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C W co �- Y � E w 7,, CC 0 O O O 0 0 0 0 0 0 0 +' 0 (0 ko O O O O O O O O O O O ra U Q CO N If) 7 N r 0 fC M N � 0 n') et In N- N- N- N CO N 4 O O = Q h M O O O M NNON E E = N N N N N N N N N N N N H L N O) CA M C) O O C7 0) M C) C) C 0 a O NNOONN NN ONN ro OU O Q1 0 0 0 0 0 0 0 0 L O U 0 0 0 0 0 0 0 0 0 0 0 f+ Y C O _ 000 C IA If) N If) If) In In U) N u) N a 'a O C co Lci;C37 F- Q) 10 •u C . U .L m E a) bA • a co W Y O W C Lh E E U u 'a �� ~ Ll Q1 .--1 4 Q O T N r C O O n 0 E a) 0) al Z a-. tm f1'1 z r M M N N v m = n n li O Y 2 W O N LL O N d Q O N ...I M N N M M N H Z W O O CD ro •�• .0 . .-1 C F ro E y E E O CI3 a LD Q F= a s F°- STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COM. ,SION JUN 1 9 L61:i REPORT OF SUNDRY WELL OPERATIONS ; �r:i. - 1.Operations Abandon r Rug Perforations J Fracture Stimulate r Pull Tubing p operations Shutdown r Performed Suspend r Perforate I— Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Fool r Repair Well rRe-enter Susp Well Other: r 2.Operator Name: 4.Well Class Before Work. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p. Exploratory r 185-271 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21481-00 7.Property Designation(Lease Number): 8 Well Name and Number. ADL 25643 KRU 3F-10 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 6650 feet Plugs(measured) none true vertical 6218 feet Junk(measured) none Effective Depth measured 6512 feet Packer(measured) 6031,6317 true vertical 6087 feet (true vertical) 5628, 5901 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 SURFACE 3065 9.625 3102 3042 PRODUCTION 6568 7 6603 6174 Perforation depth. Measured depth: 6202-6266,6384-6404, 6419-6452 r p True Vertical Depth: 5791-5852, 5965-5984, 5998-6030 SCANNED ,!i„'L I 20 1µ, Tubing(size,grade,MD,and ND) 3.5, L-80,6323 MD, 5907 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 47B2 FHL RETRIEVABLE PACKER @ 6031 MD and 5628 TVD PACKER-OTIS WD PACKER @ 6317 MD and 5901 TVD NO SSSV 12.Stimulation or cement squeeze summary. Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in - Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations F 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 Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt none Contact Theresa Lee ( ,263-4837 Email Theresa.M.Lee(a�conocophillips.com Printed Name Theresa Lee Title Wells Engineer Signature / „ / Phone:263-4837 Date / 1 I� I t-fi-/- 3/11/, ,0 RBDMS1 JUN 2 5 2015 Form 10-404 Revised 5/2015 Submit Original Only KUP PROD 3F-10 Conoco Phillips hillips A Well Attributes Max Angle&MD TD Alaska Inc Wellbore APt/UWI Field Name Wellbore Status ncl('( MD(ftKB) Act Btm(ftKB) 03rw Pops 500292148100 KUPARUK RIVER UNIT PROD 31.03 4,000.00 6,650.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3F-10,6/912015 11:10.25 AM SSSV:NONE 185 3/7/2014 Last WO: 5/13/2015 41.79 11/29/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _..__.. Last Tag:SLM 6,412.0 6/1/2015 Rev Reason:WORKOVER smsmith 6/8/2015 HANGER;35.0 1111 Casing Strings """'''p Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) . Wt/Len(I Grade Top Thread I CONDUCTOR 16 15.062 37.0 115.0 11B0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .,,.SURFACE 9 5/8 8.921 37.0 3,102.3 3,042.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(9103) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 6,602.8 6,173.5 26.00 J-55 BTC Tubing Strings CONDUCTOR;37.0-115.0"A - Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...Wt(Ibtft) Grade Top Connection TUBING-2015 WO- 31/2 2.992 35.0 6,323.0 5,906.6 9.30 L-80 EUE 8rd Mod 3 1/2"x 2 7/8"@6304 GAS LIFT;2,491.7 Completion Details Nominal ID Top(ftKB) Top(TVD)(fIKB) Top Incl("( Item Des Com (in) 35.0 35.0 0.05 HANGER FMC TUBING HANGER 2.992 6,001.8 5,599.3 16.98 LOCATOR BAKER GBH-22 LOCATOR SUB 2.990 6,002.6 5,600.2 16.98 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 6,008.2- 5,605.6' 16.98 PBR BAKER 80-40 PBR 4.000 SURFACE;37.0-3,102.3-a 4 6,031.3 5,627.7 16.97 PACKER BAKER 47B2 FHL RETRIEVABLE PACKER 2.992 6,195.8 5,785.1- 16.90 BLAST JTS PEST BLAST RING JOINT 2.992 GAS LIFT;3,786.46,290.6 5,875.7 17.20 SLEEVE BAKER CMU SLIDING SLEEVE W/2.813 BX PROFILE 2.813 6,304.8 5,889.2 17.24 XO(3-1/2"x 2- Crossover,3-1/2",9.3#,EUE 8rd Mod Box x 2-7/8',6.5#, 2.441 7/8") EUE 8rd Pin 6,316.4 5,900.3 17.28 LOCATOR OTIS LOCATOR SUB 2.992 GAS LIFT;4,803.7 ' 6,317.31 5,901.2 17.28 SEAL ASSY HALLIBURTON SEAL ASSEMBLY 2.992 Tubing Description !String Ma...l ID(in) I Top(ftKB) I Set Depth(ft../Set Depth(TVD)(...IWt(Ib/ft) 'Grade Top Connection TUBING-ORIGINAL 27/8 2.441 6,3173 6,34071 5,923.6 6.50 J-55 II EUE 8RD Completion Details 11,:::k,- GAS *'GAS LIFT;5,450.8Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 6,317.3 5,901.2 17.28 PACKER OTIS WD PACKER 4.000 6,320.7 5,904.4 17.29 SBE i OTIS SEAL BORE EXTENTION 4.000 6,332.5 5,915.7 17.32 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;5,944.2 6,340.0 5,922.9 17.34 SOS CAMCO SHEAR OUT SUB 2.441 Perforations&Slots Shot Dens Top(TVD) Bbn(TVD) (shatslf LOCATOR;6,001.6 Top(ftKB) Bim(ftKB) MILD) (ftKB) Zone Date t) Type Com -- 6,202.0 6,266.0 5,791.0 5,852.2 UNIT B,C-3, 1/19/1986 12.0 (PERF 5"Csg Gun;120 deg ph SEAL ASSY;6,002.6 C-4,3F-10 PBR;6,058.2 6,384.0 6,404.0 5,964.9 5,983.9 A-3,3F-10 2/18/1992 6.0 APERF 2 1/8"DynaStrip TT;0 PACKER;8,031.3 deg ph 6,419.0 6,452.0 5,998.2 6,029.7 A-2,3F-10 1/19/1986 6.0 IPERF 4"Csg Gun;90 deg ph Mandrel Inserts St a6 GAS LIFT;6,145.7 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com la 2,491.7 2,486.2 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.813 1,207.0 6/1/2015 I 2 3,786.5 3,631.5 CAMCO MMG 1 1/2 GAS LIFT OV " 0.250 0.0 6/1/2015 3 4,803.7 4,509.3 CAMCO MMG 1 ill GAS LIFT DMY RK 0.000 0.0 5/23/2015 4 5,450.9 5,085.0 CAMCO MMG 1 1/2 GAS LIFT DMY IRK 0.000 0.0 5/23/2015 -- 5 5,944.2 5,544.5 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/23/2015 !PERE;6,202.0-6,266.0 3 6 6,145.7 5,737.2 CAMCO KBUG 1 GAS LIFT DMY 0.000 0.0 5/23/2015 Notes:General&Safety End Date Annotation 5/18/1996 NOTE:WAIVERED WELL:IA X OA COMMUNICATION SLEEVE 6,290.6 _ 7/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 I9 r LOCATOR;6,316A PACKER;6,317.3 =1 SEAL ASSY;6,317.3 SBE;6,3227 `= ErNIPPLE;6,332.5 ■ SOS;8,340.0 APERF;6,384.0-6,404.0- IPERF;6,419.0-6,452.0 PRODUCTION;35.0-6,602.8 3F-10 WELL WORK SUMMARY DATE SUMMARY 2/21/2015 (PRE-RWO): FUNCTION TEST LDS/GN'S:T LDS/GN'S-PASSED; IC LDS-PASSED; IC GN'S © 2, 6 & 8:00-PASSED. T POT-PASSED. T PPPOT-PASSED. IC POT-PASSED. IC 2/22/2015 (PRE-RWO); MITOA (PASSED TO 1800 PSI). 4/20/2015 MEASURED BHP @ 6040' RKB: 2827 PSI. PULLED DV @ 5718' RKB. READY FOR E/L. 4/23/2015 RAN STRING SHOT FROM 6,011' RKB TO 6,019' RKB CUT TBG W/CHEM CUTTER @ 6,015' RKB Conoco hillips Time Log & Summary Weriview Web Reporting Report Well Name: 3F-10 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 5/15/2015 6:00:00 PM Rig Release: 5/24/2015 11:59:00 PM Time Logs _Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/13/2015 24 hr Summary RDMO. Lower derrick,warm up the moving system, and move the sub off 2G-02. Move the sub from 2G pad to the intersection of the Spine road and 2G access road. 12:00 13:00 1.00 0 0 MIRU MOVE MOB P Prep rig floor to lower the derrick. Weld fixed carriage onto roughneck. Install brace for A-leg 13:00 14:00 1.00 0 0 MIRU MOVE MOB P Clean and secure the cellar. Set TD in slips. Lay down cattle chute. 14:00 16:00 2.00 0 0 MIRU MOVE MOB P Tie back hoses. Bridle up and disconnect service loop. 16:00 17:30 1.50 0 0 MIRU MOVE MOB P Remove derrick pins. Inspect derrick and roof. Lower the derrick. 17:30 18:00 0.50 0 0 MIRU MOVE MOB P Warm up moving system. Finish pre rig move inspection. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Move sub off 2G-02 and move sub 1.9 miles from 2G pad to the intersection of the Spine road and 2G access road. 35/14/2015 Move the sub from the intersection of the Spine road and 2G access road to 0.5 miles from 3B pad. Failed seal on the drive motor spilled 2 gallons of hydraulic oil(amount determined by Alaska Clean Seas). Spill was cleaned up and disposed of properly. Continue to move the sub to 3F pad, position the sub with the wind blowing into the back of the sub, raised the derrick, pinned the derrick, and raised the cattle chute. 00:00 05:15 5.25 0 0 MIRU MOVE MOB P Move the sub 6 miles from the intersection of the Spine road and 2G access road to the Oliktok Y. 05:15 06:15 1.00 0 0 MIRU MOVE WAIT P Wait at the Oliktok Y for field wide crew change. 06:15 09:45 3.50 0 0 MIRU MOVE MOB P Move 4.9 miles with the sub from the Oliktok Y to CPF3, 09:45 11:30 1.75 0 0 MIRU MOVE MOB P Move 1 mile with the sub from CPF3 to 3B Pad and lost drive motor. Page 1 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 17:30 6.00 0 0 MIRU MOVE RGRP T After removal of the motor on the front drive train beside the drivers cab,the cause was found to be a lost seal in the drive motor,filling the axel housing through the brake spline and releasing fluid through the vent on top into secondary containment, leaving trail on the gravel road. Tool Pusher notified the Company man, in return notified Alaska Clean Seas to evaluate and clean up residual from gravel road (spill volume determined by ACS was 2 gallons). Security was notified and First report was filed. The rig was repaired and all soiled gravel was recovered and disposed of after rig was on 3B Pad. 17:30 18:00 0.50 0 0 MIRU MOVE MOB P Move sub 0.5 miles to 3B pad. 18:00 18:30 0.50 0 0 MIRU MOVE WAIT P Wait for field change out and recover the remaining soiled gravel and dispose of properly. 18:30 21:00 2.50 0 0 MIRU MOVE MOB P Move the sub 2.7 miles from 3B pad to 3F pad and position the sub with the wind blowing into the back of the sub. 21:00 21:30 0.50 0 0 MIRU MOVE RURD P Hang the tree in the cellar. 21:30 00:00 2.50 0 0 MIRU MOVE RURD P PJSM. Pre to raise the derrick. Raise the derrick and pin. Raise the cattle chute. 05/15/2015 Spot the sub over well 3F-10 and spot the pits to the sub. Held an After Action Review(AAR)on the Between Wells Maintenance(BWM)program discussing lessons learned, procedures,timelines, and manuals with crews. Held Pre-Spud meeting for 3F-10. Continued to RU and accept the rig at 18:00 hours. RU the lubricator and pull the BPV(tubing =850 psi and IA= 1250 psi). Open up well to the choke and bring the pumps online. Begin well kill operation by pumping 55 bbls down the tubing at 2 BPM. Shut down the pumps. SITP=0 psi and SICP=460 psi. 00:00 01:00 1.00 0 0 MIRU MOVE RURD P Raise the block with bridal line but to windy to pin to the TD. 01:00 03:00 2.00 0 0 MIRU MOVE MOB P Spot the sub over well 3F-10. 03:00 05:00 2.00 0 0 MIRU MOVE MOB P Spot the pits to the sub. 05:00 09:00 4.00 0 0 MIRU MOVE RURD P Spot cuttings box and spot LEPD tank. Setup berming around sub and pit flow line area. 09:00 10:30 1.50 0 0 MIRU MOVE SFTY P Held After Action Review(AAR)on Between Wells Maintenance(BWM) program discussing lessons learned, procedures,timelines, and manuals. Held Pre-Spud meeting for 3F-10. Page 2 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:30 14:00 3.50 0 0 MIRU MOVE RURD P Continue to berm sub, relocate cuttings box, hook up service lines from the pits to the sub. Build transition for the cellar door. Setup berming around cuttings box and LEPD tank. *On high line power at 12:00 hours* 14:00 15:30 1.50 0 0 MIRU MOVE RURD P Bridal down,tighten the Kelly hose. Start taking on 10.1 ppg NaCI with KCL brine. 15:30 16:00 0.50 0 0 MIRU MOVE RURD P Hook up hydraulics to the TD and RU mud lines. 16:00 18:00 2.00 0 0 MIRU MOVE RURD P PJSM. Install secondary valves on the IA and OA. RU lines and equipment for well kill. *Rig Accepted at 18:00 hours* 18:00 19:00 1.00 0 0 MIRU WELCTL RURD P RU rig floor and bring lubricator to the rig floor. Clean and clear the floor. 19:00 19:30 0.50 0 0 MIRU WELCTL RURD P RU to test surface lines,tiger tank line, and surface equipment. 19:30 20:00 0.50 0 0 MIRU WELCTL SEQP P PT surface lines, tiger tank line, and surface equipment to 250/3500 psi (good test). 20:00 21:00 1.00 0 0 MIRU WELCTL SEQP P PU and MU lubricator to the tree. 21:00 22:00 1.00 0 0 MIRU WELCTL MPSP P Test lubricator to 2000 psi(good test)and pull BPV per FMC rep. Pressures: Tubing =850 psi and IA = 1250 psi. 22:00 23:00 1.00 0 0 MIRU WELCTL RURD P RU well kill line to the tree and test line to 3500 psi(good test) 23:00 00:00 1.00 0 0 MIRU WELCTL KLWL P PJSM. Open up well to the choke and bring the pumps online. Begin well kill operation by pumping 55 bbls down the tubing at 2 BPM. Shut down the pumps. SITP=0 psi and SICP=460 psi. 05/16/2015 Shut in the IA and bullhead 10 bbls of 10.1 ppg NaCl with KCL brine to the formation at 2 BPM=40 psi. Open the IA to the choke and continue with the well kill operation at 2 BPM. Shut down due to a small leak at the kill tank 2"threaded connection to the 1502 connection above the block valve. No fluid went into containment or on the ground. Fluid was wiped off the connection and hose with absorb and disposed of properly. Wait for hardline crew to arrive on location. Change out connection. Close block valve and PT line to 3500 psi(good test). The connection that was leaking cannot be tested because it is above the block valve. Resumed circulation at 3 BPM = 120 psi on the tubing and 430 psi on the casing. Shut down pumps and close in the well; pumped at total of 300 bbls of 10.1 ppg NaCI with KCL brine(10 bbls were bullheaded), returned 160 bbls in the kill tank, and lost 130 bbls to the formation. Monitor the well;tubing=0 psi, IA= 320 psi,and OA= 1480 psi. Hook up the bleed trailer and bleed the OA to 0 psi. Pumped an additional 131 bbls and shut in the well. Monitor the well;tubing=0 psi, IA=60 psi, and OA= 10 psi. Wait for additional KWF to arrive. Load pits with 9.8 ppg NaBr brine and weight up to 10.1 ppg for a total of 270 bbls of brine. Pumped 250 bbls of 10.1 ppg NaBr brine down the tubing taking returns out the IA to the kill tank at 3 BPM = 460 psi on the tubing. FCP=260 psi on the tubing and 20 psi on the IA. Recovered 33 bbls in the kill tank. Gas cut 10.1 ppg brine seen at surface. Page 3 of 20 9 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 MIRU WELCTL KLWL P Shut in the IA and bullhead 10 bbis of 10.1 ppg NaCI with KCL brine to the formation at 2 BPM=40 psi. Open the IA to the choke and continue with the well kill operation at 2 BPM. Shut down due to a small leak at the kill tank 2"threaded connection to the 1502 connection above the block valve. No fluid went into containment or on the ground. Fluid was wiped off the connection and hose with absorb and disposed of properly. 01:00 02:00 1.00 0 0 MIRU WELCTL WAIT T Secure the well by closing in the IA and master valve on the tree. Blow down the line and break the connection from the hardline to the kill tank. Wait for hardline crew to arrive on location. Connection where fluid was leaking from was loose. Inspect thread and MU connection. MU connection from hardline to kill tank. Flood the line and no visual leak at connection. Close block valve and PT line to 3500 psi(good test). The connection that was leaking cannot be tested because it is above the block valve. 02:00 02:15 0.25 0 0 MIRU WELCTL KLWL T Attempt to resume well kill operation at 2 BPM but same connection is still leaking. No fluid went into containment or on the ground. Fluid was wiped off the connection and hose with absorb and disposed of properly. 02:15 03:30 1.25 0 0 MIRU WELCTL WAIT T Secure the well by closing in the IA and master valve on the tree. Blow down the line and break the connection from the hardline to the kill tank. Wait for hardline crew to go back to the tool house and procure replacement parts. Change out connection. MU connection from hardline to kill tank. Flood the line and no visual leak at connection. Close block valve and PT line to 3500 psi(good test). The connection that was leaking cannot be tested because it is above the block valve. Page 4 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 0 0 MIRU WELCTL KLWL P Opened up the well to closed choke and opened the master valve(SITP= 0 psi and SICP=620 psi). Resumed circulation at 2 BPM=40 psi on the tubing and 450 psi on the casing. Bring the pump rate up to 3 BPM = 120 psi on the tubing and 430 psi on the casing. Shut down pumps and close in the well;pumped at total of 300 bbls of 10.1 ppg NaCI with KCL brine(10 bbls were bullheaded), returned 160 bbls in the kill tank, and lost 130 bbls to the formation. 05:00 06:30 1.50 0 0 MIRU WELCTL OWFF P Install low pressure gauges on the tubing/IA and monitor the well;tubing =0 psi, IA=320 psi,and OA= 1480 psi. 06:30 07:00 0.50 0 0 MIRU WELCTL COND P Hook up the bleed trailer and bleed the OA to 0 psi. Empty the kill tank. Transfer fluids around in the pits to be able to pump maximum volume that is on location. 07:00 07:30 0.50 0 0 MIRU WELCTL KLWL P Open up the choke and bleed the IA to 0 psi. Begin pumping at 3 BPM= 170 psi on the tubing and 210 psi on the casing. FCP= 130 psi on the tubing and 100 psi on the casing. Shut down the pumps and close the choke(SITP=0 psi, SICP= 130 psi. Pumped 45 bbls. 07:30 08:00 0.50 0 0 MIRU WELCTL COND P Move fluid from trip tank, pill pit, and BST into the pits. 08:00 09:30 1.50 0 0 MIRU WELCTL KLWL P Open up the choke and begin pumping at 4 BPM =330 psi on the tubing and 40 psi on the casing. FCP=400 psi on the tubing and 20 psi on the casing. Shut in the well. Pumped 86 bbls 09:30 10:30 1.00 0 0 MIRU WELCTL OWFF P Monitor the well;tubing=0 psi, IA= 60 psi, and OA= 10 psi. 10:30 11:30 1.00 0 0 MIRU WELCTLWAIT T Wait for additional KWF to arrive. SimOps: Held BWM program training season with rig crew, tool pusher and company man. 11:30 16:00 4.50 0 0 MIRU WELCTL WAIT T Wait for additional KWF to arrive. Continue to monitor the well;tubing =0 psi, IA=50 psi, and OA= 10 psi. SimOps: Load the pipe shed with 4" DP and strap/tally. Inspect lines and equipment. Load BST with freshwater. Page 5 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:30 1.50 0 0 MIRU WELCTL WAIT T Wait for additional KWF to arrive. SimOps: Continue to load, strap, and tally 4"DP. General housekeeping. Test rig gas alarms(States right to witness of BOPE test waived by AOGCC inspector Bob Noble). 17:30 21:30 4.00 0 0 MIRU WELCTL COND T Load pits with 9.8 ppg NaBr brine and weight up to 10.1 ppg fora total of 270 bbls of brine. SimOps: Load the pipe shed with 4-3/4"DC's and strap/tally. 