pipe into pipe _shed. 23:00 23:30 0.50 0 0 MIRU WHDBO MPSP P Set HP-BPV per CIW Rep. Hanger threads are in good shape. 23:30 00:00 0.50 0 0 MIRU WHDBO NUND P Nipple Down Tree. 04/20/2015 Nipple Down Tree. Nipple Up BOPE. Test BOPE with 3.5"and 5.5"test joints.All tests PASS. Koomey test, 5 bottle avg 2000 psi,Accumulator 2950 psi, 1700 psi after all rams functioned,200 psi recovery in 15 sec, full pressure recovery in 93 sec. Pull BPV. Pull 3.5"completion free. Reverse Circulate well clean. Monitor well. Stand Back 3.5"completion removing jewelry. 00:00 01:30 1.50 0 0 MIRU WHDBO NUND P Continue to Nipple Down Tree. Dart set and threads cleaned and inspected. 01:30 06:00 4.50 0 0 MIRU WHDBO NUND P Nipple Up BOPE. Put 5.5"Solid Body Rams in lower VBR cavities. 06:00 11:30 5.50 0 0 MIRU WHDBO BOPE P Perform the initial BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,000 psi, using a 3 1/2"and 5 1/2"Test Joints. All pressure tests were recorded on a chart. The State's right to witness the test was waived by M. Herrera. 11:30 12:00 0.50 0 0 MIRU WHDBO SVRG P Service Rig. Drawworks and Top Drive Inspection. 12:00 12:30 0.50 0 0 MIRU WHDBO OTHR P Rig up GBR equipment. Load 4 3/4" Drill collars in the Pipe Shed. Rig up Spooling Unit. 12:30 14:30 2.00 0 0 MIRU WHDBO BOPE P Resume BOP test. Make-up the 5 1/2"Test Joint. Test the Pipe Rams and Annular at 250/3,000 psi. Perform the Koomey draw down test. Test summary: BOPE test per ConocoPhillips/AOGCC requirements at 250/3000 psi with 3 1/2"and 5 1/2"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, Matt Herrera. All pressure tests PASS. All tests recorded on a chart. Koomey draw test,good. 5 bottle avg 2000 psi.Accum Pressure 2950 psi, Manifold Pressure 1600 psi,Annular Pressure 680 psi. Pressure after all rams functioned 1700 psi.200 psi recovery in 15 sec,full system pressure 93 sec. 14:30 15:00 0.50 0 0 MIRU WHDBO RURD P Rig Down test equipment. Blow down lines. 15:00 15:30 0.50 0 0 MIRU WHDBO RURD P Pull Test Dart and BPV. Lay down same. Page 2 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode -T Comment 15:30 16:30 1.00 7,070 7,040 COMPZ RPCOM PULL P Make-up Landing Joint. BOLDS. Seal Assembly pulled free at 90K. Pull tubing Hanger to the floor at 75K. Lay down Tubing Hanger and landing joint. 16:30 17:00 0.50 7,040 7,040 COMPZ RPCOM RURD P Rig up lines to reverse circulate the Well. 17:00 17:45 0.75 7,040 7,040 COMPZ RPCOM CIRC P Reverse Circulate the Well clean at 2bpm,200 psi. pumped 87 bbls. 17:45 18:15 0.50 7,040 7,040 COMPZ RPCOM OWFF P Monitor well. Static. 18:15 18:45 0.50 7,040 7,040 COMPZ RPCOM RURD P Rig Up GBR 18:45 19:00 0.25 7,040 7,040 COMPZ RPCOM SFTY P PJSM,Tripping completion out of hole. 19:00 21:30 2.50 7,040 5,214 COMPZ RPCOM TRIP P Trip tubing standing it back in derrick while spooling control line.62 SS bands recovered. 21:30 22:00 0.50 5,214 5,214 COMPZ RPCOM RURD P Rig Down SLB spooling unit and remove from rig floor. 22:00 00:00 2.00 5,214 3,000 COMPZ RPCOM TRIP P Continue to trip tubing standing it back in derrick. 34/21/2015 Stand Back 3.5"completion. PU BHA#1 (PBR spear)and SIH on Drill Pipe. Fish PBR/Packer. Shut in and circulate out gas. TOOH with BHA#1 and fish. 00:00 03:30 3.50 3,000 0 COMPZ RPCOM TRIP P Continue to trip tubing standing it back in derrick, Removed 3 joints with damaged box/pin. Laid down 1 GLM and the seal assembly. 03:30 04:30 1.00 0 0 COMPZ RPCOM RURD P Rig Down GBR equipment. Set 6 3/8"wear ring. Clean and clear rig floor. 04:30 05:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig. Top Drive Inspection. Grease Crown. 05:00 07:15 2.25 0 316 COMPZ RPCOM BHAH P Pick Up BHA#1. Overall length: 315.80 07:15 07:30 0.25 316 316 COMPZ RPCOM SFTY P Well Control Drill.Well Shut In=41 sec.All crew in position=89 sec 07:30 08:30 1.00 316 1,261 COMPZ RPCOM PULD P Single in hole with BHA#1 with Drill Pipe from the pipe shed. Up Wt= 53k, Dn Wt=51k. 08:30 09:00 0.50 1,261 316 COMPZ RPCOM TRIP P Trip out of hole standing back 10 stands of Drill Pipe in derrick. 09:00 14:30 5.50 316 6,560 COMPZ RPCOM PULD P Single in hole with BHA#1 with Drill Pipe from the pipe shed. Up Wt= 140k, Dn Wt= 100k. 14:30 15:00 0.50 6,560 7,065 COMPZ RPCOM TRIP P Trip in hole. Up Wt= 155k, Dn Wt= 105. SPRs Taken: Pump#1:2 bpm=260 psi; 3 bpm= 520 psi Pump#2: 2 bpm=260 psi; 3 bpm= 500 psi 15:00 15:15 0.25 7,065 7,065 COMPZ RPCOM FISH P Engage spear in PBR with 15k Down Wt. Page 3 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 15:30 0.25 7,065 7,170 COMPZ RPCOM JAR P Straight pull to 70k. Cock jars and hit once at 50k and fish free.Work string to ensure free per BH Rep. Up Wt= 156k, Dn Wt= 105k. No flow observed. 15:30 17:00 1.50 7,170 7,170 COMPZ RPCOM CIRC P Circulate well clean staging pumps from 3bpm,4 bpm and 5 bpm.At 5 bpm observed increase in flow rate. shut down pumps and continued to observe increase in flow rate. Shut in well with Upper VBRs. 17:00 17:30 0.50 7,170 7,170 COMPZ RPCOM OWFF P Observe Initial SICP stabilize at200 psi. Initial SIDP at 90 psi. Stabilized SICP=200 psi,stabilized SIDP=20 psi. 17:30 19:00 1.50 7,170 7,170 COMPZ RPCOM CIRC P Circulate through gas buster per pump down schedule, initial Pressure 300 psi,final pressure 260 psi @ 2 bpm. Once gas cleared circulate well @ 3 bpm @ 570 psi. 19:00 19:45 0.75 7,170 7,170 COMPZ RPCOM OWFF P Monitor well. 0 psi tubing and IA. Open rams and fill hole to monitor. Tubing dead IA constant slight flow. 19:45 21:15 1.50 7,170 7,170 COMPZ RPCOM CIRC P Circulate hole clean. Nothing at bottoms up. 5 bpm 21:15 21:45 0.50 7,170 7,170 COMPZ RPCOM OWFF P Monitor well. Static. 21:45 00:00 2.25 7,170 3,107 COMPZ RPCOM TRIP P Trip out of hole with BHA#1 and fish. 04/22/2015 TOOH and LD BHA#1 and fish.Test BOPE components. PU BHA#2(casing scraper)and RIH. TOOH with BHA#2 and Lay Down. Pick Up test Packer and RIH. 00:00 01:15 1.25 3,107 516 COMPZ RPCOM TRIP P Continue to Trip out of hole with BHA #1 and fish. 01:15 01:30 0.25 516 516 COMPZ RPCOM OWFF P Monitor well at collars. Static. 01:30 02:45 1.25 516 200 COMPZ RPCOM BHAH P Lay Down BHA#1 02:45 03:00 0.25 200 200 COMPZ RPCOM RURD P Rig Up GBR power tongs. 03:00 04:30 1.50 200 0 COMPZ RPCOM PULL P Lay down fish consisting of PBR/Packer. 1 joint, 1 nipple with pups, 3 joints and seal assembly with a pup. Retrieved 2 large pieces of rubber from the top of the PBR that was wedged between PBR and spear. 04:30 05:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. SIMOPS: Drain stack. 05:00 05:45 0.75 0 0 COMPZ RPCOM BOPE P Pull wear ring and set test plug. Rig Up testing equipment. 05:45 06:30 0.75 0 0 COMPZ RPCOM BOPE P Test Upper VBR(with 3.5"joint) 06:30 08:00 1.50 0 0 COMPZ RPCOM BOPE P Blow Down and Rig Down test equipment. Pull test plug. Set wear ring: 6 3/8"ID. 08:00 09:00 1.00 0 321 COMPZ RPCOM BHAH P Pick Up BHA#2(7"casing scraper). Total Length: 321.22' Page 4 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:30 3.50 321 7,260 COMPZ RPCOM TRIP P Trip in hole with BHA#2.Tag up on PBR at 7259'dpmd. Up Wt= 154k, Dn Wt= 106k. SPRs taken. Pump#1: 2 bpm =200 psi, 3bpm= 360 psi Pump#2: 2 bpm =200 psi; 3 bpm= 350 psi 12:30 12:45 0.25 7,260 7,260 COMPZ RPCOM RURD P Rig Up to reverse circulate. 12:45 13:15 0.50 7,260 7,260 COMPZ RPCOM CIRC P Reverse Circulate Bottoms Up. ICP 2bpm=280 psi. FCP 3 bpm=560 psi. Dirty returns at Bottoms Up. 13:15 13:30 0.25 7,260 7,260 COMPZ RPCOM OWFF P Monitor well. Static. 13:30 14:00 0.50 7,260 7,260 COMPZ RPCOM RURD P Rig Down Circulating equipment. 14:00 17:30 3.50 7,260 321 COMPZ RPCOM TRIP P Trip out of hole with BHA#2. 17:30 18:00 0.50 321 321 COMPZ RPCOM SVRG P Service Rig. Top Drive Inspection. 18:00 19:00 1.00 321 0 COMPZ RPCOM BHAH P Lay Down BHA#2. 19:00 19:30 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. 19:30 19:45 0.25 0 21 COMPZ RPCOM BHAH P Pick Up test packer with mule shoe beneath. Total Length 21.37' 19:45 21:00 1.25 21 1,000 COMPZ RPCOM TRIP P Trip in hole with test packer.to 1000'. 21:00 21:30 0.50 1,000 1,000 COMPZ RPCOM PRTS P Test IA to test packer. good test. charted. 21:30 00:00 2.50 1,000 6,200 COMPZ RPCOM TRIP P Trip in hole with test packer. 34/23/2015 Test with Test packer. Slip and Cut Drilling Line. POOH laying Down Drill Pipe. Run 3.5"Stacker Packer Completion. 00:00 00:45 0.75 6,200 7,210 COMPZ RPCOM TRIP P Continue trip in hole with test packer. 00:45 01:15 0.50 7,210 7,261 COMPZ RPCOM PULD P Pick up two joints of Drill Pipe out of the shed. Locate muleshoe in PBR @ 7259'dpmd, confirm location as pump pressure increased when loacted. and pull up 1'. Up Wt= 140k, Dn Wt= 108k. 01:15 02:30 1.25 7,261 7,261 COMPZ RPCOM PRTS P Set Test Packer per BH Rep. Pressure Test down Drill Pipe to 3000 psi for 10 min.Test IA/casing to 3000 psi for 10 min. Both tested. Charted. Consult CPAI Engineer, decision to test both again with element at 7050'and if both test then come out laying down drill pipe. 02:30 03:00 0.50 7,261 7,055 COMPZ RPCOM TRIP P Trip out of hole to set element at 7050'. 03:00 04:15 1.25 7,055 7,055 COMPZ RPCOM PRTS P Set Test Packer per BH Rep. Pressure Test down Drill Pipe to 3000 psi for 10 min.Test IA/casing to 3000 psi for 10 min. Both tested. Charted. 04:15 06:00 1.75 7,055 7,055 COMPZ RPCOM SLPC P Slip and Cut 68'of Drilling line. Page 5 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:15 0.25 7,055 7,055 COMPZ RPCOM CIRC P Take SPRs Pump#1: 2 bpm =210 psi; 3 bpm= 350 psi Pump#2: 2 bpm =200 psi; 3 bpm= 360 psi 06:15 12:30 6.25 7,055 21 COMPZ RPCOM PULD P POOH Laying down Drill Pipe. 12:30 13:00 0.50 21 0 COMPZ-RPCOM BHAH P Lay Down Test packer and muleshoe. 13:00 13:30 0.50 0 384 COMPZ RPCOM TRIP P Trip in hole with 1 stand of Drill Pipe and 3 stands of Drill collars. 13:30 14:00 0.50 384 0 COMPZ RPCOM PULD P Lay Down 3 joints of Drill Pipe and 9 joints of Drill Collars. 14:00 14:30 0.50 0 0 COMPZ RPCOM RURD P Suck out stack and remove wear bushing. 14:30 15:00 0.50 0 0 COMPZ RPCOM SVRG P Service Rig. Service Top Drive and do Daily Top Drive inspection. 15:00 16:00 1.00 0 0 COMPZ RPCOM RURD P Rig Up Power Tongs and 3.5" completion running equipment. 16:00 18:30 2.50 0 0 COMPZ RPCOM OTHR P Load completion jewelry in pipe shed. Line up single joints in pipe shed. Check completion jewelry and tally. Install RHC sleeve in 2.812"X" profile nipple. 18:30 19:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM for running 3.5"completion. Discuss safety and hazard recognition issues. Discuss procedure to make up and run completion. 19:00 00:00 5.00 0 3,752 COMPZ RPCOM PUTB P Make up 3.5"completion per detail, with Baker FHL Retrievable packer assembly. . 04/24/2015 Run 3.5"Stacker Packer Completion. String would not pressure up when seal engaged PBR. Mobilize slickline. Drop Ball and Rod and confirm SOV not sheared. Slickline Rig Up. RIH Pull Ball and Rod and POOH. RIH Pull RHC sleeve and POOH. RIH, confirm seal assembly located in PBR, detect leak location @ 7274', POOH. RIH to set RHC Plug. 00:00 01:15 1.25 3,752 5,068 COMPZ RPCOM PUTB P Continue run 3.5"completion per detail. 01:15 02:30 1.25 5,068 5,068 COMPZ RPCOM SSSV P Rig Up SLB Control Line Spool and unit on rig floor. Make up lines to SSSV and test same to 6000 PSI. 02:30 07:30 5.00 5,068 7,245 COMPZ RPCOM PUTB P Continue run 3.5"completion per detail with control line.Attach stainless steel control bands to each joint at the collar. Monitor presure on control line. 07:30 08:15 0.75 7,245 7,245 COMPZ RPCOM PUTB P Make up floorvalve and head pin with circulating hose on joint#228. Make up to string. Page 6 of 10 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 10:00 1.75 7,245 7,274 COMPZ RPCOM PUTB T UP WT-88K, SO WT 73K. Pumps at 1 BPM 60 PSI. Slowly slack off attempting to observe a pressure increase with seals entering the lower PBR.We did not see a pressure increase and bottomed out at 25'down on joint. Retry to verify depth. Results the same. Rotate 1/2 of a RH turn in string to reposition the mule shoe.Attempt to enter PBR and observe pressure increase.No pressure increase but good flow on IA. Same results. Suspect SOV issues??. Check and verify tallies correct-good.Tally verification confirmed we believe we are located out on top of the PBR with seals engaged. Repeat attempts while discussing options with Engineer. Decision to call out Digital Slickline. Position the string to allow the locator to be located for CCL locating run. Keep hole fill pump on and observe no losses. Maintain 6000 PSI on Control line to hold open. 10:00 11:00 1.00 7,274 7,274 COMPZ RPCOM WAIT T Called out Digital Slickline Unit.Wait on DSL Unit and crew. 11:00 11:30 0.50 7,274 7,274 COMPZ RPCOM RURD T Rig down circulating hose and pup on top of the string for DSL rig up. Observed no fluid losses. 11:30 12:00 0.50 7,274 7,274 COMPZ RPCOM SFTY T Held PJSM with rig crew and DSL crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up DSL lubricator and, BOP"s, and pump in sub on the 3 1/2"Completion string. 12:00 15:30 3.50 7,274 7,274 COMPZ RPCOM SLKL T Spot DSL unit. Pull tools and BOP's to rig floor. Make up Otis connection crossover and slickline tools. Suggestion to drop ball& Rod and test the SOV initially. Drop Ball& rod and allow to seat. Continue make up lubricator assembly. Test Lubricator assembly to 500 PSI- above floor valve. 15:30 16:45 1.25 7,274 7,274 COMPZ RPCOM SLKL T Line up and pressure down tubing slowly to observe pressure increase to 225 PSI without hesiation, indicating testing against ball&rod, and the SOV is intact. Bleed pressure and WLIH to retrieve the Ball&Rod.Wireline Retrieved Ball and Rod. 16:45 18:00 1.25 7,274 7,274 COMPZ RPCOM SLKL T Wireline Run to retrieve RHC plug. RHC plug retrieved from nipple @ 7146'. Page 7 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 7,274 7,274 COMPZ RPCOM SLKL T Wireline cut—80'of line off the line and rehead due to insulation being scraped off. 20:00 22:45 2.75 7,274 7,272 COMPZ RPCOM SLKL T Wireline RIH with leak detection and CCL. Pumped @ 1 bpm, 280-360 psi. CCL confirms seal assembly located in PBR. Leak detectors identify leak at end of seal assembly which is at base of PBR @ 7274'. Slickline confirmed leak location by setting 3 stations and straddled leak with 1 flow meter above and 1 flow meter below. POOH with leak detection and CCL tool. CPAI Engineer contacted.decision to set packer as planned due to leak being at—7474'well below the new packer and Nipple Assembly. 22:45 00:00 1.25 7,274 7,274 COMPZ RPCOM SLKL T Wireline RIH with RHC body to set in Nipple @ 7146'. 04/25/2015 Set RHC Plug with Slickline, POOH. Rig Down Slickline. Pump CI Seawater. Set Packer.Test IA/Packer. Shear seal assembly. Space out and hang off completion.Test tubing and IA. Set BPV. Inspect BOPE per CPAI program. 00:00 02:00 2.00 7,274 7,274 COMPZ RPCOM SLKL T Wireline Crew Change.Wireline Safety meeting. POOH after RHC plug is set.and Rig Down Wireline. 02:00 02:30 0.50 7,274 7,274 COMPZ RPCOM RURD P Rig Up circulating equipment. SIMOPS: Rig Down Slickline. 02:30 02:45 0.25 7,274 7,273 COMPZ RPCOM PUTB P Locate string 1'off of fully located. SIMOPS: Rig Down Slickline. 02:45 04:15 1.50 7,273 7,273 COMPZ RPCOM CRIH P Pump 250 bbls of Corrosion Inhibited Seawater @ 3.5 bpm 340 psi. 04:15 05:15 1.00 7,273 7,273 COMPZ RPCOM PACK P Set Packer by dropping Ball and Rod, allow time to fall. Pressure up to 3000 psi. Observe Packer set at —1800 psi. 05:15 05:45 0.50 7,273 7,046 COMPZ RPCOM PRTS P Hold 2500 psi on tubing and test IA/Packer to 3000 psi. Shear seal from PBR once test completed. 05:45 07:30 1.75 7,046 7,046 COMPZ RPCOM HOSO P Lay down3 joints and pickup space out joints: 8.19', 10.21'. Space out is 7.61'. Make up with full joint on top. 07:30 08:30 1.00 7,046 0 COMPZ RPCOM THGR P Pick Up tubing hanger and make up with landing joint to completion string.Terminate control line and make up to hanger. Land Hanger and RILDS. 71 SS control line bands run. 08:30 10:00 1.50 0 0 COMPZ RPCOM PRTS P Pressure test completion tubing to 3500 psi for 15 min with IA open. Bleed tubing to 2500 psi and pressure test IA to 3000 psi for 30 min. Bleed off IA and tubing pressure. Ramp up IA and observe SOV shear at 2300 psi. Pumped 2 bbl each way to confirm flow path.All Charted. Page 8 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:30 0.50 0 0 COMPZ WHDBO MPSP P Set BPV and test from below to 1000 psi. 10:30 11:00 0.50 0 0 COMPZ WHDBO OTHR P Rig Down Power Tongs and completion running equipment. Bleed off control line and terminate.Clean and Clear rig floor. 11:00 12:00 1.00 0 0 COMPZ WHDBO SFTY P PJSM with all hands for CPAI BGetween Wlls Maintenance& Inspection program and upcoming BOP inspection. 12:00 14:00 2.00 0 0 COMPZ WHDBO OTHR P Clean Rotary Table and under Drawworks with Super Sucker. 14:00 14:30 0.50 0 0 COMPZ WHDBO WWWH P Jet stack while functioning top rams to clean prior to BOP Inspection. 14:30 16:30 2.00 0 0 COMPZ WHDBO NUND P Nipple Down Riser and blow down all lines. 16:30 18:00 1.50 0 0 COMPZ WHDBO OTHR P CPAI BOP inspection. Break bolts on upper and lower Ram doors on BOP stack. 18:00 22:30 4.50 0 0 COMPZ WHDBO OTHR P CPAI BOPE Inspection. Inspect Upper and Lower Rams and BOP Ram Cavities. Photos taken of all components and of stack cavities. SIMOPS Clear rig floor and prepare for rig move. Empty and clean pits. 22:30 00:00 1.50 0 0 COMPZ WHDBO OTHR P CPAI BOPE Inspection. Break bolts for blinds rams on BOP stack. Photos taken of all components and of stack cavities. SIMOPS:Weld piping in pits to repair lines. Continue to prepare rig for move. 04/26/2015 Inspect BOPE per CPAI program. Nipple Down BOPE. Nipple Up tree. Test tree to 250/5000 PSI. Pump 75 BBLS of Freeze protect diesel, and allow to U-tube until dead. Intall BPV. Secure tree and cellar. Blow down and rig down lines. RELEASE RIG @ 12:00 PM. 00:00 02:00 2.00 0 0 COMPZ WHDBO OTHR P Continue CPAI BOPE Inspection. Inspect Blind Rams and blind ram cavities. Photos taken of all components and of stack cavities. Close up blind rams and tighten bolts. 11.5 hours of time dedicated to CPAI BOPE inspection. (1 hr safety meeting, 30 minutes to clean stack and 9.5 hours of work to inspect) 02:00 03:30 1.50 0 0 COMPZ WHDBO NUND P Nipple Down BOPE and set back on stump in cellar. 03:30 06:00 2.50 0 0 COMPZ WHDBO NUND P Nipple Up adapter flange and test packoff to 250/5000 PSI. . SIMOPS: Spot LRS for Freeze Protect. Crew Change 06:00 07:00 1.00 0 0 COMPZ WHDBO NUND P Nipple up tree and torque bolts. 07:00 08:00 1.00 0 0 COMPZ WHDBO PRTS P Fill tree with diesel, and test tree and connections to 250/5000 PSI, on chart, Good test. RD and blow down test lines. Page 9 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 0 0 COMPZ WHDBO MPSP P Pull tree test dart and BPV as per Cameron rep. 08:30 09:00 0.50 0 0 COMPZ WHDBO SFTY P Held PJSM with LRS rep, and rig up to freeze protect well. PT lines to 2500 PSI. 09:00 10:30 1.50 0 0 COMPZ WHDBO FRZP P Pump 75 BBLS of freeze protect diesel at 2 BPM. ICP-650 PSI. and FCP-900 PSI.Allow to u-tube until dead. IA and TBG on Vac. 10:30 11:00 0.50 0 0 COMPZ WHDBO MPSP P Install BPV, as per Cameron rep. 11:00 12:00 1.00 0 0 DEMOB MOVE RURD P Blow down and rig down all lines., Remove secondary annulus valve. Secure tree and cellar. Rig released at 12:00 Noon. Page 10 of 10 KUP INJ 1B-02 COnocoPhillipS Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD 01613) Act Blot(966) ,,,a ,4,atR 500292053100 KUPARUK RIVER UNIT INJ 43.00 2,500.00 8,153.0 """ Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 18.02.5/14/201510:09:51 AM SSSV:TRDP Last WO: 4/18/2015 28.48 1/11/1981 Vertical schematic(astral) Annotation Depth(RKB) End Date Annotation Last Mod By End Date HANGER;22.6 Last Tag:SLM 7,287.0 4/2/2015 Rev Reason:WORKOVER,PULL PLUG,GLV smsmith 5/13/2015 CO Casing Strings Casing Description OD(in) ID(in) Top(ftK8) Set Depth(RKB) Set Depth(TVD)... WI/Len(I...Grade 'Top Thread CONDUCTOR 16 15.062 28.5 110.0 110.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I_ SURFACE 103/4 9.950 28.8 2,933.9 2,646.3 45.50 K-55 BTC �IIII v Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 24.7 8,113.5 6,760.8 26.00 K-55 LCONDUCTOR;28.5-110.0--r. Tubing Strings } Tubing Description String Ma...ID(in) Top(flKB) Set Depth(ft..'Set Depth(TVD)(...Wt(IbHI) Grade Top Connection TUBING-2015-WO 31/2 2.992 22.6 7,272.8 6,106.5 9.30 L-80 EUE8rd 5508:2,1ee.4 Completion Details I Nominal ID Top(RKB) Top(ND)(MB) Top Incl(°) Item Des Com (in) 22.6 22.6 0.00 HANGER CAMERON TUBING HANGER 2.992 2,188.4 2,093.3 40.53 SSSV CAMCO TRMAXX-5E SSSV,2.812"X PROFILE 2.812 SURFACE;28.8-2,933.9- 7,031.2 5,914.6 36.31 LOCATOR LOCATOR SUB 2.990 7,032.2 5,915.4 36.32 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 r 7,039.5 5,921.3 36.39 PBR BAKER 80-40 PBR 4.000 GAS LIFT;6,975.4F 7,062.4" 5,939.7 36.62 PACKER BAKER FHL RETRIEVABLE PACKER 2.910 7,146.5 6,006.9 37.23 NIPPLE OTIS X NIPPLE 2.812 • 7,257.5 6,094.6 38.94 LOCATOR LOCATOR SUB 2.950 LOCATOR;7,031.2 SEAL ASSY;7,0322 7,258.3 6,095.3 38.96 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY GBH-22 2.990 • PBR;7,039.5 Tubing Description String Ma...ID(in) Top(flKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection PACKER;7,082.4 M TUBING WO 1989 31/2 2.992 7,259.3 7,812.9 6,522.7 9.30 J-55 EUE 8RD Completion Details -- Nominal ID Top(ftK8) Top(ND)(RKB) Top Incl(") Item Des Com (in) - lib NIPPLE;7,146.5 - 7,259.3 6,096.0 38.98 PBR BAKER OIL TOOLS PBR 3.000 7,276.5 6,109.3 39.41 PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 7,496.3 6,277.8 40.00 BLAST RING CARBIDE BLAST RING(1) 2.992 LOCATOR;7,257.5 7,561.8 6,327.9 40.00 BLAST JOINT BLAST JOINT(1) 2.992 SEAL ASSY;7,258.3, PBR;7.259. 7,594.8 6,353.2 40.00 PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 7,602.1 6,358.9 39.98 BLAST RINGS CARBIDE BLAST RINGS(2) 2.992 PACKER;7,276.5- SAND;7,287.0 7,662.5 6,405.3 39.38 BLAST JOINT BLAST JOINT(1) 2.992 INJECTION;7,313.9 7,786.6 6,502.0 38.35 LOCATOR BOT LOCATOR W XO 3.000 7,787.9 6,503.0 38.34 PACKER BAKER WIRELINE SET PERMANENT PACKER 3.000 INJECTION;7,386.4 7,805.0 6,516.4 3821 NIPPLE CAMCO'D'NO GO NIPPLE 2.750 7,812.0' 6,521.9 38.16 SOS BAKER SHEAR OUT 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) INJECTION;7,457.8 • • Top(ND) Top Incl L7� Top(flKB) (RKB) (^) Des Com Run Date ID(in) IPERF;7,46e.0-7,524.0- i qI 7,287.0 6,117.4 39.68 SAND DUMP BAIL 20/40 SAND 3/28/2015 0.000 7,605.0" 6,361.1 39.95 PATCH 2.72"TTS retrievable packer mid-element @ 7607', 4/26/2009 1.625 N-80 blank pipe w/seals anchor latch r IPERF;7,529.0-7,538.0- : 7,617.0 6,370.3 39.83 PATCH Merla 21'Tbg Patch;Set on 12/1/94 12/1/1994 2.375 7,625.0 6,376.4 39.75 PATCH TTS 2.5"Size 287 Paragon 2 retrievable dual seal 4/25/2009 1.100 IPERF;7,544.0-7,553.0- bore packer 7,692.0 6,428.2 39.08 PATCH 21.5'Meda Tbg Patch 11/20/1994 2.375 7,703.0 6,436.7 38.98 NIPPLE AVA TPL NIPPLE inside Patch 11/20/1994 2.260 IPERF;7,558.0-7,587.0--p 7,805.0 6,516.4 38.21 NIP RDCR AVA NIPPLE REDUCER 2.75"X 1.81" 11/17/1994 1.810 IPERF;7,572.0-7,579.0- a Perforations&Slots Shot PACKER;7,894.8 -• Dens Top(ND) Blot(TVD) (shots/f ' Top(RKB) Btm(RKB) (RKB) MB) Zone Date t) Type Com PATCH;7,605.0- I ( 7,468.0 7,524.0 6,256.1 6,299.0 C-4,C-3,1B- 5/4/1981 12.0 IPERF 5"Geo Vann Gun- IPERF;7,597.0-7,848.0 L 02 CLOSED PATCH;7,617.0 PATCH;7,825.0 ( 7,529.0 7,538.0 6,302.8 6,309.7 C-3,1B-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- O CLOSED 7,544.0 7,553.0 6,314.3' 6,321.2 C-2,1B-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- CLOSED IPERF;7,652.0-7,669.0 7,558.0 7,567.0 6,325.1 6,331.9 C-2,16-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- CLOSED 7,572.0 7,579.0 6,335.8 6,341.1 C-2,113-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- INJECTION;7,8911.4 CLOSED PATCH:7.692.0 NIPPLE;7,703.0 7,597.0 7,646.0 6,354.9 6,392.6 C-1,UNIT B, 5/4/1981 12.0 IPERF 5"Geo Vann Gun- I 16-02 CLOSED 7,652.0 7,669.0 6,397.2 6,410.4 UNIT B,19- 5/4/1981 12.0 IPERF 5"Geo Vann Gun 02 INJECTION;7,767.3 7,863.0 7,900.0 6,562.2 6,591.5 A-5,A-4,19- 5/4/1981 " 12.0 IPERF 5"Geo Vann Gun 02 LOCATOR;7,786.6 PACKER;7,787.9 _ 7,866.0 7,896.0 6,564.5 6,588.3 A-5,A-4,1 B- 4/5/2005 6.0 APERF 1 11/16"Power EJ NIPPLE;7,805.0 02 NIP RDCR;7,605.0, '�! Cement Squeezes ITop(ND) Blm(TVD) Top(ftKB) Btm(flKB) (ftK8) (flKB) Des Start Date Com SOS;7,812.0 y 7,468.0 7,646.0 6,256.1 6,392.6 Cement Squeeze 5/13/2006 PUMPED 22.7 BELS CEMENT APERF;7,866.8-7,896.0, IPERF;7.863.0.7,900.0 PRODUCTION;24.7-8,113.5- KUP INJ 1B-02 ConocoPhillips t Alaska,Inc. r_ e.iviw4.tps 10,02 5/1412015 10'.09'.53 AM Vertical schematic(actual) HANGER 226 ;,/'. IN i.. .., Mandrel Inserts all on Top(TVD) Valve Latch Port Size TRO Run `., III N Top(8K6) (8KB)11 Make Model OD(in) Sem Type Type (in) (psi) Run Date Com 1 6,975.4 5,869.4 CAMCO MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 5/1/2015 2 7,313.9 6,138.1 OTIS LBX 1 1/2 NJ DMY RM 0.000 0.0 12/18/2008 s CONDUCTOR,28.5-110.0 ` 3 7,386.4 6,193.6 OTIS LBX 11/2 NJ HFCV RM 0.000 0.0 7/13/2011 4 7,457.6 6,248.1 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 3/2/2009 SSSV;2,188.4 ir? 5 7,696.4 6,431.6 OTIS LBX 11/2 INJ Patch 0.000 0.0 11/23/1994 6 7,767.3 6486.9 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 10/7/1994 Notes:General&Safety 9 End Date Annotation SURFACE;28.8-2,833. 2/1/1989 NOTE WORKOVER 2/1/1989 NOTE:COMPLETION BELOW PBR @ 7261'RUN 6/7/1985 WORKOVER 2/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT;6,975.4 5/14/2015 NOTE:Leaking PBR/Seal Assembly at 7,258'RKB remains after 2015 Rig Workover LOCATOR;7,031.2 SEAL ASSY;7,032.2 PER;7,062.4 r� PACKER;7,062.4 NIPPLE;7,146.5 LOCATOR;7,257.5 SEAL ASSY;7,258.3- PER;7,259.3 PACKER;7,278.511 SAND;7,287.0 ..... INJECTION;7,313.9 INJECTION;7,388.4 INJECTION;7,457.8 IPERF;7,468.0-7,524.0— ill 1 IPERF;7,529.0-7,538.0— {I 3 ' IPERF;7,544.0-7,553.0— Y II IPERF;7,558.0-7,567.0 a. IPERF;7,572.0-7,5]8.0— tge PACKER;7,594.8 - (I ■. PATCH;7,605.0- J I. IPERF;7,597.0-7,646.0 _j PATCH;7,617.0. ;,I PATCH;7,825.0 I, IPERF;7,652.0-7,6690—_ INJECTOR;7,696.4 5. PATCH;7,892.0 NIPPLE;7,703.0 t s INJECTION;7,787.3 LOCATOR;7,788.8 PACKER;7,787.9 _' NIPPLE;7,806.0 II NIP RDCR;7,805.0, �'I'/' II i SOS;7,812.0 f APERF;7,866.0.7,898.0, IPERF;7,863.0-7,900.0 PRODUCTION;24.7.8,113.5 Kea l 13-Oz Fit t Ol330 Regg, James B (DOA) From: Edward Oglesby <noreply@formresponse.com> I � Q-(�i� Sent: Tuesday, April 21, 2015 9:08 PM 1 To: DOA AOGCC Prudhoe Bay Subject: AOGCC Test Witness Notification Request: BOPEOther, Nabors 7ES, 1B-02, Kuparuk f Cobh( @mss /Jott=orm Question Answer Type of Test Requested: BOPE Other eaNNEfi MAY 0 42.015 Requested Time for 04-22-2015 3:00 AM Inspection Location Nabors 7ES, 1B-02, Kuparuk Name Edward Oglesby E-mail n2364@conocophillips.com Phone Number (907) 659-7247 Company ConocoPhillips Alaska Gentlemen, While fishing operations with a Spear, and after releasing the upper Packer the well was shut in due to increased flow coming from beneath the packer on the IA. The flow began to increase and pumps were shut down. The IBOP and the Upper VBRs were shut-in. Initial shut in pressure on the DP— 90 PSI , on the IA—200 PSI. We circulated out the gas using the hydraulic choke. We intend to retest the Rams and IBOP and hydraulic Other Information: choke once we get out of the hole early tomorrow morning. ✓ Please let us know if you have any questions or plan to witness this test after use. The well was killed with no issues and we will ensure the well is static prior to coming out of the hole. Nabors 7ES Scott Heim/Edward Oglesby 659-7844 659-7247 Rig Floor Submission ID: 305488506661960349 1 • V OF T�� �w\1//7,�s,, THE STATE Alaska Oil and Gas ofALASKA Conservation Commission x 333 West Seventh Avenue • GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 WN-7-77 Main: 907.279.1433 OF ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov SCANNED = Jonathan Coberly Sr. Wells Engineer ConocoPhillips Alaska, Inc. �lJ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1B-02 Sundry Number: 315-138 Dear Mr. Coberly: 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, Cathy P. oerster Chair DATED this I9 day of March, 2015 Encl. STATE OF ALASKA A. AKA OIL AND GAS CONSERVATION COMM. ,ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r7► Time Extension r Operational Shutdown r Re-enter Susp.Well r StimulateAlter casing g r Other: f 2 Operator Name 4 Current Well Class. 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 180-133 3 Address Stratigraphic r Service 6 API Number P.O.Box 100360,Anchorage,Alaska 99510 50-029-20531-00 - 7.If perforating, What 8 Well Name and Number: Regulation or Conservation Order governs well spacing in this pool' Will planned perforations require spacing exception? Yes r No 17 KRU 1 B-02 . 9 Property Designation(Lease Number) 10.Field/Pool(s) ADL 25648 . Kuparuk River Field/Kuparuk River Oil Pool • 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft). Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured) 8153 • 6792 . 8027'• 6692' • 7146' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 2905 10.75 2934' 2646' RECEIVED PRODUCTION 8089 7 8114' 6761' MAR 12 20.15 AOGCC Perforation Depth MD(ft) Perforation Depth TVD(ft). Tubing Size Tubing Grade Tubing MD(ft). 7652-7669,7863-7900 • 6397-6410,6562-6592 3.5 L-80 7259 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL RETRIEVABLE PACKER MD=7092 TVD=5964 • PACKER-BAKER HB-1 RETRIEVABLE PACKER MD=7277 TVD=6109 ' PACKER-BAKER HB-1 RETRIEVABLE PACKER MD=7595 TVD=6353 PACKER-BAKER WIRELINE SET PERMANENT PACKER MD=7788 TVD=6503 SSSV-CAMCO TRMAXX-CMT-SR-5 SAFETY VALVE MD=1893 TVD=1853 • 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work' Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Servicel✓ • 14 Estimated Date for Commencing Operations 15 Well Status after proposed work. 4/19/2015 Oil r Gas r WDSPL r Suspended r 16 Verbal Approval Date VVINJ r GINJ r WAG R7 • Abandoned r Commission Representative GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Jonathan Coberly @ 265-1013 Email: Jonathan Coberly(aiconocophillips corn Printed Name Jo athan Coberly Title Sr.Wells Engineer Signature 60. Phone 265-1013 Date 3-y-Zeis Commission Use Only Sundry Number. c� Conditions of approval Notify Commission so that a representative may witness 3 IS-!3 a Plug Integrity r BOP Test V Mechanical Integrity Test r Location Clearance r Other.BOP "tcsf h 30 v c ,25; (rvi P 5 P is 2.0 l l /2 5; ) /41-1--7 r-1 til a/—,P rc v cv,h-r -7,--r-5 D` to Z 5-z,0 , i-c/ J / n t••j, f/.%). -1 . fl-a f-c Pr i 7`v1 -/tet t 5 f ccs NL l Trel v/1--c-cd" a f;"e-'" f a- b/ /.3 Spacing Exception Required? Yes ❑ No [ Subsequent Form Required 10 —401- r M O o'' 4 tea/ vc<- /'S go-an7cc/ to allow p4ciccr ¢o a /oG / crd a-•f S9U b dCC,/Jcr' l';) 11,2E etv�fva `- /iv7c0-- o/vfs"y , n,- ... n-7o,rv'Mp i n tz 5f ItCireCi a-67° tion (,2oAs1C25. 4/2C6)) • 31�r-�S APPROVED BY Approved by � COMMISSIONER THE COMMISSION Date. V7-C v/! /5 Appr I aI' f r 12 months from the date of approval. m4/� 1 I I� L3//1//s-- m� -�� Form 10-403(Revised 10 2012Submit Form and Attar is in Duplicate ;� RBDM3 APR - 2 2015 ✓ RECEIVEDConocoPhillips MAR 1 Alaska 2 2015 P.O. BOX 100360 /►nG^C ANCHORAGE,ALASKA 99510-0360 AOGCC March 2,2015 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Foerster: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 1B-02(PTD: 180-133). 1B-02 was completed into the Kuparuk A&C sand in 1981 and is currently a triple selective miscible gas and water injector. It was a producer from 1981 until 1995. 1B-02 has had three previous rig workovers: pulled and replaced the selective in 1985, pulled and replaced tubing in 1989, and pulled and replaced tubing with a stacked packer and IC packoff change out in 2011. The well was shut in during December 2013 due to a failing IA—DDT. A leak in the upper packer that was confirmed via a LDL on 4/25/2014. Prior to being shut in the well was averaging 4,000 bwpd and 8MMscfd into the Kuparuk C sand. In order to bring the well back online to MI and water injection the upper(stacked)packer and completion tubing will be removed. A test packer will be run to assess the condition of the 7"production casing above the uppermost production packer. If the casing is damaged a 5 'h" liner will be installed and cemented across the damaged casing. If the upper production packer is leaking and the casing is good,a new stacked packer will be run to just above the current depth and new completion tubing will then be installed. Both the stacked packer and cemented liner options involve setting a packer or seal bore above the usual 200' zone above the upper perforations. Permission is requested to set a packer just above the depth of the currently installed stacked packer (7,092' RKB) or install a cemented liner with seal bore within 1,500' above the packer at 7,276' RKB. This is requested because the top of cement for the production casing is — to at least 5,260'RKB based on the 1/9/1981 CBLNDL. See attached schematics for completion details. If you have any questions or require any further information,please contact me at 265-1013 or Jonathan.Coberly@conocophillips.com. Sincerely, ij. I( Jonathan Coberly Senior Wells Engineer ConocoPhillips Drilling and Wells 1B-02 Rig Workover, Cemented Liner or Stacked Packer (PTD #: 180-133) Current Status: The well is currently shut in due to a failing IA-DDT in December 2013. Scope of Work: (1)Pull completion tubing, (2)run a test packer to diagnose leak path, (3)pull stacked packer,(4) run a cemented liner from the top packer to above the casing damage or stack another packer, (5) run new completion tubing General Well info: MPSP: 2,011 psig(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Combined Kuparuk A&C-Sands—2,643 psig/6,319' TVD (8.1 ppg EMW)measured 5/12/2014. Wellhead type/pressure rating: McEvoy Gen I/IV Retrofit,7 '/16"5M Top x 11"3M Bottom Nabors 7ES BOP Configuration: Annular/VBR /Blind Rams/Mud Cross/VBR(or 5 1/2") MIT results: MIT-IA—Pass(2/22/2015) MIT-T—Pass(7/27/2014) MIT-OA—Pass(2/22/2015) Well Type: Miscible Gas/Water Injector Estimated Start Date: April 19,2015 Production Engineer: David Lagerlef/David Haakinson Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly@conocophillips.com) Proposed Procedure: Pre-Rig Setup: RU slickline: Pull existing tubing plug. Run plug below the packer at 7,276' RKB. PT plug. Dump sand on top of plug. Lock Out SSSV. Pull DV from GLM#1. RWO Procedure: 1. MIRU. Pull BPV. Circulate killweight fluid to kill well.Install BPV. 2. ND Tree. Install blanking plug. NU BOPE and test to 3,000 psig. kV 3. Pull blanking plug. Pull BPV. Pull completion tubing. (If the seals did not pull free from the PBR: RU E- line and cut the tubing above the PBR and RD E-line. RIH and fish the tubing stub on drillpipe.) 4. Single in on DP and fish the PBR on the stacked packer. Release the packer and POOH. 5. If necessary based on tubing conditions: RIH on DP and scraper assembly to clean out the casing to the PBR. POOH. 6. RIH with a test packer on DP to 1,000' RKB. PT the IA to confirm integrity of the packer. Release the packer and RIH to just above the packer at 7,274' RKB. PT the packer. PT the IA. Release the test packer. If the IA fails to PT,PU and locate the leak with the test packer. POOH. If the packer is determined to be the leak path,stack a packer. If the casing is determined to be leaking above the packer at 7,274'RKB,but less than 1,500'above that packer,install the cemented liner option. If any other scenario is encountered,analyze the data and determine path forward. 7. Cemented Liner Option: MU the 5 '/2"liner equipment and RIH. Engage the PBR and space out. Set the liner hanger. POOH. PU the inner string and RIH engage the cement valve. Pump the following cement program: 10 bbls of Fresh Water or Viscosified Spacer XX bbls 15.8 Class 'G'Neat(volume dependent on liner setting depth) 10 bbls of Fresh Water or Viscosified Spacer PU to close the cement valve. Set down on the liner top to set the liner top packer. Reverse circulate to remove any excess cement. PT the liner. POOH laying down inner string and DP. RIH with completion tubing to the SBE. Space out the completion. Circulate the well over to corrosion inhibited fluid. Land the tubing hanger. RILDS. Stacked Packer Option: RIH with new stacked packer completion to the PBR. Circulate the well over to corrosion inhibited brine or seawater. Space out the seals in the PBR. Drop ball and rod and set the packer. Shear out of the PBR. Space out the completion. Land the tubing hanger. RILDS. 8. PT the tubing. PT the IA to 3,000 psig for 30 minutes on chart. Shear the SOV. 9. Pull landing joint. Install TWC. PT IA. ND BOPE. 10. NU tree. PT packoffs. Pull TWC. Freeze protect. Set BPV. 11. RDMO. Post-Rig Work: 1. Reset the well houses and flow lines. Pull BPV. 2. RU Slickline: Pull ball and rod and RHC plug(if used), Pull SOV and run DV. Cleanout sand. Pull tubing plug. 3. Turn well over to Operations ConocoPhillips 2015 RWO PROPOSED COMPLETION (Cemented Liner Option) Well: 1B-02 API: 500292053100 PTD: 180-133 AIJ Wellhead: RetroFitted McEvoy Gen I/McEvoy Gen IV Tree: 3 1/8"5M 4- SSSV at-2000'MD Conductor: 16"65.0#H-40 Welded to 110'RKB Surface Casing: 10-3/4"45.5#K-55 BTC to 2,934'RKB A 11. Production Casing: 7"26.0#K-55 BTC to 8,114'RKB Cemented Liner: 5 1/2"15.5#L-80-5,776'RKB to 7,276'RKB Production Tubing: Ili :,,,\.:' . 5ti`� 4- TOC at 5,260'RKB(est) iNN 3-1/2"9.3#L-80 EUE-Mod to 7,259'RKB 3-1/2"9.3#J-55 EUE IPC to 7,813'RKB "*� - (g 1- Baker 5-1/2"x 7"ZXPN Liner Top Packer w/HMC Liner Hanger f `+ A. (Set within 1,500'of packer at 7,276'RKB) Perforations: MD Zone \ J \ 11 4- 1"Camco KBG 2-9 GLM 7,468'-7,524' C-4,C-3(Cemented) x f I % 4- 2.812"ID'X'Nipple 7,529'-7,538' C-3(Cemented) . ' 4 ''� �o I- 20'80-40 Baker PBR w/Seal Assembly 7,544'-7,553' C-2(Cemented) ‘,*17,558'7,567' C-2(Cemented) 0 J P 4-4-1/2"Baker HMCV Cementing Valve 7,572'-7,579' C-2(Cemented) 9, ` 7,597-7,646' C-1 (Cemented) 1 �.�i '\ ♦- 15'80-40 Baker PBR w/Seal Assembly 7,652'-7,669' B „, i 7,863'-7,900' A-5,A-4 ,,� i\s, 72 Baker HB-1 Retrievable Packer(Set at 7,276'RKB) 7,866'-7,896' APERF:A-5,A-4 J '1- 1-1/2"Otis LBX Injection Mandrels �k45f Directional. ° Blast -' 1 Joint,Tungsten Carbide(FL4S)Blast Rings Max Incline: 43°(@ 2,500') ' 1:12 moo\ 4- 1 Joint,Carbon Steel Blast Joint 4.5"OD Max Dogleg: 6.8 u/tooFT(@1,500') N,, �♦ ''''s,,'''':: i- Baker HB-1 Retrievable Packer += 4- 1 Joint,Tungsten Carbide(FL4S)Blast Rings w/TTS 2.72" Blas Packer and Tbg Patch(1.625"ID)Installed Last Tagged Fill: 7,889'RKB ' Blast 4- 1 Joint,Carbon Steel Blast Joint 4.5"OD Total Depth: 8,153'RKB .,,Z,-!:7421-1 % 1-1/2"Otis LBX Injection Mandrel w/Merla Tubing Patch and TTS 2.5"(1.1"ID)Size 287 Paragon 2 Packer :-, J "N; 4- 1-1/2"Otis LBX Injection Mandrel ` 4- Baker WL Set Permanent Packer w/Seal Locator y i ., o I I' 4- CAMCO 2.75"ID'D'Nipple w/1.81"ID Nipple Reducer Updated by:J.Coberly 3/11/2015 ConocoPhillips 2015 RWO PROPOSED COMPLETION (Stacked Packer Option) Well: 1B-02 API: 500292053100 J L PTD: 180-133 Wellhead: RetroFitted McEvoy Gen I/ McEvoy Gen IV Tree: 3 1/8"5M Conductor: sssv 4- SSSVat-2000'MD 16"65.0#H-40 Welded to 110'RKB Surface Casing: 10-3/4"45.5#K-55 BTC to 2,934'RKB A 111. Production Casing: 7"26.0#K-55 BTC to 8,114'RKB Production Tubing: J2"9.3#L-80 EUE-Mod to 7,259'RKB 3-1/2"9.3#J-55 EUE IPC to 7,813'RKB w" 4-TOC at 5,260'RKB(est) Perforations: MD Zone ' 7,468'-7,524' C-4,C-3(Cemented) 7,529'-7,538' C-3(Cemented) 7,544'-7,553' C-2(Cemented) J 4- 1-1/2"Camco MMG GLM 7,558'-7,567' C-2(Cemented) ; 7,572'-7,579' C-2(Cemented) I,--'I Ak; 7,597'-7,646' C-1 (Cemented) ;' I ♦ 20'800 Baker PBR w/Seal Assembly 7,652'-7,669' B 4 ►,4 7'a50i- Baker FHL Retrievable Packer(Set Approx.7,050'RKB) 7,863'-7,900' A-5,A-4 x 5 44 4- 2.812"ID'X'Profile Nipple 7,866'-7,896' APERF:A-5,A-4 �' I1-'I a ,) D. 4- 15'800 Baker PBR w/Seal Assembly ' 4 R ,4 t f- Baker HB-1 Retrievable Packer(Set at 7,276'RKB) Directional: Max Incline: 43°(@ 2,500') J ) 1-1/2"Otis LBX Injection Mandrels Max Dogleg: 6.8°/rooFT(@1,500') ,‘,'t,‘,'t -tib 774&V* eiasc 4-- 1 Joint,Tungsten Carbide(FL4S)Blast Rings 'a.N7' I I =x\ Last Tagged Fill: 7,889'RKB '- Blast 4- 1 Joint,Carbon Steel Blast Joint 4.5"OD Total Depth: 8,153'RKB '4 � } 4--- Baker HB-1 Retrievable Packer ',_ 4- 1 Joint,Tungsten Carbide(FL4S)Blast Rings w/TTS 2.72" rL■B asi -.TV - Packer and Tbg Patch(1.625"ID)Installed Bias, ` 1 Joint,Carbon Steel Blast Joint 4.5"OD k\ 4- 1-1/2"Otis LBX Injection Mandrel w/Merla Tubing Patch and J ‘,1 TTS 2.5"(1.1"ID)Size 287 Paragon 2 Packer i 4- 1-1/2"Otis LBX Injection Mandrel 1 4- Baker WL Set Permanent Packer w/Seal Locator o ' ] + CAMCO 2.75"ID'D'Nipple w/1.81"ID Nipple Reducer J T Updated by: J.Coberly 3/11/2015 1 KUP INJ 1B-02 ConocoPhillips 4 Well Attributes Max Angle&MD TD Alaska,It1C. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • c mnnimahp, 500292053100 KUPARUK RIVER UNIT INJ 43.00 2,500.00 8,153.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Gid(ft) Rig Release Date 1B-02,7/28/2014 8.17.45 AM SSSV:TRDP Last WO: 6/27/2011 28.48 1/11/1981 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,889.0 12/31/2008 Rev Reason:SET PLUG hipshkt 7/28/2014 HANGER;22.6 t�;�1 - Casing Strings /yiuwwnunn...,.,wew.,.ww.wi.. Yom'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.5 110.0 110.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(T/D)...'WtlLen(I...Grade Top Thread SURFACE 103/4 9.950 28.8 2,933.9 2,646.3 45.50 K-55 ETC • Casing Description -OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtILen 0...Grade Top Thread PRODUCTION 7 6276 24.7 8,113.5 6,760.8 26.00 K-55 CONDUCTOR;28.5-710.0 • ' Tubing Strings MMTubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection SAFETY VLV;1.892.9- _:':j TUBING WO 2011 'String 31/21 2.9921 2261 7,259.4+ 6,096.11 9.301 L-80 1EUE Completion Details Nominal ID Top(01(13) Top(ND)(ftKB) Top Incl(3 Item Des Com (in) 226 226 0.00 HANGER FMC HANGER w/3.65'pup 2.992 SURFACE;28.8-2,933.9-. 1,892.9 1,852.6 30.22 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SAFETY VALVE w/2.813 2.812 X PROFILE 7,062.4 5,939.7 36.62 SEAL ASSY SEAL ASSEMBLY LOCATOR 3.000 7,070.4 5,946.1 36.70 PBR BAKER 80-40 PBR(40K SHEAR) 4.000 GAS LIFT;6.995.5 7,092.4 5,963.8 36.92 PACKER BAKER FHL RETRIEVABLE PACKER 2.920 7,145.6 6,006.2 37.23 NIPPLE OTIS X LANDING NIPPLE 2.812 7,2565 6,093.9 38.91 SEAL ASSY BAKER 80-40 GBH-22 LTSA SEAL ASSEMBLY w/ 3.750 SEAL ASSY;7,062.4 -2- LOCATOR W/O SEALS ( PBR;7,070.4 .` Tubing Description String Mn...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(,..Wt(Iblft) Grade Top Connection f A .�PACKER;7,0924 TUBING WO 1989 I 31/21 2.9921 7,259.3 7,812.91 6,522.71 9.301 J-55 I EUE 8RD 10 !/ - Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(°) Item Des Com (in) NIPPLE;7,145.6- 7,259.3 6,096.0 38.98 PBR 'BAKER OIL TOOLS PBR 3.000 PLUG;7,145.6 FA 7,276.5 6,109.3 39.41 PACKER 'BAKER HB-1 RETRIEVABLE PACKER 3.000 7,496.3 6,277.8 40.00 BLAST RING 'CARBIDE BLAST RING(1) 2.992 7,561.8 6,327.9 40.00 BLAST JOINT BLAST JOINT(1) 2.992 SEAL ASSY;7256s = 7,594.8 6,3532 40.00 PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 - 7,602.1 6,358.9 39.98 BLAST RINGS CARBIDE BLAST RINGS(2) 2.992 PBR;7259.3 PACKER;7,2765 • 7,662.5 6,4053 39.38 BLAST JOINT BLAST JOINT(1) 2.992 INJECTION;7313.9 7,786.6 6,5020 38.35 LOCATOR BOT LOCATOR W XO 3.000 7,787.9 6,503.0 38.34 PACKER BAKER WIRELINE SET PERMANENT PACKER 3.000 INJECTION;7,386.4 7,805.0 6,516.4 38.21 NIPPLE CAMCO'D'NO GO NIPPLE 2.750 • 7,812.0 6,521.9 38.16 SOS BAKER SHEAR OUT 2.992 INJECTION;7.457.6 ;. TE Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) (PERF;7468.0.7,524.0-- 7,145.6 6,006.2 37.23 PLUG 2.81"XX PLUG(OAL=46") 7/24/2014 0.000 7,605.0 6,361.1 39.95 PATCH 2.72"TTS retrievable packer mid-element @ 7607', 4/26/2009 1.625 N-80 blank pipe w/seals anchor latch !PERF;7.529.0-7.538.0-_- 7,617.0 6,370.3 39.83 PATCH Meda 21'Tbg Patch;Set on 12/1/94 12/1/1994 2.375 IPERF;7.5440-7.553.0-. 7,625.0 6,376.4 39.75 PATCH TTS 2.5"Size 287 Paragon 2 retrievable dual seal 4/25/2009 1.100 bore packer _ 7,692.0 6,4282 39.08 PATCH 21.5'Merla Tbg Patch 11/20/1994 2.375 IPERF;7,559.0-7.567.0-- , 7,703.0 6,436.7 38.98 NIPPLE AVA TPL NIPPLE inside Patch 11/20/1994 2.260 7,805.0 6,516.4 38.21 NIP RDCR AVA NIPPLE REDUCER 2.75"X 1.81" 11/17/1994 I 1.810 IPERF;7.572.0-7.579.0 Perforations&Slots I I I Shot PACKER;7,594.8 - Dens Top(TVD) Btm(TVD) (shotsR Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PATCH;7,605.0'" I I 7,468.0 7,524.0 6,256.1 6,299.0',C-4,C-3,1B- 5/4/1981 12.0'IPERF 5"Geo Vann Gun- IPERF;7,597J17.646.0"" r '02 CLOSED PATCH;7,817.0 PATCH;7,625.0 - 4 - �4 7,529.0 7,538.0 6,302.8 6,309.7 C-3,1B-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- ¢ CLOSED x 7,544.0 7,553.0 6,314.3 6,3212 C-2,1B-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- IPERF;7,652.07,669.0- # , CLOSED a 7,558.0 7,567.0 6,325.1 6,331.9'C-2,1B-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- CLOSED 7,572.0 7,579.0 6,335.8 6,341.1 C-2,1B-02 5/4/1981 12.0 IPERF 5"Geo Vann Gun- INJECTION;7,696.4 CLOSED PATCH;7,692.01 MI NIPPLE;7,703.0 a, 7,597.0 7,646.0 6,354.9 6,392.6 C-1,UNIT B, 5/4/1981 12.0 IPERF 5"Geo Vann Gun- 1., 18-02 CLOSED I 7,652.0 7,669.0 6,397.2 6,410.4 UNIT B,1B- 5/4/1981 12.0 IPERF 5"Geo Vann Gun 02 INJECTION;7,767.3 7,863.0 7,900.0 6,562.2 6,591.5 A-5,A-4,1B- 5/4/1981 12.0 IPERF 5"Geo Vann Gun LOCATOR;7.786.6 02 PACKER;7,787.9 7,866.0 7,896.0 6,564.5 6,588.3 A-5,A-4,1B- 4/5/2005 6.0 APERF 1 11/16"Power EJ NIPPLE;7805.0 02 NIP RDCR;7,805.01 Cement Squeezes Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 000,7,812,0 c 7,468.0 7,646.0 6,256.1 6,392.6 Cement Squeeze 5/13/2006 PUMPED 22.7 BBLS CEMENT APERF;7,866.07,898.0, -- .- Mandrel Inserts 3.0. IPERF;7,867,90D.0 - St - c aft C - - on Top(TVD) Valve Latch Port Size TRO Run Na Top(ftKB) (ftKB) Make Model OD(!n) Sery Type Type (in) (psi) Run Date 1 6,995.5 5,885.