21:30 00:00 2.50 0 0 MIRU WELCTL KLWL T PJSM. Fill lines. Pump 250 bbls of 10.1 ppg NaBr brine down the tubing taking returns out the IA to the kill tank at 3 BPM =460 psi on the tubing. FCP=260 psi on the tubing and 20 psi on the IA. Recovered 33 bbls in the kill tank. 05/17/2015 Monitor the well: Tubing=0 psi, IA= 120 psi, and OA=0 psi. Bleed the IA to 0 psi(all gas)and wait for additional KWF to arrive while monitoring the well(IA pressure is slowly increasing). Load the pits with 10.1 ppg brine. Reverse circulate 290 bbls of 10.1 ppg brine at 3 BPM; observed gas cut 10.1 ppg brine at surface. Recovered 117 bbls in the kill tank(173 bbls lost). Shut in pressures after circulation-Tubing=0 psi, IA=0 psi, and OA=0 psi. Wait for additional KWF to arrive while monitoring the well(tubing pressure is slowly increasing). Load the pits with 290 bbls of 10.1 ppg brine and build 10.3 ppg hi-visc pill. Attempt to pump pill but power visc would not shear. Dispose of pill and build a new pill while still waiting on additional KWF. Notified that additional KWF would not arrive until after midnight. Pressures after being shut in for 12.5 hours: Tubing=450 psi, IA=40 psi, and OA=20 psi. Reverse circulate 40 bbls of 10.3 ppg hi-visc pill down the IA at 3 BPM followed by 128 bbls of 10.1 ppg brine. Recovered 34 bbls in the kill tank. Shut in pressures after circulation-Tubing= 10 psi, IA=0 psi, and OA=20 psi(tubing pressure slowly increasing). Bullhead 10 bbls down the tubing. Shut in pressures after bullhead-Tubing=0 psi, IA=0 psi, and OA=20 psi. Wait for additional 10.1 ppg brine to arrive to weight up to 10.3 ppg. Tubing pressure built to 150 psi in 4 hours and the IA remained at 0 psi. 00:00 01:00 1.00 0 0 MIRU WELCTL OWFF T Monitor the well: Tubing=0 psi, IA = 120 psi, and OA=0 01:00 01:15 0.25 0 0 MIRU WELCTL OWFF T Bleed the IA to 0 psi, shut in, and monitor the well. Tubing=0 psi, IA= 0 psi, and OA=0 01:15 02:15 1.00 0 0 MIRU WELCTL WAIT T Wait for additional KWF to arrive. Continue to monitor the well: Tubing=0 psi, IA=70 psi, and OA =0 02:15 03:30 1.25 0 0 MIRU WELCTL COND T Load the pits 290 bbls with 10.1 ppg NaBr brine. Continue to monitor the well: Tubing=0 psi, IA=80 psi, and OA=0 Page 6 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 0 0 MIRU WELCTI KLWL T PJSM. Line up to reverse circulate. Start reverse circulation 10.1 ppg brine down the IA and taking returns up the tubing at 3 BPM with 160 psi on the IA and 50 psi on the tubing. FCP= 150 psi on the casing and 0 psi on the tubing. Shut down pumps and shut in the well. Pumped 290 bbls and returned 117 bbls in the kill tank(173 bbls lost). Observed gas cut 10.1 ppg brine at surface. Shut in pressures: tubing=0 psi, IA= 10 psi, and OA=0 psi 05:00 05:30 0.50 0 0 MIRU WELCTI OWFF T Monitor the well: tubing=0 psi, IA= 0 psi, and OA=0 psi. 05:30 09:00 3.50 0 0 MIRU WELCTL WAIT T Wait for additional KWF to arrive. SimOps: Equalize the tubing and the IA, open up the well to monitor, and observed minimal fluid return that decreased to no fluid and just gas venting. Offload 149 bbls from the kill tank. 09:00 09:15 0.25 0 0 MIRU WELCTL WAIT T Wait for additional KWF to arrive. SimOps: Monitor the well-Tubing= 20 psi, IA=5 psi, and OA=0 psi. Open the tubing and IA to vent gas. Tubing gas venting did not decrease, shut the well back in. 09:15 10:45 1.50 0 0 MIRU WELCTL WAIT T Wait for additional KWF to arrive. SimOps: Monitor the well recording pressures every 30 minutes. Start- Tubing=30 psi, IA=5 psi, and OA =0 psi. End-Tubing= 155 psi, IA= 15 psi, and OA=20 psi. 10:45 12:00 1.25 0 0 MIRU WELCTL COND T Load the pits with 290 bbls of 10.1 NaBr brine. Continue to monitor the well. Pressures at 12:00 hours- Tubing=275 psi, IA= 15 psi, and OA=20 psi. SimOps: Load the pipe shed with jewelry. 12:00 14:00 2.00 0 0 MIRU WELCTL WAIT T Wait for additional KWF to arrive. SimOps: Build a 45 bbl 10.3 ppg hi-visc pill. Strap and tally jewelry. General housekeeping. 14:00 16:00 2.00 0 0 MIRU WELCTI KLWL T Pressures: Tubing =400 psi, IA= 30 psi,and OA=20 psi. Attempt to pump 10.3 ppg hi-visc pill but power vis would not shear. Decision was made to dispose of pill. Build a new 10.3 ppg hi-visc pill. Page 7 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:45 1.75 0 0 MIRU WELCTI WAIT T Wait for additional KWF to arrive. Notified that truck with additional KWF would not arrive until after midnight. Pressures: Tubing=450 psi, IA=40 psi, and OA=20 psi. SimOps: Continue general housekeeping. 17:45 19:00 1.25 0 0 MIRU WELCTL KLWL T PJSM. Reverse circulate 40 bbls of 10.3 ppg hi-visc pill down the IA at 3 BPM=300 psi on the tubing and 120 psi on the IA followed by 128 bbls of 10.1 ppg brine. ICP=280 psi on the tubing and 120 psi on the IA. FCP=0 psi on the tubing and 120 psi on the IA. Shut down the pumps and shut in the well to monitor. Recovered 34 bbls in the kill tank. 19:00 19:30 0.50 0 0 MIRU WELCTL OWFF T Monitor the well recording pressures every 15 minutes. Start-Tubing= 10 psi, IA=0 psi, and OA=20 psi. End-Tubing=40 psi, IA=0 psi, and OA=20 psi. 19:30 19:45 0.25 0 0 MIRU WELCTL KLWL T Bullhead 10 bbls of 10.1 ppg brine down the tubing. Shut in the well to monitor 19:45 21:00 1.25 0 0 MIRU WELCTI OWFF T Monitor the well recording pressures every 15 minutes. Start-Tubing=0 psi, IA=0 psi, and OA=20 psi. End-Tubing= 18 psi, IA=0 psi, and OA=20 psi. Attempt to bleed off the tubing ,vented all gas and pressure did not decrease. 21:00 00:00 3.00 0 0 MIRU WELCTI WAIT T Wait for additional 10.1 ppg brine to arrive to weight up to 10.3 ppg. Continue to monitor the well recording pressures every 15 minutes. Start-Tubing=35 psi, IA =0 psi, and OA=20 psi. End- Tubing= 185 psi, IA=0 psi, and OA =20 psi. 05/18/2015 Wait for 10.1 ppg brine to arrive, load the pits with 290 bbls of 10.1 ppg, and weight up to 10.3 ppg brine. Reverse circulate 10.3 ppg brine until clean 10.3 ppg brine seen at surface(437 bbls). Shut down the pumps and shut in the well to monitor. Tubing and IA at 0 psi; open up the tubing and IA and both are on a vac. Install BPV, ND tree, NU DSA, and NU BOPE. Conducted initial BOPE test to 250/2500 psi: test 2-7/8"x 5" VBR's(lower pipe rams)and 3-1/2"x 6"VBR's(upper pipe rams)with 3-1/2"test joint; test annular to 250/2500 with 3-1/2"test joint; conducted CPAI Koomey Draw Down Test. All tested passed. The States right to witness was waived by AOGCC inspector Bob Noble on 5/16/15 at 10:46 hours via email. RD BOPE testing equipment and pull blanking plug. Page 8 of 20 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 0 0 MIRU WELCTL WAIT T Wait for additional 10.1 ppg brine to arrive to weight up to 10.3 ppg. Continue to monitor the well recording pressures every 15 minutes. Start-Tubing= 185 psi, IA =0 psi, and OA=20 psi. End- Tubing =260 psi, IA=5 psi, and OA =20 psi. 01:15 04:30 3.25 0 0 MIRU WELCTL COND T Load the pits with 290 bbls of 10.1 ppg brine and weight up to 10.3 ppg brine. Continue to monitor the well recording pressures every 15 minutes. Start-Tubing=280 psi, IA =5 psi, and OA=20 psi. End- Tubing=430 psi, IA=20 psi, and OA=20 psi. 04:30 08:00 3.50 0 0 MIRU WELCTL KLWL T Line up to reverse circulate and fill the gas buster. Reverse circulate 10.3 ppg NaBr at 2 BPM=40 psi on the casing and 150 psi on the tubing to the kill tank until clean 10.1 ppg (170 bbl). Realign to take returns through the gas bust and back to pit 4. Continue to reverse circulate 10.3 ppg NaBr at 4 BPM =250 psi on the casing and 0 psi on the tubing until clean 10.3 ppg brine is seen at surface(267 bbls). Shut down the pumps and shut in the well to monitor. Total of 437 bbls pumped and recovered 234 bbls(203 bbls lost). 08:00 09:30 1.50 0 0 MIRU WELCTL OWFF T Observe the well for flow for 30 minutes. Shut in pressures-Tubing =0 psi, IA=0 psi, and OA=20 psi. Open up the tubing and IA to check for flow and the well is on a vac. SimOps: Blow down all circulation line and choke manifold. RD circulating equipment and off load kill tank. 09:30 10:00 0.50 0 0 MIRU WHDBO MPSP P Install ISA BPV per FMC rep. 10:00 11:00 1.00 0 0 MIRU WHDBO OTHR P Bleed pressure off the control line and tubing head void. SimOps: Pumped 25 bbls down the IA and opened up the IA to confirm well is still on a vac. 11:00 13:30 2.50 0 0 MIRU WHDBO NUND P ND the tree and set outside the cellar. SimOps: Fill the IA with 25 bbls every hour. Page 9 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 0 0 MIRU WHDBO NUND P Clean and prep wellhead and NU DSA. 14:00 16:15 2.25 0 0 MIRU WHDBO NUND P PJSM. NU BOPE, obtain RKB's, install riser, and install turnbuckles. 16:15 17:00 0.75 0 0 MIRU WHDBO RURD P RU 3-1/2"test joint, 3-1/2"EUE TIW, 4"dart valve, and 4"HT40 TIW. Line up the manifold,fill the BOP/choke manifold, and check for leak(no leaks). 17:00 22:30 5.50 0 0 MIRU WHDBO BOPE P Conduct initial BOPE test to 250/2500 psi: test 2-7/8"x 5"VBR's (lower pipe rams)and 3-1/2"x 6" VBR's(upper pipe rams)with 3-1/2" test joint;test annular to 250/2500 with 3-1/2"test joint. The States right to witness was waived by AOGCC inspector Bob Noble on 5/16/15 at 10:46 hours via email. Tests: #1)Blinds, Demco Kill, 4" HT-40 Dart, Chokes 1,2, 3, & 16(Passed) #2) HCR Kill, 4" HT-40 TIW, Chokes 4, 5, &6(Passed) #3)Manual Kill, Chokes 7, 8, &9 (Passed) #4)Manual Choke, Hydraulic Choke (Passed) #5)Chokes 10& 11 (Passed) #6)Chokes 12, 13, & 14(Passed) #7)3-1/2" EUE TIW, Choke 15, HCR Kill, Annular with 3-1/2"test joint (Passed) #8)3-1/2" EUE TIW, HCR Choke, Upper Pipe rams with 3-1/2"test joint(Passed) #9) Manual Choke, Upper Pipe rams with 3-1/2"test joint(Passed) #10) Lower Pipe rams with 3-1/2" test joint(Passed) #11)Top Drive Upper IBOP, Outer Test Spool, Upper Pipe rams with 3-1/2"test joint (Passed) #12)Top Drive Lower IBOP, Inner Test Spool, Upper Pipe rams with 3-1/2"test joint (Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2950 psi Accumulator Pressure After Closer= 1800 psi Pressure Gain of 200 psi=35 seconds Full System= 127 Seconds Average N2(6 Bottles)=2128 psi Page 10 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:30 1.00 0 0 MIRU WHDBO RURD P Blow down the top drive, empty the stack, and RD BOPE testing equipment. Clean and clear the floor. 23:30 00:00 0.50 0 0 MIRU WHDBO MPSP P Pull blanking plug per FMC rep. 05/19/2015 Bullhead 30 bbl 10.5 ppg hi visc pill followed by 25 bbls of 10.3 ppg brine. Check for pressure under BPV (well on a vac)and pull BPV. Fill the hole with 25 bbls of 10.3 ppg brine every hour. RU GBR and SLB control line spooler. MU landing joint, BOLD, and pull hanger to the rig floor. POOH laying down 3-1/2" tubing spooling control line(recovered all 34 stainless steel control line bands)and lay down 7 GLM's(cut joint 16.42'). Install test plug;test upper rams, lower rams, and annular with 4"test joint to 250/2500 psi. Pull test plug and install wear ring. PU and MU overshot assembly for 3-1/2"tubing. 00:00 00:30 0.50 0 0 MIRU WHDBO MPSP T Check for pressure under BPV, gas under BPV, vent gas, but gas rate not decreasing. 00:30 00:45 0.25 0 0 MIRU WELCTE CIRC T Fill the IA with 25 bbl 00:45 02:30 1.75 0 0 MIRU WELCTI.CIRC T Bullhead 30 bbl 10.5 ppg hi visc pill at 1 BPM=60 psi followed by 25 bbls of 10.3 brine at 1 BPM =90 psi. 02:30 03:00 0.50 0 0 MIRU WHDBO MPSP P Drain the stack. Check for pressure under BPV, no pressure, and pull BPV(well on a vac). 03:00 03:30 0.50 0 0 COMPZ RPCOM OWFF P Fill the hole with 27 bbls and monitor the well to establish loss rate of 40 bbl/hr. 03:30 04:00 0.50 0 0 COMPZ RPCOM RURD P RU GBR tubing pulling equipment. Change elevators from 4" DP to 3-1/2"tubing. RU SLB control line spooler. 04:00 04:45 0.75 0 0 COMPZ RPCOM RURD P PU and MU three 10'3-1/2"EUE pup joints to use as a landing joint. Screw landing joint into tubing hanger lift threads. MU crossover from 3-1/2"EUE to 4"HT-40. Screw into TD. 04:45 06:15 1.50 0 6,015 COMPZ RPCOM PULL P BOLDS,tubing hanger pushed up 2', pull tubing free at 95K, unscrew TD, pull hanger to the rig floor(PU=85K, SO=75K), break out crossover, unscrew landing joint,and lay down landing joint. 06:15 06:45 0.50 6,015 6,015 COMPZ RPCOM CIRC P Fill the hole with 25 bbls of 10.3 ppg. _ _ Blow down the TD and kill line. 06:45 09:15 2.50 6,015 4,190 COMPZ RPCOM PULL P POOH laying down 3-1/2"tubing, spooling control line, and removing stainless steel bands. Straping and unloading the pipe shed as needed and monitoring the well on the trip tank. Lay down SCSSSV. Recovered all 34 stainless steel band. 09:15 09:30 0.25 4,190 4,190 COMPZ RPCOM RURD P RD SLB control line spooler. 09:30 17:00 7.50 4,190 0 COMPZ RPCOM PULL P Continue POOH laying down 3-1/2" tubing and lay down 7 GLM's. Filling the hole with 25 bbls every hour Cut joint length= 16.42'. Page 11 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 0 COMPZ RPCOM RURD P PJSM. RD GBR tubing pulling equipment. Clean and clear the _ floor. 18:00 18:45 0.75 0 0 COMPZ RPCOM BOPE P PJSM. RU BOPE testing euqipment, PU 4"test joint, install test plug, open the IA to verify plug is set, fill the test pump, and fill the stack. 18:45 20:00 1.25 0 0 COMPZ RPCOM BOPE P Test annular, 3-1/2"x 6"VBR's (upper pipe rams), and 2-7/8"x 5" VBR's(lower pipe rams)with 4"test joint to 250/2500 psi. Tests: 1)4"TIW, HCR Kill, HCR Choke, Annular with 4"test joint(passed) 2)4"TIW, HCR Kill, HCR Choke, Upper Pipe Rams with 4"test joint (passed) 3)4"TIW, HCR Kill, HCR Choke, Lower Pipe Rams with 4"test joint (passed) 20:00 20:45 0.75 0 0 COMPZ RPCOM BOPE P Empty the stack, blow down lines and RD BOPE testing equipment. Pull test plug, lay down 4"test joint, and.set wear ring. 20:45 21:45 1.00 0 0 COMPZ RPCOM RURD P Load and strap fishing tools that arrived on the airplane due to water over the Kaparuk River bridge. 21:45 22:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM for picking up fishing BHA 22:00 00:00 2.00 0 314 COMPZ RPCOM BHAH P PU and MU BHA#1 -Overshot Assembly for 3-1/2"tubing. (PU = 47K, SO=45K) 05/20/2015 Single in the hole with overshot assembly,tag tubing stub at 5994' RKB, engage fish, and jar free. TOOH standing back DP because it appears that we have the upper packer and selective. Lay down overshot assembly with cut joint, GLM#8, SBR, Otis Packer, GLM#9, and the first of three blast ring joints. 00:00 00:30 0.50 314 314 COMPZ RPCOM RURD P RU fill up hose to fill the DP. Fill the IA with 25 bbls of 10.3 ppg brine. 00:30 06:00 5.50 314 5,965 COMPZ RPCOM PULD P Single in the hole with BHA#1 - Overshot Assembly for 3-1/2"tubing on 4" DP to 5965' RKB(PU = 145K, SO= 105K). Fill the hole 25 bbls every hour and fill the DP as need to avoid gas migration. 06:00 06:30 0.50 5,965 5,997 COMPZ RPCOM FISH P Tag tubing stub at 5994' RKB(PU= 145K, SO= 105K). Rotate at 15 RPM to get over tubing stub, shut down the rotary, SO to 5997'RKB, and set 10K down. PU to 180K and fish is not free. 06:30 09:45 3.25 5,997 5,997 COMPZ RPCOM JAR P Warm up the jars and start jarring working up to max jarring at 190K (45K over)with straight pull of 195K (50K over). After 34 jar lick fish pulled free(PU= 155K). Fill the hole with 25 bbls of 10.3 ppg brine every hour. Page 12 of 20 . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:00 0.25 5,997 5,901 COMPZ RPCOM CIRC P Pump 28 bbls down the DP at 3 BPM= 120 psi. Stand back one stand of DP and blow down the TD. 10:00 12:00 2.00 5,901 4,880 COMPZ RPCOM TRIP P TOOH standing back DP from 5901' to 4880'RKB(PU = 150k, SO= 105K). Encountered tight spots at 5860' RKB and 5050'RKB(max overpull 20K). The upper packer and selective might have been pulled. 12:00 12:30 0.50 4,880 4,880 COMPZ RPCOM CIRC P Fill the hole with 25 bbls down the IA and 3 bbls down the DP. Take on fluid in the pits. 12:30 13:00 0.50 4,880 4,880 COMPZ RPCOM SVRG P PJSM. Inspect TD and grease. Inspect draw works and grease. 13:00 18:00 5.00 4,880 314 COMPZ RPCOM TRIP P Continue to TOOH from 4880'to 314' RKB filling the IA with 25 bbls every hour and filling the DP as needed. 18:00 20:00 2.00 314 0 COMPZ RPCOM BHAH P Lay down intensifier and pump out sub. Stand back 3 stands of DC's and lay down bumper sub with oil jars. 20:00 00:00 4.00 307 100 COMPZ RPCOM PULL P Lay down cut joint. Break out joint and GLM. Spacer tubing from tubing patch free from upper patch packer but stuck in the lower patch packer. Cut space pipe and lay down. Lay down joint with up patch packer and GLM. Lay down tubing joint with • lower patch packer. Recovered SBR and Otis Packer(wear ring was pulled by the packer). Lay down selective GLM and two joints of tubing. Lay down first joint of blast rings. On the second joint of blast ring the coupling cover is stuck due to scale. Note: Holes below GLM#8 at 6074.21'ORKB(center of hole)and 6084.06'ORKB(center of hole). Both holes covered by tubing patch. Hole below GLM#8 not covered by tubing patch at 6097.96'ORKB (center of hole). Pictures in the well folder. 05/21/2015 Lay down two blast ring joints,Ava BPL sleeve, and locator seal assembly. Install new wear ring. PU, MU, and TIH with cleanout assembly to tag at 6217' RKB. Wash and ream from 6217'to 6230' RKB, observed increase in flow, shut down the pumps to monitor the well, and observed gas/crude returns. Shut in the well SIDPP=20 psi and SICP=40 psi. Pressure stabilized at 20 psi on the DP and 80 psi on the IA. Circulate bottoms up(144 bbls)down DP taking returns out choke to kill tank at 2 bpm =90 psi(no returns observed). Monitor the well, SIDPP=20 psi, SICP=20 psi, bleed tubing and IA to 0 psi. Open the well, fill the IA with 30 bbls, monitor the well, and the well is on a vac. Wash and ream from 6207'to 6297' RKB. Pump 40 bbl hi vics pill and spot on bottom. POOH laying down DP to 551'at midnight. Page 13 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 100 0 COMPZ RPCOM PULL P PU break out the seal assembly with Ava BPL sleeve and lay down. Break out 15'pup and lay down. Cut of couple cover from blast ring connection and lay down the two blast ring joints. Note: Ava sleeve ports washed/corroded out. Hole below Ava sleeve just above crossover (Center of hole at 6305.5'ORKB). Pictures in well file. 02:30 03:15 0.75 0 0 COMPZ RPCOM RURD P RD GBR tubing pulling equipment. Clean and clear the floor 03:15 03:45 0.50 0 0 COMPZ RPCOM SVRG P Service and inspect top drive and crown. Perform post jarring derrick inspection. 03:45 05:45 2.00 0 0 COMPZ RPCOM BHAH P PU overshot with cut joint. Break out cut joint from overshot and service break overshot. Lay down overshot. 05:45 06:15 0.50 0 0 COMPZ WELLPF RURD P Install wear ring. 06:15 08:00 1.75 0 305 COMPZ WELLPF BHAH P PU and MU BHA#2-cleanout assembly. 08:00 11:00 3.00 305 6,217 COMPZ WELLPF TRIP P RIH f/305't/6217' RKB take weight 10k,work string unable to work through. 11:00 12:00 1.00 6,217 6,207 COMPZ WELLPF REAM T Wash and ream through tight spot perfs, f/6217't/6230'RKB observe flow increase, shut down pumps observe well gas and crude returns P/U t/6207' RKB shut well in @ 1149 hrs monitor pressure SIDPP 20 psi SICP 40 psi 12:00 12:30 0.50 6,207 6,207 COMPZ WELLPF OWFF T Continue monitoring pressures SIDPP 20 psi SICP 80 psi stabilized. 