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0.5/11/2014 - PRODUCTION;24.7-8,113.5-. KUP INJ 1B-02 ConocoPhillips • Alaska.Inc. c+vxnRvihrn ••• 1B-02,728/2014 817:46 AM Vedaal acheonto(actual) HANGER.22.6 L ,� il Mandrel Inserts liral�aaulue lit 80 st au N Top(TVD) Valve Latch Port Size TRO Run 0 -. _ Top(ftKB) (01KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m - 2 7,313.9 6,138.1 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 12/18/2008 3 7,386.4 6,193.6 OTIS LBX 1 1/2 INJ 'HFCV RM 0.000 0.0 7/13/2011 CONDUCTOR.28.5-110.0 hisA. 4 7,457.6 6,248.1 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 3/2/2009 5 7,696.4 6,431.6 OTIS LBX 11/2 INJ Patch 0.000 0.0 11/23/1994 SAFETYVLV;1,892.9 6 7,767.3 6,486.9 OTIS LBX 11/2 INJ DMY RM 0.000 0.0 10/7/1994 Notes:General&Safety End Date Annotation 2/1/1989 NOTE:WORKOVER SURFACE,28.8-2.933.9- 2/1/1989 NOTE:COMPLETION BELOW PBR @ 7261'RUN 6/7/1985 WORKOVER 2/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 8/23/2009 NOTE:Leak detected @ 7200',3 GPM©2500 psi GAS LIFT,6.995.5 SEAL ASSY;7,062.411"9 PBR;7,070.4 9 PACKER;7,092.4 NIPPLE;7.145.6- �I PLUG;7,145.6 SEAL ASSY;7,256.5 PBR;7,259.3 PACKER;7,276.5 INJECTION;7,313.9 INJECTION;7,386.4 INJECTION;7,457.6 1.1 IPERF;7,468.0-7524.0 IPERF;7,529.07.538.0-7_ IPERF;7544.07,553,0- �- IPERF;7,558.0-7,567.0it IPERF;7,572.0-7,579.0- a� PACKER;7,594.8 PATCH;7,605.0` IPERF;7,597.0-7,648.0, -I I I PATCH;7,617.0 PATCH;7,625.0 .I �. IPERF;7,6520.7.669.0-_. INJECTION.7,696.4 PATCH;7.692.01 I NIPPLE;7,703.0 A INJECTION;7.767.3 • LOCATOR;7,786.6 PACKER;7,787.9 NIPPLE;7,805.0 NIP RDCR;7805.01 11� SOS;7,812.0 APERF;7,866.0.7,896.0, IPERF;7,863.0-7,900.0 �- c PRODUCTION;24.7-8,113.5-- • Conoco Phillips Alaska FrFEVED P.O. BOX 100360 �` `°' ANCHORAGE, ALASKA 99510 -0360 2012 March 9, 2012 Alaska OR & Gas Cons. Commission Anchorage Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th R L Avenue, Suite 100 k t .., • M � Anchorage, AK 99501 ; A K 1 . 3 ‘?—' 0 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement 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 in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Since" MJ veland ConocoPhillips Well Integrity Projects Supervisor • • CCo occoP( umm ps Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3 -09 -2012 1B, 1 C, 1D, 1E PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 18.02 50029205310000 _ 1801330 SF NA 16" NA 2.98 1/21/2012 18-08 50029206030000 1810750 8' 1.50 5'6" 9/11/11 18 1/21/2012 WSW -04 50029208330000 1821590 6'4" 1.30 24" 9/11/11 6.8 1/21/2012 WSW -06 50029208510000 1821770 20" NA 20" NA 2.13 121/2012 1C -11 50029227140000 1961720 SF 1.50 22" 9/11/11 4.68 2/10/2012 1C -18 50029229390000 1990050 SF NA 18" NA 2.55 2/10/2012 1C-26 50029229440000 1990510 SF NA 18" NA 3.75 _ 2/10/2012 1D-128 50029229000000 1981330 2" NA 26" NA 3.83 2/10/2012 . • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 27, 2011 TO: Jim Regg I ( f�7/ it P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-02 FROM: Lou Grimaldi KUPARUK RIV UNIT 1B -02 Petroleum Inspector • Src: Inspector Reviewed By: • P.I. Supry L [ 2 -- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT IB - 02 API Well Number: 50 029 - 20531 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110906104204 Permit Number: 180 - 133 - Inspection Date: 9/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1B -02-' Type Inj. G J TVD 5964 - IA 1 2997 ' 2878 -' 2811 - 2755 - 2708 - P.T.D 1801330 TypeTest SPT Test psi 1500 - OA 10 50 40 50 60 50 , Interval ITAI' P/F P - Tubing 2248 2197 2231 2197 2265 2266 Notes: Retest of previously incomplete test (unstable). 3 Bbl's pumped and returned. Held test for 60 minutes due to low but unacceptable rate of decline. Will turn results in for determination of suitability. 90 day TIO pressure plot received 9/27/11 (attached). Test passed per J. Regg. ✓ yy I I II Tuesday, September 27, 2011 Page 1 of I Page 1 of 1 • Regg, James B (DOA) A 61 4v tpiepP /Licit 14it fOi,tC4z 4 99 From: NSK Problem Well Supv [n1617 @conocophillips.com Sent: Tuesday, September 27, 2011 3:16 PM oeiq 112-tit( To: Regg, James B (DOA) l Subject: RE: TIO Plot - KRU 1B-02 (PTD 1801330) Attachments: 1 B -02 90 day TIO plot.jpg Jim, Attached is a 90 day TIO plot as requested. Please let me know if you have questions or need anything else. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, September 27, 2011 2:51 PM To: NSK Problem Well Supv Subject: 110 Plot - KRU 1B -02 (PTD 1801330) Please provide TIO plot for KRU 1B-02 for past 90 days; I am reviewing the MIT performed 9/12/11; results deemed inconclusive by Inspector that witnessed the test. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 9/27/2011 KRU 1B-02 PTD 1801330 9/27/2011 TIO Pressures Plot TRN_ANNL TRII_PHNL._ HT T ANNULUS PRESSURE TRENDS I _....,- - sno. SC WELL NAME WLKRU1B-02 3000. 3000 200. 3000 iabo. 2700 3000. !IRO. 2400 _ ... __ __ . _ 3000. i . 2100 __ 1 4111 4 1000 • ...... - - - - .. -- V - --"--....- . r A , 1500 & % t 1200 111 1 I 1 kAlireNi 1.k-e-A\ *A-4 Ideirk . !I i irkibiA4.. ,.1_44,4,.., r i arg 'y 900 .-eAr 1 . - Pc ------- l' _ _, . i\ 1 O. 4 AA I / )■ i 1 1 L i O. 600 , : t O. nk-AL - i HI-M1 — - ---_, , ...A 0. 1 : O. PLOT START TIME MINOR TIME IWIT, P.!-T4TI,PM PLOT END E _TIX 28-JUN-11 13:29 MAJOR TIME WEEK 4.02i6WOD:00 ms26 - -- MIZIENEMICI Prinnin In 4111 ; PICK TimE464*P-Ii1li46:00 ; sc TAG KANE DESCRIPTION P-VALPE LATEST 1 FON, AI-21B1153-02 FLOW TUBING CHOKE ??????, PREV WELL DRILLSITE WELL Pr SCRATCH 61 FLOW TUBING PRESSURE 7777??? lb 02 ' SCRATCH_61 FLOW TUBING TEMP 7777777 III NEXT WELL Pl. 777777? IW TM??? ENTRY TYPE OPERATOR Pr 7777777 Pmr OPERATOR VERIFIED Illir SCRATCH_61 INNER ANNULUS PRES 7????? Por SYSTEM AUTO ENTRY - SCRATCH_61 OUTER ANNULUS PRES 77777'27 - BOTH • MEMORANDUM State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 20, 2011 TO: Jim Regg C� P.I. Supervisor ( l l p7, SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA INC 1B -02 FROM: John Crisp KUPARUK RIV UNIT 1B -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1B -02 API Well Number: 50- 029 - 20531 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110919114405 Permit Number: 180 -133 -0 Inspection Date: 9/15/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IB -02 "Type Inj. W ' TVD 5964 I I 820 f 3000 ' 2950 2940 I 2935 - P.T.D 18 °133° " TypeTest SP T Test psi 1500 . OA 40 40 40 40 40 - Interval INITAL p/F P Tubing 2140 2138 2149 2154 2154 Notes: 1.25 bbls pumped for test. - 5 2r,11:1 Tuesday, September 20, 2011 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07, 2011 TO: Jim Re ery P.I. Sup C/ rC SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B -02 FROM: Jeff Jones KUPARUK RIV UNIT 1B -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry l'?— NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1B - 02 API Well Number: 50 029 - 20531 - 00 - 00 Inspector Name: JeffJones Insp Num: mitJJ110906085149 Permit Number: 180 - 133 - Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 1B4o2 Type Inj. G - I TVD 5964 ' IA 10 3220 - 3290 - 3360 , 3380 - P.T.D 1801330 ' TypeTest sPT Test psi 1soo - OA 80 110 130 150 160 Interval P/F 1 - Tubing 2575 2527 2495 2525 2509 Notes: Test "inconclusive ". 2.5 BBLS diesel pumped, IA pressure failed to stabilize due to thermal expansion. 1 well inspected; no exceptions noted. Wednesday, September 07, 2011 Page 1 of 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1B -02 Run Date: 6/12/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1B -02 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20531 -00 rr) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com r Al . Date: 1c 1 \ Signed: `-` igo-i 33 ' STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell s' Plug Ftrforations J Stimulate r Other E Alter Casing r PUII Tubing Perforate New Fool f Waiver fl Time Extension r Change Approved Program r Operat. Shutdow n fl Frforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 180 -133 3. Address: 6. API Number: Stratigraphic r Service IV P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 20531 - 00. On 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25648 „ '1 B -02 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8153 feet Plugs (measured) None true vertical 6792 feet Junk (measured) None Effective Depth measured 8027 feet Packer (measured) 7092, 7277, 7595, 7788 true vertical 6692 feet (true vertucal) 5964, 6109, 6353, 6503 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 2905 10.75 2934 2646 R " b E . t A f PRODUCTION 8089 7 8114 6760 f I -� t ; `' �` . � ED A� p% Z ,i Ft)# ,i, - _tit , , :x,: ,f0 . t.rmWhhSSIOf Perforation depth: Measured depth: 7466- 7524', 7529'- 7538', 7544'- 7553', 7556- 7567', 7572'- 7579', 7597'- 7646', 7652'- 7669', 7863' - 7900' True Vertical Depth: 6256- 6300', 6306- 6310', 6315- 6322', 6325- 6332', 6336- 6341', 6355- 6393', 6397'- 6410', 6562' -6592' Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7259 MD, 6096 TVD __. __ cc F ' Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL RETRIEVABLE PACKE 7092 M, and 5964 TVD PACKER - BAKER HB -1 RETRIEVABLE PACKER @ 7 MD and 6109 TVD PACKER - BAKER HB -1 RETRIEVABLE PACKER @ 7595 MD and 6353 TVD PACKER - BAKER WIRELINE SET PERMANENT PACKER @ 7788 MD and 6503 TVD SAFETY VLV - CAMCO TRMAXX- CMT -SR -5 SAFETY VALVE @ 1893 MD and 1853 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 0 Subsequent to operation 5015 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory E Development r Service r Stratigraphic I 15. Well Status after work: Oil r Gas 1 WDSPL r Daily Report of Well Operations XXX GSTOR J` WIND r WAG FT, GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -163 Contact Ian Toomey ( 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature —7"----7 ." Phone: 263 -4773 Date '7 _ / q _ I / Form 10 -404 Revised 10/20f0 DMS JUL 2 0 2 , Submit Original Only 1B-02 Well Work Summary DATE SUMMARY 4/23/11 PRE RWO T -POT ( PASSED ), T- OT ( PASSED ), IC -POT ( PASSED ), IC- OT FAILED ). FT -LDS ALL NORMAL. 6/12/11 LOG CORRELATED TO WELL DIAGRAM DATED 4/27/2011. SET IBP AT 7310'. CCL STOP DEPTH 7286.3', CCL TO MID ELEMENT 23.7'. IBP Schematic attached in WellView 6/13/11 TROUBLE SHOOT IBP 6/14/11 DRIFTED FRAC SLEEVE @ 1842' RKB WITH 10' X 2" DUMP BAILER. DUMP 2' OF ' w CaCO3 ON TOP OF IBP @ 7297' SLM. IN PROGRESS 6/15/11 PLACED 9' OF CaCO3 ON TOP OF IBP @ 7297' SLM. PULLED DV @ 7220' RKB. � COMPLETE 7/4[T1 PULL BALL & ROD FROM PLUG BODY © 7146' RKB, PULLED SHEARD SOV AND SET 1.5" DGLV IN STA # 1 @ 6995' RKB, MITIA TO 2500 PSI * *PASS ** 7/5/11 PULLED RHC PLUG FROM X- NIPPLE @ 7146' RKB, BAILED 36' OF MUD OFF IBP @ 7297' WLM 7/6/11 BAILED CaC3 FROM 7279' TO 7281' SLM. ATTEMPT TO EQUALIZE IBP. IN PROGRESS. 7/7/11 PULLED 2 1/8" IBP @ 7273' SLM. COMPLETE. 7/13/11 PULLED C SAND DV @ 7461' RKB. SET HFCV @ 7461' RKB. COMPLETE. • • Conoco Ph Time Log & Summary Wellview Web Reporting Report Well Name: 1B Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/23/2011 11:00:00 PM Rig Release: 6/28/2011 6:00:00 AM Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 06/23/2011 24 hr summary Rig accepted at 2300 HRS. Held RWO safety Mtg with crew. RU Hard lines to kill tank. 23:00 00:00 1.00 SURPRI WELCTL SFTY P Rig accepted at 2300 HRS. Hel RWO safety meeting with rig crew. Rig up hard lines to kill tank. 06/24/2011 Continue rig up hard lines to kill tank and tree. Pressure test to 2500 PSI.PuII BPV. Open up well. Tbg = 600 PSI, IA = 435 PSI, OA = 90 PSI. Pump 30 BBL spacer pill followed with 250 BBLS of 9.6 Brine at 3 BPM - 300 PSI, to kill well taking returns to kill tank. Pump to pits to verify no gas, and well dead. Install BPV. Test down IA to 1000 PSI. Blow down & rig down all lines. ND Tree. Install test plug. Install spacer spools, and NU BOP's. Rig up to test BOP's. AOGCC rep jeff Jones to witness test. Observed bad API ring in spool. ND to replace API ring. NU BOP stack. Rig up and test BOP's. 00:00 02:00 2.00 SURPRI WELCTL RURD P Continue rig up hard lines, and test same to 2500 PSI. Rig up lines in cellar to tree. Test same to 2500 PSI. 02:00 04:00 2.00 SURPRI WELCTL RURD P Take on 9.6 PPG brine to pits. RU CIW Lubricator, and pull BPV. TBG PSI = 600, IA PSI = 435, OA PSI = 90 PSI. Rig down Lubricator. 04:00 09:00 5.00 SURPRI WELCTL CIRC P Open lines up to choke on hardline to tank. Stage pumps up to 2.5 BPM - 350 PSI, and circulate 30 BBL Hi -Visc spacer in front of 9.6 PPG brine. Take returns to Kill tank until observed good 30 BBLS of 9.6 PPG brine at the tank. Shut in and blow down hard lines. 09:00 10:45 1.75 SURPRI RPEQP1 CIRC P Circulate well to pits. Monitor well for Fluid loss. 10:45 12:00 1.25 SURPRI RPEQP1PULD P Install BPV - Test BPV pumping down annulus to 1000 PSI. Blow down & rig down all lines. Record on chart. Crew Change 12:00 12:30 0.50 SURPRI RPEQP1 NUND P Continue blow down & rig down all lines and cellar. 12:30 14:00 1.50 SURPRI RPEQP1 NUND P Held PJSM with crew & CIW rep. ND tree. Prep spacer spools. Install test plug. 14:00 16:30 2.50 SURPRI RPEQP1 NUND P Nipple up BOP stack , choke & kill lines. Install 2 - 1' spacer spools. 16:30 18:00 1.50 SURPRI RPEQP1RURD P Held PJSM with crew. Rig up test equipment. 18:00 19:30 1.50 SURPRI RPEQP1 BOPE P Test BOP's. Observed leak on API ring in spacer spool. remove fluid form stack. Pull test joint. Pull riser. 19:30 21:00 1.50 SURPRI RPEQP1NUND P ND BOP stack. Change out API ring in spacer spool. NU BOP's. Page 1 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 SURPRI RPEQP1 BOPE P Test BOP's. Test Stack, choke & kill lines. Test NCR's and manual valves. test Choke maifold and all valves. AOGCC rep Jeff Jones here to witness test. Crew Change 36/25/2011 Continue test BOP's. AOGCC rep Jeff Jones here to witness test. Observed failures on Koomey test, repair Koomey regulator. Replace bladder on bottle. Repeat Koomey test. Perform Flow test on manual & hydraulic chokes as per State man. RD Test Equipment. Make up landing joint. Pull tbg hanger to floor. Observed seals pulled free with 120K pulled. POOH, lay down 3 1/2" tbg and control line to the SSSV. Make up & set BOT storm valve at 95'. pressure test storm valve to 1500 PSI. ND BOP Stack. ND tbg head.. Retap all casing head LDS, and install new tbg head and packoff. Test packoff to 3000 PSI. NU BOP stack and spacer spools. Install test plug and test BOP break & tbg head to 250/3500 PSI. Witness of test waived by AOGCC rep Jeff Jones. 00:00 04:30 4.50 SURPRI RPEQP1 BOPE P Continue test BOP's. Test to 250 - 3500 psi. Test all rig floor safety valves. Perform Koomey test. Test ,� ) failed with 4 minute recovery. �" 04:30 06:30 2.00 SURPRI WELCTL BOPE T Service Koomey Unit. Change out 1 f " bladder. 06:30 07:30 1.00 SURPRI WELCTL BOPE P Re -test Koomey Unit._RD test equipment. Blow down lines. 07:30 08:00 0.50 SURPRI RPEQPI OTHR P Drain stack. Pull BPV and test dart. 08:00 08:30 0.50 SURPRI RPEQPI RURD P RU XO and valve. MU landing jt and screw into hanger. 08:30 09:30 1.00 SURPRI RPEQP1 PULL P Pull 65k over expected wt on hanger. Back out and double check all lock down screws. OK Pull hanger free 09:30 10:00 0.50 SURPRI RPEQP1 PULL P Pull hanger to rig floor. Took 10k - 20k over pull to pull seals out of PBR. LD LJ and hanger. 10:00 11:00 1.00 SURPRI RPEQP1CIRC P Circ on hole volume at 5 bpm 525 psi. 11:00 11:30 0.50 SURPRI RPEQP1RURD P Monitor well. Static. RU control line spooler. 11:30 14:00 2.50 SURPRI RPEQPI PULL P POH LD 3 1/2" BTC tbg. SLB spooled control line. Line was parted on jt #40 out of hole. Complete recovery of control line and bands. 32 bands total. 14:00 15:30 1.50 SURPRI RPEQP1 PULD P Rig down Control line equipment. . r) Make up and RIH with 7" BOT Storm Z valve @ 80'. Test storm valve to 1500 PSI. UP WT = 77K, SO WT = 52K 15:30 15:45 0.25 SURPRI RPEQP1 BOPE P Perform Kommey test with AOGCC rep witness. Obtained initial 200 PSI in 30 sec, and full 3000 PSI in 175 secs. 6 Nitrogen bottles with an avg PSI of 2075. 15:45 16:30 0.75 SURPRI RPEQP1 PULD P POOH, lay down running tool. Blow down lines, and drain stack. 16:30 16:45 0.25 SURPRI RPEQP1SFTY P Held PJSM with crew & CIW rep. Discuss safety & hazard recognition issues. Discuss procedure to nipple down BOP stack and tree. Page 2 of 5 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:45 2.00 SURPRI RPEQP1 NUND P Nipple down BOP stack and spacer spool. Nipple down tbg head with no casing growth observed. Remove tbg head and packoff. Prep head for new packoff. 18:45 20:30 1.75 SURPRI RPEQP1 NUND P Remove all LDS on casing head as they were bad. Re -tap all threads on casing head for installation of new LDS & Gland nuts. Install packoff. 20:30 22:45 2.25 SURPRI RPEQP1 NUND P Nipple up tbg head, Test flange to 3000 PSI - 15 minutes. Nipple up BOP stack and lines. Install riser. 22:45 00:00 1.25 SURPRI RPEQP1BOPE P Rig up test equipment. Test BOP stack break, spacer spools, and tbg f� head flange. test to 250/3500 PSI. record on chart. Crew Change 06/26/2011 Rig down test equipment. Retrieve & lay down storm packer. No Pressure. Continue POOH lay down 3 1/2" tbg and GLM's. Dress old Seal Assembly removing seals. Make up seal assembly and RIH with 3 1/2" Completion string as per detail with SSSV and control line. Locate lower seal assembly above PBR. Rig up lines, and reverse circulate 192 BBLS of 9.6 PPG brine with corrsion inhibitor at 3 BPM - 300 PSI. 00:00 01:30 1.50 SURPRI RPEQP1 PULD P Held PJSM with crew & BOT rep. Make up retreiving tool 1111J.t engage storm valve. Observed no pressure under valve. POOH lay down storm valve. 01:30 08:00 6.50 SURPRI RPEQP1 PULL P Continue POOH, lay down 3 1/2" tbg , GLM's and seal assembly. Observed proper displacement. 08:00 09:00 1.00 SURPRI RPEQP1 OTHR P Clear and clean rig floor. 09:00 09:30 0.50 SURPRI RPEQP1SFTY P PJSM on running 3 1/2" tbg. 09:30 16:30 7.00 0 5,300 SURPRI RPCOM RCST P RIH with 3 1/2" completion equipment and 167jts 3 1/2" EUE 8rd mod tbg. Observed proper displacement. 16:30 17:30 1.00 5,300 5,300 SURPRI RPCOM RCST P Make up SSSV and control line. Test line to 6000 PSI. 17:30 21:00 3.50 5,300 7,250 SURPRI RPCOM RCST P Continue RIH with 3 1/2" Completion string as per detail to 7250'. UP WT = 92K, SO WT = 70K. 21:00 22:00 1.00 7,250 7,259 SURPRI RPCOM RCST P Make up lines, valves and pump in sub, on jnt # 228. Slack off to locate PBR @ 7259' as planned, and sting into same with increased pressure from 30 PSI - 280 PSI to verify sting in. Verify depth with 11' of seal swallow. Pull out of PBR to locate seals above P6R" 22:00 00:00 2.00 7,259 7,259 SURPRI RPCOM CIRC P Rig up truck to mud pump. Close annular, and pump down annulus at 3 BPM - 300 PSI to spot 192 BBLS of 9.6 PPG w/ corrosion inhibitor. Crew Change Page 3 of 5 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/27/2011 24 hr Summary Continue circulation of inhibited brine. 192 BLS total. Land seals into lower PBR. Pick to locate 1' above PBR. Drop Ball & rod, allow to seat. Set upper BOT FHL packer on depth at 7092'. Shear PBR. POOH lay down jnts and install space out pups. Make up hanger and landing joint. land tbg. UP WT = 87K, SO WT = 73K. RILDS. Test tbg to 3000 PSI - 30 minutes. Bleed tbg to 2250 PSI. Test annulus to 3000 PSI - 30 minutes. Bleed pressure to shear SOV, verify circulation. Install BPV. Test down annulus to 1000 PSI to test BPV. ND BOP's, Pull ram blocks from doors of BOP's. NU Tree & test. Displace well with 75 BBLS of freeze protect deisel. Allow to U -tube until dead. Install BPV. Secure tree, and cellar. prep rig for Move. 00:00 00:30 0.50 7,259 7,259 SURPRI RPCOM CIRC P Held PJSM with new crew. Continue circulate down annulus to spot a total of 192 BBLS of 9.6 PPG corrosion inhibited brine on annulus. 00:30 01:00 0.50 SURPRI RPCOM RCST P Sting seals in to lower PBR, and locate same with neutral weight plus 1' above PBR. Drop Ball & rod. Allow to seat. UP WT = 87K, SO WT = 73K. 01:00 01:30 0.50 SURPRI RPCOM PRTS P Pressure down tbg to 1800 PSI observing BOT FHL packer set on depth at 7092'. Continue pressure to 2500 PSI. Bleed pressures. 01:30 02:00 0.50 SURPRI RPCOM PRTS P Shear out of upper PBR @ 98K and continue POOH lay down joints to install space out pup. Install 6.06' space out pup and 1 joint. 02:00 03:30 1.50 SURPRI RPCOM RCST P Make up tbg hanger. Attach control line to same and test to 6000 PSI. RIH to land tbg hanger with RKB at 22.60'. RILDS. 03:30 05:00 1.50 SURPRI RPCOM PRTS P Make up lines, and pressure down tbg to 3000 PSI for a 30 minute test on chart. Bleed pressure to 2250 (P( PSI. Pressure down annulus to 3000 PSI - 30 minutes on chart. Bleed pressure to shear out SOV, and verify circulation. Bleed all pressures. 05:00 06:00 1.00 SURPRI RPCOM PULD P Pull and lay down landing joint. Install BPV as per CIW rep. Test down annulus to 1000 PSI to test BPV. 06:00 08:30 2.50 SURPRI RPCOM OTHR P Clear and clean rig floor. Flush out all lines. 08:30 12:00 3.50 SURPRI RPCOM NUND P PJSM. Open all ram doors and remove rams. Simops - Remove all subs from rig. Clean pits. Remove caps and valves from rig pumps. Crew Change 12:00 15:30 3.50 SURPRI RPCOM NUND P Insatll all ram blocks back in the BOP's. Nipple down BOP stack, adapter spools. 15:30 18:00 2.50 SURPRI RPCOM NUND P Nipple up tree aapter flange. Nipple up tree. Fill tree with deisel, and test same to 250 / 5000 PSI. 18:00 21:15 3.25 SURPRI RPCOM FRZP P Pull TWC. Rig up Little Red services. Held PJSM. Pump 75 BBLS down annulus at 2 BPM - 750 PSI to freeze protect well. Allow to U -tube until dead. Page 4 of 5 • 1 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:15 22:30 1.25 SURPRI RPCOM RURD P Blow down and rig down all lines. Install BPV. Secure tree and cellar. Dress tree with blanks and gauges. 22:30 00:00 1.50 SURPRI MOVE DMOB P Clean rig, and prepare rig for move to 1J and stackout. Crew Change 06/28/2011 Continue clean & wash rig for move. Prep for move. Rig released at 0600 HRS. 00:00 06:00 6.00 SURPRI MOVE DMOB P Continue wash & clean rig. prep for rig move. Rig released at 0600 HRS. Page 5 of 5 ,„ r KU P 0 1 B -02 C8nocih1lhips '" Well Attributes M ax Angle & MD TD M' WeIlbore APVUWI IF ld Name Well Status Inc! 1 ° ) IMD (866) Act Btm (ftK8) cr ,a 500292053100 KUPARUK RIVER UNIT INJ 4300 2,500.00 8,153.0 - Comment H2S (ppm) ... we ®c 1 - 711 a1 ] 1r q SSSV: LOCKED OUT I Date "Annotation 1 End Date KB - Grd (ft) Rig Release Date 2!111989 _ 28.48 1!11/1981 "'t "` "' M _ - ' : A notation Depth (RKB End Date Ann otatwn Last Mod ... End Date Last Tag: SLM 7,889 0 12f31/2008 Rev Reasons WORK rnnam l 7/16!2011 HANGER 23 - Casing Strings 7 , 3 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt. .. String ... String Top Thrd CONDUCTOR 16 15.062 28.5 110.0 110.0 65.00 H WELDED Casing Description String 0... String ID ... Top (fd(6) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 10 3/4 9.794 28.8 2,933.9 2,646.3 45.50 K Casing Description String 0... String ID... Top (ftK8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... !String Top Thrd PRODUCTION 7 6.276 24.7 8,113.5 6, /60.9 26.00 K -55 CONDUCTOR, Tubing Strings 28-110 Tubing Description String 0... String ID ... Top (ftK8) Set Depth (1... Set Depth (ND) . String Wt... String ... String Top Thrd Tubing WO 3 1/2 2.992 I 22 6 1 7,259 4 6,096.3 9.30 L-80 EUE Completion Details SAFETY VLV, T op Depth (TVD) Top Nomi... 1,893 To Inc! ; i'; Top (RKB) (ftK6) ( °) '� Item Description Commend ID (in) 22.6 22.6 0.00' HANGER F HANGER w/ 3.65' pup 2.992 1,892.9 1,852.6 30.23 SAFETY VLV CAMCO TRMAXX- CMTSR -5 SAFETY VALVE w/ 2.813 X PROFILE 2.812 SURFACE, 7,062.4 5,939.7 36.81 SEAL ASSY SEAL ASSEMBLY LOCATOR 3.000 29 7,070.4 5,946.1 36.85 PBR BAKER 80-40 PBR (40K SHEAR) 4.000 7,092.4 5,963.8 36.96 PACKER BAKER FHL RETRIEVABLE PACKER 2.920 7,145.6 6,006.1 37.23 NIPPLE OTIS X LANDING NIPPLE 2.812 GAS LIFT, 6,995 7,256.5 6,094.1 40.00 SEAL ASSY BAKER 8040 GBH -22 LTSA SEAL ASSEMBLY W/ LOCATOR W/O 3.750 Sr Sr SEALS SEAL ASSY, Igik Tubing Description IStr ng 0.. String ID . Top (RKB) Set Depth (L..I Depth (ND) - String Wt... ]String . - g ..IString Top Thrd 7,062 TUBING Ongmal ___1. 3 1/2 - - __ 2 992 _ 7,259,3 1 7,812.9 l_ - 6,522.4 ___ - 9 30 - - -, � J . - ._ .. _ EUE 8RD SPACE OUT, - -- - 7,063 - -_._ --, V Completion Details PBR, 7.070 - Top Depth PACKER, 7,092 - (TVD) Top Intl N mi... i Top(ftKB) (11(8) (°) Item Description comment ID(in) t,�` - 7,259.3 6,096.2 40 -00 PBR BAKER OIL TOOLS PBR 3.000 NIPPLE. 7.14s -- y vi___ 7,276.5 6,109.4 40.00 PACKER BAKER HB -1 RETRIEVABLE PACKER 3.000 7,496.4 6,277.8 40.00 BLAST RINGS 2.992 - --_:, 7,561.8 6,328.1 40.38 BLAST JOINT 2.992 SEAL ASSY, _.. 7,594.8 6,353.2 40.05 PACKER BAKERHB -1 RETRIEVABLE PACKER 3.000 7,257 f .. __ 7,602.1 6,359.1 39.73 BLAST RINGS 2.992 PBR, 7,259 _... T-- . - -_.. 1 7,662.5 6,405.3 3928 BLAST JOINT 2.992 7,786.6 6,502.0 38.35 LOCATOR BOT LOCATOR W XO 3.000 • 7,787.9 6,503.0 38.34 PACKER BAKER WIRELINE SET PERMANENT PACKER 3.000 7,805 -0 6,516.1 37.50 NIPPLE CAMCO 'ID NO GO NIPPLE 2.720 INJECTION, 7,314 " - 7,812.0'. 6,521.6 37 -50 SOS BAKER SHEAR OUT 2.992 INJECT Other In Hole reline retrievable plugs, valves pumps, fish, etc.) i Top Depth (TVO) Top Inc! Tap (RKB) (61(8) ( °) Description Comment Run Date ID (in) INJECTION, - *if* 7,605 6,361.3 39.71 PATCH 2.72" TTS retrievable packer mid - element @ 7607, N 4/26/2009 1.625 7,458 'PEKE, blank pipe w /seals anchor latch 7,468 BLAST RINGS, , 7,617 6,370.5 39.62 PATCH Meda 21' Tbg Patch; Set on 12/1/94 12/1/1994 2.375 - 7,496 Z 7,625 6,376 -6 39.56 PATCH TTS 2.5" Size 287 Paragon 2 retrievable dual seal bore 4/25/2009 1.100 packer IPERF, 7,529 £ ' 7,692 6,428.2 39-06 PATCH 21.5' Meda Tbg Patch 11/20/1994 2.375 IPERF._ ) .: 7,703 6,436.7 38.98 NIPPLE AVA TPL NIPPLE inside Patch 11/20/1994 2.260 7,546 -7,553 7,805 6,516.1 37.50 NIP RDCR AVA NIPPLE REDUCER 2.75" X 1 81" 11/17/1994 1.810 IPERF, IPERF, Perforations &Slots -,__ 7,558.7,567 , = ' - __ Shot 7,572 - 7,579 Top (TVD) Btm (TVD) Dens BLAST JOINT, Top (MKS) Btm (8KB) (1106) (RKB) Zone Date (sh^• Type Comment 7,562 _ - - .-_ ._... 7,468 7,52 6,256.1 6,299.7 C4, C3, 16 - 02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED PACKER, 7,595 _ - -- PATCH, 7,605 7,529 7,538 6,303.4 6,310.2 C -3, 16-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED IPERF. 7,544 7,553 6,314.7 6,321.5 C -2, 16-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED 7,597 - 7,646 PATCH, 7,617 7,558 7,567 6,325.3 6,332.1 C - 2, 16 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED &AST RINGS, 7,602 - 7,572 7,579 6,335.9 6,341.2 C - 2, 16.02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED PATCH, ],625 - 7,597 7,646 6,354.9 6,392.7 C - 1, UNIT B, 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED SQUEEZE, I_'.1 113 7,468 I� _- IPERF - - 7,652 7,669 6,397.3 6,410.4 UNIT 8, 16 5/4/1981 12.0 IPERF 5" Geo Vann Gun 7T BLAST JOINT, 7,863 7,900 6,562.1 6,591.5 A -5, A4, 1B -02 5/4/1981 12.0 IPERF 5" Geo Vann Gun 7,862 - - -- - 7.662 - '>� 7,866 7,896 6,564.5 6,588.3 A-5, A4, 1B -02 4/5/2005 6.0 APERF 1 11/16" Power EJ INJECTION, ( 7,696 PATCH, 7,692 + NIPPLE, 7,703 -n- a Mandrel Details '' 4,r F`-is ,1;�,. INJECTION, Top Depth Top Port 7,767 - (TVD) Inc' OD Valve Latch SW 7R0 Run LOCATOR, ' - ' Stn Top (ftK8) (ftK8) (1 Make Model (in) Sere Type TIN. ( (psi) Run Date Can... 7.787 _ 1 6,995.5 5,885.8 35.91 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 6/272011 PACKER, 7,788 _ NIPPLE, 7,805 2 7,313.9 6,138.1 40.00 OTIS 1.13X 112 INJ DMY RM 0.000 0.012/182008 NIP RDCR, 7,805 3 7,386.4 6,193.6 40.00 OTIS LBX 1 12 INJ HFCV RM 0.000 0.0 7/13/2011 4 7,457.6 6,248.1 40.00 OTIS LBX 1 12 INJ DMY RM 0.500 0.0 3/2/2009 SOS, 7,812 5 7,696.5 6,431.6 39.03 OTIS LBX 1 12 INJ Patch 0.000 0.0 11/23/1994 APERF, 6 7,767.3 6,486.9 38.50 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 10/7/1994 7,866 -7,896 IPERF, 7,863 -7,906 PRODUCTION, 25.8,114 TD,8,153 .-- __ • KU P • 1B-02 ConocoPlillips ``` ‘ Ataska. ux.meotwilus .., KB-Grd (ft) Rig Release Date weri cn --02 7 /16/20117;11,08 A14 28.48 1/11/1981 SdAiwielc - ACN4I HANGER. 23 - Cement Squeezes To 1 Top Depth Btrn Depth (TVD) (MD) v Ten (EKE) Ban (tIK6) (tiK8) (EKE) Description scan Dab Comment - _ 7,468.0 7,646.0 6,256.1 6,3923 Cement Squeeze 5/13/2006 PUMPED 22.7 BBLS CEMENT .;.. - . .. . -s, ,. - .. .., �. - End Dab Annotation CONDU __. 2/1/1989 NOTE: COMPLETION BELOW PBR 0 7261' RUN 6/7/1985 WORKOVER 2 6-110 2/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 8/23/2009 NOTE: Leak detected 0 7200'.3 GPM @ 2500 psi RIF SAFETY VLV, _.'.- 1,893 SUR Y FACE, ` 29 -2,934 GAS 1 . , 1 9 F - 9 1 - _ _ _. .______ 6,995 IF �+a•� SEAL ASSY. 7,062 SPACE OUT, - 7,063 -. ;; PBR, 7,070 PACKER, 7,092 - _ NIPPLE, 7,146 _- .., SEAL ASSY, ... . 7,257 irt PBR, 7,258 / PACKER. 7,277 - = V INJECTION, 7,314 INJECTION. .: 7,386 -_.. INJECTION,_ __ 7,458 IPERF, 7,166 -7,521 �. __ -..- • lit BLAST RINGS, _... f. - 7,496 r4a IPERF, 7,529 -7,536 IPERF, 7,541 -7,553 IPERF, 7,558 -7,567 IPERF, 7,572. 7,579 I:. T, BLAST JOIN(,_ -- 7,562 N 1 PACKER 7,595, PATCH 7.605 IPERF, ..- 7,597.7,648 -... PATCH, 7,817 .1- _T BLAST R11 G S, 02 � PATCH, 7,625 - - ' I SQUEEZE, 7,468 IPERF, 7,652 -7,669 BLAST JOINT, _.- ' N 7,662 INJECTION, 7,696 \ PATCH, 7,692 NIPPLE, 7,703 -' - K ' INJECTION, LOCATOR, 7,787 7 PACKER, 7,788 NIPPLE,7,860 NIP 6006, 7,805 i ■ SOS, 7,812- �. APERF, 7,886 - 7,896 IPERF, 7,863.7,900 n PRODUCTION, 25.6,114 " TD, 8,153 [ r • • SITERE AELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GrAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1B-02 Sundry Number: 311 -163 stikAlliMELI MAY 1 8 aW • Dear Mr. Toomey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Og Daniel T. Seamount, Jr. Chair DATED this ` ? day of May, 2011. Encl. . . P Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED ritIO - ' 11 1 May 10, 2011 �y} g�//r� Oil & g (��y� {rc'�@¢ //�� Aloska Oil & Gag Cons. remission Commissioner Dan Seamount ;Interne State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1B -02 (PTD 180 -133). Well 1B -02 was originally drilled and completed in 1981. The well was a producer from 1981 until 1995 when it was converted to an injector. The well is currently completed as an A and C sand triple completion MWAG injector. In July 2009 tubing to IA communication appeared. A leak detection log was run, a leak was detected in the tubing near GLM 5 at 7200' MD and the well was shut in. The proposed workover will consist of pulling the existing 3 -1/2" tubing string and stacking a packer with new 3 -1/2" L -80 tubing string. The planned completion is to stack a packer at —7136' MD ( -332' above top perforation) which does not comply with 20 AAC 25.412 "The packer must be placed within 200 feet measured depth of above the top of the perforations ". We wish a variance to be granted. A Passing CMIT TxIA test occurring on August 1, 2009 indicates that the production casing and current packer is competent. The workover plan does not include pulling the damaged selective because of the risk associated with pulling blast rings and assorted jewelry. If you have any questions or require any further information, please contact me at 263 -4773. Sincerely, Ian Toomey Wells Engineer CPAI Drilling and Well STATE OF ALASKA 1111 +� ALASKL AND GAS CONSERVATION COMMISSI• ��' 1 ; t APPLICATION FOR SUNDRY APPROVALS 6 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill J' Perforate New Pool r Repair w ell � . Change Approved Program F' Suspend r Plug Perforations '—• Perforate r Pull Tubing Time Extension j-° Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 180 - 133 ' 3. Address: Stratigraphic r Service r•,7 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20531 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No p- 1B -02 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25648 . Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8153 • 6792 • 8027' 6692' Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 2905 10.75 2934' 2646' PRODUCTION 8089 7 8114' 6760' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7468' - 7896' 6256-6583' 3.5 J -55 7812 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB -1 RETRIEVABLE PACKER MD= 7281 TVD= 6112 PACKER - BAKER HB -1 RETRIEVABLE PACKER MD= 7595 TVD= 6353 PACKER - BAKER WRELINE SET PERMANENT PACKER MD= 7788 TVD= 6503 SAFETY VLV - OTIS TR -FMX MD= 1842 TVD= 1808 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/27/2011 Oil E Gas r WDSPL r Suspended E 16. Verbal Approval: Date: WINJ r GINJ r WAG p ' Abandoned r Commission Representative: GSTOR r SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263 -4773 Printed Name Ian Toomey Title: Wells Engineer Signature 1 �_ �� Phone: 263 -4773 Date s -/i'lf c Commission Use Only Sundry Numbers''' 1 5 Conditions of approval: Notify Commission so that a representative may witness � Plug Integrity r BOP Test r Mechanical Inte rity Test y Location Clearance r RECEIVED) Other 5� f ?SL / GS ) - A AY )t x-- 2S0o r s,. / 4nn,„*- -. Id— hzr -" Subsequent Form Required: Al aka Oil &' Gest C W*6. af11(iIi $WA 1 •- y A ncner APPROVED BY Approved by: s ` COMMISSIONER THE COMMISSION Date: S/ -/i 5.11 11 Form 10 -403 Revises 'Y '' nil ' a R 1 G 1 N A L Submit in Duplicate • • 1B -02 Expense Rig Workover (PTD #: 180 -133) Current Status 1B -02 is currently shut in awaiting a workover. A passing CMIT TxIA test occurred on August 1, 2009 indicates that the production casing and current packer are competent. Scope of Work Pull the existing 3 -1/2" tubing string and stack a packer with new 3 -1/2" L -80 tubing string. General Well info MASP: 2230 psi (utilizing 0.1 psi/ft gas gradient and SBHP listed below) Reservoir pressure /TVD: 2858 psi at 7500' MD (6281' TVD) SBHP taken on March 22, 2011 ¥ 7 Wellhead type /pressure rating: WKM Gen I, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MITIA and MITOA results: MIT -IA — failed on August 1, 2009, tubing leak detected at 7200' RKB CMIT -TxIA — passed on August 1, 2009 MIT -OA - passed on May 11, 2009 Well Type: Injector Estimated Start Date: May 27, 2011 Production Engineer: Dan Bearden/David Lagerlef ./ Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey@ conocophillips.com) Pre -Rig Work Request 1. RU HES E -line. a. Set Baker 2 -1/8" IBP at 7298' RKB. Pressure test IBP to 2500 psi and drawn down test to 0 psi. 2. RDMO HES E -line. • 3. RU HES slickline a. Dump 10' of CaCO on top of IBP b. Pull DV from GLM #5 at 7220' MD, leave open. 4. RDMO HES slickline. 5. PT tubing and casing packoffs, FT LDS. 6. Set BPV. Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Bleed IA to outside open top tank. Keeping IA open circulate well to 9.6 ppg brine until 9.6 ppg brine returns at surface. Monitor well to ensure that it is dead. Set 3" `H' BPV. ND tree. NU 11" 5K BOP and pressure test BOP to 250/3500 psi. ' 2. Pull blanking plug and BPV. MU landing jt and PU tbg hgr to rig floor. Circulate KWF down tbg taking h-aw returns from the IA at max rate to ensure well is loaded with KWF. 3. TOOH laying down tubing and spooling up control line. • 4. RIH with locator assembly without seals, 2.812" `X' nipple w /RHC plug body installed, FHL packer, PBR, GLM #1, SCSSV and 3 -1/2" L -80 tubing. Locate PBR, PU to neutral +1 ft and circulate well to 9.6 ppg corrosion inhibited brine. 5. Drop ball and rod. Pressure up to 2500 psi and set FHL packer. 6. PU and shear PBR. Space out positioning one full joint below tubing hanger. Space out should leave locator 3 ft above located position when tubing hanger is landed IC I Page 1 of 2 • i — Proposed Procedure Continued- 7 . MU new hanger and land tubing hanger. RILDS. Function test and PT TRMAXX -CMT SCSSV as per Schlumberger guidelines. 8. Pressure test tbg to 2500 psi for 15 mins. PT IA to 3000 psi for 30 mins and record on chart. 9. Bleed IA to 0 psi followed by tbg pressure to 0 psi. Ramp up IA pressure to 2000 psi to shear SOV. Bleed tbg and IA to 0 psi. 10. Set 2 -way check. ND BOP. NU tree and test. 11. Pull 2-way check. Freeze protect well. Set BPV. 12. RDMO Nordic 3. Post -Rig Work request: 1. Pull BPV 2. RU HES Slickline: a. Pull SOV from GLM #1 b. Run DV in GLM #1 c. Pull Ball and Rod. d. Pull RHC plug body. 3. RDMO HES Slickline 4. Return well to injection. i I I Page 2 of 2 • KU P 1 B -02 ConocoPhillips o ell Attributes Max Angle & MD TD kK , W ellbore API /UWI Field Name Well Status Inc! P) MD (ftKB) Act Btm (ftKB) Alaska, <anocni+vl8ps 500292053100 KUPARUK RIVER UNIT INJ 43.00 2,500.00 8,153.0 - Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: LOCKED OUT Last WO: 2/1/1989 28.48 1/11/1981 Well Conan: - 1 B -02, 4/2702011 9:42:52 AM achematk - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,889.0 12/31/2008 Rev Reason: FORMAT UPDATE Imosbor 4/27/2011 1 Casing Strings 1 . 1.- r Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER.27 CONDUCTOR 16 15.062 28.5 110.0 110.0 65.00 H-40 WELDED ' •` " 7 Casing Description String 0... String ID ° °. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt_. String ... String Top Thrd SURFACE 103/4 9.794 28.8 2,933.9 2,646.3 45.50 K -55 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 24.7 8,113.5 6,760.9 26.00 K -55 II Tubing Strings CONDUCTOR, _� Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 7.e - tto - TUBING I Str 31/2 I 2.992 I 26.7 I 7,813.0 I 6,522.4 I 9.20 I J - 55 BTCABMOD SAFETY VLV, 6 Completion Details SLEEVE -C, I 9 Top Depth 7'842 (TVD) Top Inel Noml... Top (ftKB) (RKB) (°) item Description Comment ID (in) GAS LIFT, { 26.7 26.7 0.00 HANGER McEVOY TUBING HANGER 3.500 2.838 T L 1,842.4 1,808.0 28.34 SAFETY VLV OTIS TR -FMX (LOCKED OUT 9/30/1998) NOTE: "BEWARE" SSSV 2.813 • FLAPPER IS BROKEN i 7,231.5 6,074.9 40.00 NIPPLE OTIS 'X' SELECTIVE LANDING NIPPLE 2.813 SURFACE, 29-2 934 7,266.0 6,101.3 40.00 PBR BAKER OILTOOLSPBR 3.000 7,280.6 6,112.5 40.00 PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 7,500.4 6,282.1 41.00 BLAST RINGS 2.992 GAS LIFT, J 5.173 1 7,561.8 6,328.1 40.38 BLAST JOINT 2.992 GAS uT, ,2F90 _ J I -.. 7,594.8 6,353.3 40.05 PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 6 7,602.2 6,359.2 39.73 BLAST RINGS 2.992 GAS LIFT, 6.899 - 1 7,632.1 6,382.0 39.51 BLAST RINGS 2.992 7,662.5 6,405.4 39.28 BLAST JOINT 2.992 GAS LIFT 7,786.7 6,502.1 38.35 LOCATOR BOT LOCATOR W X0 3.000 7,220 7,787.9 6,503.1 38.34 PACKER BAKER WIRELINE SET PERMANENT PACKER 3.000 NIPPLE. 7,231 7,805.0 6,516.1 37.50 NIPPLE CAMCO 'D' NO GO NIPPLE 2.720 7,812.1 6,521.7 37.50 SOS BAKER SHEAR OUT 2.992 PBR 1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) PACKER, 7,287 °-- Top Depth INJECTION. - I L (TVD) Top Inc! 7,378 _ Top (ftKB) (ftKB) (°) Description Comment Run Date ID (In) 1,842.4 1,808.0 28.34 SLEEVE -C FRAC sleeve over SSSV FLAPPER (GAL 8'10") 7/28/2009 2.310 INJECTION, 7,390 7 6,361.3 39.71 PATCH 2.72" TTS retrievable packer mid - element @ 7607, N-80 4/26/2009 1.625 blank pipe w /seals anchor latch 7 6,370.5 39.62 PATCH Merle 21' Tbg Patch; Set on 12/1/94 12/1/1994 2.375 INJECTION, 7,625.0 6,376.6 39.56 PATCH TTS 2.5" Size 287 Paragon 2 retrievable dual seal bore 4/25/2009 1.100 7 e6z = packer IPERF. 7.468 -7.524 \ ' , 7,692.0 6,428.2 39.06 PATCH 21.5' Merla Tbg Patch 11/20/1994 2.375 BLAST RINGS, ) I 1 ' 7,703.0 6,436.7 38.98 NIPPLE AVA TPL NIPPLE inside Patch 11/20/1994 2.260 7,805.0 6,516.1 37.50 NIP RDCR AVA NIPPLE REDUCER 2.75" X 1.81" 11/17/1994 1.810 IPERF, 7.529-7,538 - Perforations & Slots - Shot 7,54x7553 7553 - Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (RK8) (RKB) (ftKB) Zone Date (sh... Type Comment _ 7,468.0 7,524.0 6,256.1 6,299.7 C-4, C -3, 16-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED IPERF, 4 . ' I 7,529.0 7,538.0 6,303.4 6,310.2 C -3, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED 7,558 -7,567 I IPERF, 7,544.0 7,553.0 6,314.7 6,321.5 C-2, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED 7,572 -7,579 BLAST JOINT, 7,558.0 7,567.0 6,325.3 6,332.1 C-2, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun- CLOSED 7,582 7,572.0 7,579.0 6,335.9 6,341.2 C-2, 1B-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED PACKER 7,595 - 7,597.0 7,646.0 6,354.9 6,392.7 C-1, UNIT B, 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED PATCH. 7,805 `! 18-02 BLAST RINGS, ;X IF 7,652.0 7,669.0 6,397.3 6,410.4 UNIT B, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun 7,597-7,646 _ _ 7, 863.0 7,900.0 6,562.1 6,591.5 A -5, A-4, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun PATCH. 7,877 7,866.0 7,896.0 6,564.5 6,588.3 A -5, A-4, 1B -02 4/5/2005 6.0 APERF 1 11/16" Power EJ PATCH, 7825 SQUEEZE. :f il(' &d ueezes 7,488 •,� Ce ments Q BLAST RINGS, Top Depth Btm Depth 7,632 (TVD) (TVD) IPERF, Top (ftKB) Bhn (RKB) (RKB) (RKB) Description Start Date Comment 7.6527,e69 7,468.0 7,646.0 6,256.1 6,392.7 Cement Squeeze 5/13/2006 PUMPED 22.7 BBLS CEMENT Bu JOINT, 7.863 NT, 6TJ7 Notes: General & Safety End Date Annotation INJECTION, 2 /1 /1989 NOTE: COMPLETION BELOW PBR @ 7261' RUN 6/7/1985 WORKOVER 7.697 \ PATCH 7,892- e. 9/10/1998 NOTE: - BEWARE"' SSSV FLAPPER HAS A PROBLEM . %' NIPPLE 7703 2/17/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 8/23/2009 NOTE: Leak detected @ 7200', 3 GPM @ 2500 psi it I INJECTION. Mandrel Details 7,767 W. .,.. Top Depth Top Port LOCATOR. .; RKB) Inc! C) Make Mode OD S ere Valve Type „n, TRO (p Run (psi) Run Data Cont... 7.787 Stn Top (ftKB) ( Co PACKER, 7,768 - - 1 2837.8 2,574.3 41.50 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/1/1989 1 NIPPLE. 7805 M 2 5,172.7 4,346.0 39.59 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/1/1989 NIP RDCR, :1111111 7,ao5 3 6,279.6 5,270.8 26.19 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0 °0 2/1/1989 SE SOS.7.812 , 4 6,899.0 5,806.7 33.98 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/1/1989 APERF, 5 7,220.1 6 40.00 MERLA TPDX 1 12 GAS LIFT DMY T2 0.000 0.0 2/1/1989 7,eee- 7,999\ I 6 7,318.0 6,141.240.00OTIS LBX 112 INJ DMY RM 0.000 0.012/18/2008 PERF, \ 7.863 -7.900 7 7,390.5 6,196.7 40.00 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 12/182008 8 7,461.7 6,251.3 40.00 OTIS LBX 1 12 INJ DMY RM 0.500 0.0 3/2/2009 i 9 7,696.5 6,431.7 39.03 OTIS LBX 1 12 INJ Patch 0.000 0.0 11/23/1994 PRODUCTION, 10 7,767.4 6,487.0 38.49 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 10/7/1994 25A,174� T0. 8,153 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Attachments: CPAI Failed MITIA Monthly Data 12- 10_edit.xls \ J--- Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back °the comments /questions I am developing. also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A -07, 1A -12 and 1B-02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE StAiNED JAN 2 0 2O1c AOGCC -V 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1A-12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. F • : NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: .turday, January 01, 2011 10:55 AM To: Regg, - es B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well -grity Proj; NSK Problem Well Supv Subject: Conoco' i•s Monthly Injector Report - Dec 2010 Jim /Tom /Guy, Attached for your records is the Conoc. ' illips monthly injector report for December 2010. Please contact me at your convenience if you h- e questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/3/2011 The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 CeII 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 • • ConocoPhillips Well 1B-02 Injection Data • Tbg Psi IA Psi A OA Psi 4000 3500 - I 3000 . 13) 2500 w a a 2000 z 1500 1000 500 0 ma 09/10 10/10 11/10 12/10 01/11 Date PTD# 180 -133 TxIA Communication 5/6/2009 Well last injected 6/09 • • ConocoPhillips Well 1B-02 Injection Data • Water Injection • Gas Injection I 4000 3500 3000 .c 2500 a a 2000 E 1500 - 1000 - 500 - 0* 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd J Water Tubing Date of Gas Injected IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 28 700 20 30- Dec -10 0 0 25 700 20 29- Dec -10 0 0 19 700 20 28- Dec -10 0 0 18 700 20 27- Dec -10 0 0 20 700 20 26- Dec -10 0 0 19 700 20 25- Dec -10 0 0 20 700 20 24- Dec -10 0 0 19 700 20 23- Dec -10 0 0 18 700 20 22- Dec -10 0 0 17 700 20 21- Dec -10 0 0 -4 700 20 20- Dec -10 0 0 23 700 20 19- Dec -10 0 0 23 700 20 18- Dec -10 0 0 21 700 20 17- Dec -10 0 0 21 700 20 16- Dec -10 0 0 23 700 20 15- Dec -10 0 0 21 700 20 14- Dec -10 0 0 18 750 20 13- Dec -10 0 0 22 750 20 12- Dec -10 0 0 21 750 20 11- Dec -10 0 0 17 750 20 10- Dec -10 0 0 20 750 20 9- Dec -10 0 0 22 750 20 8- Dec -10 0 0 23 750 20 7- Dec -10 0 0 21 750 20 6- Dec -10 0 0 21 750 20 5- Dec -10 0 0 22 750 20 0 • 4- Dec -10 0 0 20 750 20 3- Dec -10 0 0 21 750 20 2- Dec -10 0 0 21 750 50 1- Dec -10 0 0 21 750 50 30- Nov -10 0 0 19 750 50 29- Nov -10 0 0 20 750 50 28- Nov -10 0 0 22 750 50 27- Nov -10 0 0 21 750 10 26- Nov -10 0 0 21 750 10 25- Nov -10 0 0 25 750 10 24- Nov -10 0 0 24 750 10 23- Nov -10 0 0 29 750 10 22- Nov -10 0 0 28 750 10 21- Nov -10 0 0 27 750 10 20- Nov -10 0 0 30 750 10 19- Nov -10 0 0 26 750 10 18- Nov -10 0 0 23 750 10 17- Nov -10 0 0 23 750 10 16- Nov -10 0 0 21 750 10 15- Nov -10 0 0 19 750 10 14- Nov -10 0 0 23 750 10 13- Nov -10 0 0 22 750 10 12- Nov -10 0 0 22 750 10 11- Nov -10 0 0 24 750 10 10- Nov -10 0 0 20 750 10 9- Nov -10 0 0 20 750 10 8-Nov-10 0 0 26 750 10 0 v -1 0 7- Nov -10 0 0 27 750 10 6- Nov -10 0 0 25 800 10 5- Nov -10 0 0 25 800 10 4- Nov -10 0 0 22 800 10 3- Nov -10 0 0 22 800 10 2- Nov -10 0 0 22 800 10 1- Nov -10 0 0 24 800 10 31- Oct -10 0 0 23 800 10 30- Oct -10 0 0 26 800 10 29- Oct -10 0 0 27 800 10 28- Oct -10 0 0 25 800 10 27- Oct -10 0 0 25 800 10 26- Oct -10 0 0 26 800 10 25- Oct -10 0 0 27 800 10 24- Oct -10 0 0 25 800 10 23- Oct -10 0 0 24 800 10 22- Oct -10 0 0 26 800 10 21- Oct -10 0 0 26 800 10 20- Oct -10 0 0 25 800 10 19- Oct -10 0 0 26 800 10 18- Oct -10 0 0 23 800 10 17- Oct -10 0 0 23 800 10 16- Oct -10 0 0 25 800 10 15- Oct -10 0 0 25 800 10 14- Oct -10 0 0 28 800 10 i 0 13- Oct -10 0 0 28 800 10 12- Oct -10 0 0 27 800 10 11- Oct -10 0 0 27 800 10 10- Oct -10 0 0 26 800 10 9- Oct -10 0 0 26 800 10 8- Oct -10 0 0 21 800 10 7- Oct -10 0 0 27 800 10 6- Oct -10 0 0 27 800 10 5- Oct -10 0 0 21 800 10 4- Oct -10 0 0 20 750 10 3- Oct -10 0 0 20 750 10 2- Oct -10 0 0 20 750 10 WELL L~ S TRAN.Sl~9//TIAL PaoAc~ive DiayNOSric SERVICES, INC. 1) 2) Signed To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~~'~.';~"~~,~ ~~~ ~ ~ ~~Q~ Anchorage, AK 99518 Fax: (907) 245-8952 Leak Detection - WLD 23-Aug-09 18-02 EDE 50-029-20531-00 (~~~ ~~0-(3~ r~~CoG~ Date Print Name: - __ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : iii' , i ~,_ WEBSITE : '. i' __,_ `'? C'.Docmnent and Settings\Diane Williams\Desktop\Tcansmit_Conoco.docx ~ ~ y~I~,I L T,i~'~ ~I'~'L~~11,~~1II~('~<~~T ~'~o ~las~~a ~~il a~d ~as ~ons~rva~i~~ ~~~~. ~~$gri.; ~1lristi~~ l~ahn~cen 333 ~/V~s~~ 7Yh ~v~n~~, S~a~~~ 1 ~0 ~~cho~age, ~-'~laska 3950~ RE: Plug Setting lZecord: 1 B-02 ~uly 3 ~, ~009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1~-02 Digital Data in LAS format s~-~ ~, ~~>~;~ =i ~~ ~ ~r ~; - ~~jr~~r~ , ~. t .