12:30 13:00 0.50 6,207 6,207 COMPZ WELLPF RURD T PJSM. RU to circulate out secondary choke to the tiger tank. Pressure test line to 1500 psi and blow down secondary kill. 13:00 14:30 1.50 6,207 6,207 COMPZ WELLPF CIRC T Circulate bottoms up(144 bbls)down DP taking returns out choke to kill tank at 2 bpm=90 psi(no returns observed). 14:30 15:00 0.50 6,207 6,207 COMPZ WELLPF OWFF T Monitor pressures 20 psi SIDPP 20 psi SICP, bleed off psi, Open well fill back side w/30 bbls with hole fill shut off hole fill monitor fluid level dropping at fast rate. 15:00 16:30 1.50 6,207 6,210 COMPZ WELLPF REAM P Wash and ream from 6207'to 6297' RKB rotating at 50 RPM with 5-6K ft-lbs torque(rotating weight= 125K), Stand one stand back in the derrick to pump pill 16:30 17:30 1.00 6,210 6,210 COMPZ WELLPF CIRC P Pump 40 bbls hi visc pill and spot on bottom at 2 BPM=225 psi. Blow down TD. Page 14 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 00:00 6.50 6,210 ' 551 COMPZ WELLPF PULD P POOH with BHA#2-cleanout assembly laying down DP to 551' (PU= 155K, SO= 106K). Filling the IA 25 bbls every hour and filling the DP every 15 joints. 05/22/2015 Continue to POOH laying down DP. Lay down nine DC's and cleanout assembly. Test 3-1/2"x 6"VBR's (upper pipe rams), HCR choke, and super choke to 250/2500 psi with 3-1/2"test joint. PU and MU selective completion: seal assembly, CMU,2 blast ring joints, GLM, FHL packer, and PBR. Continue to RIH with selective gas lift completion on 3-1/2"tubing. Tag existing packer at 6297' RKB. Circulate down the tubing at 2 BPM, SO,observed pressure increase as seal engage seal bore, and locate out on existing packer with 15K down at 6303' RKB. 00:00 00:30 0.50 551 305 COMPZ WELLPF PULD P Continue to lay down DP from 551'to 305' RKB. 00:30 03:00 2.50 305 0 COMPZ WELLPF BHAH P Lay down 9 DC's and lay down BHA #2-cleanout assembly. Clean and clear the floor. SimOps: Load completion jewelry into the pipe shed. 03:00 04:00 1.00 0 0 COMPZ RPCOM BOPE P RU BOPE testing equipment. Pull wear ring and install test plug with 3-1/2"test joint. 04:00 04:30 0.50 0 0 COMPZ RPCOM BOPE P Test 3-1/2"x 6"VBR's(upper pipe rams), HCR choke, and super choke to 250/2500 psi with 3-1/2"test joint. SimOps: Install blast rings onto 41' joints in the pipe shed. 04:30 05:00 0.50 0 0 COMPZ RPCOM BOPE P Drain the stack, pull test plug, RD BOPE testing equipment, and blow down lines. 05:00 06:00 1.00 0 0 COMPZ RPCOM RURD P PU and break out original locator to re-use with selective completion. 06:00 07:45 1.75 0 0 COMPZ RPCOM RURD P RU GBR tubing running equipment. Bring pups needed for the completion to the rig floor and bring false table to the rig floor. Continue to fill the hole with 25 bbls of 10.3 ppg brine every hour. 07:45 11:30 3.75 0 328 COMPZ RPCOM PUTB P PU and MU selective completion: seal assembly, CMU, 2 blast ring joints, GLM, FHL packer, and PBR. 11:30 22:30 11.00 328 6,297 COMPZ RPCOM PUTB P Continue to RIH with selective gas lift completion on 3-1/2"tubing. Filling the hole with 25 bbls of 10.3 ppg brine every hour. Tag existing packer at 6297'RKB 22:30 23:15 0.75 6,297 6,297 COMPZ RPCOM RURD P RU to circulate down the tubing to locate existing packer. 23:15 00:00 0.75 6,297 6,303 COMPZ RPCOM CIRC P Circulate down the tubing at 2 BPM = 133 psi, SO,observed pressure increase as seal engage seal bore, shut the pump off, SO, and locate out on existing packer with 15K down at 6303' RKB. Page 15 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode` T Comment 05/23/2015 24 hr Summary Drop ball&rod and pressure up the tubing to 3000 psi to set the FHL packer per Baker rep. With 500 psi on the tubing attempt to pressure test the IA to 1500 psi but tubing started tracking the IA after the IA pressure was above 700 psi. Trouble shoot and confirm that the SOV sheared prematurely. RU slickline,set catcher sub on top of ball&rod, pull failed SOV, install new SOV(2000 psi casing to tubing shear), and RD slickline. MU tubing hanger, circulate the well over to 10.3 ppg corrosion inhibited NaCl/NaBr brine, land tubing hanger, pull old LDS, install new LDS,and RILDS. PT the tubing to 3000 psi for 15 minutes(good test), bleed the tubing to 1500 psi, and PT the IA to 2500 psi for 30 minutes(good test). Shear the SOV, install BPV, and PT the BPV to 1000 psi from below. Conduct CPAI BOPE inspection per CPAI Between Well Maintenance (BWM)program. 00:00 00:30 0.50 6,303 6,303 COMPZ RPCOM OTHR P Break off circulation hose and drop ball&rod. Allow for ball&rod to gravitate to RHC plug body. 00:30 00:45 0.25 6,303 6,010 COMPZ RPCOM PACK P Set FHL packer per Baker rep: Pressure up on the DP to 2500 psi (initial shear at 1700 psi)hold for 5 minutes. Bring the pressure up to 3000 psi and hold for 5 minutes (PBR hydraulic sheared at 2850 psi). Bleed the tubing pressure to 0 psi. FHL packer set at 6031' ORKB 00:45 01:30 0.75 6,010 6,010 COMPZ RPCOM PRTS T Pressure up on the tubing to 500 psi. Close the upper pipe rams and slowly brought up the IA to 1500 psi (the tubing starting tracking the IA), Turned the pump off and tubing and IA held steady at 1500 psi for 5 minutes. Bleed the pressure off the IA and the tubing tracked. Opened the upper pipe rams and attempted to pressure up on the DP and returns were established. Call town engineer and discuss option. Since SOV is at 3800'slickline is needed in order to circulate the well full on corrosion inhibited brine. 01:30 02:00 0.50 6,010 6,010 COMPZ RPCOM RURD P PJSM. RD circulating equipment. 02:00 02:30 0.50 6,010 5,981 COMPZ RPCOM HOSO P Lay down joint#'s 194, 193, and 192. PU and MU space out pup and joint #192. Set the tubing in the slips at a good working height for slickline. Secure the tubing with TIW and monitor the well on the trip tank while circulating over the top. 02:30 05:30 3.00 5,981 5,981 COMPZ RPCOM WAIT T Wait for slickline to arrive. SimOps: General housekeeping. 05:30 06:30 1.00 5,981 5,981 COMPZ RPCOM SLKL T Position slickline unit to RU. 06:30 07:00 0.50 5,981 6,012 COMPZ RPCOM CIRC T PU tubing joint#193 of tubing and sting seal into PBR, close the annular, pump down the IA, and again confirm communication between the tubing and IA through the SOV. 07:00 08:45 1.75 6,012 6,012 COMPZ RPCOM SLKL T PJSM. RU HES slickline Page 16 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 09:45 1.00 6,012 6,012 COMPZ RPCOM SLKL T MU tool string to run catcher sub. RIH with catcher sub and set catcher sub on top of ball&rod at 6260' SLM. POOH with running tools. 09:45 10:30 0.75 6,012 6,012 COMPZ RPCOM SLKL T Reconfigure tool string to pull SOV. RIH, latch SOV at 3778'SLM, pull SOV, and POOH. 10:30 11:30 1.00 6,012 6,012 COMPZ RPCOM SLKL T Reconfigure tool string to set new SOV. RIH with SOV pinned for 2000 psi casing to tubing shear with RKP latch,set at 3778' SLM, and POOH 11:30 12:00 0.50 6,012 6,012 COMPZ RPCOM SLKL T PJSM. RD HES slickline. 12:00 14:00 2.00 6,012 6,006 COMPZ RPCOM HOSO P Lay down joint#193. PU and MU tubing hanger. Sting seals into PBR, pressure tubing to 200 psi, PU until pressure dropped off, and PU an additional 2'. 14:00 15:30 1.50 6,006 6,006 COMPZ RPCOM CRIH P Circulate the well over to 10.3 ppg corrosion inhibited NaCI/NaBr brine with 209 bbls following by 12 bbls of 10.3 ppg brine down the tubing taking returns out the IA. 15:30 16:00 0.50 6,006 6,023 COMPZ RPCOM THGR P Suck out the BOP stack, land the tubing hanger, pull old LDS, install new LDS, and RILDS. Back out landing joint and lay down. 16:00 17:30 1.50 0 0 COMPZ RPCOM PRTS P Fill the BOP stack with brine,close the blind rams, pressure test the tubing to 3000 psi for 15 minutes (good test), bleed the tubing pressure to 1500 psi, pressure test the IA to 2500 psi for 30 minutes (good test), quickly bleed the pressure off the tubing,and sheared SOV. Bleed tubing and IA to 0 psi. 17:30 18:30 1.00 0 0 COMPZ WHDBO MPSP P Open the blind rams,drain the stack, MU ISA BPV, and set the ISA BPV. Pressure up on the IA to 1000 psi to test the BPV from below in the direction of flow for 10 minutes(good test). Bleed IA to 0 psi. 18:30 19:30 1.00 0 0 COMPZ WHDBO WWWH P PU 4"joint of DP and MU BOP stacking jetting tool. Jet the stack with freshwater and flush the choke manifold. Drain the stack and blow down choke/kill lines in preparation for CPAI BOPE inspection. Page 17 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 22:00 2.50 0 0 COMPZ WHDBO SVRG P CPAI BOPE inspection per CPAI Between Well Maintenance(BWM) program: Break bolts on lower ram doors, open doors, and function ram piston to the closed position. Inspect ram cavities,sealing surfaces, and door seals. Inspect piston and rod wear plate. Inspect 2-7/8"x 5"VBR's upper seal and front packer assembly. Close lower ram doors and tighten bolts(photos taken of all components and of stack cavities). SimOps: Empty the pit and send 10.3 ppg NaCl/NaBr to 1B storage tanks 22:00 00:00 2.00 0 0 COMPZ WHDBO SVRG P CPAI BOPE inspection per CPAI BWM program: Break bolts on blind ram doors, open doors, and function ram piston to the closed position. Inspect ram cavities,sealing surfaces, and door seals. Inspect blind upper seal and front packer assembly. Upper seals on both blind rams have a little wear(photos taken of all components and of stack cavities). SimOps: Continue to empty the pit and send 10.3 ppg NaCI/NaBr to 1B storage tanks 05/24/2015 Perform CPAI BOPE inspection per CPAI Between Well Maintenance(BWM)program. ND BOPE,set back on stump, and secure for rig move. ND DSA, NU new tubing head adaptor, and NU 3-1/8"tree. PT void to 250/5000 psi. Pull BPV, install tree test plug, and PT tree to 250/5000 psi. Pull tree test plug,freeze protect the well with diesel down to 1940' MD with LRS, install BPV, and RDMO. Rig released at 23:59 hours. 00:00 01:00 1.00 0 0 COMPZ WHDBO SVRG P Close blind ram doors and tighten bolts CPAI BOPE inspection per CPAI Between Well Maintenance(BWM) program: Finish inspection on the blind rams. Close blind ram doors and tighten bolts SimOps: Clean the pits. Page 18 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 03:00 2.00 0 0 COMPZ WHDBO SVRG P CPAI BOPE inspection per CPAI BWM program: Break bolts on upper ram doors, open doors, and function ram piston to the closed position. Inspect ram cavities, sealing surfaces, and door seals. Inspect 3-1/2"x 6"VBR's upper seal and front packer assembly. Close upper ram doors and tighten bolts (photos taken of all components and of stack cavities). SimOps: Continue to clean the pits 03:00 03:30 0.50 0 0 COMPZ WHDBO SVRG P CPAI BOPE inspection per CPAI BWM program: Install 4"test joint and function annular checking for excessive wear and overall condition (photos taken of annular). SimOps: Continue to clean the pits 03:30 05:30 2.00 0 0 COMPZ WHDBO NUND P Suck out the stack. Pull the mouse hole in order to rack back the BOP on the stump. Pull riser, ND BOPE, set back on the stump, and ND DSA. SimOps: Continue to clean the pits 05:30 07:15 1.75 0 0 COMPZ WHDBO NUND P NU new tubing head adaptor and NU 3-1/8"tree. 07:15 07:45 0.50 0 0 COMPZ WHDBO PRTS P Pressure test void to 250/5000 psi for 10 minutes(good test). 07:45 08:15 0.50 0 0 COMPZ WHDBO MPSP P Pull BPV and install tree test plug. 08:15 08:45 0.50 0 0 COMPZ WHDBO OTHR P RU tree testing equipment and fill the tree with diesel. 08:45 09:45 1.00 0 0 COMPZ WHDBO PRTS P Pressure test the tree to 250/5000 psi for 5 minutes(good test). 09:45 10:15 0.50 0 0 COMPZ WHDBO OTHR P RD tree testing equipment. 10:15 10:30 0.25 0 0 COMPZ WHDBO MPSP P Pull tree test plug. 10:30 11:00 0.50 0 0 COMPZ WHDBO FRZP P RU Little Red Services(LRS)to pump freeze protect diesel. PJSM. 11:00 13:00 2.00 0 0 COMPZ WHDBO FRZP P Pressure test lines to 2500 psi.. Pump 68 bbls of diesel down the IA taking returns up the tubing at 2 BPM =1000 psi. Place tubing and IA in communication,allow the well to u-tube, and for diesel to equalize between the tubing and IA to freeze protect the well down to 1940'MD. RD LRS. 13:00 14:00 1.00 0 0 COMPZ WHDBO MPSP P RU lubricator, test to 1000 psi, set 'ISA'BPV,and RD lubricator. 14:00 15:00 1.00 0 0 DEMOB MOVE RURD P Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. Final well pressures:tubing= 0 psi, IA=0 psi, and OA= 110 psi. Page 19 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 18:00 3.00 0 0 DEMOB MOVE RURD P Prep for moving the rig. SimOps: Move satellite office and shop#1 from 3F pad to 1C pad. 18:00 00:00 6.00 0 0 DEMOB MOVE RURD P Continue to prep pit and sub to move rig. Rig released at 11:59 hours. Page 20 of 20 ` _u zi- I0 P� i$sz- Regg, James B (DOA) From: Lee, Theresa M <Theresa.M.Lee@conocophillips.com> (ZilK Sent: Thursday, May 21, 2015 3:52 PM rRi( t' To: DOA AOGCC Prudhoe Bay Cc: Nabors 9ES Co man; Rauchenstein, Rock D; Packer,J.Brett Subject: 3F-10 BOPE Usage Attachments: Well Control 3F-10 Letter.docx Good afternoon, Attached is the 10-003 BOPE Use to Prevent the Flow of Fluids from a Well report for 3F-10 on Nabors 9ES. Please let me know if you have any questions. Thank you, Theresa Lee Wells Engineer ConocoPhillips Alaska Office:907-263-4837 Cell:505-301-6483 (cCp►HiED f" 2 8 2015 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 21,2015 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, I am following up the email notification of BOPE usage on Nabors 9 ES with a written report. Time of BOPE Use: 5/21/2015 at 11:40 hours Well Location: 3F-10 API Number: 50-029-21481-00 PTD Number: 185-271 Rig Name: Nabors 9 ES ✓ Operator Contact: Theresa Lee 907-263-4837 Theresa.M.Lee@conocophillips.com Operations Summary: Today 5/21/15 at 11:40 hrs the upper pipe rams were shut in on 3F-10. We were in the process of cleaning out the perforations and were 210 strokes into a circulation when we observed a flow increase. There was no pit gain but gas and crude started to bubble up to the rotary table and the driller shut in the well. SIDPP was 20 psi and SICP was 80 psi. With the A and C sands open we are experiencing 30-40 bbl/hour losses with 10.3 ppg KWF due to zone pressure differentials,therefor we were unable to detect a pit gain. We circulated the trapped gas and crude out then observe 0 psi surface pressure. BOPE Used: Upper VBR's Reason for BOPE Use: Control flow of gas to surface Actions To Be Taken: We circulated a hole volume with 10.3 ppg brine.Well was observed to be dead by being shut in and observing zero pressures on the gauges. Plan to re-test upper VB after we trip out of the hole with the current BHA. If you have any questions or require any further information, please contact me at 263-4837. Sincerely, Theresa Lee RWO Engineer CPAI Drilling and Wells Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j_ ~_ ~ ~.~ _.( Well History File Identifier Organization RESCAN Color items: ~.,,/~. ayscale items: ''15~00r Quality Original ' DIGITAL DATA O Diskettes, No. o Other, No/Type NOTES: BEVERLY BREN VINCENT SHERYL MARIA OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds o Other LOWELL DATE: /SI Project Proofing n Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ SCANNED BY~ BEVERLY BREN VINC~ARIA LOWELL ReScanned (done) RESCANNEDBY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: PAGES: Quality Checked (done) RevINOTScenned.wpcl • ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we113F-10 (PTD 1852710). This report records the completion of the tubing ' patch repair on this well. Please call Brent Rogers or Martin Walters at 659-7224 if you have any questions. Sincerely, rent Roger Problem Well Supervisor Attachments • • v STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION `~ REPORT OF SUNDRY WELL OPERATION 1. Operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Deveiopment^ Exploratory ^ 185-271 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21481-00~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 93' 3F-10 • 8. Property Designation: 10. Field/Pool(s): ADL 25643' ALK 2574 Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 6650' feet true vertical 6218' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 3009' 9-5/8" 3102' 3042' 3520 psi 2020 psi PRODUCTION 6510' 7" 6603' 6173' 4980 psi 4320 psl Perforation depth: Measured depth: 6202'-6266', 6384'-6404', 6419'-6452' true vertical depth: 5791'-5852', 5965'-5984', 5998'-6030' Tubing (size, grade, and measured depth) 3-1/2", J-55, 6306' MD: 2-7/8", J-55, 6338' MD: 3-1/2" Weatherford tubing patch 6041' - 6090' Packers & SSSV (type & measured depth) Otis'RRH', 6118' MD Camco TRDP-1A-SSA, 1810' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 11/3/2008 ~ Form 10-404 Revised 04/2004 ~ E ~ ;,t ~ ~"~ ~+ L Submit Original Only / ~- 3F-10 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/27/08 BRUSH AND FLUSH FROM 6030' RKB- 6100' RKB. TAG AVA SLEEVE AT 6302' RKB W/ 12' x 2.72" DUMMY PATCH DRIFT 09/28/08 SET WEATHERFORD ER PACKER FOR PATCH WITH MEAT 6090' 10/07/08 10/14/08 10/17/08 10/17/08 10/18/08 10/23/08 Sum RAN ER TEST TOOL, CMIT TBG X IA TO 2500 PSI (PASSED ). WELL READY FOR PATCH INSTALL, IN PROGRESS. SET 33' SPACER/SNAP LATCH IN LOWER ER PKR @ 6090' RKB. SET 16' SPACER/SNAP LATCH/ER PKR TO COMPLETE STRADDLE PATCH ASS'Y. MIN. PATCH ID 1.75" @ 6090' RKB. TESTED UPPER ER PKR, GOOD TEST. COMPLETE. SET CATCHER ON PATCH @ 6008' SLM. PULLED DVs @ 5719', 4991' & 4624' RKB. SET 3/16" OV @ 5719' RKB. IN PROGRESS. Re-TIFL -passed, Initial T/I/0=200/900/660. Shut in well and gas lift, shot initial IA FL @ 4624' (Sta#4 OV). Stacked out tubing with lift gas, T/I/0=800/800/630. Bled IA down, shot 2nd IA FL @ same location. Final T/I/0=750/200/630. PULLED DVs @ 4249', 3636' & 2277' RKB. SET GLVs @ 4991', 3636' & 2277', DVs @ 4624' & 4249' RKB. PULLED CATCHER SUB. COMPLETE. Re-TIFL -passed, Initial T/I/0=200/900/750. Shut in well and lift gas, shot initial IA FL @ 5719' (Sta# 7 OV). Stacked out tubing with lift gas, T/I/0=800/800/750. Bled IA down, shot second IA FL @ same location. Final T/I/0=800/300/680. after BOL passed to test the GLVs. to `, ~~ KUP ~, 3F-10 CO~IOCOPI'11~~IP5 ~~ Well Attributes Alatik~ I~t: WellboreA PI/UWI FlaldNama WellStatua ProdlnJWellType Inc!(°) MD(ttKB) TD(m ax)(ft... . . 500292148100 KUPARUK RIVER UNIT PROD 31.03 4,000.00 6,650.0 Comment H23 (ppm) D ab Annoatlon End Data KB-Grd (ft) Rlg Release Date °°, SSSV: LOCKED OUT 280 7/1/2008 L25t WO: 41 79 11/29/1985 WBII -3F•10 702 3:25:07 PM . el Annotation Depth (ftK8) E nd Date Annotation Entl Data Lasi Tag: RKB 6,477.0 4/30/2008 Rev Reason: GLV GO 10/20/2008 Casin Strin s String OD String ID Set Oepth Sat Deplh (ND) SMng Wt String CONDUCTOR, Casing Oestrlptlon (In) (In) Top (RKB) (ftl(B) (RKB) (Ita/ft) Grant String Top Thrtl 715 CONDUCTOR 1 6 15.06 2 0.0 115.0 115.0 62.50 H~40 sAFETr vLV SURFACE 95/ 8 8.76 5 0.0 3,102.0 3,042.0 36.00 J-55 . 1.atn p - PRODUCTION 7 6.15 1 0.0 6,603.0 6,173.7 26.00 J-55 Tubin Strin s Sldng lM SMng ID Se[ Depth Set Depth (TVD) Stang Wt String Tubing Deecdptlon (In) (In) Top (ftKe) (RKB) (ftKe) (1ba/fl) Grant Sldng To p Thrd Gns LIFT, 2,zn h TUBING 3 1/ 2 2.99 2 0.0 6,306.0 5,890.4 9.30 J-55 8RD EUE a TUBING 2 7/ 8 2.44 1 6,306.0 6,338.0 5,921.0 6.50 J-55 SURF ~ 3,102 Other I n Hole A ll Jewel :Tubi n Run 8 Retrievable Fish etc. Top Depth (TVD) Top GA536~ lop (ftK8) I~B) Inc! (°) Dascdptlon Comment Run Dan ID (In) 1,810.0 1,809.9 0.44 SAFETY VLV Camco'TRDP-IA-SSA' (Locked Out 11/29/97) 1/20/1986 2.812 2,277.0 2,276.0 8.71 GAS LIFT CAMCO/KBUG/1/GLV/BK/.156/13151 Comment: STA 1 10/18/2008 2.875 3,636.0 3,502.6 31.03 GAS LIFT CAMCO/KBUGl1/GLV/BK/.15&13031 Comment: STA 2 10/18/2008 2.875 cAS LIFT, a,z49 4,249.0 4,028.3 30.67 GAS LIFT CAMCO/KBUG/1/DMY/BK/I/ Comment: STA 3 10/1812008 2.875 4,624.0 4,352.5 29.48 GAS LIFT CAMCO/KBUGl1/DMY/BK/// Comment: STA 4 10/1812008 2.875 GAS LIFT, 4,991.0 4,673.6 28.16 GAS LIFT CAMCO/KBUGl1/GLV/BKI.168I7330/ Comment: STA 5 10/18YL008 2.875 6.6z4 5,352.0 4,995.3 25.33 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA 6 1/22/1999 2.875 5,719.0 5,331.9 20.98 GAS LIFT CAMCO/KBUG/1lOV/BK/.188// Comment: STA 7 10/17/2008 2.875 GAS41 6,041.0 5,637.0 16.96 PATCH WEATHERFORD 3.5" ER LOWER PATCH PACKER w/JJ ' 10/1412008 1.635 ~; TIEBACK Q 6090 SE 9/28/08. STRADDLE PATCH ASSEMBLY w/SPACE PIPE SET 10/15/08. OAL 49' FOR ENTIRE PATCH min ID 1.75; SPACER PIPE min ID 1.635 6,082.0 5,657.1 16.96 GAS LIFT OTIS/LBX/1.5/PATCH/RM/// Comment: STA 8 8/24/2008 2.907 GAS LIFT, s,3sz 6,101.0 5,694.4 16.94 SBR Otis 1/2011986 3.000 6,118.0 5,710.6 18.93 PACKER OGs'RRH' 1/20/1986 2.970 cnsLIFT, 6,155.0 5,746.0 16.92 PRODUCTION CAMCO/KBUG/1/DMY/8K//I Comment: CLOSED STA9 7/31/1988 2.875 s,779 6,302.0 5,888.6 17.24 NIPPLE AVA BPL nipple "05B" 1/20/1986 2.750 6,302.0 5,888.6 17.24 SLEEVEL 2.75" AVA BPI (29') 4/30/2008 2.313 6,314.0 5,898.1 17.27 PACKER Otis'WD' 1/20/1986 4.000 6,329.0 5,912.4 17.31 NIPPLE Camco'D' Nipple NO GO 1/20/1986 2.250 Gns LIFT, 6,337.0 5,920.0 17.33 SOS Camco 1/20/1986 2.441 6,as2 6,338.0 5,921.0 17.34 TTL 1/20/1986 2.441 PATCH, 8,061 Perfora tions Shot Top(ND) Bhn (ND) Dens Top (ftK8) etm (RKB) (ftK8) (ftNB) lane Date (eh... Type Comment sea, 6,101 6,202.0 6,266.0 5,790.9 5,852.2 UNIT B, C-3, 1/19/1986 12.0 IPERF 5" Csg Gun; 120 deg ph C-4, 3F-10 6,384.0 6,404.0 5,964.9 5,984.0 A-3, 3F-10 2/18/1992 6.0 APREF 2 1/8" DynaStdp TT; 0 deg ph PACKER, 6,118 6,419.0 6,452.0 5,998.3 6,029.7 A-2, 3F-10 1/19/1986 6.0 IPERF 4" Csg Gun; 90 deg ph Notes: General 8 Safe End Date Annoation 5!18/1996 NOTE: WAIVERED WELL: IA X OA COMMUNICATION PRODUCTION, 8,155 IPERF, ' 8,2028,288 NIPPLE, 8,302 I SLEEVEL. 8,302 I I I PACKER, 8,314 NIPPLE, 8,329 SOS, 8,337 TTL. 8,338 ~ APREF, 8.384-8.409 IPERF, 6,41s-6,ssz , PRODUCTION, 8,603 TD, 6,650 • IfV~,~L L~~{.7 ~~/ Va7/Yl~~f-OL ~~- ProActive Diagnostic Services, Inc. • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Ancharage, 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: Rolxrt A. Richey 130 West International Airport. Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) Caliper Report 09,Sep-08 3F10 1 Report/ EDE j ~1S -c~~ l ~/(c~ ! ~ Signed Print Name: 50-029-21481-00 ~- yh r Date ~-' ~- ~ _~ ~' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8957 FAX: (907)245-88952 E-MAIL : pcisanchor~geCa~memorvlog.corra WEBSITE : www.meinorvlog.com C:\Documents and Settings\Owne~Desk[op\1Yansmit Catoco.doc i~ Memory MultirFinger Caliper & MT' Results Summary. Company: GonocoPhiliips Alaska, Mc. Log Date: September 9, 2008 Log No.: 8709 Run No.: 1 Pipet Desc.: 3.5" 9.3 Ib. J-55 8RD EUE Pipet Use: Tubing Pipet Desc.: 7" 26 Ib. J-55 Pipet Use: Production Casing Well: 3F-10 Field: Kuparuk State: Alaska API No.: 50-029-21481-00 Top Log lntvl.: surtace Bot. Log fntvl.: 6,138 Ft. (MD) Top Log Intvl.: 3,104 Ft. (MD) Bot. Log Intvl.: 6,130 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS The MTT data from this log has been tied into the GLM 8 @ 6,062' (Driller's Depth). This is the first time a PDS Multi-Finger Caliper and 12 Arm Magnetic Thickness Tool (MTT) has been run in this well. The MTT responds to the total thickness of metal of the 3.5" tubing and 7" production casing. A single pass at 8Hz was made at 20 fpm ftom surtace to 6,130'. The additional metal volume of the 9.625" surface casing interferes with the normal function of the MTT, so no interpretable results are available from the end of the 9.625" surtace casing (3,104') to surtace. ' INTERPRETATION O~ CALIPER LOG RESULTS This log was run to assess the condition of the 3.5" tubing logged with respect to intemal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing logged is in good condition, with no si ni i nt > - > ° ~ "on r g fca wall penetrations ( 15%), areas of sigrnficant cross sectional wall loss ( 6 /o), or LD. restneti s recorded. Caliper recordings indicate slight buckling throughout the interval logged. The Work Request indicates a leak in the tubing at 6,080'. A 3-D log plot of the caliper recordings across this interval is included in this report. 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 15%) are recorded throughout the interval logged. 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the interval togged. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the interval logged. ii ~ ProActive Diagnostic Services, Inc. / P.O. Bax 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: 1281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~~~ -~~ l` tl ~~~ • • INTERPRETATION OF MTT LOG RESULTS A graph of the change in metal thickness on a joint-by joint basis relative to the calibration point is included in this report. The Average Metal Thickness Relative to the Calibration Point graph indicates relative metal loss ranging from 1 °~ to 6°~ throughout the logged interval. A maximum average relative metal loss over an entire joint interval of 6% is indicated in Jt. 174 (5,325' - 5,352'}. A 2" scale log plot of the MTT recordings at 8Hz from 3,104' to 6,130' is included in this report. The Delta Metal Thickness (%} curve in this plot refers to total metal surrounding the MTT tool, which includes both the tubing and casing strings. The majority of the MTT recordings appear to correlate with the minor damage to the interior of the tubing recorded by the caliper. The MTT recordings of intervals of minor metal loss from 4,224' to 4,243', 5,365' to 5,388', 5,454' to 5,498', 5,538' to 5,583' and 5,910' to 5,940' may reflect metal loss from the exterior of the tubing, the casing or both. 6% circumferential metal loss is recorded in Jt. 198 (6,075' - 6,106'}. The Log Plot of the data shows the configuration of the metal loss as appearing in areas of general corrosion and areas of isolated metal loss. These terms are used to describe the pattern of high frequency responses indicated in the 12 individual sensor recordings. The term General Metal Loss is used to describe intervals where the overall average change in metal volume indicates a significant change in overall metal volume, regardless of any patterns of high frequency response in the individual sensor recordings. It is assumed that shifts in the overall metal thickness curve represent more significant areas of metal loss than those represented by the patterns of high frequency responses indicated in the individual sensor recordings. In this log, the MTT was calibrated downhole (5,517'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing and 7° production casing. Field Engineer: K Miller Analyst: HY Yang Witness: S. Ferguson ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~Lamemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot ~~ S ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3F-10 Date : September 9, 2008 Description : Detail of Caliper Recordings Across Tubing with Leak at 6,080' • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (26.7' - 6130.8') Well: 3F-10 Field: Kuparuk Company: ConocoPhigips Alaska, Inc. Country: USA Survey Date: September 9, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 48 25 767 50 C 1536 GLM 1 75 2312 100 3066 ~ v E ~ ~ ._ GLM 2 s ~ ~ 125 3829 a~i o p GLM 3 GLM 4 4599 GLM 5 GLM 6 5359 GLM 7 GLM 8 _, 199 6131 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 199 • • PDS Report Overview ~, ~.. Body Region Analysis Well: 3F-10 Survey Date: September 9, 2008 Field: Kuparuk Tool Type: MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 2.992 ins 3.5 ins 6.0 ins 0.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body : metal loss body 150 100 50 0 0 to 1 to 1% 10% 10 to 20 to 40 to over LO% 40% 85% 85% Number of'oints anal sed total = 203 pene. 0 97 loss 98 105 106 0 0 0 0 0 0 0 Damage Configuration (body ) 20 10 0 isolated general line ring hole /puss pitting corrosion corrosion corrosion ible hale Number of ~oints darna ed total = 20 20 0 0 0 0 Damage Profile (% wall) ~ penetration body ;~,,,.;, metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM 8 Bottom of Survey = 199 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf }55 Wel: 3F-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiMips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: SeplQmber 9, 2008 Joint No. Jt. Depth (Ft,) I'c~n. Ul~~c~t (Ins.l Pen. Body (Ins.) Pen. `;4, wl~~t.~l I ~ ~.~ ,~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 27 t1 0.01 5 I 3.00 PUP .2 31 tt 0.01 5 I 2.98 PUP .3 42 U 0.03 I u 2.91 PUP 1 48 t~ 0.02 £3 -1 2.93 Lt. De sits. 2 78 t t 0.02 <~ ~ 2.94 3 108 U 0.02 I 2.96 Lt. De sits. 4 139 t? 0.02 ~i ~ 2.93 Lt. De osits. 5 168 to 0.02 ~) I 2.94 6 197 t1 0.02 ~~ ~~ 2.95 7 226 n 0.02 <, I 2.95 8 256 t) 0.02 ~? 2.94 Lt. De sits. 9 286 a 0.03 I1 .94 10 31 S t l 0.03 1 t ~ I 2.92 LL De sits. 11 343 t ~ 0.02 `~ ~' 2.95 12 373 U 0.02 ~> 2.95 13 402 t~ 0.02 ~~ -l 2.94 14 432 l) 0.03 11 _' 2.95 15 461 t) 0.02 ~) I 2.95 16 489 t~ 0.02 ~) 2.94 17 520 tl 0.02 £3 2.94 18 551 i ~ 0.02 -1 2.95 19 581 U 0.03 1 U _' 2.94 Lt. De its. 20 613 U 0.03 1:1 -4 .95 Shallow itUn . 21 643 t ~ 0.03 1 U ? 2.96 22 673 U 0.02 ~~ I 2.94 23 705 t~ 0.02 ~~ 2.95 24 736 a 0.03 I U 2.94 25 767 U 0.02 ~~ -~! 2.93 Lt. De sits. 2 798 U 0.02 ~~ a 2.95 27 829 t) 0.02 t3 ! ~ 2.97 28 861 O 0.02 0 ~ 2.96 29 892 a 0.02 y _' 2.95 30 923 U 0.03 1 U ~ 2.92 31 954 U 0.03 1 t) ~ 2.94 32 984 U 0.03 11 2.94 33 1013 t 1 0.03 1 I 2.93 34 1044 (! 0.03 11 2.95 35 1075 i~ 0.03 1(1 4 2.95 36 1106 a 0.03 11 5 2.97 - 37 1135 i~ 0.03 11 ~ 2.96 38 1166 t1 0.03 12 _' 2.88 Lt. De osits. 39 1198 (1 0.03 11 I 2.92 40 1228 U 0.03 Il 2.94 41 1260 t ~ 0.03 I Z 2.93 42 12 1 u .0 I I -I 5 43 1320 i) 0.03 I I 2.91 Lt. De sits. 44 1349 t I 0.03 I 1 2.93 45 1381 U 0.03 11 ! 2.95 46 1412 U 0.03 1 t) 4 2.93 Lt. De sits. 47 1444 U 0.03 11 ~ 2.93 Lt. De osits. _ Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf }55 Wel: 3F-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 9, 2008 Joint No. Jt. Depth (Ft.) P~•n. IJInFt (Ins.) Pen. Body (Ins.) Pc~n. %> Mel,il I ~~ss ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 48 1475 t) 0.03 10 I 2.93 49 1506 t) 0.03 1 1 I 2. 3 50 1536 U 0.03 1O ~ 2.94 51 1567 ~ ~ 0.03 1 1 s 2.95 52 1595 t ~ 0.03 I t) ' 2.93 3 1627 t) 0.02 ~~ ? 2.96 S4 1656 ti 0.03 11~ 2.93 5 1688 t) 0.02 c) ) 2.96 56 1719 O 0.02 ~~ 3 2.95 57 1750 U 0.02 ~? ~ 2.93 58 1778 O 0.02 ti ~ 2.96 58.1 1807 ~) 0 U 0 2.81 Camco TRDP-IA-SSA' SSSV 59 1822 t) 0.03 12 ~ 2.95 60 1853 U 0.02 ~~ -t 2.96 61 1883 l) 0.03 I t) 5 .95 62 1911 t) 0.02 ~~ 4 2.96 63 1940 U 0.03 I ~ 1 2.93 Shallow itfin . 64 1971 U 0.03 I? 1 2.92 Shall w itUn . 65 2001 t~ 0.04 14 1 2.92 Shallow itU 2032 0 0.03 I_' 1 92 67 2063 t) 0.03 13 _' 2.93 Shallow itrin . 68 2094 t) 0.03 I 1 ~' 2.95 69 2124 n 0.03 1 u 2.95 70 2155 U 0.03 12 _' 2.95 71 2186 t) 0.04 15 _' 2.94 Shallow it ~n . 72 2216 U 0.03 11 ! 2.94 73 2247 U 0.02 ~) i 2.96 73.1 2276 t) 0 0 t) N A GLM 1 Latch ~ 4:00 74 2284 t? 0 02 9 ~' 2.94 75 2312 t) 0.03 11 1 2.93 76 2341 a 0.03 11 3 2.94 77 2371 t) 0.03 12 ? 2.92 Lt De sits. 78 2402 t) 0.03 11 1 2.94 79 2433 t) 0.03 1O 2 2.95 80 2463 U 0.02 ti a 2.94 81 2495 U 0.03 1l) ~ 2.95 82 2526 I) 0.03 1 ~ 1 2.93 Shallow itUn . 83 2557 (~ 0.03 11 2 2.94 84 2587 t~ 0.03 I2 1 2.91 85 2616 U 0.03 1 t) I 2.93 86 2645 t) 0.03 10 I 2.93 Lt. De sits. 87 2676 a 0.02 9 I 2.94 88 2705 U 0.02 9 I 2.93 89 2 73 7 U 0.02 t3 I 2.94 90 2 7 U 0.02 ~) ~ 94 91 2798 U 0.02 8 2 2.93 92 2829 t) 0.03 11 ? 2.90 Lt. De osits. 93 2859 U 0.03 I1 1 2.93 94 2888 i? 0.02 ~) I 2.94 95 2919 i? 0. 3 11 I 2.93 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf }55 Wel: 3F-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Cornpany. ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 9, 2008 Joint No. )t. Depth (Ft.) I'c~n. UI~.<~t (Irn.) Pen. Body (Ins.) I'c~n. °4, ~~1ct.~l Lcxs °i, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 2949 U 0.03 11 1 2.94 97 2978 U 0.02 ~) 1 2.94 98 3007 ~~ 0.03 11 I 2.93 99 3036 O 0.03 11 _' 2.94 100 3066 U 0.03 I ? t t 2.89 t. De sit . 101 3094 a 0.03 11 ~ 2.95 102 3124 t 1 0.03 1 u I 2.93 103 3154 U 0.03 1 ~' 3 2.91 Lt. a sits. 104 3184 l) 0.03 1 I 1 2.94 105 3214 t t 0.03 I _' 2.92 106 3245 U 0.03 lI _' 2.93 107 3275 i ~ 0.03 I ? 2.93 Shallow itti 108 3306 i I 0.03 I ~ 2.95 109 3337 t ~ 0.03 I I i 2.93 110 3368 a 0.03 I Z I 2.93 111 3399 t I 0.03 13 I .91 Shallow itUn . 112 3429 It 0.03 12 tl 2.92 11 3459 tt 0.03 1 1 1 2.92 Lt. De sits. 114 3489 U 0.03 12 _' 2.94 1 5 3 19 t t 0.03 12 1 2 93 116 3548 tI 0.04 15 2.9 Shallow it6n . 117 3578 t i 0.03 I I I 2.93 118 3610 It 0.02 ~) _' 2.95 118.1 3641 tI 0 li U N A GLM 2 Latch @ 4:00 11 3647 tl 0.0 l:> .92 120 3677 U 0.03 1 Z i 2.93 121 3707 a 0.03 12 I 2.92 122 3738 tI 0.03 11 3 2.94 123 3769 U 0. 2 ~) 1 2.94 124 3798 t I 0.02 ~t I 2.93 125 3829 U 0.03 I t ~ I 2.92 126 3858 a 0.03 I1 ~ 2.93 127 888 t I 0.03 1 ~~ I 2.94 128 3918 U 0.02 ~~ 2.95 129 3949 U 0.02 ~) I 2.94 130 3980 U 0.04 14 tt 2.89 Shallow ittin . 131 4012 t) 0.03 1 ~ I 2.90 Shallow itUn . 132 4042 t t 0.02 ti t ~ 2.93 133 407 i ~ 0.03 I Z I 2.93 134 4103 tt 0.04 I.1 I 2.91 Shallow itUn . 135 4133 a 0.03 t l I 2.94 136 4164 l1 0.03 1 1 2.92 Lt. De sits. 137 4193 tt 0.03 13 2.94 Shallow itUn . 138 4224 a 0.03 1 Z ~' 2.93 138.1 4255 U 0 tl t) N A LM Latch ~ 10:30 139 4262 U 0.02 ~) (1 2.92 140 4293 t ~ 0.03 I 1 I 2.93 141 4324 ~ ~ 0.03 1 I I 2.93 142 4356 0.03 II I 2.91 143 4386 0.03 I t ~ 2.94 _ Penetration Body McPal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 Wetl: 3F-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhitlips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: Sep~mber 9, 2008 Joint No. Jt. Depth (Ft.) Pen. Ul~s~~t (ln,.) Pen. Body (Ins.) I'c~n. `%> Met~~l Loss ",'~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4415 (~ 0.03 11 1 2.93 145 4444 U 0.03 11 1 2.92 146 4475 O .02 ~? I) 2.91 147 4506 U 0.02 t ~ ~ ? 2.92 148 4536 U 0.03 I 1 U 2.90 Lt. De sits. 149 4568 U 0.03 I Z 2.94 150 4599 ~) 0.03 I I 2.92 150.1 4630 u 0 U :: N A CLM 4 Latch ~ 10:30 151 4636 a 0.03 1:3 I 2.91 Shallow itUn . 152 4668 a 0.03 11 _' 2.93 153 4698 !) 0.03 I _' I 2.92 154 4729 !) 0.03 1 1 2.93 155 4759 U 0.04 15 ! 2.91 Shallow it6n . 156 4789 tl 0.03 1 _' I 2.92 157 4821 a 0.03 1 Z ~ 2.92 Lt. De osits. 158 4850 !) 0.02 ~) 1 2.90 159 4879 O 0.03 1 I I 2.92 160 4911 a 0.02 ~~ I 2.92 161 4941 O 0.03 11 I 2.91 162 970 O .03 1 I .93 162.1 4992 !) 0 l) (~ N A GLM 5 Latch ~ 12:30 163 5001 (1 0.02 ~> 2.93 164 5028 l) 0.03 1 ~ I 2.90 Lt. De sits. 165 5057 ~) 0.03 12 1 2.93 166 5085 U 0 03 1 1 1 .91 167 5114 O 0.03 10 1 2.93 168 5142 !) 0.03 1:5 O 2.93 Shallow ittin . 169 5173 O 0.03 Il ? 2.94 170 5204 I) 0.04 14 I 2.92 Sallow itUn . 171 5235 I) 0.02 t1 ~) 2.93 172 5264 U 0.03 1 Z tl 2.90 173 5293 U 0.02 8 I 2.92 174 5325 U 0.03 12 1 2.93 174.1 5354 !) 0 O n N A GLM 6 Latch ~ 7:00 175 5359 n 0.01 i a 2.94 176 5390 ! ~ 0.02 I 2.94 177 5419 a 0.03 1 U n 2.91 178 5450 i ~ 0.03 1 ~ 2.95 Shallow itUn . 179 5480 O 0.02 ~) 2.93 180 5510 c) 0.03 It) 1 2.93 181 5539 O 0.02 ~) 2.95 182 5567 a 0.02 1 2.94 183 5598 a 0.03 I1 I 2.92 184 5629 U 0.02 9 u 2.91 185 565 t) .02 ~) 1 .92 186 5690 a 0.03 1 ~ 1 2.93 186.1 5720 O 0 U ~~ N A LM 7 Latch C~ 8:30 187 5726 O 0.02 9 3 2.94 188 5756 (~ 0.03 12 2.93 189 5787 ~ ~ 0.03 1 1 I 2.93 Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf }-55 We9: 3F-10 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiGips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: September 9, 2008 Joint No. Jt. Depth (Ft.) I'cn. Ul,tic•t (In,.l Pen. Body (Ins.) PE°n. °ro ~1c•i,~l I ors ",~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 190 5818 ~) 0.02 ~~ _' 2.94 191 5849 a 0.01 ~ 2.94 192 5880 a 0.02 ~~ I .93 193 5911 ~ ~ 0.02 ti I .93 194 5941 (~ 0.02 I 2.93 195 5972 U 0.02 ~~ _' 2.95 196 6003 c I 0.03 1 <' ~ 2.93 197 6034 U 0.02 i I 2.93 197.1 6062 t1 0 t) U N A GLM 8 Latch @ 3:00 198 6076 U 0.03 1 9 I 2.93 Shallow itUn . 198.1 6106 t) 0 U (1 3.00 Otis SBR 198.2 6122 ~? 0 U ~~ 2.97 Otis' RH' Packer 198.3 6124 U 0.02 ti I 2.92 PUP Lt. De osits. 199 6131 ~ ~ 0.01 b 2.92 _ Penetration Body Metal Loss Body Page 5 Average Recorded Metal Thickness Relative to Calibration Point 3.5" Tubing / 7" Production Casing Well: 3F-10 Field: Kuparuk Company. ConocoPhilips Alaska, Inc. Country: USA Survey Date: Sep~mber 9, 2008 ^ D ecrease ^ In crease 110 3368 GLM 2 120 3677 130 3980 GLM 3 140 4293 ~ v ~ GLM 4 4599 'i ~ .