~,~~ ~ , _ c ~~ ~r 50-029-20531-00 1 CD Rom ~. ~ ~~v ~ [33 d~s3~5~ ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr~to@halliburton.com Date: ,~ I,~ ,~ ~ ~ ~~ ~ ~~ ~ Signed: / ~ ~~Y~ , 1B -02 (PTD# 180 -133) Report of Communication • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, July 28, 2009 1:43 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Seitz, Brian Subject: 1 B -02 (PTD# 180 -133) Report of TxIA Communication Attachments: 1 B -02 TIO Plot.pdf Jim /Tom /Guy, On 06/17/09, AOGCC granted permission to continue water only injection in the 1 B -02 well (PTD# 180 -133) based upon pressure performance while on water injection. CPAI originally reported TxIA communication while on MI injection on 05/06/09. Subsequent to your approval, the pressure performance while on water injection has degraded significantly. The well is currently shut in and we are preparing to diagnose the nature of the communication. Attached is an updated TIO plot. Martin «1B-02 TIO Plot.pdf» mer) JAN 2 0 201 r From: NSK Problem Well Supv Sent: Wednesday, May 06, 2009 10:20 AM To: 'Regg, James B (DOA)'; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Seitz, Brian Subject: 1B -02 (PTD# 180 -133) Report of Suspected TxIA Communication Jim/Tom, Kuparuk WAG injector 1 B -02 (PTD #180 -133) is suspected of having TxIA communication based upon recent frequent bleeds. The well is currently injecting MI, so ConocoPhillips plans to convert it to water injection for one week prior to starting wellwork. The well will be added to the monthly report and will be injected into as necessary to perform diagnostics. A leaking gaslift valve is suspected so slickline will troubleshoot and repair if possible. CPAI will submit a 10- 403 proposing repair if necessary or an application for administrative approval to continue injection. Attached is the wellbore schematic and 90 day TIO plot. « File: 1 B -02 Wellbore Schematic.pdf » « File: 1 B -02 TIO Plot.ppt » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/3/2011 Well Name 1 B -02 Notes: KLM Report End Date 8/1/2009 Days 120 Start Date 4/3/2009 Annular Communication Surveillance 4500 — — 160 _ WHP IAP 4000 - OAP — 140 WH 3500 U �' • - .A ■Alk 1 I — 120 3000 I - - 100 2500 ' LL co I a 2000 ► $111 80 0, ru I - —60 1500 1000 MALI -40 500 `, - 20 Vl� .— 0 �� ^ 0 Apr - 09 May -09 Jun -09 Jul -09 s000 —DGI • 6000 — 7000 .MGI o 6000 — .PWI 5 5000 - �SWI 0 5000 -'BLPD U 3000 2000 1000 Apr -09 May -09 Jun -09 Jul -09 Date ~ MEMORANDUM To: Jim Regg ~~~~ 7r~~/~ ~ P.I. Supervisor ~~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July O6, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 B-02 KUPARLJK RIV LTNTT 1B-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `~ Comm Well Name: KUPARUK RN iJNIT IB-02 Insp Num: mitJJ090706092339 Rel Insp Num: API Well Number: 50-029-20531-00-00 Permit Number: 180-133-0 ~ Inspector Name: Jeff Jones Inspection Date: 6/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~] 1B-0z Type Inj. W Z'~ 6109 jA 550 1730 1650 1630 / P.T.D 1801330 TypeTest SPT Test psi 152725 QA ' 40 30 30 30 Interval 4YRTST P~' P -~ Tubing 2250 2250 2250 2240 Notes: 2•8 BBLS diesel pumped. 1 well inspected; 2 bolts not properly engaged on tubing adapter, Mr. Colee will address these items. ~ ~ (>f~t~~~ '~ ~'N i_1" _~,~ F.. I l~ 1„[ ~; .~ ~ ` Monday, July 06, 2009 Page 1 of 1 1B-02 (PTD #180-133) Notice ~ntent to leave on water injection only. Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, June 17, 2009 11:05 AM To: 'NSK Problem Well Supv' Subject: FW: 1 B-02 (PTD #180-133) Notice of intent to leave on water injection only Jim Regg AOGCC ~ ~ , i t~ ~ t h~~!c 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Wednesday, June 17, 2009 11:04 AM To: 'NSK DHD Tech' Subject: RE: 1B-02 (PTD #180-133) Notice of intent to leave on water injection only Page 1 of 2 Looking that the TIO pressure data provided with monthly rpt, it appears IA pressure has stabilized in the 500-700 psi range. Continuing water injection only is appropriate -well should have AA to set operating limits (no MI) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK DHD Tech [mailto:n1656@conocophillips.com] Sent: Friday, May 22, 2009 5:12 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: 1B-02 (PTD #180-133) Notice of intent to leave on water injection only Jim, Kuparuk WAG injector 1 B-02 (PTD #180-133) is suspected of having T X IA communication when on MI based upon recent frequent bleeds. Since converting to water injection, well has passed a diagnostic MITIA on 5/11/09. It is ConocoPhillips intention to leave the well on water injection only and monitor for further signs of communication. Attached is the schematic and a 90 day TIO plot. Please let the Problem Well Supervisor if you have any questions. Ron Bates (DHD Tech) 6/17/2009 1B-02 (PTD #180-133) Notice ~ntent to leave on water injection only • Page 2 of 2 Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 «1 B-02.pdf» «1 B-02 90 day TIO plot.jpg» 6/17/2009 KRU 1 B-02 PTD 180-133 5/22/2009 TIO Pressures • • +~~ne~coPhillips Alaska,_~nc~~ •,~ M ~ PATCH (7683-7704, OD:2.765) TUBING (70257813, OD:3.500, ID2.992) ~~ ~.~ I~ I -_ i __ I - ~ - _~ - _. ----~ KRU 1 B-02 1 B-02 API: 500292053100 Well T e: INJ An le TS: 40 d 7468 SSSV T e: WRDP Ori Com letion: 1/11/1981 An le TD: 38 de 81 53 Annular Fluid: Last W/0: 2/1/1989 Rev Reason: Pull FRAC SLV & Plug, Set INJ VLV, TAG Reference Lo Ref Lo Date: Last U date: 8/14/2006 Last Ta : 7910' TD: 8153 ftKB Last Ta Date: 8/13/2006 Max Hole An le: 43 de 2600 Casin Strin -All Strin s Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 65.00 H-40 WELDED SURFACE 10.750 0 2933 2646 45.50 K-55 PRODUCTION 7.000 0 8113 6760 26.00 K-55 Tubirt Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7025 5910 9.20 J-55 BTC 3.500 7025 7813 6523 9.30 J-55 EUE 8RD Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7468 - 7524 6256 - 6299 C-4 C-3 O en 56 12 5/4/1981 IPERF 5" Geo Vann Gun 7529 - 7538 6303 - 6310 C-3 O en 9 12 5/4/1981 IPERF 5" Geo Vann Gun 7544 - 7553 6314 - 6321 C-2 O en 9 12 5/4/1981 IPERF 5" Geo Vann Gun 7558 - 7567 6325 - 6332 C-2 O en 9 12 5/4/1981 IPERF 5" Geo Vann Gun 7572 - 7579 6336 - 6341 C-2 O en 7 12 5/4/1981 IPERF 5" Geo Vann Gun 7597 - 7646 6355 - 6393 C-1 UNIT B O en 49 12 5/4/1981 IPERF 5" Geo Vann Gun 7652 - 7669 6397 - 6410 UNIT B O en 17 12 5/4/1981 IPERF 5" Geo Vann Gun 7863 - 7900 6562 - 6591 A-5 A-4 O en 37 12 5/4/1981 IPERF 5" Geo Vann Gun Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2834 2572 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 2 5169 4343 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 3 6276 5268 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 4 6895 5803 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 2/1/1989 5 7216 6062 Merla TPDX CAMCO DMY 1.5 T2 0.000 0 2/1/1989 In'ection MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 6 7314 6138 Otis LBX MAACO DMY 1.5 RM 0.000 0 2/14/2005 7 7386 6193 Otis LBX MAACO DMY 1.5 RM 0.000 0 2/14/2005 8 7458 6248 Otis LBX MAACO DMY 1.5 RM 0.000 0 2/14/2005 9 7694 6430 Otis LBX PATCH 1.5 0.000 0 11/23/1994 10 7767 6487 Otis LBX DMY 1.5 RM 0.000 0 1017/1994 Other. lu s, a ui .etc. -SLEEVE/PATC` H De th TVD T e Descri tion ID 7609 6364 PATCH Merla 21' Tb Patch' Set on 12/1/94 2.375 7683 6421 PATCH 21.5' Merla Tb Patch' Set on 11/20/94 2.375 7694 6430 NIP 0/94 AVA TPL NIPPLE inside Patch; Set on 11/2 2.310 Other plu s, __ a ui .,,etc. -COMPLETION De th TVD T e Descri tion ID 1838 1804 SSSV Otis TR-FMX. LOCKED OUT 9130/98 - NOTE: "BEWARE" SSSV FLAPPER IS BROKEN 2.813 1838 1804 VALVE 2.81" X-LOCK w/A-1 INJECTION VALVE 1" CHOKE, SN: HKS-238 set 8/13/2006 1.000 7227 6070 NIP Otis 'X' Selective Landin 2.813 7262 6098 PBR Baker 3.000 7277 6109 PKR Baker HB-1 RETR. 3.000 7595 6353 PKR Baker HB-1 RETR. 3.000 7788 6503 PKR Baker W/L Set PERM. 3.000 7805 6516 NIPPLE REDUCER AVA 2.75" X 1.81"; Set on 11/17/94 1.810 7805 6516 NIP Camco 'D' Ni le NO GO 2.750 7812 6522 SOS Baker 2.992 7813 6523 TTL 2.992 General Notes Date Note 9/10/1998 *BEWARE* SSSV FLAPPER HAS A PROBLEM • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~~r~~ V D r~AY ~ s 2ao9 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ 8S n~ p~NSSto Stimulate ^ 8S ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ //-- Waiver ^ Time Extensfa~O~~Q Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 180-133 / • 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20531-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 1 B-02 8. Property Designation: 10. Field/Pool(s): ADL 25648 - Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8153' feet true vertical 6792' , feet Plugs (measured) Effective Depth measured 8027' feet Junk (measured) true vertical 6692' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SURFACE 2893' 10-3/4" 2933' 2646' ""' "` ' -~ PRODUCTION 8073' 7" 8113' 6760' Perforation depth: Measured depth: 7468'-7896' ,~ ^.r °~~~~ true vertical depth: 6256'-6583' Tubing (size, grade, and measured depth) 3.5", J-55, 7813' MD. Packers &SSSV (type & measured depth) Baker HB-1 retriev. Pkrs (2), Baker permanent pkr @ 7276', 7594', 7788' Otis TR-FMC SSSV @ 1838' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1575 Subsequent to operation 1120 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service O Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 309-070 contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer Signature 7~ !~ .- Phone: 265-6471 Date (,~,, Pre ared b Sharon All u -Drake 263-4612 Form 10- 04 Revised 04/2006 ~ ,j~)iV (j ~ ~11'JQ' - ~--~` ~ . .J Submit Origina ly _,_ . _ ~ KUP 1 B-02 ` / ConoeoPhi~li(3s 1) welLAttnbutes _ __ _ Max Angle 8 MD jTD A4t41ta 11"h: wellbore API/UWI Fieltl Name Well Status Intl (`) MD (fiK6) I ,Act Btrn (ftKB) / 500292053100 'IKUPARUK RIVER UNIT INJECI ING 43.00 2,500.00 - 8,153.0 Comment H25 (ppm) (Date SSSV' LOCKED OUT 0 1/1/20 Annotation I~End Data KB-G rd (fi) Last WO: 2/1/1989 2848 09 Rig Release Data 1/11/1981 _rMLCarmg c1~42~4/30L2.04?11-t5:us ri _- ~ _ ~~ ~ . Ssi~ Apual HANGER, 22-- m ~ . A otation Depth (fiK8( End Dale 'Annotation L' s[ i ag. SLM 7,889 0 12131/2008 ,Rev Reas Ca51ng String$ ^--' . Last Mod By on ADJUST PATCH ID,'OU Imosbor D f 5 D hTVD St- VJi St' End Date 4/2812009 _ Str' T Thrd CONDUCTOR,_ 28-110 $AFETV VLV. - 1.838 GAS LIFT, 2,833 SURFACE, 29 2934 GAS LIFT. 6.t 88 GAS LIFT, __ 6,275 GAS LIFT, __ 6.894 GAS LIFT, 7.215 NIPPLE. 7.227 - PBR, 7.261 -- PACKER. 7.276 - -- INJECTION. 7.313 INJECTION. 7.386 INJECTION, ],69 IPERF. 7.468-7.524 IPERF. 7,529-7.538 IPERF, _ 7,544-],553 PERF. _ 7.558-].56] 7,572-7,519 PACKER. ].590 PATCH, ].605 IPERf, 7.557-7.646 PATCH. 7.617 PATCH, ].625 SQUEEZE, 7.468 IPERF, 7,652-7.669 INJECTION, _ 7,690 PATCH. 7,692- NIPPLE. 7,703 - PACKER, 7.]88 NIPPLE, ],805 -. NIP RDCR, 7,805 SOS. ].612 - APERF. _ 7.8667.896 - IPERF, _ ._ ].863].900 trig Descripton String 0... ~ String ID _. Top (ftKB) ,Set epth (... et ept ( ) ... i nng ... nng ... nng op 2 '. 28.5 110.0 ~ 110.0 65.00 H-40 WELDED 06 ~~ ~ D OR 16 n Desc ion i g p 0 ~ g g snin o... istrin 'TOp (ftKB) ~'ISet Depth (f... 'Set Depth (TVD) ... String Wt... String ... String Top Thrtl 4FACE 10 314 9.794 ' 28.8 '~ 2,933.9 ~ 2 h46.3 i 45.50 K-55 on 9 ',Strin 0... Sh6 9 9 5~... D p3h f... ''(Sat Depth (TVD)... String Wt... Top 247) Set ( String... Siring Top Thrd JDUC(ION 7 . i ' 5 ( 6 6,760 9 26 00 K-55 i bing Strings trig Description String O_. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 31NC ( ( 31/2 2.992 I 22.0 I 7,813.0 6,5224 9.20_- J-55-~_BTC ABMOD Impletion_De Top Depth tails_ _ ' __ ~' _ _ I (TVD) .Top Inc! (fiK8) (HK6) (°I '. ttem Descriptio n Comment -___ __ ID (ir _- 22.0 22.0 O.OOLHANGER ~ McEVOY TUBING HANGER 3.5( .837.7 1,803.9 '~ 28.171SAFETY VLV ~IOTIS TR-FMC (LOCKED OUT 9/30/1998) NOTE: ^BEWARE" SSSV 2.81 FLAPPER IS BROKEN j ,226.8 6,0714 4000 NIPPLE ~.OTIS'X'SELECTIVE LANDING NIPPLE - 12.81 _.._ ,260.6 6,097.2 40.00 PBR BAKER PBR 3.0C ,275.9 6,109.0 40.00 PACKER (BAKER HB-1 RETRIEVABLE PACKER 3.0C ~~ Oth ~~ yen 7 ', N~0 BLANK PIPE w/SEALED ANCHOR L 9 21' Tbg Patch; Set on 12/1/94 2.25' SIZE 287 PARAGON 2 RETRIEVABL L BORE PACKER Merle Tbg Patch TPL NIPPLE inside Patch NIPPLE REDUCER 2.75' X 1.81" I I De« I I (ftKB) Btm (ftKB(! (fiK8) (ftKB) Zone '. Date ~ is^~- ~ Type Comment _ 7 468 ~ 7 524 6,256.1 6,299.7 C-0, C-3. 16-02 5!4/1981 12 0 IPERF 5' Geo Vann Gun -CLOSED 7,529 7,538 6,303 41 6,310.2iC-3. 18-02 (5/411981 i 12.0 IPERF 5' Geo Vann Gun -CLOSED 7,544 7,553 6,314 7'~ 6,321.SC-2, 18-02 15/411981 112.0 IPERF 5' Geo Vann Gun -CLOSED 7,558 7,567 6,325.3 6, 332.11C-2. 18-02 5/411981 12.0 IPERF 5' Geo Vann Gun -CLOSED 7,572 7,579 6,335.9 6,341.2 C-2, iB-02 5/417981 12.0 IPERF 5' Geo Vann Gun -CLOSED 7,597 7,646 6,354.9 6,392.7 C-1, UNIT B, 5/4/1981 12.0 IPERF 5" Geo Vann Gun -CLOSED 1 B-02 7,652 ~ 7,669 6,397.3 6,410.4 UNIT 6, 16-02 5/411981 12.0 IPERF ~5' Geo Vann Gun 7,863 _ 7,900 6,562.1 6.591. S,A-5. A-0, 18-02 5/4/1981 12.0 IPERF _ ___- 5" Geo Vann Gun 7,866_ 7,896_ 6,564.5 6,588.3.A-5, A-4.18-02 4/5/2005 I 6.O APERF 111116"Power EJ merit S queez es Top DepN Blm Depth _ (TVD( RVDI (ftKB) Bim (ftKB( (ftKB) (ftKB) Description Start Data Comment 468.0 7,646.0 6.2.56 1'i 6,392.7iCement Squeeze _5/1 312 00 6 PUMPED 22.7 BBLS CE_ MENT ' tes; G End Date eneral & Safety Annotation -1 1989 NOTE- COMPLEI ION BELOW PBR (~ 7261' RUN 6/7/1985 WORKOVER /1998 NOTE: "BEWARE"'SSSV FLAPPER HASAPROBLEM 72009 NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 Mandrel Details ITop Depih Top _--- -_----- -- - Port _._ -._ - (NDI Intl OD Valve Latch Size ~ TRO Run (RKB) rin Top (fiK6) (°) Make Model (in) Serv Type Type (n) (psi( Run Date Com_._.. 1 2,833.2 2,570.9 41.50 CAMCO KBUG 1 GAS LIFT DMY 8K 0.000' 0.0 2/111989 2 5,168.1 4,342.4 39.65 CAMCOI KBUG 1 GAS LIFT DMY BK 1 0-000 0.0 2/1/1989 3 6,2750 5,266.6 26.12 CAMCOI IKBUG 1 GAS LIFT DMY BK 1 0.000 0.0 2/1/1989 5,802.9 4 6,894.4 33.89 CAMCO KBUG 1 GAS LIFT ( DMY BK 0.000 0.0 21/1989 5 7,215.5 6,062.7 40.00 MERLA TPDX 1 1/2 GAS LIFT DMY T2 0.000 0.0 2/1!1989 6 7,313.4 6,137.6 40.00( 07(5 LBX 11/2 INJ DMY RM 0.000 0.0 12/18/2008 7 7,385.9 B, 193.2 40.OO+ OTIS LBX 11Y2 INJ DMY RM 0.000 0.012/18/2008 8 7,4570 6,247.7 40.OOI OTIS LBX 11/2 1NJ DMY RM 0.500 I 003/2/2009 9 7,6935 6,429.4 39.05 OTIS LBX 11/2 1NJ Patch J 0.000 00,~11/23/1994 10 7,7674 6,487.0 38.49 07(5 LBX 11/2 1NJ DMY RM 10.000 00(10/7/1994 PRODUCTION, _ 258,116 \ TD, 8,153 ~ 1 B-02 Well Work Summary DATE SUMMARY 3/2/09 PULLED A-1 INJ VALVE ON " X-LOCK @ 1838' RKB. PULLED HFC~ (MINIMAL EROSION) AND SET DV @ 7457' RKB. BRUSHED AND FLUSHED PATCHES AND TAGGED NIPPLE REDUCER 7805' RKB. IN PROGRESS. 3/3/09 LOGGED CALIPER SURVEY FROM 7805' RKB TO SURFACE. RECOVERED GOOD DATA. RESET A-1 INJ VALVE (1" CK BEAN) ON 2.813" X-LOCK Cad 1838'. RKB. COMPLETE. 4/22/09 PULLED Al INJECTION VALVE ON 3-1/2" X LOCK 1838' RKB. WELL SHUT-IN & FREEZE-PROTECTED, READY FOR E/L SET PATCH. 4/25/09 SET TTS 2.25" SIZE 287 PARAGON 2 RETRIEVABLE DUAL SEAL BORE PACKER. UPPER PACKER CENTER OF ELEMENT SET AT 7628' IN THE MIDDLE OF 21' MERLA PATCH. ATTEMPT TO SET INFLATABLE PACKER FAILED. S/L WILL SET TOP SECTION OF PATCH. 4/26/09 SET UPPER TTS PACKER SPACER PIPE, SNAP LATCH SEAL (20.13' OAL. MIN ID 1.25"). PKR TOP ~ 7606 RK6. PUMP UP TBG TO SET LOWER INFLATABLE PKR. .TE~~T TAO 3500 PSI BEFORE BULL PLUG SHEARED. SET 3-1/2" A-1 INJ VALVI~ONX=C~C1~~6A~'f"BEA1~S7f~TJ~~$ @ 1838' RKB. COMPLETE. 5/4/09 AC EVAL, T-POT (PASSED ), T-PPPOT (PASSED ) 5/11/09 MITIA -PASSED, MITOA -PASSED, (AC EVAL) 1B-02 (PTD# 180-133) Report o~uspected TxIA Communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, May 06, 2009 10:20 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Well Integrity Proj; NSK Probiem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Seitz, Brian Subject: 1 B-02 (PTD# 180-133) Report of Suspected TxIA Communication Attachments: 1 B-02 Wellbore Schematic.pdf; 16-02 TIO Plot.ppt Jim/Tom, Kuparuk WAG injector 1 B-02 (PTD#180-133) is suspected of having TxIA communication based upon recent frequent~bl_eeds. The well is currently injecting MI, so ConocoPhillips plans to convert it to water inlection for one week prior to starting weliwork. The well will be added to the monthly report and w'iil be injected into as necessary to perform diagnostics. A leaking gaslift valve is suspected so slickiine will troubleshoot and repair if possible. CPAI will submit a 10-403 proposing repa~r i necessary or an application for administrative approval to continue injection. Attached is the wellbore schematic and 90 day TIO plot. «1 B-02 Wellbore Schematic.pdf» «1 B-02 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers ~;.:.~ i ~~~a`~ `~`~ -.' ~`~~:~" Problem Wells Supervisor ConocoPhillips Alaska inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 8/6/2009 ~/b (~9 f'%D I ~ ~ - ~ 3 -~ CHOKE FTP FTT iaP oaP TIIIC~ Plot -1 B-02 Zoo 4000 3000 .......... ...................................................... .................. ............................. . .... .................... ........ .............................. ........ ... . _. ~ ... .............. '~~' ~`` . . - 150 } f _- - _ _, - --- _ _ ~ ~ , -~ v - , r~~ ~ , , I I ` . ~, ; I I I a I I I ~ I ' '~ `W r a 2000 .....~I. .~~ .......... .. .......~.. .................................. _ ............................................ 100 Y I i ~ I ~ ~ v I I 4~ r. I I ( I i ~ `, ~ ~. i i ~ i 1000 i ~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .I . . . . . . . . . ~~ . .~'. . . t''S . . . . . . . . . .......... , , ( ~.= 50 ~ i i 0 i ~ 0 06-Feb-09 19-Feb-09 04-Mar-09 17-Mar-09 30-Mar-09 12-Apr-09 25-Apr-09 Date ~ ~ J , _ ,~ KUP ~ 1B-02 Cc~nt~coF~t~tlips e~~~i~~ ~ . s ; , , ~i ~ } .~ ~ ; ~ = Y ~--~ ;~ ~~ 6': ~~ ~= T = ~ ~~~. ~~~ Wellbore API/UWI Fleltl Name Well Status Incl (°) MD (itKB) Act Btrn (kKB) 500292053100 KUPARUK RIVER UNIT INJECTING 43.00 2,500.00 8,153.0 Comment H25 (ppm) Date Annorotion End Data KB-Grd (it) Rip Raleasa Date SSSV: LOCKED OUT 0 1/1I2009 Last WO: 2!1/1989 28.48 1/11l1981 ~~~ z ~:~ ~~. ~ Anmfation DepM (kKB) End Dab Annotation Last Motl By ~ End Dah Last Tag: SLM 7,869.0 12131/2008 Rev Reason: ADJUST PATCH IDIOD Imosbor 4I28I2009 . . .. . . ~jB~ ~ ~ L ;-~Ii~t~' ~ t ~ ..~. :~i t:. ~fia ' . x~'~ ,~t °';. .LL _ a .,-n~X ~: . "~ I i ~ HANGER~22 ~.: „~ .~ Casinp Description String 0... SVing ID ._ _ _. __ bR Top (RKB) Set Depth (f... Set Depth (TVU) ... String Wt... SMng ... String Top Thrd ~ " CONQUCTOR 16 15.062 28.5 110.0 110.0 65.00 H-40 WELDED . .. __._. Caaing Description String 0... Slring 10 ._ Top (ftKB) Set Depth (f... S et Depth (TVD) ... String Wt... String ... SMing Top Thrd ~ SURFACE 103/4 9.794 28.8 2,933.9 2,646.3 45.50 K-55 j IJ'~; Casing DascrlONon String 0... Stdnp ID ... Top (ttKB) Set Depth (f... Set Depth (ND) ... SUing WA.. String ... Stdng Top Thrd PRODUCTION 7 6.151 24.7 8,113.5 6,760.9 26.00 K-55 "~"EI~l~fl .'u~~C1 $ - ~3.. ~ _ ` ~ ~ °=-3 ~ r d i ,~ r' _ ~o~ ~t r F ° = .a i v ~ ` "+sr- ,i~;~ ~:-_ , w~i u r~-~== CONDUCTOR, ,5 Tubine Description Strinp 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (7VD) _. 9Mng Wt... String ... String Top Thrd 2e-iio TUBING 3112 2.992 22.0 7,813.0 6,522.4 920 J-55 BTCABMOD BAFETYVLV. ~ °°4 '~ ~_ Id - I 1 9f ~; - IN II ~ 11~1~' r ~ ., s~7V d ,c- ~ , i~ . _ ~~ "' :; ~HC ~@~~Q~ ~ ~~~~ '? ~ `~: ~ ' y :- ~ ~ I #2` 1.898 . . . . ..~ .. ... __.. . ~ E . ,~ • , Top Depth GAS uFT, 2,aaa - = (N~) Top Incl Top (ftK8) (ftKe) (') Imm Deacription Comment ID in) 22.0 22.0 0.00 HANGER McEVOV TUBING HANGER 3.500 SURFACE - ~.83~.~ 1,803.9 28.17 SAFETY VLV OTIS TR-FMC (LOCKED OUT 9I30I1998) NOTE: "BEWARE" SSSV 2.813 , ze-z,eaa -- FLAPPER IS BROKEN GASLIFT, 5 168 ~,ZZB.B 6,071.4 40.OO NIPPLE OT~S'X'SELECTIVELANDINGNIPPLE ~ 2.813 , 7,260.6 6,097.2 40.00 PBR BAKER PBR 3.000 GASLIFT, 8,275 _ ],'j~S.J 6,109.0 40.00 PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 - 7,594.2 6,352.8 40.06 PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 GASLIFT, - ] ~$~ J 6 503 1 38 34 PACKER BAKERWIRELINESETPERMANENTPACKER 3.000 fi,884 ~ , , . . 7,605.0 6,516.1 37.50 NIPPLE CAMCO'D' NO GO NIPPLE 2.720 ''"~ 7,812.1 6,521.7 37.50 SOS BAKER SHEAR OUT 2.992 QAS LIFT, 7,215 : •A~y [ ~1.FI@r~3~~. ~. ` ~! ~~~ • b .~ ~1~, . ~~v y y~. p {~.. ~ ~fu xi ~ $' ~ ~~{R ~4Ye . A~ ~ ~ ._ .vi~. , . - ~.i I~ "x'i . Top Depth NIPPLE. 7.247 - Top (kKB) (TV~) ToP Intl (~~B) (°) Dascription Comment Run Date ID (In) - 7,605 6,361.3 39.77 PATCH 272" TTS RETRIEVABLE PACKER, MID ELEMENT @ 4/26I2009 1.625 PBR, 7,P61 7607, N-80 BLANK PIPE w/SEALED ANCHOR LATCH 7,617 6,370.5 39.62 PATCH MeAa 21' Tbg Patch; Set on 12/1194 1211/7994 2.375 PACKER, 7,27fi .. :..... 7,625 6,376.6 39.56 PATCH TTS 2.25" SIZE 287 PARAGON 2 RETRIEVABLE DUAL 4I25/2009 1.100 . -!;;;~ SEAL BORE PACKER~ . IWECTION, 7,313 ~~6Q2 6,428.2 39.06 PATCH 21.5' Merla Tbg Patch 11I2011994 2.375 INJEC 10 - 7,703 6,436.7 38.98 NIPPLE AVA TPL NIPPLE inside Patch 11I2011994 2260 7 6 7,805 6,516.1 37.50 NIP RDCR AVA NIPPLE REDUCER 2.75' X 1.81" 11I1711994 1.81D INJECTION. ' ~6~ P{~~~ f~~~~r ..~~ ~~I.pi "kG~' ~ i~ _ `r~i. ~ I ~=~ ~~~ . ~ 4 _~ i~4 ~~ ~ Ijd7ra~~`~~. 7,45] ' 9hot Top (TVD) Btm (ND) Pens iPERF, _ Top (itKB) Btm (kKB) (ftK6) (kKB) Zone Date (ih°~ Typa Comment ~,aea-~,szn . 7,q68 7,524 fi,256.1 6,299.7 C-4, C-3, 18-02 Sl4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED IPERF, 7 52H 7 538 ~,SZ9 7,536 6,303.4 6,3102 C-3,1B-02 5/4/1981 12.O IPERF 5"GeoVannGun-CLOSED , - , ~ 7,544 7,553 6,314.7 6,321.5 G2, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED iPeRF, ~ s~a-~ ssa 7,558 7,567 6,325.3 6,332.1 G2, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED , , . i 7,572 7,579 6,335.9 6,341.2 C-2, 18-02 5/4/1981 12.0 IPERF 5" Geo Vann Gun - CLOSED iPERF, ••°•;: '~ ~~.:' -~ 7,597 7,646 6,354.9 6,392.~ C-1, UNIT B, 5/4/1981 12.0 IPERF 5" Geo Vann Gun-CLOSED 7,558-7,587 = ~B QZ ~ iaeRF, 7 572-7 579 ~`~ 7,652 7,669 6,397.3 ~ 6,410.4 UNIT B, 1B-02 5/4/1981 12.0 IPERF 5" Geo Yann Gun , . 7,863 7,900 6,562.1 6,591.5 A-5, A-4, 18-02 ~ 5/4/1981 12.0 IPERF 5" Geo Vann Gun 7,866 7,896 6,564.5 6,588.3 A-5, A-4, 1B-02 4/SI2005 6.0 APERF 1 11/16' Power EJ PACKER, ],584 BRI - f~~ r a ~ 7._ ~ e- ~ c`~~ P, ,i - ~ ~~.; zy - ~~ Top Depth Btm DepM - (TVD) (ND) PA7CH, 7,805 Top ((tKB) Btm (ftKB) (~B) (kK8) Descrtptlon Start Date Comment IPERF, 7,597-7,648 ' '],Q6$.O 7,646.0 6,256.1 6,392.7 Cement S ueeze 4 5/13I2006 PUMPED 22.7 BBLS CEMENT PATCH. 7,fi17 ~ ~, ~ ~ •:~ ~$~~ ~ ~,. ~ ,: ~P ~i 5 ~:' n ~ P ~ "y i F 5 ~" ~° ,t^ ~ r( '~.a ~~ .ti: ~ ~ - ~ s v ° ~~ . . -' .. PATCM, 7,625 ~ . .g End D . ate _ . Anno . ~ . . ~ . - tetion ' ' 2l1/1989 NOTE: COMPLETION BELOW PBR Q 7261' RUN 6/7I1985 WORKOVER S~UEE2E, :;`~~ ~,ase .....: , 9~~OI'IJJS NOTE: "BEWARE" SSSV FLAPPER HAS A PROBLEM D172009 ~ NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 IPERF, 7,852~7,669 INJECTION, - 7.fi94 PATCH, 7,692 NIPPLE.7~703 ~~~~ ~ " ~ it~W((~`a _ ~ 3~ ` s::ii ~~'~:_.a - 9 _-''F4.1~ tia~P"Iii.. '. a v ° x_i , , .,-.. : ...__ .-. q: Top DeOth To0 Port (NC) Incl OD Valve Lafch $~ie TRO Run ~ Stn Top (ftK8) (~8) (°) Maka Model (~~) Sarv Type Type (~N (psi) Run Dab Com... INJECTION, - ~ 2 833 2 2 570 9 41 50 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 D.0 2/1I1989 7,78] , . , . . " 2 5,168.1 4,342.4 39.65 CAMCO KBUG t GAS LIFT DMY BK 0.000 0.0 2It11989 PACKER, 7,]88 3 6,275.0 5,266.6 26.12 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7Jt11989 ~ NIPPLE, 7.805 NIP ftDCR, 4 6,894.4 5,802.9 33.89 CAMCO KBUG t GAS LIFT DMY BK 0.000 0.0 7J1/1989 ~,eos 5 7,215.5 6,062.7 40.00 MERLA TPDX 1 1/2 GAS LIFT DMY T2 0.000 0.0 7J1/1989 - 6 7,313.4 6,137.6 40.00 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 12I18l2008 sos, ~,aiz 7 7,3g5.9 6,1932 40.00 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 iZiS12008 8 7 457 0 6 247 7 40 00 OTIS LBX 1 1/2 INJ DMY RM 0.500 0.0 3/2/2009 APERF, , . , . . ~,ess-i,e9s 9 7 693 5 6 429 4 39 05 OTIS LBX 1 1/2 INJ Patch 0.000 0.0 11123/1994 IPERF, . . , . . 7,8fi3-7,900 10 7,767.4 6,487.0 38.49 OTIS LBX 1 1/2 INJ DMV RM 0.000 0.0 101711994 PRODUCTION, 25-8,114 TD,8,153 ~ ~ V V~~~ ~6~ T.4/USfI/I/T7".4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/men Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C 4 ~^ ~,a[~~3 Anchorage, AK 99518 '~~'~'~~ ~~~ ~ µ Fax (907] 245-8952 1) Caliper Report 02-Mar09 1 D-128 1 Report / EDE 50029-2290000 T2) Caliper Report 03-Mar-09 18.02 1 Report/E~ 50]29-20531-0Oq ;.-. -~ - ~" ~~ J Signed : ~~ (;' 1' ; 1. ~; = Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~~?~~3:~~~ ~~ Cc7! ~:'33's?d;~~~.:~~ WEBSITE:tit'~~'~V,t:I~,T,~Y'is~C.~~~§73 ~~., C:\Documettts and Settings\Owner\Desktop\Ttansmit_Co~noco.docx • • Memory Multi-Finger Caliper Log Resutts Summary Company: ConocoPhillips Alaska, Inc. Well: 16-02 Log Date: March 3, 2009 Field: Kuparuk Log No.: 10545 State: Alaska Run No.: 1 AP! No.: 50-029-20531-00 Pipet Dese.: 3.5° 9.2 Ib. J-55 BTC AB-MOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 7,794 Ft. (Mph Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the top of the Mersa TBG Patch ~ 7,892' (Orilier's Depth). This log was run to verify the condition of the tubing before making a final decision to patch. The caliper recordings indicate that the 3.5" tubing appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. A 3-D log plot of the caliper recordings across the Merla TBG Patch where an (PROF (1-04-09) detected a leak is included in this report. MAXIMUM RECORDED WALL PENETRATIONS ' No significant wall penetrations (> 18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 3°/6) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant LD. restrictions are recorded. K ~ 1, ~ ~ A.~~ '~' ~~ 431.s~`~' 1~D~e. - i I ' Field Engineer: G. Erherton Analyst: C. Wa/drap 1N~dness: C. Fitzpatrick ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281} ar (888} 565-9085 Fax: (281) 565-1369 E-maN; PDS~'memorylog.com ' Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk ~ ° .~ Well : 1 B-02 Date : March 3, 2009 ' Description : Detail of Caliper Recordings Across Merla Patch Where (PROF (1-0409) Detected a Leak o° so• ~so° 2~0° o° • • 7550 Pup Jt 7560 Pup Jt 7570 7580 Joint 243 7590 Baker HB-1 Packer 7600 Joint 244 (Partial) 7610 7620 Merla TBG Patch Leak petected in (1-04-09) 7630 IPROF 7640 Joint 245 7650 7660 7670 i i Joint 246 ~~, 7680 i Joint 247 • .. ;~: y ,T _. ~ . <.~. Merla TBG 7700 Patch (Covering INJ MDRL 9) 7710 7720 Joint 248 7730 7740 7750 Joint 248 7760 7770 INJ MDRL 10 7780 Pup Jt Baker Perm. 7790 Packer Nominal ID (1/1000 in.) 2200 3700° Min ID (1/1000 in.) 2200 3700 Comments Depth Max. Pen. (%) Max ID (1/1000 in.) 3-D Log Image Map 1ft:170k 0 100 X200 3700 ~ 0° 0° 90° 180° 270° 0° • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (5.8' - 7786.2') Well: 18-02 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: March 3, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 10 749 1513 2299 GLM 1 3077 O 3841 ii c s a a~ 4611 ~ GLM 2 5387 GLM 3 6151 GLM 4 6929 GLM 5 I~ INJ 10 249.3 7786 0 5 0 1 00 Damage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 249.3 1 25 50 75 100 `w ~ 125 Z c ° 150 175 200 225 • • PDS Report Overview ~~~~ sµ Body Region Analysis Well: 1 B-02 Survey Date: March 3, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 f -55 BTC AB-MOD 2.992 ins 3.756 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°k wall) ~ penetration body ,~ metal loss body 200 150 100 50 0 0 to 1 to 10 ro 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d rotal = 257 pens. 54 194 9 loss 156 101 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 IN) 8 INI 10 Bottom of Survey = 249.3 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 B-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: Mardi 3, 2009 Joint No. Jt. Depth (Ft.) I'en. I11riet (In:.i Pen. Body (Ins.) Nc>n. °o Metal I os, °~~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 u 0.01 4 I 2. 3 PUP 1 10 ~) .02 9 .93 1.1 41 a 0.01 ~' I .92 PUP 2 44 a 0.0 1 U 2.88 74 t) 0.01 ' I 2.9 4 10 U 0. 1 ' .9 5 136 a 0.01 ? I 2.96 6 167 U .00 1 ~) 2 92 7 19 U 1 t) 2.93 8 2 7 t) 0.00 1 t) 2.93 9 5 t) 0. 1 2 2.9 10 91 U .01 2 .90 11 3 1 U 0.01 4 .93 12 35 l) .01 I 2.9 13 381 U 0.01 _' I 2.93 14 412 t) 0.01 _' I 2.95 15 443 t) 0 O1 ~ ~ ~ 2.90 16 474 U 0.02 ~> ' 90 17 504 U 0.01 1 I .9 18 5 4 ~! 0.0 1 t) 2. 2 19 565 O 0. 1 2 2. 4 20 595 c) 0.01 1 .9 21 625 t) 0.01 ? 1 2.93 22 657 ~? 0.01 2 I 2.90 7 t) .01 2 93 24 718 l) 0.00 1 n 2.95 25 749 U 0. 0 1 I 0 26 780 U 0.00 Z I 2.94 2 7 81 t 1 .04 1 i 2.92 28 841 l) 0.01 1 2.92 29 870 (1 0.01 ~ 1 2.90 30 900 U 0.01 ~ I 2.93 931 O 0.01 2 2.94 32 962 U 0.01 2 2.89 33 991 U 0.00 1 I .9 34 1021 U 0.00 1 I 2.96 35 0 1 t) 0.00 I ~ ~ .94 36 1081 r ~ 0.00 1 U 2.89 37 12 a 0.01 ' ' 2.94 38 1143 ~) 0.01 2 2.92 39 1 7 i ~ 0.03 12 ' 2.93 40 1207 t) 0.01 2 I 2.94 41 237 t) 0.01 5 .95 42 1269 U 0.00 1 (~ 2.96 43 300 a 0. 2 1 2 91 44 1331 a 0.01 2 I 2.93 45 1361 l) 0.01 ? 1 2.91 46 1392 i) 0.02 ~) 2.92 47 1421 ~ ? 0.01 1 ~ ~ 2.93 48 1452 ? 0.01 _' 2.93 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 B-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 3, 2009 Joint No. Jt. Depth (Ft.) I'c~n. l ll,~c~i Un..? Pen. Body (Ins.) Pc~n. °6 ~1c~t,il I use ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1483 ~? 0.01 ? 1 2.9 15 3 ~? 0.00 1 ~? 2.91 51 154 (? 0.00 1 U .96 52 1 74 ~ ~ 0.01 _' 1 2.91 53 1604 ~? 0.00 I u 2.9 54 1635 ~? 1 ~ i 2. 6 5 16 5 U 0.00 I .93 56 1695 ~? 0.0 1 ~ ~ .90 57 172 U 0.00 1 ~~ .94 8 1756 t? 0.00 1 U 2.93 59 1788 U 0. 1 U 2. 3 59.1 818 U 0. 4 1 E3 2. P P 59.2 1829 c) 0 U i? .81 X-Lock 3.5" A- In'ection Valve 9. 1 3 ~? 0.00 1 ~? .93 P 6 1 39 a 0.00 1 I .94 61 1870 ~ ? .01 ' ' .9 62 1900 ~ ? 0.01 2 _' .91 63 192 9 U 0.0 2 I 2 91 64 19 8 U 001 2 1 5 65 1 9 ~~ 0.00 1 1 3 66 202 a 0.00 2 I .96 67 205 (? 0.00 1 1 2. 1 6 2083 ~) 0.01 2 2.94 69 2114 ~? 0.00 1 l? 2.94 14 U 0 1 ~) .94 71 2176 U 0.00 1 u 2.96 72 2 06 U 0.00 1 1 2.91 73 2237 U 0.01 4 ? 2.96 7 68 a 0.00 1 u 2. 1 75 2299 n 0.00 1 u 2.92 76 2330 ~? 0.00 1 I .92 77 2361 ~~ 0.01 2 .' 2.91 78 2 90 ~? 0.00 1 u .94 79 2421 a 0.01 Z I 2.93 80 2 5 ~? 0. 1 2 ' .9 81 2482 a 0.00 1 I 2.93 82 25 4 ~? 0 01 z 1 .9 83 2545 ~ ? 0.01 2 I 2.94 84 2576 a 0.00 2 I .95 85 2608 t~ 0.01 Z ' 2.91 86 2 39 U 0.01 3 I .92 87 2669 U 0.01 2 1 2.93 88 2699 ~) 0.01 2 .96 89 2731 ~? 0.01 2 ~' 2.88 0 2762 a 0.01 2 Z 2.92 91 2792 ~? 0.01 2 1 2.91 91.1 823 t? 0 U U N G 1 atch ~ 6:30 92 2829 U 0.01 Z I 2.93 93 859 ~? 0.03 11 5 94 2891 ~? 0.01 _' I 2.92 _ Penetration Body Metal loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf J-55 BTC AB•MOD Well: Body Wall: 0.254 in field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~ LATI O N SHEET 16-02 Kuparuk ConocoPhillips Alaska, Inc USA March 3, 2009 Joint No. Jt. Depth (ft) Pcrn. Ul~~~~t (In..) Pen. Body (Ins.) Pcn. °/, Mc~t,rl I (ass `i~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2922 t) 0.00 1 (J 2.92 96 2954 t) 0.01 4 1 2.93 7 2 85 U 0.00 1 (l 8 3 15 U 0.01 2 .92 99 3046 U 0.01 2 2.93 100 3 77 U 0.01 Z 1 291 101 3106 a 0.00 1 (? 2.93 102 3137 tJ 0.01 Z I 2.93 1 3 3168 (( 0. 1 ' I .91 104 3199 U 0.00 1 r J .89 10 3 29 U .01 ' 2.90 106 3260 1 1 0. 3 l U ~ 2.93 1 7 3290 ~J 0.01 ? 2.96 10 33 1 l) .01 ' I 2.89 109 3351 U 0.01 ~' I .95 110 3382 t) .O1 ~ 2. 11 3414 U 0.01 2 I .93 112 3446 U 0.01 2 91 11 3476 ll 0.01 2 .91 114 3505 O 0.0 1 r r 2.9 115 3 7 U 0.0 t3 .9 116 3568 U 0. 1 Z ~' 91 117 3599 U 0.00 2 I 2.93 118 3627 O 0.00 1 I 2.93 11 6 8 i? 0 2 7 ' 120 3689 O 0.01 2 I 2.92 121 3718 U 0.0 1 tJ 2.93 122 3749 tt 0.00 1 U 2.90 1 3 3780 ll .0 ~ I .9 124 3811 lJ 0.01 2 ll 2.91 125 3841 O 0.01 ~ I .95 126 3872 (J 0.01 ? I 2.91 1 7 3903 t) 1 2 I .91 128 3934 !) 0.02 9 _' 2.92 129 3965 t~ 0. 1 Z ? 2.9 130 3995 (~ 0.00 1 (1 2.92 1 402 7 t) 0. 1 , 132 4058 (J 0.01 ~' I 2.90 133 4089 U .0 5 2.92 134 4120 U 0.01 2 I 2.92 5 4151 c) 0.01 2 ;' 2.93 136 4181 U 0.01 2 1 2.95 13 4213 U 0.01 Z I .91 138 4241 C) 0.01 ? I 2.93 39 4273 U .00 I r) .9 140 4304 t J 0.01 ~' ~ ~ 2.90 141 4334 U 0 0 5 I 2.91 142 4365 a 0.00 1 u 2.95 14 4396 ~ ~ 0.01 1 .91 144 442 6 0.00 ~ I 2.91 _ Penetration Body Metal Loss Body Page 3 PD~EPORT OINT TABULATION ~EET 1 ' Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 B-02 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 3, 2009 Joint No. Jt. Depth (Ft) I'~~n. Ul~u~t (Ins.l Pen. Body (Ins.) I'c~n. °~~ ~Vc~t.il I rx5 ",~~ Min. LD- (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4457 a 0.0 ? I 2.9 14b 4487 i I 0.01 ~' I 2.91 147 451 U 0.0 1 i) 2.91 148 45 8 i ~ 0.0 t3 2.96 149 45 0 l) 0.0 I ~.~ 2.91 15 461 a 0. 0 1 ~~ .93 15 4 4 i ~ 0.02 7 2.92 152 4673 a 0.01 2 .91 153 4701 U 0. 0 1 tl 2.95 154 4733 it 0.01 2 Z 2.91 155 4764 t ~ 0.01 2 ~' 2.91 1 6 793 U 0 00 1 t1 2.92 157 4825 it 0.01 2 1 2.90 158 48 5 l ~ 0.00 2 1 2.91 159 4885 i ~ 0. 1 2 I 2.90 160 4917 (~ 1 2 2.9 161 4948 i I 0.01 ~ I 2.91 162 4979 u 0 0 1 ~ .95 163 011 (~ 0.01 2 ~_' .91 164 5041 U 0.01 Z I 2.93 165 507 a 0.01 2 I 2. 16 5101 U 0.00 Z 1 2.92 167 5133 i ~ 0.02 ~) I 2.91 167.1 5163 i~ 0 U i? N A GLM 2 Latch ®9:00 8 1 U .01 4 .9 169 5200 c~ 0.01 4 _' 2.91 170 5 3 U 0.01 4 2 2.9 171 5263 U 0.01 1 2.91 1 2 5294 U 0.00 1 i) 2.92 173 5325 a 0.01 2.91 174 53 i? 0.0 ' 2.93 175 5387 t~ 0.01 Z 2.90 176 5417 U 0.00 I U 2.89 177 5 7 U 0.01 2 1 2.90 178 5479 U 0.00 1 1 2.91 179 5510 U 0.01 Z I 2.95 180 5541 ~ ~ 0 01 ? I 2.91 181 5569 t I 0.00 1 1 2.94 1 5601 i ~ 0.00 1 U 2.92 183 5631 U 0.01 4 ~' 2.91 184 566 i 1 0.0 ' I 2. 2 185 5694 U 0.00 2 I 2.92 18 5725 a 0.01 Z I 2.92 187 5753 a 0.02 t3 2.95 188 5784 u 1 ~ .9 189 5816 l) 0.01 ~' .92 19 847 i I 0.00 I 2. 3 191 5877 t1 0.01 1 1 2.91 1 2 590 t I 0.01 2. 193 5938 i ~ 0.00 I ~ ~ 2.91 Penetration Body Metal loss Body Page 4 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 B-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 3, 2009 Joint No. Jt. Depth (Ft.) I'en. l llzset (Ins.) Pen. Body (Ins.) Nc~n. `% Metal I ~~s~ .~ Min. LD• (Ins.) Comments Uamage Profile (%wall) 0 50 100 94 596 U 0.00 I I 2.93 195 997 ~t 0.01 ~ I 2.9 196 60 7 ~~ 0. 1 Z I 2. 1 197 60 7 I t 0.01 _' 1 2 9 198 088 a 0.02 ~t 1 2. 9 199 120 ~ t 0.01 I 2.88 200 6151 I t 0.01 5 1 2.90 201 6 8 (t 0.01 ~ ' 2.90 202 6 12 ~t 0.01 3 ? 2.9 203 6241 tt 0.0 2 ? .93 203.1 6 72 ~? 0 U u N G M Latch ~ 5:00 204 6 79 a 0.02 £3 ! 2.90 205 6310 ~ t 0.01 ~' U 2 6 6341 ~ t 0.01 3 2. 0 07 6372 n 0. 1 Z ~t .94 20 6404 ~ t 0.01 9 209 6434 ~t 0.01 Z 1 2.93 10 6465 a 0.02 8 ' 91 211 64 3 n 0.03 ttt ~' 2.93 12 6 24 tt 0.01 ~ 1 2.94 213 65 6 U 0, ' 1 2.9 214 65 7 U 0.02 2.89 215 6617 tt .O1 Z 1 2.91 216 6649 U 0.01 5 2.93 17 66 U 0.0 -t 8 218 6710 U 0.01 2 I 2.91 19 740 t) 0. 1 2 2. 220 6771 U 0.01 Z 2.92 221 6800 U 0 01 -~ ~ 2.9 222 6832 a 0.01 2 ? 2.93 23 6862 a 0.01 5 2.92 223.1 6892 It 0 U n N A GLM 4 atch ~ 12:30 224 898 a 0.01 5 2. 0 225 6929 a 0.01 s _' 2.93 226 6960 ~l 0.02 9 I 2 90 227 6991 U 0.01 4 _' 2.91 228 7022 U 0. 2 4 U L e s't . 229 7051 a 0.02 ~~ I 2.86 230 7083 ~t 0.0 - I 2.87 231 7116 ~ t 0.02 ~t I 2.85 232 7148 c1 .0 t3 1 2. 3 233 7181 n 0.03 1O 2.87 233. 7214 U l~ U N G 5 La h~ 1 :00 233.2 7222 ~t 0.02 9 _' 2.88 PUP 233.3 7225 U 0 U I) 2.81 O 's X-Ni le 234 7227 U 0.00 1 1 2.92 234.1 258 O 0 l) U 3.00 Baker PBR 234.2 7272 ~t 0 U u 3.00 Baker HB-1 Retrievable Packer 235 7281 0.0 9 u .85 35.1 731 3 0 tt it N A In'ection Mandrel 6 Latch @ 9:00 Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 B-02 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 3, 2009 Joint No. Jt. Depth (Ft) I'~~n. Ulsc~i (In..) Pen. Body (Ins.) I'c~n. °/, Metal I ntis ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 236 7322 U 0.0 I ti i ~ 2.83 237 7353 ~~ 0.02 ~) I 2.89 371 7385 ~~ 0 0 u N A In'ec'on Ma rel 7 tch 10:3 2 8 7 94 a 0.03 I I 2.90 23 7426 a 0.02 ~) ' .8 39.1 7457 U 0 0 u N A I 'ectio Mandrel 8 tch 12: 40 7465 a 0.02 8 2.92 1 7497 ~~ 0.03 I1 85 42 7524 l) 0.01 ' _' 2.89 24 .1 7554 ~~ 0.02 tt .93 PUP 42.2 7561 l~ 0.04 I.3 I 2.93 PU 43 7571 ~) 0.01 4 ~ .94 4 .1 7594 ~ ~ 0 l1 ~) 3.00 er B-1 Retr'ev ble Packer 44 7601 ~ ~ 0.01 4 ~' 2.93 244.1 7616 i ~ 0 U t ~ 2.38 erla ' T G Patch 245 7639 ~~ 0.04 17 _' 2.88 Lt. D sits. 246 7661 ~~ 0.01 _' ~ 95 247 7685 ~ ~ 0.02 t3 .93 47.1 769 l) 0 t~ i i .38 M rla 21' TBG P ch Coveri In' M rl 9 48 7714 U 0.01 5 _' 2.8 24 7736 0 0.0 t3 2 85 249.1 7767 U 0 ll ~~ N A In'ection Mandre 10 Latch @ 10:30 249.2 7776 u 0 10 -t 2.86 PUP 249.3 7786 i ~ 0 0 U 3.00 Baker Wireline Set Permanent Packer Penetration Body Metal Loss Body Page 6 • CO1~T5ERQ~ ATIO CObII II SIpH John Peirce Wells Engineer ConocoPhillips Alaska Inc. c ~ u `~~)~~ fir ~ ~ ~, ~'~ ~ ~ C E' PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, Sundry Number: 309-070 Dear Mr. Peirce: • SARAH rALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 f~ ~C 1 B-02 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing .has been requested. Sincerely, Daniel T. Seamount, Jr. h ~ Chair DATED this ~ day of March, 2009 Encl. ~~ ~~~~ ~~'~ STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~r3 .,~ RECEIVED FEB 2 4 2009 APPLICATION FOR SUNDRY APPROVAko Oil & Gas Cons. Go 20 AAC 25.280 n~i'IISSIOt! 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver 8~ Other ^/ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ install tubing patch Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 180-133 ' 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20531-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ 16-02 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Q3,.5k.'r ADL 25648 ' RKB 90' - Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8153' ~ 6792' - 8027 6692' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 110' 110' SURFACE 2893' 10-3/4" 2933' 2646' PRODUCTION 8073' 7" 8113' 6760' Perforation Depth MD {ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7468'-7900' 6256'-6591' 3-1/2" J-55 7813' Packers and SSSV Type: Packers and SSSV MD (ft) Baker HB-1 retriev pkrs (2), Baker permanent pkr @ 7276', 7594', 7788' Otis TR-FMC SSSV @ 1838' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat March 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ~- WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name JOhn P@IfC@ Title: Wells Engineer Signature ~ ~' Phone 265-6471 t~ Date 2 ^1 /--(~ Commission Use Onl Conditions of a roval: Notif Commission so that a re resentative ma witness Sundry Number. ~~~ y pp p y ,. Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~ E ~l h~` ~ /~ """"~; l ~ Other. Subsequent Form Required: ~~`~ APPROVED BY ~ ~Z Ap'roved by: COMMISSIONER THE COMMISSION Date: Form 10~Revised 06/2006 ~ ~ ~ ~ n J n r /~ j Submit in Duplicate • . 1 B-02 Proposed Patch-Through-Patch Installation A 1/4/09 (PROF shows 45% of PWI enters the C1 sand (lower selective) through a leak in a permanent patch (2.375" ID) that was set 12/1/94 at 7617 - 7638' RKB. This leak will be isolated with a retrievable patch-through-patch to halt all C1 sand PWI, and to attempt to achieve `A sand only' injection. Procedure: Slickline Pull 1" min ID A-1 Injection Valve on 2.813" X-Lock from SSSV at 1838' RKB. 2. Pull St # 8 HFCV at 7457' RKB, which allows 55% of PWI to the 02/3/4 through the upper selective, and replace it with a DV. 3. Brush & flush 7600 - 7650' RKB where a `patch-through-patch' assembly is to be set in 3.5" tubing through a leaky 2.375" ID perm patch set at 7617 - 7638' RKB. 4. Run Caliper through the tubing from tubing tail at 7812' RKB to surface. 1 B-02 has 20 to 24 year old 3-1/2" J-55 tubing. A caliper has never been run, and overall tubing condition needs to be verified before running a new patch. E-line Install new retrievable patch-through-patch assembly: 5. RIH with run #1:2.13" run OD Retrievable Inflatable Packer with pump out plug, Anchor Seal assembly, ~16' Spacer Pipe, and 2.225" run OD Packer. Set the 2.225" OD packer at the mid-point of the leaky perm patch at 7628' RKB to leave the 2.13" OD packer hanging at +/- 7644' in 3.5" tubing ~6' below the base of the perm patch. POOH w/running tools. RU pumping equipment to attempt to inflate lower packer. PU tubing in 500 psi increments to 2800 psi to inflate and set the Packer at +/- 7644' RKB, and to shear out the pump out plug. This process pressure tests tubing and new patch integrity while setting the lower packer to complete the new patch. (a) If shear out plug successfully sheared out and lower inflatable packer set, the leak has been isolated. If this is the case, RD E-line and return 1 B-02 to `A sand only' PWI to obtain valid injection tests, else proceed to part (b) to install run #2 assembly to isolate the leak and the entire leaky permanent patch. (b) If needed, RIH with run #2 consisting of an Anchor Seal assembly, ~16' Spacer Pipe, and a 2.72" run OD retrievable Packer. Latch Anchor Seal to the Packer at 7628' RKB, and set the 2.72" OD Packer at +/- 7612' RKB to complete isolation of the leaky perm patch. This packer setting location puts the upper packer for the patch-through-patch ~5' above the top of the leaky perm patch. RU pumping equipment. PU tubing in 500 psi increments to a final pressure of 2600 psi to inflate and set the lower Packer and shear the pump out plug. RD. Return 1 B-02 to PWI as an `A sand only' injector for injection testing. JWP 2/19/2009 ` , ~'~ KU P • pL t ~ . CQ1~QL'~Q1-1 ll~llp5i ` ',Well Attribut j es AI".>r ti frr„ 1 Wellbore APl/UWI !Field Name 'Well Status Protlllnj Type ~ ti00292053100 ,KUPARUK RIVER UNIT (INJECTING MI Comment H25 (ppm) Date (Annotation End Date ep c ml 7~ o3 vlQtzW 9y:3zer AM"-- -SSSV: LOCKED ( I OU7 0 ( ( 1/1/2009 IlLast WO: 2/1 ___~ g;_, , , o ~~~ __ _ __ Stlwme, (ic AaJ. Annotation eL Depth (k KB) End Date Annotation ( Last Tag: SLM ( ( 7,889 12/31/2008 Rev Reason: CORRECT PATCH DEP ~ ~ .n__-__ r..__ __ corVDUCroR, ~ 0-110 VALVE, 1,838 SSSV, 1,838 ~- GA$ LIFT, 2.833 SURFACE, 294,934 GAS LIFT. _. 5,168 GAS LIFT. __ 6.275 GAS LIFT, s.a9a GAS LIFT, 7,215 NIPPLE, 7.227 PBR, 7,261 PACKER, ],276 INJECTION. 7,313 INJECTION, _ 7,386 INJECTON. _ zas7 IPERF, __- ],d68-7,524 IPERF, 7,5297,538 IPERF, 7,544-7,553 IPERF, ],558-],567 'ACKER. 7.590 IPERF. SQUEEZE. ],d68 IPERF, 1,652-7,669 INJECTION, ___ 7.690 PATCH, ],892 - NIPPLE.7.703 ---- INJECTION, __ ],76] 'ACKER, ],788 NIPPLE, ].sos VIP REDUCER, sos.7,e1z rtl (fl1 28.48 1 B-02 153 ease Date 'Casing Desmplion ,String 0... String ID ... Top (kK8) Sat DepM (i... Set Dap[h (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 0 110 110.0 ~ 65.00 H-00 WELDED _ (Casing Description ', String 0... String ID ... Top (kK6) Set Depth (i... Set Depth (ND) ... 'iString Wt...'String ... String Top Thrd .SURFACE 10 3/4 9 794 29 2,934 2646 3 _ K55 ~ 45.50 _ __ ',Casio Descri lion Strin 0... Strin ID ... To (kK6 Set Da lh 1... Set Depth ND 9 P 9 9 P 1 P ( ( ) ~~ Str Wt.. 'Str g String Top 9 ~ __ Thrd (PRODUCTION 7 6.151 25_ _ _ 8,114 6,760.9 2600 K 55 'I. Tubing Strings _ -- -- _ _ Tubing Descr pbon String 0... String ID ... Top (kK8) Set Depth (f... Set Depth (ND) .. ,String Wt... Str g ... String Top Thrd ( TUBING ___'~, 3 1/2 2.992 22 7,813 6,522 I 9.20 J 55 BTC ABMOD Com letion Details __ Top Depth j ( j To ncl To kKB P( i kl(B (, Item Description Comment _ ID (in) 22 22.0 0.00 HANGER McEVOY TUBING HANGER 3.500 1,838 1,803.9, 28.17 i,SSSV OTIS TR-FMC (LOCKED OUT 9/30/1998) NOTE: "BEWARE" SSSV 2.813 FLAPPER IS BROKEN 7227 6071.4' 4000INIPPLE ' OTIS X'SELECTIVE LANDING NIPPLE 2.813 7,261 6097 2 40 00 PBR BAKER PBR 3.000 7,276 6 109 0 40 OOPACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 7,594 6,352.8 ~. 40.061PACKER BAKER HB-1 RETRIEVABLE PACKER 3.000 7,788 6,503.1 38.341, PACKER BAKER WIRELINE SET PERMANENT PACKER 3.000 7, 8051 6,516.1 , 37.50 NIPPLE CAMCO'D'NO GO NIPPLE 2.720 7,812 8,521.7 37.SO~~SOS BAKER SHEAR OUT 2.992 Other In Hole treline retrievable lu s, valves, um s, fish etc. Top Depth' (ND) Top Inc! Top (kKe) (kl(6) (°) Description Comment _ _ ___ Run Dale ID(in)- 1,838 1,803 6i 28.161 VALVE 12.81° X-Lock 3.5" A-1 INJ VLV (#HJS-958, BEAN=1", 1111/2009 1.000 OAL~S") 7,617 6,370.5 39.62 PATCH Meda 21' Tbg Patch; Set on 12!1/94 1v1/1994 ~ 2.375 7,692 6,428.2 39.06 PATCH 21.5' Merle Thg Patch 11/20/1994 2.375 7,703 6,436.7 38.98 NIPPLE AVA TPL NIPPLE inside Patch 11/20/1994 2.260 -__ 7,805 6 516.1 37.50 NIP REDUCER AVA NIPPLE REDUCER 2.75" X 1.81" 11/17/1994 1.810 Perforations 8 Slots . _- - - _- -. ~ - -.. - Dens Top (TVD) Btm (ND) ' Top (kKe) ~ Btm (ffKB) _ (kK6) (kK8) Zone Date (sk... Type Commetd 7,468 1 7,524 : 6,256.1 6,299.7 C-0, C-3, 18-02 5/4/1981 12.0' IPERF 5" Geo Vann Gun -CLOSED 7,529 7,538 6.303.4 6,310.2 C-3,16-02 5/4/1981 12.0' IPERF I S"Geo Vann Gun-CLOSED 7,544 7,553 6,314] 6,3215 C-2, 1B-02 5/4/1981 120 i 1PERF ! 