~ Z y c ~ fl- v ~ 160 4911 GLM 5 170 5204 GLM 6 180 5510 GLM 7 190 5818 GLM 8 198.2 6122 - 50% 0 5 0% C hange in Metal Thick ness (% ) Bottom of Su rvey = 198.2 • • ~~ Average Difference in Metal Thickness Relative to Calibration Point Well: 3F-10 Survey Date: September 9, 2008 Field: Kuparuk Tool: UW MTT 51754 Company: ConocoPhillips Alaska, Inc. Tubing: 3.5" 9.3 Ib J-55 SRD EUE Country: USA Casing: 7" 261b. J-55 Joint. No Depth ft. %Delta Mtl Thck Comments ti o ~ o i n o Joint. No Depth ft. %Delta Mtl Thck Comments N o ,, , o ~ , o 101 3104 4 General Corrosion 149 4568 0 General Corrosion 102 3124 2 General Corrosion 150 4599 -2 General Metal Loss 103 3154 4 General Corrosion 150.1 4629 23 GLM 4 104 3184 5 General Corrosion 151 4637 -2 General Metal Loss 105 3214 5 General Corrosion 152 4669 0 General Corrosion 106 3245 5 General Corrosion 153 4698 -3 Isolated Metal Loss 107 3276 2 General Corrosion 154 4728 -1 General Metal Loss 108 3307 5 General Corrosion 155 4758 0 General Corrosion 109 3337 4 General Corrosion 156 4790 2 General Corrosion 110 3368 3 General Corrosion 157 4822 ~ General Metal Loss 111 3399 4 General Corrosion 1 58 4850 3 General Corrosion 112 3429 3 159 4880 0 General Metal Loss 113 3459 2 General Corrosion 160 4912 4 General Corrosion 114 3490 2 General Corrosion 161 4942 -3 General Metal Loss 115 3519 1 General Corrosion 162 4970 1 116 3548 -3 General Metal Loss 162.1 4994 23 GLM 5 117 3578 1 General Corrosion 163 4999 2 General Corrosion 118 3610 3 General Corrosion 164 5029 4 General Corrosion 118.1 3640 26 GLM 2 165 5057 3 General Corrosion 119 3647 2 General Corrosion 166 5085 0 General Corrosion 120 3677 1 167 5115 -3 General Metal Loss 121 3707 1 General Corrosion 168 5142 0 General Corrosion 122 3738 4 169 5174 1 General Corrosion 123 3770 1 General Corrosion 170 5204 -1 General Metal Loss 124 3799 1 General Corrosion 171 5235 2 General Corrosion 125 3829 -1 General Metal Loss 172 5265 1 General Corrosion 126 3858 0 General Corrosion 173 5293 0 General Corrosion 127 3889 4 General Corrosion 174 5325 -6 General Metal Loss 128 3918 4 General Corrosion 174.1 5352 26 GLM 6 129 3950 4 General Corrosion 175 5361 0 General Corrosion 130 3980 2 General Corrosion 176 5391 -2 General Metal Loss 131 4012 0 177 5419 ~ General Metal Loss 132 4042 5 General Corrosion 178 5450 -2 General Metal Loss 133 4073 3 General Corrosion 179 5480 -2 General Metal Loss 134 4103 3 General Corrosion 180 5510 -2 General Metal Loss 135 4133 5 General Corrosion 181 5539 0 General Corrosion 136 4164 2 General Corrosion 182 5567 3 General Corrosion 137 4194 4 General Corrosion 183 5598 -2 General Metal Loss 138 4225 1 General Corrosion 184 5629 -3 General Metal Loss 138.1 4255 24 GLM 3 185 5658 -1 General Metal Loss 139 4261 2 General Corrosion 186 5689 -3 General Metal Loss 140 4293 1 General Corrosion 186.1 5719 24 GL.M 7 141 4324 1 General Corrosion 187 5727 -1 General Metal Loss 142 4355 2 General Corrosion 188 5756 -2 General Metal Loss 143 4386 1 General Corrosion 189 5787 3 General Corrosion 144 4414 3 General Corrosion 190 5818 3 General Metal Loss 145 4444 1 General Corrosion 191 5849 -3 General Metal Loss 146 4476 0 Isolated Metal loss 192 5880 3 General Corrosion 147 4507 -2 General Metal Loss 193 5912 -1 General Metal Loss 148 4537 -2 General Metal Loss 194 5941 -1 General Metal Loss Page 1 • ~~~ Average Difference in Metal Thickness Relative to Calibration Point Well: 3F-10 Survey Date: September 9, 2008 Field: Kuparuk Tool: UW MTT 51754 Company: ConocoPhillips Alaska, Inc. Tubing: 3.5" 9.3 Ib J-55 8RD EUE Country: USA Casing: 7" 261b. J-55 Joint. No Depth ft. % Delta Mtl Thck Comments N o ~ ~ o N o Joint. No Depth ft. % Delta Mtl Thck Comments N o ~ o ~ o 195 5972 -1 General Metal Loss 196 6003 0 General Metal Loss 197 6035 -1 General Metal Loss 197.1 6064 27 GLM 8 198 6075 -5 General Metal Loss 198.1 6106 ~1 SBR 198.2 6111 59 Packer Page 2 oint 114 Joint 115 Join General Metal Lo,,,. Joint 117 3600 Joint 118 ~GLM 2~ Joint 119 Joint 120 3700 Joint 121 Joint 122 Metal Joird 123 ~~ Joint 124 Joint 125 Joint 126 i Joint 127 r Joint 128 Joint 129 Joint 130 4000 i General Metal Los Joint 131 Joint 132 General Corrosio - Joint 133 eneral Corrosion n~ Joint 134 Joint 135 Joint 136 General Corrosio 4~ Joint 137 - - --- - - --- - Joint 138 w Joint 139 eneral Corrosio 4300 Joint 140 Joint 141 eneral Corrosio eneral Corrosio Joint 142 .Joiner --- Joint 144 General Corrosio Joint 145 eneral Corrosio Isolated Metal Los Joint 146 4500 General #' ~ '' General Joint 147 Metal Loss Joint 148 Metal Loss Joint 149 General Metal Loss I I I I Joint 150 General Metal Lo~oint 151 Joint 15^ Joint 153 Joint 154 Joint 155 Hann Joint 156 General Metal Loss~int 157 Joint 158 Joint 159 4900 Join Joie General Metal Loy., Joie ~GLM 5~ Joint 163 Jor~ Joint 1G5 Joie --- ~ General Metal Loss. -,-,T-, .,mint 167 Metal Joint 168 Joint 169 Joint 170 Joy Joint 17~ 5~ Joint 173 General Metal Loss~i Joint 175 Joie 177 Joint 178 Joint 179 General Metal Loss 5500 Joint 180 Joint 181 Joint 18~ Metal Lossoint 183 Metal Lo~Joint 184 Joint 185 General Metal L .,oint 186 ~ GLM 7 _ _ eneral Me tal L oss~in e nera l Metal L oss~int 188 Joint 189 Joint 190 General Metal LosJoint 191 Joint 192 eneral Corro sio Delta Meta! Th ickness Joint 193 Line Spe General Metal Loss Joint 194 Casin Collar T ubing Collar~~ Joint 195 `~? ubing Collar Casing Co llar Joint 196 Tubing Collar Joint 197 Casing Col lar G~ 6 % M etal Loss ~ Joint 198 Casin Collar Ge nera l Me tal L oss 6100 ~Packer~ -50 Delta Metal Thickness (%) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) -200 -6.8 MTTP12 (rad) 3.2 ConocoPhillips Alaska, Inc. KRU 3F-10 3F-10 API: 500292148100 Well T e: PROD An le TS: 17 de 6201 sssv SSSV Type: LOCKED OUT Orig 1129/1985 Angle @ TD: 18 deg @ 6650 Com letion: (1s1a1s11, OD:3.500) Annular Fluid: Last W/O: Rev Reason: SET JET PUMP Reference Lo Ref L Date: Last U ate: 728/2006 Last Ta : 6479' RKB TD: 6650 ftlC6 Gas Lift Last Ta Date: 4/5/2004 Max Hole An le: 31 d 4000 MarWrewaMe 1 Casin Strin -ALL STRINGS (zz77-zz7a, Deaai lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 Gas Lin SURFACE 9.625 0 3102 3042 36.00 J-55 MantlrewaNe z - PRODUCTION 7.000 0 6603 6174 26.00 J-55 (3636-3637 Tubin Strin -TUBING , I Size To Bottom TVD Wt Grade Thread Gas Lift 3.500 0 6306 5890 9.30 J-55 8RD EUE Mandrewahe 2.875 6306 6338 5921 6.50 J-55 3 (4249-4250 Perforations Summa , ( Interval TVD Zone Status Ft 3PF Date T Comment Gas Lift MandrewaMe 6202 - 6266 5791 - 5852 ,C~,C-1,U B 64 12 1/19/1986 IPERF 5" Csg Gun; 120 deg ph 4 (4624-4625, I 6384 -6404 5965 - 5984 A-3 20 6 2/18/1992 APREF 2 1!8" DynaStrip TT; 0 deg h 6419 - 6452 5998 - 6030 A-2 33 6 1/19/1986 IPERF 4" Cs Gun; 90 d h Gas Lift M andrel sNalves St MD ND Man Mfr Men Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2277 2276 Camco KBUG GLV 1.0 BK 0.156 1248 421/2004 2 3636 3503 Camco KBUG GLV 1.0 BK 0.188 1294 421/2004 3 4249 4028 Camco KBUG GLV 1.0 BK 0.250 1394 421/2004 4 4624 4352 Camco KBUG OV 1.0 BK 0.250 0 4212004 5 4991 4674 Camco KBUG DMY 1.0 BK 0.000 0 120/1986 6 5352 4995 Camco KBUG DMY 1.0 BK 0.000 0 122/1999 7 5719 5332 Camco KBUG DMY 1.0 BK 0.000 0 120/1986 8 6062 5657 Otis LBX Marla DMY 1.5 RM 0.000 0 8/62002 Production Mand relsNalve s St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 9 6155 5746 Camco KBUG DMY 1.0 BK 0.000 0 7x31/1988 Closed Other lu s ui .etc. -JEWELRY sBR De th ND T Descri lion ID (6101-6102, OD:3.500) 1810 1810 SSSV Camco'TRDP-IA-SSA' Locked Out 1129/97 2.812 6101 5694 SBR Otis 3.000 6118 5711 PKR Otis'RRH' 2.970 PKR (sllasn9, 6302 5887 PUMP 3" R.C. JET PUMP 16 RATIO, #16 NOZZLE, #15 THROAT, SM# PH - 1016. set?/262006 0.000 oD:s.151) 6302 5887 SLIPSTOP SLIPSTOPset5252004 3.000 6302 5887 NIP AVA BPL ni le "05B" 2.750 6314 5898 PKR Otis'WD' 4.000 6329 5912 NIP Camco'D' Ni le NO GO 2.250 6337 5920 SOS Camco 2.441 6338 5921 TTL 2.441 General No Pert Date Nose (szo2-szss) 5/18/1996 WAIVERED WELL: IA X OA COMMUNICATION TUBING 2/14/199 Hard fill to w/CTU cleanout 6467' CTM (0-6306, OD3.500, ID:2.992) PKR (6314-6315, OD:6.151) NIP (6329-6330, OD:2.875) TUBING (6306-6338, OD:2.875, ID:2.441) Pert (6384-6404) Pert (6419-6452) 09/15/08 il~~l~Fii~ie~~ N0.4871 Schlumberger -DCS ~_. ~ ~ ~ ~ „., t'~(~r) 2525 Gambell Street, Suite 400 ~ Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 . ;, . Attn: Christine Mahnken ATTN: Beth ti~~~,~;~ ~ ~~~ ~~ ~ ~ 333 West 7th Ave, Suite 100 ~. ~,~,~~~ ~ ~- ;~ `~ ~:~ ~~~~ Anchorage, AK 99501 Field: Kuparuk • Wetl Job # Log Description Date BL Color CD -1 1C-172A 11978478 PRODUCTION PROFILE t- ~- 08/19/08 1 1 1C-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT (~ - /(n 9iL/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~ aO~S -Q~ ~ I ~GI /~ 08/27!08 1 1 2U-06 12080428 ~ LDL -p( '~ 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE ~ =Q 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - j~( ! Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE ~ (p 09/05/08 1 1 1C-174 12096539 INJECTION PROFILE - p 09/07/08 1 1 2H-i2 12096540 PRODUCTION PROFILE - ` 09/09/08 1 1 30-01 11975792 LDL '~-Q'~ 09/09/08 1 1 3F-10 11975789 LDL ( 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 3F-10 (PTD 1852710) Report of~ communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, September 08, 2008 6:19 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 3F-10 (PTD 1852710) Report of TxIA communication Attachments: 3F-10 schematic.pdf; 3F-10 90 day TIO plot.jpg Tom, Jim Kuparuk gas lifted producer 3F-10 (PTD 1852710) has been identified to have TxIA communication. The well was secured to chance out the tree valves, and while attempting to unsecure the well TxIA communication was identifi An Eline LDL log was run and identified the tubing leak at 6080', right below Sta #8. The current TIO is 350/50/500. The well remains secured with a WRP plug that was set for changing out the tree valves and will remain SI until repaired. The next actions will be to run a caliper survey and evaluate the tubing for repair. A 10-404 will be submitted if the tubing can be patched. Attached is a 90 day TIO plot and wellbore schematic. ~ «3F-10 schematic.pdf» «3F-10 90 day TIO plot.jpg» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~,~~- ~~~'~~ r~.F ~' ~. 200 ~, .~. 12/10/2009 KRU 3F-10 PTD 1852710 9/8/2008 TIO Pressures r ~~ , ~, ~ 3F 10 - -- - ~CanocoPhiilips ,W Attributes_ _ _ Wcllbore API,U::; Field Name Nlell Status Maximum Incllnatlon (°) Totel Depth (RKB) ~' ;' 500292148100 KUPARUK RIVER UNIT ROD 31.03 6,603.0 ~~ Comment H2S (ppm) Date Annotation End Date - KB~Grd (ft) Rlg Release Date I I C ' f 3 F 10 710 7 - P M ___.-B LOCKED OUT .. 280 7/12008 41.79 1129/1985 W r t o -- ''--' h aN„ qc I --'- 5 A otulion Depth (RKB) End Date Annotation End Date _ _ Last Tay 6,477.0 4/302008 Rev Reason: TAG, PULL PUMP, set BPI _ 7/132008 _ ~ CasingStrinJs ! -_-': j I li ~ DONDUCTOR ' Casing Description OD (in) ____ ID (in) Top (RKB) Set Depth (RKB) _ Set Depth (ND) (RKB) Wt (Ibs/ft) Orade Top Threa d , 175 r j ~ ~ CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H-40 d SURFACE 95/8 8.765 0.0 3,102.0 3,042.0 36.OO J-55 sssv,7sln ~. o ~ PRODUCTION 7 6.151 0.0 6,603.0 6,173.7 26.00 J-55 • ' ' ~ _.- Tubing Strings - --- T -- -- Set Depth _ Tubing Dascdption OD (n) ID (In) To (RKB) (RKB) Set De th ND) (RKB) Wt Ibs/ft) Grade Top Threa d Gns uFT. °' , ~y TUBING 3 1/2 2.992 0.0 6,306.0 5,890.4 9.30 J-55 SRD EUE z,2n "°°-~ TUBING 27/8 2.441 6,306.0 6,338.0 5,921.0 6.50J-55 suRF I O l b ng Ru eta I C I a ry 3 i~ ~. cdptl oo I 1 . , 1P S10 0 SSSV T Out 1129/97) 1ASSA (Lock d Camco R DP-- D 0 C 120/1986 2.812 GAS31 a ` ~ ~ ~ ~I 2,277.0 GAS LIFT CAMCO/KBUG/1/GLV/BK/.156/1248/Comment: STA 1 4/212004 2.875 (--~ 1-,° 3,636.0 GAS LIFT CAMCO/KBUG/1/GLV/BK/.1 8 811 294/Comment: STA2 4/212004 2.875 ' ~ 4,249.0 GAS LIFT CAMCO/KBUGl1/GLV/BK/.25/1394/ Comment: STA 3 4/21/2004 2.875 GAS UFT - i_, 4,624.0 GAS LIFT CAMCO/KBUG/1/OV/BK/.25//Comment: STA4 421/2004 2.875 , a,24s 'y v ~ 4,991.0 GAS LIFT CAMCO/KBUG/1/OMY/BK///Comment: 5TA5 1/20/1986 2.875 ' q 5,352.0 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA 6 1/22/1999 2.875 ~.- ..iy 5,719.0 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment: STA7 120/1986 2.875 Gns uFT, r-~ 062 6 0 GAS LIFT 5/DMY/RM///Comment: STA8 OTIS/LBX/1 8/6/2002 2.907 4,624 ~ . , . ~ - I• 6,101.0 SBR Otis 1/20/1986 3.000 ~ --1-' 6,118.0 PACKER Otis'RRH' 120/1986 2.970 GAS LIFT, r 6 155 0 PRODUCTION CAMCO/KBUG/1/DMYBK///Comment: CLOSED STA9 7/31/1988 2.875 4,991 ~ ~~ , . 6,302.0 NIP AVA BPL nipple "058" 120/1986 2.750 6,302.0 SLEEVE-0 2.75" AVA BPI (29") set 4/30/2008 4/302008 2.313 GAS LIFT, , 1. ~ 6,314.0 PACKER OUs'WD' 120/1986 4.000 5,362 '~~ f 6,329.0 NIP Camco'D' Nipple NO GO 120/1986 2.250 , 6,337.0 SOS Camco 120/1986 2.441 ~ ' 6 338 0 TTL 120/1986 2.441 GAS LIFT, { , . -- _- aaly 5.779 ':. ~'~ `- ~ ._ Perforations _. __- _ -_ __ ___ _- _ Shot ~ ~ Top (ND) Btm (ND) Dena .n ~ GAS LIFT ~ Top (RKB etm (RKB) (RKB) (RKB) Type Zone (shot... Date Comment , aa~M 6 062 202.0 6 6,266.0 5,790.9 5,852.2 IPERF UNIT B, C-3, C-4, 12.0 1/19!1986 5" Csg Gun ; 120 deg ph . ~ , 3F-10 ~ ~ 6,384.0 6,404.0 5,964.9 5,984.0 APREF A-3, 3F-10 6.0 2/18/1992 2 1/8" DynaSirip TT; 0 deg ph SBR, 6,101 ~ '' 6,419.0 6,452.0 5,998.3 6,029.7 IPERF A-2, 3F-10 6.0 1/1911986 4" Csg Gun; 90 deg ph Notes: General S~ Saft.~_ _ _ EuU Late Annotation - 5/18/1996 NOTE: WAIVERED WELL: IA X OA COMMUNICATION PACKER. 6,118-- f-+.~.~tin ~<'f„t.:~ _ . ..'~ PRODUCTION, - ~ ~i) 6,155 ,., ~ IPERF, 6,2026,266 - NIP, 6,302 ~ ~ ~ I' SLEEVE-C, ~ ~ 6,302 I L _i PACKER, 6,314 ~.v'~(s47"R:~a9 1 , I NIP, 6,329 ~ -~ SOS, e337 -•~ tFt ~ TTL, 6,338 i ~ { APREF. ~ ~ Q3846,404 IPERF, ~ I 6,419-6,452 PRODUCTION, fi.603 TD, 6,603 ~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~-~~a ~uN r ~ zoos Log Description NO.4732 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suites 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/30/08 1 F-04 11964615 INJECTION PROFILE +(~ ~ ~ ( 05/26/08 1 1 3F-10 11964609 PRODUCTION PROFILE - ~ 05/23/08 1 1 1J-101 11970685 GLS = C ( 05/23/08 1 1 iJ-166 11970681 GLS / 05/20/08 1 1 2N-306 11964608 INJECTION PROFILE - / ~d (.~- 05/22/08 1 1 3K-13 11970688 INJECTION PROFILE - (p _ ~ 05/26/08 1 1 1B-08A 11970686 INJECTION PROFILE e, j ~ -j / 05/24/08 1 1 1Y-11 11964613 INJECTION PROFILE (tj - /(~~G} 05/25/08 1 1 3K-19 11964616 INJECTION PROFILE U"' Cj 05!27/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 0 8 2005 \ <!5':Þ1 \ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 top-fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907 -659-7043,,'((You have any questions. f // f f Sincerely, .F? /./ // 44/¿ß?¿l // f'//' I}/ jltJz/~~/~~ /1 :j MJ. t.:oveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 3F~0;t:;.· . .... 1a~r225 . . '. . . NA .... . '. . '. .- . . ·~~A·.· .....: ::;: 8f~1¡2,f¡Q§. " . : .. 3F-02 1 85-226 24' 7.0 8/1 4/2006 7.5 8/21/2006 ~F:~Q~ .' .~ >;t~~fi21 <,0 r;:: . 43'4"" . .. 'c2·.3 . .c. ,... . , 8fo14t~QOº: .-" .1A.·~":" .. :/&l~tl«ÐÐ~ .' 3F-04 1 85-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 3$,,~p;} :"1.i~Ø> .[ 5.1 .1 ~'. ". ',,' ·c; '. 'ßI1!4f2:0:ø'S '; i. .' 7" ÌZ'" . , ,8Iji~2(1Ð"6 '" 'f¿ f·.V' . . 3F-06 1 85-244 Did not modify 3F,lQ·7: . . ·~·;:tØ;$f4~:: ,; I' . . . 6.6· . 8]f4l2~ÖB r ]'.5 8J21/~QOè: " . 3F-08 1 85-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21 /2006 '3í=-Q~ " .. I 1'Ø~f2tlØ" . Did not modify 3F-1 0 185-271 SF NA NA 6.6 8/21/2006 . 3f::11; . 185:;~12'~ f'~ .. '.. NA ." . I ". I\I"A" . .1.:7.' .; 8/~3IZø:Q~ . 3F-1 2 185-273 7'4" 1 .8 8/14/2006 6.2 8/23/2006 I·" . " '. '~:1~~J"t},·; I . NA . ·21~"'··· .;' .' ;'. '.B"/~gÞ~flEfØ· ';.-> . ~ 1 85-292 Did not" ,~~" .. ';'" ..f:~¡¡{~~'~ ....... 2~¡!r .' . .:. ..'ß'tt4l2çxÔa:;':'· :'." '. .. ': c',Øf~3'~Z~j'Ø&" .' 3F-16 196-151 6" NA NA 2.7 8/23/2006 3J~';11 . , ~ 11'" . .", 3;r . . . 'i8ft4/2ØØ6, : " . "8. " ··8/~âì2~ÖÐ.6;~ 3F-1 8 196-112 4' NA NA 28 8/23/2006 '3¡:::~~9 ..: ZEt#~~16' .::< . J:K:·· .. . .M;"ð. . . '. .8" : .., I: "2. .'. ... "8¡;~912Ð·Ø6., . 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-21 " ..... 2Ó~2Ò3 ;45" NA . . NA . 31 . .: 8121J2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. O[~erations Performed' Operation Shutdown __ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360. Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 21' FSL, 89' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1358' FNL, 1115' FEL, Sec. 30, T12N, R9E, UM At effective depth 1432' FNL, 1171' FEL, Sec. 30, T12N, R9E, UM At total depth 1465' FNL. 1197' FEE Sec. 30, T12N. R9E, UM 6. Datum elevation (DF or KB) RKB 93 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-10 9. Permit number 85-271 10. APl number 50-02 9- 2 1 48 1 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Deptt~: measured 6 6 5 0' true vertical 621 8' Effective depth: measured 6 51 2' true vertical 6 0 8 7' Casing Length Size Structural Conductor 6 6' 1 6" Surface 30 6 4' 9 5/8" Intermediate Production 6 5 65' 7" Liner Perforation depth: measured 6202'-6266' true vertical 5790'-5853' feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True vertical depth 307SxAS II 104' 104' 840 Sx PF 'E' & 31 02' 3041 490 Sx PF 'C' 200 Sx Class G & 6603' 61 71' 175 Sx PF 'C' 6419'-6452', 6384'-6404' 5998'-6029', 5965'-5984' Tubing (size, grade, and measured depth) 3 1/2", 9.3#, J-55 EUE to 6313', 2 7/8", 6.5#, J-55 EUE w/ tbg tail at 6337' Packers and SSSV (type and measured depth) J~ SSSV: Camco TRDP-1A-SSA @ 1810', PACKERS: Otis RRH @ 6118'. Otis WD @ 631 ECEIVF _ 13. Stimulation or cement squeeze summary Fracture Stimulate A Sands Intervals treated (measured} 6384'-6404', 6419'-6452' Treatment description including volumes used and final pressure Pump 10.6 Mlbs 20/40 & 133.0 Mlbs 12/18 Mesh Ceramic Proppant. 14. ReDre~ntative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure JUN 0 7 !995 Alaska 0il & Gas Cons. Commission Anchora ~ Final WHTP = 4023 psi. Tubing Pressure Prior to well operation 5 3 5' 186 2 1 4 0 3 187 Subsequent to operation 1003 1 303 2 671 212 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~~~'/~'''' ~ Title Wells Superintendent Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. /Ii Subsidiary. of Atlantic Richtield Company WELL 3F-10 DATE 4/10/95 DAY 1 DESCRIPTION OF WORK "A" SANDS RE-FRAC CONTRACTOR / KEY PERSON DOW-ELL R.G. PBTD (RKB) LAST TAG (RKB) - DATE TIME LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT I AFC/CC# - SCA# ! 9984O2 8O43O IFIELD COST F_,ST. IACCUMULAr~D COSX ! *156,045 ! *164.145 ISSSV TYPE / STATUS IFRAC SLEEVE INSTALLED 0600 MIRU FRAC EQUIP. & HOT OIL TRUCK 0900 PRESSURE TEST TO 6500 PSI 0922 0941 PUMPING 3 PMP-IN AT 20 BPM 40 BBLS EACH DOWN FOR ISIP AFTER EACH TOTAL 236 BBLS PUMPING BREAKDOWN STAGES AT 30 BPM , AT 4838 PSI, TOTAL DELAY XL GW 100BB 1008 PUMPING STEP RATES W/NON XL GEL , 10,15,20,25,20 BPM, TOTAL 359 BBLS.FG.74 DOWN FOR FORCED CLOSURE dqq2 PSI AND ISIP 1105 PUMPING DISPLACE, DATA FRAC AND FLUSH AT 20 BPM , 4027 PSI, ISIP 2600 1209 PUMPED DISPLACE, 56 BBLS PUMPED 110 BBLS PAD , 20 BPM AND 4243 PSI 1303 i PUMPED 255 STAGE OF 20/40 C.PROP, 10,602# AT 20 BPM AND 4243 PSI 1308 RAMPED TO 655 STAGE W/79,7168 12/18 PROP AT 20 BPM AND 3968 PSI 1328 PUMPED 10g STAGE OF 12/18 PROP AT 19 BPM AND 4249 PSI SWITCHED TO 909 X-LINKER TO HELP FRICTION. 1347 RAMPING TO 1355 STAGE W/12/18 , TREATING AT MAX. AND CUTTING RATE FROM 19 TO 7 BPM. 1349 HIGH TREATING PRESSURES , CALLED FLUSH AT 7 BPM AND 4023 PSI 12 PPA FG. 1353 PRESSURED OUT AND SHUT DOWN W./18 BBLS OF FLUSH , ONLY ABOUT 5 BBLS OF DIESEL AT TOP OF WELL. SUMMARY: PUMPED "A" SANDS RE-FRAC, TOTAL OF 10,600~ OF 20/40, 133,000g OF 12/18 IN FORMATION, W! 12 PPA AT PERFS. 