5"Geo Vann Gun-CLOSED 7,888 7,567 6,325.3 6,332.1 C-2, 1B-02 5/4/1981 12.0 1PERF 5"Geo Vann Gun-CLOSED 7,572 7,579 6,335.9 6,341.2 C-2, 1 B-02 !5/4/1981 12.0 IPERF 5" Geo Vann Gun -CLOSED 7,597 7,646 6,354.9 6,392.7 C-1, UNIT B, ;5/4/1981 12.0 IPERF 5" Geo Vann Gun -CLOSED 16-02 - -- 7,652 7,669 6,397.3 6,410.4 UNIT B, 18-02 (8/4(7981 12.0 IPERF 5" Geo Vann Gun 7,863 7,900 6,562.1 6,591.5 A-5, A-0, 18-02 ',5/4/1981 12.0 IPERF 5" Geo Vann Gun I 1,866 7 896 6,564.5 6,588.3 A-5, A-0, 16-02 ~4/S12005 __ 6.0 APERF 1 11/16" Power EJ - -_. - _ _ 1 Cement Squeezes To Da th P P Bbn Da h~ Pt ' (ND) (ND) Top (ffKB) Btm (ffK8) ~ (kK8) (kK8) Description Start Data I Comment 7,468 7646 6,256.1 6,392.7~ Cement Squeeze ~5/13/2006 ( PUMPED 22.7 BBLS CEMENT Notes: General 8 Safety End Date Annotation _ 2/1/1989 NOTE: COMPLETION BELOW PBR ~a 7261' RUN 6!7/1985 WORKOVER _ 9/10/1998 .NOT E: ""BEWARE" SSSV FLAPPER HAS A PROBLEM 2/17/2009 '.NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Top Depth Top ~- - Port -- - - i I (TVD) Inc! OD Valve Latch Siza TRO Run Stn TOp (kKB)', (kKe) (°) Make Model (inl Sarv Type Type (in) (psi) Run Date Comm... 1 2,833 2,570.9 41.50 CAMCO~IKBUG 1 GAS LIFT DMY BK 0.000 0.0 2/1/1989 2 5,1681 4,342.4 39.65 CAMCO,'KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/1/1989 3 6,2751 5,266.6 26.12 CAMCOiiKBUG 1 GAS LIFT DMY BK 0.000 0.0 2/1/1989 4 6,89415,802.9 3389~CAMCO!KBUG 1 GAS LIFT DMV BK 0.000 0.0~2/1I7989 5 7,215 6,062.7 40.OOIMERLA TPDX 1 12 GAS LIFT DMY IT2 0.000 0.0 2/1/1989 6 7,313 6,137.6 40.00•IOTIS LBX 1112 INJ (DMY ~IRM 0.000 0.0 12/1812008 ~ 7 7,386 6,1932 40.OO~iOTIS LBX 11(2iINJ (DMY IIRM 0.000 O.OI12/18/2008 8 7,457 6,247.7 40.00•'OTIS LBX 1 12 INJ HFCV FIRM 0.500 0.0 12/17/2008 9 7,694 6,429.4 39.05 OTIS LBX 1 1/2 INJ Patch O.000i 0.0 11/23/1994 10 .7,767 6,487.0 3849 OTIS LBX 1 1/2 INJ DMY RM 0,000 0.0 10/7/1994 25-e.1 u TD. 8.153 Schlumberger -DCS ^- ~ - /j \~ ~ / 1 / Jf .. j'~~ NO.5035 01 /08/09 2525 Gambell Street, Suite 400 , ' r F '°+'~~" ~~~i .~ ~ ~nr~r+ Anchorage, AK 99503-2838 ATTN: Beth Wel I Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Kt::Lit::1 v t:u ~t.$ APR. Ð 2007 Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 ¿- Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 180-1331 / 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20531-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' r 1 B-02 ./ 8. Property Designation: . 10. Field/Pool(s): ADL 25648 / Kuparuk River Field 1 Kuparuk Oil Pool ..- 11. Present Well Condition Summary: Total Depth measured 8153' ¿ feet true vertical 6792' / feet Plugs (measured) Effective Depth measured 7910' feet Junk (measured) true vertical 6599' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SURFACE 2893' 10-3/4" 2933' 2646' PRODUCTION 8073' 7" 8113' 6760' Perforation depth: Measured depth: 7468'-7900' SCANNED APR 1 1 2007 true vertical depth: 6256'-6591' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7813' MD. Packers & SSSV (type & measured depth) pkr= BAKER HB-1 RETR.; BAKER HB-1 RETR.; BAKER HB-1 RETR. pkr= 7277'; 7595'; 7788' Otis TR-FMX SSSV= 1838' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 658 bbls of sea water "" 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation na na 80 Subsequent to operation na na 3245 .. 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0/ Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ0 /' WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact John Peirce @ 265-6471 Printed Name John Peirce ~ Title Wells Group Engineer Signature ~ ~ ".--.... _../ Phone Date 4 -"-07 Prenart>rl bv Sharon AI/sun-Drake 263-4612 / ... RBDMS 8ft APR 1 J iD 7 ~J> ~,/V- 0 Form 10-404 Revised 04/2006./ 0 R \ G \ Nt!!.. L ~c vI, "7 SUbm~~~#7 . 1 B-02 Well Events Summary . DATE Summaryops 3/19/07 PULLED A-1INJECTION VALVE @ 1838' RKB. SET 2.81" FMX FRAC SLEEVE (OAL= 104") @ 1838' RKB. MITIA TO 2500#. PASSED. JOB COMPLETE. 3/21/07 POOR BOY HPBD. PUMPED 658 BBLS OF COLD SEA WATER IN 4 STAGES. r MAINTAIN BETWEEN 6.5 TO 7.5 BPM AT 4000 PSI THROUGHOUT FIRST 3 STAGES AND START OF 4TH. BLEW HEAD GASKET IN LRS UNIT 40 DURING 4TH STAGE AND PUMP REMAINING SW AT 4.4 BPM AT 3400 PSI. WHP DROPPED OFF TO 1500 PSI IN 45 MINUTES AFTR THE FOURTH STAGE. WELL PUT BACK ON INJECTION. ... 3/22/07 PULLED FMX 2.81" FRAC SLEEVE FROM 1838' RKB, SET AVA STYLE CATCHER @ 7609' RKB, PULLED DV'S @ 7458' RKB, 7386' RKB, 7314' RKB, SET CV @ 7314' RKB, IN PROGRESS. 3/23/07 SET CV'S @ 7386' RKB, 7458' RKB, SET 2.81" FMX FRAC SLEEVE @ 1838' RKB, COMPLETE. . . KRU 18-02 ConocoPhilUps Alaska, Inc_ ~. @ 7468 API: 500292053100 SSSV Type: WRDP Orio Comoletion: 1/11/1981 Anale lâ) TD: 38 dea lâ) 8153 Annular Fluid: Last W/O: 2/1/1989 Rev Reason: Show cement SQZ Reference LOCI: Ref Loa Date: Last Uodate: 3/29/2007 Last Taa: 7910' TD: 8153 ftKB Description Size Top Bottom TVD wt Grade Thread CONDUCTOR 16.000 0 110 110 65.00 H-40 WELDED SURFACE 10.750 0 2933 2646 45.50 K-55 PRODUCTION 7.000 0 8113 6760 ~ K-55 .iIIll""" T I Size I I 3.500 I 0 I 7025 I 5910 1 9.20 I J-55 I BTC 3.500 7025 9.30 J-55 8RD Interval TVD Zone Status Ft SPF Date Type Comment 7468 - 7524 6256 - 6299 C-4,C-3 C 56 0 5/1312006 Saz 7529 - 7538 6303 - 6310 C-3 9 0 5/1312006 7544 - 7553 6314 - 6321 C-2 9 0 5/13/2006 7558 - 7567 6325 - 6332 C-2 9 0 5/1312006 7572 - 7579 6336 - 6341 C-2 7 0 5/13/2006 7597 - 7646 6355 - 6393 C-1,UNIT 49 0 5/13/2006 B - 7863 - 7900 - 5" Gun Interval Date Type Comment ~ I APPROX. 23 BBLS CEMENT BEHIND PIPE St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 2834 2572 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 2 5169 4343 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 3 6276 5268 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 4 6895 5803 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 2/1/1989 5 7216 6062 Merta TPDX CAMCO DMY 1.5 T2 0.000 0 2/1/1989 St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 6 7314 6138 Otis LBX MAACO DMY 1.5 RM 0.000 0 2/14/2005 7 7386 6193 Otis LBX MAACO DMY 1.5 RM 0.000 0 2/14/2005 ... 8 7458 6248 Otis LBX MAACO DMY 1.5 RM 0.000 0 2/14/2005 9 7694 6430 Otis LBX PATCH 1.5 0.000 0 11/23/1994 _7767 6487 Otis LBX DMY 1.5 RM 0.000 0 10/7/1994 SQUEEZE (7468-7646) . Depth TVD Type Description ID 7609 6364 PATCH Merta 21' Tba Patch; Set on 12/1/94 2.375 7683 6421 PATCH 21.5' Merta Tba Patch; Set on 11/20/94 2.375 I .. Depth TVD TVDe Description ID 1838 1804 SSSV Otis TR-FMX. LOCKED OUT 9/30/98 - 2.813 - NOTE: "BEWARE" SSSV FLAPPER IS BROKEN - I 1838 1804 VALVE 2.81" X-LOCK w/A-1INJECTION VALVE (1" CHOKE, SN: HKS-238) set 1.000 PATCH 8/13/2006 (7683-7704, 7227 6070 NIP Otis 'X' Selective Landina 2.813 OD:2.765) 7262 6098 PBR Baker 3.000 7277 6109 PKR Baker HB-1 RETR. 3.000 7595 6353 PKR Baker HB-1 RETR. 3.000 7788 6503 PKR Baker W/L Set PERM. 3.000 7805 6516 NIPPLE AVA 2.75" X 1.81"; Set on 11/17/94 1.810 REDUCER 7805 6516 NIP Cameo 'D' Nioole NO GO 2.750 7812 6522 SOS Baker 2.992 TUBING (7025-7813, OD:3.500, Date Note ID:2.992) 9/10/19981 NOTE: -*BEWARE" SSSV FLAPPER HAS A PROBLEM _mm - - -. ...... Œ 04/05/07 Sç~lunlÞepgep RECEIVED NO. 4205 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR 0 6 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ OIl &. Gas Cons. Commission c:Ji"A......a:::rt Anchorage uwru......, APR 1 0 2007 UTC- /'to -/33 Field: Kuparuk Wen Color CD Job# Log Description Date BL 2M.12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 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 1H-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 03/22107 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 . . 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 90' e e Kt:.l"t:1 V t:U JUN 2 9 2006 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing D Opera!. ShutdownD Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D Other Time Extension Service Re-enter Suspended Well 5. Permit to Drill Number: 180-133 t-SQi 171 " 6. API Number: 50-029-20531-00 " Exploratory D o 9. Well Name and Number: 1 B-02 8. Property Designation: ADL 25648 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: measured 8153' feet true vertical 6792' feet measured 7902' feet true vertical 6591' feet Length Size MD 110' 16" 110' 2843' 10-3/4" 2933' 8023' 7" 8113' Plugs (measured) Junk (measured) 7805' TVD Burst Collapse 110' 2646' 6760' Measured depth: 7468'-7900' true vertical depth: 6256'-6591' , '~~ ~i;~.H::: ~ . ):", J''U . "'" J ;0 r~i Tubing (size, grade, and measured depth) 3-1/2" . J-55, 7813' MD. Packers & SSSV (type & measured depth) pkr= BAKER HB-1 RETR.; BAKER HB-1 RETR.; BAKER HB-1 RETR. pkr= 7277'; 7595'; 7788' SSSV - Otis TR-FMX @ 1838' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7712'-7805' refer to summary Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature OR\G\NA\J Title Phone b Sharon All u Drake 263-4612 1. ß~' z.."/. tJ¿' hÞ)h> SUb~. . Ori.ginalOnlY ~ ~¡66 -..- ....... ..... ... e 1 B-02 Well Events Summary e DATE Summary 13-May-06 LAY IN SAND PLUG FROM TT PLUG AT 7805' TO 7712'. PUMP 22.7 BBLS. CEMENT, UNABLE TO ESTABLISH ANY SQUEEZE PRESSURE, LAY IN 100' ABOVE SAND PLUG AND MAINTAIN 300 PSI WHILE POOH. FULL COLUMN OF DIESEL ABOVE CEMENT. 14-May-06 PT CEMENT SQUEEZE TO 2500 PSI AND HOLD FOR 30 MIN. COULD NOT GET THROUGH FRAC SLEEVE WITH 2.295" MILL. SL WILL INSPECT FRAC SLEEVE IN AM, THEN CONTINUE MILLING JOB WITH SMALLER MILL. 15-May-06 PULLED 2.81" FRAC SLEEVE (2.30" ID) @ 1838' RKB. SLEEVE IN GOOD SHAPE. UNDERREAMER FROM COIL WOULD NOT DRIFT IT. FILED DOWN WRENCH MARKS & TOOLS DRIFTED FINE. RE-RUN THE SAME 2.81" FRAC SLEEVE TO 1838' RKB. 15-May-06 MILL CEMENT FROM 7483' TO 7709' CTMD USING A 2.269" MILL WITH HAILEY UNDERREAMER. SAND PLUG STILL IN PLACE. POOH AND SWAP WELLBORE TO DIESEL. MIT-T TO 2500 PSI AT SURFACE. 20-May-06 WASHED OUT SAND TO PLUG AT 7805' RKB WI 1.5# DUO-VIS USING 1.5" JETSWIRL NOZZLE. WELL LEFT SHUT IN AND LOADED WITH DIESEL TO THE PLUG. ConocoPhillips Alala, Inc. e KRU "8-02 1 B-02 API: 500292053100 Well Type: INJ Anç¡le (Q) TS: 40 deç¡ @ 7468 TUBING SSSV Type: WRDP Orio Completion: 1/11/1981 Anole (Q) TD: 38 deo (Q) 8153 (0-7025, Annular Fluid: Last W/O: 2/1/1989 Rey Reason: Pull INJ VLV, Set SLV 00:3.500, & Pluç¡ 10:2.992) Reference Loa: Ref Loo Date: Last Update: 1 0/30/2005 Last Taa: 7902 TD: 815311KB Last Taç¡ Date: 5/23/2005 Max Hole Anç¡le: 43 d~600 Casing String - All Strings Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 65.00 H-40 WELDED SURFACE 10.750 0 2933 2646 45.50 K-55 PRODUCTION 7.000 0 8113 6760 26.00 K-55 TubinQ StrinQ ~ TUBING Size Top I Bottom I TVD I Wt I Grade Thread 3.500 0 I 7025 I 5910 I 9.20 I J-55 I BTC 3.500 I 7025 I 7813 I 6523 I 9.30 I J-55 I EUE 8RD Perforations Summarv TUBING Interval TVD Zone Status Ft SPF Date Type Comment (7025-7813, 7468 - 7524 6256 - 6299 C-4,C-3 Open 56 12 5/4/1981 IPERF 5" Goo Vann Gun 00:3.500, 7529 - 7538 6303 - 6310 C-3 Open 9 12 5/4/1981 IPERF 5" Geo Vann Gun 10:2.992) 7544 - 7553 6314 - 6321 C-2 Open 9 12 5/4/1981 IPERF 5" Geo Vann Gun 7558 - 7567 6325 - 6332 C-2 Open 9 12 5/4/1981 IPERF 5" Geo Vann Gun 7572 - 7579 6336 - 6341 C-2 ODen 7 12 5/4/1981 IPERF 5" Geo Vann Gun 7597 - 7646 6355 - 6393 C-1,UNIT B Open 49 12 5/4/1981 IPERF 5" Goo Vann Gun 7652 - 7669 6397 - 6410 UNITB Open 17 12 5/4/1981 IPERF 5" Geo Vann Gun 7863 - 7900 6562 - 6591 A-5,A-4 Open 37 12 5/4/1981 IPERF 5" Geo Vann Gun Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt 1 2834 2572 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 2 5169 4343 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 3 6276 5268 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 10/8/1994 4 6895 5803 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 2/1/1989 5 7216 6062 Merta TPDX CAMCO DMY 1.5 T2 0.000 0 2/1/1989 Injection MandrelsNalves St MD rvD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt 6 7314 6138 Otis LBX MMCO DMY 1.5 RM 0.000 0 2/14/2005 7 7386 6193 Otis LBX MMCO DMY 1.5 RM 0.000 0 2/14/2005 8 7458 6248 Otis LBX MMCO DMY 1.5 RM 0.000 0 2/14/2005 9 7694 6430 Otis LBX PATCH 1.5 0.000 0 11/23/1994 - 10 7767 6487 Otis LBX DMY 1.5 RM 0.000 0 10/7/1994 Perf - - (7468-7524) - - Other 'pluQs, eQuip., etc.) - JEWELRY Perf = = Depth TVD Type Description ID - - (7529-7538) = = 1838 1804 SSSV Otis TR-FMX. LOCKED OUT 9/30/98 - 2.813 Perf NOTE: "BEWARE" S5SV FLAPPER IS BROKEN (7544-7553) - - 1838 1804 SLEEVE NO GO FRAC SLEEVE, 104' OAL set 10/29/2005 2.300 Perf = = 7227 6070 NIP Otis 'X' Selective Landinç¡ 2.813 (7558-7567) - - 7262 6098 PBR Ba ker 3.000 Perf = = 7277 6109 PKR Baker HB-1 RETR. 3.000 (7572-7579) - - 7595 6353 PKR Baker HB-1 RETR. 3.000 - - 7788 6503 PKR Baker W/L Set PERM. 3.000 7805 6516 PLUG 1.81" A-2 PLUG set 10/29/2005 0.000 7805 6516 NIPPLE AVA 2.75" X 1.81"; Seton 11/17/94 1.810 - - REDUCER Perf - - 7805 6516 NIP Cameo 'D' Nipple NO GO 2.750 (7597-7646) - - 7812 6522 50S Ba ker 2.992 - - 7813 6523 TTL 2.992 PATCH - (7609-7630, - - Other 'pluQs, eè¡uip., etc.) - SLEEVE/PATCH 00:2.859) - - - - Depth TVD Type Description ID Perf - -- 7609 6364 PATCH Merla 21' Tbo Patch; Set on 12/1/94 2.375 (7652-7669) - I-- 7683 6421 PATCH 21.5' Merla Tba Patch; Set on 11/20/94 2.375 - I-- 7694 6430 NIP AVA TPL NIPPLE inside Patch; Set on 11/20/94 2.310 PATCH (7683-7704, General Notes 00:2.765) Date I Note 9/10/1998 I "BEWARE" SSSV FLAPPER HAS A PROBLEM SOS (7812-7813, 00:3.500) - I-- Perf - -- (7863-7900) - -- e [Ø e John Peirce Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~1íA. OlL~ ~ COlYS~aV1U'lON CO~SSION FRANK H. MURKOWSKI, GOVERNOR 333 IN. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KUParuk 1B-02 SundIy NUmber: 305-377 ~NE:r: \C60J \33 q "'i L .t Dear Mr. Peirce: Enclosed is the approved Application for SundIy ApProval relating to the above referenced well. Please note the COnditions of approval set Out in the enclosed form. Pie""" Provide at least twenty-four (24) hours notice for a representative of the COl111n:iSSion to Witness any required test. Contact the Col111n:iSSion's petroleum field inspector at (907) 659-3607 (pager). As Pl'OVided in AS 31.05.080, Within 20 days after written notice of this decision, Or such further time as the Col111n:iSSion grants for good cause shown, a person affected by it may file With the Col111n:ission an application for rehearing. A request for rehearing is considered ti1nely 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 fa1Js on a hOliday Or weekend. A 1'erson may not appeal a Col111n:iSSion decision to SUPerior CoUrt unless rehearing has been requested. Sincerely, h Korman Chairman DATED thi4 day of December, 2005 Encl. A c/11Z,'I~ A RECEIVED - Or:J (Z- STATE OF ALASKA · ¡s IdfI. DEC 0 2005 ALASKA Oil AND GAS CONSERVATION COMMISSION ~ 9 APPLICATION FOR SUNDRY APPROV ALAla$ka Oil & Gas Cons. Commissioñ C A h 20M 25.280 nc orage 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 ·-otlJer ~' Alter casing 0 Rep~ Plug Perforations 0 SIi~- Time Extension 0 /2?i1 Change approved program 0 Pull ubi g -_ Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill ~r: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 180-133 3. Address: Stratigraphic 0 Service 0 6. API Number: ./ P. O. Box 100360, Anchorage, Alaska 99510 50-029-20531-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 1 B-02 8. Property Designation: 10. Field/Pool(s): ADL 25648 Kuparuk River Field I Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8153' 6792' 7902' 7805' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 2843' 10-3/4" 2933' 2646' PRODUCTION 8023' 7" 8113' 6760' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7468'-7900' 6256'-6591' 3-1/2" J-55 7813' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER HB-1 RETR. ; BAKER HB-1 RETR.; BAKER HB-1 pkr= 7277'; 7595'; 7788' SSSV - Otis TR-FMX @ 1838' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program tJ BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 16, 2005 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J:;h~ ee Ire.. e.. Printed Name "";J ~h >'\. Pe ì r c.. e. Title: E. ~¡'11. ee.rì ':.:3 Tec:.h Signature 4'¿lfR·~ - Phone 2~5' -~4 7' Date 1.. 2/'7/05 / ~ , Commission Use Only I I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness :0$-3'77 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~OO ~c;l M\ . \"\.. ~ "'- ~a y -\-~>\-- , RBDMS 8Ft nFC 1 Æ 7005 Appro~ ?j ~ APPROVED BY D"./1'/3.{)( COMMISSIONER THE COMMISSION '-'" -~ / ¡ 1 \1 . . Form 10-403 Revised 7/2005 \; II\JAL Submit In Duplicate TUBING (0-7025. 00:3.500. 10:2.992) TUBING (7025-7813. 00:3.500, 10:2.992) Perf (7468-7524) Perf (7529-7538) Perf (7544-7553) Perf (7558-7567) Perf (7572-7579) Perf (7597-7646) PATCH (7609-7630, 00:2.859) Perf (7652-7669) PATCH (7683-7704, 00:2.765) SOS (7812-7813, 00:3.500) Perf (7863-7900) e ConocoPhillips Alaska, Inc. 11 B-02 PIlI :Jr' .;". " . .: . _I, - - - = - = - = - = - - I . I ,"!I~ ~¡~~ - - - . .- . API: 500292053100 SSSV TVDe: WRDP~"- _.. Annular Fluid: e KRU 'B-02 . . . Well-"!:YQe: INJ . OrigCompleti!JIl.:_ !l!.!D...!181 Last W/O: 2/1/1989 ...Ar1gleJ~.l~:¿º_d~g @ 7468 _Angle~: '38 deg @ 8153 Rev Reason: PulllNJ VLV, Set SLY & PluQ Last UDdate: 10/30/2005 6138 Otis LBX MAACO DMY 6193 Otis LBX MAACO DMY 6248 Otis LBX MAACO DMY 6430 Otis LBX PATCH 6487 Otis LBX DMY An"in At" \ II::\AlI: QV Tvpe SSSV ....----_.- TVD 110 2646 6760 ....--.- Wt 65.00 45.50 26.00 Reference Loa: Ref Loa Date: Last Tao: 7902 TD: 8153 ftKB ,... . Lª~t Tag Date: 5/23/2005_____ __.Ma)(.H!JI~ AnQle: 43 de¡¡ @ 2600 i.G.ªªLr:"I9 String - All Strings . Description Size Top Bottom CONDUCTOR 16.000 0 110 SURFACE 10.750 0 2933 '--__._ PRO[)~CTION 7.000 0 8113 ;TubingJ?~ri_rlg - TUBING Size Top 3.500 0 3.500 7025 I Wt I Grade I I 9.20 I J-55 I I 9.30 I J-55 I >i Interval TVD Zone I Status Ft SPF I Date Type Comment 7468 - 7524 6256 - 6299 C-4 C-3 I ODen I 56 12 I 5/4/1981 I IPERF 5" Geo Vann Gun 7529 - 7538 6303 - 6310 C-3 I ODen I 9 12 I 5/4/1981 I IPERF 5" Geo Vann Gun 7544 - 7553 6314 - 6321 .... C-2 ,Open, 9 ____12 5/4/1981 I IPERF 5" Geo Vann Gun ---7558 - 7567 63?5- 633? I -- C:2 -----;---Open í,9 12 ---::-574i1981_~_.IP_~~ ~_G~º Vann Gun 7572 -7579 6336: 6341___.. C-2 I O"'pEm, 7 .12;5/4/198L_UPERF 5" G_eo Vann Gun 7597·7646 I 6355 - 6393 C-1,UNIT BJ Open 49; 12 ' 5/4/1981 : IPERF 5" Geo Vann Gun 7652 - 7669 ' 6397.. 6410--- . --UNIT B .. opë~ rr, 12 5/4/1981 IPERF 5" Geo Vann Gun ~jª63-=)990 I 6562 - 6591-- -·_ð.:.5,1\-.5_ _ . _Qpën--37 -----:¡-2----sT4/1981 , IPERF _ 5" Geo Vann Gun Q-ª!>LiftMandrelsNalves r--,---- St MD TVD Man Mfr Man Type V Mfr .-. I I I 1 I I Bottom 7025 7813 TVD 5910 6523 Grade H-40 K-55 K-55 Thread WELDED V Type Port Thread BTC EUE 8RD TRO Date Run 10/8/1994 10/8/1994 10/8/1994 2/1/1989 2/1/1989 Date Vlv Run Cmnt 2/14/2005 2/14/2005 2/14/2005 11/23/1994 Vlv Cmnt VOD Latch 1 2834 2572 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 2 5169 4343 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 3 6276 5268 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 4 6895 5803 Cameo KBUG CAMCO DMY 1.0 BK 0.000 0 5 7216 6062 Merla TPDX CAMCO DMY 1.5 T2 0.000 0 St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO SLEEVE NIP PBR PKR PKR PKR PLUG NIPPLE REDUCER 7805 6516 NIP 7812 6522 SOS 7813 6523 TTL OtherDluas, eauiD.. et< .) - Depth TVD Type 7609 6364 PATCH 7683 6421 PATCH 7694 6430 NIP Notes Date I Note 9/10/1998 I 'BEWARE' SSSV FLAPPER HAS A PROBLEM f-- f-- 1== f-- 1= f-- 1= f-- ~ r-- r-- 6 7 8 9 10 7314 7386 7458 7694 767 Depth TVD 1838 1804 1838 7227 7262 7277 7595 7788 7805 7805 1804 6070 6098 6109 6353 6503 6516 6516 - - - 1.5 RM 0.000 0 1.5 RM 0.000 0 1.5 RM 0.000 0 1.5 0.000 0 1.5 RM 0.000 0 » Description Otis TR-FMX. LOCKED OUT 9/30/98 - NOTE: "BEWARE" SSSV FLAPPER IS BROKEN NO GO FRAC SLEEVE, 104' OAL set 10/29/2005 Otis 'X' Selective Landino Ba ker Baker HB-1 RETR. Baker HB-1 RETR. Baker W/L Set PERM. 1.81" A-2 PLUG set 10/29/2005 AVA 2.75" X 1.81"; Seton 11/17/94 Cameo 'D' NiDDle NO GO Baker "-',. Description Merla 21' Tbo Patch; Set on 12/1/94 21.5' Merla TbQ Patch; Set on 11/20/94 AVA TPL NIPPLE inside Patch: Set on 11/20/94 ii ID 2.813 2.300 2.813 3.000 3.000 3.000 3.000 0.000 1.810 2.750 2.992 2.992 ID 2.375 2.375 2.310 e e 18-02 Cement Squeeze Leaking Permanent Tubing Patch Procedure Job Objective: Cement squeeze the C-1/ B sands in the lower straddle to permanently halt injection through the lower leaking permanent tubing patch set in the lower straddle. Well Status: Shut-in due to leak through tubing patch to the C-1/B sands that takes all injection. Procedure: Slickline: 1. Pull the 2.81" X-lock w/A-1 injection valve at 1838' RKB (set 6/11/05). 2. Pull the AVA CII Sleeve set in the leaking Merla tubing patch at 7694' RKB. (1.875" ID; set 12/12/94). 3. Set a TT plug w/prong for A sand perforation isolation in the AVA 2.75 x 1.81" Nipple Reducer at 7805' RKB. (1.81" ID; nipple reducer set 11/17/94). Coil Tubina: 4. RIH w/CT to tag TT plug at 7805' RKB, then PU & pump 2.1 bbls of gelled sand slurry containing 420 Ibs of sand at 6 PPA (lbs sand per gal of gel), to place an isolation sand plug over the A sand perfs at 7863 -7900' RKB. Target depth for top of the sand plug is 7725' RKB. Slickline: 5. RIH to tag top of sand plug. Dump bail sand, if needed, to adjust TOS to target depth of 7725' RKB (+ /- 10' MD). Coil Tubina: 6. MIRU CTU. Mix and prepare 20 bbls of -15.8 ppg Latex Acid Resistive Cement (LARC) for squeeze job. QAlQC cement slurry for filter cake of 0.75 - 1.0" and a target fluid loss range of 80 - 100 mL/30 min. The slurry is acceptable if fluid loss is less than 150 mL/30 min with filter cake of 0.75 - 1.0". Cement slurry working time expected at BHT is +/- 7 hours (inclusive of 2 hours surface time). RIH displacing CT with Seawater spacer at 1.5 bpm. Tag the top of sand at -7725' RKB, then swap to pumping 20 bbls of LARC at 1.5 bpm, followed by a CT volume of Seawater to displace all the cement from the CT. Displace 2-3 bbls of slurry from the CT on top of sand plug, then start to POOH w/CT laying in the remaining cement while keeping the nozzle -50' in the cement and taking returns. When all of the slurry has exited the CT, shut in the well and squeeze off the C-1/B sands through the tubing patch leak at 7704' RKB. JWP 12/9/2005 e e Obtain 3000 psi squeeze pressure and hold pressure for 1 hour, else hold the maximum sustainable squeeze pressure for 1 hour. Note, the worst case top of cement is -5425' RKB if the well locks up instantly with application of squeeze pressure after 20 bbls of cement is pumped. Contaminate excess cement at 2: 1 ratio w/1.5 ppb Biozan and jet the contaminated cement from tubing to 7630' RKB. Leave a cement plug below 7630' RKB. Bleed WHP down to 500 psi and shut-in the well w/500 psi on the wellhead for 3 days to prevent possibility of U-tubing of cement slurry from the straddle back into the tubing through the patch leak before the cement sets. RO CTU. Slickline: 7. RIH & tag the top of the cement plug. PT the cement squeeze to 2500 psi on the tubing and record leakoff rate. If PT indicates squeeze is leaking, reschedule a resqueeze and repeat steps #6 & 7. If PT passes, proceed to step #8. Coil Tubina: 8. RU CTU & RIH with a Hailey Underreamer w/Banana Blades for 2.992" tubing. Tag TOC and underream through the cement plug to the cement I sand interface at - 7725' RKB, then continue jetting out the sand plug to the IT plug set at 7805' RKB. Note: 10 restrictions encountered during underreaming operations will be the upper tubing patch at 7609 - 7630' RKB (2.375" 10), and the AVA TPL at 7694' RKB (2.31" 10) inside the lower tubing patch at 7683 - 7704' RKB (2.375" 10). Slickline: 9. PT the cement squeeze to 2500 psi on the tubing and record leakoff rate. If PT indicates the squeeze is leaking, reschedule to repeat steps #4 through 8 above. If PT passes, RIH & pull the IT plug set at 7805' RKB. Return the well to produced water injection as an A Sand only injector. JWP 12/9/2005 ,. Operations Performed: f (I Abandon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D Suspend 0 Operation Shl!tdown 0 o Repair Well 0 .' Plug Periorations 0 o Pull Tubing 0 . Pertorate New Pool 0 4. Current Well Status: Development .. 0 . Exploratory D Stratigraphic 0 Service 0 . Other '0 ¿;):vJJ -h -W IK::¡ Alter Casing. Change Approved Progra~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Variance D. Annular Disp. 0 TiI:ne .Extension 0 . RE;!-enter Suspended W~II 0 5. Permit to Drill Number: 180-133 1 6. API Number: 50-029-20531-00 P. O. Box 100360 7. KB Elevation (ft): RKB 90' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: Perforate ·0 Stimulate D. .. . 9. Well Name and Number: 1 B-02 10. Field/Pool(s): Kuparuk Oil Pool measured 8153' feet true vertical 6792' feet measured 8027 feet true vertical 6692 feet Length Size MD 110' 16" 110' 2843' 1 0-314" 2933' 8023' 7" 8113' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 2646' 6760' Measured depth: 7468 -7900 AUG 1. 5 2003 true vertical depth: 6256 - 6591 Tubing (size, grade, and measured depth) 3-1/2" ,J-55, 7813' MD. Packers & SSSV (type & measured depth) pkl""= BAKER HB-1 RETR.; BAKER HB-1 RETR.; BAKER HB-1 RETR. pkr= 7277'; 7595'; 7788' SSSV= sssv SSSV= 1838' . ·'1.~.:Stirrïuïélti91i .or c~ment:sqW~ez"e summary:.· . . Inte.rÝals treated (measui"éd) N/A.· ·1"3~ Treatment descriptions including volum·es used and final pressÜre·: P~ior to 1N~1I operation Sub.s~qlJent to operati.Qn 14. Attachments· ·ÇQpiesof Logs and Surveys run _ 7Q26. 15.··Well Class äft"er proposed work: Exploratory. D· Development 0 S!3rvice ·.0· . . . . 16. Well Status·after·proposed work: oilD. ·GasD WAG0 GINJLJ WINJ [] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: ....... ·Oil-Bbl . Repre~"~mtativ~.DaiIY AverageProd.uctiori or· Injection "Data Gas-Mct . Water"Bbl· ·50E?7 450 450 . Casin Pressure· Tubin· Pressure· -: ·21·73 3!3.62 Daily Report of Well Operations_X .WDSPLD Contact Form 10-4'5~~N~3AUG 2 0 2003 ORIGINAL 1 8-02 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/08/03ICÞmrnènced WAG EOR Injection MEMORANDUM TO: Cammy O Taylor j Chairman State of Alaska Alaska oil and Gas Conservation Commission DATE: June 16, 2002 -}) SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips P_1_ Supervisor 1B Pad KRU FROM: Chuck Scheve Kuparuk r Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 34 Min. WeJl1B-02 Type Inj. F T.V.D. 6109 Tubing 1 1450 1 1450 1 1450 1 1450 I Interval 4 P Test psi 1527 Casjng_l 150 1 1980 1 1930 1 1920 1 P1F I P Notes: Well 1B-01 I Type Inj- F T.V.D. 6180 Tubing 1 2400 1 2400 1 2400 2400 interval 4 P.T.D. 181-065 1 Type test I P I Test psi 1 1545 1 Casing 1 550 2050 2050 2050 PIF P Motes: Well 16-05 Type Inj. F TV, 1), 6341 Tubing 2500 2500 2500 2500 Interval 4 P.T.D. 177-001 Type test P Test psi 1585 Casing 250 2000 1950 1925 PIF P Notes: Well 18-07 Type Inj. F T.V.1). 6227 1 Tubing 2350 235+0 1 2350 1 2350 Interval:4:::] P.T.D. 181-089 1 Type testj P I Test psi 1 1557 1 Casing 1 1400 1950 1 1920 1 1920 PIF P Notes: Well 1 1 B-08 I Type Inj. F T.V. D. 1 4837 1 Tubing 1 2500 2500 1 2500 1 2500 linterval 4 P.T.D. 197-112 1 Type testj P I Test psi 1 1209 1 Casing 1 0 2050 2000 2000 PIF P Notes: Well 1 1 B-09 I Type Inj. F T.V. D. 6109 Tubing 2500 2500 2500 2500 Interval 4 P.T.D. 181-134 1 Type test I P I Test psi 1527 Casing 550 2025 2000 2000 PIF P Notes: Weill 16-12 Type Inj. F TV. D. 6094 Tubing 1950 1950 1950 1 1950 1 Interval 4 P.T.D. 193-061 Type test P Test psl 1524 Casing 0 2100 2050 2050 PIF I P Notes: Type INJ. Fluid Codes Type Test inrervai F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ_ P- Standard Pressure Test 4= Four Year Cyde S = SALT WATER INJ. R= Intemal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details I traveled to Phillips 1B Pad in the Kuparuk River Field and witnessed the routine 4 year MITs on the above 7 wells_ The pretest tubing and casing pressures on all wells was observed and found to be stable. The standard annulus pressure tests were then performed with all 7 wells dcmonstrating good mcchanical integrity. performed: 7 Attachments-, Number of Failures: 0 Total Time during tests: 4 Hours CC: MIT report farm 5112100 L.G. MIT KRU 10 Pad 6-16-02 CS.xls 6/20/2002 ~ .... STATE OF ALASKA ~ ALASI~A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown~ Stimulate~ Plugging Pull tubing ~ Alter casing ~ Repair well~ Perforate Other X _ Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X F_xplorato~ Stratigraphic __ Service 4. Location of well at surface 496' FNL, 862' FEL, Sec. 9, T11 N, R10E, UM At top of productive interval 1204' FSL, 1380' FWL, Sec. 4, T11 N, RIOE, UM At effective depth 1555' FSL, 1256' FWL, Sec. 4, T11 N, R10E, UM At total depth 1628' FSLr 17_31' FWL~ Sec. 4r T11N~ R10E~ UM 12, Present well condition summary Total Depth: measured 81 5 3 feet true vertical 6 7 9 2 feet 6. Datum elevation (DF or KB) RKB 90 7. Unit or Property name Kuparuk River Unit feet 8. Well number lB-02 9, Permit number 80-135/94-282 10. APl number so-029-20551 1 1, Field/Poo~ Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 8027 feet true vertical 6792 feet Junk (measured) None 13. 14. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 200 SX PF 80' 80' Surface 2934' 10-3/4" 1350 SX FONDU 2934' 2647' Intermediate Production 8113' 7 650 SX Class G 8113' 6760' Liner Perforation depth: measured 7468~-7524~~7529~~7538~~7544~~7553~~7558~~7567~~7572~~7579~~7597~-7646~~7652'-7669~~7863~~79~~' true vertical 6256'-6299',6303'-6310',6314'-6321 ',6325'-6332',6336'-6341 ',6355'-6392',6397'-6410',6561 '-6591 ' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 BTC tbg w/tail @ 7801' Packers and SSSV (type and measured depth) Pkr' BOT HB-1 @ 7263'~ BOT HB @ 7582'~ BOT 2B @ 7775'; SSSV: Otis QLS @ 1914~ Stimulation or cement squeeze summary ~ ~ ~' .... N/A Intervals treated (measured) FEB -' 6 1995 ..... N/A Treatment description including volumes used and final pressure ,A,~,~S~,~ Oil & Gas Cons. Col~missiO~ CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR 10/7/94 began inj on Representative Daily Average Production or In_iection Data Oil-Sbl Gas-Mcr Water-Sbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1 050 900 1400 1 ?.75 160 0 0 950 11 O0 ?.550 15. Attachments Well Schematic 16. Status of well classification as: Copies of Logs and Surveys run __ Reclasify as Water Injector ~ Daily Report of Well Operations X Oil __ Gas Suspended~ "i7. I hereby certify that the foregoing is true and correct to the best of my knowledge, Service Signed ~ " Form 10'404 ~ev~~~ Title Wells Superintendent ., Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL t DATE DAY / TIME t15'0 / ?05' DESCRIPTION OF WORK CONTRACTOR/KEY PERSON OPERATION AT REPORT TIME [] COMPLETE I~OMPLETE FIELD EST: $ ,_3/9,,5' ~'~-~-° ~.~lCC ,~c_RI/o// ACCUMULATED COST $ 3/q,5- ~-~-~-~ LOG ENTRY l<JFhO.' </00:~ ~/'.~: /,~.(~O'~:;Z' ~¢{.., ,,,¢"~0 ~,/:~5'.~" PAGE 1 OF Oil & ,,~,,o ................ I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. Chill Factor Visibility Report I °F °F miles AR3B-7031 Wind Vel. knots Isigned -- / ~' 298-3486 REMARKS CONTINUED: SERVICE COMPANY SCA # DAILY ACCu M. TOTAL ........ /./~ /o//,~ t~ 7'3 ~ ................... ................ ........................... , , , ,, , ~ ............. , ............. ............. ....... ......... ,, , ,,, ,,, ...... , ............. TOTAL FIELD ESTIMATE ~/~~ .. .. ......... . ....... ~,~,,~ ~~~ :. ~~ ..... ARCO Aiaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL / ~ -O,~ DATE /o-~ DESCRIPTION OF WORK 1,0//¢7-6-~/=-Coo z ) ('o,,~ ~ / ~-~. S' / o AJ CONTRACTOR I KEY PERSON F~)CC ,~(~,'/o//24.. DAY TIME 0 07/5 t /.¢',.~o / 60,9o / ?o,% i 75-.5' / 9/0 OPERATION AT REPORT TIME E] COMPLETE [~I~COMPLETE FIELD EST: ACCUMULATED COST $ LOG ENTRY t.-,.]f-/P.' ~ C.,(b'~'~ _~_/¢.' /~c)o ~.~ PAGE 1 OF FEB - 6 1995 Oil & Gas Co~s. F-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK' Report °F °F miles AR3B-7031 Wind Vel. knots ]' Sig~ed 298-3486 REMARKS CONTINUED: , SERVICE COMPANY SCA # DALLY ACCUM TOTAL · , . ' '.. ' ...fO/z ,':2.. 0 ,, , / , , . , , ,. · , ,, , , , , , , . , TOTAL FIELD ESTI MATE ,~-~o ~:~ ~ .-- , ; ..... ARCO Alaska, Inc. WELL DESCRIPTION OF WORK KUPARUK RIVER UNIT WELL SERVICE REPORT DATE DAY ..7 FEB - 6 CONTRACTOR/KEY PERSON Alaska 0ii & ~as Cons. 0mm OPERATION AT REPORT TIME E~COMPLETE [] INCOMPLETE FIELD EST: $ '7/,¢Z ACCUMULATED COST $ /0~ Z. 3~-,°<r---- TIME LOG ENTRY t'J/,/,°.' '2,.~O ~?,.~- ~--/~!/~t/',~'O~ C~,' ~.)c:.~-3'~P.~r- PAGE 1 OF 08'--/.5' / 'y'.5"O L'~c"w~,-?,.:,.z~ ¢.~c"..~L /'/co ~-',z.z ;. v'~co ,,e.vn A ,.'s" z],,~¢~r TZ3C_,.'~'L /~ ~,~.,.z- C.~(:.~E L / ~oo ~..zr ~, c-.,.~ I~]/CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. I Chill Factor Visibility Report °F °F miles AR3B-7031 JWind Vel. knots I Signe~ REMARKS CONTINUED: ~1 zO =~1~5 o~,2. / C) . ~'~??/5. "a~. (7--,.). c/t-red.) (C 7~z ~¢.~ ~<~ ?r~. ~5 '7-0 ,~,~"','-~ 'Tz~ ~7' =~ ~.z- Gco,b ,.?o,~,,V, ........ ACCUM. SERVICE COMPANY SOA # DAILY TOTAL ................. oO l-lc-T? ,,'o//,q <_FE-,-q </ ................. _~×e'?-¢(? P(..~,,~F' .......... i~ ×o~,./-e. ... / ~,.~,P "~"" ,;~..-~g,~-:,d/q,,V~rPo,,CT . /~ 5"1 z... ,~2 ,~.z~ ~ ...... .... ............. ......... , ..... , ................... ................. ~OT^~ ~' ~s,,u^,~ ......... 7 / +7_.~ ............. ,, _'.'. .. . ..... ' ....... ~,~ ~ .~ ~), ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE /o-I~ DaY TIME 0700 oq~o DESCRIPTION OF WORK /2. Z.0 CONTRACTOR/KEY PERSON OPERATION AT REPORT TIME FIELD EST: dCOMPLETE ['"]INCOMPLETE $ AFC/CC ,~. sc//-,~-/o 11~ ACCUMULATED COST LOG ENTRY ~/,/~/D.' ~4:~.5,' ..~",~.' 7~Opa ; 0~.' 70~,' PAGE 1 OF ~~ ~~-~ .'b~.~ ~,-~ ~~~ ~~,~ ,-~.'~~~/ ' ~'~ '~" ' ' ' ' ~z" ' ,. ~111~ ~ I--1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. J Chill Factor I Visibility Report 2 °F °F miles AR3B-7031 298-3486 REMARKS CONTINUED: (/3/$) 3/oo ~,~ J 7- (/o7o) zwo,~ .... (/~ ~ x ~~,,, df [ ....... ACCUM' SERVICE COMPANY SCA # DAILY TOTAL ......... /cs ............... ~/~ ............ ................. , , , , .................. ............................ ......................... .............................. ............................... ........................... ............................ _ .......... TOTAL FIELD ESTIMATE 47/0 ........... ,, ,, SIGNED ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 September 13, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Applicaton for Sundry APprovals (Form 10-403) and in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. FORM WELL ACTION 10-403 1B-02" 10-403 1 B-05 '/ 10-403 1 L-21 / 10-403 1 L-21 10-403 1 L-25'" 10-404 1 R-26 10-404 1Y-29 Other (Conversion) Other (Conversion) Other (Conversion) Other (Conversion) Other (Conversion) Other (Inj Valve) Other (Gel Sqeeze) If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (atch only) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company REC'£-IVED OCT - 6 1994 At~ska Oil & (~as Cons. Commission A~ch0ra~e i" ~,~ 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, I.n¢, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 496' FNL, 862' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1204' FSL, 1380' FWL, Sec. 4, T11N, R10E, UM At effective depth 1555' FSL, 1256' FWL, Sec. 4, T11N, R10E, UM At total depth 1628' FSL~ 1231' FWL, Sec. 4~ T11N~ R10E~ UM 12. Present well condition summary 6. Datum elevation (DF or KB) RKB 90 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1B-02 9. Permit number 80-133 10. APl number 5o-029-20531 11. Field/Pool Kuparuk River Oil F!e_ld/.P~o.L RE£t:IV U Total Depth: measured true vertical Effective depth: measured true vertical' Casing Length Structural Conductor 8 0' Surface 2 9 3 4' Intermediate Production 81 1 3' Liner Perforation depth: measured 8153 6792 8027 6692 Size feet feet feet feet Cemented Plugs (measured) None 0(;T - 6 199~ Junk (measured) None ,.u~sl~ u. & Gas Cons. Commission Anch0ra~je Measured depth True vertical depth 1 6" 200 SX PF 8 0' 8 0' 1 0-3/4" 1350 SX FONDU 2934' 2647' 7 650 SX Class G 81 1 3' 6 7 6 0' 13. 14. 16. 7468'-7524', 7529'- 7538', 7544'-7553', 7558'-7567', 7572'-7579', 7597'- 7646', 7652'-7669', 7863'-7900' true vertical 6256'-6299', 6303'-6310', 6314'-6321 ', 6325'-6332', 6336'-6341 ', 6355'- 6392' ~ 6397'- 6410', 6561 '-6591' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 'BTC tbg w/tail @ 7801' Packers and SSSV (type and measured depth) Pkr' BOT HB-1 @ 7263'~ BOT HB @ 7582'~ BOT 2B @ 7775'I SSSV: Otis QLS @ 1914 Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR Estimated date for commencing oPeration ~/1~/~)4 _ If proposal was verbally approved Name of approver Date approved I15. Status of well classification as: Oil X ~ Gas _ Suspended . Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~ ~ Title Wells Superintendent FOR COMMISSION USE ONLY Conditions of approval: Notify commission so representative may witness Plug integrity ~ BOP Test _. Location clearance Mechanical Integrity Test ~.~' Subsequent form require 10-~O.~' Date IApproval No...~_ Approved by order of the Commission Form 10-403 Rev 06/15/88 0rigJnal Signed By rJavid W. John.~fnn Commissioner Date SUBMIT IN TRIPLICATE Approved Copy Returned Attachment 1 Conversion to Water Injection Kuparuk Well 1B-02 ARCO Alaska requests approval to convert Well 1B-02 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6256' and 6591' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED OCT-6 1994 Oil & Gas Cons. Commission Anchorage WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 AUGUST 3, 1992 WATTY STRICKLAND ARCO ALASKA~INC. P O BOX 1900360 ANCHORAGE, ALASKA 99510 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR OF THE FOLLOWING WELLS MENTIONED IN THIS LETTER. WE ARE REVEIWING WELL FILES FOR MISSING 404 SUNDRY WELL OPERATION FORMS. SEVERAL 403 (SUNDRY APPROVALS) HAVE BEEN APPROVED FOR WORK ON THESE WELLS AND OUR FILES DO 'NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. WOULD YOU PLEASE LOOK INTO THESE WELL SUNDRYS SO WE CAN CLOSE THEM OUT EITHER BY SUBMITTING THE APPROPRIATE 404 FORM WITH ATTACHMENTS FOR COMPLETED WORK OR A NOTE STATING THAT THE 403 APPROVAL NUMBER IS VOID. THE APPROVAL NUMBER IS ON THE SIGNED COPY OF THE 403 THAT AOGCC SENT BACK TO THE OPERATOR. WELLNAME PERMIT 403 APPROVAL # SOLDOTNA CK UNIT 21-4A SOLDOTNA CK UNIT 42A-5 SOLDOTNA CK UNIT 41A-9 SOLDOTNA CK UNIT 41B-9 PRUDHOE BAY UNIT DS14-11 KUPARUK RIV UNIT lB-2 PRUDHOE BAY UNIT DS13-12 80-0105 9-266 80-0106 8-739 80-0107 90-835 80-0108 9-982 80-0131 9-1016 80-0133 90-876 80-0142 9-969 PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THE PROPER FORM IN A TIMELY MANNER. THIS IS GOING TO BE ANOTHER PROJECT JUST LIKE THE PLUG AND ABANDON WELLS. SINCERELY ,' STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST 1. Status of Well Classification of Service Well OIL LA'(, GAS [] SUSPENDED .ri ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-133 3. Address 8. APl Number P.O. Box 100360~ Anchora.cle, AK 99510-0360 50- 4. Location of well at surface 9. Unit or Lease Name 496' FNL, 862' FEL, Sec. 9, TllN, R10E, UM Kunaruk Riv~,r IJnlt At Top Producing Interval 10. Well I~lumber 1204' FSL, 1380' FWL, Sec. 4, TllN, R10E, UM 1B-2 At Total Depth 11. Field and Pool 1628' FSL. 12:31' FWL. Sec. 4; Tll~= RIOF~ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 90' AD~ 25648 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions l?/??/Rf~ 0!/06./8! n~ ,~'~ /m~.z-- I N~4~' feet MSLI 17. Total 'Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional ,~¢v~¢' v. I 20. Depth where__SV set I 21. Thickness of Permalrost 8153 'MD/6792 'TV[ 8027'MI3/fiRq?'TVD YES.~ NO []! l~t~n, feet MD' 22. Type Electric or Other Logs Run g [I /Ri..iPR I~..~ FDC/CNL/NCT, Pl~l ~i/rtl lP{'l l{'D I'~ .... IPl',l 23. - .......... CA~IT~, ~'r*l~'l~&~D CEMENTING RECORD SETTING DEPTH MD CASINGSIZEJWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1C, ,~.,.u= '.i-40 Sur~ ou: z,~" 200 sx Permafrost ~ ~'~1~ 45...~' EI'--.'.~¢~ GU' f 2934: 13--3/4' '~U SX Fondu & Z~U SX ~S II ' 7" 26.0~; K-55 Surf 6ii3' 8-5/4: 650 sx Ciass G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforated w/12 spf SIZE DEPTH SET (MD) PACKER SET (MD) I_ I V I! I 7544 ' -7553 ' MD'/6314' -6321 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc.I ........ .... 7558 ' -7567 'MD/6325 ~ -6332 ~TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATER IAL USED 7572 ' -7579 'MD/6336 ' -6341 'TVD 7597'-7646'MD/6355'-6392'TVD See Sundry Noting d, ted 7/17/R.K; fnr fr~ct,_,re data_ 7652 ' -7669 ' MD/6397 ' -6410 'TVD "' 7863'-7900'MD/6561 '-6591 'TVD 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) N/A , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAs-OILRATIO TEST PERIOD II~ I , Flow Tubing Casing Pressure CALCULATED.k, OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE IF' , , 28. CORE DATA ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED None NOTE: Perforated well and tubing run 5/4/81. Workovers performed 6/7/85 and 2/2/89. Fractured 7/17/85. (~'~ I STATE OF ALASKA '(l~ll ~ ' ALASKA OIL AND GAS CONSERVATION COMMISSION ./¢ '~¢" WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Submit in dupli.cate Rev. 7-1-80 105/WC5 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS NAME Top Kuparuk Top Upper Sand Base Upper Sand Top Louver Sand Base Lower Sand Base Kuparuk MEAS. DEPTH 7432 7466 7635 7854 7898 7964 31. LISTOF AT'FACHMENTS None TRUE VERT. DEPTH 6228 6254' 6384' 6555' 6590' 6642' FORMATION TESTS Include interval tested, pressure data, ali fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Area Or~lling Engr~ . Date. INSTRUCTIONS General: This form is designed 'for submitting a complete and correct well comple[ion report and Icg on all types of lands and leases in Alaska. ~tem 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. l'(em 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. ttern 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. ~tem 28: If no cores taken, indicate "none" Form 10-407 STATE OF ALASKA AL~'._,~A OIL AND GAS CONSERVATION COMMI~.~.ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown m Stimulate __ Plugging m Perforate m Pull tubing __ Alter casing __ Repair well __ Pull tubing '~z Other 2. Name of Operator ARCO Alaskaa Inc. 3'. "Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 496' FNL, 862' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1204' FSL, 1380' FWL, Sec. 4, T11N, R10E, UM At At total depth 1628' FSL, 1231' FWL, Sec. 4, T11N, R10E, UM 12. Present well condition summary Total depth: measured 8153' MD true vertical 6792 ' TVD 8027'MD Effective depth: measured 6692 ' TVD feet true vertical feet 5. Type of Well: Development '" Exploratory __ Stratigraphic m Service w feet Plugs (measured) feet measured Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: None None Workover 6. Datum elevation(DF or KB) RKB 90' Z UnitorPropedyname Kuparuk River Unit 8. Well number 1B-02 Length Size Cemented Measured depth 80' 16" 200 sx Permafrost 80'MD 2934' 10-3/4" 1:350 sx Fondu & 2934'MD 250 sx AS II 8113 ' 7" 650 sx C1 ass G 8113 'MD 7468 ' -7524 'MD, 7529 ' -7538 'MD, 7544 ' -7553 'MD, 7558 ' -7567 'MD, 7572 ' -7579 ' MD, 7597 ' -7646' MD, 7652 ' -7669 ' MD, 7863 ' -7900 ' MD true vertical 6256.'-6299'TVD, 6303'-6310'TVD, 6314'-6321'TVD, 6325'-6:332'TVD 6336'-6341'TVD, 6355'-6392'TVD, 6397'-6410'TVD, 6561 '-6591'TVD Tubing (size. grade, and measured depth) :3-1/2", J-55, tbg w/tail @ 7813' Packers arldSSS,V (type a~ndjoogg~ure, cl.~l.eDth.) Baker HB-1 pKrs ~ /z// , /:~:~- ~ 'BOT' pkr @ 7788' & OTIS 'FMX' SSSV @ 1838' 13. Sti~/u/~ation or cement squeeze Summary ' Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Prior to well operation Subsequent to operation , , feet 15. Attachments Copies of Logs and Surveys ruq.~ Daily Report of Well Operations "~ 9. Permit number/approval number 80-133/8-836 10. APl number 50-- 029-20531 11. Field/Pool Kuparuk River 0il Pool True vertical depth 80'TVD 2647 'TVD 6760'TVD Repres ,entative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure ! 16. Status of well classification as: * Oil'~ Gas __ Suspended __ Service" Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¢~ ~~/ Title Area Drill lng Engi neet Signed Form 10-404 Rev 06/15/88 * Workover Well History (Dani) SW04/013 SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report- Daily Instructiona: Prepare and submit the "Initial R'eport" 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. ARCO ALASKA INC. NORTH SLOPE Field ILeese or Unit KUPARUK RIVER I ADL: 25648 1B-2 Auth, or W.O. no. }Title AK3820 [ WORKOVER A~I .' 50-029-20531 Well no. Operator ARCO Spudded or W,O. begun IDate IHour ACCEPT 01/27/89 1400 ERS Date and depth as of 8:00 a.m. 01/28/89 ( TD: 8153 PB: 8027 SUPV:CDEV 01/29/89 ( TD: 8153 PB: 8027 SUPV:CDEV 01/30/89 ( TD: 8153 PB: 8027 SUPV:CDEV 01/31/89 ( TD: 8153 PB: 8027 SUPV:CDEV 02/01/89 ( TD= 8153 PB: 8027 SUPV=CDEV ARCO W.I. 0,0000 Pr or status if a W,O, Complete record for each day reported NORDIC I CUT MUD WT TO 9.5PPG MW:11.9 WBM FINISH WARMING AXLES, MOVE RIG FROM 1B-8 TO 1B-2. ACCEPT RIG AT 1400 HRS 1-27-89. PULL BPV. RU WL. RIH WITH 2-5/8" CHEMICAL CUTTER, CUT TBG AT 6561'. RD WL. CIRC WELL WITH DIESEL. SITP- 770 PSI. CUT MUD WT. IN PITS TO 9.5 PPG. DAILY=S39,326 CUM:$39,326 ETD:S39,326 EFC:$420,000 POOH WITH TBG. MW: 9.7 WBM FINISH CUTTING MW TO 9.5 PPG. CIRC WELL TO 9.5 PPG MUD. RETURNS CUT TO 7.0 PPG RAISE MW TO 9.7 PPG, CIRC WELL, STATIC. SET BPV. ND TREE AND NU BOPE, TEST SAME. PULLED TBG HANGER TO FLOOR. CIRC BTMS UP. POOH WITH TBG. DAILY=S57,754 CUM:$97,080 ETD:S97,080 EFC~$420,000 POOH W/ COLLAPSED GLM MW: 9.8 WBM FINISH POOH W/ 206 JTS 3-1/2" TBG. RU TO RIH W/ DP. PU OVERSHOT AND RIH. LATCH FISH 6562', CBU, POOH WITH FiSH (COLLAPSED GLM) DAILY:S27,599 CUM:$124,679 ETD=$124,679 EFC:$420,000 LAYING DOWN DRILL PIPE MW: 9.8 WBM FINISH POOH LD COLLAPSED GLM. MU RBP, RIH AND SET AT 7010'. POOH WITH 2 STANDS TEST RBP TO 1500 PSI. MU STORM VALVE AND RTTS AND SET AT 25'. ND BOPE AND TUBING HEAD. REPLACE 7" PRIMARY & SECONDARY SEALS. NU TUBING HEAD AND TEST SEALS TO 3000 PSI. NU BOPE AND TEST. PULL STORM VALVE AND RTTS. RIH 2 STANDS AND UNSEAT RBP. CIRC BTM UP. POOH LAYING DOWN DRILL PIPE. DAILY=S41,771 CUM=$166,450 ETD=S166,450 EFC=$420,000 SETTING PLUG IN X NIPPLE MW: 9.8 WBM FINISH LAYING DOWN DRILL PIPE. RUN COMPLETION OF 227 JT 3-1/2" 9.2~ BTC ABM IPC TBG AND 7 JTS 3-1/2" 9.3~ J-55 EUE 8RD ABM IPC TBG. MU HANGER AND TEST TO 5000 PSI. RU WL. RIH WITH OTIS PX PLUG. STUCK IN SSSV. SHEAR OFF, POOH. RIH WITH GS PULLING TOOL AND RETRIEVE PX PLUG. UNABLE TO KEEP PRESSURE ON SSSV. PULL TBG HANGER, SIDE PORT LEAKING. CHANGE OUT HANGER AND TEST TO 5000 PSI, KELAND TBG. RIH WITH PX PLUG, STUCK IN SSSV, SHEARED OFF AND RETRIEVE PLUG. RIH W/ 2.79"GR TO 7277. ATTEMPT TO SET PLUG IN X NIPPLE. (OTIS 'FMC' SSSV ~ 1838', BAKER 'HB-I' PKRS @ 7277', 7595', & PERM PKR @ 7788', & TT ~ 7813'.) DAILY=S34,913 CUM:$201,363 ETD:S201,363 EFC:$420,000 The above ts..eo, rrect For form proparation.al~dlS~'rlbutlon, see Procedures Man~'al,.Section 10, Drilling, Pages 86 AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well, Page no, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after aJlowable has been assigned or well is Plugged, At~andoned, or Sold. "Final Report" should be submitted also when operations are suspenOed for an indefinite or appreciable length of time. On workovers when en official test is not requirecl upon completion, report completion and representative test dala in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is avadable. Accounting cost center code API: 50-029-20531 District ~3.CO ALASY~% INC. County ort~Ee'~H SLOPE StateAK Field KUPARUK RIVER Lease or ~: 25648 lB-2 We,~ no. Auth, or W.O. ~3820 Title WORKO~R O~erator ~CO A.R.Co. V~I, 0000 Spudded or W~C{~3~p~1~ Date 01/27/89 Date and depth as of 8:00 a.m. 02/02/89 ( TD: 8153 PB: 8027 SUPV:CDEV Complete rec[q(~[~,:~ch[day reported Iotal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our 1400 HRS Prior status if a w,o. RIG RELEASED MW: 6.9 DIESEL TEST CASING TO 3500 PSI. ND BOPE NU TREE. PULL BPV, SET TEST PLUG AND TEST TREE TO 5000 PSI. DISPLACE MUD WITH WATER FOLLOWED BY DIESEL. SET PLUG IN TBG AT 7227'. TEST SSSV 1500 PSI, TEST TBG TO 2500 PSI. SET BPV. RE-ORIENT TREE SET TEST PLUG AND RETEST TO 5000 PSI. PULL PLUG AT 7227'. SET BPV. RIG RELEASED AT 0600 HRS. 2-2-89. DAILY:S50,606 CUM:$251,969 ETD:S251,969 EFC:$420,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Of c a reservoir name(s) Potential test data Well no. Date Reservoir Producing interval Oil or gasTest 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,~s' ¢,orrect S,gnatur ~& Date T,tle see Procedures Maqual/Section 10, Drilling, Pages 86 a~7. AR3B-459-3-C JNumber all dally well history forms consecutively as they are prepared for each well. Page no. Division of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date: January 30, 1989 Transmittal #: 7417 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. I B - 0 8 Kuparuk Well Pressure Report 1 2- 0 4 - 8 8 Both Sands 1 B - 0 2 Kuparuk Well Pressure Report 1 0- 2 8 - 8 8 Amerada 1 H- 0 3 Kuparuk Well Pressure Report I 1 - 2 2- 8 8 Amerada 1 D- 0 8 Kuparuk Well Pressure Report 1 1 - 2 5 - 8 8 Both Sands 1 C- 0 4 Kuparuk Well Pressure Report 1-27-89 Amerada ., Receipt Acknowledged: ........................... Date: ---; ........ DISTRIBUTION; D&M State of Alaska Unocal Chevron Mobil SAPC L(,_' STATE OF ALASKA A ,.,KA OIL AND GAS CONSERVATION COMM ,.,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well v/ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing ~ Variance ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360~, Anchorage~ AK 99510.0360 4. Location of well at surface A ~96' FNL, 862' FEL, Sec.9, TllN, RIOE, UN t top of producbve interval 1204' FSL, 1380' FWL, Sec.4, TllN, RIOE, UM At effective depth 1555' FSL, J;~5'~.' FWL, Sec.4, T11N, RIOE, UM At total depth 1628' FSL, 1231' FWL, Sec.4, T11N, RIOE, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB gQ ' Z Unit or Property name Kuparuk River Unit 8. Well number 1B-02 9. Permit number 80-133 10. APl number 50-- 029-20531 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 81 53 'MD feet 6792 ' TVD feet Plugs (measured) None Effective depth: measured true vertical 8027 'MD feet 6692'TVD feet Junk (measured) None Casing Length Structural Conductor 80' Surface 2934 ' Intermediate Production 811 3 ' Liner Perforation depth: measured true vertical Size 1 6" 10-3/4" 7" Cemented Measured depth True vertical depth 200 sx Permafrost 80 'MD 80'TVD 1350 sx Fondu & 2934'MD 2647'TVD 250 sx AS II 650 sx Class G 8113'MD 6760'TVD 7468'-7524'MD, 7529'-7538'MD, 7544'-7553'MD, 7558'-7567'MD, 7572'-7579'MD, 7597'-7646'MD, 7652'-7669'MD, 7863'-7900'MD 6256'-6299'TVD, 6303'-6310'TVD, 6314'-6321'TVD, 6325'-6332'TVD 6336'-6341'TVD, 6355'-6392'TVD, 6397'-6410'TVD, 6561'-6591'TVD ~bing(size, grade, and measureddepth) Subseque~t~¢o~ ~epor[ed o~ 3-1/2", 9.2¢. J-55, BTC tbg w/tail e 7801' ~ ~ PackersandSSSV(typeandmeasureddepth) Form No. Dated'~-~-/~'/ Packers: BOT HB-1 @ 7263', BOT HB ~ 7582', BOT 2B ~ 7775'; SSSV: Otis QLS @ 1914' 13. Attachments Description summary~.of 14. Estimated date for commencing operation December 15, 1988 16. If proposal wss verbally approved ,A~aska 0~1 & Gas Cons. Name of approver [~etailed operations program __ i5. status of well classification as: Oil / Service BOP sketch v/ Gas ~ SuSpended 17. I hereby certify that the foregoing istrue and correct to the best of mY knowledge. signed Ffj...~4.~ '~' ~ Title ^reaDr~].nq E nqjn,,r Date FOR OOMMISSIONUSE ONLY Conditions of approval: Notify Commission so representative may witness ( J'WB ) S A~/019 ~ ApprovaI No. Plug integrity BOP Test ~ Location clearance Mechanical In~rity Test ~ Subsequent form required 1~ L/¢ .... ~ R:':,turned ~, Approved by order of the Commission~ Commissioner Date Form 10-403Rev06/15/88 ~'../ Z / ' SUBMITI iCAT KRU lB-02 REPLACE COLLAPSED GLM GENERAL PROCEDURE SUMMARY: This well is a triple packer selective single completion with 3.5" tubing. A 1" GLM located at 6588' has collapsed causing a restriction in the tubing. The proposed workover consists of pulling the tubing above the first retrievable packer in order to replace the collapsed GLM. Also, the primary and secondary 7" packoffs on the wellhead will be replaced. PIlE-RIG O. pERATIONS: 1. Obtain BHP of the C Sand after well has been shut-in for at least one week. 2. Set BPV. OPERATIONS: 1. MIRU Nordic. Pull BPV. Pump kill pill as necessary. ND tree. NU BOPE. 2. POOH w/3.5" tubing above the first retrievable packer. 3. RIH w/retrievable BP on DP. 4. PU storm packer and set same 1' below tubing spool. 5. Change out primary and secondary 7" packoffs. 6. Retrieve storm packer and BP. 7. Replace collapsed GLM. Inspect other GLM's for possible damage. 8. RIH w/3.5" tubing. Stab into retrievable packer. 9. Displace well with diesel. ND BOPE. NU tree. Release rig. ANNULAR PREVENTER § PIPE RAI'IS 4 TUBING HEAD 1. 16" CONDUCTOR SWAGED TO 10-;5/4" 2. 11"-3000 PSI STARTING HEAD 11"-;5000 PSI X 7-1/16"-S000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1 / 16" - 5000 PSI BLIND RAMS 6. '7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS ;3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, :~. OBSERVE TIME, THEN CLOSE ALL UNITS SIf'IULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT, THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCPEWS ARE FULLY RETRACTED. PREDETERrlINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DO~/N SCREWS IN HEAD. CLOSE ANNOLAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, Ct\ ~TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. ~.~NCREASE PRESSURE TO 1800 PSi AND HOLD FOR I0 MINUTES. BLEED TO ZERO PSI, ~L_~%~;~PEN~,~N~ULAR PREVENTER AND CLOSE PiPE RAMS. 7. _1~ PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. %~B'~I~(~§~ VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM ~c.%~:a%aPRESSURE TO ZERO PSI TO TEST VALVES, TEST REMAINING UNTESTED Ik~,~,"' MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSt. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSi FOR 10 MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI, 12. TEST KELLY COCKS AND INSIDE BOP TO ;5000 PSI WITH KOOF1EY PUI'lP. 13, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORVI, SIGN AND SEND TO DRILLING SUPERVISOR, 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLy OPERATE BOPE DAILY. JULY 28, 1986 (kl/'tl~l~l~ ~1t~. 1 ('t..~/,,'1"~ ARCO Alaska, Inc,('r' Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 5, 1987 Transmittal # 7006 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ lB-2 ~ 1C-4 ~ 1H-4 "~ 1H-4 '~"J 1H-3 -'-~ 2F-5 '---.3 2C_9 ~ 2F-6 ~'~3C-13 ~'~3 3A_13 ~'"'~ 1L-2 ~ 1L-5 '-"' 1L-7, "'"~ 1L-1 ~---~ 1L-16 ~ 1E-4 "'~ 1F-16 '""'~ 1F-10 ~ 1F-9 ~ 1F-4 ~ lQ-9 Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Sperry-Sun Pressure Build Up Test 'A' Sand Static BHP Survey PBU Well Test Interpretation Plots 'A' Sand Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report)Otis) KOE Buildup Analysis. KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis Kuparuk Well Pressure Report 7-8-87 Static 7-7-87 'C' Sand 8-5-87 Static 8-3/5-87 PBU 8-22-87 7-19-87 AK-MS-70043 7-14/17-87 100591H 7-15/19-87 6-10-87 7-28-87 6-3.0-87' 'C' Sand 6-13-87 'C' Sand 6-14-87 Both Sands 6-17-87 Both Sands 6-18-87 Both Sands 6-14-87 Both Sands 6-11-87 'C' Sand ' 6-10-87 Both Sands 6-17-87 Both Sands 6-12-87 'C' Sand 6-9-87 Both Sands 11-3-87 Static Static Static 'A' Sand Receipt Acknowledged: DISTRIBUTION: Anchorage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B,..,. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 25, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1B-2 Dear Mr. Chatterton: Enclosed are the revised Well Completion Report and gyroscopic survey for 1B-2. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L179 Enclosures FEB 2 8 lg85 ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA (" ALASKA UlL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well REVISED Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-133 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20531 4. Location of well at surface 9. Unit or Lease Name 496' FNL, 862' FEL, Sec.9, TllN, R10E, UM Kupaurk River Unit At Top Producing Interval 10. Well Number 1204' FSL, 1380' FWL, Sec.4, T11N, R10E, UM 1B-2 At Total Depth 11. Field and Pool 1628' FSL, 1231' FWL, Sec.4, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 90' RKB ADL 25648 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 1 2/22/80 01/06/81 01/11/81'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8153'MD,6792'TVD 8027 'MD ,6692 'TVD YES I-XIX NO [] 1902 feetMD 1650' (approx) 22. Tvpe Electric or Other Logs Run D I L/BHCS/GR, FDC/CNL/NGT, CBL/VDL/CCL/GR, Gyro/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING :RECORD - AMOUNT PULLED 16" 65.0# H-40 Surf 80' 24" 200 sx Permafrost to sul'face 10-3/4" 45.5# K-55 Surf 2934' 13-3/4" 1350 sx Fondu & 250 sx t~S II 7" 26.0# K-55 Surf 8113' 8-3/4" 650 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) 7863' - 7900' :3-1/2" 7801 ' 7776' & 7268' 7468' - 7524' 7529' - 7538' w/12 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7544' - 7553' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7558' - 7567' N/A 7572' - 7579' 7597' - 7646' 7652' - 7669' .,, 27. N/A PRODUCTION TEST Date First Production ] Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested I PRODUCTION FOR OIL~BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED"~"a~' OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED FEB 2 8 1986 AIBst(a 0il & Gas Cons. COlllmll~slon Anchorag~ Submit in duplicate Form 10-407 * NOTE: This well was recompleted on 6/7/85. GRU13/WC10 Rev. 7-1180 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARl(ERS NAN/! E MEAS. DEPTH TRUE VERT. DEPTH Top Kuparuk Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand Base Kuparuk 7432 7466 7635 7854 7898 7964 31. LIS-f' OF ATTACFIIVIEN'I'S 6228' 6254' 6384' 6555' 6590' 6642' FORMATION TESTS Include intervai tested, p~essu~e (tala, ali fluids recovered and gravity', GOR, and time of each phase. N/A Revised Gyroscopic Survey (2 copies) 32. I hereby certify that ~he foregoing is ti'De and correct to the best of my knowledge / /~ , ~/,,,i,,, , Associate Engineer ~ ~1 ~,/ Signed ~_~.../._~ ~t~L,,~_ '......~ ~~ ........................ Title ............................ Date .................. _'...._~LC..Z_¢-~_~_ I NST R UC-F I O NS General: -l'his form is designed for sLlbmitting a complete and correct well completion report and log on all types of lands and leases in Alaska. I'tem 1' Classification o'f Service Wells: Gas injection, water injection, steam injec'rion, air injection, salt water disposal, water supply 'for injection, observation, ir~jection 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 forrn and in any attachments. item 16 and 24: If this well is cornpleted '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 pertiner~t to such interval. Item 21' Indicate whether 'from ground level (GL.) or other elevation (DF, KB, etc.). Item 23~ ...,~.tt.{ac.,h.ed., su,ppjemer~tal records 'for this well should show the details of any multiple stage cement- · ,, .,,i~ ~' ~ ,,.)i ',, ? ': ~' . ' ~ng an&.,tb,e ~)cat.]~.i. o0':' o~ t~.be cennent ng tool. Item 27::',~letlhod 'of,' Operation' Flowing, Gas Lift, jectk)n, Gas InjeCtion, Shut..in, Other-explain. ~,~, item 28' If n~:c,o.res taken, indicate "none". Rod Pump, Hydraulic Pump, Submersible, Water in- Form 10..407 SCIENTIFIC DRILLING INTERNATIONAL 1111 East 80th Street, Anchorage, Alaska 99502 · 907/349-3541 · Telex: 09025364 (SDC AHG) Subsidiary of AMF INCORPORATED April 2, 1982 Job #4428 North Slope Drilling- Enclosed please find our revised Gyro Survey on Kuparuk B-2 along with our Horizontal and Vertical Section maps. If any other information is needed please call 349-3541. Thank you for using Scientific and please call again. Drilling International Sincerely Manager )MPLETION REPORT '.CO OIL 6 GAS 'ROSCOP IC SURVEY ,DIUS OF CURVATURE ~MPUTED FOR SDC BY METHOD OF FM LINDSEY CONPUTATION ~ A$SOC 2 APRIL 82 KUPARUK KB ELEV 90, JOB NO 442 8 FT. 'AS. DRIFT :?TM ANGLE D TRUE VERTICAL DEPTH 100 0 0 100,00 200 0 0 200,00 300 0 0 300,00 400 0 0 400,00 500 0 O 500.00 60U 0 0 600.00 700 0 0 700,00 800 O 0 800.00 900 1 30 899,98 000 7 0 999,67 .100 8 15 1098.78 200 9 3~ 1197,58 .300 9 0 1296,28 .400 9 45 1394',95 .500 16 30 1492.28 .600 19 15 1587.44 .700 24 0 1680.38 .~300 26 30 1770.82 .qO0 30 30 1858.68 !000 34 15 1943,12 I100 37 0 2024-,~0 1200 ~1 0 2102.10 '300 ~2 O 21~6,99 :400 42 0 2251,31 SU~ SEA -90.00 10,00 110,00 210.00 310.00 410.00 510.00 610,00 710,00 809,98 909,67 1008,78 1107.58 1206,28 1304,95 1402,28 1497,44 15Q0.38 16~0,82 1768.68 1853-i2 1934.40 2012,10 2086,99 2161,31 RECORD OF SURVEY DRIFT DIREC DEG, TOTAL COORDINATES N O,OOE 0,00 S 0.00 W N47,5~W 0,00 S 0,00 W N47,46W O,O0 S 0.00 W N47,40W 0.00 S 0.00 W N47.26W 0,00 $ 0.00 W NqT,1BW 0,00 S 0,00 W N47,06W O.UO S 0,00 W N47.00W 0.00 S 0.00 W N46.93W 0.O0 S 0.00 W ND7,13W 0.~O h~ 1,03 W N74.61W 3,82 N 7.76 W N61.58w 8.75 h 20.04 W FI49,63W 17,45 N 32-75 W N63,40W 26,30 N 46,13 W N76.16~ 31.92 N 61.38 W N72.16W 38.11 N 83,21 W N78.55W 45.86 N 112,89 W NTB,60W 53.16 N 149.00 W NSO,90W 60.75 N 190,97 W N78,86W 69,13 N 237,93 W N77.71W 79,99 N 290.36 W iN75.85W 93,31 N 347.05 W N74,40W 109,46 N ~07,86 W N73,96~ 127,52 N 471,61 W N73.90W 146.04 N 535,91W CLOSURES DISTANCE ANGLE D M 0,00 S 0 0 0 W 0,00 S 0 0 0 W u,O0 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W O,OO S 0 0 0 ~ 0,00 S 0 0 0 W O,O0 S 0 0 0 W 1,30 N 52 1 59 W 8,65 N 63 48 14 W 21.87 tN 66 24 7 W 37,11 N 61 56 45 W 53.10 iN 60 18 31 W 69,19 N 62 31 30 W 91,52 N 65 23 33 W 121,85 iN 67 53 21 W 158,20 IN 70 21 51 W 200,40 N -/2 21 11 W 247.77 N 73 47 55 W 301,17 N 74 35 48 W 359.38 N -/4 57 3 W 422,30 N 74 58 3b W ~+88e55 N 74 52 9 W 555.46 N 74 45 23 w DOG LEG SEVERITY DEG/100FT 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0,000 1,500 5,506 1.278 1,292 O,603 0,83fi 6,758 2.836 4,750 2,~42 4,034 3,768 2,832 4,048 1.019 0-04~ SECTION DISTANCE 0.00 0,00 0.00 0.00 0.00 0,00 0,00 0,00 0,00 1,30 8,58 21,54 36,93 b2.97 68.78 90.38 119,37 153.47 192,60 230,33 2U5,97 340.53 400,09 ~3.16 D26.93 :~CO KUPARUK. GYROSCOPIC SURVEY JO15 NO /-+428 2 APRIL 82 RECORD OF SURVEY EAS. DRIFT EPTH ANGLE D H 2500 43 0 260O 43 0 2700 42 ,," 2800 42 0 290O .~1 30 3000 41 30 3100 41 30 3200 4`1 0 3300 41 0 34`O0 40 30 3500 4,0 0 3600 4`0 0 3700 39 4`5 ~800 40 '~ 3900 39 30 4000 39 30 4100 40 O 4200 99 0 4-300 40 15 44O0 4` 1 0 4500 42 30 4600 42 (] z~700 41 30 48O0 ~+1 0 4900 ~ 1 0 5000 40 30 51 O0 40 39 5200 39 15 5300 3B 0 TRUE VERTICAL DEPTH 2325,03 2398,17 2471.89 2546,21 2620,81 2695.71 2770.61 2845.79 2921.26 2997.02 3073,34` 3149.94 3226.09 3303,43 3380.32 3457.48 3534,36 3611,53 3688.55 3764.45 3839.05 3913.07 3987.68 4062.86 4138.33 4214,09 429G,13 4366,87 SUB SEA 2235.03 2308,17 2381,89 2456.21 2530,81 2605.71 268G.61 2755,79 2831,26 2907.02 2983,34 3059.94` 3136.69 3213.43 3290e32 3387,48 3~4,36 3521.53 3598.55 3674`.4`5 3749,05 3823.07 3897.68 3972.86 4048.33 4124,09 4200,13 4276.87 4354,99 DR IFT DIREC DEG. N73,81W N73.23W N73,05W N72,BSw N72,06W N71,48w N70,91W N72,33W N71,75W N72,28W N70.8~W N70.PSW N70.75W N71,O3W N69,68W N71,O3w N70e25W NTO.O6W N66,13~ N61.60W N58.75W N60,21W N60,81W N59.63W N60.95W N59.V3W N~O,16W N60.15~ N59.gow TOTAL COORDINATES CLOSURES D I STANCE ANGLE D M 164,~2 N 184.16 N 203,75 ~ 223,~3 N 243.96 N 264,68 'N 286,04 N ~06,8:2 N 327,05 N 347,20 N 307,62 N 389,00 N 410,38 N 431.~7 N 45~.87 N 495.44 N 517.03 N ~40,81 N 569.48 N 602,60 N 636.74 N 669.51N 702,25 N 734,77 N 767,07 N 799,59 N. 831.49 N 863,00 N 600.81 W 623,01 N 74 39 32 w 666.21 W 691.19 N 74 32 50 W 730.86 W 758,73 N 74 25 19 W 794.75 W 825,62 N 74 17 Z W 858,16 W 892,17 N 74 7 48 W 921,10 W 958,38 N 73 58 2 W 983.83 W 1024.57 N 73 47 18 W 1046.40 W 1090.4`5 N 73 39 27 W 1108.81 W 1156.04 N 73 33 57 W 1170.89 W 1221,29 N 73 28 59 W 1232,19 W 1285.87 N 73 23 14 W 1292,81 W 1350.07 N 73 15 12 W 1353,25 W 1414,11 N 73 7 46 W 1413,83 ~W . ~1478,18 N 73 1 56 W 1474.05 W 1542,05 N 72 55 17 W 1533.96 W 1605,60 N 72 49 12 W 1594.29 W 1669e50 N 72 44 12 W 1654.12 W 1733,04 N 72 38 31W 1713,28 W 1796,61 N 72 ~8 51 W 1771.72 W 1860,99 N 72 10 51 W 1829,48 W 1926,17 N 71 46 8 W i887.40 W 1991,91 N 71 21 26 W 1945,36 W 2057,35 N 71 0 31 W 2002,59 W 2122.16 N 70 40 32 W 2C59.57 W 2186.72 N 70 21 ~6 W 2116.30 w 2251.02 N 70 4 35 W 2172.51W 2314.98 N 69 47 38 W 2228,12 W 2378,22 N 69 32 7 W 2282,00 W 2439,74 N 69 17 3 W DOG LBG SEVERITY DEG/iOOFT leO01 0,398 1,003 0,446 0,519 0,387 0e375 0,789 0,383 0,548 0,770 0,37~ 0,314 0,276 0,740 0,~59 0e596 1,003 2,064 2,090 1.98~ 0,825 0,565 0,714 0.864 0.716 0.281 ].,250 1.301 SECTION DISTANCE 59~.35 656,49 721,16 785.35 84`9.39 913.25 977,29 1040,88 1104.03 1166,87 lg29.20 1291,50 1~53.65 1415,70 1477.73 1539,44 1601,39 1663.15 1725.57 1790.10 1856.53 1923.66 1990.07 2055,85 2121.29 2186.41 2251.22 2315.19 2377.~0 RCO KUPARUK GYROSCOPIC SURVEY JOB NO 4428 2 APRIL 82 RECORD OF SURVEY TRUE EAS, DRIFT VERTICAL SUB DRIFT EPTH ANGLE DEPTH S,FA DIREC D M DEG, 5400 36 30 4524.59 4434,59 N59,21W 5500 35 0 4605.75 4515,75 N57.70W 5600 34 30 4687.91 4597,91 ND6.43W 5700 33 30 4770.81 4680.81 N56,26W 5800 32 45 4854,56 4764,56 N56,95W 5900 31 15 4939,36 4949,36 N54,98W 6000 30 30 5025,19 4935.19 N52,80W 6100 29 45 5111.68 5021.68 NSOo61W 6200 27 0 5199.66 5]09.66 N48e86W 6300 26 30 5288,96 5198.96 N46,60W 6400 28 0 5377,86 5287.86 N44.86W 6500 28 15 5466.05 5376,05 N40,95W 6600 31 0 5552,97 5462,97 ND7,53w 6700 31 30 5638,46 55~8,46 N33,73~'/ 6~00 32 0 5723,50 5633,50 N32,60w 690U 34 0 5807.30 571'7,36 N31,25W 7000 36 0 5889,27 5799,27 1'129.10W 7100 37 0 5969.65 5879.65 N25,55W 7200 37 30 6049,25 5959.25 Ng3,71w 7300 40 0 6127,24 ~037.24 NZ1.76W 7400 40 O 62U3.84 6113.84 N20.OSW 7500 40 0 6280.45 6190.45 ~19.73W 760(1 40 0 6357.05 6267,05 N19.55W 7700 39 0 6434,21 6344,21 NZO,20W 7800 38 15 6512,34 6422.34 N20.O6W 7900 ~7 BO 6591,27 65C1.27 ~19,15W 8000 37 BO 6670.61 65~0,61 ~ilS,l~W 8100 37 30 6749,94 6659,9a N18,78W 8153 37 30 6791,99 6701.99 N18.60w TOTAL COORDINATES 893,99 N 2334,00 W 924,55 N 2383.79 W 955,54 N 2431,63 W 986.52 N 2478.18 W 1016,60 N 2523.80 W 1046,26 N 2567.71 W 1076.50 N 2609.17 W 1107.59 N 2648.56 W 11~8,~0 N 2684,82 W 1168.57 N 2718,13 W 1~00,~ N 2750,91 W 123b.05 N 2783.00 W 1273,3~ N 2814.26 W 1315,48 N 2844,~8 W 1359.b3 i'i 2875.27 W 1~05.75 ~ 2902.07 W 1508,17 ~i 2958.19 W 1563,18 N 2983,4Z W 1620.90 g 3U0'1,62 w 1680.95 N 3030.Sb W 1741.39 N 3052.~2 W 1801,93 ~S 3074.03 W 1861,75 N 3095,66 W 1920,35 N 3117,14 W 1978,19 N 3137.74 W 2035,86 ~ 3157,23 W 2093.~0 N 3176-53 W 2124.16 N 3186,~7 W CLOSURES DISTANCE ANGLE D M 2499.35 N 69 2 2556,80 N 68 48 2612,64 N 68 32 2667.32 N 68 17 2720.86 N 68 3 2772,69 N 67 49 2822.52 N 67 34 2870.82 N 67 18 2916,16 N 67 1 2958.68 N 66 44 3001,47 N 66 25 3044,74 N 06 4 3088,92 ~ 05 39 3133,94 N 65 10 317d,68 N 64 40 3Z72.~3 N 63 35 33Z0,46 N 62 59 341o,99 N 01 40 DOG LEG SEVERITY DEG/1OOFT 3514.22 N 60 17 43 w 3563.23 N 59 37 19 w 3612,37 N 58 58 37 W 3661,19 Iq 58 21 51 W 3709,27 N 57 46 1~ W 3756,70 N 57 Il 6 W 3804,40 N 56 36 42 W B829.91 i~ 56 i8 5~ W SECTION DISTANCE ! 29 W 1,500 2437.95 4 W 1,581 2496.33 49 W 0,644 2553.32 35 W 1.001 2609,24 36 W 0,776 2663.89 50 W 1.591 2716.87 47 W 0.937 2768.14 21 W 0,923 2818.17 26 W 2.774 2865.37 10 W 0.67~+ 2~O~.b7 22 W 1,54b i9 ,~' 2.895 3047.97 bl W 1.lPg D090,49 41 V,' 0.593 3144,8~ ~6 w 2.i5~ ~g45,9o' ~ i0 W 1,629 3~97,9~ 50 W Oef144 3349,49 41 W '2.b2 / 3401.63 b W 1.103 3~54e0~ C,ZO~ DD~5,74 0.11~ 3Db7.3U 1,033 3608.47 0.752 30bS,bb O. 823 3708 · 07 0,588 3756,27 O*gll 3829-91 OTTOM HOLE CLOSURE 3629,91 FEET AT N 56 1~ 5~ W RCO KUPARUK GYROSCOPIC SURVEY JOB NO 4428 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE ODE MEASURED VERTICAL AME DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE O .,M S 2 APR I L 82 SUB SEA 4007 3462,88 6486 5453.72 6623 5572.67 6936 5837,08 7177 6030.99 7312 613b,43 KUPARUK 7432 6228.35 UP SAND 7466 6254,40 7486 6269,72 7525 6299.60 7597 6354.75 UP SAND 7635 6383,93 LOW SAND 7854 6554.86 7862 6561.18 7877 6573.04 ~ LOW SAND 7898 6589,68 ~ KUPARUK 7964 6642.05 ~LUG BACK 8027 6692,03 'D 8153 6791.99 475.70 N 1230,50 1282,86 N 1423 · 23 N 1550.61 N 1628,11 N 172)0,30 N 1720.90 1733.03 N 1756 · 59 N 1800.34 N 1823,10 N 1951,68 N 1956,31 N 1964,97 N 1977,07 2015,10 2051,49 2124,16 N 1538,17 w 2778.17 W 2821,33 W 2912,42 W 2977.30 W 3010.37 w 3037,54 W 3049.07 W 3057,66 W 3072.72 ~ 3081,39 W 3128.38 ~ 3130,01 W 3133.04 ~; 313:7,24 W 3150'2~ W 3162.31 W 3186.87 W i610,05 N 72 48 53 W 3372.68 3038,48 N 66 6 37 W 5363.72 3099,29 N 65 32 55 W 5482,67 3241,57 N 63 57 22 w b747,08 3356,89 N 62 29 20 W 5940.99 3422.44 N 61 35 38 W 6046.43 3~81.04 N 60 45 41 W 6138.35 3497,50 N 60 31 31 W 6164.40 3507.17 N 60 23 12 W 6179.72 3526.31 N 60 7 23 W 6Z09.60 3561.30 N 59 38 O W 6264,75 3580,32 N 59 23 21 W 6293.93 3687,25 N 58 2 29 W 6464,~6 ~691,08 N 57 59 37 W 6471.18 3698.25 N 57 54 17 W 6483.04 3708,25 N ~7 46 51 W 6499,6~ 3739.59 N 57 23 39 W 6552.05 3769.46 N 57 1 37'W G602.03 3829.91 N 56 18 54 W 6701.99 ARCO KUPARUK B-2 "-:EASURED DEPTH AND OTHER OAI'A GYROSCOPIC SURVEY FOR EVERY EVE~, lOC) JOB FEET OF NO 4428 SUB SEA DEPTH, APRIL ~2 TRUE MEASURED VERTICAL DEPTH DEPTH SUB SEA N.1D-TvD DIFFERENCE VERT I CAL CORRECTION TOTAL COORDINATES 19(') 190. 290 290, 390 390. 490 490. 590 590. 690 690. 790 790. 890 890, 9gO 990. 1091 1090, 1192 1190, 1294 1290. 1395 1390. 1498 1490, 1603 1590, 1710 1690, 1921 1790. 1937 1890. 2057 1990. 2184 2090. 2317 2190, 2452 2290. 2589 2390. 2724 2490, 2859 2590. 2992 2690, 3126 2790, 3258 2890, 3391 2990. 3522 3090, 3652 3190. 3782 3290. 3912 3390, 4042 3490. 4172 3590. 100 200 300 400 500 60O 700 800 900 1000 1100 1200 130o 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 29(}0 3000 3100 3200 3300 3400 3500 0 0 0 0 0 0 0 0 0 1 2 4 4 7 12 20 31 67 94 127 162 199 234 269 302 336 368 401 432 462 492 522 5~2 552 0 0 0 0 0 0 0 0 0 1 1 2 0 3 8 11 15 21 27 33 35 37 35 33 34 32 33 31 30 30 30 30 30 0.00 S 0,00 0.00 S 0,00 0,00 S 0.00 S 0.00 S 0,66 N 3,4b N 8,28 N 16.75 iN 25.96 N 31.78 N 37.97 N 46.05 N 54,00 N 62,44 N 73,17 87.67 N 10/.27 N 130.84 N 156.26 N 182.53 N 208,48 N 263,2} N 29i,~2 N 318,77 N 345.90 N 372.40 N 400,42 428,00 N 455,58 N 48D.06 0,00 0,00 0,00 0,00 0.00 0,00 O.O0 0,82 18.86 31e66 45.16 60,53 82,55 113.76 153,00 200,33 256.~7 322,17 b69e36 6D~e'?4 746.2£ 915.9~ 999,94 1082.53 1165.00 1245,33 13Z4,18 1402.76 1481.1~ 1559.24 i0~7,45 ARCO KU:P ARUK B-2 v.,.EASURED DEPfH AND OTHER DATA GYi<OSCOP I C SURVLY FOR cVrRY ~.VLN 100 JOin ~EE1- Oh ,NO 442d APRIL 82 MEASURED DEPTH T iR U E VERT I CAL DEPTH SUB SEA MD-TVD DIFFERENCE VERT I CAL C Oi-4.~ EC T I ON l'OfAL COORDINATES 4302 4434 4569 4703 4836 4968 5100 5230 5357 D481 5602 5723 5842 5959 6075 6189 6301 6414 6527 6643 6760 6879 7001 7125 7252 7382 7512 7643 7771 7898 8024 8150 3690 3790 3890 3990 4090 4190 4290 439(3 4490 4590 4690 4790 4890 4990 5090 5190 5290 5390 549O 559O 5690 5790 5890 5990 6090 6190 6290 6390 6490 6590 6690 6790 3600 3700 3800 3900 4000' 4100 4200 4300 440O 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5'700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 611 643 679 713 746 778 810 840 867 891 912 933 952 969 985 999 1011 1023 1037 1053 1070 1089 1110 1135 1161 1192 1222 1253 1281 1308 1334 1360 29 32 33 32 30 27 24 Zl 21 19 17 16 14 12 iL 14 16 17 19 21 25 31 30 28 27 26 54i,31 626,7i 67o.51 7~7,Z2 799,9~ 840,91 880,84 956,i7 99~,60 1064,41 1100-12 1135,41 1205,20 i2.5.02 1291,27 1341 · 9b i39b,97 1455e79 1521,85 1592,87 1670,20 1740,68 1827.8- 1977,07 2049,76 2122.54 17i~,40 1791.23 1~69.12 i947.0~ 2022,85 20~7.9~ 2172,16 Z244.~5 2311.6~ 2374,22 2488.67 2592,17 26~U,60 2680,6U 2718,~5 Z755,38 2791,~4 Z~Z7,3~ 2861,49 2895,69 2931,15 2964,50 2995,70 ~020.14 5054.94 3083,00 31i0.85 3137.2~ 3161.74 ~18~.93 ARCO KUPARUK B-2 GYROSCOPIC 5UI<VEY JO~5 r.4. O q. 428 2 APRIL INTEi-~POLATED VALUES FOl-< EVEN 1000 FEb[ OF- ,,Vi&ASOREL) DEPi-ri, TRUE MEASURED VERTICAL SUB DEPTH DE PTH SEA TUTAL COORDINATE$ 1000 999, 2000 1943, 3000 2695- 4000 3457, 5000 4214. 6000 D025. 7000 5889, 8000 6670. 909. 3,86 N 7,74 1853, 80,71N 290,20 2605. 264,99 N 92i,00 3367, 474.62 N 1533,82 4124. 767,90 N 2115,82 4935. 1077e14 N 2608,69 5799e 1455.42 N 2930.74 6580, 20~5,92 N 3157,06 SURFACE LOCATION IS 496' SNL, 862'WEL, SEC. 9 t TIIN~ R IOE, U.Id. 400 800 VERTICAL SECTION ARCO ALASKA INC. KUPARUK WELL B-2 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE : I" = I000' APRIL 2~ 1982 12OO O ~-~soo ALL DEPTHS SHOWN '~oo ARE TVD , ~000 °°1~~ · $~' T~D : 8155' F E El 2 8 ]986 Alaska 0il & ba~ (;utlS. uuil,~]ission Anchorage HORIZONTAL VIEW ARCO ALASKA INC. KUPARUK WELL B-2 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE = I" = I000' APRIL 2~ 1982 TVD = 6792' TMD = 8155' 4 $ 9 I0 862' T II Nv R IOEt U.M. ALL DEPTHS SHOWN ARE TVD RECEIVED FEB 2 8 1986 Alast(a Oil & Gas Cons. Commission Anchorage / / Drill Site lA Wel 1 No. "1A-4 ,~1A-5 1A-7 ~1A-9 -1A-11 ~.. '~1A-12 '~IA-14 '~ 1A-15 '",lA-16A ATTACHMENT I I KUPARUK RIVER UNIT Production Logs Log Date 7/6/83 10/29/83 5/7/82// 1125182~- 3/23/83 / 1/19/83') 3/21/83/ 3/8/82 4/1/82 6/5/82 5/11/82% Drill Site Well No. Log Date 18 "~18-1 12/26/81 ~18-2 6/25/81 '~i8-3 11/16-18/81"-7 '~ 3/12/82 ./ '~18-6 11/18/81~ '~ 9/10/82/ "18-7 11/23/81 ~18-8 12/28/81",~ '~ 8/4/82/ "18-9 __ 6/24/82,._~, % Drill Site 1C Wel 1 No. '"~lC-1 '"'1C-2 '~1C-3 ',~1C-4 ~'~ ~lC- 5 ,. '"~1C-6 '~1C-7 "~ 1C-8 Log'Date 5/9/8'1 5/8/81 7/13/81 11/8/81> 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 · Drill Site 1D Well No. Log Date z/8o% ~' 5/23/83/,. "~1D-3 8/5/80 " 1D-4 "'7/30/8 0"'~' ~,,- ~. 8/13/80/ ~ ~1D-5 6/11/81 .... ~1D-6 6/9/81 ~1D-7 6/8/81 · '..-: "~1D-8 (ws-8) 5/10/78' · . · . , RECEIVED '.--: :.::- :.:::i?!:-::-- · . · ...-_... . ...... ,~_:_... Alaska 011 I Gas Cons.' Commission..~%~¢%~.::: · Anchorage ':-~'~.',:>".-.9~:~.-.'.~~ .. ,. .... 7 ~':-:' '."-.4.; ,-~ e-." "'~'.".- " .-~'.-.':.'-?~2_'~,~':':':Y.' ARCO Alaska, Inc. Ii" Post Office B(~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1B-2 Dear Mr. Chatterton' Enclosed is the Well Completion Report questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L120 Enclosure for 1B-2. If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . STATE OF ALASKA ,~', ALASKA{' _AND GAS CONSERVATION C AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-133 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20531 4. Location of well at surface 9. Unit or Lease Name 496' FNL, 862' FEL, Sec.9, T11N, R10E, UN Kupaurk River Unit At Top Producing Interval 10. Well Number 120#' FSL, 1380' FWL, Sec.4, T11N, R10E, UM 1B-2 At Total Depth 11. Field and Pool 1628' FSL, 1231' FWL, Sec.4, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i I Pool r~lL9 /98~, RKB ADL 25648 12. Date Spudded 12/22/80 13. Date T.D. Reached 01/06/81 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns 01/11/81' N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I'VD) 19. Directional Survey i 20. DePth where SSSV set 21. Thickness of Permafrost 8153'ND,6792'TVD 8027'ND,6692'TVD YES E~X NO []I 1902 feet MD 1650' (approx) 22. Type Electric or Other Logs Run D I L/BHCS/GR, FDC/CNL/NGT, CBL/VDL/CCL/GR, G.yro/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 80' 24" 200 sx Permafrost to su:'face 10-3/4" /+5.5# K-55 Surf 2934' 13-3/4" 1350 sx Fondu & 250 sx ,S II 7" 26.0# K-55 Surf 8113' 8-3/4" 650 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) 7863' - 7900' 3-1/2''- 7801' 7776' & 7268' 7468' - 752/+' 7529' - 7538' w/12 spf 26. ACID, FRACTURE, C'EMENT SQUEEZE, ETC. 7544' - 7553' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7558' - 7567' N/A 7572' - 7579' 7597' - 7646' 7652' - 7669' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I1~ FlowTubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE =~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ~il~. ~,.. E ~ V t U NONE Alaska Oil & Gas Cons. Commission Anch~,r'a~ Form 10-407 -b NOTE: This well was recompleted on 6/7/85. DRH/WC27 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Kuparuk Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand Base Kuparuk GEOLOGIC MARKERS MEAS. DEPTH 7432' 7466' 76:35 ' 7854' 7898 ' 7964' TRUE VERT. DEPTH 6228' 6254 ' 6:384' 6555 ' 6590' 6642' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS .- Wo rJ(o_v,e L.~e/]._J~i s t.o ~y 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer Date ..... ,. 9-2~-~' 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 o'f 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 t© be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether fronq 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-.40'7 ARCO Oil and Gas Company Well History- Initial Report- Daily Inetmctlone: Prepare and submit the "Initial Rel~l" on the first Wednesday after a well la spudded or workover operations are started, Dally work odor to spudding should be summarized on the form giving Inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 904490 lCounty, parish or borough North Slope Borough Lea~e or Unit Title ADL #25648 Recompletion State Alaska IWell no. lB-2 W-WS #1 AP1 50-029-20531 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun [Date IHour Pr or status if a w.o. Workover [ 5/31/85 [ 0100 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 5/31/85 6/01/85 thru 6/03/85 6/04/85 6/05/85 6/06/85 The above is correct For form prepar~lo~and ~lietl~utlon ' - see Procedures Menus, Sectl6n 10, Drilling, Pages 86 and 87. 7" @ 8113' 8027' PBTD, Pull lower dummy vlv 9.9 ppg NaC1/NaBr Accept rig @ 0100 hrs, 5/31/85. well to crude. ND tree, NU & tst BOPE. Displ 7" @ 8113' 8027' PBTD, POOH 9.9 ppg NaCi/NaBr Pmp 40 bbls BridgeSal pill, followed by 9.8 ppg brine. Set BPV. ND tree, NU & tst BOPE to 3000 psi. Mx & spot pill across perfs. Pull 3½" tbg, chg out colts to AB Mod. RIH w/3~" DP, fsh pkr, circ out gas bubble, observe well. POOH w/pkr & tailpipe. PU fsh'g tls. RIH, wsh to 7772' TOF. Latch onto fsh, circ, POOH. Rec'd 4' of 3½" tbg & 3' of 2-7/8" tbg. RIH w/RTTS to 7000'. Tst csg; OK. POOH. 7" @ 8113' 8027' PBTD, POOH w/wshpipe 9.9 ppg NaC1/NaBr ND BO?E, chg out tbg head, NU & tst BOPE to 3000 psi. pull BP. RIH w/wsh pipe to 7762', wsh dn & CBU, POOH. 7" @ 8113' 8027' PBTD, POOH w/gage ring & JB 9.9 ppg NaCl/NaBr RIH w/OS. POH w/fsh. RIH, circ hole cln. RU WL. 7" @ 8113' 8027' PBTD, Att to set pkrs 9.9 ppg NaCl/NaBr RIH w/pkr & tailpipe assy, set @ 7785'. RIH w/compl string. Locate into perm pkr, drop ball. : SSSV @ .1902',HB.Retr'v Pkr @ 7268', ~ , 2-B Perm. Pkr @ /776', "D" Nipple @ 7793, TT @ 7801'.) q RECEIVED <: EP 3' 0 15,85 Alaska Oil & Gas Cons. Commission Anchora, qe Date 6/20/85 ITM Drilling Superintendent AR3B-459-1-D Number all dally well history forms a8 they are prepared for each we I. consecutively iPag~ no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repoil completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit lWell no. Kuparuk River ADL ~25648 I lB-2 Auth, or W.O. no, T t e AFE 904490 Recompletion WWS #1 AP1 50-029-20531 A,R.Co. W.I, 56.24% Operator ARCO Alaska, Inc. Spudded or W.O. begun Date Workover 5 / 31/85 Date and depth Complete record for each day reported as of 8:00 a.m. 6/07/85 TcOtal number of wells (active or inactive) on this est center prior to plugging and labandonment of this well IHour Prior status if a W,O. 0100 hrs. 7" @ 8113' 8027' PBTD,..RR 7.4 crude Press tbg to 2500 psi to set pkr. Tbg would not tst. Shear PBR, POH w/tbg. Tst GLM's; leak in contrl in. Lnd tbg & tst to 2200 psi. Tst ann to 1500 psi. Set BP . ND BOPE. NU tree. Tst SSSV. Tst pack-off & tree to 5000 psi. Displ w/diesel & crude. Shear ball w/3500 psi. Set BPV. RR @ 0600 hfs, 6/7/85. Old TD New TD PB Depth 8027 ' PBTD Released rig Date Kind of rig 0600 hrs. 6/7/85 Rotary Classifications (oil, gas, etc,) Type completion (single, dual, etc,) Oil Single Producing method Official reservoir name(s) Flowing ' ~Kuparuk Sands Potential test data Well no, Date Reservoir ! Producing IntervalOil or gasTest 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 see Procedures Manual, Section 10, Drilling, Pages 86 and 87, The above is correct AR3B-459-3-C Alaska 0ii & Gas. Corts. C0~fflrFiJssJor~ A~ch(~age Number all daily well history forms consecutively Page2. no. as they are prepared for each well. Dlvl,ion of AllantlcRIchfleldCompsny ARCO Alaska, Inc.(' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-18-85 TiiANSMITTAL NO: 5358 RETURN TO: ARCO ALASKa, INC. KUPARUK OPERATIUNS ENGINEEkING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERkl~ITB AAAE ThE FOLLOWING IT.4~S. PLEASE ACKNOWLEDGE R~.'CEIPT AND I~ETURN ONE SIGNED COPY OF TiiI$ TRANSMITTAL. PRESSURE DATA ~QU~NCk' OF EV~NT~ lA-3 C1 SAND PBU 08-11-85 DKESSEI~ ATLAS -"~B-2 PBU C-1 SAND 08-05-85 DRESSER A~LAS 1C-5 PBU 07-29-~5 DA{ESSER ATLAS -'--2H-1 A SAND POST FRAC PBU 08-24-85 DRESSER ATLAS SEQUENCE OF EVENt'S F~{L~M WELL SEI~VICE REPORTS ~'"iG-!i SlBhP & HISC. 09-09-85 1G--ll SIBHP & MISC. 09-10-85 CAMCO CAMCO KU~-.~{RUK WELL PRESSURE kl~PORT ENVELOPE DATA -" 1B-.-~ PBU C-1 SAND 08-05-85 1C-~ PBU 07-29/30-85 DRESSER ATLAS DRESSER ATLAS RECEIPT ACKNOWLEDGED: BPAE* B. CURRII~R CHEVRON* D & M* DRILLING L. JOHNSTON MOBIL* NSK CLERK DISTKISUTION: W. PASRER EXXON PHILLIPS OIL* J. RAT[~MELL* STATE OF ALASKA* SOHIO* UNION* K .'£ULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc Post Office Bi[.,, 100360 Anchorage, Alask~ 99510-0360 Telephone 907 276 1215 DATE: 09-10-85 TRANSMITTAL NO: 5341 RETURN TO: ARCO ALASKA, INC. KUPARUK OPEt{ATIONS ENGINEERING KECOP. DS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITiL~IS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. CASED HOLE LOGS (FINALS): ~XlQ-15 --"- 'CBL 6/12/85 8000-8745 ~ iQ-l-- CCL & PERFORATING RECORD 4/16/85 ~J 2V-9---- COMPLETION RECORD 4/25/85 7525-7800 ~ ~2H-15"' 'COMPLETION ,RECORD 4/13/85 6998-7438 -v2H-2-- CCL & PERFORATING RECORD 4/24/85 '-~ 2H-14-- CCL & PERFORATING RECORD 4/23/85 ~'~2H-16-" CCL & PERFORATING RECORD 4/19/85 ~-~lR-9-- PERFORATING RECORD 8/3/85 7800-8000 ~;1B-2--- PACKER SETTING RECORD 6/5/85 7290-7820 ~-'~lA-9" PACKER S~TTING RECORD ~/15/85 6700-6950 - ~ 2H-13-- COMPLETION RECORD 4/17/85 7434-7650 ~'~IR-10 "~ PERFORATING RECORD 8/5/85 8300-8550 x~2Z-8-'~ COMPLETION RECORD 4/27/85 8920-9030 o~J 3B-11_- CET 7/5/85 6500-9100 RECEIPT ACKNOWLEDGED: · DISTRIBUTION: BPAE DRILLING* W. PASHER B. CURRIER L. JOHNSTON EXXON 'CHEVRON ~OBIL PHILLIPS OIL D &,,M NSK CLERK* J. RATHMELL UNION K.TULIN/VAULT ARCO Alaska, Inc. Post Office"-- )x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT~: 09-05-85 TkA.N SMITTAL NO: 5332 R~TURN TO: ARCO ALASKA, INC. KUPARUK. OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 A~C~OKAGE, AK 99510 TRANSMITTED HERk~ITH ARE THE FOLLOW RECEIPT AND RETURN ONE SIGNED COPY SEQUENCE OF EVENTS PRESSURE DATA 1H-3 -" PBU 2A-I--- 'C' SAND PBU 2B-12',-- 'C' SAND PBU 2C-~ 'A' SAND PBU 2V-2 - 'A' SAND PBU 2V-5 '~ 'A' SAND PBU ENGINEERING ING IT]iMS. PLEASE ACKNOWLEDGE OF THIS TRANSMITTAL. 03-07-85 08-03-85 08-01-85 08-16-85 07-27-85 06-25-85 SEQUENCE OF lA- 8 "~ bBHP lA-5 lA- 3--'"' lA- 3--' 1B-2-- 1B-2--- lb-5 / 1E- 21~%. RUN 1F-5 PBU 1F-5 / 1G-15--" 'C' 1G-15''~ 'A' 1G-15/ 'C ' EVENTS FROM WELL SERVICE REPORTS/PRESSURE DATA & MISC. PBU & MISC. PBU PBU 'C' SAND PL~U 'C' SAND PBU STATIC TEMP.LOG BHP & MISC. 'A' & 'C' bAJ.qD {ISLTD) SAND PBU SAND PBU SAND PBU iR-10-'/ BHP & MISC. 1R-9/ Blip & MIbC. 1R-12 .- Blip & MISC. 2A-l~ 'C' SAND PBU 2A-1'/ 'A' SAND BHP 2A-1'''~ 'C' SAND PBU 2A-13.- Bt/P & MISC. 2B-13~- 'A' SAND BHP 2B-13-' 'C' SAND PBU & MISC. DATA FROM Blip SURVEY 'C' SAND Pk~U PBU PBO PBU ACKNOWLEDGED:. 08-22-85 08-14-85 08-12-85 08-11-85 08-05-85 08-06-85 08-15-~5 08-03-85 08-18-~5 08-17-85 08-10-85 08-06-85 08-09-85 08-15-85 08-15-85 08-19-85 08-04-85 08-04-85 08-03-85 08-25-85 08-02-85 08-02-85 08-03-85 08-01-85 08-17-85 08-17-85 08-1~-85 2B-13-~ 2B- 13-'" 2G-16" 2G-16/ ~LCEIPT DRILLING L. JOHNSTON [uOblL NbA CLERK DISTRIBUTION: W. PAStiER EXXON BPAE B. CURRIER CHEVRON D & M *PLEASE NOTE--DISTRIb- NEXT PAGE. DATE: ~,~'~ / ~./ ~'I,.., SOhiO "~ P~ILLIPS OIL UNION ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCo~npany ARCO Alaska, In~. Post Offic[ ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 TRANSMITTAL NO: RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECOPJ3S CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING TRANSMITTED HEREWITH AKL rx'~g FOLLOWING I'i'~lb. P~,gASE RECEIPT AND RETU~J~ ON~ SIGNED COPY OF %'HIS TRANS~IITTAL. PRESSURE FINALS/ASSORTED VENDE~S CAMCO 1C-4 / STAT.lC GRADI~:NT 04-25-85 2G-1 ~ PRESSURE BUILD-UP 04-17-85 OTIb 2X~ ~5 '~ FLOWING PRESSURE 07-09-85 TO~<,2 UE TURN 2D-2~'''' 24 HOUR PBU 04-21/22-~5 GUAGE LYNES / 2X-4 ~' PRESSURE R~PORT 08-12-85 DRESSER ATLAS lA-5/ PRESSURE SUkVEY 08-13-85 lB-2"/ PRESSURE SURVEY 08-05/06-85 1Y- 2 '"' PRESSURE SURVgY 08-07-85 2C-8'// PRESSURE SORVEY 08-16-85 2G-9~' PRESSURE SURVEY 08-22-85 2H-l~ PRESSURE SURVEY 08-24-85 2W-7 PRESSURE SURVEY 08-22-85 2X-11~/ P~ESSURE b URV].:Y 0~-25-85 5331 ACKNOWLEDGE #63137 RECEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE* DRILLING W. PASHE~ B. CURRIER L. JOHNSTON EXXON CHEVRON* HOBIL* PHILLIPS OIL* D & M* NSK CLER/< J. RATHMELL* DATE: STATE OF ALASKA* SOHIO* UNION* K.TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inv' Post Office= ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO:5292 RETURN TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECOtiDS CLER/{ ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED itECEIPT AND KUPARUK lB-1. 1B-2~ ~iB- 4· 1C-4 1C-6 1D-8 .... --1H-3 ~lQ_13.~'' ~lQ_14-~t "'lQ- 15 "lQ-16 1R_5 1R_6--~ / ~lR-7./ -' 1R-8 j' "2A-2 .... ~2W-7"' ~2 V- 3 3B-t 3B-2~- 3B-3 .... "3B-3" -.3B-4" "3B-5 -~' '3B-6 --3B- 7.' 3B-7-- 3B-8~' -3B-9" ~,3B- 10-~ -3B-11 -- 3B- 12 3B-13' ~3B-14 RECEIPT HEREWITH ARE THE RETURN WELL PRESSU 05-30-~5 05-30-85 05-16-85 07-24-85 07-25-85 07-30-85 07-30'85 06-24-85 06-23-85 06-21-85 06-21-85 07-05-85 07-06-~5 07-06-85 07-08-85 07-04-85 FOLLOWING ONE SIGNED COPY OF THIS TRANSMITTAL. RE REPORT--ENVELOPE FACE DATA CAMCO . ~3B-15 05-28-85 CAMCO 3B-16 -' 05- 28- 85 CAMCO ~ 3C-11.''~ 07-29-85 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS 0.7-26-85 DRESSEi{ 07-11-85 OTIS .08-04-85 OTIS 06-14-85 ???? 06-1.4 - 85 CAMCO 06-28-~5 OTIS 06-15-85 CAMCO 06-15-85 CAMCO 06- 26- 85 CAMCO O 6- 2 6- 8 5 CA[~ICO 06-28-85 CAMCO 06- 27- 85 CAMCO 06-28-85 OTIS 07-18- 85 CAMCO 07- 20- 85 CAMCO 07- 20- 85 CAMCO 07- 21- 85 CAMCO 05-29-85 OTIS 05-29-85 OTIS ACKNOWLEDGED: DISTRIBUTION: ,, DRILLING W. PAShER L. JOHNSTON EXXON ~DBIL* P~ILLIPS OIL* NSK CLERK J. RATHMELL* BPAE* ' B. CURRIER CHEVRON* D & M* ITEMS. PLEASE ACKNOWLEDGE OTIS OTIS CAMCO STATE OF ALASKA* SOHIO* UNION* K . TULIN/VAULT ARCO Alaska, Inc. ~s a Subsidiary of AllantJcRJchfJeldCompany RETURN TO: ARC~r ~laska, Inc. I,)st Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-19-85 TRANSMITTAL NO: 5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO- 1 ! 15B P.O. 'BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH .ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE, FLUID,. AND ACID DATA I.B~! .~.~ SBHP 05-3 0-85 ~tI~~,. '~ "' ~l~g?~ '~ 111 ~"?""~:~ SBHP' 05-30-85 lB-4 SBHP 05-16-85 lB-4 PRE-WORKOVER 05-24-85 iD-8 SBHP 04-29-85 1E-iA TUBING LEAK 05-03-85 1E-5 COMP PBU ETC.. 04-28-85 !E-11 LEUTERT BI{ SMPL 06-02-85 1E-23 SBHP 05-22-85 !E-23 SBHP 05-23-85 IE-27 TEMP/SPIN-LEAK 05-03-85 1E-27 TUBING LEAK 05-04-85 1G-6 PRESSURE FALL- 05-07-85 OFF 1H-6 SBHP 04-29-85 1L-5 PBU W/E-LINE 04-27-85 1L-5 PBU 04-29-85 lQ-1 . ISIP ~ 05-30-85 .!Q-1 SBHP 'A'SDS 05-26-85 lQ-3 TAG FILL BHP 05-18-85 lQ-4 SBHP 'C' SD ETC 05-10-85 lQ-4 SBHP ETC 05-14-85 lQ-4 ACID JOB' 05-17-85 lQ-5 ISIP TEST 04-29-85 lQ-7 ACID JOB 05-26-85 !Q-9 'C' SD PBU 05-12-85 lQ-9 PBU 'C'SD ETC 05-13-85 1Y-12 FALL-OFF TEST 05-05-85 2A-2 BHP 05-27-85 2A-4 'A'SD BHP 05-10-85 2A-4 'A'SD BHP 05-09-85 2A-4 'A'SD BHP 05-11-85 2A-5 SBHP 05-05-85 ***CONTINUED ON THE FOLLOWING RECEIPT ACKNOWLEDGED: BPAE* DRILLING B.'CURRIER L. JOHNSTON CHEVRON* MOB IL* D & M-'~' NS K CLERK (ONE COPY OF EACH) CAMCO CAMCO CAMCO CA CO CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO B. J. HUGHES CAMCO CAMCO CAMCO 'CAMCO NOWSCO/B . J. HUGHES B. J. HUGHES NOWSCO/DOWELL CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO PAGE *** L~'S'Tt{ TB UTION: W. PASHER EXXON PHILLIPS OIL* J. P, ATHMELL~ DATE: ALASz%A~. '~'STATE 'OF "~" ..... 7SOHIO, . U NI ON* K. TULIN/VAULT ARCO Alaska, InC. is a Subsidiary of AtlanlicRichtieldCompa.y ARCO Alaska, lnc' o~ Post Office B x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- Well 1E-lA 1E-lA 1E-27 1E-30 1F-6 1F-13 1G-1 1Q-5 1Q-6 1Q-7 1Q-11 1Q-13 1Q-14 1Q-15 1Q-16 1Y-2 1Y-8 1Y-12 2A-2 2C-8 2C-14 2H-15 2V-2 Action Fractu Fractu Cancel Cancel Cancel Polyme Cancel Cancel Cancel Acidize Acidize Fracture Cancellation Fracture Fracture Fracture Fracture Conversion Conversion Conversion Conversion Cancellation Acidize Stimulation Conversion re re lation (Reper f) lation (Frac) lation (Frac) r Project lation (Frac) lation (Frac) lation (Stressfrac) (Frac) (Perf) Date Performed 6/14/85 6/14/85 1/5/85 6/23/85 6/24/85 6/25/85 7/2/85 7/1/85 7/2/85 7/2/85 3/30/85 3/30/85 3/30/85 3/31/85 7/2/85 6/30/85 5/16/85 on the If you have any questions, please call · T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COtVl MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, ! NC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION. T11N, R10E, 5. Elevation in feet (indicate KB, DF, etc.) 98' (RKB) 12. 496' FNL, 862' FEL, Sec. 9 UM 7. Permit No. 80-133 8. APl Number ~ 50- 029-20531 9. Unit or Lease Name KUPARIJK RIVFR IINIT 10. Well Number 1B-2 11. Field and Pool KUPARUK RIVER FI ELD 6. Lease Designation and Serial No. KU PARUK R I VER O I L ADL25648 POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~] Abandon [] Stimulation ~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including 'estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 14 1985, the "A" sands of Kuparuk well 1B-2 were hydraulicaily fractured and propped to improve production. The treatment consisted of 353 BBLS of gel led diesel as pad and carrying fluid and 11,920 LBS of 100 mesh and 20/40 sand as proppant. 74 BBLS of gel led diesel was used as a flush. Prior to pumping, equipment and lines were tested to 5000 psi. RECEIVED JUL1819'~5 ~laska Oil ~ ~.~ 'uu~l~. ~ornmission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,/~O,,c~'~ ~~ Title KUPARUK D te 7 / 17 / 85 The space below for Commission use OPERATIONS COORDINATOR L~> Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Ii" Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 11, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001~ Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells: 1B-2 1B-4 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L64 Enclosures [ FCEJVED Gas Cons. Com~iss~oll Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~' STATE OF ALASKA OL ALASKA OiL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-133 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 496' FNL, 862' FEL, Sec.9, T11N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 98' 12. I 6. Lease Designation and Serial No. ADL 25Gb, R Al K 8. APl Number 50- 029-20531 9. Unit or Lease Name Kun~r~k Riv~_r IIn~ 10. Well Number 1B-2 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig @ 0100 hrs, 5/31/85. Killed well. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled 3-1/2" tubing. Retrieved pkr and tailpipe. Tstd csg to 2000 psi - ok. Set pkr @ 7785'WLM. Ran completion assy. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp w/crude. Set BPV. Secured well & released rig ~ 0600 hrs, 6/7/85. J U L ,I 198,5 '.';::~:,','..:~ Od & (:;as Cons, Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~!0 ~~/ ,~/L~~j Title Associate Engineer The space belo for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU10/SN06 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~o~ ,,d0360 Anchorage, A~aska 99510-0360 Telephone 907 275 J235 May 16, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Kuparuk 1B-2 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1B-2 to a selective single completion. Since we expect to start this work on May 26, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/PJA/tw SN/L033 Enclosure 1 6 1.o85 Alaska 0i~ & ~.