1437 BBLS OF GEL WATER. LEFT 10, 0{X)g OF 12/18 PROP, AT 13 PPA IN PIPE. CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather jTemp- rChiil Factor IVisibility Wind Vel. Report miles, mph, Signed COMPLETE THOMAS ~TE ~ OIL AND G/~ ~RVATION COMMi~~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate m Plugging Perforate X Repair well Other __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. I_cmation of well at surface 21' FSL, 89' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1358' FNL, 1115' FEL, Sec. 30, T12N, R9E, UM At effective depth 1432' FNL, 1171' FEL, Sec. 30, T12N, R9E, UM At total depth 1465' FNLr 1197' FELt Sec. 30~ T12N~ R9E, UM 12. Present well condition summary Total Depth: measured 6 6 5 0' true vertical 6 21 8' feet Plugs (measured) feet None Effective depth: measured true vertical 651 2' feet Junk (measured) 60 8 7' feet Norle Casing Length Structural Conductor 6 6' Surface 3 0 6 4' Intermediate Production 65 6 5' Uner Perforation depth: measured 6202'-6266', true vertical 5790'-5853', Size Cemented 1 6" 307 Sx AS II 9 5/8" 840 Sx PF 'E'& 490 Sx PF 'C' 7" 200 Sx Class G & 175 Sx PF 'C' 6419'-6452', 6384'-6404' 6. Datum eievatio~ (DF or KB) 13. RKB 93 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3F-10 9. Permit number 85-271 10. APl number so-029-21481 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 104' 104' 3102' 3041 6603' 6171' RECEIVED S998'-6029', S965'-S984' MAY - 6 1992 Tubing (size, grade, and measured depth) ~J~aS~ 0jj & Gas Cons. Commissit 3 1/2", 9.3#, J-55 EUE to 6313', 2 7/8", 6.5#, J-55 EUE wi tbg tail at 6337' Ar~chorag8 Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SAA @ 1810'~ PACKERS: Otis RRH ~ 6118'~ Otis WD ~ 6314' Stimulation or cement squeeze summary Intervals treated (measured) ADD A3 SAND PERFS: 6384'-6404' 14. Treatment description includincj volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mc/ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1110 525 8200 1560 250 1190 /'740 8700 1560 250 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Operations Engineer Date ~/~'/~ Z SUBMIT IN DUPLICATE R~ ~rt of Sundry Well Ope, ,ons Kuparuk River Unit Well 3F-10 April 22, 1992 On February 18, 1992, ARCO Alaska, Inc. added perforations in the A3 interval of the Kuparuk Sands on Well 3F-10. The perforations were completed with a 2 1/8" HLS Dynastrip from 6384' to 6404' MD at 6 SPF, and 0 degree phasing. RECEIVED M AY - 6 1992 Alaska 0il & Gas Cons. Comm'tss[o~ Anchorage t"tl I¥¥ I-tll~lgl1~l;i! IIl¥. ~.;t:)s~clJary of Atlantic Ricl~fi®lcl COml:~.O~ WELL PBDT !FIELD- DISTRICT. STATE CONTRACTOR OPERATION AT REPORT TIME WI-LL ~SERVICE REPOR~, DAYS CATE I ~-- ~'~ EMARKS c c ~ 3 o05 ~¢ Fl-- /65,0 ,O od l../ . · I (.,,~ C v 9-o ~'~ O Y ' 0° /o h,x,,~ MAY - 6 199~ Alaska Oil & Gas Cons. Commission Anchorage [-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Wllther Temp' I Chill Flct°l' I Vlliblllty tWInd VII'Report 'F 'F mil. REMARKS CONTINUED: DESCRIPTION DALLY ACCU M TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Jo{3 Safety Meeting AFE TOTAL FIELD ESTIMATE ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 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. 3 F- 1 5 Kupaurk Fluid Level Report 1 2- 0 3 - 8 7 3 N - 1 8 Kupaurk Fluid Level Report 1 2 - 1 8 - 8 7 3 F- 01 Kupaurk Fluid Level Report 8-29-87 3 F-02 Kupaurk Fluid Level Report 8-29-87 3 F-09 Kupaurk Fluid Level Report 8-29-87 3 F- 0 6 Kupaurk Fluid Level Report 8-29-87 3 F- 1 0 Kupaurk Fluid Level Report 8-29-87 3 F- 1 1 Kupaurk Fluid Level Report 8-29-87 3 F-1 5 Kupaurk Fluid Level Report 8-29-87 3 F- 1 4 Kupaurk Fluid Level Report 8-29-87 3 N- 1 0 Kupaurk Fluid Level Report 5-18-87 3 N-06 Kupaurk Fluid Level Report 5-22-87 3N-09 Kupaurk Fluid Level Report 5-21-87 31-0 1 Kupaurk Fluid Level Report 4-24-87 3 N- 1 1 Kupaurk Fluid Level Report 4-15-87 3 N - 1 4 Kupaurk Fluid Level Report 4-13-87 3 F- 0 8 Kupaurk Fluid Level Report 4-14-87 3 N-01 Kupaurk Fluid Level Report 4-20-87 3 N - 1 4 Kupaurk Fluid Level Report 1 2 - 0 4 - 8 7 3 F-1 5 Kupaurk Fluid Level Report 2-02-89 3 F- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B- 0 5 Kuapruk Well Pressure Report 2-20-89 1 E-25 Kuparuk Fluid Level Report 2-19-89 3 B- 1 1 Kupaurk Fluid Level Report 2-20-89 3A-03 Kupaurk Fluid Level Report 2-21-89 3 H-01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31-1 2 Kupaurk Fluid Level Report 2-20-89 1 E-08 Kupaurk Fluid Level Report 2-19-89 3 M - 1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' Amerada Casing Casing Casing Casing Tubing Tubin~~l~ Casin~L~' Casino]'''~ 3 H - 01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 E-29 Kupaurk Fluid Level Report 2-15-89 Casing lC-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M-1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2 Z- 2 0 Kupaurk Fluid Level Report 2-18-89 Tubing 30- 1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 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. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 3(3-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Kuparuk Well Pressure Report Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuapruk Ku ~aruk Ku~aruk Ku ~aruk Ku~aruk Ku~aruk Ku~aruk Ku ~aruk Ku3aruk Ku3aruk Ku3aruk Ku ~aruk Ku )aruk Ku~aruk Ku )aruk Ku )aruk Ku )aruk 10-06-88 8-29-88 Well Pressure Report I 2- 2 0 - 8 8 Well Pressure Report 8 - 2 9 - 8 7 Well Pressure Report 8-29- 87 Well Pressure Report 8 - 2 9 - 8 9 Well Pressure Report 8 - 1 7 - 8 7 Well Pressure Report 8- 1 7-87 Well Pressure Report 8-29- 87 Well Pressure Report 6-26- 87 Well Pressure Report 1 2- 1 2 - 8 8 Well Pressure Report 1 2-3 1 -88 Well Pressure Report 6- 1 1 - 87 Well Pressure Report 6-1 1- 87 Well Pressure Report 9 - 01 - 8 7 Fluid Level Report 5 - 0 4 - 8 7 Fluid Level Report 2- 1 3 - 8 9 Fluid Level Report 2- 1 0 - 8 9 Fluid Level Report 2- 1 0- 8 9 Fluid Level Report 6 - 0 5 - 8 7 Fluid Level Report 6- 09- 87 Fluid Level Report 6 - 1 8 - 8 7 Fluid Level Report 6 - 1 6 - 8 7 Fluid Level Report 6 - 21 - 8 7 Fluid Level Report 5 - 0 8 - 8 7 Fluid Level Report 8 - 1 8 - 8 7 Fluid Level Report 8 - 2 4 - 8 7 Fluid Level Report 6 - 05 - 8 7 Fluid Level Report 6- 2 / 3 ~ 8 7 Fluid Level Report 8- 5 - 8 7 Fluid Level Report 6 - 5 - 8 7 Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casing Anchorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Kuaaruk Fluid Ku aaruk Fluid Ku aaruk Fluid Ku :)aruk Fluid Ku aaruk Fluid Ku aaruk Fluid Ku aaruk Fluid Ku aaruk Fluid Ku aaruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku aaruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku :~aruk Fluid Ku ~aruk Fluid Acknowledged: Level Report 9- 11 -87 Level Report 12 - 06 - 86 Level Report 9 - 11 - 87 Level Report 10 - 11 - 87 Level Report 9- 16-87 Level Report 4 - 11 - 88 Level Report 4-08-88 Leyel Report 4-01 -88 Level Report 3-26-88 Level Report 1 - 30 - 88 Level Report 10 - 1 2 - 87 Level Report 10 - 1 5 - 87 Level Report 10 - 28 - 87 Level Report 10 - 28 - 87 Level Report 10 - 28 - 87 Level Report 10 - 28 - 87 Level Report 3 - 1 9 - 87 Level Report 9- 1 2-87 Level Report 9 - 1 0 - 98 Level Report 9 - 1 0 - 87 Level Report 9 - 1 0 - 87 Level Report 9- 1 2- 87 Level Report 9 - 08 - 87 Level Report 9 - 01 - 87 Level Report 9 - 01 - 87 Level Report 9-06-87 Level Report 9 - 06 - 87 Level Report 9 - 06 - 87 Level Report 9 - 06 - 87 Level Report 6 - 01 - 87 Level Report 5-31 -87 Level Report 6-03-87 Level Report 6-06-87 Level Report 6-08-87 Level Report 6-09-87 Level Report 6 - 25 - 87 Level Report 4 - 1 7 - 87 Level Report 4 - 1 8 - 87 Level Report 6- 1 7- 87 Level Report 6 - 20 - 87 Level Report 5- 0 7 - 87 Level Report 8 - 24 - 87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casino. Casin~. Casino_ Casino_ Casinc~ Casino. Casino. C asing'~l~'" ~1~ C ~ Alaska Oil & G~s Con:.. DISTRIBUTION: D&M State of Alaska Mobil Chevron Unocal SAPC ARCO Alaska, inc. -- Post Office Bc J360 Anchorage. Ala~,r,a 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal ¢5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints- ~ --~'f1R-14 CET/CEL ~ ~R-14 CET/CEL ~ -~ 2A-14 CET/CEL '~ xu-~3A-1 CET/CEL ~ '~f3A-2 CET/CEL ~ -u~-3A-3 CET/CEL ~ ~ ~-3A-15 CET/CEL ~ ~--3A-16 CET/CEL ~ ~-~3C-15 CET/CEL '"'" '-~--3C-16 CET/CEL x~ ~3F-1 CET/CEL ~ ~U_3F_lO .CET/CEL '~ "~3F:11 CET/CEL ~ -o ~3J-4 CET/CEL ~3J-6 CET/CEL "~'~ ~3J-9 CET/CEL 10-12-85 Run ~2 8600 10-13-85 Run ~3 8550 10-02-85 Run #1 6795 10-01-85 Run #1 7550 10-01-85 Run #1 6680 10-01-85 Run #1 6080 12-30-85 Run #2 6400 12-30-85 Run ~2 7300 10-!5-85 Run ~1 5887 10-15-85 Run #1 3995 10-!7-85 Run #1 7000 12-19-85 Run #1 5166 12-19-85 Run #1 6950 10-05-85 Run #1 6860 10-19-85 Run ~1 7000 12-18-85 Run ~1 - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 36 - 6678 · Receipt Acknowledged: ~--~-..~~'u*'Di~e~8 -, K Drillina Vault(1 film) Inc. is Z: Sulu~,~Oiery Of Al,; ' I~cRtchf~,,c~Cornuen~ - STATE OF ALASKA - - ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RF. COM LETION REI ORT AND 1. Status of Well Classification of Service Well OIL ~. GAS ~-~ SUSPENDED '~. ABANDONED ~- SERVICE -- --~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-271 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21481 9. Unit or Lease Name Kuparuk River Unit 4. Location of well at surface 21' FSL, 89' FEL, Sec.19, T12N, R9E, UN At Top Producing Interval 1359' FNL, 1115' FEL, Sec.30, T12N, R9E, UM At Total Depth 1465' FNL, 1197' FEL, Sec.30, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93' RKB I ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Sum. or Aband. 11/1 8/85 11/27/85 11/29/85* 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 6650 'MD,6218 'TVD 6512 'MD,6087 'TVD YE~ NO ~ 22. Type Electric or Other Logs Run DIL/CR/SP/SFL, FDC/CNL, SHDT, LSS, RFT, GR/CCL/CET, CCT 10. Well Number 3F-10 23. WT. PER FT. 67 .b# CASING SIZE i6~' 9-5/8" 7" 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 15. Water Depth, if offshore 16. No. of Completions N/A feet MSL , 1 20. Depth where SSSV set 21. Thickness of Permafrost 1810 feet MD 1500' (Approx) GRADE H-40 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD BOTTOM TOP Surf HOLE SIZE 115' 24" '36.0# J-55 Surf 3102' 12-1/4" 6.0# J-55 Surf 6603' 8-1/2" Cmtd w/200 sx Class G & 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 6419' - 6452' w/4 spf, 90° phasing 6202' - 6266' w/12 spf, 120° phasing CEMENTING RECORD AMOUNT PULLED 307 SX AS II Cmtd w/840 sx PF "E" & 3~90 sx PF "C" Performed top job w/100 lsx PF "C" 175 sx PF "C" 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6338' 6118' & 6314' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27!'l/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Hours Tested Date of Test Casing Pressure Flow Tubing Press. GAS-MCF GAS-MCF 28. CORE DATA WATER-BBL WATER-BBL ICHOKE SIZE [ GAS-OIL RATIO IOILGRAVITY-API (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description previously submitted. · Form 10407 * NOTE: Tubing was run & the well perforated 1/20/86. WC1/052 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKERS 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gray ty, MEAS. DEPTH IJ TRUE VERT. DEPTH GOR,and time of each phase DEPTH HYDRO. PRESS. SHUT-IN PRESS. 3126 :si 31 23 )si 3121 )si 3109 )si 3109 )si 3108 )si 3111 )si 3045 )si 3037 ;si 3030 psi 3027.5 psi Top Kuparuk C 6199' Base Kuparuk C [i 6266' Top Kuparuk A 6365' Base Kuparuk A 6492' 31 LIST OF ATTACHMENTS None 6431 6426 6421 6391 6397 6393 6388 6259 6238' 6223' 6216' 5788' 5852' 5946' 6068 ' 3007 psi 3008 psi 3008.5 psi 2996 ps i 2998 psi 2996 ps i 2995 psi 2880.5 psi 2876 psi 2871 ps i 2871 .S Fsi 32 I hereby certify that the foregoing is t,ue and correct to the best of my knowledge Signed I T,tle 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 lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 STATE OF ," "CKA ALASKA OIL AND GAS CONS=~'''' ~ ,~v,.-,. ION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL 2. Name of Operator ARCO Alaska~ inc. 3. Address P. 0. Box 100360~ Anchora§e, AK 4. Location of Well Surface: 99510-0360 22' FSL, 90' FEL, Sec.19, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB ~ ' 12. COMPLETED WELL 7. Permit No. 85-271 8. APl Number 50-- 029-21481 OTHER 6. Lease Designation and Serial No. ADI 2F, 6b,?, Al K 2c~7b, 9. Unit or Lease Name Kuparuk River Unit 10. Well Number ~F-IO 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil 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). Spudded well ~ 1400 hrs., 11-18-85. Drilled 12-1/4" hole to 3110'~ ran, cmtd and tstd 9-5/8" csg w/shoe ~ 3102'. (Cmtd. 9-5/8" csg w/840 sx Permafrost E and 390 sx Permafrost C. Performed top job w/lO0 sx Permafrost C.) Drilled 8-1/2" hole to 6215'; cored we]] f/6215'-6529'. Continued drilling 8-1/2" hole to 6650' TD; ran logs. Ran, cmtd and tstd 7" csg w/shoe ~ 6603'. Secured we]l and released rig ~ 1830 hrs., 11-29-85. BHL: 1465' FNL, 1197' FEL, Sec. 30, T12N, R9E, UM 14. I hereby certify that the foregoing is true and correct to the best of my knowieclge. The space below for~ommission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Submit "Intent,ohs" in Triplicate Oki /1 ~o ...... ARCO Alaska, Inc_._ Post Offi¢ 0360 Anchorage, A~ast(a 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL SHIPPED TO: STATE OF ALASKA DATE: AK, OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR. ANCHORAGE, AK 99510 ATTN: JOHN BOYLE APRIL 15, 1986 OPERATOR: ARCO NAME: SAMPLE TYPE: CORE CHIPS ~F-]Q NUMBER OF BOXES: 15 BOXES SEE ATTACHED: O PEG WEISSER TECH AIDE BY T A GORUP SHIPPED BY: ~ kk>~,~,~ ' ' UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 RECEIVED BY P LAB, BV- 100 i~ DATE: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.- Date: March 19,. 1986 Internal Corresp Subj~t: Documentation Request-Core Chips For The State Of Alaska From 3F-10 From/Location: ~.Gorup, ABV-100 To/Location: Dan Fortier, ATO-1026 . @ 1' Intervals DEPTHS COMMENTS DEPTHS COMMENTS .. 621526275 6295-6502 .' 6508-6523 ADDENDUM WELL: 12/09/85 12/20/85 3F-lO Arctic Pak w/175 sx PF "C", followed by 54 bbls Arctic Pak. Rn GR/CCL/CET/gage ring f/6489'-5166'. Drilling ~Superintendent / Da/re ARCO Alaska, Inc. Pest Office Be,,. 100360 Anchorage. Alaska 99510-0360 Teiephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3F-10 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/LI54 Enclosures RECEIVED FEB 28 1-q86 STATE OF ALASKA - ALASKA L,,L AND GAS CONSERVATION C(..,,v, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL _ GAS _ SUSPENDED _ ABANDONED _ SERVICE _ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-271 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 !50 029-21481 Ciassification of Service Well 4. Location of well at surface 21' FSL, 89' FEL, Sec.19, T12N, R9E, UM At Top Producing Interval 1358' FNL, 1115' FEL, Sec.30, T12N, R9E, ~! At Total Depth 1465' FNL, 1197' FEL, Sec.30, T12N, RgE, UH 9. Unit or Lease %lame Kuparuk River Unit 10. Well Number 3F-10 11. Field an(] Pool Kuparuk River Fi eld Kuparuk River 0il Pop] 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial 'No. 93' RKB ! ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore , 1 (3. No. of Completions 11/18/85 11/27/85 11/29/85' I N/A feet MSL 1 17. Total Depth (MD~-TVD) [18. Plug Back Depth (MD~TVD) ,~ 19. Directional Survey 20. Depth where SSSV set 21 Thick. ness of Permaf-ost 6650 'MD ,6218 'TVD I 6512'MD,6087'TVDil YES ~-X NO -- 1810 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, SHDT, LSS, RFT, GR/CCL/CET, GCT 23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" t Conductor report not yet received. 9-5/8" 36.0# J-55 Surf 3102' 12-1/4"! Cmtd w/8~O sx PF "E" &. 390 sx PF "C" ' Performed top job w/lOp sx PF "C" ! 7" 26.0# J-55 Surf 6603' 8-1/2" Cmtd w/200 sx Class C & 175 sx PF "C" 25. 24. Perforations open to Production (MD-TVD of Top and Bottom and inte-val, size and number) 6419' - 6452' W/4 spf, 90° phasing 6202' - 6266' w/12 spf, 120° phasing SIZE 3-1/2" 26. TUBING RECORD DEPTH SET ,MD) PACKER SET fMD} i 6338' 6118' & 6314' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL IMD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production ! Method of Operation (Flowing, gas lift, etc.) Date of Test Flow Tubing Press. Hours Tested Casing Pressure I PRODUCTION FOR OIL-BBL TEST PERIOD ~ iCALCULATED iOIL BBL '24-HOURRATE- 28. CORE DATA GAS-MCF IGAS-MCF WATER-BBL WATER-BBL CHOKE SIZE GAS-OIL RATIO IOIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description previously submitted. RECEIVED FEB 2 8 lg86 Alasl~ 0ii & Gas 6u,s. t~mm~ssion Anchorage Form 10-407 -k NOTE: Tubing was run & the well perforated 1/20/86. DAM/WC44 Suture,' in dupl,cate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS DEPTH 6199' ,, !i 6266' 6365 ' 6492 ' h 30. FORM, A. TION TESTS j IncluOe ~oter .~', tested, pressure 'Iai3, all ~',uids recove,ed anrJ ~:'a~ ,'~, ,- II TRUE VERT DEPTH ' GOR, and tin-e of each phase 5788' 5852' 5946' 6068' DEPTH HYDRO. PRESS. SHUT-IN PRESS. 643i 6426 6421 6391 6397 6393 6388 6259 6238 6223 6216 3126 psi 31 23 psi 3121 3109 )s 3109 3108 )s 3111 )s 3045 )s 3037 )s 3030 )s 3027.5 psi 3007 psi 3008 psi 3008.5 psi 2996 psi 2998 psi 2996 psi 2995 psi 2880.5 psi 2876 psi 2871 psi 2871.5 psi L- C: Gyroscopic Survey (2 copies), Wei] History (comp]etion details) ! ne'eD¥ certify that the foregoing ~s true and correct tc ~he bes: o~ r~ - ~c.'.~e¢:ze Associate Engineer __ INSTRUCT iOr':S Geqe.~a~' This form is designed for submitting a comp~e:e and correct well completion report and ids on all t'ypes of lands and leases in Alaska. ',tem I Classification of Service Wells' Gas injection, ~%ater injection, steam injection, air injectior~ salt water c;isposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where no: otherwise shown) for depth measurements giver; ;,r~ 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 ~nterval (multiple cor,nple'{ion), so state in item 16, and in item 24 show ti~e producir, g intervals for only the interval reported in i~em 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 oti~er elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water jection, Gas Injec[ion, Shut-in, Other-explain. ~tem 28' If no cores taken, indicate "none". F_'m. 10 46,? ARCO Oil and Gas Company Daily Well History-Final Report Instructions: m,eDare and SL;3m t t~e "Final Report" .ar, t'~e ;+-st '¢,'ec-es~ay after a o¢,ac~e 'as =een ass%cnec 3, ~e s C:ug;ec A=an~3ne~ "Final Re~o~" s~curc De su=m:t:ec a~so *hem oce,at~ons a,e susaencea 'or an :ncefm te o' acc,ec:ae,e ~eng:~ o' :me C~ ac'~overs ~-e~ a~ c"': a~ :est ,s not required uccn com3;et~om. ,ecc~ completion and ,earesentat,ve :est :ate ;n s,cc~s =,ovtcec T~e "Final Report" 'o,m may ce usec oDerat:cn ' space s a.a~ a~ e Accountmg ccst center ccOe Alaska We" ~o 3F-10 F~e:= Alaska L ...... u~t North Slope Borough Kuparuk River ADL 25643 Auth. cr W.C no Tit~e AFE AK0481 Completion Nordic 1 AP1 50-029-21481 ODerat? ARCO Alaska, Inc. S~udoed or WC uegun Complete A~Co w~6.24% Date 1/19/86 I ota( number of wells (active or inactive) om ir'is pst center prior to plugging and bandonment of th~s weil our 1 Prior status If a W.O 0200 hrs. Date an= depth as of 8 00 a.m 1/19/86 thru 1/20/86 1/21/86 Complete record ~or each day reported 7" @ 6603' 6512' PBTD, Rn'g 3½" CA 9.8 ppg NaCl/NaBr Accept rig @ 0200 hrs, 1/19/86. ND tree, NU & tst BOPE. RIH to 6515', POOH. Perf well w/4" gun, 4 SPF, 90° phasing f/6419'-6452'. Perf w/5" guns, 12 SPF, 120° phasing f/6202'-6266'. Make gage ring/JB rn. Wet W~ pkr . RU & begin rn'g 3½" compl. 