~ Co~s, Commission Anc:'~oraga ARCO Alaska, ~nc. is a Subsidiary of AtlanticRichfieldCompany '{O STATE OF ALASKA OL ALASKA ~L AND GAS CONSERVATION C iMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 496' FNL, 862' FEL, Sec.9, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 80-!33 8. APl Number 50- 029-20531 9. Unit or Lease Name 12-2 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool _ RYR 98' 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon Stimulation Repair Well [] Change Plans [] Repairs Made (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] Pull Tubing ~1 Other m~itt Pulling Tubing comp etions (Note: Report multiple on Form 10-407 with a sub ed Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1B-2 to a selective single completion. follows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A CET will be run to test for zone isolation between the A and C Sand. A squeeze will be performed, if required. 4. A retrievable packer will be run to test casing. 5. The well will be completed as a selective single with three (3) packers. 6. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: May 26, 1985 ~~o[~ ~D"t*~.~-~~- MAY 619~5 ~ --- Alaska OlJ & Gas Cons. Commission Anc~0raffe 14. I hereby certj4'C'~at the foregoing Es true and correct to the best of my knowledge. Signed / /f~ _ _ _ , ~- Title Area Dri l I i ng Engineer ~onditio~ of ApprOval, if any: ,/. Approved by O~I'~TN~I. SIGtiEB ~j~proYecl jleturned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 (PJA) SN/057 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office( 100360 ' Anchorage?,,taska 99510-0360 Telephone 907 276 1215 A T '/" N · [;: E f-.'. 0 R I),":: C L. E F;: I< A'T 0-.- i i i Y B P.,[)~ B{]X i".}0¥6() ANCHOF::&[;E., A!'.'.'. $:9'Ti 0 1' IE' R ['"' W I T I..I A F;.: I.--. T l..I.r..i: F 0 L. I.. [)H ]: f..! 6 RETLIF:N (]hie :' · .. _ ,.~ .,. 6 i',! E D r". 0 I'"' Y L'I F' ,~] AT].C BHF' £TA'T I C.. BI"IF' STAT * .... ~. U BHP ,:., , ,..~ T I C r., r"', · ::, I'] I" ,?TATIr',.., BHF' £TATIC BHP SOE./STAT ]: C S T A T I C B H F:' ,?OE/STAT I C STATT. C ]3HF' ~ r.:) E ...' .? 'r ¢.~'r' ]; c ::,'/TAT Z C 2 O_r" ,.,' 2 T A T I ,_.r' ,_,TATIC BHF' "1 ""% I, :.., T A D A T A I) A 'f' A DATA ' D fi T'A DATA BHP DA'TA BHP DATA BFIP DATA BI. IF' DATA SE]E/'A' SAND F'BU STATIC _T...:I--IF' ,,,,..~Tr-~ F'BU DATA STATIC BHF' DAT~ STATIC BI"IF' DATA .......... · ... .... PBU DATA . SOE,."F'BtJ 'C' 5./A i"l D I 0 C) r.:' ,..- S) ~ i 4 I 1' E iq ,?, F:' L E A,'.;' El A C I< N. 0 !,,.J L. E D [.:. I':: T I"11 S T F;: A i'..!.'? H I T T A I.., I/: ':.> .a i / 2 6/' 8 '3 t/27/8'"-'.., t /")A /,~&. --t / %,2 ../ ,~, ~...... ~,, ~ .,...' 2/t 'I/8.5 n," i t/EtS 2/I 2/i '~ · '2 / i n / · ') r-, / ,~..? 7, ,.., _.' 2 / 9 / 2/24/"' -:; · (?... '" 27,8-=-. :&...,' ~,'. I / '..: _" ~,.) .y /.m) --? · .',./ ~'. I ,'/ t..j _.:. ~:. / .._,, ,"j _: I) I S T F;,' I I.-: U 1' I (] N · I.,,1 ,, F','-':: £ I"1 I!" R E X X [) H F' H I 1.. I... I F:',:? (] I 1... J,. F:ATHHELI. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany . ARCO Alaska, In~ Post Offic~~ ,.ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4992 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. STATIC~ BHP REPORTS & WSW f/24 12/29,28/84 1H-4 '11/25/84 1C-4 12/05/84 lB-2 12/03/84 1D-8 12/06/84 SEQUENCE OF EVENTS Static BHp 12/29,28/84 · SBHP 11/25/84. Static 11/26/84 Statid BHp 12/05/84 Static BHP 12/03/84 St'atic BHP 12/06/84 /cat Receipt Acknowledged: B. Currier BPAE Chevron D & M Drilling Geology Mobil NSK Ops. DISTRIBUTION Date: W. Pasher 'G. Phillips Phillips Oil J. Rathmell Sohio Union Well Files ARCO Ale~ka. Inc is a sub~idis~'y of AllanticqichiieldCompen¥ ARCO Alaska, Inc. /- :,c ~:o:a.o.:.. , ~ka 9cj£10 ?e~ephone 907 277 5~37 Date: 10/05/84 Transmittal No: 4739 Return To: · . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 tted herewith are the following items. Please acknowledge receipt Cz and return one signed copy of this transmittal. SEQUENCE OF ~S PBU Surveys/·PressureAnalysis lB-2/ 9/08/84 Camco 9/08/84 SBHP 1F-2~- 9/15/84 Otis 9/15/84 2V-6f 8/17/84 Torque Turn 8/17~84 2V-7 8/17/84 " " 8/17/84 SET 2V-3 8/17/84 8/17/84 2C-6 8/18/84 ~' ~' 8/18/84 ' /cat Receipt Acknowledged: DISTRIBUTION B. Adams D & M ' G. Phillips F.G. Baker Dzilling P. Baxter Geology Phillips Oil BPAE Mobil J.J. Rathmell Chevron Alaska Oil & £~as~l~on~R.Co~D~_.~[ell' W.V. Pasher AnchoT.~ge State of Alaska Sohio Union NSK Operations R & D Well Files KUPA~UK I~1 NEERING D. W. Bose/Shelby J. Matthews ' TranSmitted herewith are the fol lowing: PLEASE I',DTE: BL - BLUELINE, 'S - SEPIA, F - FILM, T - TAPE, ~ l~- .~ -~_~_._ ~f-~F:> ~...~£u~__.~ ~/~__.~.o -(- ~-e~"~-~. q-2q-~T~ '. ~- ~-~ ~ t~ '" .... ~c' " "~-'~~~ LIPT A2KN~VLEIZi;ED: ' PLEASE R.E-RJ~,I RECEI PT TO: ~ ALASKA, INC. ATTN: SHELBY J. k,A~E¥~,S - ATO/1115-B: P. O. BOX 100360 ~E, At(.. 99510 KUPARUK ENGINEERING TO' William V~-n Alen TRANSMITTAL ~ -. ...... FROM. D. W. Bose/Shelby J. Matthews DATE: ,.-~---/~' ~' WELL NAME' .~ ~ A~.~') Transmitted herewith are the following- PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM~PC - PHOTOCOPY . . ._ - L/'~LEASE R~TURN RECEIPT T(J: ARCO A~ASKA, INC. . - .' A'TTN- SHELBY J. MATTHEWS- AFA/311 P.O. BOX 360 A/aaka Oil & Gas Cons. ANCHORAGE, AK. 99510 Anchorage TO: KUPARUK ENGINEERING DATE: ~ /,~ ~/~.7, WELL NA34E: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE R~E~[T ACKNOWLEDGED , LEASE RETURN RECEIPT TO: ~m~'.a'Oi~& Gas Cona Coir~. issio~ ARCO ALASKA, INC. A~c.~orage ATTN: LORIE L. JOHNSON - AFA/311 P. O. Box 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. t~ Post Office Bo,. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 30, 1982 Mr. Ghat Chatterton State of Alaska 0il & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Comm. Attached please find Sundry Report for Kuparuk Well 18-2. Sincerely, Area Operations Engineer V33/bl Attachment Notice Subsequent ARCO A~asl(a., I!nc. is ;:~ s~,'bsidiary of AUanticb~ich~ie~dCo~:'~?any ,,. ALASKA IL AND GAS CONSERVATION C iv~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX[] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80- 133 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20531 4. Location of Well 9. Unit or Lease Name Kuparuk River Un£t . HL - 1555'FSL, 1256'FWL, Sec 4, T11N, RIOE, UM 10. Well Number 1B-2 urface - 496'FNL, 862'FEL, Sec 9, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. (up ar uk i 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool (uparuk River Field River 0il Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation X [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well 1B-2 was acid stimulated on 3/9/82. coiled tubing unit was used to spot and squeeze acid over the perforated in'terval between 7468'-7669' MD. 12% HC1 acid with mud and silt remover was used. Clean up of 'the wellbore was effected by flowing the well with gaslift. A total of 147 bbls of acid and 188 bbls of diesel were used in the procedure. Pre-stimulation rate was 1372 BOPD and current rate is 1752 BOPD. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~x ~ ~0~ Area Operations Engineer Signed . - ~. __ I _ _~ Title The space be~ for Commission use~ II.,-~, Conditions of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date ......................................... Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA jr" ALASKA~ .L AND GAS CONSERVATION C~ ..MISSION ,WELL COMPLETIUN OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Pear, it ~l~ber ARCO Alaska, Inc. - 3. Address 8. APl Number P.0.Box 360, Anchot`age, AK 99510 50- 029-20531 4. Location of well at surface 4c36' I' NL, 862 i I' hL, Sec 9, Ti iN, Ri 0E, 9. Unit or Lease Name Kupat`uk 25648 At Top Producing lnterval 1204'FSL, 1380'FWL, Sec 4, T11N, R10E 10. WellNumber 1B-2 AtTotal Depth 1628'FSL, 1231 'FWL, Sec ~-~, T11N, R10E, 11. Fieldand Pool ~.~. Kupat`uk River Field 5. Elevation 90'in feet RKa(indicate KB, DF, etc.) { 6. LeaseADLDesignation25648 and Serial No. Kuparuk Rivet' 0il Po°l 12. Date Spudded12/22/80 13. Date T.D. Reached1/6/81 14' Date C°mp" SuMp' °r Ab;and' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns1/11/81. , -- . feetMSL. 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 1 20. Depth where SSSV set 21. Thickness of Permafrost 8153' 6792' 8027' 6692' YES ~( NO []I 1705 feetMD 1650' (approx) 22. Type Electric or Other Logs Run DIL/BCHS/GR, FDC/CNL/NGT, CBL/VDL/CCL/GR, Gyro/CCL '23. ' CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE ITOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED lg" '"65# H-40 Sut`f 80' ' 24" 200 sx Permafrost :o sut`face' 10 ~,/z~,, 45.5# K.-55 Surf 2934' 13 3/4' 1350 sx AS III & 2 50 AS II .... · 7" 26~ K._-.55 Sut`f 8113' 8 3/4" 650 sx Class "G" cement , 24. Perforations open to Prddu:d~ion (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7468'-7524' 3 1/2" 7438' 7367' 7529'-7538' . , 7544'-7553' w/12 SPF 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7558'-7567' DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 7572,_7579, ', ,N/A, , 7597 '-7646 ' 7652'-7669' 7Rt~':l ' _701313 ~ 27. ' .... pRODucTION TEsT , , Date First Production Method of OPeration (Flowi.ng, gas lift, etc.) , 12/'14/81 FloWin'.( ',' ., Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO g/24/81 14.45 TEST PERIOD .1~ 1789 626 -- 4,8/64I 350 Flow Tubing Casing Pressure CALcUI'ATEE~ '1~ . OIL-BBL GAS:McF WATER-BBL ~)IL GRAVITY-APl (corn) · Press. ]90 -- 24'Hou'R 'RATE -~ 2972 '1040 -- 24.2 28. CORE DATA ,. , , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , , . , ,. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30, NAME Top Kuparuk River Form. Base Kuparuk River Form. GEOLOGIC MARKERS MEAS. DEPTH 7426' 7964 ' TRUE VERT. DEPTH 6224' 6642' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ldAR t 0 1982 Title Area 0ps. Engr. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location o'f the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office B~ .... 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 2, 1982 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Attn' Commissioner Dear Sir' Attached are t_h~_~. Sundry Notices for an acid treatment on Well__lB-2 in ~uparuk River Field. This treatment is the same as those performed on Kuparuk wells last year. Verbal approval for this work was obtained from Russ Douglas on March 1, 1982, since we have equipment on standby waiting to do this work, and plan to start the treatment on March 2. Sincerely, Laura K. Blacker Senior Operations Engineer Kuparuk River Field slz SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Arco Alaska, ]:nc. '" 3. Address P.O. Box 360 Anchorage, AK 99510 4. Location of Well Surface Location 496' BH Location 1205' 5. Elevation in feet (indicate KB, DF, etc,.) _ KB 98' 12. FNL, 862' FEL, Sec. 9, T11N, RIOE FSL, 1380' FWL, Sec 4, T11N, RIOE 7. Permit No. 80-133 8. AFl Number 50- 029-20531 9. Unit or Lease Name Kuparuk River Unit 10. Well Number lB-2 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool ADL 25649 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and .give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to stimulate the Kuparuk Sands with acid. Acid will be spotted and squeezed with a coiled tubing unit with BOP assembly tested to 4000 psi. All circulated and flowed fluids will be diverted to tanks off location. Once the well is. cleaned up it will be flow tested through the CPF test separators. Estimated start date is 3/2/82. Received verbal approval from Russ Douglas to Laura Blacker on 3/1/82. 14. hereby certify that the~foregoing is true and correct to the best of my knowledge. The space ~w for"~Commission usc Date Conditions of Approval, if any: Approved by R.~turned, By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,' ' "?', .... STATE O? ALASKA CO'~,' ALASKA t,{,_ AND GAS CONSERVATION i.. ,~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Name of Operator DRILLING WELL [] COMPLETED WELL F__3 7. Permit No. OTHER ARCO Alaska, 3. Address P.O.Box 360, 4. Location of Well See below Inc. Anchoraq_.e_z..AK 99510 See below 8. APl Number 5o- See below 9. Unit or Lease Name See below. 10. Well Number S ae__b_e 1_o~ .... 11. Fiel.d and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. / _See below k_Sae_helaw. Kuparuk P_iv~r Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~ Abandon [] Stimulation [_-~] Abandonment ["] Repair Well [] Change Plans [] Repairs Made [~ Other XE~ Pull Tubing E~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all Pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.!05-17.0). During August 1981 ARCO Alaska, Inc. performed a water injectivity test in the Kuparuk Sands to gain pertinent reservoir data in preparation for its Increment I Waterflood of the Kuparuk Sands. Injection was successfully achieved in that Upper and Middle Kuparuk Sands in Well lB-2 but not achieved in the Lower Sand in Well lB-1. Reservoir pressure response was monitored in two wells, lA-3 and lB-5.' Water for the test was produced from our water source well No. 1. A brief review of test is attached. Well API Number Location Elev. Unit Name Lease Designation lB-1 50-029-20465 Sec,9 TllN R10E KB-98' Kuparuk 25648 ADL 25648 ~~. 50-029-20531 Sec.4 TllN R10E KB-98' Kuparuk 25648 ADL 25648 lB-5 50-029-20237 Sec.9 TllN R10E KB-89.5.' Kuparuk 25648 ADL 25648 lA-3 50-029-20615 Sec.5 TllN R10E KB-100' Kuparuk 25647 ADL 25647 WS-1 50-029020090 Sec.9 TllN R10E KB=98' Kuparuk 25648 ADL 25648 14. I here~_____~..,~oin~~ t to the best of my knowledge. The sp~lowVfor C/m r~ _u.s_e__~.__~ ._~._~__~.j__~g_._._.~.~._~_~:~__, Conditions of Approval, if any: ' By Orde,' of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Attachment to Sundry Notices and Reports on Wells Kuparuk Water Injectivity Test The Kuparuk Water Injectivity Test began on August ?, 1981 with injection into the Upper and Middle Sands in Well lB-2 at a constant surface pressure of + 1050 psi. Injection continued until August 24, 1981. A stabilized injection rate during this period of +1050 BWPD was observed. An average BHP of + 3850 psi during this Period yielded an injectivity index of + 1.7. Injection profiles run during the test indicated that the majority (70%+) of the water was going into the Middle Sand. After completion of the steady state~' injection period, injec- tion was stopped for a pressure fall off test. Following this shut~ in period, a step rate test was run. Results of the step rate test indicated a reservior parting pressure of + 4320 psi. · Having successfully demonstrated the injectability 'of the Upper and Middle Sands in lB-2, attention was turned to the Lower Sand in Well lB-1. On August 27 attempts were begun to estab- lish injection in lB-1. Two attempts to begin injection with surface pressures of up to 2250 psi were unsuccessful. A coiled tubing unit was used to displace wellbore fluids with diesel and again attempt to inject. This too proved unsuccess- ful. The well was.flowed to be sure that the perforations were open. No further efforts to inject were made. It is felt that some sOrt of plugging is preventing injection in the well. The test was concluded on August 30, 1981. During the injectiVity test, reservoir pressure response was monitored in' two offset wells, lA-3 and lB-5. A bottom hole pressure increase of ~ 3.7 psi and ~ 8.0 psi respectively was measured in the wells. Attached as part of this report are charts and plots of injec- tion parameters, step rate testing, and offset pressure response. HCV 10/26/81 KUPARUK ~ATER INJECTIVITY TEST Steady State Injection DATE 8 6 8 7 '8 8 8 9 8 10 8 11 8 12 8 13 8 14 8 15. 8 17 8 18 8 19 8 2O 8 21 8' 22 8 23 8 ,24 /NJ RATE BHP TEMP & P 0 3230.9 2448 3847.9 2398 3827.3 2273 3817.5 1520 3854.2 1254 3861.0 1210 3867.5 1301 3811.4 1297 3855.3 1018 3850.1 1063 3846.7~ 1068 3843.7 1112 3848.9 1082 3842.4 975 3844.3 1063 3846.5 1050 3844.8 923 3860.8 160.2 76 69 69 77 77 77 77 76 76 77 77 76 76 75 77 75 78 617.0 596.4 586.6 623.3 630.1 636.6 580.5 624.4 619.2 615.8 612.8 618.0 611.5 613.4 615.6 613.9 629.9 II 3.97 4.02 3.87 2.44 1.99 1.90 2.24 2.08 1.64 1.73 1.74 1.80 1.77 1.59 1.73 1.71 1.47 Cumulative Steady State Injection = 22 MBW 2500.- 2000- 15oO- 5OO- KUPARUK WATER IHJECTIVITY TEST IilJECTIOI,I RATE KUPARUK lB-2 6 I ~10 , DAYS' · l ,14 : · . · ' 4000~. 380-9-- 360O-- 34OO- 320O- 300O KUPARUK WATER INJECTIVITY TEST IflJECTION, BHP · INJECTIVITY INDEX · ,, ! kUPARUk 1D-2 .~ . · ,.:, .3 :,. '-' >,.: ; ,:.-, I - · ' I ' ' I'. ' " i .... J' ' I ' ' I I · 5 ~ 2? 4 6:-- 8, -' . 10 12 14 16 .. if:::, , ,_:. - . ""'L' ' ' t ... ..... DAYS ; · · . ; .... .: ..... ,- _5 _4 _3 _2 18 KUPARUK ~fATE~ INJECTMTY TEST Step Rate Test INJ PRESS iNJ RA~ B}~P 'TEMP AP II 0 3260 122. 750 336 3433 117. 173 1.94 1000 692 3797 109. 537 1.29 1250 1266 4068 100. 808 1.57 1550 3060' 4344 77. 1084 2.82 1800 4648 4490 70. 1230 3.78 '2000 7968 4554 64. 1294 6.16 --~, .... 4250 - · Cz..3 ~ · . · ~ -- '4000 - ': ........... :'' 3750 - ' ' '% ~L3500- 4500 ............ . .. KUPARUK WATER INJECTIVITY TEST STEP RATE TEST KUPARUK 1B-2 ; , ,i.:~-~. :.__L ........ · : ' ,''~ ..... : :i : ! ._ k~3PARLS< WATER INJECTMTY TEST ~,~nitor Wells Pressure Response DATE 8 6 8 7 8 8 8 9 8 10 8 11 8 12 8 13 8 14 8 15 8 16 8 17 8 18 8 19 8 20 8 21 8 22 8 23 8 24 8 25 8 26 8 27 8 28 8 29 KUPARU]< lB-5 T~P 3261.8 3262.1 3261.6 3262.6 3263.5 3263.8 3264.4 3264.3 3265.3 3265.7 3266.4 3266.9 .3267.4 3267.9 3268.4 3268.6 3269.3 3269.8 3270.0 3269.9 3270.2 3270.3 3270.2 3270.2 157.1 157.1 157.2 157.4 157.6 157.6 157.7 157.9 157.9 158.0 158.1 158.2 158.3 158.4 158.5 158.6 158.5 158.6 158.7 158.7 158.7 158.7 158.8 158.8 KUPARUK lA-3 Tt~4P 3173.4 158.2 3173.4 158.4 3173.4 158.6 3173.6 158.8 3173.8 159.0 3173.9 159.1 3174.0 159.2 3174.2 159.4 3174.4 159.6 3174.6 159.7 3174.9~ 159.9 3175.1. 160.0 3175.3 160.1 3175.5 160.1 3175.7 160.2 3175.9 160.3 3176.2 160.4 3176.4 160.6 3176.7 1'60.7 3176.8 160.8 3177.1 161.0 Pressure Response + 8.0 PSI Pressure Response _+ 3.7 PSI 3180.0- 3177.5 - 3175.0 - 3172.5 3170.0 - . KUPARUK W/LTER INJECTIVITY TEST MOIiITOR WELLS PRESSURE RESPONSE 2 zl 6 8 10 , Kuparuk !A-3 I ' ~ l ............ ~ ........ l" '--- ~ ~ ...... =--F-~='-= =-~ 12 14 16 18 20 22 ,. 24 ,, 3270.0 3.2,6 Y. :5 3265..'0 3262.,5 3260.0 4 6 8 i0 Kuparuk 1Bi5""' 1o lq, 16 18 20 22 , , 24 .. ARCO Alaska, In~,,. Post Office, .,, 360 Anchorage. Alaska 99510 Telephone 907 277 563? October 1, 1981 Mr. William VanAlen State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine DriVe Anchorage, Alaska 99504 Attached is well test information for Wells A-l, A-2, .~~ C-l, C-2, C-7, C-8. The test results were obtained subsequent to the completion of the Well Completion Report (Form 1-407) or Sundry notice (Form 10-403) which was submitted to you. . ineer EAS/bl Attachments I £CE.'IVED OCT 1 ~ .12L71 4nchorago ARCO Alaska, Itl(: i: ,'t ~,i, ub--,Idi;',iy Of AIInr'Hi,'.:Hicl'tlI,,idC. olrH);~,u~, Supplementary Test Data A-1 A-2 RU WLU, tested lub. to 2500 psi. RIH with HP, temp tool, gradiomanometer, & fullbore flowmeter. Opened well for flow test and survey. HP tool set at 5933'ss Flowed at rate of 2880 BOPD. GOR=387 FTP=325 psi, FBHP=1860psi. Ran .... p~'~oduction logs. si well for PBU, final SI BHP=3094 psi. POH with PL string. Secured well 7-3-81. RU WLU, tested lUb. RIH with fullbore spinner, temp. tool, HP, gradiomanometer & CCL. HP tool set at 5948'ss. Opened well for flow test and survey. Flowed at rate of 2971 BOPD. GOR=410, FTP=685, FBHP=2490 psi. Ran' ProdUction logs. SI well for PBU, final SI BHP=3091 psi. POH with PL string. Secured well 8-2-81. S-'2 C-1 RU WLU, tested lub. RIH with spinner temp too1, HP and gradio. HP tool set at 6145'ss. Opened well for flow test and. survey. Flowed at rate of 2972 .... BOPD. GOR=350, FTP=380, FBHP=2131 psi. Ran production logs. SI well for PBU, final SI BHP=3173 psi. POH with PL string, Secured well 6-26-81. Production test results: Flow rate = ~.4~8,0.~_ BOPD, GOR=435, FTP=400 psi, FBHP=1990 psi.. HP tool set at 6329'ss0 SI well for PBU, final SI BHP=3252 psi. POH with PL string. Secured well 5-9-81. C-2 RIH with HP, temp tool, gradio and fullbore flow- meter. HP tool set at 6307'ss. Opened well for flow test and survey. Flowed at rate of.,~,~, BOPD. GOR=401 FTP=270 psi, FBHP=1866 psi. Ran production logs. SI well for PBU, final SI BHP=3160 psi. PDH with PL string. Secured well 5-7-81. October 1, 1981 Supplementary Test Data Page Two C-7 RU WLU, tested lub. to 2500#. RIH with HP, gradio, temp tool and spinner. HP tool set at 6458'ss. Opened Well for flow test and survey. Results unreliable due to bad test data SI & Secured well on 5-18-81 Retest performed 7-12-81. RIH with production tool, set HP at 6489'ss. Opened well for flow test and survey. Flowed at rate of 1528 BOPD. GOR=344, FTP=170 psi, FBHP=3244 psi. Rah'"~production logs. SI well for PBU, final SI BHP=3240 psi. POH with PL string. Secured well 7-13-81. C-8 RIH with HP, temp tool, gradio, spinner and CCL. HP set at 6448'ss. Opened well for flow test and survey, Flowed at rate of 413 BOPD. GOR=366, FTP=120 psi, FBHp=2181 psi. '~'~'~' porduction logs. SI well for PBU, final SI BHP=3264 psi. POH with PL string. Secured well 5,23-81. NORTtt '~LOPE EHGI[~EERII~G TRAH..,.I!TTAL ¢ ¢~V TO' //~/~ ~/~~ FROM: J. J. Pawelek/Ann Simonsen DATE' ~-'2-<-~-"~ f WELL HAME' Transmitted herewith are the fol'lowing: PLEASE HOTE' BL - BLUELIHE, S - SEPIA, F - FILM, T - TAPE REC"I, T ACK~IO',.:LEDGE~, /~ ~ ~ / ~v~~ - ~ E RETURN RECEIPT TO: ARCO ALAS~, INC. ' ATTN' ANH SIMONSEH - AFA/311 P.O. BOX 360 A~.~CHO~'~,~ AK 99510 HOP, TH 5LOPE Ei'IglHEERIHG ( TO' TRAHSMITTAL # ,. FROM' J.J. Pawelek/Ann Simonsen DATE' ~ ~ 0.--'-"~? WELL IIAME' Transmitted herewith are the following' PLEASE HOTE'~-BLUELIHE, ~-- SEPIA, F- F"ILI,I, T - TAPE ~'"RETUR~'4 RECEIPT TO: ARCO ALAS~&, INC. ATTN' ANN SIMONSE!,I P.O. BOX 36O ANCHORAGE, AK '. 9951 DATE' - AFA/31 1 AUG ? 1 1'38'i A~sska Oil & Gas Cons. Commission Anchorage TO' IIORTIt SLOI:E E[IGI~,IEERi!I(:: TRAIiS~.II TT,AL L~ J J. Pa,.,eieu · ,, ,./Ann Sim, r]nsen -. Transmitted herewith are the follo~.,,,ing' ~r' PLEA~ IIOTE' BL - BLUELIilE, S - SEPIA, F - FILM, T - TAPE RECEIP'T,. ACKiIO',,,'I_EDGED!...~ ./.1..~,.,~...~..'.C.x.,!,,.. ~.."._~_ -.._ DATE' r, ..- ' · I rt C ,-, TUP,~; P, EC~I?T TO ARCO ALAS~Lq · ~ · ATl'ii' AIJi,I SIi,IO~tSEiI - AFA/311 P.O. BOX 360 A;ICIiC, R.,AGE, AK 99B10 ~ STATE OF ALASKA ALASKi' .)IL AND GAS CONSERVATION £~ ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER FX 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 4. Location of Well 5. Elevation in feet (indicate KB, DF, etc.) See be1 ow See bel ow ,%' · IL,, I 6 . Lease Designation and Serial No. See bel ow 8. APl Number 5o- See below 9. Unit or Lease Name See bel ow 10. Well Number See bel ow 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations . [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment J~ Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10.407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In preparation for its Increment I Waterflood of"the Kuparuk sands, ARCO Alaska, Inc. intends to perform a water injectivity test in two wells in late July and August, 1981. The purpose of' the .test is to gain pertinent .data on the ability of the Upper, Middle, and Lower Kuparuk Sand segments to accept injected waters. In addition, reservoir pressures in offset wells will be monitored to attempt to determine response to the injection. We anticipate a maximum of three weeks of testing, injecting into the B-1 (Lower Kuparuk) and B-2 (Upper & Middle Kuparuk) wells. Continuous monitoring of pressures and periodic production logging'will characteristics. Monitoring of reservoir press injection, the A-3, B-4, and B-5 will be used i injection. Water for the injection testing wil wel 1 No. 1. be used to aid in determining injection ures in three offset wells during the n evaluating reservoir response to the 1 be produced from our water source l~[ected start date is Jul~ 27 1981. API NUMBER L6CAT~ON B-1 50-029-20465 Sec 9 T' ~.. 50-029-20531 Sec 4 T' B-4 50-029.20595 Sec 9 T' B-5 50-029-20237 Sec 9 T' A-3 Not Assigned Sec 5 T' WS-1 50-02.9-20090 Sec 9 T' s, ELEVAT. IONS 1N RIOE KD = 98' 1N RIOE KB = 98' 1N RIOE KB = 98' 1N RIOE KB = 89.5' 1N RIOE KB = 100' ~. RIOE KB = 98' UNIT NAME Kuparuk 25648 Kuparuk 25648 Kuparuk 25648 Kuparuk 25648 Kuparuk 25647 Kuparuk 25648 / 14. I hereby certify that the foreg'oing is true and Ct°rrect to the best of my knowledge. · / ' / The spac~elow for Commission use LEASE DESIGNATION ADL 25648 ADL 25648 ADL 25648 ADL 25648 ADL 25647 ADL 25648 Date ¢ - 2'.,,,~'-g / Conditions of Approval, if any: Approved by, "~ 'B~ rder of COMMISSIONER theComm~ss~on } Date ................. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duphcate ARCO Alaska, Inc. Post Oftico ,U, ox 360 . Anchorage;( ..... 'asl,,n 99F, 1 Telephone~. , 2'?: 5{~3" June 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 4-13 DS 16-6 DS 5-1 DS 16-13 DS. 12-9 DS 17-7 DS 12-10 ~ DS 13-12 DS 14-18 B-3 DS 14-19 C-8 ., Dear Si r' Enclosed please find' , 1.) The subsequent sundries for DS~4-13 & DS 5-1. 2.) ,The'monthly reports for DS 12L'~]0, DS 14"19, DS '16u13, DS i7-7, "A- 1 & B- 3"./ " ,/. ~./ 3.) The completion reports for DS 12L9, DS 13'"'12, DS 14-18, DS 16-6~. 4 ) ~,iThe-. G~;r°'scopic' Surveys'"'for DS '12 DS"' 1~7i"'8, DS 1~~ ' - . ~~,Sincerely' P.A. VanDusen District Drilling Engineer PAV/KJG' sr Enclosure ..- .... (L STATE OF ALASKA ALASKA" ,. AND GAS CONSERVATION C . .,,¢IISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. gn-133 3. Address 8. APl Number P.O. Box 360. Anchoraae. AK 99510 5o-029-20531 4. Location of well at surface 9. Unit or Lease Name ' 496'FNL, 862'FEL, Sec 9, TllN, R10E, UM Kuparuk 25648 At Top Producing Interval 10. Well Number 1204'FSL, 1380'FWL, Sec 4, TllN, RIOE, UM B-2 At Total Depth 11. Field and Pool 1628'FSL, 1231'FWL, Sec 4, TllN, RlOE, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Ku.paruk River 0i 1 Pool 98' RKB ALU 25648 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 12/22/80 l/6/81 1/11/81 feet MSL 1 17. Total Depth (MD+TVD)18. Plug Back Depth ,MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21.Thickness of Permafrost 8153'MD 6792'TV£ 8027'MD 6692'T\D'ES~ NOl-1 1705 feetMD 1650' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/NGT, CBL/VDL/CCL/GR, Syr0/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 surface 80' 24" 200 sx Permafrost to surface 10-3/4" 45.5# K-55 surface 2934' 13-3/4' 1350 sx Fondu & 250 sx AS II 7" 26# K-55 Surface 8113' 8:3/4" 650 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) '7863- 79_0~ 3~" 7438' 7367' 7529-7538w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7544-7553. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7558-7567 n/a ,, 7572-7579 7597-7646 , ,. 7652-7669 27. PRoDucTION TEST Date Fir,st Production .. Method of Operation (Flowing, gas I!f,,t, etc.) n/a Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MifF WATER-DEL CHOKE SIZE IGAS-OILRATIO .. TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ ., 28. CORE DATA ,, · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , none ',' :: : : , · ,., Form 10-407 Submit in duplicate. Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T Kuparuk 74321 6228' .none T Up Sand 7466' 6254' B Up Sa nd 7635' 6384' T Low Sand 7854' 6555' B Low Sand 7898' 6590' B Kuparuk 7964' 6642' 31. LIST OF ATTACHMENTS Completion History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/~i1~o ~~ Title D.ist, Dr']g. Engo Date ~ //?//~/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 del~ails 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". B-2 COMPLETION HISTORY Accepted rig @ OlO0 hrs, 4/23/81. ND tree. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Displ well w/lO.O ppg NaC1. RIH w/pkr & Vannguns on DP. Set pkr @ 7812'. Dropped perf bar & perfd 7863-7900' w/12 spf. Ran SOS gradio survey/temp survey/HP/CCL. Flowed well. SI well. RIH for samples. Bullheaded brine to pkr @ 7367' & killed well. POOH w/pkr & Vannguns. Ran 3½" perf completion assy w/tail @ 7438' & pkr @ 7367'. Tstd tbg to 3000 psi & ann to 500 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Displ NaC1 w/257 bbls diesel thru GLM @ 7317' Dropped perf bar & perfd 7468- 7524', 7529-7538', 7544-7553', 755~-7567', 7572-7579', 7597-7646', & 7652-7669' w/12 spf. Flowed well f/clean up. SI well. Bullheaded diesel to 2000'. Equalized press across SSSV. Secured well & re- leased rig @ 0200 hrs, 5/4/81. STATE OF ALASKA "I~OHTHLY ALASKA('LAND GAS CONSERVATION C~?~MISSION REPORT DRII,.LING AND WOR..OVER OPERATIONS · Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 80-133 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 so-029-20531 4. Location of Well at surface 496'FNL, 862'FEL, Sec 9, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 98' RKB ADL 25648 9. Unit or Lease Name Kuparuk 25648 10. Well No. B-2 11. Field and Pool Prudhoe Bay Field Kuparuk River 0il Pool For the Month of: April , 19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks .... Commenced operations @ 0100 hfs, 4/23/81. Ran perf equip and perfd well. tbg, as of 4/30/81. (See attached Workover History) RU to run 13. Casing or liner run and quantities of cement, results of pressure tests 16" conductor to 80'. Cmtd w/200 sx Permafrost. 10-3/4" csg w/shoe @ 2934' Cmtd w/1350 sx Fondu and 250 sx AS II. 7" csg w/shoe @ 811"3'. Cm~d w/650 sx Class G. 14. Coring resume and brief description n/a 15. Logs run and depth where run CCL, Gradio/Temp/HP. Subsequent Work Beported on Form No. -------- Dated ---/--/-- Alaska 0i/& ~as Co 6. DST data, perforating data, shows of H2S, miscellaneous data Perfd 7468-7524' w/l'2 spf 7527-7538' 7544-7553' 7558-7567' 7572-7579' 7597-7646' 7652-7669' 17. I hereby certify'that the foregoing is true and correct to the best of my knowledge. SIGNED-~./~, '7~~ TITLE District Drilling Eng. NOTE--Report on 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. Form 10-404 Submit in duplicate Rev. 7-1-80 B-2 WORKOVER Accepted rig @ OlO0 hrs, 4/23/81. ND tree. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Displ well 10.0 ppg NaC1. RIH w/pkr & Vannguns on DP. Set pkr @ 7812'. Dropped perf bar & perfd 7468-7524', 7529-7538', 7544-7553', 7558-7567', 7572-7579', 7597-7646', and 7652-7669' w/12 spf. Ran SOS Gradio survey/Temp survey/HP/CCL. Flowed well. SI well. RIH for samples. Bullhead brine down to pkr @ 7812' & killed well. POOH w/pkr & Vannguns. Circ & cond .~$g to run tbg, as of 4/30/81. ~. 'ARCO Alaska, Inc. Post Office B(. Anchorage. Alaska ~J.g510 Telephone 907 27'7 5637 May 13, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 5-1 DS 5-10 DS 9-18 DS 12-9 DS 14-18 DS 16-5 DS 16-6 Dear S ir' Enclosed please find' j e 3. 4, DS 1 6-13 B-2 C-7 C-8 ~T-3C .CONFIDENTIAL W. Sak #18 CONFIDENTIAL The Completion Report for DS 16-5. The Completion Reports and Gyroscopic Surveys' for C-7, W. Sak #18& T-3C. (Please note that W. Sak #18 & T-3C are to be considered confidential). The Monthly Reports of Drilling & Workover Operations for DS 5-1, DS 14-18, DS 12-9, DS 16'6, DS 16-13, B-2 & C-8. The Subsequent Sundry Notices for DS 5-10 and DS 9-18. Sincerely;. P. A. VanDusen District Drilling Engineer PAV/KJG:sp Enclosures ARCO A'c~:ik;~ In~ n-' u %~Ji:,', r ,' ~,~, (d Athlrlllcfln:',hlic, i P (,Int);'~,T ARCO Alaska, In~:. ~~ Post Office ~^ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 16, 1981 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 14-9A DS 16-1 DS 16-10 DS 16-11 B-2 Dear Sir' Enclosed please find the Monthly Reports of Drilling Operations for DS 14-9A, DS 16-1, DS 16-10, DS 16-11 & B-2. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG-sp Enclosures I ECEI VED MAR 1 ? I981 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, h'~c. is a Subsidiary of AtlanticRichfie]dCompany ,,,"' STATE OE ALASKA '"" ~" ALASKA( _ ~ND GAS CONSERVATION Cd(" MISSION MONTHLY REPORT OF DRILLINOi AND WORI~OVER OI~ERATION$ · Drilling well Workover operation [] 2. Name of operator Atlantic Richfield Company 3. Address P.O. Box 360, Anchorage, Alaska 99501 4. Location of Well at surface 496'FNL, 862'FEL, Sec 9, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 98' RKBI ADL 25648 7. Permit No. 80-133 8. APl Number 50- 029-20531 9. Unit or Lease Name Kuparuk 25648 10. Well No. B-2 11. Field and Pool Prudhoe Bay Fi el d Kuparuk River Oil Pool For the Month of. Dec. & Jan. ,19 80-81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks , Spudded well 12/22/80. Drld 8-3/4" hole to 4356' Completed wel 1 1/11/81. (See attached Drilling History) (1/1/81) & 8153' (1/5/81). 13. Casing or liner run and quantities of cement, results of pressure tests 16", 65#/ft, H-40 conductor to 80'.. Cmtd w/200 sx Permafros{. 10-3/4", 45.5#/ft, K-55 csg w/shoe@ 2934' Cmtd w/1350 sx Fondu & 250 sx AS II. 7" 26# K-55 csg w/shoe @ 8113' Cmtd w/~;50 sx Class G (See attached Drilling History) 14. Coring resume and brief description n/a 15. Logs run and depth where run Ran DIL/BHCS/GR FDC/CNL/NGT,'. CBL./VDL/CCL/GR, Gyro/CCL · 16. DST data, perforating data, shows'of H2S, miscellaneous data n/a 17. I hereby certify that the forTg_is tlue and correct to the best of my knowledge. 'SIGNEE~~/.~I~¢~t~it~ ~.~.0. TITLE Dist. Drilling Engineer DATE NOTE--Report on this form is required f6r each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 B-2 DRILLING HISTORY Spudded well @ 1400 hrs, 12/22/80. Drld 13-3/4" hole to 2960'. ~. Ran multishot. Ran 71 its 45.5# K-55 BTC 10-3/4" csg w/shoe @ 2934'. Cmtd w/1350 sx Fondu & 250 sx Arctic Set #. Instld 10-3/4'' pkoff & tstd to 2000 psi - ok. NU BOPE & t,st. Tstd csg to 1500 psi - ok. Drld cmt, Shoe &~lO' new hole. '"'~l~std form to 12.5 Pp~F' " EMW- ok. Drld 8-3/4" hole to 4017'. Ran DIL/SP/GR, RFT. Changed to oil base mud. Drld 8-3/4" hole to 8153'. Ran DIL/BHCS/GR, FDC/CNL/NGT. Ran 194 its 26# K-55 7" BTC csg w/shoe @ 8113'. Cmtd w/650 sx Class G. Downsqueezed 7" x 10-3/4" annulus w/300 bbl H?O and 250 sx AS II cmt & 112 Bbl Arctic Pak. Cleaned out csg to 7938'. Displaced well to NaC1/NaBr. Ran CBL/VDL/CCL/GR. Displaced top 300' of NaCI/ NaBr w/diesel. ND BOPE. NU & tstd tree to 3000 psi - ok. Secured well and released rig @ 0900 hrs, 1/11/81. NOTE- A completion .assy was not run in this well. February 24, 1981 Mr. P. A. VanDusen District Drilling Engineer Atlantic Richfield Company P. O. Box 360 AnchOrage, Alaska 99510 Dear Mr. VanDusen: A random sampling of Atlantic Richfield Company well files indicates a severe shortage of 10-404 Forms which are required to b~ filed monthly for each drilling well. The data on the following wells indicates the reason for this le tte r: ~ ~ELL PERTINENT DATA PBU #DS 14-9A Reportedly spudded on December 31, 1980. NO Form 10-404 for December. ~ Form 10-404 for January. PBU #DS 14-10 Spudded on November 10, 1980. Have received Form 10-404 for November. NO Form 10-404 for December. NO Form 10-407 for well. PBU ~DS 16-1 Reportedly spudded on December 5, 1980. Reportedly completed on January 9, 1981. NO Form 10-404 for December. __NO Form 10-404 for January. NO Form 10-407. PBU ~DS 16-16 Reportedly spudded on December 12, 1980. NO Form 10-404 for December. NO Form 10-404 for January. NO Form 10-407. Spudded on December 22, 1980. Temporarily suspended on January 11, 1981. ~O Form 10-404 for Decemt~r. _N~ Form 10-404 for January. Mr. P. A. VanDusen Page 2 February 24, 1981 The random sampling of these and a.few other well files .indicates that Form 10-404 is almost a forgotten item at ARCO. The Commission would like to remind your company that the submission of a Form 10-404 is required by 20 AAC 25.030(e)(2) and 20 AAC 25.070(a)(2) of the regulations. Yours very truly, Harry W. Kugler Commi ssione r HWK:be Date: Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, F - Film, T - Tape · Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 ~aska Oil & aas Cons, /~ohomg~ NORTH SLOPE ENGIlffFT~RAlqG From: J. J. Pawelek / Leo Lash Transmitted herewith are the following: Please note: BL - Blueline, I i~L, · I $ ~-a.'. S- S~ia, F-Fi~, T- T~e RECEIPT ACKNOWItI~ED: PLEASE ~2IAtN~CEI~ ~: /fA. ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O..Box 360 Anchorage, AK 99510 RE'CEIYEO DATE: ~'r'i~., ~ .... Alaska Oil & Gas Cons. Commission Anchorage Date. NORTH SLOPE ENGINEeRInG 1 K J COM~ ~'~ 'co,,~^~ Transmitted herewith are the following: Please note: I 81.. From: J. J. Pawelek / Leo Lash BL - Blueline, S - Sepia, F - Film, T - Tape ~r..l,, ~ 1 S 0",t5" Bn~ S O"~f"' RECEIPT ACKNOWLEDGED ,!...;.,~~_./~,,~.,,,~ ~:'i:'~2->. .........,,.~ ~E RE2IRRN RECEIPT TO: ARCO Alaska, Inc. · Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 £E81 3.1981 Oil & Gas Cons. . ~Chorag~ C°~l==io NORTH SLOPE ENG%NrEFRZNG From: J. J. Pawelek / Leo Lash Date: ~~ ~ /~/ Transmitted herewith are the following- Please note. BL- Blueline, S- Sepia, F - Film, T Tape '~~,FASE RETURN RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash'/ AFA-311 P. O. Box 360 Anchorage, AK 99510 , RECEIVED I.-:~. ~ -- 6 1981 ,Alaska Oil & Gas CODS, CommissJorl Anchorage Sperry-Sun, inc. P. O. Box 620,.'- 1.50 W. Dowiing Anchorage, AK 99502 Mr. Bob Hines Arco Oil & Gas Company P. O. Box 360 Anchorage, Alaska 99510 December 29, 1980 Re: Our Magnetic Multishot Survey Job No. MS-16724 Well B-2 Kuparuk Field North Slope, Alaska Operator: John Samec Date of Survey: December 25, 1980 Dear Mr. Hines: Please find enclosed the "Original" and one copy of our Magnetic Multishot Directional Survey on the above well. Also included~are the field data sheet.~and film. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN , INC. Ken Broussard District Manager KB/kc Enclosures . ' '. : -~.T:'j: . 'C' ' ' ' ' . . - a. PCO OIL AND GA'~"' - · : "~.:' "./':i:?:i?.'::..'.:.i ' . : - . DATE=.OF ':SURVEY :.DECEPBER 25, 198C: ' ..r~ .- ~ ......................................... ,. -.v ~-~:y"'z'd ~ L "'S ~'c T-Z~'~ .... o z R-E 'C T Z'~'~"-' ~': SV:~-T:O0-U KUP~RUK FIELD ~['PTH SLOPE FAG~ETIC kgLllS~C1 MS-1672q .................................................................................................... S'FERR'Y-SU~!~ INC; '' ~ ....... ] ............... -".'"~]7".'."]'.-'.]:':].~T~-;]~:~~ .: .. ~ RECORD OF SURVEY ' '-] ';: '~ ]'' ' ~' .' :].-'~ . . .... TRUE SUB COURSE COURSE DOG-LEG TOTAL" :- : C, EPTH [EFTI-.', TVD OSG MIN ~EG HIN DEG/IOG NORTH/SOUTH EAST/WEST SECTION ..... ?('~;';'[0 ....... 75 ~'."~0 ............ ~'.,_.,~."~'~ ......... ~SSO'~'E. 'VER TI'cAL TO "750 .... FEET ..................c';~on'"'I~Tr;C. : ..... : .............. , O-";'d'O-'" E, .............. . . 777:"-0;'~b. ................ ~4].00 Aq].O0 743.00 045-'- H 54 G W .~2' '. ~5 N ~,,,.::~'-..::.:~:. . ~ ~ - ' "'? ;':~.~-~ .... '~ = z 5 .. u"-: ~-.:~L.:)-.((~,-. -,.s~ .. ~ - ~- ~ ~0 ~32 q3 8~4 ~3 ~ ::'.3 5~...: ~.~ - N 85 ":-~ Y ' P.47 .. <.;: .-;,,~' ' I 7~ .N.,~,,:,,.:---~.';--. - ~ . ·., ~ ~ . . ~. . -. ..... ...................................... - .... '"- '-' ............ = ~ ....................... ~;5'O-'N ......................... 1 · ~ ~' ,_, ~ - . ... -~ · ~ 0 ~ 02'~ · ~ 2 ~ 25, '~ 2 ........... :":" -6 .... i 5'''~'~-'''~ ..... N 69 ,, ~ ~ · .. ~ ]]5-00, 1113,q9. lnl~,., ~,qc.. , 7 15 N ~z.~ 0 W ~°-x~'~, c-~,7~ N, 19-1~ W 21,4~ ' - ............ ~ ....... . ........... "':"': .......... F"'~'~'C'~'7b'o ...... ~26~';'~ .......... ~-~o'G',z~"; ~'.~:. ~ o ~'.:~, ": D,~ 5o u ~ .:..~3. .... 7.2~ ;N?>;~..,;.~:.:.;m.,2e.5B,,~u?,,,;,...' , . ~ ].2~7.0~ ~294.27 ~$6.27 ~" :::(~8:~5f::"~:~::'' ~::~N 53 .~0 .W, ."":.5~ '. :- z5.26 1~'P' c. O0. ' ._,g~..~5,~ lO~7.~: ... ~:)(, ..' 7; 1~:~:~, ],,:.~:'~,;<., N 8n,:)'O y ;':.,,';;'4.06~ .;'.. ';, .:.~;.'2~ '-:N:-."'~:~;;.~).~j~::'-~'(~'~'.);~9.Bq-]',W' / ~,::~'~-; 58.12- ............................... '~ ' ............ r'"' .... ~'--~'"~"-:~'~ .... ;' '~-~:::-~':-~ ..... ~:-~" ~ ......................... : ............. ~ ........ Sq"' e6 .... N- ................. g-4';54-'--~- ....... -72 ;9'6 .......... lqPO. CO 1~75.12 1377.12 1215 ,~ 73 [; W ~571.00 15~2.87 1464,87 18 15 N 77 O k. 6.69 ~0.i0 N : 87.67 W 95.91 F'-f~"~C'f;"O"C ........... i~5"~" 'i~ '":":'-'~ 55,., ~ - ~...--~-, ...... .- .. - , - .... ...- ..... · ................ .6n '-" 2~ xO "i;:-;- '~';N 7q:-:?":O Y'' 6.49 ';,-:' 54'e2G'N-'?.'?~::.:,,::;:"lAg'51:,W':.:-'L .~:~;i56.39 ' ' ~75.7.00 1737.60 1639.~.. :~ :-;27 ;'~O.')':'(.,-~?~:;.:~:~'.~'N ~-~",':0-~:':~;-2.7&.;~;~; ";. ~ 6!'.~7 L- ~ s~ ~' °°'~"~"~'~-;' c o .......... 1182 o. ~59. ~:, o. 70 ....... ' ; ' 1722 ,'70': ""'-'"L"':~'i'--30~::~;'-:':'-::"~'~~'8'62 ~7:;-':-0 g;-: ""~'5 .'1 A'-':"~" .............. 70';-5'-~'-'- ~-~"'~ 2~4.00 197F.~9 1280.69 34.30 N 74 0 U 3.67 83.2q N 281.82 U 285.21 · ' J u u .... ~. 7q ,~,'~ ' .... -~9';7'~'~'-~'~.~?T':"-'.~]i'33'~';~I'-L'~TTT'~TS3-~-4] i9.00 2125.66 2~27.66 ' ' 40 u:.~':- :.. N 7'1';--'0. W ':-' ('~'2.72;~]~ 118.46 -N-i~'~':~-.'.]: :'.';-~ [~']1.00 2195.~8 2097.H8 '. '~"">4~ 30-"-;'~;"~;,~:''- .N 70 O Y'~' :"., .89~ 138.31' 2403.00 ................................... 2265.'0fl '2'i67 · 0 q ' ......... '4'2 9 ~':-'~:'-~ ...... N' '68 'O W ...... ...... 2' ':: -'. ] 7::~: "~"'': ..... 16 ~'-'0'5 '- N'~''~- ......... 50'0~;'9'9~'W'--' ...... 5-113 ;'1-4 249~.0~ 2~3~.02 22~E..02 q2 15 N 68 0 ~ .27 ~g3.~2 N 55~.R3 ~ 57~.85 . . .... ~,. ['2'~'~'~';'00 ................ 2~OZ ,9'g ............. 2303,"g8 ........... : ..... ~2."-30,~77~/:.':.:.'"N'~ 6'8 "~::::': '0 ::'" y :-.;:'--:/';';-27:"~":"~'/;):' 2'0E;65 ~ 2~RO. O0 2~7o.26 '- 2372.26 ~'-.,".ql ~0):-.:.;:..:;' N.6g (:fl:2 ':-:.:.9~. ..... 229.75 N):.' -'..).':~73.~9/WJ~:-'~'~:~ 697.i9 "'2"A-~,"?'.-O-b ....... 2~-o',~ -'25'~:~';~r' '"--:-'~f""~--o ~-':69%~'---o"'~'~:---'-~-';35 ............... ~"274--;'~'2-'-:'N ....... "" 29~5.05 P68D.42 2582 A2 41 ID N 69 0 W O nO 296 55 N 646-Q2 W ~79.82 h-2 ~ ' - DATE OF SURVEY DECEMBER 25, 1980 ' ..................................................................... L .................................. L,Z .... .................................... ~tJP/~RUK FIELD VER'T"i'C~L S'E'CT'I"bN DIR"E'~'TIOr, J'"~5'~'-$"I~Og'-'I~ .............. MOP TI-f SLOPE ~'/~ 6.~IET I C FULTISHOT ~,1S-1672~ RECSRE OF SURVEY .... . ...... .................................. *' ;~ T ~ E ..... C"A'I-'C U L A' T ] C: N S" 'A R F__-- B'A ~ E D -0 b~' T Fi-E' '"M HORI'~CNT/~L DISPLACEMENT : 8. gE.q9 FEET AT :" . · ._ _ .. ~,ORTH 7r~ DEG itl ~-~IN. t,/FST {TRUF) .......... -- ......................................... :: ":' ":'":'::: ..... - - '- ' .'" i-'!:"':" '."T:::. ':.: :' "]i: ]i; ........... .:"'; :"i''~''~ .... ?:.i;:'T ........... :"-"'-- ............ ' i ' START OF S[JRVEY 'W'AS . 98'00 FEET .a. BOVE:' SEA 'LE'VEL--' -'::i::]' .'~-i~ ]-] -::", ,'~':~. : .: -: OIL AND GAS KUPARUK FI ELD SLOPE I¢$ GIVETI £ k.U L T I S,H,gT MS-1672~ Sr.:rPpy_Slll,,.I,TNPo,...,,..-.,,, .,...... .'.;' · ' ..:i' : INTERPOLATED RECORD OF SURVEY ..................................... T R 0 E ........................................ T 'O'T-~ L P"F/IS tIRE D V'ER T I C.~L SU~ SEA TRUE RECTANGULAR COORDINATES DFPTH DEPTH TV B ELEV ATI ON NOR TH/SOUTH E 4. ST/W FST ..................... : ...................... ~ ............ =~ ........... .,~ ....................... .~_.~, ............. · . . . - . . . : - .. ; :: . ;'::.-~ . i 750· 750. -i .' ".:i::: 652. ' '652. ' - . : :0·;:N':.' :: - ' O· E · : i '750. 1731. . :' ' '"-":~., 16,~3. .... - i. -1633. · :.~'":":! ::"..J'i; 5z~"::~'N::Y:"~:: ~'/' .:'1~7.'N. -- ' 7~0, ....................................... 2523 ..................................2~25 -2z~25, 2~7 N 717" .... 2~60. 2 ~,P,O · 25.-_,-~ ~- · -2582. 297. N · F..................... ir,!'TEF.'r~:aL'ATED .... £O0',6.'D'INATE~'' F-OR EVERy":! '[ '.; -- ' :FROM ;:-::i:.':.' 75O'?JO'i' FEET· TO;.: C ~' SPERRY -- sUN, INC. MAGNETIC MULTISHOT FIELD DATA AND TJx,,- SHEET NO. 1 t JOB NO,. COMPANY ~, ~ .r'_ ~ ,'-"' ' ~ ~,~ ~ ~ DATE -J .... ...... STATE ~;I ,/'""~'~ ~"- ~OUNTY/PARISH ~"-]~l~'~-j ~'~:[ FIELD ~.LJ ~~.~ .... LEASE ~ WELL NO, ~ SURVEYED FROM ~ ~O TO FILM LENGTH CALC, ~ ~'' MEASURED ~7 ~" FIRST FLASH C~ ~OO LAST FLASH REMARKS: IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN SURFACE TIME DEPTH ' SURFACE TIME ISURFACE TIME DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE TIM[ ..,,I ~ ~ ,,, .' , , ~ I- I~ /~~ ' , ..... ~/-/o ,/~. .... ,, ~/-~ ~ ~ .............. , , , "' , ......... ' ...... eZ-eZ6 ~o II ........ ~ o ~- 7 -3~ .... . ...... ~ .... ,, / % 2 ~ f'O / ,, . , ~ ' ......., .~o~-~,~-' /Z~- ~6 ........ ., 0 0 /. \ STEEL SUB MAGNETS L COMPASS STOP YES-NO STEEL SUB 101-2 03(2/76)5M NORTH SLOPE ENG~ Date: From: J. J. Pawelek / Leo Lash Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, I - L- :;k L~r,o I - C--~ ~y~o F - Film, T - Tape '.'. ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 FEB - 6 ]CgSl Alas~(a 0il &' Gas Cons. Commission Anchorage 700 West 41st, Suite 101 Anchorage, Alaska 99502 Phone 272-2496 Telex: 25-364 World Leader in Service to the Oil Industry January 9, 1981 Job ~4428 North Slope Drilling' Enclosed please find our Gyro Survey on Kuparuk B-2 along with our Vertical Section and Horizontal View maps. Also enclosed you ~vill find the Gyro Film, Field Sheet and Calculations. If any other information is needed please call 272-2496. Thank you for using Scientific Drilling International and please call again. Sincerely Manager COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY & ASSOC 14 JAN 8'1 KUPARUK B-2 KB ELEV 98, FT, JOB NO 4.428 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 0,00 100 0 0 100.00 200 0 0 200,00 300 0 0 300.00 400 0 0 400o00 500 0 0 500,00 600 0 0 600,00 700 0 0 700.00 80O 0 0 800,00 400 1 30 899,98 1000 7 0 999,67 -98.00 N O,OOE 2,00 N47,53W 102,00 N47,46W 202,00 N47,40W 302,00 N47.26W 402,00 N47,13W 502,00 N47,06W 602,00 N47.00W 702.00 N46,gBw 801.98 NS?,13W 901,67 N74,61W 1100 8 15 1098,78 1000,78 N61.58W 1200 9 30 1197,58 1099,58 N49,63W 1300 9 0 1296,28 1198,28 N63.40W 1400 9 45 1394,95 1296,95 N76,16W 1500 16 30 1492.28 1394,28 N72,16W 1600 19 15 1587,44 1489,44 N78,55W 1700 24 0 1680,38 1582,38 N78,60W 1800 26 30 1770,82 1672,82 N80,90W 1900 30 30 1858,68 1760,68 N78,86W 2000 34 15 1943.12 1845.12 N77,71W 2100 37 0 2024.40 1926.40 N75,85W 2200 41 0 2102,10 2004,10 N74,40W 2300 42 0 2176,99 2078,99 N73,96W 2400 42 0 2251.31 2153.31 N73,90W TOTAL COORDINATES 0.00 S 0.00 W 0.00 S 0,00 W 0.00 S 0,00 W 0.00 S 0.00 W 0,00 S 0,00 W 0.00 S 0,00 W O,O0.S : 0,00 W 0.00: S ': 0,00 W 0,00 S ..~ :-0,00 W 0,80 N 1.03 W 3,82 N 7,76 W 8,75 N 20,04 W 17.45 N 32,75 W 26.30 N 46,13 W 31.92 N 61,38 W 38,11 N 83,21 W 45,86 N 112,89 W 53,16 N 149,00 W 60,75 N 190.97 W 69,13 N 237,93 W 79,99 N 290,36 W 93,31 N 347,05 W 109,46 N 407,86 W 127,52 N 471,61 W 146.04 N 535,91W CLOSURES DISTANCE ANGLE O M S 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 1.30 N 52 i 59 w 8,65 N 63 48 14 W 21,87 N 66 24 7 W 37,11 N 61 56 45 W 53.10 N 60 18 31 W 69.19 N 62 31 30 W 91,52 N 65 23 33 W 121,85 N 67 53 21 W 158,20 N 70 21 51 W 200,40 N 72 21 11 W 247,77 N 73 47 55 W 301.17 N 74 35 48 W 359.38 N 74 57 3 W 422,30 N 74 58 36 W 488.55 N 74 52 9 W 555.46 N 74 45 23 W DOG LEG SEVERITY DEG/iOOFT 0.000 0,000 0.000 0.000 0.000 0,000 0o000 0.000 0,000 1,500 5,506 1,278 1,292 0,603 0,835 6,758 2.836 4,750 2,542 4,034 3e768 2.832 4,048 1,019 0,045 SECTION DISTANCE 0,00 0,00 0,00 0,00 0.00 0,00 0,00 0,00 0,00 1,30 8.58 36,~_ 52,97 68.78 90.38 119,37 153,47 192,60 236,33 285.97 340,53 400,09 463,16 526,93 ,, ARCO' KUPARUK B-2 GYROS{OPIC SURVEY JOB N.O 44.28 14 JAN 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S 2500 43 0 2325.03 2227.03 N73.81W 2600 43 0 2398.17 2300.17 N73.23W 2700 42 0 2471.89 2373.89 N73.OSW 2800 42 0 2546.21 2448.21 N72,38W 2900 41 30 2620,81 2522,81 N72,06W 3000 41 30 2695.71 2597.71 N71.48W 3100 41 30 2770.61- 2672,61 N70.91W 3200 41 0 2845,79 2747,79 N72,33W 3300 41 0 2921.26 2823.26 N71,75W 3400 40 30 2997.02 2899.02 N72.28W 3500 40 0 3073.34 2975.34 N70.86W 3600 40 0 3149.94 3051.94 N70,28W 3700 39 45 3226.69 3128,69 N70,75W 3800 40 0 3303,43 3205,43 N71.O3W 3gO0 39 30 3380.32 3282,32 N69,68W 4000 39 30 3457,48 3359.48 N71,O3W 4100 40 0 3534.36 3436,36 N70.25W 4200 39 0 3611.53 3513,53 N70,O6W 4300 40 15 3688.55 3590,55 N66,13W 4400 41 0 3764,45 3666,45 N61.60W 4500 42 30 3839,05 3741,05 N58,75W 164.82 N 600,81 W 184.16 N 666.21 W 203,75 N 730-86 W 223,63 N 794,75 W 243,96 N 858,16 W 264.68 N 921.10 W 286,04 N 983,83 W 306,82 N 1046,40 W 327.05 N 1108.81 W 347,20 N 1170,89 W 367,62 N · 1232,19 W 389,00 N 1292,81 W 410,38 N- 1353,25 W 431.37 N 1413,83 W 452,87 N 1474.05 W 474,25 N 1533,96 W 495.44 N 1594.29 W 517.03 N 1654,12 w 540,81 N 1713.28 W 623.01 N 74 39 32 W 691.19 N 74 32 50 W 758,73 N 74 25 19 W 825.62 N 74 17 2 W 892,17 N 74 7 48 W 958,38 N 73 58 2 W 1024.57 N 73 47 18 W 1090.45 N 73 39 27 W 1156.04 N 73 33 57 W 1221,29 N .73 28 59 W 1285,87 N 73 23 14 W 1350,07 N 73 15 12 W 1414.11 N 73 7 46 W 1478,18 N 73 1 56 W 1542,05 N 72 55 17 W 1605,60 N 72 49 12 W 166'9.50 N 72 44 12 W 1733.04 N 72 38 31 W 1796.61 N 72 28 51 W 569.48 N 1771,72 W '1860,99 N 72 10 51 W 602.60 N 1829.48 W 1926,17 N 71 46 8 W 4600 42 0 3913.07 3815,07 N60,21W- 636,74 N 1887,40 W 4700 41 30 3987,68 3889,68 N60,81W 4800 41 0 4062.86 3964.86 N59.63W 4900 41 0 4138.33 4040.33 N60,95W 5000 40 30 4214.09 4116.09 N59,73W 5100 40 30 4290,13 4192,13 N60,16W 5200 39 15 4366.87 4268.87 N60,15W 5300 38 0 4444,99 4346,99 N59.20W 669.51 N 1945.36 W 702,25 N 2002.59 W 734,77 N 2059,57 W 767.07 N 2116,30 W 799.59 N 2172,51 W 831,49 N 2228,12 W 863.00 N 2282.00 W 1991.91 N 71 21 26 W 2057.35 N 71 0'31 W 2122.16 N 70 40 32 W 2186.72 N 70 21 56 W 3251,02 N 70 4 35 W 2314.98 N 69 47 38 W 2378.22 N 69 32 7 W 2439.74 N 69 17 3 W DOG LEG SEVERITY DEG/iOOFT 1,001 0,398 1,003 0,446 0,519 0,387 0.375 0,789 0,383 0,548 0,770 0,375 0,314 0,276 0,740 0,859 0,596' 1,003 2,064 2,090 1,985 0,825 0,565 0.714 0,864 0,716 0,281 1,250 1.301 SECTION DISTANCE 591.31 656,49 721.16 785,35 849,39 913,25 977,29 1040,88 1104,03 1166,87 1229,20 1291,50 1~53.65 1415.70 1477.73 1539,44 1601, 1663,1. 1725,57 1790,10 1856.53 1923,66 1990,07 2055,85 21Z1,29 2186e41 2251,22 2315,19 2377.50 ARCO KUPARUK B-2 GYROSCOPIC SURVEY JOB NO 44.28 14 JAN 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S 5400 36 30 4524.59 4426,59 N59,21W 893.99 N 2334,00 W 5500 35 0 4605,75 4507,75 N57,70W 924,55 N 2383,79 W 5600 34 30 4687,91 4589,91 N56,43W 955,54 N 2431,63 W 5700 33 30 4770.81 4672,81 N56,26W 986.52 N 2478,18 W 5800 32 45 4854.56 4756,56 N56.95W 1016.60 N 2523,80 W 5900 31 15 4939.36 4841,36 N54,98W 1046.26 N 2567.71 W 6000 30 30 5025.19 4927,19 N52,80W 1076.50 N 2609,17 W 6100 29 45 5111.68 5013,68 NSO,61W 1107,59 N 2648,56 W 6200 27 0 5199.66 5101,66 N48,86W 1138,30 N 2684,82 W 6300 26 30 5288.96 5190,96 N46,60W 1168,57 N 2718,13 W 6400 28 0 5377.86 5279.86 N44.86W 1200.53 N 2750,91 W 2499.35 N 69 2 29 W 2556.80 N 68 48 4 W 2612,64 N 68 32 49 W 2667.32 N 68 17 35 W 2720.86 N 68 3 36 W 2772,69 N 67 49 50 W 2822,52 N 67 34 47 W 2870,82 N 67 18 21 W 2916,16 N 67 1 26 W 2958,68 N 66 44 10 W 3001.47 N 66 25 22 W 6500 28 15 5466.05 5368,05 N40,95W 1235.05 N .2783,00 W 3044,74 N 66 4 8 W 6600 31 0 5552.97 5454,97 N37.53W 1273,32 N' !~2814,26 W 3088,92 N 65 39 19 W 6700 31 30 5638,46 5540,46 N33,73W 1315,48 i'N-~:2844.48 W 6~00 32 0 5723.50 5625.50 N32.60W 1359.53 N 2873.27 W 6900 34 0 5807.36 5709,36 NB1,25W 1405,75 N 2902,07 W 7000 36 0 5889.27 5791,27 N29,10W 1455.33 N 2930,89 W 7100 37 0 5969.65 5871,65 N25,55W 1508,17 N 2958,19 W 7200 37 30 6049.25 5951,25 N23.71W 1563,18 N 2983,42 W 7300 40 0 6127.24 6029,24 N21,76W 1620.90 N 3007,62 W 7400 40 0 6203.84 6105,84 N20.OSW 1680,95 N 3030.55 W 7500 40 0 6280.45 6182,45 N19,73W 1741,39 N 3052.42 W 7600 40 0 6357,05 6259.05 N19,55W 1801.93 N 3074,03 W 7700 39 0 6434,21 6336.21 N20,20W 1861,75 N 3095,66 W 7800 38 15 6512,34 6414,34 N20,OBW 1920,35 N 3117,14 W 7900 37 30 6591.27 6493,27 N19,15W 1978,19 N 3137.74 W 8000 37 30 6670.61 6572.61 N18'18W 2035.86 N 3157,23 W 8100 37 30 6749.94 6651.94 N18.78W 2093,60 N 3176,53 W 8153 37 30 6791,99_ 6693,99 N18eBOW 2124,16 N 3186e87 W 3133,94 N 65 10 51W 3178.68 N 64 40 41W 3224,61N 64 9 16 W 3272,33 N 63 35 96 W 3320.46 N 62 59 10 W 3368,14 N 62 20 50 W 3416.59 N 61 40 41 W 3465,52 N 60 59 3 W 3514,22 N 60 17 43 W 3563,23 N 59 37 19 W 3612.37 N 58 58 37 W 3661.19 N 58 21 51 W 3709,27 N 57 46 14 W 3756,70 N 57 11 6 W 3804.,40 N 56 36 42 W 3829e91 N 56 18 54 W DOG LEG SEVERITY DEG/IOOFT 1.500 1.581 0,644 1,001 0,776 1.591 0,937 0,923 2,774 0,674 1,548 0,912 2,895 1.152 0,593 2,044 2,133 1,629 0,844 2,627 1.103 0,204 0,118 1,033 0.752 0,823 0.588 0.211 SECTION DISTANCE 2437,95 2496,33 2553,32 2609,24 2663,89 2716,87 2768,14 2818,17 2865,37 2909,87 2954.88 3000.73 3047,97 3096,49 3144,88 3194.48 3297,9~ 3349,49 3401,63 3454,02 3505,74 3557,30 3608,47 3658'85 3708,07 3756.27 3804,35 3829.91 BOTTOM HOLE CLOSURE 3829,91 FEET AT N 56 18 54 W ARCO KUPARUK B-2 GYROSCOPIC SURVEY JOB NO 44.28 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES C L O S U R E DISTANCE ANGLE D H S 14 JAN 81 SUB SEA 4007 3462.88 6486 5453.72 6623 5572.67 6936 5837,08 7177 6030.99 7312 6136,43 T KUPARUK 7432 6228,35 T UP SAND 7466 6254.40 7486 6269.72 7525 6299,60 7597 6354,75 B UP SAND 7635 6383.93 T LOW SA~D 7854 6554.86 7862 6561,18 7877 6573.04 B LOW SAND 7898 6589,68 B KUPARUK 7964 6642.05 PLUG BACK 8027 6692,03 TD 8153 6791.99 475.70 N 1230,50 N 1282,86 N 1423.23 N 1550.61 N 1628.11 N 1700,30 N 1720.90 N 1733,03 N 1756.59 N 1538,17 W 2778,17 W 2821,33 W 2912,42 W 2977.30 W 3010.37 W 3037,54 W 3044.83 W 3049.07 W 3057,66 W 1800.34 N ::i~ 3072,72 W 1823,10 N i'.i 3081,39 W 1951,68 N !~:. 3128,38 W 1956,31 N ~ 3130,01-W 1964.97 N ~' 3133.04 W 1977.07 N 'i 3137.24 W 2015.10 N 3150.22 W 2051.49 N 3162.31 W 2124.16 N 3186,87 W 1610,05 N 72 48 53 W 3364,88 3038,48 N 66 6 37 W 5355.72 3099.29 N 65 32 55 W 5474,67 3241.57 N 63 57 22 W 5739,08 3356,89 N 62 29 20 W 5932.99 3422.44 N 61 35 38 W 6038,43 3481,04 N 60 45 41 W 6130,35 3497.50 N 60 31 31 W. 6156.40 3507.17 N 60 23 12 W 6171.72 3526.31 N 60 7 23 W 6201,60 3561.30 N 59 38 0 W 6256,75 3580.32 N 59 23 21 W 6285.93 3687.25 N 58. 2 29 W 6456,86 3691,08 N 57 59 37 W 6463,18 3698,25 N 57 54 17 W 6475.04 3708,25 N 57 46 51 W 6491.68 3739,59 N 57 23 ~9 W 6544.05 3769,46 N 57 1 37 W 6594.03 3829,91 N 56 18 54 W 6693,99 ., ARCO KUPARUK B-2 GYROSCOPIC SURVEY JOB N.O 44'28 i'~EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 14 JAN 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 198 198, 100 0 298 298, 200 0 398 398, 300 0 498 498, 400 0 598 598, 500 0 698 698, 600 0 798 798, 700 0 898 898, 800 0 998 998, 900 0 1099 1098, 1000 1 1200 1198, 1100 2 1302 1298, 1200 3 1403 1398, 1300 5 1506 1498, 1400 7 1611 1598, 1500 13 1719 1698. 1600 21 1830 1798, 1700 32 1946 1898. 1800 48 2067 1998, 1900 69 2194 2098, 2000 96 2328 2198, 2100 130 2463 2298, 2200 165 2600 2398. 2300 202 2735 2498, 2400 237 2869 2598, 2500 271 3003 2698, 2600 305 3136 2798. 2700 338 3269 2898, 2800 371 3401 2998. 2900 403 3532 3098, 3000 434 3663 3198. 3100 465 3793 3298' 3200 494 3923 3398, 3300 525 4052 3498, 3400 554 4182 3598, 3500 584 0 0.00 0 0,00 S 0 0,00 S 0 0,00 0 0,00 S 0 0,00 S 0 0,00 S 0 0,78 N 0 3,78 N 1 8,82 N 1 17,45 N 1 26,42 N 2 32.04 N 38,63 N 46.63 N 54,76 N 63,20 N 16 74,20 N 21 89,12 N 27 109,05 N 34 133,00 N 35' 158,44 N 37 184.71N 35 210.67 N 34 237.85 N 34 265.33 N 33 294.04 N 33 321.07 N 32 347,40 N 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,98 W 7.53 W 19,87 W 32,75 W 46,37 W 61,88 W 84,84 W 116.48 W 156.64 W 20~,43 W 261.~4 W 327,86 W 403.92 W 489*53 W 576.47 W 665.87 W 753,24 W 838.52 W 922.98 W 1006.25 W i089,37 W li?l,51 W 31 31 29 31 29 30 374.66 N ' 1251,52 W 402,75 N 1330,59 W 430,30 N 1409,37 W 458,03 N 1487,68 W 485,19 N 1565,27 W 513,31 N 1643,39 W ARCO KUPARUK B-2 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 JOB NO 4.4-28 FEET OF SUB SEA DEPTH, 14 JAN 81 TRUE MEASURED VERTICAL SUB MD-TVD DEPTH DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 4312 3698. 3600 614 4445 3798, 3700 646 4580 3898. 3800 682 4714 3998, 3900 716 4846 4098, 4000 748 4979 4198, 4100 781 5110 4298, 4200 812 5240 4398, 4300 842 5367 4498, 4400 869 5490 4598, 4500 892 5612 4698, 4600 914 5732 4798. 4700 934 5851 4898, 4800 953 5968 4998, 4900 970 6084 5098, 5000 986 6198 5198. 5100 1000 6310 5298, 5200 1012 6423 5398, 5300 1024 6536 5498, 5400 1038 6653 5598, 5500 1054 6770 5698, 5600 1071 6889 5798, 5700 1090 7011 5898. 5800 1112 7135 5998, 5900 1137 7262 6098, 6000 1164 7392 6198. 6100 1194 7523 6298- 6200 1225 7653 6398. 6300 1255 7782 6498. 6400 1284 7908 6598, 6500 13'10 8034 6698, 6600 1336 30 5~4.01N 32 584,10 N 36 630.39 N 34 674.08 N 32 717,69 N 33 760,82 N 31 802,83 N 30 844,17 N 27 883,95 N 23 921,83 N 22 959,33 N 20 996.3? N I9 1032,07 N i7 I067,I7 N ~ I6 ~ Ii02,98 N L 14 ~./: i_ ~ :i i: !. '; ~ 1138,16 N '12 ~' - ~ i~ 1171.69 N 12 1208.30 N 14 1248,42 N 16 1295,34 N , 17 1346,43 N 19 1400.58 N 22 1460,90 N 25 1527.35 N 27 1598,70 N 30 1676.28 N 31 1755,31 N 30 1833,91N 29 1909.75 N 26 1982,79 N 26 2055.55 N 1720,35 W 1797,36 W 1875.35 W 1953,25 W 2028.52 W 2104,00 W 2178,13 W 2249,90 W 2316,86 w 2378.71 W 24.37,25 W 2492,77 W 2546.30 W 2595.79 W 2642,06 W 2683,74 W 2721.34 W 2758,$0 W 2794,00 W 2830,23 W 2864,31 W 2898,48 W 2933,95 W 2966.99 W 2998.04 W 3028,36 W 3057,22 W 3085,21 W 3113,13 W 3139.33 W 3163,62 W ARCO KUPARUK B-2 INTERPOLATED VALUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH GYROSCOPIC SURVEY JOB NO 1000 FEET OF MEASURED DEPTH. SUB SEA TOTAL. COORDINATES 1000 999, 901, 2000 - 1943, 1845, 3000 2695, 2597, 4000 3457. 3359, 5000 4214. 4116, 6000 5025. 4927. 7000 5889, 5791. 8000 6670. 6572. 3,86 N 80,71 N 264,99 N 474.62 N 767,90 N 1077.14 N 1455,42 N 2035 · 92 N 7,74 W 290,20 W 921,00 W 1533,82 W 2115,82 W 2 608 · 69 W 2930 · 74 W 3157,06 W 44'2 14 JAN 81 VERTICAL SECTION ARCO OIL ~ GAS KUPARUK 19-2 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000' dAN. 15, 1981 SURFACE LOCATION IS "' I 496' SNL, 86?..' WEL, SEC. 9 ' I\ 160i~ , \ ":~' I .... ................ ~°.°:~' ' ...... ' ~' ~oo~ ..... . ..........'"' .................................... .~... .......... . ..... .ooox ....................... , .-~:..~ ~ ""'x "~°°_ , s4oo~~ TVD = 6792' m ~ TMD = 8153' , ........................... HORIZONTAL VIEW ARCO OIL ~ GAS KUPARUK B-2 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000' ~IAN. 15)1981 '. ' ALL ARE DEPTHS SHOWN TVD ARCO Cii'and G~ t'.~orth Slop~. ,.,~stri¢t Post Office B":x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 2, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 2-9 DS 3-13 DS 6-15 DS 1 5-21 DS 16-11 Kuparuk B-2 C-2 C-3 Dear Sir- Enclosed please find' 1.) The subsequent Sundry Notices for DS 2-9, DS 3-13 an~ DS 6-15. 2) The Completion Reports for DS 15-21, DS 16-11, B-2, C-2 and C-3. Please note that the Completion Reports for DS 14-10, DS 15-10, DS 16-1, DS 16-16 and B-1 will follow shortly. Sincerely yours, / ~.P.A. VanDusen District Drilling Engineer PAV:sp Enclosures RECEIVED FEB - 1981 ~laska Oil & Gas Cons. CommissJol] Anchorage ARCO Oil and Oas Company is a Division of &lh.~ntic Richlield(',; '~,' STATE OF ALASKA ,,,r ""' ~ ' Al'AsK . .,'LAND GAS CONSERVATION C~,. ..... ,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL)~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Atlantic Richfield Company 80-133 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20531 4. Location of well at surface 9. Unit or Lease Name 496'FNL, 862'FEL, Sec 9, TllN, R10E, UM Kuparuk 25648 At Top Producing Interval 10. Well Number 1204'FSL, 1380'FWL, Sec 4, TllN, RIOE, UM B-2 At Total Depth 11. Field and Pool '.' 1628'FSL~ 1231'FWL, Sec 4~ TllN~ RIOE, UM.. Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il poOl 98' RKBI ADL 25648 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 12/22/80 1/6/81 1/1.,1/81I -- feet MSLI 0 i7.'Total Depth (MD+TVD) 18. Plug Back DePth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8153'MD 6792'TVD 8027'MD 6692'TVD YES[~ NO[]I _- feetMD 1650' fapprox) 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/NGT, CBL/VDL/CCL/GR, Gyr0/CCL 23. ' CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 surface 80' 24" 200 sx Permafrost t) surface 10-3/4" 45.5# K. 55 surface 2934' 13-3/4" 1350 sx Fondu & 2501 sx AS II 7" 26# K-55 surface 8113' 8-3/4" 650 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) n/a n/a 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . . ~ :.. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED n/a · . 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) n/a Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FlowTUbing Casing Pressure CALCULATED,4~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA ' £C£1V£D .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch , , .Alaska 0il & aas Con,, :' ,. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE ~IDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T Kuparuk 7432' 6228' none T Up Sand 7466' 6254' B Up Sand 7635' 6384' T Low Sand 7854' 6555' B Low Sand 7898' 6590' B Kuparuk 7964' 6642' , ...... 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 1 .... ~"- '~ 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 to01. 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" Form 10-407 none". B-2 DRILLING HISTORY Spudded well @ 1400 hrs, 12/22/80. Drld_13-3/4" hole to '2960'. Ran multishot. Ran 71 its 45.5# K-55 BTC 10-3/4" csg w/shoe @ 2934'. Cmtd w/1350 sx Fondu & 250 sx Arctic Set #. Instld 10-3/4" pkoff & tstd to 2000 psi - ok. NU BOPE & tst. Tstd csg to 1500 psi - ok. Drld cmt, shoe & 10' new hole. Tstd form to 12.5 ppg EMW- ok. Drld 8-3/4" hole to 4017'. Ran DIL/SP/GR, RFT. Changed to oil base mud. Drld 8-3/4" hole to ~53'. Ran DIL/BHCS/GR, FDC/CNL/NGT. Ran 194 its 26# K-55.7"-BTC csg'w/shoe @ 8113'. Cmtd w/650 sx Class G. Downsqueezed 7" x 10-3/4" annulus w/300 bbl H?O and 250 sx AS II cmt & 112 Bbl Arctic Pak. Cleaned out csg to 7938'. Displaced well to NaC1/NaBr. Ran CBL/VDL/CCL/GR. Displaced top 300' of NaCl/ NaBr w/diesel. ND BOPE. NU & tstd tree to 3000 psi - ok. Secured well and released rig @ 0900 hrs, 1/11/81. NOTE- A completion assy was not run in this well. FEP, - 3 1.,o81 Alaska Oil & Gas Cons. ComDmi$sioD ADchorago g il : lT lif ll World Leader in Service to the Df lll l li l Oil Industry 700 West 41st, Suite 101 Anchorage, Alaska 99502 Phone 272-2496 Telex: 25-364 January 9, Job #4428 1981 North Slope Drilling: Enclosed please find our Gyro Survey o~Kuparuk B-2 along with our Vertical Section and Also enclosed you will find the Gyro ~ilm, Field Sheet and Calculations. If any other information is needed please call 272-2496. Thank you for using Scientific Drilling International and please call again. Sincerely Manager .. COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS Of CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY G ASSOC 14 JAN 8'1 ' KUPARUK B-2 ?-~LEV 98, FT, .... JOB NO 44-28 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 0 0 0 0,00 100 0 0 100.00 200 0 0 200.00 300 0 0 300.00 400 0 0 400.00 500 0 0 500.00 600 0 0 600,00 700 0 0 700,00 800 0 0 800.00 400 1 30 899.98 1000 7 0 999,67 -98.00 N O,OOE 2.00 N47.53W 102,00 N47.46W 202.00 N47.40W 302.00 N47.26W 402,00 N47.13W 502,00 N47,06W 602.00 N47.00W 702,00 N46.93W 801,98 N57,13W 901,67 N74.61W 1100 8 15 1098.78 1000,78 N61-58W 1200 9 30 1197,58 1099,58 N49.63W 1300 9 0 1296.28 1198,28 N63.40W 1400 9 45 1394,95 1296,95 N76.16W 1500 16 30 1492.28 1394.28 N72,16W 1600 19 15 1587,44 1489,44 N78,55W 1700 24 0 1680,38 1582.38 N78,60W 1800 26 30 1770.82 1672,82 NSO,90W 1900.30 30 1858.68 1760,68 N78,86W 2000 34 15 1943.12 1845.12 N77.T1W 2100 37 0 2024.40 1926,40 N75.85W 2200 41 0 2102,10 2004e10 N74,40W 2900 42 0 2176.99 2078.99 NTB.96W 2400 42 0 2251,31 2153.31 N73,90W TOTAL COORDINATES 0,00 $ 0.00 S 0.00 S 0.:00 S 0.00 S 0.00 S 0.00 S 0.00 W 0.00 W 0.00 W 0.00 W 0o00 W 0,00 W 0.00 W 0.00 S i 0,00 W 0.00 S 0.80 N 3.82 N 8,75 N 17.45 N 26.30 N 31,92 N 38.11N 45.86 N 0.00 W 1,03 W 7.76 W 20.04 W 32.75 W 46.13 W 61.38 W 83.21 W 112,89 W 53.16 N 149,00 W 60.75 N 190.97 W 69.13 N 237.93 W 79.99 N 290.36 W 93.31N 347.05 W 109.4.6 N 407.86 W 127,52 N 471,61 W 146.04 N 535.91 W CLOSURES DISTANCE ANGLE D M S 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 5 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 1.30 N 52 i 59 W 8,65 N 63 48 14 W 21.87 N 66 24 7 W 37.11 N 61 56 45 W 53.10 N 60 18 31 W 69.19 N 62 31 30 W 91.52 N 65 23 33 W 121.85 N 67 53 21 W 158,20 N 70 21 51 W 200,4.0 N 72 21 11 W 247.77 N 73 47 55 W 301.17 N 74 35 48 W 359.38 N 74. 57 3 W 422.30 N 74 5fl 36 W 488.55 N 74 52 9 W 555.46 N 74 45 23 W DOG LEG SEVERITY DEG/IOOFT 0,000 0.000 0,000 0,000 0,000 0,000 0,000 0.000 0,000 1.500 5.506 1,278 1,292 0e603 0,835 6,758 2.836 4.750 2,542 4,034 3,768 2,832 4,048 1,019 0,045 SECTION DISTANCE 0.00 0,00 0,00 0.00 0,00 0.00 0,00 0.00 0,00 1,30 8.58 36.9. 52.97 68.78 90.38 119.37 153,47 192,60 236,33 285,97 340,55 400e09 463,16 526.93 ,, ARCO KUPARUK B-2 GYROSCOPIC SURVEY JOB N.O 44.28 . 14 JAN 81 RECORD OF SURVEY TRUE NEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 2500 43 0 2325.03 2227.03 NTB.81W 2600 43 0 2398,17 2300.17 NTB,23W 2700 42 0 2471.89 2373.89 N73.05W 2800 42 0 2546.21 2448,21 N72,38W 2900 41 30 2620.81 2522,81 N?2,06W 3000 41 30 2695,71 2597,71 N71.48W 3100 41 30 2770.61 2672,61 N70,91W 3200 41 0 2845,79 2747,79 N72,33W 3300 41 0 2921.26 2823.26 N71,75W 3400 40 30 2997.02 2899,02 N72,28W 3500 40 0 3073.34 2975.34 NTO.86W 3600 40 0 3149.94 3051,94 N70.28W 3700 39 45 3226.69 3128.69 N70.75W 3800 40 0 3303.43 3205,43 N71.O3W 3200 39 30 3380.32 3282,32 N69,68W 4000 39 30 3457,48 3359.48 N71,O3W 4100 40 0 3534.36 3436,36 N70,25W 4200 39 0 3611,53 3513,53 N70,O6W 4300 40 15 3688,55 3590,55 N66,13W 164.82 N 600.81 W 184.16 N 666.21 W 203,75 N 730.86 W 223,63 N 794,75 W 243.96 N 858,16 W 264,68 N 921.10 W 286.04 N 983.83 W 306.82 N 1046.40 W 327.05 N 1108.81 W 347.20 N 1170.89 W 367.62 N 1232,19 W 389,00 N 1292,81 W 410.38 N 1353,25 W 431.37 N 1413,83 W 452,87 N 1474.05 W 474,25 N 1533,96 W 495,/+4 N 1594,29 W 517.03 N 1654,12 W 540,81 N 1713,28 W 4400 41 0 3764.45 3666,45 N61,60W 569.48 N 1771.72 W 4500 42 30 3839,05 3741,05 N58,75W 4600 42 0 3913.07 3815,07 N60,21W 4700 41 30 3987.68 3889.68 N60,81W 4800 41 0 4062.86 3964,86 N59.63W 4900 41 0 4138.33 4040.33 N60,95W 5000 40 30 4214.09 4116.09 N59.73W 5100 40 30 4290,13 4192.13 N60,16W 5200 39 15 4366,87 4268,87 N60.15W 5300 38 0 4444.99 4346.99 N59.20W 602,60 N 1829.48 W 636,74 N 1887,40 W 669.51 N 1945.36 W 702.25 N 2002.59 W 734,77 N 2059.57 W 767.07 N 2116,30 W 799.59 N 2172,51 W 831,49 N 2228,12 W 863,00 N 2282.00 W CLOSURES DISTANCE ANGLE D M S 623.01 N 74 39 32 W 691.19 N 74 32 50 W 758,73 N 74 25 19 W 825.62 N 74 17 2 W 892.17 N 74 7 48 W 958.38 N 73 58 2 W 1024.57 N 73 47 18 W 1090,45 N 73 39 27 W 1156.04 N 73 33 57 W 1221,29 N .73 28 59 W 1285,87 N 73 23 14 W 1350,07 N 73 15 12 W 1414,11 N 73 7 46 W 1478.18 N 73 1 56 W 1542,05 N 72 55 17 W 1605,60 N 72 49 12 W 166'9,50 N 72 44 12 W 1733.04 N 72 38 31 W 1796.61 N 72 28 51 W 1860,99 N 72 10 51 W 1926,17 N 71 46 8 W 1991.91 N 71 21 26 W 2057.35 N 71 0 '31 W 2122.16 N 70 40 32 W 2186,72 N 70 21 56 W 2251,02 N 70 4 35 W 2314.98 N 69 47 38 W 2378,22 N 69 32 7 W 2439.74 N 69 17 3 W DOG LEG SEVERITY DEG/iOOFT 1,001 0,398 1.003 0,446 0,519 0,387 0,375 0,789 0,383 0,548 0.770 0.375 0.314 0.276 0.740 0,859 0,596 1,003 2,064 2,090 1,985 0,825 0,565 0.714 0,864 0.716 0,281 1,250 1,301 SECTION DISTANCE 591.35 656,49 721.16 785,35 849,39 913,25 977,29 1040,88 1104.03 1166.87 1229e20 1291.50 1353,65 1415,70 1477,73 1539,44 1601,3~:--~.~ 1663el. 1725,57 1790.10 1856,53 1923,66 1990,07 2055.85 2121,29 2186.41 2251.22 2315.19 2377,50 ARCO KUPARUK'B-2 GYROSCOPIC SURVEY JOB NO 44.28 14 JAN 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 5400 36 30 4524.59 4426,59 N59,21W 893,99 N 2334,00 W 5500 35 0 4605,75 4507,75 N57,TOW 924,55 N 2383,79 W 5600 34 30 4687,91 4589,91 N56,43W 955,54 N 2431,63 W 5700 33 30 4770,81 4672,81 N56.26W 986,52 N 2478,18 W 5800 32 45 4854.56 4756.56 N56.95W 1016,60 N 2523.80 W 5900 31 15 4939,36 4841,36 N54,98W 1046,26 N 2567,71 W 6000 30 30' 5025,19 4927,19 N52.80W 1076.50 N 2609,17 W 6100 29 45 5ili.68 5013,68 NSO.61W 1107.59 N 2648.56 W 6200 27 0 5199.66 5101,66 N48.86W 1138,30 N 2684,82 W 6300 26 30 5288,96 5190,96 N46,60W 1168.57 N 2718,13 W 6400 28 0 5377,86 5279,86 N44,86W 1200.53 N 2750.91 W 6500 28 15 5466,05 5368,05 N40,95W 1235,05 N 2783.00 W 6600 31 0 5552.97 5454,97 N37.53W 1273.32 N 2814.26 W 6700 31 30 5638,46 5540,46 N33,73W 1315,48 N 2844.48 W 6~00 32 0 5723,50 5625.50 N32,60W 1359,53 N 2873,27 W 6900 34 0 5807,36 5709,36 N31,25W 1405,75 N 2902.07 W 7000 36 0 5889,27 5791.27 N29,10W 1455,33 N 2930,89 W 7100 37 0 5969,65 5871.65 N25,55W 1508,17 N 2958.19 W 7200 37 30 6049,25 5951,25 N23.71W 1563,18 N 2983,42 W 7300 40 0 6127,24 6029.24 N21.76W 1620,90 N 3007,62 W 7400 40 0 6203.84 6105.84 N20.OSW 1680.95 N 3030.55 W 7500 40 0 6280.45 6182,45 N19.73W 1741.39 N 3052.42 W 7600 40 0 6357,05 6259.05 N19,55W 1801,93 N 3074,03 W 7700 39 0 6434.21 6336.21 N20,20W 1861,75 N 3095,66 W 7800 38 15 6512.34 6414,34 N20.06W 1920.35 N 3117.14 W 7900 37 30 6591.27 6493.27 N19-15W 1978,19 N 3137.74 W ooo 3o 53 37 30 6791.99 6693.99 N18.60W 2124.16 N 3186.87 W CLOSURES DISTANCE ANGLE D M S 2499,35 N 69 2 29 W 2556.80 N 68 48 4 W 2612,64 N 68 32 49 W 2667,32 N 68 17 35 W 2720,86 N 68 3 36 W 2772.69 N 67 49 50 W 2822.52 N 67 34 47 W 2870.82 N 67 18 21 W 2916.16 N 67 1 26 W 2958.68 N 66 44 10 W 3001.47 N 66 25 22 W 3044.74 N 66 4 8 W 3088.92 N 65 39 19 W 3133.94 N 65 10 51W 3178,68 N 64 40 41W 3224.61N 64 9 16 W 3272,33 N 63 35 56 W 3320e46 N 62 59 10 W 3368.14 N 62 20 50 W 3416,59 N 61 40 41W 3465.52 N 60 59 3 W 3514,22 N 60 17 43 W 3563,23 N 59 37 19 W 3612.37 N 58 58 37 W 3661.19 N 58 21 51 W 3709,27 N 57 46 14 W 3756,70 N 57 11 6 W 3804.40 N 56 36 42 W 3829,91 N 56 18 54 W DOG LEG SEVERITY DEG/iOOFT 1,500 1,581 0,644 1,001 0.776 1,591 0,937 0.923 2.774 0,674 1,548 0.912 2,895 1.152 0e593 2e044 2.133 1,629 0.844 2,627 1,103 0.204 0.118 1.033 0,752 0,823 0,588 0,365 0,211 SECTION DISTANCE 2496,33 2553.32 2609.24 2663.89 2716.87 2768,14 2818.17 2865,37 2909.87 2954.88 3000.73 3047,97 3096.49 3144,88 3194e48 3297.9 3349.49 3401e63 3454e02 3505,74 3557.30 3608.47 3658.85 3708.07 3756.27 3804.35 3829.91 BOTTOM HOLE CLOSURE 3829,91 FEET AT N 56 18 54 W ARCO KUPARUK B-2 CODE NAME GYROSCOPIC SURVEY JOB NO 4428 · INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE MEASURED VERTICAL TOTAL COORDINATES C L 0 S U R E DEPTH DEPTH DISTANCE ANGLE D M S 14 JAN 81 SUB SEA 4007 3462,88 6486 5453,72 6623 5572,67 6936 5837.08 7177 6030,99 7312 6136.43 T KUPARUK 7432 6228.35 T UP SAND 7466 6254,40 7486 6269.72 7525 6299,60 7597 6354.75 B UP SAND 7635 6383,93 T LOW SAND 7854 6554,86 7862 6561,18 7877 6573.04 B LOW SAND 7898 6589.68 B KUPARUK 7964 6642.05 PLUG BACK 8027 6692.03 TD 8153 6791,99 475,70 N 1230,50 N 1282,86 N 1423.23 N 1550,61 N 1628,11 N 1700,30 N 1720,90 N 1733,03 N 1756,59 N 1800,34 N 1538,17 W 2778,17 W 2821,33 W 2912.42 W 2977,30 W 3010,37 W 3037,54 W 3044.83 W 3049,07 W 3057,66 W 3072.72 W 1823,10 N : 3081.39 W 1951.68 N 1956.31 N 1964.97 N 1977.07 N 2015.10 N 2051.49 N 2124.16 N 3128,38 W 3130,01 W 3133.04 W 3137.24 W 3150,22 W 3162,31 W 3186,87 W 1610,05 N 72 48 53 W 3364.88 3038.48 N 66 6 37 W 5355,72 3099,29 N 65 32 55 W 5474,67 3241.57 N 63 57 22 W 5739,08 3356,89 N 62 29 20 W 5932,99 3422.44 N 61 35 38 W 6038.43 3481,04 N 60 45 41W 6130,35 3497.50 N 60 31 31 W 6156,40 3507,17 N 60 23 12 W 6171.72 3526.31 N 60 7 23 W 6201,60 3561.30 N 59 38 0 W 6256,75 3580.32 N 59 23 21 W 6285.93 3687.25 N 58. 2 29 W 6456,86 3691,08 N 57 59 37 W 6463,18 3698.25 N 57 54 17 W 6475.04 3708.25 N 57 46 51 W 6491,68 3739,59 N 57 23 ~9 W 6544.05 3769,46 N 57 1 37 W 6594.03 3829,91 N 56 18 54 W 6693,99 ', ARCO KUPARUK B-2 CqEASURED DEPTH AND OTHER DATA GYROSCOPIC SURVEY JOB ND 44'28 FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 14 JAN 81 TRUE MEASURED VERTICAL DEPTH DEPTH SUB MD-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 198 198. 298 298. 398 398. 498 498. 598 598. 698 698. 798 798, 898 898. 998 998. 1099 1098. 1200 1198. 1302 1298, 1403 1398. 1506 1498. 1611 1598. 1719 1698. 1830 1798. 1946 1898. 2067 1998, 2194 2098. 2328 2198, 2463 2298, 2600 2398. 2735 2498, 2869 2598, 3003 2698. 3136 2798. 3269 2898, 3401 2998. 3532 3098, 3663 3198, 3793 3298. 3923 3398. 4052 3498. 4182 3598. 100 0 0 .200 0 0 300 0 0 4-00 0 0 500 0 0 600 0 0 7OO 0 0 800 0 0 900 0 0 1000 1 1100 2 .. 1 1200 3 - 1 1300 5 ~ 2 1400 7 ~' 2 1500 13 .:~ 6 1600 21 8 1700 32 11 1800 48 16 1900 69 21 2000 96 27 2100 130 34 2200 165 35 2300 202 37 2400 237 35 2500 271 34 2600 305 34 2700 338 33 2800 371 33 2900 403 32 3000 434 31 3100 465 31 3200 494 29 3300 525 31 3400 554 __ 29 3500 584 30 0.00 0.00 0,00 0.00 0,00 0.00 0,00 0.78 3,78 8.82 17,45 26,42 32,04 38,63 46,63 54e76 63,20 74e20 89.12 109,05 133,00 158,44 184,71 210,67 237,85 265,33 294,04 321,07 347,40 374,66 402,75 430.30 458,03 485.19 513,31 0.00 W 0,00 W 0.00 W 0,00 W 0.00 W 0,00 W 0.00 W 0,98 W 7,53 W 19,87 W 32,75 W 46,37 W 61,88 W 84,84 W 116,48 W 156e64 W 204,43 W 261,34 W 327.86 W 403,92 W 489,53 W 576,47 W 665,87 W 753,24 W 838,52 W 922,98 W 1006,25 W 1089e37 W 1171,51 W '1251,52 W 1330,59 W 1409e37 W 1487,68 W 1565,27 W 1643.39 W ARCO KUPARUK B-2 GYROSCOPIC SURVEY JOB NO 4~28 , 14 JAN 81 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED vERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 4312 3698. 3600 614 30 4445 3798. 3700 646 32 4580 3898. 3800 682 36 4714 3998. 3900 716 34 4846 4098. 4000 748 32 4979 4198, 4100 781 33 5110 4298. 4200 812 31 5240 4398, 4300 842 30 5367 4498. 4400 869 27 5490 4598, 4500 892 ~ 23 5612 4698. 4600 914 ;-! 22 5732 4798. 4700 934 ::~:: 20 5851 4898, 4800 953 19 5968 4998. 4900 970 17 : 6084 5098. 5000 986 :16 6198 5198. 5100 1000 14 6310 5298. 5200 1012 12 6423 5398, 5300 1024 12 6536 5498. 5400 1038 14 6653 5598. 5500 1054 16 6770 5698. 5600 1071 17 6889 5798, 5700 1090 19 7011 5898. 5800 1112 22 7135 5998, 5900 1137 25 7262 6098. 6000 1164 27 7392 6198, 6100 1194 30 7523 6298. 6200 1225 31 7653 6398. 6300 1255 30 7782 6498. 6400 1284 29 7908 6598, 6500 1310 26 8034 6698, 6600 1336 26 5~4,01 N 584,10 N 630.39 N 674,08 N 717.69 N 760,82 N 802.83 N 844.17 N 883.95 N 921.83 N 959.33 N 996.37 N 1032.07 N 1067.17 N 1102,98 N 1138.16 N 1171.69 N 1208.30 N 1248.42 N 1295.3~ N 1346.43 N 1400.58 N 1460.90 N 1527.35 N 1598.70 N 1676.28 N 1755,31 N 1833,91 N 1909,75 N 1982,79 N 2055,55 N 1720.35 W 1797.36 W 1875.35 W 1953.25 W 2028.52 W 2104,00 W 2178.13 W 2249.90 W 2316.86 W 2378.71W 2437.25 W 2492.77 W 2546.30 W 2595,79 W 2642.06 W 2683.74 W 2721.34 W 2758.~0 W 2794.00 W 2830.23 W 2864.31 W 2898.48 W 2933.95 W 2966,99 W 2998.04 W 3028.36 W 3057.22 W 3085.21 W 3113.13 W 3139.33 W 3163.62 W ARCO KUPARUK B-2 GYROSCOPIC SURVEY JOB NO 4428 . 14 gAN 81 ,' INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 2000 1943. 3000 2695, 4000 3457, 5000 4214. 6000 5025, 7000 5889, 8000 6670. 901, 3.86 N 7.74 W 1845. 80.71N 290,20 W 2597, 264.99 N 921,00 W 3359, 474.62 N 1533,82 W 4116. 767,90 N 2115,82 W 4927, 1077.14 N 2608.69 W 5791. 1455,42 N 2930e74 W 6572, 2035.92 N 3157.06 W 400' , 800- I ~00 I SURFACE LOCATION IS 496~ SNL~ 862' WEL, SEC. 9 T II N~ R IOE, U.M. VERTICAL SECTION ARCO OIL 8~ GAS KUPARUK RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000~ dAN. 15~ 1981 x, 520 ~0'-~ ~ 5600~~ ....................................... "~ ....................................... 6000 ~-% ..................... TMD = 8153' (, HORIZONTAL VIEW · ARCO OIL 8~ (~AS KUPARUK B-2 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000' JAN. 15~ 1981 · TVD = 6792.' TMD = 815:5' I0 'T II N~ R I0 E~ U.M. ALL DEPTHS SHOWN ARE TVD Check Form for timely compliance with our regulations. OperatOr/Well Name and Number Reports and Materials to be received by: Completion Report Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Required Yes Yes /Vo -t0-/ Date Received Date Remarks Drill Stem Test Reports Production Test Reports ~gs RLt~ Digitized Log Data Yes ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton//~ Chairman Thru: Lonnie C. Smith ~Ji'-'~' Commis s ioner / Petroleum Inspector January 14, 1981 Witness BOPE Test on ARCO'S B-2 Kupa~k Well Sec. 9, TllN, R10E, UM Permit No. 80-133 on Parker Rig No. 141. Friday December 26, 1980: I departed my residence at 5:30 am for a 7:00 am departure On Wien flight %72 arriving Deadhorse airport at 10:00 am. I arrived Parker Rig 141 at 2:30 pm. Saturday December_ ~27~.~ 19 80: The BOPE test commenced at 6:30 pm and was concluded, at 3:30 am 12-2 8-80. I filled out an A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the BOPE test on ARCO'S B-2 Kuparuk Well on Parker Rig #141, there were no failures. I filied out an A.O..G.C.C. BOPE test report which is attached. DA: mm O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator ~~.~ Representative ~'~ Well K&aP~/~U/C ~'Z Permit # Location: Sec 9 T]]/J R/O~ M ~2,A~. /~/ Casing Set @ ~4 ! ft. Drilling Contractor ~/~/~ Rig # /~/ Representative Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer ,.!Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve : Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM ~ co.f~ Full Charge Pressure ~.Q psig ~~ Pressure After Closure /~f_~) psig 200 psig Above Precharge Attained: / rain /~ sec Full Charge Pressure A'ttained: ~ rain Od~sec Controls: Master Remote Blinds switch cover Kelly and Floor Safety Valves Upper KellZ' / Lower Kelly'" '/ Ball Type / Inside BOP / Choke Manifold ~ Test Pressure No. Valves ~ Test Pressure Test Pressure Test Pressure Test Pressure 3ooo NO..flanges Adjustable Chokes / Hydrauically operated choke Test Results: Failures Repair or Replacement of failed equipment to be made within Test Time ~-- hrs.. days and Inspector/Commission office notified. Remarks Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ARCO Oil and Gas~' mpany North SIope~_r ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 8, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 I._ RE(-'. ---~:'" I J 4 EN,-D'-'/-: C.t SEOL" ~1 "STA'r Y'EC-- I StAT TEC CONFER: -FILE; Subject: Kuparuk B-2 Permit No. 80-133 Dear Sir' Enclosed is the Sundry Notice detailing the wOrk to be done on the above-mentioned well. P. A. VanDusen District Drilling Engineer PAV:sp Enclosure ARCO Oil and Gas Company is a Division of AtianticRichfleldCompany Form 10'403 REV. 1-10~73 Subml t "1 ntentlons" In Triplicate & "Subsequent Reports" Duplicate in STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposalS.) O,L F'ql GAS I--! WELL L~J WELLI ! OTHER NAME OF OPERATOR Atl anti c Ri chfi el d Company 3. ADDRESS OF OPERATOR P.O. Box 360~ Anchora§e~ Alaska 99510 4. LOCATION OF WELL At su trace 496'FNL, 862'FEL, Sec 9, TllN, R10E, UM 1320'FWL, 1320.'FSL~ Sec 4, TllN, RlOE, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approx 63' : Tundra/71'=Pad/98'=RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20531 6. LEASE DESIGNATION AND SERIAL NO. 25648 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Kuparuk 25648 9. WELL NO. B-2 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay/Kuparuk River Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 4, TllN, RlOE, UM 12. PERMIT NO, 80-133 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACID'IZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS, (Clearly state all pertinent ¢letells, and give pertinent dates, Including estimated date of starting any proposed work. ARCo Oil & Gas proposes to temporarily suspend operations on B-2 after setting 7" production casing to permit adequate time for the drilling of our two West Sak ex- ploratory wells prior to breakup this spring. 7" will be set @ + 8100' and cemented as per the original permit. Cased ,hole logs will be run and the '-well left w/lO ppg NaC1/NaBr brine from PBTD to 300' and diesel from 300' to surface. Operations will resume in mid May (+) after returning from our exploratory program. The well will then be completed w/the selective single completion'assy as originally planned. $~bsequent Worl( 16. I hereby certify_that the fo,regolng Is true and correct SIGNED ~'~~ ~~ ~ TIT LE · (This space for State-'~/.°f'~/use)~' APPROVED BY {../t SC~m'""'"~- CONDITIONS OF APPROVAL, IF Dist. Dril li.ng E. nginee.~ . DATE COMMISSIONER TITLE See Instructions On Reverse Side Approved Copy Returned November 7, 1980 Mr. P. A. Van Dusen District Drilling Engineer ARCO Oil and Gas Company P.O. Box 3'60 Anchorage, Alaska 99510 Re: Kuparuk 25648 B-2 Atlantic Richfield Company Permit No. 80-133 Sur. Loc.~ 496'FNL, 862'FEL, Sec. 9, Ti1N, R10E, UM. Bottomhole Loc..: 1320'FWL, 1320'FSL, Sec. Dear Mr. Van.Dusen: Enclosed is t/Re approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If ~available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration~of ~ anadromous fish. Operations in these areas are subject to AS 16..50.870 and the regulations promulgated, thereunder (Title 5, Alaska AdminiStrative Code). Prior to commencing operations you may be contacted by' the. Mabitat Coordinator's .office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations 'promulgated thereunder (Title 18, Alaska Administrative COde, Chapter 70) and by the Federal Water Pollution COntrol Act, as amended. Prior to Mr. P. A. Van Dusen Kuparuk 25648 B-2 -2- November 11, 1980 commencing operations you may' be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire. Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hour's after the'well is spudded.. We would also like to be notified so that a repre- sentative of' the commission may be present to witness testing of blowout Preventer equipment before surface casing shoe is drilled. In the .event of: .suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ,,..,.,,~ ~ ,/~/ ~: ~, ~ ~ Heyfe}~' ~amt!ton , Alaska Oil & Gas Conservation Commission Enc lo sure cc: .Department of Fish. & Game, .~abitat Section w/o encl. Department of Environmental Conservation. w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and G~['~ 3mpany North Slope L)istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 4, 1980 Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: ARCo Oil and Gas proposes to drill a develoPment well, Kuparuk B-2, commencing on approximately December 3, 1980. Attached, please find: 1. A plat showing proposed surface and bottom hole location. 2. A diagram and description of BOP equipment. 3. A determination of maximum pressure to which BOPE could be subjected. 4. A diagram, list of equipment, and operational procedure for surface hole diverter system. 5. A plat showing the proposed wellbore path in relation to other wells within 200 feet. Sincerely, P. A. VanDusen District Drilling Engineer PAV/MEM:Sp Attachments NOV ? 1380 Al#k! 011 & Gas Cons, Commission 'Anchorage ARCO Oil and Gas Company is a Division of AtlantlcRichfieldCompany Form 10-401 REV. 9-1-78 SUBMIT IN 'I~ .'ATE (Other instrt~ s on reverse siae) STATE O F ALASKA ALASKA el L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [~] DEEPEN [--] b. TYPE OF WELL OIL ~] GAS [~ WELL WELL OTHER 2. NAME OF OPERATOR Atl anti c Ri chfi el d Company 3.ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 4. LOCATION OF WELL At surface SINGLE ZONE MULTIPLE ZONE 99510 496' FNL, 862' FEL, Sec 9, TllN, RIOE, UM At proposed prod. zone 1320'. FWL, 1320' FSL, Sec 4, TllN, RIOE, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* R'E£-E -VE !) 30 miles northwest of Deadhorse 14. BOND INFORMATION: Oil and Gas Bond r~E Statewi de Surety and/or No. 15. DISTANCE FROM PROPOSED * LOCATION TO NEARESTSurface- 4418 ' PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, i£any)BH' 1320' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. BH = 4119 ' 21. ELEVATIONS (Show wh~h~'r'D~,'~,~l~, et~.)--v Approx 63' Tundra~..7l' Pad,.. 98' RKB 16. No. OF ACRES IN LEASE 2560 19. PROPOSED DEPTH RD00 :!: MD 5. 50-029-20531 6. LEASE DESIGNATION AND SERIAL NO. 25648 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25648 9. WELL NO. B-2 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay/Kuparuk River Oi' 11. SEC.,T. R., M., (BOTTOM HOLE OBJECTIVE) 12. Sec 4, TllN. RIOE mount $500 :o00 17. NO,ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS Rota ~y 22. APPROX. DATE WORK '6qLL START 12-1 3-80 23. PROPOSED CASING AND CEMENTING PROGRAM ,, SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement ...24" .16" 64.0 H-40 80 -+ Mn " £mt t.n ~,,rfanP. annrnx ?00 ft3 13-3/4" 10-3/4" 45.5 ~-55BTC 2933 8-3/4" 7"' 26.0 ~-55BTC 8000 -+ MD Cmt_witb~aoorox .!.000 ft3 prima] aoorox bE?ore ctJc PaL ry ARCO Oil and Gas Compan. y proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to approximately -*8000' MD. Selected intervals will be logged and tested. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 3-1/2" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the. permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report. Completion equipment will consist of a triple packer selective single hookup. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If propo~! is to deepen give data on present productive zone and proposed new productive zone. It' proposal is to drill or deepen dkectionally, give pertinent data on subs'urface locations and measured and true vertical depths. Give blowout preventer program. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED DIRECTIONAL SURVEY REQUIRED [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES ~O OTtlER REQUIREMENTS: A.P.I. NUMERICAL CODE ,,~o--eL5 - ~o PERMIT NO. ~ 0 - ! ~3 APPROVAL DATE ~g .~~, ~ C hai 'r man APPROVED BY . . TITLE ~ ~ . *See Instruction On Reverse Side BY ,ORDER OF" THE November 7,. 1980 11-7-80 DATE , ¢.~ ~ .., ~Y .................. e~...~..~e~4cg ........ TI'IO=4P65 DEP. iii il i ii i iii jll i i i i i ii ii iii i · · i i I · .J i qgZ' ' 8~'L.' ' 74'L' 62,Z' ~OZ' 3gl' : :~c,,L' 141' ,, ,, .,, ,, ,, _~ " ,, . ¢ ..... ~-----O---~--~ -- () ......-O- ~-" g I EIZ g~ B4 ~ ~,6, 87 g8 .. "'~ '~ ..... ~ ....... ~" '" ' " ........... ¥ ..,,. / ri'''-' ~. .,.,,.- ¢"' , ^ A ...... A ,,, A · , /~ A .... WELL "-'1 Y = 5.cJ69..646o72 WELL ."?7 Y = 5,ggg,6L~7o31 x -- 54~,h57o~O x = 550,17~o~2 LAT = 70°19~40o2~0'' LAT -- 70°19~40,2~q': LONe, 1~9°35~S6oO5~'' LONG = ~4B°35~35~035'' WELL .--"2 y ~ 5,969,6/~7o44 WELL ~8 Y = 5,~69.04~o38 LAT ~ 70°1~0~2q0'' LAT : 70o19~O~237'' LOHg: 1[~°35TM.~2,5~3'' LONG = 1~5°35~31 ~5,2"_ WELL ~3 Y = 5,969~646,.89 I HEREBY CERTIFY THAT I AM X = 549,697,h7 PROPERLY REGISTERED AHD LICENSED LAT ~ 70°19'40,27~'' TO PRACTICE LAND SURVEYING IN L'O~IG = 149P35'49.,04~" THE STATE OF ALAS~ AHD THAT THIS PLAT REPRESENTS A~I9 AS- WELL .'~4 Y ~ 5,q67,647~31 BUILT SUP. V~Y MADE BY ME, ArID X = S49,817,62 THAT ALL DIM[~.ISIO~,iS AND OTH[~ kAT 70°I~40 272" DETAILS ARE CORRECT, AS OF' kOHq = 149°3'~'45,,539'' 'DAT~ t/7/~ ....." '": ~. "... .,.,~..-'":.. . -~.' ~. ~[ WELL :~5 Y ~ 5,969,~702~ .~.<. · , . r~ X : 549,937.65 ., .~- ,'.. · . ~ LAT = 70°19~0 263" ../ .... .jZ .... 4 ''. ~ LOHG = lbg°3G~2003[TM . . ~ ~ . ,, ¢.. :,%s...-, .; WELL .~6 Y = 5,36~.5~7030 · · ,-.q · ~ ~50 0¢7 33 "'" ' ' ' · , ~ ~ ~" . ., .,' LAT = 70°1g~;0~2~6'' , ' ".;.-,..,. '".' LOtiG = I~q°~5~38,527'' '"'" ' ..... ' ............... i i i ii _ ~ _11 i Il ' ,, _ _ J ! II 2 _ I . _ } __' ~ ( P.~. ~, WELL~ 1 -8 LOCATIOM~ A~' DUILT ........... mp .................................. AtlanticSichfieldCo any ~ D~iE: DBAWING No: NOSTH AMERICAN PRODUCING DIVISION,l~/o~t~]~O '"' ........... Distance from RT 8.5-0 -! 3.35 11.85 t 2.55 14.40'--~. t 2.4 16.80' 't t- 1.7 18.50- t I" 2'.35 d' ., P i P F. G, 5' (~' I P ~ P. AM$ 1. 16" 2CCO :'.CE'.'OY 2. 16" 2C'30 PSi x ~0" .:.,~.0 F.c:,C': HEAD. .3. 10" 3003 x 10" x 3-:/2 .... :.,n,- . 4. 10" 3000 PSI x 13-5/8" DRiLLi:;S 5000 SPC3~. 5. 13-5/8" 5000 PSI SHAFFER :.I/P:?E R~'iS. .,6. 13-5/8" 5000 CHC.'<E SPCOL. · .7. 13-5/8" 5000 PSI SHAFFER. 8. 13-5/8" 5000 PSI SHAFFER AMHULAR. ACCUMULATOR CAPACITY TEST · .. . 1. CHECK A;~D FILL ACCUHULATOR RES-'?.':O[R TO PROPER LEVEL WITh' HYOPAULIC FLUIO. 2. ASSURE THAT ACCU:.'.ULATOR PRESSURE IS 3000 PSI WITH 1500 PSi DC',,:NSTRE4;'I OF THE 'REGULATOR. · · 3../.. OBSERVE TIHE THE~; CLOSE ALL U;;,.'T SIF;UL- '" -- TA~iEOUSLY AND RECCRD THE TI[.!E AND PRESSURE REF~AINI~';G AFTER ALL UNITS ARE CLOSED WITH CHARGiHG PUH? OFF. 4. RECORD ON IABC REPORT. THE ACCEPTABLE LONER LIMIT IS 45 SECO;IDS CLOS::;G TiME A;ID %~oPSI REHAINi:;G PRESSURE. " 13-5/8" BOP STACK .TEST (TO BE WITNESSED BY DOG REPRESEiiTATIVE) 3" ' H~ 1. FILL BOP STACK AND HANIFOLD WITH ARCTZC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FUL'LY' ,, RETRACTED. " .... ~ .... PRr_u:~cxmI.,E DE?TH PLUG HILL SEAL & HARK RUNNING JOINT. RUN TEST PLUG DRILL PIPE AND SEAT IN WELLHEAd. RUN IN LOCK DOWel SCREI.'IS .IN HEAD. · 3. CLOSE ANNULAR PREVENTER A~;D CHCKE'S AND BYPASS VALVES 4. '[EST ALL COMPONENTS TO 250 PS.: AND HOLD FOR · :..' 10 HINUTES. .,.." ..-" 5. IHCREASE P~ESSURE TO 1800 PSI AND HOLD FOR 20.85 10 MINUTES. BLEED TO ZERO PSi. I -- | 6. OPE;'I AHXULAR PREVENTER AND CLC.:-' TOP SET OF 1.4'3 .: (~ ~] , PIPE RAHS. ' ' ' .7. INCREASE PRESSURE TO 3000 PS Z AND HOLD FOR "' :" '--· '.: ....... 22.28 8. OPEN TOP SET OF PIPES RAMS A~:D CHO~ES, . ' ' ' ': ' 3"~]~ ' ' THEN CLOSE BOTTOM SET OF PI~E RAMS AND -'. ,,ri ,.. ANY WITH 3000 PSI UPSTEA:.i OF VALVE AND ZERO 10. BAC;< OFF RUNNI~G JOINT A~;D PULL OUT OF HOLE 24.50 --~~-~. . ~~~}' 3~:'~.co'' M[~UTEs.CLOSE BLJHD ~',[S AND TEST TO 3080 PSI FOR 10 1.3 ~~~ l i. ~LEED PRE~SURE OFF ALL EQUIP. OPE;,BOTTO:.I 25.85 · - -., ( FULL OF ARCTIC DIESEL AND ALL VALVES ARE ~ SET IH DPJLLI¢;S POSITION. 12. ~EST STA¢~DPIPE VALVES TO 3000 PSI'. [' 13. ~EST KELLY COCKS A¢;D INSiCE BC9 TO 3000 PSI ~r,~ 14. C~ECK OPERATIC:: OF DE GASSER. x LE',~L 15. RECCRD TEST I"-'"'""ION ON BLCi:CUT.R,R~rE.~TCR ' · TEST FOP;I S[G:; AND SEND TO . ~ ,, " 10. PEP. FOR;t CC;.tPLETE BCPE TEST k, FU;;CT~C;:AL OPERATE 5CPE D.A[L'~'. NOV 7 . . ,. .... ~ ....~ .... ~.¢ . . · .'.. v'. '. ,... :...;,'. -t4- Alask~ 011 &. Gas:Co~. ' ...~.,. ..... ~ ,~. , , , PRESSURE CALCULATIONS The anticipated bottom hole pressure in the Upper Kuparuk zone is estimated to be 3265 psi. This number was based on empirical data drawn from completed wells in Kuparuk. The maximum pressure subjected to BOP equipment is esti- mated to be 2700 psi. This figure assumed a conservative 1 psi/ft overburden pressure gradient (2700 psi surface casing shoe integrity @ 2700 ft) and a full gas column to the surface. This 2700 psi is 10% below the BOP test pressure. Et EIVE NOV 7 Alaska Oil & Gas Cons. Commi~' Anchorage outlets blanked "' ' .~ ~ ' operate preventor to chec 2. 16' 2000 psi drilling spool ] . ~ on opening and closing at 3. l~" 2000 psi annular preventer ] ] .2- Every 12 hours blow air c 4. lO'ball valves ' ~ ' diverter lines. . 5. 16" B~adenhead ~ q ] ' . ~ . 6. Tarqet Tee's ' ~ ~ Operating Instruction '' .~Elbow · '~ ~ ' 1. Open valve to dowm~ind l'i '. Connections on ~ ~ ~ . '2. ,Close annular preventor. I E£EIVEI) Alaska Oil & GaS~.ns. Commission Anchorage ,',r,.~' ..... ~,~',~ Kuparuk B-Pad · . . . z~ ' : .,'~L~'.. ................. , "i ',.~. i 'i;Z'i~]i] .... ; ,. ....... . .-.ill :]i:ii~:Lii' ': .... ' ' . :-L_' ! :].. Z L'_. I .... -: .:: :' LL"':-'Z! :- - £!.LL LLi. T.i-i.-: i:.L- ].Z ..Z:~ i:: ...... : ....... ..]-::ii.i: ".:.' "::..::F~-~ii~!'_-':;!!!i.i!i.':'!'::.-i:.!i!Target LOCa~ion':ii;::i:!.:':'ii:-:::i"::' ............ ............... , .............. " " 2 ' :i.] i :..:::i',,. :..-.z~!;i!:'!:..i!.!.:.::i]].:i.' ]1320'. FSL .... ............ "======================== . ........ ~&L~:& ...... : ...... : ........ :...:_: ..... '.~:~n :~...'~i-'...:.~_!~~ '. ~·:.:i:i~-L ::!: ].'} !~'-].: surface. .,: i: i-:~:,~ ii 'i:-:'.Li :'~.. ~..:: :: ~T[F"~TT'?-"' i-'-'T'--'i~-9 6'"--FN-L'i: F'~:T'--':""~T!"--' !?: "--- t'-:'"'"~ --::!-'.,.l,'.-'.-:-i~h! !.Tr.:F:~?.:Z~L iL}'], i.~!:'i.}-:' : .-:':-'-:.]:':/'.-'862' :. :""~i':i .... ~-.-.":'·2S'.~:: ·Fi',.'.:"::.2,:.'