7" @ 6603' 6512' PBTD, RR 9.8 ppg NaC1/NaBr Rn 200 jts, 3½", 9.3#, J-55 EUE 8RD tbg w/SSSV @ 1810', RRH pkr @ 6118'. WD Pkr @ 6314', "D" Nipple @ 6329', T% @ 6338'. Set pkr, tst tbg, pkr & SSSV. Att shear out, lockdn screws failed. Pull hgr & redress lockdn screws. Re-lnd & tst pkr, SSSV. Shear out. Displ well to diesel. RR @ 1745 hrs, 1/20/86. Old TD Ne'* TD Re:eased r,g Date 1745 hrs. C'.ess+';caticns ,o, gas etd Oil RECEIVED F E B 2 8 1986 Alasl(a 0il & b,~s Cu~,s. L;ommission An~orage I ~:e::',, 6512' PBTD K nC C~ ' g 1/20/86 Rotary Tyce com2~et:cn .s,ng e 3ua etd Single PrccuC:ng reef"pC Cff[c;al -ese,~o, ~ame s Flowing Kuparuk Sands ~otent~a~ :est ca:a rzca /tz. We~l '~o Date Reservc,r P,oCucmg Inter~.a~ C:, or gas Test : --e =-3c¢ct c- C or, test Gas Der day Pump size. SPM X iergth Cno~e s,ze ! T ~ C P. '/,ater % GCR Gra~ :y A .o~ao e Effec:..ve cate co,red:ed The above ,s correct Signature ,~ Date IT~t e ~__2~ /--~/---_-~"~2 ---~D I~/~ I Drilling Superintendent DrHhng. Pages 86 and 87 ARCO Alaska, Inc. Post Office Bo,, ,00360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-10 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 3F-10. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and She well completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L94 Enclosures -- STATE OF ALASKA ALASKA AND GAS CONSERVATION C VlISSION 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. 85-2_71 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21481 4. Location of well at surface 22' FSL, 90' FEL, Sec.19, T12N, R9E, UM At Top Producing Interval To be submitted when gyro is run. At Total Depth To be submitted when gyro is run. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93' RKB I ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 11/1 8/85 11/27/85 11/29/85 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 6650 'MD 651 2 'HD YES ,~ NO ~X 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3F-10 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 15. Water Depth, if offshore 116. No. of Completions N/A feet MSL]~ N/A 20. Depth where SSSV set 21. Thickness of Permafrost N/A feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/CR/SP/SFL, FDC/CNL, SHDT, LSS, RFT, GR/CCL/CET/Gauge ring 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 9-5/8" 7" WT. PER FT. 62.5# 36.0# 26.0# GRADE H-40 J-55 J-55 SETTING DEPTH MD TOP BOTTOM Surf 115' Surf 3102' Surf 6603 ' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None HOLE SIZE 24" 1 2-1/4" 8-1/2" CEMENTING RECORD Conductor report not y~ Cmtd w/840 sx PF "E" & Performed top job ~/101 Cmtd w/200 sx Class G AMOUNT PULLED ,~t received. 390 sx PF "C" sx PF "C" 175 sx PF "C" 25. TUBING RECORD SIZE N/A DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested Casing Pressure Flow Tubing Press. iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL :TEST PERIOD I~ OIL-BBL GAS-MCF WATER-BBL CALCULATED 24-HOUR RATE ICHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description attached. .~ :L ..- .- ~.- Form 10-407 Rev. 7-1-80 TEHP3/WC53 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS N/A NAME MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all ftuids recovered and gravity, GOR, and time of each phase. ~th 6431 6426 6421 6391 6397 6393 6388 6259 6238 6223 6216 Hydro Shut-in Press Press 31. LIST OF ATTACHMENTS Cnre d~script~nn~ Well Hi ~tnr~L 32. I hereby certify that the foregoing is True and correct to the best of my knowledge 3126 p 3123 p 3121 p 3109 p 3109 p 3108 p 3111 p 3045 P 3037 p 3030 p 3027.5 p si 3 si 3 s 300 s 2 s 2 s 299 s 299 s 2880. s 287 s 287 s 2871 . 007 psi 008 psi 8.5 psi 996 psi 998 psi 6 psi 5 psi 5 psi 6 psi 1 psi S psi INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form l 0-407 TEMP3/WC53a ARCO Oil and Gas Company Well History - Initial Report - Daily Inlln~cli~ni: Prepare and submit the "Initial RIl~rl" on the first Wednesday after a well is spudded or workover operations are stirred. Daily worX prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0481 Doyon 9 Operator ICount~. I:~ri~ or DOrou~h North Slope Borough Lease or Unit ADL 25643 ITitle Drill IState Alaska lWell no. 3F-lO API 50-029-21481 IARCO W I Prior status if s W.O. ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date IHour 11/18/85 Date and depth as of 8:00 a.m. 11/20/85 11/21/85 11/22/85 11/23/85 thru 11/25/85 Complete record for each day reported 1400 hrs. 56.24% 16" @ 115' 2136', (2021'), Navi-Drl Wt. 9.2, PV 9, YP 8, PH 9.0, WL 16.8, Sol 6 Accept rig @ 1015 hrs, 11/18/85. NU diverter sys. Spud well @ 1400 hrs, 11/18/85. Drl & Navi-Drl 12¼" hole to 2136'. 16" @ 115' 3110', (974'), Prep f/top job Wt. 9.3, PV 12, YP 8, PH 9.0, WL --, Sol 6 Navi-Drl & surv 12¼" hole to 3110', make wiper trip f/csg, TOH, LD BHA. RU & rn 78 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3102', FC @ 3020'. Cmt w/840 sx PF "E", followed by 390 sx PF "C". Displ using rig pmps, bump plug. No cmt rtns. CIP @ 0530 hrs, 11/20/85. Prep f/top job. 2082' 2.0° S34 25W, 2082 TVD, 1 VS, 8S, .5W 2457', 13.5°, S39.25W, 2452 TVD, 53 VS, 43S, 31W -; ~ .... . . ~ ~- 2832', 25.7°, S34.25W, 2804 TVD, 179 VS, 146S, 105W .~ 3055', 30.4°, S32.25W, 3001 TVD, 283 VS, 233S, 163W 9-5/8" @ 3102' 4366', (1256'), Drlg Wt. 8.8, PV 3, YP 3, PH 9.5, WL 10.8, Sol 4 ND diverter sys. Perform 100 sx PF "C" top job. NU & tst BOPE. RIH, tst csg to 2000 psi. DO FC, cmt, FS & CO to 3110'. Drl 10' new hole. Conduct formation tst to 12.2 ppg EMW. Navi-Drl & surv 8½" hole to 4366'. 3506', 30.7°, S38.25W, 3390.1TVD, 512.1VS, 420.5S, 295.4W 4139', 30.9°, S39.25W, 3933.5 IVD, 836.7 VS, 672.7S, 499.7W 9-5/8" @ 3102' 6215', (1849'), Prep to core Wt. 9.8, PV 13, YP 6, PH 9.4, WL 6.2, Sol 9 Navi-Drl & surv 8½" hole to 6215', POH. PU core bbl & RIH. 4450', 30.1°, S39.25W, 4201.5 TVD, 994.5 VS, 795.0S, 599.5W 5072', 27.8°, S39.25W, 4745.6 TVD, 1295.8 VS, 1026.6S, 792.2W 5355', 24.6°, S40.25W, 4999.5 TVD, 1420.8 VS, 1122.3S, 872.6W 5546', 23.1°, S40.25W, 5174.2 TVD, 1498.0 VS, 1181.3S, 922.5W 6155', 16.7°, S38.25W, 5749.5 TVD, 1696.2 VS, 1336.1S, 1046.3W 9-5/8" @ 3102' 6387', (172'), POH w/core #5 Wt. 9.8, PV 14, YP 10, PH 9.5, WL 6.0, Sol 10 RIH, wsh & rm 6135'-6215', cut core #1, 6215'-6245', rec'd 30'. Core #2, 6245'-6266', rec'd 20.75' Core #3, 6266'-6296', rec'd 9'. RIH w/core #4, wsh over core in hole f/core #3, 6276'-6296', cut core #4 f/6296'-6327', rec'd 31.5'. Core #5, 6327'-6387', POH. The above is correct Signature For form preparation and (~stribution, see Procedures Manual, Sd'ction 10, Drilling, Pages 86 and 87. Drilling Superintendent .ARCO Oil and Gas Company Daily Well History-Final Report Instructiona: Prepare and submit the "Final Resort" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Ref~ll" should be submitted also when operations are suspended for an inclefinite or appreciable length of time. On workovers when an official test ie not required upon completion, report completion and representative test data in blocks provided The "Final Ral:l,~t" form may be used for reporting the entire operation if space is avatlal~le. District ICounty or Parish I Alaska Field Jtease or Unit Kuparuk River I ADL 25643 Auth. or W.O. no. ITitle AFE AK0481 j Drill Doyen 9 API 50-029-21481 Operator I AR.Co. W.I. ARCO Alaska, Inc. J 56.24% IDate 11/18/85 Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m, 11/26/85 11/27/85 11/28/85 thru ~2/02/85 Complete record for each day reported Accounting cost center code State North Slope Borough Alaska Iotal number of wells (active or inactive) on this. Ost center prior to plugging and l bandonment of this well our ~ Prior statue if a W.O. 1400 hrs. 9-5/8" @ 3102' 6502', (115'), Coring Wt. 9.8, PV 15, YP 10, PH 9.5, WL 5.6, Sol 10 Rec'd 60' f/core #5. Core #6, 6387'-6447', rec f/6447'-6502', incompl. 'd 60'. Core #7 9-5/8" @ 3102' 6540', (38'), Drlg Wt. 9.9, PV 41, YP 6, PH 9.0, WL 5.2, Sol 10 Fin core #7, 6502'-6508', rec'd 53.67'. Core #8, 6508'-6529', rec'd 15.25'. PU BHA, RIH, rm 6198'-6529', drl 8½" hole to 6540'. IWell no. 3F-10 12/06/85 Old TD New TD PM Depth 6650' TD 6512' PBTD Released r,g Date Kind of rig 1830 hrs. 1/29/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) 0il Single Producing me~hod Official reservoir name(s] Flowing Kuparuk Sands Potential test clara 7" @ 6603' 6650' TD, 6513' PBTD, (110'), RR 9.8 ppg Brine Drl to 6650', 20 std short trip, C&C, TOH f/logs. RU Schl, log w/DIL/GR/SP/SFL f/6639'-3100', GR to 2000', FDC/CNL f/6639'-3100'. Attempt to log w/LSS, tight hole @ 3800', POH, RD Schl. RIH, rm 3758'-3826', cent in hole, C&C, TOH. RU Schl, attempt to rn LSS, would not pass 4643', TOH. Rn SHDT f/6639'-3100', TOH. ?U LSS, log f/6639'-6000'. Rn RFT @ selected intervals. RD Schl. TIH, C&C, TOH, LD DP. Chg rams to 7" & tst. RU & rn 152 its + 2 mkr jts, 7", 26#, J-55 BTC csg w/FS @ 6603', FC @ 6513'. Cmt w/200 sx class G. Bump plug. ND BOPE, NU & tst tree to 3000 psi. RR @ 1830 hrs, 11/29/85. ;'-', Arctic Jacked well w/175 sx PF "C". Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump Size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abov~ i_~ cmrr~ct Signature aa- For form preparation and dis~bution see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent 3F-10 CORE DESCRIPTION Core ~ 1 Core ~'2 Core #3 Core ~4 Core #5 Core Core Core 6215 - 6245 ; cut 30 , recovered 30' Brown, fine-grained sandstone 6245 - 6266 ; cut 21 , recovered 20'9" Brown, fine to coarse grained sandstone 6266 - 6296 ; cut 30 , recovered 9'6" Brown, very fine-grained sandstone and interbedded silty shale 6296 - 6327 ; cut 31 , recovered 32' a/a 6327 - 6387 ; cut 60 , recovered 60' a/a 6387 - 6447 ; cut 60 , recovered 60' Sandstone and interbedded silty shale; sandstone, brown, very fine-grained 6447' - 6508'; cut 61', recovered 53 '8" Brown, very fine-grained sandstone and silty shale; black shale wish minor siltstone 6508' 6529'; cut 21' - , recovered 15'4" Black shale ; - ? GRU12/CDO1'tw 12/16/85 8UB. SURFA DIRECTIONAl. SURVEY ~]UIDANCE [~ONTINUOU$ [~OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED _ 3F-lO ( ' FSL, 1:1~' FEL, S19, KUPARUK, NORTH SLOPE, ALASKA Je~ Reference No. 71160 WEST RECEIVED FEB28 ~ Alaska Oil & 6as Cons, ~ T12N, RgE) [8-JAN-85 Compute, ~¥: HALSTEAD '~CT 2IR~CTI]N~L SURV-Y -UST,gME~ LISTINS ARC] ALaSKa, IN~. ~F-13 KUP~RUK SURVEY ~TE: 12-23-~S ENGINEER: k-ST ~ETHDDS Om C2MPUT~TIDN TgOL LDC~TIJN: T~NSENTI~L- &VS,.IGC2 INT~RPGL&TI]N: LINEAR VErTICaL S:'CTI3N: fl.]RIZ. ..mIST. PRCJECT~}~ aZ'MJT-~ a Z I '4 J T H 3= S 3'J T't ~'9 3'3 51 ~IIN N=ST COMPUTATIDN DAT5: 18-JS, N-3$ PAG~ 1 ~eCO ALaSKa, INC. 3F-lO KJPARJK NgRTH SLgPE,ALASKA INTERPOLATED VALUES FOR EVEN 1DO mEET TRUE SJB-SEA MEASURED V£RTZCaL VERTICAL DEPTH DEPTH O~PFH 0.03 0.00 -93.00 100.00 100.03 7.00 ZO0.O0 200.00 107,00 300.00 300.00 207.00 400.00 400.00 307.00 500.00 499.99 405.99 500.09 599.99 506,93 700.00 699.99 505.99 800.00 799.99 705.99 900.00 899.99 805.99 1000.00 999.98 905.98 1100.00 1099.99 1005.93 1200.20 1199.~7 1105.97 1300.9) 1299.97 1205.97 1400.00 1399.96 1305.9~ 1500.00 1499.36 1405.96 1500.00 15'99.95 1506.95 1700.00 1699.95 1606.95 1800.00 1799.95 1705.95 1930.09 1899.94 1805.9~ 2000.00 1999.94 1905.9~ 2100.00 2099.92 2005.92 2230.0~ 2199.52 2105.62 2300,00 2298,72 2205,72 2~00,00 2396.30 2303.90 2500.00 2~9~.17 2a01,17 2590.00 2589.86 2~95.86 2700.00 {683.65 2590.65 2~00.00 775.63 2632.63 2900.00 2865.14 2772.1~ 3100.00 3200.00 3 !6,51 3330.00 3213.22 3¢00.00 3299.~7 3500.00 3385.47 35DO.OD 3471.31 3?00.30 3557.05 3800.00 3642.74 3900.00 3728.~9 CDORSE V=~TICAL 93G.~S DEVI$TION 4ZIWUTH S=CTIDrq SEV=RITT 3EG ~IN DmG Mlq FEET 3EG/iO0 0 0 N 0 0 : 0.00 0.00 O 7 S 39 3 W 0.12 0.37 0 16 S 44 45 W 3.49 0.21 0 20 S 6 7 W 0.98 3.07 0 ia $ 23 39 W 1.49 0.17 0 10 S 34 15 W 1.95 3.26 0 10 S $6 14 ~ 2.0~ ~.2~ 0 18 S 70 17 E 1.99 0 24 S 50 9 = 1.76 0.13 0 31 S ~6 23 E 1.73 3.25 0 38 S 59 25 E 1.59 J.1J = 1.41 3.19 0 38 S 59 15 0 36 S 70 42 c 1.17 0 30 S 62 39 E 0.84 0.25 0 38 S 51 ~ E 0.87 0.43 0 22 S 35 59 E 0.73 0.62 0 27 S 51 2B ~ O 82 0 45 0 29 S 64 16 .-_ 0.~7 1.O~ 0 30 S a3 3~ E 0.~8 0.92 0 19 S 21 32 E O.gO 0.2,3 0 2 5 9 11 15 13 21 27 11 S 57 9 E 0.76 1.28 33 S 23 39 W 2.29 57 S 2~ 35 W 9.7~ 2.95 19 S 3~ ~ W 22.~5 ~.07 58 S 35 55 W ~1.77 1.~ O S 313 59 ~ 64.90 3.9! 50 S 33 19 W 93 ~2 ~ 7~ 35 S 32 39 N 12~.27 2.73 45 S 32 3a ~ 157.14 3.31 ~8 S 33 2~ W 211.37 I.~ 2860.05 2945.82 3033.61 3120.22 3205.47 3292.47 3378.31 3~6~.05 3535.4'3 29 29 29 30 30 30 30 31 30 30 14 S 31 12 W 258..51 2.1~ ~6 .3 31 a ~ 307.74 3.63 55 S 30 43 w 355.80 10 S 30 23 W a05.13 0.51 35 S 32 33 w ~56.13 2.77 ~6 S 37 20 R 305.9~3 1.11 55 S 33 5 W 338.25 D.2~ 1 S 38 19 W 50~.70 :9.29 39 S 3~ 35 w 661.22 3.27 56 S 38 55 'a 712.65 0.25 9&T: 3r- S:JRVEY: 12-23-~q5 KELLY ~]:JSHIN3 =LEVATIJN: ~"JGINEE~: WEST 5. 5. 5. 7. 7. 7. 16. 27. ~2. 61. 112, 146. 1~3. 256. 308. 351 . 395. '-,35. 517. 553. 59 ?. ']UTq C39RDINAT:'S 2&ST/~:ST O. O0 0.02 0.31 0.51 0..55 0. g 9 0.q5 0.43 0.10 0.75 1.53 2.50 3.59 4.53 5.24 5. '35 6.~6 7.16 7.53 5.12 ,~.47 8.15 4.38 2.55 14.01 28.19 45.56 64.85 85.85 110.15 135.66 161.32 186.81 212.22 238.24 267.30 293.31 331,17 363.2Z 335.~2 gIST. F ,-' =T O.OO O. 17 0.4) 0. ~9 1.54 2.00 2.12 2.13 2.38 2.97 3.79 4.77 5.77 6.55 7.61 ~.27 13.09 13.77 11.37 11.5'9 12.73 15.92 27.75 57.20 93.72 130.23 15~.42 213.92 261.35 311.26 360.94 ~10.92 ~51.53 512.40 563.41 514.61 ~ ,55.8 '9 717.10 9'?.90 FT D[-:o ~RTUR: 2ZIvlUTH S 31 14 ::, 31 13 S 31 10 S 31 5 S 3l S 31 30 S 3236 S 37 3 S 33 27 4RSO 4L4S~A, I~C. 3:-10 KdP&RUK ~]RTH SLOPE,ALaSKA COMPUT&TIDN OArE: 1B-JAN-85 3&T= 3~ SJqVEY: 12-23-35 K=LLY 5USHII',~G ELEV&Ti,DN: ~NGINEER: W:ST TRUE ME~SURE] V=RTIC~L OEOTH DEPTH 4000.00 3814.21 4100.00 3399.90 4200.00 3985.80 4300.00 4400.00 4157.99 4500.00 4244.%5 4500.00 ~331.22 4700.00 ~413.30 a~O0.OO 4505.53 4900.00 ~593.23 5000.00 ~581.14 5100.00 4769.56 5200.00 ~58.35 5300.00 4947.~9 5~O0.OO 5038.38 5500.00 $129.3~ 5500.00 5221.34 5700.30 5313.80 5800.00 5~07.~1 5900.00 5502.00 5000.00 5597.~5 5100.03 5693.11 6200.00 5789.77 6300.00 5884.3'9 6&O0.OO 5979.82 6500.00 6075.16 6500.00 6170.~9 6550.00 6218.15 INT~qPOL&TE9 VALUES FOR EVEN 100 SdS-SEA VERTI'aL DEPTH COJRSE DEVIATION AZIMUTH DEG MIN D:G 3721.21 3~00.90 3892.80 3979.79 406~.99 %151.45 4238.22 ~325.30 4412.63 ~500.23 31 1 S 39 3 30 55 S 39 30 %6 S 39 30 33 S 3) 2 30 19 S 39 9 29 59 S 39 1l 29 3~ S 39 lO 2'9 15 S 39 5 2~ '59 S 39 7 2:5 ~4 S 39 5 ~5~8.14 ~676.56 ~755.36 4945.35 5035.39 512~.04 5229.80 531~.41 5409.00 28 5 S 39 51 27 ~1 S 38 42 2b %8 S 38 42 26 $ S 38 55 24 35 S 39 29 2~ 10 S 39 Z5 22 ~8 S 39 21 15 S 37 S~ 19 ~9 S 33 50 18 4 S 38 ~9 5600.11 55)5.77 5791.38 5835.82 5982.15 5077.&9 5125.15 VERTICAL SECTION :E=_T 764,16 ~15,69 366,89 917,93 968,62 1018,~7 1068,56 1!17,72 1156,44 1214.6~ 1252.32 1309.02 135~.~9 13'~.53 14~2.09 i~,.53 1523.50 1560.~4 1595.00 1628.41 Z55B.22 1557.35 1716,43 1745.71 1775.~5 I~35.8~ :':ET O: DO:3LEG S;VE~IT¥ 0:3/100 0,14 0,31 O. ;"~ 0,25 0.2~ 0.20 0.36 ND2TH/ '3UL &R C 'SOOTH : T 53;9.22 57~,24 717.99 757,53 795,}B ~5.~2 .97~.~4 91.!,55 ~50,37 ~7,79 ]]RDINAT=S AST/~EST F~ST 27.'~9 W 50.35 w 92.5~ W 24.~0 W 56.76 W 8~.52 W 1~.$2 ~ 50.~6 W 61,73 W lZ.15 W 0.70 132,.~2 $ 742.12 3.25 1061.25 S 771.35 1.31 1197.14 S 800,3) 1.32 11~1.~5 ~ 82B.~1 3.35 1164,~4 S ~54,~2 1.24 1196,~1 3 ,~$1.2~ 2.23 1227.70 S 906,,56 1.35 1257.32 S ~2'),~0 1,~5 1284,51 % 951,51 1.75 1B09.79 S 972.01 1333.26 S 1356.30 S lO 137~.35 1402.67 S 10 1425.45 S 10 1430,3,9 S 10 l~?a.l~ S 10 !~.:56.!2 S 11 H3RIZ. DIST. 0,21 O, 31 O,~$ O,O0 0.00 759.38 31~.72 ~70.75 921.53 1322.31 1120. }5 115"~. 57 1217. ~ 125:5. 31 1311.¥7 1357.~9 1402.3~ 1%,'.q6.17 1 '525.19 15~3.53 159~;. 59 1631.05 90,43 26,05 43,7~ 51,B5 80,32 98,B3 08,11 a zI ,I{JT H 3~:3 '41q N3RTH SLOPE,ALASKA INTER°SLaTE3 VflLJES ;OR EVEq 1O0O TRUE 5JB-SEA MEASURED VERTICAL VERTICAL ]EmTH DEPTH DEPTH 0.00 0.00 -93.00 1000.09 999.98 905.98 20D0.00 1999.94 1905.94 3000.00 2953.D5 286D.05 4000.20 381~.21 3721.21 5000.09 ~631.14 658~.14 6900.03 5597.~5 550~.45 6550.00 5218.15 5125.15 F~T CF C]JRSE VERTICAL DOGLEG DEVIATION ~ZIMUTM S5CTI3N SEVERITY DEG MIN D:G MIN FEET OEG/IO0 0.00 I. 59 258.61 754.16 1252.32 1~9.22 1 ,~ ~ 0.9 '9 0 0 N 0 O 0 3~ S 59 25 0 11 S 57 :~ 29 1/+ S 31 lZ 31 1 S 39 3 28 6 S 38 51 16 58 S 37 ~1 17 35 S 37 ,~5 9.00 0.19 1 · 23 2.1~ 0.14 0.73 0.1~ RECT~N N0qTH/ · 223. 535. 132~+. 1333. 3~T- 3: SJ~V-Y: 12- 2 3- ,.q '3 q'LLY gUS'tt'~C. F.L~V,ITiO'..i: :N,3iN~ =q: 4~:3T SULA~ CJJ~DINATES q]RZL. SDIJTq EaST/WEST O[ST. T ;~ET F~ET O0 N 0.00 E O.O0 ~3 S 1. 53 E 3. 7-) 05 S 3.&7 E 11.59 5! S 135.55 .' 251. 55 2,2 S 427.~9 W 76J.3~ 82 S 742.12 W 1265. ~1 25 S 990.43 W 1550.b3 12 S llO,t.ll W 1~53.77 DEPARTURE aZZqUTd J£3 MIN COMPUTATION DATE: 18-J~IN-B5 P~GE 4 ~CO ~LaSK~, INC. 3~-10 KJP~RUK NgRTH SLOPE,aL~SK~ ZNTERPOL~TED VALUES FOR EVEN 100 FEET TRUE SDS-SEa MEASURED VERTICAL VERTI'&L DEPTH DEPTH DEPTH 0.00 0.00 -93.00 93.00 93.00 0.00 193.00 193.00 100.00 293.00 293.00 200.00 393.00 393.00 300.00 493.01 ~93.00 aO0.O0 593.01 593.00 502.00 593.01 693.00 600.00 793.01 793.00 700.00 393.01 893.00 800.00 ~93.02 993.00 900.00 1093.02 1093.00 1000.00 1193.93 1193.00 1100.00 1293.03 1293.00 1200.00 1393.04 1393.00 1300.00 1493.04 1493.C0 1400.00 1593.05 1593.00 1500.00 1593,05 1693.00 1500.00 1793.05 1793.00 1?O0.O0 1393.05 1893.00 1800.00 1993.05 1993.00 1903.00 2093.07 2093.00 2000.00 2193.35 2193.00 2100.00 2294.21 2293.00 2200.00 2395.02 2393.00 2300.00 2498.79 2~93.00 2400.00 2503.30 2593.00 2500.00 2710.07 2693.00 2600.00 2819.15 2?93.00 2700.00 2~31.59 Z893.00 2800.00 3045.97 ~93.~ 2900.00 3151.23 ~093, 3000.00 3276.62 3193.00 3100.00 3392.49 3293.00 3200.00 oo.oo =oo.oo 3975.25 3793.00 3700.00 4091.95 3893.00 3803.00 COORSE V£RTIC~L DOGLEG 3EVICTION AZIMUTH SECTION SEVERITY ]cG 4IN DES MIN FEET 9EG/iO0 0 0 N 0 0 0 7 S 28 35 0 16 S ~,7 35 0 ZO S 5 35 0 18 S 22 25 0 11 S 35 33 0 9 S 63 33 0 18 S 70 ~ 0 24 S 51 22 0 30 S 55 45 0.00 0.00 0.10 0.35 0.45 0.21 0 · 94 0 · 03 1.45 0.19 1.92 0.2~ 2.05 0.33 1.90 0.03 1.76 0.22 1.73 0.20 1.60 0.02 1.~2 0.19 1.19 3.12 0.35 0.~0 o.g7 0.55 0.72 0.93 O 84 0.65 0.89 1.1~ 0.38 0.94 O. 8g 0.23 0.76 1.12 2.00 ~.35 '~. 0 g 3.38 21.92 3.90 40.~5 1.73 64.5~ 3.95 94.85 3.77 131.98 2 .¢3 175.1a 3.55 226.15 1.75 2:31 · 09 O. ,33 337.71 0.49 394.55 0.5-~ 452 . 34 2 · 59 511.47 O.gl 571 · 25 D · 15 531.32 .3.28 691.3'~ 0.17 751.41 0.12 ~11.56 }.31 0 38 S 59 0 38 S 5~ 53 0 36 S 7017 0 31 S 54 21 0 38 S 4~ 35 0 21 S 43 25 0 29 S 61 29 0 31 S 59 24 0 29 S 37 0 19 S 21 49 0 9 S 85 ~ 2 16 S 23 44 5 45 S 28 ~ 9 6 S 34 10 11 55 S 37 1 14 37 S 39 2 13 ~$ S 35 14 21 52 S 32 32 25 25 S 32 42 28 9 S 32 5~ 29 ~9 S 31 i 29 ~a S 30 50 30 3 S 30 28 30 34 S 32 9 30 47 S 37 33 30 57 S 33 10 31 O S 3q 25 30 57 S 33 45 31 0 S 39 5 30 56 S ~g ~ 9&T- i3F SJRVDY: 12-23-35 K-LLY 51J S-~ l N'3 SNGIN=ER: W=_ST Sd~-S~ RECT&N NORTH! SUL&R SOUTH T 0.30 N 9.15 S O. 35 S 0 · ,~ I S 1.37 S 1.77 S 1.93 S 2.07 % 2.35 S 2.3,~ S 3.3-~ S 3.96 S ~.49 S 5 .