.]LL.:'.:'..;., :."2':'.'LZ::LZ~L'T_:'~: ..... :'ZZ:?'.'.'-: '. 'T: .. L:.: ..-' :~' :.~.~ ~:- :-.':-: ,:::-.::.'.".-.-:.: ' . ..................... :..-:.:....-.....- .... .:.. :..~:.::~:.:~ : !.. ..................................... ................................ ....................................................................................................................... ......... -::::": .................... ................................ ......................... ! !~ }...-.-:£! ::~`£ S.~S--. ?:.~!:~:".~.T:-..:F....~: :: : :: !~:. i. !~.!~:.~i~.:..:.:. ... '' ..................................... .................... __ ................................................................ ".L~_EE PRQ'_.B,:'~EEL']NO: ~2 :'F~,'ROPOSED ::L!_::.... .... ':"L: ...... ~' ..... ~ KUPRRJK...FI~ELD,.... NORTN ' SEOPE~.--.~ _RSKR,2~-'--:'-~ ........ ~.--SCRLE 1--tN.-. =. "100( FEET .... ,~ .~. ..... ....... ....... ........... :2:: :5: ::5' ; , , , = . . ,, ,.,rL-r...~~ ~ '-.~.,,~_~,~ , ' ~..m~_~_~_~_;_~%_~_; . . ~. , .............. ~ .... ~_,~ ............. ,.', ,~ ~ ~ '~ -~ ~--.~ , ,, ~ ...... ~..~.~ .... ~_~...~- ~ . , ~ -'-r---r-~ ...... f~ ..... ~..~-~- .__~,_+-rT~-?T-~-~_~ ~ --~-.._~__~.~,' ..... . ?~e .... ~---~ :. .-~-..~-.---;~ ............ ~. . ~ "'~-~'~- "'~"%~'~ ~000 ~_ """ ......... ..... ~-'~-~, _~.~ .... ...... ~'--1,_~ .............................. ...... , ~, .............. ~ ...... 4~4-.- ~-4 .... ;-.- ~?~Z?' '~U~c~:"-= ............ ' ...... ' .............. ~-'; ..... 8ooo' .;..T4.-;... ~ooo. ¢ ............ Eooo"-['"[-'~- o' :'::: 7;:7~ .:.~ ~ ~ 'E'-'E+- ~'- K I ' , ~"7', ~ ~ ~l . -r-.-,,-e--~ ~ ..... ~-~.~--~.-~-~ .......................... 1 ........ ~-~1.--~ .... ~. ~. ~ ..~-S~ ........ ~ .......... ,__.~,.t ...... ~:. ~--. / ~. ~ .... ,--~.-~.--- ..-~. ~". ..... L~.~.~ ., ~ ~ . ~. j Nm-S~S~S~Z.- ' ~ ~ .~.+.~-..~...~. ...... L~. _~% .... ;~ .... ;___ . . ;_~...; ~ 'r ...... . , , ~ 0 KO~~[ O0 ,, , ~r ~ ~. r' , , ........ ~'"~ ...... ~,-r ..................... · ~.~ ...... ~ ......... , m ~ ~ ~ .... . . ' ' , , , _~al . , ~T~-f-~-~-'~I8BRSE.PER~RFROST. ~ .................... ~-~ ....... ~ ..... :..~ ........................ ~~ ~i¥'-5~"[VD-16~11 'T~D-I651 'DEP. IID-=--- -~-~ ..... rRRSET '-~ ........ ~ ........ ~-~...~.. ~-L-':~ ........ ~ .... ~-~"-TS'~"r-'''~' , : ~ , , , ~, ,, ....... ~, ~--,~-, ~ ~'~' ,-~ .................. --.~ ..... ; ~-~ ..... ~ , , . ; , ~l' ~ ' ': ' ~'l---.-----'~'~ ' ' .... ' ' ' ' ~ ~e'~ 4 ~9 ' ''~, ........................... ....~-', ~-~ ~ ...... ~ .............~ ; ~ ...... ' r ..... ~ I~S~ ..... L_~_~. _[ ~""~ OEP.407 .... : ...... ~-'T '-~ ........ r ":-'T I-' ~'?-"~ .... h--t~ ....... r4 ....... ~-; ............ ~ .... ~--,.~ ....... ~ _~__~ ...[Z; ~_~; ~ ~ .... ~ ~ ~'~ · , ~ . ~"~ ...... :r"~"?~ .... :'-~'~'-t"t'~ ........ ~t-~--~ ...... '. , mi ~ ~ ' ~ [ [. ,I m .: ' ~ ~ .~ '---, . l"?-~'m-{-~r-,----~ ...... ~.~ .... ~.~.. .... ~ . ¢ _ ,_,~._~ ]~'-~'~$-~ "~'-~-~-~--~-rX ....... ~ ........ ~ ............. 1 ......... ' ....... ~. :'"?'"r'7--'...".~r7 .... ~'"'~ ~-"""f-"l ..... ~"f-~ ........ ~-~-~'--~ [~---t-.~ ~ .. ~.~-,;-,,,L4-.L,,N . ~-~---:-.' ...... : .' i ~ I ' ~ ~ ~ T : .... T"T"~-T ....... ?~ ........ ~T"t ..... ~ ....... l"--~"-h ........... ~'='-~ ...... ~: ~uuu _ ,, , , t ' " ............ ,"I'-~''*-~ ......... ~'"t .... ~ ................... ~t' ............... ;-'f'"'~ ..... ~/-~RF ~ ~ ~~_ m , ' '~ ~ ..... F-t ..... + ..................~ ~-.--~ ....... ' ' ' , - ~ , : , : ~ ......... r- ~- ~ ...... ~-'~ .... ~ ...... ~-~ ..... 4...~-.~-.~ ....... ~ ~ ......... ~_ _ ~_' ..... ' ' , ' i . ' n~" ...... _~..~_ ..:,_..~_~ ;_.~ .... ~ ..... r __~ .... L~ . '.. --''~--~' ~ ....... ~ ..... ="rT~'~'~rs'--OOZ ...... r: ~-ff ........... ~ ...~-~ ~:~... _.. ,. ,, ....., , ~'.,,~. "~N;,z~s~,~,.~.,.,~,~.,~z~~~--.,, ...... ., ~ ................ ~:.~.._::.~ ....... ~:-.?~ _~ ...~..~,A~ [ ........ ; .... ~ ......... :..~..,...~ ....... -~::~:~ .... rvO,~4~.T~O.4~s o~.~e ......... ~---[ ............. ~-....-~ ..... ' T----~ ........ ~ ....... ~'~ ............. ~ ........ · ....... ~ ...... ~ ..... , ~ ~ , L , , ~ r -- ' ' ~"~ ...... r', .......... - ~,..~. " ...... ',..' ..... '~.. . : : ~ . - ....... i"T ....... r'T''''-~ ........... ~ ', . , ,- , . , - ~ . , , , '~?-'-~-~"~ .... ~t ...... r--~-.~.~...~ ......... ~- -¢ ...... : ............... ~ ...... ~...,.. ~.~.~ ............... ' .... ~._~__?~..~ ......... ~ ..... ,._~...~ ......... ~ .................... ':::~ ~. ~ ........ ..... ~'-~--~- ~-r-.,-~ ....... ~---~ ........ ~ , , '. X ~' , ' ~ l' , ~ ~ . . '" ........................... ~--,~-- ~ ....... L L ~ ' ~ ~ ~ ~ ~ ', ' , ' 'T-"'"= ..... T-~'N ~ '~ ...... t"'~ ......... ~-. ~. ~r ...... , ..... .... ~--~" ~"' ........... ~'~ ~ ........ ~ ...... ~"~ .~ ~.- , ~ -~-~ ; ~ ~, : I . ~ .............. ~-.~ ..... ~..~....~.~.~ ...... ~ ~ ~ ~-. --~ -~., ~ *,- ...... .............. ................................... . ....... .................. ' ~ ' ' : , ':: ' . ~ , ................ T .............. ~-~'~-~'~'-~ ................. '-~ ...... "' -~-~-4 ' ' ' .... ' : ' ~'"~", , ~ . 'r"t .... ~'""T-'t ........ ~ ................................ ~ ..................... . ~' ' ' ' '~ ..... ~.-~ ...... , ............ .. · ~ ' x. ' ~. , ' .................. r .... r ........................... i ............ . ~ ~_~_. , ,, R~ ....................................... : ............ ~ .......................... ,.. . ..... ~.~.-~..' '/ ':.:":":."[ '7' . ERRGE RNGLE ...... ~,.;. ':..~, ~, ~ ~ ....................... ,,~..~,. ~,.~,~ ................ ..:~::~.,:,-: ::-.:.:- ~m~_., , ~ ,~G.~ ''~ ....... :~,'":'1 ................. ~ .............. ~ ..... .. [::Z~: -~-T: ....................... ~': ..... :: ."?..'::,::..:.'. :.:::." 7:. [':::::':. ~ , : :': 7: ~ ,TRRGET :[,T~P KUP. SRNDS).: TVD=6~8 T~D=~4~ DEP=~59~' ~ . --'~--r-~ .......... . ..... : ..... I ..... T ........ ::: .......... ~.:.: .... ~ ........ ~j~:.:~ .......... ~ ...... d ........ ~ ....... : .... ~ ........ ~ ..................... , ........... ....... :--r ...... ~..~-.-T ..... t .......... ~ ....................... i ...... ~ :, -~ ~-'~ ~~ T~b~-~'~ ~ b~ -~-~e~'E - .......... ~ ...... ~".-T ............. ~ ........ ~..~ ........................ ', ......... I ........ ~ .... t-~'~ .............. ........ , ............. ~ ............ ~ ..................................... ~ ......... ~ ' ' '~TD' TYD=6687 T~D=BO00 DEP-~94~ .......... ~ .............. ..... ~.~ . . , . ~ . .., .......... -- .... ,~no~ ..... ~ .................. ~ ........... , ............. , ................... ~ ... j .... 'T~'~-~ ....... I ........ ~-~, ~ ................. - .... ~"-'~ .... :-: I. -. ' ........ ~- ......... :..,.'-...: ........... ::':::" '::~:~ .... ~': ............... ::':::'::: :'::_~'""::~'::":~:'::':'-~ ~ ,, ~ ~ ,. ~" ';.":::.','.':::::~::..~oo :' [.':":':::'~' ooo ::'~.:. :::.: ~ooo "', '~:'..":':' 4ooo "~ ............... L ~ ~ I mL 'I'''' 'VERT ICALT-SEC~'ION , ~,':, ' r ---~ .......... ~ ............. t ' .... .... :',: t':::'::':- :..::.' :::' ,'"'.'.'-:: ........ ...... iii i i ii iii i i i iii I .... ~ ~ 4i 'T ii kI"~iOF-'U ~" I'' , I' ~ ~ ~ l, ' · · '~ c:l~Z' 8 ~,2.'L_ 742' ~,ZZ' Foz' 38~' 2 co2.' ~41' i .j . .... ., ' V ¥ ........ V V ..... V ........ V' ' ¥' "' I I i ..,-' ': ." .,. ' ~_ a, ..... Z,, '^ ' I 'dELL .'-'1 Y = $,969.,646,,72 WELL ;;7 Y = 5,~69,647,,31 X = 5hg,h57o40 X = 550,177oa2 LAT = 70°19:hOo290'' LAT = 70°lg~4Oo2t, q'; LONG, t49°35~56oO5~,, LONG = ]hg°35~35oO3F,, WELL .;:'2 Y--. 5,96~,6t~7.44 WELL ~8 Y = x = 5h9,577o73 x =. 550,297o?~ LAT = 70°19~hO.,2qO'' LAT = 70o19;hOo237'' . L0:~G 149°35TM _" = .~2.543" LONG = 149°35'3]o5~2 WELL !:'3 Y = 5,969o646,.89 ! HEREBY CERTIFY THAT I AM X = 549,697,,~7 PROPERLY REGISTERED Al'ID LICENSED LAT -- 70o19~4Oo27~'' TO PRACTI£E LAND SURVEYING IN L'O,qG = 149.°35'45~,,O4~3'' THE STATE OF ALASI-t~ Al'ID TttAT THIS PLAT REPRESENTS' Al'ID AS.- WELL · '~4 Y-- 5,q6~,647~3] BUILT SURVEY MADE BY ME, A.qD X = S~9,.q17o62 THAT ALL DIHEI'.ISIOI',:S AND OTHER LAT = 70°I~,:4Oo27£'' DETAILS ARE CORRECT, AS.O[' lONq= 149°3C'45.,539'' .DA'I'E t/7/,~O ....." '": c. ".-'.."..' .": -...a... ~.o, ,.' ~ ~. ',/ELL ::'5 Y .-- ,r',96g,647o24 _.,. ,... · r~ X -- 549,737o6.-' '¢'~ LAT = 70°'1'3'40 263" ,, ' '/' .... .-, LO'IG = 149°3S~t~2,,O3.r'' I ..,.~.,ZJ . . ,. :.. :;".,..~,f..-., .=.: ~mWELL .e6 Y = 5,96~,5&7o30 " . ~ X --- SSe,g57.~3 .... LAT : 70°1~40 '~56" '::, ''---, ",'~ LO~/r, 14q°'' .7' ....... J~ i~ ~ t .................. -- .- ~-- , ....... P.O. B, W'ELL5 I --8 LOCATIOLI4o AG- BUILT ,, · i ii _ - ' .......... . i~! i i __L II AtlanticRiChfieldCompany 0 DATE' DRAWING No: NORTH AMERICAN PRODUCING DIVISION 1 ALASKA DISTRICT- KUPARUK 'ri, u,'~o~,u.~i.'~ ' ~ '> "~ q h k~ -~ -~ "0- -" ' cl~?..' ,!~,2.' 74'L' r,,ZZ' FOZ' ~Jgl' ~ c,,?..' 141' ,~-----( ~------~-----~--' C) ----tO---ql-- -~ 151 BZ B~ 154, E~ fl, 4, lB7 ,. .......... , ............ ..,.' ': - A ..... ~ ,A A A A .............. _., .c~" 'v"~6&"' - · CO-OR~IMkTE~ Distance from RT 3.35 2.55 2.4 16.80' 't " 1.7 18.50-, t" ' ' 2'.35 8L ! ~;D · I. i ,. e, I P E PY..V,S S~ . o " I ' ' 1'1'3 ': ' :: 7. lA · ' :'nl"J ®' 24.50 "3ccc' ' 25.85 ' - .... \ pr, D 1 ,;. \ LE',--_L ' 15, ',, \, · , , . · . 12-:,/%" -'CC'] :'-" 'SC? :-'-92 16" 2COO,.Cc.~.{n ............ =.,,.~,:.,.-.?~ 16" 2CLIO PSi x '10" -m~ .;,.,u 0 SSG HE~D 10" 3000 x 10" x 3-!12" ;;cE':OY TOG RA.':GER. 10" 3000 PSI x 13-5/2" DRiLLi:;S SO00 SPCSl, 13-5/8" 5000 PSI SHAFFER '..I/PiPE 13-5/2" 5000 CHC':tE SPOOL. 13-5/8" 5C00 PSI SHAFFER. h,, ,UL .... 13-5/8" 5000 PSI SHAFFER ..... ACCU:.IULATO.R CAPACITY TEST CHECK A~ID FILL ACCU>iULATOR RESE!':OIR TO PROPER LEVEL WIT~. HYDRAULIC FLUID. ASSURE THAT ACCS>tULATOR PRESSU~.E IS 3000 PS): WITH 1500 PSI DC'.{ilSTREAM OF THE REGULATOX. OBSERVE TIHE THEf: CLOSE ALL U~;iT SI~'iUL- .T~?~EC'USLY AND RECORD THE T!~.iE A;:D PRESSURE RE!'iAIi.II;':G AFTER ,-,_L U~I!TS ARE CLOSE'3 WITH CHARGi~':G PUMP OFF. RECORD 0~ IAI]C REPORT. THE ACCEPTARLE LO'..IER LIHIT IS 45 SECO:IDS CLOSi:;G TiHE ~2.00PSI REHAINI~JG PRESSURE. 13-5/8" BOP STACK ·TEST (TO BE NITHESSED BY DOG RE?RESEHTATIVE) FILL BOP STACK AND HAHIFGLD WITH ARCTIC DIESEL. · CHECK THAT ALL HOLD DOWN SCRE',':S ARE FULLY RETRACTED. PRECETERMINE DEPT:'( PLUG :'fILL SEAL & MARK RU~'INING JO!~;T. RU~: TEST PLUG DRILL PIPE A:~D SEAT Ii'( ' ' ,'ELLH,.,-.~,. LOCK DO'.':;I SCRE~.'~S .IN HEAD. CLOSE A}i~iULAR Pr, z,c,,TcR A~D C:-:CKES AND BYPASS VALVES ON HANIFOLD. .' lEST ALL COMPOi;E?]TS TO 250 PS", A;:D HOLD FOR 10 I'Ili;UTES. IIICREASE P~ESSU?,E TO 1800 PSI A::D HOLD FOX 10 HI:lUTES. BLEED TO ZEP, O PSi. OPEl') AN~;ULAR PREVENTER AND CLC,~E TOP SET OF 'PIPE RA;'~S . INCREASE PRESSURE TO 3000 PSi A:;D HOLD FOR 10 HINUTES. BLEED PRESS TO 0 ~SI. OPEN TOP SET OF PIPES RAMS A~:D CHO:<ES, , THE~i CtOSE BO~ ,~,., SET OF PIPE ?,A~.:S AND VALVES DIRECTLY UPSTEA:,I OF CHCKE5. TEST RE~.!AIHI~:G U~ffESTED ...... = ' r,..,I, C~D VALVES IF ANY WIIH 3000 PSI UPSTE~2 OF VALVE A~D ZERO PRESSb.'RE BACK OFF RU~NI~G JOIHT A,~;D PULL OUT OF HOtE CLOSE BLt~:D RS2S A~:D TEST TO 3CC0 PSI FOR 10 ~.%I F, UTES. BLEED PRESSURE OFF ALL EQUIP. OPEN BOTTC."l PREVENTERS MAKE SUP. E I'WIIFOLD &LIIIES ARE FULL OF ARCTIC DIE~:I A~D ^ I ~,- ~L, VALVES ARE SET Iii DE~LLIi~S POSITION. VEST STA~DPIPE VALVES TO SO00 PSI' TEST KELLY COCKS ~D INSidE ~C? TO 3000 PSI C~ECK OPE.,RATID~: OF DE GASSE~. RE£C~.D TEST I~lrC,?,2,q, ICN .OP: .QLC,~uU TEST F07}1 SIC:; A:ID SEtJ~ ..~3~ t~L~Jl';~ SUPERVISC? PC ...... r-- -, -:1. , :Il' FU:ZTtC::AL OPE,.':,,',TE 3C?E DAILY. NOV 7 1-980 -14- AlaskaOil & Gas'Cons, Commission.' ..... ~- ,i Ane, bora. ge .. CHECK LIST FOR NEW WELL PERMITS Company Item Approve Date (1) Fee .LY~ ?//?//~ 1. Is the permit fee attaChed .......................................... 2. Is roll to be located in a defined pool ............................. Yes No (2) Loc. ' .... // , . Is a registered survey plat attached ................................ / Is well located proper distance frcm property line ................... Is ~11 located proper distance frcm other ~ells .................... ~?~. ,/ Lease & Wel 1 No. /_~,j,.,~ Remarks (4) Cas9. -~ ~ ~ ( 5 ) BOPE ~? 6. Is sufficient undedicated acreage available in this pool ............ 7. Is ~11 to 1~ deviated .............................................. ~. 8. Is operator the only affected party ................................. 9. Can permit be approved kefore ten-day wait .......................... '~ 10. Dc~s operator have a Bond in force ........... . ....................... 11. Is a conservation order needed .................. , ................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings .. ~ 16. Will c~t cover all known preductive horizons ..................... '~ 1'7. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and turst.. · /f'" ~L..~c..~ 19. Does BOPE have sufficient pressure rating - Test to ~'~¢P© CEE) ,,~proval Rec~nded: psig .. Additional Requirements: Geology: /? Engineering: LCS ~-~ mEW JKT --- RAD_J~_ rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this ' nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. ,. II II 1111 Ii II 11. II II II Ii Ii 11.111.1 111111 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 77 ? 7777777 77 77 77 77 ~7 77 77 77 77 77 77 7'7 666666 Ii 3.33333 660666 II 3133.~3 66 1111 33 .Il ~6 1111 33 66 1,1 '~3 66 11 '~ 66666666 !1 33 66666666 11 66 66 11 .~3 66 66 11 66 66 11 33 66 66 11 666666 1,11111 33333,3 666666 1,111ll 000000 000000 00 O0 O0 O0 00 0000 O0 0000 00 O0 00 O0 O0 O0 0000 O0 O00O O0 O0 O0 O0 O0 000000 000000 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 77777777'17 7777777'777 77 77 77 77 77 77 77 7'1 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 (o (: G (, ,, G G G G GG(; G G GGG H H BBBB H H 8 B H Fl B B HHHHH 8BBB H H B [4 H E B B PPPP R F, RI9 P P P P R PPPP RRRR P R R P t~ R P U O D D D O R U U D R U 0 D U II 1) U O D O U D R 'U U O 0 U O O D D H H 000 D H H 0 0 D H H H H H 0 0 [.) H H ti 0 H H PL, EEEE E E EEEE E h, *START* O N I T 0 R * 8TA R T* riSER FCA,L [10707,6:1350.1 dOB SWS KLIOE40 N[]V-80. *STAR~* 1,18~ PCAL 8W8 KLIOE40 [1070'7,61350]T dOB NOV-80. *STAR * SEQ. 401 Si-tiP SEQ. 401 DATE ()I-FEB-al [)ATE 03-1' EB-81 16:25:16 16:25:16 IIIII1 IIIIii II I.I II I1 II Il II II II II iIIItT IIIII1 PPPPPPPP PPPPPPPP PP PP PP PP PP Pp PP Pp PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTf TTTT *SIAR,q. USER PCAb [10707 ,bJ 3501 dOB SHIP M[JN,IT[)R SWS KLIOE40 NtJ'V-80. *STAR C* F1LE: DSKH:SHIP.T,O<255>[lO707 61350] CRE;A'rEI): PR].NTED: 03-F'EB-81 1~:25:,34 Q'LIELJF, SWITCHES: /FILE:FORT tCOP,IES:I /SPAC1NG:I /LI. MII'lll,q /FOR~S:NuR~,I~B SEO. 401 DATE O't-~EB-81 03-F'EB-81 10:16:49 16:25:16 StrIP TO : 6H1PP.[NG I N,STRUC'~ IONS I, S S U 1~[,) 3-[~'Ei~-8 1 10:10 VENT~JRA, CAI. IBO~NIA 9300] PCCC ~RRRRPR IIIIII PRPRRRR~ ilillI ~2 RR II RRRRRR~ I1 ~FRRRRR II RR RR Ii RR RR RR R~ II RB RB II R~ RR IIIII! BB RR IIIIII ~¥ YY YY YY ¥'¥ YY YY YY YY YY YY 000000 000000 11 O000OO 000000 11 O0 O0 O0 O0 1111 O0 O0 O0 O0 1111 O0 0000 O0 0000 11 O0 00:00 O0 ()000 11 00 O0 O0 00 00 00 11 O0 O0 O0 O0 O0 O0 11 0000 O0 0000 O0 11 0000 O0 0000 O0 11 O0 O0 O0 O0 O0 O0 O0 O0 1,1 000000 000000 1,111 000000 000000 11,11 1, 1 11, *~TAR%* USER PCAL [10 07,613501 dOB SHJ. P SEg. MONIT(1R 8W8 KLtOE40 N[)V~O. *START* FILE: DSKHI'VE,R1F'Y.O01<05'7>[10707 6,~i350] CREATED: FRINTED: 03-FEB-81 16:2~:-6 OUEUE SWITCBES: /FII,,E:FO~T /COPIEM:I /SPACING:l, /LI~'tI1':134 /FORNS:NOBHAb 401 D A T E O 't-FE B- 81 O,]-FEB-8 1 16:08".08 16:25:16 LiS VE~SIUN 15.}i01 79/031:26 SCHL[IMBERGER CO~IPUT.1NG C~NT~]~ 10707,61350 ~LEL HEADER LENGT~t: 132 B.~TEb REEl, .t%~ A.I~ E: P.C.A.L. SERVICE NAME: El)IT REEL CONTINUATION NU~ti~;R: O1 PR~iVIOUS REEL NA~IE: C[]~I~ENTS: LIS FORMAT CUSTO~E~ TAPE DA~E: @l/ 21 3 'TAPE LENGTH: 1~2 B~'TES TAPE NAME,,: 61350 8ER'ViC~: ~,IANE: EDIT TAPE C[15ITINUATIt.3N NOi~B~;~: O1 PREVIDI.18 TAPE iNANe.;: C(']M~IENTS: TAPE CO~ME.NTS t)IL RUN ~ 1, L[)GGE':D 12-DEC-80 CASII~G DRILLER 10.75 IN. 8 2928 FT. BIT SIZE 10.75 IN. DENS = 11.0 VISC = 51.0 PH : 9.5 FLU ID LOSS = 6.4 ML RM ~ NEAS TEMP. = 1.46 (a 76 17 ,RM[';" " " = 1.05 Ca 76 F' [)IL ~[;N ~ 2, LOGGED 6-dAN-81, CAS,Ii.NC [)la ILI, Et{ = 10.75 IN. @ 2955 FT. BlT $IZ~] = 8.75 IN. FLUID IN TttE }tOLE = OI.L B,ASE I)ENS = 1, 0.5 V,ISC = 53.0 FLU],D Lt,]SS = 2.4 ~L BHT = 1 ,~9 F LENGTH PP, EVIOUS F'IL~, RUN ONE CUNP~,N¥ WELL FIELD RANGE TOmNSHIP ~E, CTION STATE 1DENSIT~ 62 BYTES EblT .001 HYSICAL RECORD LENGTH: ILE NAME: OMMENTS ATLANTIC B-2 ~UPARI~ 10~ 1 1N 9 NURTft SI, OPE ALASKA 800. RICHFIELD C 1024 B~TES D~TA P(]R~IAT SPECIFICATION LENG~I~I~: 250 ~YTES ENTRY BLOCKS: TYPE 0 SIZ~ 1 CODE ENTSY 0 DATUIVi ~$PECI~, ICBTI~]N Bb[!Cl<8 ~ NAME I[IOL AP1 AP1 AP1 API FIL?] SIZE SAM RhP B6OCESS INDICATORS 1 DEPT 2. SP DIL 3 ILD D!L 4 IL~,~ DIL 5 SFLU DIL 6 GR [0IL DATA RECORDS Nt.INBLI~ f]~, RECORDS: 252 J~E~G'I'h FJF' ~ECORDS: 1014 BYTES hENGTB ~F LAST REC£]t<D: 222 BY%ES FII~E T?AILER LENGTB: 62 BYTES FILE NAtZE: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~iLE NA~iE: 1024 BYTES FILE FIE,ADER hENGTB: 62 B~TES FILE h,~ME: EDIT .002 .M~XIMU~I PB~81C.~L REC[IRD LEr~GTH: 1024 BYTES PREVIOUS FILE F I.L~ C[JMNENTS RUN TN(~ £)P THE DIL - NO SP OR SF'L DUE TI.] [)Ib B~SE MOD. 6300.000 6200.000 6100.000 6000.000 5900. 000 5800. 000 5700.000 5600. 000 5500. 000 5400 . 000 51t00.000 5200.000 51,00.000 5000.000 4900. 000 4800. 000 4'700. 000 4600.000 4.500.000 SP GR SP GR SP SP 8P SP GR SP GR SP GR SP GR SP GR SP GR SP SP GR SP GR VALUE -30.109 g0.750 -30.109 90.750 -30.109 90. 750 -30.109 90.750 -30.10q 90. '750 -30.109 90.750 -30.1,09 90. '750 -'30.109 90. 750 -'30.109 90.750 - 30. 109 90.750 -30.109 90.750 -30.109 90.750 -30.109 90. 750 -30.10q 9O. '750 -30.109 90.750 ,-30.1(]9 90.750 -30.109 90. '750 - 30..109 90.750 -30.109 90.75(1 MN[ ~ MON IC ILD 1LD ILD ILD ILD ILD I. L D i I L 1) I 1.., D ILD I LD I LD 1LD II~D I. L D ILD ILD 7.051 7.051 7.051 7.051 7.051 7.051 7.051 7.051 7.051 7.051 7. O51 7.051 7.051 7.O51 7.051 7.05! 7 .n5:l 7 .O51 7.051 VALUE 8.172 8.17~ 8.172 8.172 8. :172 8.172 8.!72 8.112 8.172 8.1 72 8.172 8.1'72 8.172 8.172 8.172 8.172 8.172 8.11'2 8.1.72 MNEMON l C SFLU SFLU SFLU SFLU SFLU SFbU SFLU SFLU SFLU SFLU S :F ,L U Si: LU SFLU SFLU S F" .LU SFLU SFLU SFLU SFLU VALUE 7.6:13 7 .~33 7 .~33 7.633 7.6"~3 7. 633 7.033 7.633 7 .~33 7.633 7.63] 7.633 7.633 '7 .e3 3 7 .~.33 '7.633 7 .b33 7 .b3 J DEPTH 4400,000 4300.000 4200. 000 4100.000 4000.000 3000.000 3800.000 ]700. 000 13600.000 3500.000 3400. O00 30O. 000 3200. 000 3100.000 3O00.OO0 2000.0O0 2885.000 ~q N VALUE -]0.109 90.750 -]0.109 90.750 -30.109 90.750 -30.109 90.750 -21.20~ 9(3. 750 -,30. 859 54.938 -34.406 38.969 -.27. 875 64..188 -27.859 44.750 -24.64,1 45.62,5 -23.891 51.094 -21,359 50.5'31. -15.859 ,t8.188 -9.609 32,063 -1,4.578 43.~69 36.844 39.531 -999. 250 -999,250 HNE, HON lC 1LD I L.O I LD Ibg I LD 1LD 1LD 1LD :I L D iLD I L D I LD 1 L D ]LEI ,I LD V AL 7.051 7.051 7.051 7.051 7.258 7.65~ 20.891 1.2.508 9.5~3 1,0.547 11.086 I ~.~I1 o.016 ILO .66,4 11.391 2?. 56,3 -999.250 VAbUE 8.172 8.172 8.172 8.1.12 6.902 7.656 19.156 12.266 8.984 9.992 11.003 13.477 @.711 9.828 10.555 2000.000 -999.250 V A L, U [i.,,; 7.633 7.633 7.633 7 .b33 7.518 7. 941 26.891 11..398 8,711 9,99~, 1~.922 12.828 8.789 12.242 11.461 O.179 -999,250 DE, P.TH 8160.000 8100.O00 8000.000 7900.000 7800.000 7700.000 7600.000 7500.000 74O0. 000 7 '~0o. 000 7200.O00 71 o°. 000 7000.000 6900.000 6800.000 6700.000 66:00.000 6500.000 6400.000 G? SP GR G~ $1> GR SP GR SP GR SP GR SP GR SP $? SP GR SP VAL -30 90 -30 90 -30 90 -30 90 -30 90 - 30 90 -30 90 ' 30 90 -30 90 ' 30 90 -30 90 -] 0 90 '-30 90 -313 90 -30. 90. - 30. 90 . 30 . 90. -30. 90. -30 . 90. UE .109 .750 .10g .750 .109 .750 .109 .750 .109 .750 .109 .750 .i09 .750 .109 .750 .109 .750 .109 .750 .109 .750 .109 .750 .109 .750 .10q . '750 10q 750 109 750 109 750 109 75 () 109 75O a N E: M O iq I C I LD ILD 1LD 1LD 1 LD ILD ILD 1, LD ILD I LD I L D I LD I L D I L D I h [) I,LD ,I L [) I L 13 I b D V AL'{JE 7.051 7.051 7.051 7.O51 7.O51 7.O5.1. 7.051 7.051. 7. 051 '7.051 7.051 7. 051 7 .O51 7.051 7.051 7.051 7.051 7.051 7.051 MN }~Nf]N ]lC ILM I L M i LM 1 i LN I, LM i, L ~1 iLM VALUE 8.172 8.172 8.172 8.172 8.172 8.172 8.172 8.1,72 8.17 2 8.172 1'72 8.172 8.172 8.172 8.1 '72 8.172 8. 172 8.1'72 8.1'72 ~NEMUNiC SF'LU SFLO S FLU SFLU SFLU $ F L U SFLU SF'LU SFLU SFLU SFLU SFLU S F L U SFLU SFLU S F L U S F' L U SFLU VALUE 7.633 'l .633 7.633 7.633 7.633 7. 633 7. 633 "7.6 3.3 '7.633 7.633 7.633 7.633 7.633 7.633 7.633 7.633 7.633 7.6 33 LENGTh: 690 BYTES ~ (.)PMAT 8PEC1F ICAT!IJN 0 SIZE ! REP C O DE ENTR~ 0 OATtJN SPECIFICAII[)N gLOCI<$: N~M£ TOOL 1 DEPT 2 ILD DIL ) [I.,M DIL 4 GR DIL 5 D'r OIL 6 SGR CNI, 7 CALl CNL 8 DRHO CNL 9 NPHI CNL 10 RH[IB CNL 1 1 NRAT CNL 12 NCN[, CNL 1.] FCNL CNL 14 GRST 15 THOR 17 PtlTA UNIT AP1 AP1 AP1 AP1 FILE, SIZE 8At,'l REP PBi)CESS INDICATORS FT 0 0 0 0 0 4 OHNM 7 12 44 0 0 4 G h P I 7 31 32 0 0 4 US/F 7 52 .!t2 0 0 4 GAPi 42 31 32 0 0 4 Ii~ 42 28 1, 0 0 4 G/C3 42 44 0 0 0 4 PU 42 68 3 0 0 4 G/C] 42 35 1 0 0 4 C/C 42 42 1 0 0 4 CPS 42 ]4 92 0 0 4 CPS 42 34 93 0 0 4 GAPI 0 0 0 0 0 4 [.' P I~ 0 0 0 0 O 4 P P H 0 0 0 0 0 q PCT 0 0 0 0 0 4 USE, lq DEFINED OUTPUT ARRAY OUTPtIT I.LD AT 2 O U T P ti T '[ L M A %' 3 OUTPUT Gle AI 4 OUTPIIT DT A~[ 5 O[,ITP UT SGR AT 6 OUTPtlT C.ALI AT 7 OUTPUT DR}t{] AT 8 OUTP[IT .NPHI A'T 9 OUTPUT RHOB AT 10 OUTPilT NRAT .g~ 11 OUTPUT NCNL Al 12 OUTPUT FCNL AT 13 O~TPI1T GEST AT 14 OUTPUT TH(]~ AT 15 OUTPiIT I]RAN AT 16 OUTPUT POTA AT 17 1 68 1 1 68 1 68 I 08 t 08 I 68 1 68 1 68 1 08 1. 68 I 68 ~ 68 1 68 1 68 1L t~8 81 bO. 000 8!00.000 8000.000 7900.000 7800.000 '7700.000 7600.000 7500.000 7400.0O0 7300.000 7200,000 MNE~iJN1C ILD SGR GRST II,D GRST I LD SGR RHOB GRST I LD SGR GRST I L D SGR RHOB GRST ,I, l, D GRST I I,,, D SGR RHOB Gl~$'r I LO SGR RHOB GRST iLD R H 0 B GRST I L O E H []B GRST i L D SGR R H [3 B V A L U E 2.926 77.9]8 2.070 77.063 2.027 100.065 2.479 72.250 2.572 112.375 2.47] 89.06J .4.742 88.688 2.4]2 72.250 4.121, 83.688 2..406 71.000 5.1 ]7 84 ' 4,]8 2,379 6 3,375 9. 250 64.000 2.441 4'7. 000 37.156 ]6.,406 2.205 40.625 1.391 120.125 2.3,36 88.563 2.094 106.563 2.512 85.625 2.188 :1,26.000 2.471 70.000 M N E H [) N I C IbM CALI NEAT THOR i L.M CALI N R A T THOR CALl NRAT TH(~R ,I LM CAb I NEAT T H O R I b M CALl NRAT T H 0 ~ CAbI NEAT THOR CALI NEAT THOR IbM C A L I NE,AT T H (] R I C AL I NE,AT T'It O,R ILM CALl NEAT THOR CALI NRAT T H O R VA LI'IE 3.150 5.945 3.475 8.500 2.824 8.742 ~.049 1.156 2.729 8.914 3.5OO 2.016 4.793 9.031 2.9]0 10.511 4.266 8,961 2.922 10.914 5.203 9.070 3. 029 9.:!t13 8.547 9.602 2.838 7.602 41 .7lq ~."l 1, 1 2.8"79 b. 480 1.434 9.461 3.717 1 3.4.38 2.2~8 9.484 3.604 11.930 2.26,4 9.422 IO.680 MN GR DRHO NCNL GR DRHO NCNL URAN GR DRHU NC.Nb U R A iq GR D R H 0 NCNL U R A N GR D R R 0 N C N L U R A N GR D R It u NCNb LJRAN GR L) R H U NCNb [,JRAN GR DRH 0 NCNb URAN GR D R H 0 NCNb ORA l~ GR D R Ft 0 N C N L U R Arq G R DRHO NC.N b U R A N VALUE 89.]75 -0.138 1067.000 0.106 95.3'75 0.01~, 2320.000 3.605 87.750 -0.006 1813.000 2.039 81.000 0.001 2332.000 1.807 80.188 -0.006 2312.000 1.84,4 ~0.375 0.00'7 2380.000 2.500 58.06.3 -0.027 2716.000 3.027 .35.000 -0.006 2856.000 -0.045 1.0q.025 -0.004 1708.00.0 3.9~5 86.375 -0.0013 1.858.000 2.6.1q 126.563 -O. 059 21.90.000 6.24.6 .gNEMONIC D T NPHIL FCNL POTA D'I' NPHI F'CNL POTA DT NPH 1 FCNL POTA DT NPHI FCNL POTA DT NPH,i FCNL POTA NPHI FCNL POTA DT NPHI FC Nb POTA DT N P H l FC NL POTA DT NPH I. .I.." C N ,L, P O I' A DT NPH i FCNL P [.I T A D'I' NPHi FCNL POT A VAi', 94 284 0 94 35 690 0 101. 42. 475. O. 93. 32. 765. O. 93. 32. 751. O. 93. 34. 728. 0. 1.07. 30. 875. O. 110. 31. 929. (). 1:13. 45. 433. 0. 19. 14,3. 458. O. 115. ,48. 49t. O. UE .0 .0 .0 .0 .5 .0 .0 .0 O0 94 O0 29 63 10 00 21 O0 71 50 27 50 78 00 20 88 78 00 2O 80 O0 1,7 88 27 O0 1'2 75 36 00 09 63 47 50 2'7 '75 96 00 24, 3 '75 975 000 021 7100.000 70O0. 000 6900. 000 6800.000 6700.000 6600,000 6500.000 b 40 0.0 C) 0 6 ,'300.00 () 6200.000 61 O0. O00 ~q N E M 0 N I C I LD SGR R H I) B GRST ILD 5GI~ RHI. JB GRST I L D SGR RI40B GRST iLD SGR GRST IL[) SGR RIIOB GRST 1 P a 0 B GRST I L D SGH G RS T i I., D SGR RHI]B G R S T i LO SGR R H fi B GRST I L SGR GRST ILD SC, lq RHOB GE S T VAL. U . -999. -999. -999. · -999. -999. -999. . -999. -999. -999. · -999. -999. -999. · -999. -999. -999. . -999. -999. -999. 6 '~, 5 250 250 250 451 250 250 250 018 250 250 250 lg4 250 250 250 131, 250 250 250 713 250 250 250 2.514 -999.250 -999.250 -999.250 1 -999 -999 -999 8 -999 -999 -999 1 -999 -999 -999 2 -999 -999 -999 .858 .250 ·250 .250 .38 '~ .250 .250 .250 .991 .250 .250 .250 · 438 .250 .250 .250 1'"t N E M 0 N ii C CALl NRAT THOR IL~ CALI NRAT THOR CAb I NRAT THOR I. i.~H CALl NRAT THOR CALI NRA T .TH 0 R I L M C AL I N R A T THOR 1 L M CALl NRAT THi. JR 1 L M CAb I: N R A T THOR I CAI., I NRAT T H O R I ]LM CALl NRAT T H 0 R CAbI NRAT T H [} R V a, L, (l E 1·709 -999.250 -999.250 -999.250 2.4'~4 -999.250 -999.250 -999.250 2.941 -909.25o -999.250 -999.250 2.1.74 -999.250 -999.250 -999.250 1.390 -999.250 -999.250 -999.250 2·748 -999.250 -999 250 -999]250 2.543 -999.250 -999.250 -999.250 2 11,7 -999 .' 250 :999 250 999 7.496 -999.250 -999.250 -999.250 2 !48 -9991250 -999.250 -999.250 2.445 -999.250 -999.250 -999.250 Mi~ LMU N lC GR DRHU NCNL [.1RAN GR DRHtJ lq C N L URA N GR D,R H 0 NCNL [iRAN GR NCNb ORAN GR I)RHO NCNb ORAN GR DRHO ~ C N L UR AN GR D R H 0 NCNL ORAN GR NC NL URAN GR D R H 0 N C N L U R A N GR DRHO 11 C N L URAN GR D R H tJ NCNb URAN V A L [) E MlqEMON lC VALUE 316.250 DT 113.'750 -999.250 NPHI -99925.000 -999.250 FCNL -999.250 -999.250 POTA -999.250 158.500 -999.250 -999.250 -999.250 10'7.563 -999.250 -999.250 -999.250 10].750 -999.250 -999.250 -999.250 DT 118.3'75 NPHI -99925.000 F'CNL -999.250 POTA -999.250 DT 104.000 i~PHI -99925.000 FCNL -999.250 POTA -999.250 DT 110,750 NPHI -99925,000 FCNL -999,250 POTA -999.250 112.500 DT 116.]75 -999.250 NPHI -99925.000 -999.250 FCNL I999.250 -999.250 POTA -999.250 118,625 -999.250 -999.250 -999.250 123.250 -999 ~50 999: 50 -999.25() I 57 00o -999:250 -999.250 -999.250 DT 112.000 NPHI -99925.000 FCN.L -999.250 P[.)TA -999.250 DT 1,3,3.750 NPHI. -9992b.000 FCNL -999.250 PO'T~ -999.250 DT 9~.563 NPEI -99925.000 FCNb -999.250 POTA -999.250 '77.625 DT 79.1.88 -999.250 'NPHJ -99925.000 -999.250 FCNb -999.250 -999.250 POTA -999.250 1.07.750 DT 103.3'15 -999.250 NPH1 -999'25.000 -999.250 FCNL -999.250 -9qg.250 PO'lA, -999.250 1,40.125 O'£ 109.375 -999.250 NPHI -99925.000 -999.250 FCNL -999.250 -999.250 PUTA -999.250 DEFTH 6000. 000 5900.000 5800.000 5700. 000 5600. 000 5500.000 5400.00O 5300o000 5200.000 '5100.000 5000.000 MNEMONIC 1 LD SGR GRST i LD S GR GRST ILD SGP GRST ILD RHOB GRST ILD SGR RHOB GRST ILD R H 0 B GRST I L D SGR GF ST i LD SGR 1~ H fi B 1 LD SGR RH[JB GRST I LO SGR GIaST I L D }{HOB G R S 'T VALUE 2.164 -999.250 -999.250 -999.250 2.391 -999.250 -999.250 -999.250 2.713 -999.250 -999.250 -999.250 1.987 -999.250 -999.250 -999.250 2.281 -999.250 -999.250 -999.250 2.221 -999.250 -999.'250 -999.250 2.617 -999.25(') -999. 250 -999. 250 3.~05 -999.250 -999.250 -999.250 4.016 -999.250 -999.250 -999.250 5.762 -999.250 -999.250 -999.250 2.459 ,i5.688 2.287 28.656 MN kMUN lC iLS CALl NRAT THOR CALl NRAT I LM CA/, i NRAT THOR IbM CALl NRAT THOR I L M CALI 'NRAT THOR 1 L ~ CALI NRAT T H 0 R I L~ CALk N R A T THOR l LM C AL I NRAT THOR IbM C A L l N R A T 1 MOlq IL~ CAI',I NRAT T H 0 R IbM C AL I NRAT T H [] R VAL 2 -999 -999 -999 2 -999 -999 -999 2 -999 -999 -999 1 -999 -999 - 99 '9 2 -999 -999 -999 2 -999 -999 -999 2 -999 -999 -999 -999 -999 -999 3 -999 -999 -999 -999 -999 - 999 .172 .250 .250 .250 '.~65 250 .250 .250 .662 .250 .250 .250 .967 .250 .250 .250 .260 .250 .250 .250 .174 '250 .250 .250 .555 .250 .250 .25O .486 .250 .250 .25O .R57 .25O 5:0 . 25 O . :250 250 .250 . :346 .844 .484 .909 MNEMONiC GR DRHO NCNb URAN GR DRHO NCNL ORAN GR DRHO NCNL GR DRHO NCNL U IR A N GR ,D R H rd NCNL U R ,A N GR D R H 0 i~ C ,N b U R A N GR D R H 0 NCNb URAN GR DRHO NC URAN GR DRHO NCNL URAN GR D R H (J N C N L URAN GR, D R H U NCNL URAN VALUE 97.500 -999.250 -999.250 -999.250 90.813 -999.250 -999.250 -999.250 70.563 -999.250 -999.250 -999.250 86.563 -999.250 -999.250 -999.250 ~NLMUNiC VALUE, PT 1.07 NPHi -99925 f'CNL -999 PUTA -999 .000 .250 .250 DT 105.000 NPH1 -99925.000 FCNL -999.250 POTA -999.250 OT 99.000 NPH1 -99925.000 FCNL -999.250 POTA -999.250 DT 1.07.563 NPHI -99925.000 FCNL -999.250 POTA -999.250 95.088 DT 109.188 -999.250 :NPHI -99925.000 '999.250 FCNL -999.250 -999.250 P[JTA -999.250 88.56,3 -999.:250 -999.250 -999.250 95.5O0 -999.250 -999.250 -999.250 82.813 -999.250 -999.250 -999.250 80.188 -999.250 -999.250 -999.250 ]0.181 -999.250 -999.250 -999.250 DT 109.375 NPHI, -99925.000 FCHL -999.250 PE)TA -999.250 OT 1 O6.750 NPHi -99925.000 i;'CNL -999.250 POTA -999. 250 DT 102.188 NPHi -99925.000 F'CNL -999.250 POTA -999.250 DT 102.750 NPH1 -99925.000 FCNL -999.250 POTA -999.250 DT 77.3'75 NPH] -99925.000 FCNb -999.250 PUTA -999.250 DT :l 23. l 88 NPI~t I 41,. 21 1 FCNL 11 I .0~o3 POTA 0.01, 7 69.688 -0.003 4'1,8.250 2.127 I)EPTH 4900,000 4800,000 4700.000 4600.000 4500.000 44O0.000 ~,300.000 4200 . o 0 () 41 O0. 000 tO00, 3900.000 M N E M II N I C I LD SGR RH(JB i L D SGR RHt]B (;?ST I L D R HOB GRST I LD SGR RHf}B G R S '1' I LD SGR GRST ILD SGR GRST ILD S G R RHOB GRST i L D G R S T lid S GR ,H H O b GR ST I. L D SGR RH(iB G}~ST I LD SGR RHOB GRST VALUE 3.184 115.000 2.301 ql .375 4.920 98.313 2.295 69.750 3..410 97.375 2. 232 73.3'75 3.88 3 89.063 2.246 63.875 3.965 76.000 2.223 61.313 3.902 78.563 2.234 58.375 7.609. '73.31 3 2.170 66.31] 10.664 60. 406 2.1 8O 51. q69 7.56.3 60. 625 2.168 42.844 6.629 81.750 2.309 56.844 7.1.84 65.81 3 2.234 53.40 O ~ N E M O N I c CALl NRAT THOR [LU CALl bRAT THOR CALl NRAT THOR I bM CALl N R A T THO¢ IBM CALl N tq AT 'I Hi,IR CALl NRAT THOR ILM CALI NHAT I3 H [) R I LM CAL I. N R A T 1LM CALl NRAT T H [) R I iJ M C A L I N R A T T H (] R I L M CALl N'RAT THOR V A 3.078 0.719 3.469 0.092 5.051 9.656 3.457 7.496 3.182 9.922 ~.445 9.414 ~.699 9.805 3.385 8.242 3. 965 9.797 3. 629 8.394 3 b76 9:203 3. 576 8.648 6.805 8.484 3.611 8.555 9.7.34 q. 000 ..~. 330 6.2.3:1 7.]98 q. 125 ~.570 6.164 ~. ] ]2 2.023 3. 473 6.281, 7. 223 9.8"t6 3. 455 6.520 M,N ,E M I] N I C GH D,RHO NCNL UHAN GR DRHO NCNL U R A ,N GR DRHu NCN& URAN GR DRHO N C N L URAN GR 13RHO NCNL tJRAN GR DRHO NCNb URAN GR D R H u NCNb GR DRHO NCNL IIRAN GR O R FI U N C N L UR AFl GR D~{HO NCNb URAN GR NCNL URAIq 'VALUE' 92.5 0.0 1938.0 3.0 87,0 -0.0 1980.0 3.1 88.8 -0.0 1950.0 2.1 77.5 -0.0 2()62.0 3,3 65.5 -0.0 2025.0 1.7 64.6 -0.0 2012.0 2.7 63.8 0.0 1986.0 0.8 59. ,1 -0.0 2176.0 1..0 63.4 -0.0 203~,.0 2.2 76.8 0.0 1880.0 3.3 57.1 -0.0 20443.0 1.5 63 Ol O0 45 O0 0l 00 19 13 11 00 93 03 10 O0 24 6 3 O5 O0 77 88 04 00 34 75 l~t O0 7,8 25 04 O0 48 06 07 O0 21 13 08 O0 32 25 06 O0 47 MNEM[.INIC DT NPHI FCNb POTA DT NPHI PCNL POTA DT NPH1 t~CNL P 0 T A NPHI FC N L POTA, DT NPHi FC NL PUTA DT NPHI ~'CN,6 POTA D'f NPHI FCN6 POTA DT N P H .I FC N,L POTA DT NPH 1 FCNL POTA OT NPHi F C NL P [,'I T A DT NPHI FCN6 P 0 T A VA 11 4 49 11 4 52 11 4 53 11 3 58 11 4 49 I1 4 51 12 4 50 10 1,2 54 12 3 48 12 4 54 LUE 5.000 1.113 7.500 0.033 2.188 1.016 6.500 0.029 4.750 0.381 1.500 0.023 6.000 9.502 5.500 0.020 9.000 3.896 8.000 0.019 0.188 3.799 3.000 0.019 '1,.188 5.508 0.750 0.021 4,000 9,6.48 1,500 0.018 1.375 3.848 6.000 0.013 5.000 9.111 5.50O 0.021 0.188 0.723 2.500 0.017 D E F ,r H 3aoo.ooo 3 ? 00.000 ]600.000 13500. 000 3900.000 ,3300 . 0 0 0 .] 200 . 000 3!00.000 3000 . 000 2900.000 2885.000 ~ N E ]~ [1N lC 1 L D SGR GRST I hD SGR GRST SGR RHOB GRST II,D SGR R H 0 B iI.,D SGR RHC]B GRST I L 13 R H 0 B GBST I LD G R S T ILl) SGR RnOB GRST I L D GRST I L D SGR ,IR, H () ~ GRST I I,,D 8GR P, H 0 B GPST VALUE 1.5.844 46,969 2.168 45.906 11.688 59.156 2,090 5,4,906 8.750 51.500 2.051 33.750 9.727 50.156 2.066 37.125 1,0.281 59.094 2.221 48.438 1,2.547 52. 500 2.219 30.98,4 8.125 57.781 2.094. 51.1,88 10.016 39.594 1.686 35.8,44 10.,36'7 55.375 2.057 46.489 -,999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 i La CALl N k A T ILM CALl NRAT IL~ CALl NRAT THOR II,,~ CALl NRAT THOR ILM CAI, I NRAT TB(.IR I L M CALI N R A T T H O R CALl NRAT THOR CALl NRAT THOR IbM CALl N R A T THf]R ILM C AL i NRAT C A L 1 NRAT V A I~ t.I .E 15.859 9.508 3.158 6,203 11.781 8.992 3.576 6.840 8.438 q .000 3.650 4. 500 9.477 8.875 3.590 5.902 11.4.38 8.909 2.998 6. 609 1.2 8:97'1 4.938 7.938 9.281 3.609 '7..367 9.703 10.281 5.121 ,l. 605 1,0.109 q 4'7'7 ]:541 5. 105 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNLtqON 1C GR NCNL [IRAN GR DRHU NCNL GI~ DP, HU NCNL ORAN GR DRHO NCNL URAN GR DRHO NCNL URAN D RHO NC NL ORAN GR DP, HU NCNL URA N GR I'}RH 0 NCN L URAN GR ORHU NCNL [J R A N GR DRHO N C N L GR DRHO NCNL (JRAN VALUE 45.188 -0.013 2052.000 0.195 59.188 -0.006 2244.000 0.812 49.563 -0.015 2134.000 2.057 44.594 -0.012 2106.000 0.75,1 54.375 0.005 2128.000 1.3'74 55.3'75 -0.004 25i2.000 2.688 55.625 -0.0O3 2192.000 0.891. 35.813 -0.036 1362.000 2.250 58.656 -0.009 2050.000 1.365 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.25O MNEMUN lC NPHi FC NL POTA bT NPHI FCNL POTA DT NPHI FCNL POT,A DT N P H I FC Nb POT A DT N P H I F'C NL POTA DT NPflI F C N L D T NPHI ~CNL P fi T A DT NPHI ECNL POTA D T NPH.i FCNL POTA DT NPHI FC N L P 0 T A DT NPHI FCNL POTA VALUE 125.168 35.840 599.500 0.01.4 129.125 44.141 57'/.500 0.018 140.000 45.459 557.0OO 0.013 135.750 44.531 540.500 0.01.0 105.000 33.7,40 614.500 0.01,5 1,1.3,563 40.52"1 694.500 0.007 137.750 44.287 584.000 0.015 153.1,25 '70.068 244,875 0.014 138,375 42.822 554.000 0.018 -999.250 -99925.000 -999,250 -999.250 -.999.250 -99925.000 -999,250 -999,250 S[IM(qA}~Y OF DATA Rk:CORDS NUMBkF: (]F RECOPDS: 754 I.,E.NG1H [.)F ~EC.ORDS: 958 BYTES LENGTB OF LAST RECORD: 618 B~IES F'ILL 'IRA1LER LENGIH: 62 SITES FILE NAME: EDIT .002 ~"IAXIMUM PHYSICAL REC~.~RD LENGTH: NEXT FiLE NAME: , , F OF TAPE TRAILEP ],ENGT}]: 112 BYTES 'rAPE NAME: 61350 SERVICE NANE: EDIT TAPE CONTIN'UATION NU~qBER: O1 NEXT TAPE NA~IE: C(']MMLNTS: 102.~ BYTES DATE: 81. i ~,1 31 -I ** 'I'A PE ORIGi~ :OEO0 COS TI f.;UAT LL;r,~ PREV IOtaS TAPE FILE DATE : SAXI~,'Uk~ [,,E:f,,GTH : 1024 PREY 1 C N RAN(.;: T [! ;',~ ~.~: SECT: C~3UN: STAT: CTRY: PRES: D I L 0 01 F OhO 000 01.8 00o 000 00,3 065 o0o 000 007 06,5 0 0 0 00 0 O 4 0 65 ~00 000 (}04 065 00 000 o O 2 065 q 00 O0 ~,, 0 00. 065 0(~0 GO0 002 065 (:~ 0 0 0 O0 0 0 4 b N I T 7 1 P :fi; C A T ff S I F, E C 0 D E ~ ~Jl ~l I~ ii ~ ~ ~1 ~ III 00(~ 000 O07 065 PACiFiC COAST !~gLL, : 6-2 S T A T f : h ~ SECTIO~ = 9 BAS~ hD(;: Dib , R~N ~ 2 BlT SIZ~ ; ~.7b I~. TYPE ~'~,5h~ FL~ID ; OIL bASE DEf~&ITY = 10.50 VISCOSITY = 53. O0 ~-bU ID b E)S :~ = 2.40 LOG BlT SIZE DE~g%ITY ¥I&COSITY FLUID Lt.~S~5 F? o LVP PAGE 1.o5 La 76 F 139 F ENTRY D A T Li ~,,'~ SPECIF'ICATI(] ~ gL()CK6 SEP~V lcd; L~ER~ 1 CE UmlT DEPT S F L LI 0 i L, ILD SP 0 G~' DiL Fl' GAPi AP1 AP1 APl AP1 FiLE bOG TYPE CLASS t~'[(".~F ;~(3. 0 0 0 0 u '7 0 0 0 0 7 0 u 0 0 7 ~ 2 46 0 0 7 1 0 ~ 0 7 31 32 0 0 i 6O 0 4 4 4 PROCESS LEVEL 0 0 0 1 1 1 I 1 REPR CODE 6~ ** DATA DEPT SP DEPT DEFT SP D E P SP DEPT -30. 8100. -30. -30. 7900, ...30. 78 '0. - 30. - 30. $~'L o G R SFL d SFLU G R S F L U GR GR SFL U GR 7.6328 q0. 7500 90.75";0 7.(~328 ]'.L 90. 7500 7.63~s 90. 7500 7. ~328 90.75o0 ~0.7500 8.1719 8,1'119 I L B i L D 7,0508 7,05O8 7.0508 7. 0508 7.050~ 7,050~ DEPT DEFT SP SP SP SP DEPT SP SP SP DEPT SP D E P T SP DEPT SP S? DEPT DEFT SP DEPT SP DEPT SP SP 760(). 0u 00 - 30.1094 7500.0o00 -30. 1094 7400.00r, 0 -30.1 'O94 7300. -30. 72 u 0.0 u 00 7100.60cio -30.1094 7000.0000 -jo. 1 O94 - 30. I u 94 ,-30.1v9,~4 -30. -30.10q4 ~500. 0000 c~ 4 00. V 0 ';) 0 -30..1. U94 30 (~. 0 0 0 u -30.3~ i)q~ -.30, i 0 q <4 -30.109& o(}00. Ou~? u 7. b'32~ 0.75o0 0.750u 7. 0. 7500 7.6328 (). 75 ~'30 7 90 7 90 7 9O 7 90 7 q 0 7 90 7 90 .632~ .750 (ii .75') 0 .632S .750o . 7500 .~32~ .75q0 .6328 .7500 7.6328 90.75'~0 7 , 6328 90.750 O 7.6 3 ? ~.~ 90 · 7 5': 0 7. 632~,~ g0. 750(', 7.6322 90.7500 7.632~ 90,7500 7.63'28 90.750 0 I L I L., P ILlq f b 1: L 'q b. 1';'19 8.1719 8.1719 8.17!9 H.1719 8.1719 8.171,9 i [: 0 i LD I LD i L D I LD I L D ][ b r~ I L 0 7. 050~{ '7. O5O8 7.0508 7.050~ 7.050B 7.0508 7. O5O8 7.0508 7.0508 7.0508 7,0b08 7. 0508 7,0508 7.050~ 7,050~ DEPT ,5800. OOr)b SFLU SP -30. 1094 DEPT B7CO.{)OOO SFL, b SP -3(:,. lU94 DfPT b600. qi)t'O ~FLij SP -30.1 oq4 CR D E P 'f b 500.0 {.',~ () 0 S F L SP -30. lo94 DEPT 5400. 0000 SF SE -30. 1094 DEPT q,3o0.0,;~0 SFLU SP -30. 1094 GH DEPT b200. 0000 SFb S P - 3 0. i 0 0 4 G SP -30.1u94 GR DEPT 5000. OuOt~ SFLU SP -,50. I og4 GR DEPT 4900. ~Of~O SFI,U SP -30. 109,¢i DEPT 4200. O0'~u S P - 30.1 u c~ ,~ G R DEPT.' a70O. UnO0 SFI,U SP -30. 1~)94 D E P T 4660.00 (',, 0 8 F L U SP -30.'.tu9~ tlr DEPT qb00. o0r}0 SP '30. 1094 DEPT 4:4o0,0000 SP -30. 1094 DEPT 4,3o0. Ot/O0 SFLU SP -30.10q4 GR l, E,Pl 4200. < Otto SFLO SP '30,., 004 (;}~ DEPT 4100.0Cr. O SFLb 7 7 90 7 90 7 90 7 9O 7 9O 7 .6378 .750t~ . ~ 3 .?, (~ .75 '") 0 .75,30 .750(' .75 ,'"} 0 .75q0 .6328 .7500 7.6328 '80.75 r) 0 7.63~8 90.7500 90. '7500 7. 632s 90. 7500 7.63~¢ 90 · 7500 7.632~ 90.750u 7.e~32~ 9O, 7500 7,639, 8 90. 7500 7.6,328 90. 7500 7. (~328 90. 7.632 g I bF~ I [, M ILt~ 1 L M I L, 8.l't.1.9 ~.1719 8.171 9 8.1,719 ti. 1.719 8.17:19 f~. 17 19 8.1719 E.1,719 8.1719 8.1719 8.1719 9.1,719 8.1719 8.1"11 9 I L D I LC I LB ( L, r, ILl) 7 7.0508 7.0508 7.0508 7.0508 7.0508 7.0508 7.0508 7.0508 7. 0508 7. 0508 7.O50~ 7. 050~ 7.0508 7.050~ 7.0508 B EP"]: .:~t) 00,, 0000 8 P - '21.2 ~-, 3 l G R DEPT 3900. O,aet~ SP -30.6594 DEP~; ~800.00~)u 8F'LO SP -34.4o~,3 GR -27.8750 DEPT ..~ 600. (., O 00 5FLiJ SP -27. 859i DEPI ~5(;0. (.~ 0 SFbu DEPT 3~00. ~000 SF' D[J DEPT 3300.00{') 0 D~3PT 32o0. uO0~ BP -15.8594 GR DEPT 31 o0. O~no 8 SP -9. ~t>94 GR DK:PT 30uo. On0O SP - 14.57 g I gR DEP~ 2900.0oo0 SFLO S P 3 o. g, ~ 37 D E P T 28 ~ 5. (~ 0 (> 0 SP -999. 2500 GR 7.5781 90.75C0 54.93"/'0 26. 38.96<0.7 11.39~q bq.1875 ~!.7109 44.75 r) 0 9. 9922 45.025O 16.9219 S1.093~ 50.5313 4g.I~75 12.2472 32. 0625 I 1. 0.17q2 39.5313 -999. 2500 -999.25°0 SERVICE DATE : F I k E', q:YPE 6.9023 ILS 7.6563 :1.9. :1.562 i b 1.'-' 12.265b 8.98,4 <~ J 9.99 ~' 2 I 11. 0025 il)f: 1 3.4:7 6 6 .l ~, ~.7109 IL, F; IO.5b<~7 2000. 000o :ILD -999.2bO{.) 1LD 7,2675 7.0563 20.8906 12.5078 9.523~, 10.546g 13[.0859 13.2109 9.01.56 lO.6b~l, 1 I. 3906 27. 5625 -999.2500 FILE l,~ ~. !t [, :5&RvlC.O02 SERVICE {'~ A*,i E : DATE : MAXIN. UM t't,!.~C, iTb : ~024 FILE TYPE : PREVIOUS FILE[ : 0 00 0 0 0 {) 0 'i 065 3. ,1504 GR ~ 9 . 3 '7 5 0 ................................................ DT P 0 ~1 A DEPT NPHI FC~L POTA D E P T DT O E P T DT 2 ~4. OuO0 CGR 2. t~ t.~ 6 9 DEFT DT FCNb POTA DEP'£ DT NPHi FCNL POTA DT n P H i F C N L DEP1, DT NPMi FC N L POTg DgPT 77 . "~' '% 7 c 2.07 03 77.0625 2.~5270 100.66'>.5 2. a7%5 72.'~5n~.~.. , 2.5723 J..05,350~ 2,4260 89,i3625 4.7422 88.~75 2.4316 72.2500 83.6~75 2.40~3 71,00nO 5. :1.367 84.4375 .37~9 9. 2500 64.00'0 ~"] 2.44. 14 47, no0o 37.1562 6.4063 2.2051 25 (.) 3369 C.;~ l,I C,~LI I L, C A 1:, i ChbI CALl ~,~RAT CAb i CALl l DM CaLl THOR Ibr~ RAT 5,0453 3.4 '74 ~.~ 8.5060 2.8242 8.7 422 i1. 1562 2.72H5 3.500u i2.0150 4..793o 9.0313 2.9297 10.5313 8.960'~ 2,9219 10.9I~i 9:0'703 2.8379 7.6016 4t. 8.7.1. (' 9 2 6 . 8 I [4336 9 3 '7168 G R r,.~ C t~i L 'JR A a C ~ b G R NCNb GR aC i~i L m C }~ L GR i.j R A N -0.13~2 1067.~ooo o.lo64 95.3750 o.oi37 2320,0000 3.6t)55 87.7500 -0.0063 18i3.0000 2.6387 81,0000 0,0oi5 2352,0u00 1.8066 80,1875 -0'0059 2312,000~ 1.8437 0.0668 2380,0000 2.5 000 58.0625 -0. 027.3 271~.~00 . 73 35. o O, 00 O.Ou~ O 4..~i 9 104,b250 O, 00. ,~ i 708. 0000 3 ' 9453 86,3750 LVP NPMI FCNL POTA DEPT DT NPHi F£~lb POT~ DEPT DT NPHI FCNL POTA DFPT DT NPHI F C N L POTA DEp%~ mPHI FCNL DEPT F C N L POT A DEPT DT NPHI FCNL DT NPHI PUTA DEPT DT ?Ct~L POT~ 01t).H~.I2 ltERiF.1C~TIO~.! 1 i9. 3750 SGR <,58. 5000 CGR 2. 3926 % 13.750 (} S G ',~ -999.25(}0 RHO~J -999.2500 CGR -999. 250o 70UO. 0000 Ibi) 118.375 ~"~ $ G ~l -999,2bG0 RHOB -999.25~ CGR -999.2br)O 6900.UU,:O ILD - 999.2 b 00 R ~,i O t3 - 999.2 ~ n, o C (,; a -999,250C ]. ] O, 75rio ,~GR -999.2~00 RHOi~ -999. 2500 CGR -999,2500 6500.0ut,}O ILO 133.7500 ~400. uuOG [ L,C' I0~.$625 2.51'!7 85,6250 2,1875 ]26,0000 2,4707 1.634~{ -999.2500 -999.2500 2,45!2 -999. 2500 -999. 2500 -999.25Ofi 3,U17o -999.25'~n -999 · 2500 -999'~5i~0 - 999.250 - 999.25 ,:'; 0 1.1309 -999. 250C, -999 2500 · .999 ~ 2500 2,7129 ,,, 99 g. 2506 9 .) 9 () 0 -990.250~' 2,5:1.37 . c~ 99.25 -q99. 2500 -999 C,:af, l T' Hn.. R I L?4 C.~. i,I i; R A '? C:~LI CALl T~OR C A L ! ~,~: RAT ,NRAT ¢,.: A L I CALT C A L I a R A T il .9297 'bRA!.) 2.2~37 GP, 9.4219 DR~-i {} 3.8 ~09 i'4ChL 10.67f~7 t!k 47',} I ,7U9o GP -999. ~5('~(~ DRHO -999.25t)0 NCNL -999.25Cc ij R,A i',i 2,433~: GR -999.250Ci -999.2506 ivCNb -999.73¢i0 tI 1:;~ .~, t"..., 2.9414 GR -999.25e0 [)RFC' -999.2500 aC~b -99q.2500 tJR~! 2,173 ~{ -999. 2500 -999. 2566 1. 3896 GR -999. 2500 DR'HO -999.25Gu NCNb -999 o 25o0 (Jw ~? 2..~ 1'12 P A G E; 10 -0. 0029 $. 000 0 2.6.'19I :126.5625 2190.0000 6.2~61 316.2500 -999.2500 -999,2500 -999.2500 1~8.5000 -999.2500 ~999.2500 999.2500 107.5~25 -999.2500 -999,2500 999.2500 09.3.250 G -99 7500 -.999.25L~ 0 -999.~500 112 5000 -999.25('t0 -999 2500 -999:2~oc -999. 2500 -999.2~00 .....~9 2500 123 2500 - 999: 2500 -999. ~ 500 -~99..~s0o I 57. DT r~ P H I FCNL PO~'A D E P T DT FC}~L POTA EPT F C N b POTA DEFT DT ~ PHi FCi}; L DT NP~I FC~L POTA DEPT DT FCNL PDTA DEPT DT [~PNI DEP% DT NPHI FC:~ L POTA D£P% DT NPdI FC~L OEP'I~ -999. 250o 999 ~ - ':, . - 0 9 . 9, 5 0 -999,2500 -999.250(' 1.9912 -999.2500 -999.2500 -999.~500 2.4375 -999.25q{; ,-999. -999.25~]o -999.25¢?0 -999.250o -999.2506 2.39O6 -999.2500 -999.250V -999.2500 2.7129 -999.2500 -999.2500 -999.2500 5700.00©0 IbD -999.2hOt, RthOb -999.2,5<i0 CGR -9-3.9.2 1.9~'73 -999.25C[: -999,2500 -999. 2566 2.2~'1.3 -999.25;:10 -999. 2500 -999.2500 .55 (i o. 0 u ,':, () I L [) 2. 2267 C A L i (:.', A [, I · .~ T 14 O R I L C A L, 1 CALi RAT TH(OR CALl ibp CALl I L CALl ,. -999,250o -999.2'50o 7 , 4961 GR - 999.25:0 - 9:99,2500 i~C i5~ L -999. 2.3652 GR -999.250C PR'HO -999.2500 ~Ci~b -999.2500 I.~RA~I 2.6021 GR -999.2500 i)g. hO -999,250'd -999,25C 0 bRA ~.9o68 G~ -999.'250{; DRt'IC -999.2500 i~C!',lb - 999 -999 2,173o {;R -999.25t)0 -999 . 2500 -999,2500 -999: 2500 -g~9.2500 g69,2500 140.1250 -999.2500 -999,2500 -999,2500 97,~000 -999. 500 -999,250o -999.2500 90.8125 -999,2500 -999.2500 -999.2500 70.5625 -999.250C -999,2500 -999.2500 86.5625 -999.2500 -999.2500 -999.2500 95.~75 -999.2500 -999.2506 -q99.25C0 L v P DT NPHI FCNL PUTA DEPT" DT NPHI POTA DEPT FCNL DEPg: DT NPHi FC .~, L.,~ DEPT DT ~qPMI FCNL POTA DEP~I DT POTA Oiu.}!~,)2 vtb,[FICATI{.?N 109.37%0 SGR -999. 2660 RiCOh -999. 250(3 CGR -999.20(:0 b400oCO00 lO6.7b00 SGR -999.2500 -999.2506 -999,2b00 77.3750 -999,2bO~) -999. 250O .~000, OuO0 ILD ~i .2109 RHOE< DE P'l' 4900 6{'t00 ILD DT 1~5.'0I nO SGF~ FC~qL ~:97.5000 POTA 3. 3203 DEP? DT FCNL DEPT DT F C N L POTA DE~T 460 O, 0 ~* 00 I L, t' -c99.2500 -999°2500 -999.25~0 2.6172 -999.2500 -999.2500 -999.2500 3.6055 -999.2500 -999.25~!0 -999.25{')0 4.0156 -999.25{;6 -999.2500 -999.2500 5.70~7 -999.2500 -999.250v -999.25a0 2 , 459U 45,6~75 2. 2871 28.6563 98.3].25 2,2949 69.750{; 3,4102 97.375(.) 2,2324 73.37~0 3, ~E~28 IL~ CALI NRAT CALl ThOR I C,~ L I !,~RAT CALX T ~.{ Cl R C A L I NRAT CALl ~RAT THOR IL M CAb I I b b C A L I ;:~ R A T -999. 250C -999. 250O -9"~9.25c0 2.554? -999.25(.,{~ -999.2500 -999.2500 3.4863 -999.2500 -999.250O -999.2500 -999.2500 -999.2500 -999.250t~ ~.3~33 -999.25O0 -999,2bo0 -999.2500 2.3457 9.8437 3,484,4 0,9087' 3.0781 9,7,1~8 ~('t.9922 9.65~3 3.4570 7.4,9al 9.q21.9 3.4,~53 9.4141 3,6992 Gl{ C R '~ O UR A':~ GR i~ C ~ L G R GR S C '~"4 L GR DRF{O G R GR PAG~ 12 -999.2500 -999.2500 -999.2500 95.5u00 -999.2500 -999.2500 -999.2500 82.812~ -999.2500 -999,2500 -999.2500 -999.2500 ~99,2500 -'699.~500 36.7813 -999,2500 -999.2500 -999.2500 ~9.68"i5 -0.0029 2.1270 92,5625 0,00i5 193~, ~ 0449 .8~ 0006 t~ .0073 1986, 1950.0000 2.193a 77.5625 D E P ',[ .37 (..' 0, ,.> o ,:) (..; I L b 76.. 0000 6~ "'"' '~ .g2 .... 7 .31, 7 ~ 3.9023 7$.5625 2.2344 5s.3750 7.6016 73.3125 2.1699 66.3l~5 lO.ob41. 60. a r) 63 7.5625 60.62%0 2.1680 42.8437 6.62a9 56.~4q7 .,'::,, 5 . & 12~: 2.2344 53.40 ~ 3 '.8 i .37 46.9 .,5 r,~ 7 ~,? (t 62 I b i'4 CALl ~ RAT CALl fiRAT C a L I ]. [j PI CALl CA/'., i T 9 C'] R CALl 'I' ;i 0 P '[ b ,<' i 9.734.,~ <;it 59. 1250 9.nO00 O.hl4<.l -0 0044 3.3301 ,.,~u ,~ L 21'; .0000 ~, 234:/4 u ~z ,a ~,4 i ' o 479 9:1250 Oa),qO -0.00'73 3.5703 i~,C r~ L 2034.0000 6.16~l, Ot'{A i~i 2,2207 7.2227 GR 57 1250 9.3359 0~)40 -0:0059 ,3.4 5 5 1 ,:,; C r,,'; b 2 0 4, o. O 0 0 0 <',. 5195 :..i Il ,~ t',, 1.5469 1!.76!.'3 Gk 59.1.~75 LVP DT PO?A DEP~ ;~P~ FCNL DEPT NP~I FC~b DEPI DT NPHi FCNL POTA DEP'I' DT NPBI F C N L DEP? DT ~PHI FC~L DEP'f DT NPHI FCaL POT^ 0EP~t DT NPHI F C ~ L POT~ DEP% DT mP~]I FCNb 3500. C: iJ ~')u I b D I. 35. ? 5n0 SGR ~4.5~!3 540. 1. 0254 3qUO. i,,OOO 1 () 5. G C:, 0 i,j $ G R 33.'~q02 29t) 0 .. OuO0 - 999.2 ~ 00 -C~99 ' 5 -999. 2500 59.15~2 CALl 2 · 0957 54.9062 T g. 7500 51.5000 CA[.,i 9.726b ],b~! 2,0664 ~RAT 10.28,.,13 59 0938 '"' . , ~ALI 2,2207 NRAT 48.4 375 T 12.54 ~ 9 I 52. 5000 CALl 2.2187 3o.g844 10.015~ IL~ 39.5938 CAI,,I 1.~85b 35.6437 TH[IR -999,2~, UO ill' 9922 .5762 8.437b q. 0000 4,. 50 C)(,.~ 3,589b 5,9023 11,4375 E.96~:7 6.8094 12. $. 9'76 e;, 3.3730 4.°375 2813 3.609q 7.3672 9.7031 1 O. 2 a 13 5,J2ii 4 · 6055 GR D R ~'~ C (; R DR~C G R GR - 9 99.2 5 ti u <; ~ P'AG~ 1,4 -o.oce3 o.81:15 g9.5625 2134.0000 2.0566 44,5938 '0.0122 2106 0000 'o b4,3750 0.0054 2128 OOuO I 55.3750 25. ,. 0000 2.8~75 55. e250 -0.0 .... )a 2 ~ 92,0000 0.8911 35.8125 -O.0356 1362, Or JO0 2,256o 5~ 6563 - . 00 g ~ 2050, OgOO 1.3652 -999, - 999 . 2 5 (;: 0 -999, -999,2500 -999.2500 ~ C .~ h - 999.25 ~) O C G ~ '999 . ,\ FILE F'. A !,~ E ;$f~vIC.O02 SER¥ICE DATE : FiLE )?YPK ; NEXT FIbE -°9~ 2600 -999.2500 ~-999,2500