~6 S 5.38 S 6.52 S 7.0~ S 7.51 S 7.91 S ~.05 S 9.51 S 15.75 S 26.~7 S ~2.36 S 59.76 S ~5.02 S 116.12 .S 152.35 S 195.78 S 243.14 S 2'~2.23 .S 341.75 S 392.0,~ S 440.~1 S ~7.55 S 534.71 S 5~1.54 S 528.32 S 575.04 ] COORDINATES E&ST/~EST F::T 0.00 E 0.02 O.Z') W 0.50 0.53 0.88 W O.~a W 0.49 w 0.05 E 0.70 E: 1.56 E 2.53 E 3.52 E 5.18 E 6.$1 E T.iO 7.53 E ~.11 8 ~5 - 8.28 - .7o 2.02 W 13.51 W 27,99 w a6.16 W 66.85 W 90.19 w 118.36 W 1&7.37 W 176.92 W 206.28 W 236.17 'W 270.54 w 307.35 W 344.59 W 382.36 W ~1').$5 W 4c7~..75 H]RIZ. FE-T 0.00 0.15 0.~5 1.50 1.98 2.13 2.12 2.35 Z.~Z 3.73 ~.70 5.70 6.59 7.53 3.36 9.21 10.03 10.?1 11.33 11.57 12.51 15.44 26.)4 44.13 66.9~ ~5.7~ 133.~9 177.~7 22~.78 28~.31 341.61 599.1B W57.71 515.87 575.34 536.13 595.90 755.69 315.53 ~3.OC DEa&2TUR= &ZIqUTH 3E3 ~i'4 ~qC9 ~L~$K~, INC. 3=-10 KUP~RUK N]RTH SLD>Et~Lfl$<A GAT ' 5F- SURV-Y: 12-23-35 ~=LLY ~US'~iN,S ELSVaTI3N: : NI,$ZN-- :': ~: W=ST ) ] . J') =T INTErPOLaTED VALJE$ FOR :V=N 100 =EET C= TRUE SU,3-SEA MEASURED VERTIC&L VERTI'~L DEPTH DEPTq OEmTH ~20~.33 3993.00 3900.00 4324.62 ~093.J0 ~00~.00 ~%~0.5~ ~193.00 ~lOO,O0 4555,99 ~293,0J ~200,OO ~570.99 4393.00 4300.00 ~795.57 4~93.00 ~OO.OO ~Bgg. T~ ~5']3.00 ~500,00 5013.45 4693.00 4600.00 5126.46 ~793.J0 4700,00 523~.72 %893.00 ~00.00 5350.05 ~993.00 ~900.00 5~60.0& 5093.00 5000.00 5559.50 5193.00 5103.00 5577.66 5293.00 520~.00 5784.65 5393.00 5300.00 5890.53 5493.00 5400.00 5995.35 5593.00 5500.00 6099.B~ 5693.00 5609.00 6204.~2 5793.00 570~.00 6309.02 5Bg3.00 5BO0.O0 6~13,B2 5993.00 590D.00 651~,71 5093.00 5000,00 6523,62 5193,00 6100,00 6550.00 621~.15 5125.15 SU~-SE& COJRSE V=RTIC~L DOGLEG R~ESTaN 3EVI4TIDN AZIMUTH S:CTION :SEVERITY N]RTH/ DEG ~IN DEG MIN FEET OEG/IO0 FEE 30 ~6 S 39 4. W ~71.17 0,15 30 ~1 S 39 3 W 930 44 . · ,,~ 30 11 S 39 11 W ~9.05 0.3~ 29 ~6 S 39 10 W 1,946.76 0.35 29 21 S 39 8 W 1103.52 29 2 S 39 7 w 1159.45 0.52 28 ~4 S 39 6 W 1214.56 28 0 S 38 4~ W 1268.65 C.79 27 35 S 38 40 W 1321.31 0.52 26 29 S 3~ 47 W 1372.29 25 10 S 39 12 W 1421.20 2.10 24 28 S 39 29 W 1467.0l 0.31 23 19 S 39 26 W 1511,50 0,37 21 32 S 37 55 W 1552.69 1.35 20 4 S 33 41 ,J 1590.73 1.63 18 1~ S 38 55 W 1625.48 1.67 16 59 S 37 42 W 1656.85 O.2~ 16 56 S 37 4B W 16~57.32 0.21 16 54 S 37 22 W 1717.71 ~.21 17 15 S 37 13 W 174B.3B 3.29 17 30 S 37 30 'W 1779.72 0.55 17 33 $ 37 4R W 1~11.33 O.OO 17 35 S 37 40_ 4 1~43.02 0.00 17 35 S 37 48 W 1950.9g ~IJL~R SOJTH T 721.32 767. 34 ~312 · 31 357.54 901.55 944.94 9'37.$9 1,329.77 1070 .H4 1110.55 1143.70 S 11 ,~ 4, C 5 S 121.~, F+2 S 1250,5q S 1250,50 5 1307,52 S 1332,1~ S 1355,27 S 1380.37 S 1404,89 S 1&29,75 S 1~54.77 S 141),82 S 1~35,12 S C ,? CR 9 l N & T I! S EAST/W:ST ~ 5 ET HDRIZ. CI3T. F: ' 'T 495.34 532.68 56~.,57 6C6,15 642.01 577.29 712.07 745.!0 77'9.05 alO.~3 w ~75.02 w 934.11 w 9'92.57 W 1353.14 w 1105.79 W 1152.60 w 1217.51 W 1271.65 W 1324.24 W 1375.1B 5~1.55 870.73 899.35 92~.90 948.31 B70.17 BBO.60 1008.26 1026.83 1045.41 1~24.04 1.~6~.78 151.~,21 1553,38 1593,41 1525,1" 155'9,52 15a9.9~ 172o.4o 1751.1o 1064,42 W 1782,~7 1053,79 W 1814..}9 1103,23 w 1~45,~0 110~,11 W 19~,77 COMPUt&TION O~rE: 18-J&N-96 p&l]~ 5 ~RSO ~L~SK~, INC. 3:-10 KJP4RUK N]RTH SLOPE,~L4SK& TOP TOP B~SE TD KUP4RUK C KUm4RUK C KUP4RUK 4 INTERPOLATED V~LdES FOR M~4SJREO D:PTH BELOW K& 6199.00 5268.00 ,5355.00 6~92.~0 5512.00 5550.00 ~HJSEN H]RZZ]NS 578?.32 5851.90 59~6.4~ 5067.5~ 60a6.60 b213.15 ] ~ 1,3i '~: 21' SJ~-S7~ 5753.)0 5')?..$4 5993.$0 6125o15 ,,Dar= ]F SUeV~y: 12-25-~35 KELLY 5US'~iNG EL-V&Ti]h: -'~GZ'~ 2~R: JEST ~3.Og :SL, 89' F~L SJR:~C~ , S~C 1~ R EC T ~ NGU LA R N,] R T H/S 3U T 13/9.12 S 1418.09 3 1453.16 S 14~6.12 S _3CaT£JN ~T , T12~ C30RDIH&TgS E&ST/WEST 1025.J?' 1037.'2 1055.31 10~2.5~ w 11D~.11 ,,! FT J t4 CCMPUTATI]N DATE: 18-JCN-95 Pa'SE 7 ARCO ~LASKA, INC. 3m-10 KJPARUK NDRTH SLOPE, ALASKA DATe 9 = SJRV_--Y: K~LLY 'CU S H I I',~ ;] EN.CZNE=R: WEST T~P 3ASE TOP 9~SE ~BTD TD KUPARIJK C KUPARUK C KUPARUK ~ KUDARUK ~ 3~I,CIN: ,!1' FSL, ~EAS~RED DE~TH TVD 5:LDW K5 =RC~ K~ SJ~-S=& 5256.00 5851.90 6365.00 5946.4~ 5~53.44 ~512.00 5055.S0 6550.00 621~.15 5125.15 FT:L REC N J S JR , S T&N RTH 379 3 ~ 4 418 · <,. ~. 3 :aCE .]C~TZCN &T EC 1,~, T12N, giJLA~ CO]~DIN&TES · 1g 5 1J25.~7 ,~ · 66 ~ 1~3.7.72 · 09 5 1255.51 .3~ S 137~.~ ~ .1~ ~ 1052.5~ W .12 > 110~.11 ~ FINAL WELL LOSATI3N ~T TRJE SJB-SEA MEASURED VERTICAL VERTICAL DEOTH 3EPTW DEPTH HORIZONTAL ~EP&RTU~: 31ST,~NCE ,aZI',i~TH ~EET 3=3 MIN =T j ~4 6650.00 5218.15 5125.15 1:~5~.77 S 3,5 42 W SCHLUMBEROER 0 1RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL ~F-~O FIELO KUPARUK COUNTRY USA RUN ONE DATE LOGGED REFERENCE 00007]]60 WELL NAME: 3F-10 - ~URFACE LOCATION: Z2' FSL, 90' FEL, S19, T12N, RgE VERTICAL I000 PROJECTION PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCPI. EO IN VERTICAl. [DEPTHS HORIZ SCALE : I/SO0 iN/FT WELL NAME: 3F-lO _ - ~URFACE'LOCATION: kz' FSL, 90' FEL, S19, T12N, R9E -I~ -~0 O 0 ,~0 I I](:IG 1500 2000 ' ' ' I I ~ ' ' ;~; i:- i "-'7: .......... 7 .... ~-';= ;=' i_:;; _;..i .... '-'~;- - ~'_;_ _ : ' · · ' ~ ' · ' I · . ~ ' ! · ~! i t ' ' I -I- ' l''' : · ' ' -~ ~ ...... ! ~ v~R~r~----~~-~ ......... : ........ : ....... - ........ t ..:..: ......... ~.:-: .... i .............. ; .... ~ ' J : ' ' ' : ' !'- * ' ....... ~...: .......... ~ ........... = : ': :'::':.:: :::::':__~..2:_:.: .~:7.:'::.:::.::':'-':_': ':"::::::-:::::., .... ::.::: ':.~.: :' :::.::":': :. J , :...; .... 4..: ...... ~ .... ; .... ................. t .......... ; ................... ; ....... , ........................... : ............. ~ .... ~ .... ............... - ..... * ......................... ~ ............ ~ ........ * ........................... ~ ..... + ......... t ..... : .... .-~-. :.-i ....... + ............................ k ............ , ............ ~ ........................ ; .......... i .......... , .......... : . . . ................ ~ ........... ~ .................. v ....................................... i ............ .......... ~ .......... : ........ : ~ ~ ~ '~ - ! ' : ' ' , i ........ ~ .......... ~ ..................................... .......... ~ ............ ~ .................................. J ~ .................. ~ ................... ', ......... i -:-..: ....... : .... ::'i ...... t ...... , ..... ~ .... ::'::::~:: -J:7':":: ....... :_.;.: .... '. ........ :::::':::"::::_:..:. :::::::::::::::::::::::::::::::::::::::::::: :.-:': :"::'"~: : :i :::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::: :: :': ::~ ; ':i-:, ,.; ......... : .................... ~ ......... ~ ........... ...... i ...... : ......................... ,__..._~ ........ S ...... : ...... : ..... : .... : ..... : .... : .......... : ........ ~ ....... + .................... 1 ......................... ~ ................... ~ .... , ......... , ............. ~ ........... ::::::::::::::::::::::::::::: :::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: : : ..... : ...... : ..... ::_.. '. ~.: ......... : ....... : ......... : .... :.. ' .... i ..... ~ ...... : ...................... ' ..... : ................................................ : .... ; ........ : ............. ] ............ ~ ................. ~ ...................................... ~ ............ : ......... ~ ~ ....... : ......... : ..... : ............... : ........... PROJECTION ON VERTICAL PLANE 219. - 3c~. SCALED IN VERTICAL DEPTHS HORIZ SCALE = I/S00 IN/CT VERTICAL PROJECTION 219. WELL NAME: 3F-lO SURFACE LOCATION: 22' FSL, 90' FEL, slg, T12N, RgE ~ = !/,~10 IN/F? · ; HORIZONTAL PROJECTION S~UTH -2S00 -2500 I -ZOO0 - 1500 - 1000 -SO0 0 500 I ooo ISOO EAST EXACT RAOIUS OF CURVATURE METHO0 TIE-IN LOCATION MEASURED DEPTH O. 0 FT TRUE VERTICAL DEPTH 0.0 FT DISTANCE NORTH 0.0 FT DISTANCE EAST 0.0 FT BOTTOM HOLE COURSE LENOTH . COURSE AZIMUTH MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE SOUTH DISTANCE WEST LOCAT I ON 18S9.6 FT 2]6.? OEO SSSO.O FT 62]8.3 FT ]486.0 FT ]108.0 FT REF 000071160 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. , . O~.~TOR, ~ELL ~AHE~ A_ND-NUHBER- - · - . Reports and Haterials to be received b~ · Date Required Date Received Remarks · Completion Report ~,,.~ : ~__//.1~.' O~~ ~__~7~ , .,Directional Survey/)_, -_._ Production Test Reports ARCO Alaska, Inc. - Post Office ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-31-85 TRANSMITTAL # 5496 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Open Hole/ Schl/ One * of each 5" DIL/SFL-GR 2" DIL/SFL-GR ~5" DEN/NEU (poro) 2" DEN/NEU (poro) ~5" DEN/NEU (raw) ~" DEN/NEU (raw) Cyberlook LSS/WF · ~ Dual Dipmeter RFT Log 5" DIL/SFL 2" DIL/SFL 5" DEN/NEU (poro) 2" DEN/NEU (poro) 5" DEN/NEU (raw) 2" DEN/NEU (raw) ~ Cyberlook 5" LSS 2" LSS 11-27-85 Run 0I 11-27-85 Run 0i 11-27-85 Run 0i 11-27-85 Run 0i 11-27-85 Run 01 11-27-85 Run 01 11-27&85 Run 01 11-28-85 Run 01 11-28-85 Run 01 11-28-85 Run 01 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-09-85 Run #2 11-10-85 Run #2 11-10-85 Run 02 1800-6631 1800-6631 6000-6605 6000-6605 6000~6605 6000-6605 6000-6582 6000-6615 3098-6628 6216-6431 3026-7040 3026-7040 4400-7015 4400-7015 4400-7015 4400-7015 6300-6900 3026-7032 3026-7032 5" DIL/SFL-GR 2" DIL/SFL-GR 5" DEN/NEU 2" DEN/NEU 5" DEN/NEU 2" DEN/NEU Cyberl~k ~ RFT Log (poro) (poro) (raw) (raw) 11-17-85 Run #1 11-17-85 Run #1 11-17-85 Run #1 11-17-85 Run 0i 11-17-85 Run #1 11-17-85 Run #1 11-17-85 Run #1 11-16-85 Run 01 3410-7770 3410-7770 7050-7744 7050-7744 7050-7744 7050-7744 7260-7427 Receipt Acknowledged: State of Ak*bl/se Rathmell*bl NSK Clerk*bl Drilling*bi D & M*bl Vault*films Date: ARCO Alllkl. Inc. ii · Sul~stchlry o! AIIInhcR~cl~helO¢omplny ARCO Alaska, Inc. Post Office B. .,,0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN .~D: ARCO ALASKA, INC ~ ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE12-19-85. TRANSMITTAL # 5473 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4// G3-18-85 Run #1 4570.0-9471.0 ref#'70997-£~r44f~ ~2H-9// 12-02-85 Run #1 1800.0-8113.0 ref# 71048 / -- ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 '~2H-12 /, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~2U-7// 03-19-85 Run #1 3594.5-8179.5 ref# ~2V-16// 06-03-85 Run #1 2973.0-7168.0 ref# 70952-f~-d~p ~3A-10]! 11-09-85 Run #1 3179.0-7014.0 ref# 70960 ~3A-11', 11-16-85 Run #1 3208.0-7330.0 ref# 70989 ~ 3A-12U 11-23-85 Run #1 3797.0-8006.0 ref# 71003 '~3A-13;/ 12-01-85 ~un #1 1800.0-7597.0 ref# 71047 ~3A- 14'/ 12-09-85 Run #1 0144.5-7818.0 re~= 71073 ~.~ 3C-9~, 07-10-85 Run #1 3920.0-8332.5 ref# 70996--~_~~ 3F-8~/ 11-09-85 Run #1&2 0115.0-7040.0 ref# 7.0994 ~3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 '~3F-10;~ 11-27-85 Run #1 1800.0-6631.0 ref# 71037 '~3F-11w 12-05-85 Run #1 0148.0-8618.5 ref# 71061 ~J3J-9,/ 11-24-85 Run #1&2 0~91.0-6789.0 ref# 71034 ~ 3J-10'~ 12-08-85 Run #1 0096.5-7348.5 ref# 71074 3~-13-~ ~??~-3- ~p~-/~o~- ~~Z ~ -" ' ' :' '~ ~ ~ . - ~'~(~//-I~-~ _ ~~ ........ '. · Receiot Acknowledged ETATE OF ALASKA* Date: ARCO Alaska, Inc. Post Office Bo. J360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are the November monthly reports for the 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures following WSP-20 263-4944. wells' RECEIVED bu ~ Gas Cons. Anchorage Comrnisslort ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompan¥ - STATE OF ALASKA - ALASKA C,_ AND GAS CONSERVATION CO~._.,AISSION MONTHLY RERORT OF DRILLING AND WORKOVER ORE:RATIONS 1. Drilling we~X~ Workover operation ~ '_~ Name of operator 7. Permit No. ARCO Alaska, Inc. 85-271 13. Address 8. APl Number ! P.O. Box 100360, Anchorage, AK 99510 50- 029-21481 4. Location of Well atsurface 22' FSL, 90' FEL, Sec.19, T12N, ReE, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 93' RKB ADL 25643 ALK 2574 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3F-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1400 hfs, 11/18/85. Drld 12-1/4" hole to 3110' Ran, cmtd & tstd 9-5/8" csg. to 6215'. Cored f/6215' - 6529' Cont'd drlg 8-1/2" hole to 6650'TD (11/27/85). Ran logs. 7" csg. PBTD = 6512'. Secured well & RR @ 1830 hrs, 11/29/85. Drld 8-1/2" hole Ran, cmtd, & tstd 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set @ 115'. Conductor report not yet received, 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3102'. Cmtd w/840 sx PF "E" & 390 sx PF "C". Performed top job w/100 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe L~ 6603' Cmtd w/200 sx Class "G". 14. Coring resume and brief description Core #1 f/6215' - 6245'; cut 30' Core #2 f/6245' - 6266'; cut 21' Core #3 f/6266' - 6296'; cut 30' Core #4 f/6296' - 6327'; cut 31' Core #5 f/6327' - 6387'; cut 60' , recovered 30' , recovered 20.75' , recovered 9' , recovered 31.5' , recovered 60' (cont'd on following sheet) 15. Logs run and depth where run DIL/GR/SP/SFL f/6639' - 3100' FDC/CNL f/6639' - 3100' SHDT f/6639' - 3100' , GR to 2000' LSS f/6639' - 6000' RFT - depths not available 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE Repor~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 TEMP2/MR62 Submit in duplicate MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 3F-10 (cont'd) ITEM #14: Core #6 f/6387' - 6447'; cut 60', recovered 60' Core #7 f/6447' - 6508'; cut 61', recovered 53.67' Core #8 f/6508' - 6529'; cut 21', recovered 15.25' MEMORANDUM TO: THRU: ._ FROM: State of Alaska ALAS~ OIL Ai~D GAS CONSERVATION COP~ISSION C. ~.~atterton Chai n/ Lonnie C. Smith Commissioner Bobby D Foster _-- -~" Petroleum Inspector DATE: November 21, 1985 ~,L~NO: D.BDF.!18 TELEPHONE NO: BOPE Test ARCO K.R.U. - 3F-10 Permit ~85-271 Kuparuk River field Wednesday, November 20, 1985: ~he BOPE test began at 10:45 ~.! and Was concluded at 12:15 PM. As the attached BOPE test report shows, there was one failure which was repaired and tested before I departed the location. In summary, I witnessed the BOPE test on ARCO's 3F-10. Attac~hment O&O #4 .5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION CO~iMISSION B.O.P.E. Inspection Report Operator Location: Date Representative Location, General ~ ~ Well Sign_~ ACCUM;o~ATOR SYSTEM General Housekeeping ~Rig ~ Full Charge Pressure ? ~~ Pressure After Closure Visual Audio Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure ! 3 o° psig psig min~ ~ sec. min~ sec. Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: , · psig Controls: Master Kelly and Floor Safety Valves Upper Kelly / %est Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Tes: Pressure Choke Manifold~5 Test Pressure No. flanges Adjustable Chokes / Hvdrauicallv ooeraued choke Test Results: Failures / Test Time / ~7.~ hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. / Distribution orig. - AO&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc. :--,st Y_,-~cc D-- ~0036© -g .... ~-~ 995-~ 0-0360 -_ - -~- ?~ November 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 3F-10 Dear Mr. Chatterton' We propose to change the approved drilling plan on 3F-10 as detailed on the enclosed Sundry Notice. If you have any questions, please call me at 263-4944 or Larry Kappmeyer at 265-6980. Sincerely, ~. Gruber Associate Engineer JG/tw SN/L070 Enclosure RECEIVED AInska Oil & Gas ConS. Con, mission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIv, MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL j~ COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 22' FSL, 90' FEL, Sec.19, T12N, RgE, UPI 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 85-271 8. APl Number 50- 029-71~R1 9. Unit or Lease Name 10. Well Number 3F-!0 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool RKB 93'; PAD 56' ADL 256#3 ALK 257q 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 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 change the approved drilling plan on Kuparuk 3F-10. A change in the directional planning will enable the Kuparuk core to be taken at a 12° angle. This enables the 9-5/8" casing to be set at 3087'PID (3033'TVD). Surface casing will be cemented with 825 sx PF "E" and 360 sx PF "C" cement. The target location will remain the same, with a change in TD location to 1378'FNL, 1255'FWL, Sec.30, T12N, RgE, UM. The 7" casing will be set at 6677'PID (6244'TVD). A revised proposal is attached. Estimated Start: November 17, 1985 RECEIVED ~l~xa 0il & ,~,~b 'J,,qs Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ /]/"/g~,/)~,..~ ~,tLZ~,L~L~ Title Associate Enqineer The space b~w-for"' Commission use Date Conditions of Approval, if any' Approved by By Order of COMMISSIONER the Commission / Submit "Intentions' ~n Triplicate Form 10-403 (LWK) SN/103 and "Subsequent Reports" in Duplicate Rev. 7-1-80 . i ) , j ..__ ..... ~ ...... PAD 3F_,_-L-WELL=~O r-~ o~2--~~~DLP~S~ ......... ~ KUPARUK 4tELD ~;~ 0 R TH-S ~PE-~wAL ASK-A-- ,, ~ - , ............................ .... ~- -'- - - ~~R~~ · TVD~3 ................. - ...... .... ', .......................... L .............. ~ ............. .... ~ .............. ~ ......... y ......... ~ ............. .................. ~OP- UGNU~SNDS --TVD~1888 ..................... ---- ~ - --2DDO ,--KOp~ TVD~2~~7 DE~=O~ -- ~- ....... PER 1 O0 ~ ~ . ........... - : ....... 9 .......... ._ ___ ...... }.~ ...................... k ~- _ .... - .............. - --'; ~ ........ ~-~- K-1 2 TVD=2833 -TM~2859 DEP=178 ..................... -- - ~ ~ ..................... ~ ........... L ......... ~ ...... ~ ...... L .......... '- ......... .... ~ _~ ...................... ~ ...... L ........... ; ...... : .......... ~ ._ . ' ~ __~__ ~ i : ~ ' ':g .... - x ", ......AV~R~E--~ffC[ E .... :~--~.-- -- ~----~-~-'- :~': ---J-:'~--: ~ ~:-:--:----31-' DEG-46-MIN -- ' ~: ::::--:- - ' ' -~0~'. ...... .~-' X T ......... .-: .... --': ..... --~ ......... ~-' __ -- __.__ __ {/ .............. ..... _. · - ~ .......... ~-- .... ~c::~ _ _ ._ .... _. --'= ........ [ ~,~=,-~OP ZONE-C-TVD=5773 TMD-6196-~P=lTlO-t .... -- : .... , ! ----_ ~-TAR~T ~TR- TVD=5911 - TMD-633Z DE~1748. --- C ' --' : ~ - '- ~ B~E_KUP SN~ ' TVD=B048 TMD=6477- TMD=17~7-~ - - - , ' T.D ~LOO PT)- TVD=6244 TMD=667T DEP=1819' - ~ f , , ~ .... ; ~TARGET._ANGLE - . ' , ~ ~ , .... ~ ..... ~ ~~~~ ~. ~ __._~ ~ DOO 2000 ' . ......i ...... ; ..... _ - . + ! ~ ........ ~ ....... ~ ............... , ; ~ ...... ff ....... :_ _ ~ ...... i ..... -- { ~ t , A~ ~-& GaS- CoilS. O~l~~ - - ~ ..... t , $ .I HI3R-T~,ON-T-At--PRO J_'EO T TON ] _ ' ' ' i --~RCO-ALASKh,-- t NC-. f - J - - i P~D-;~F; WELI_-~NO~ -10~?R_L~/-ISED-PROPOS^L- /. :~ _ I .... EASTHAN-]4H[P-STOOK~, , I~e' '---'-] ~JEST-~E ~ _~oo0: 2000__ · - r i 22"--FSL~ : ~-b'URFA~ - .................. 1 ODDS .... __ _ TARGET CENTER TVD-591 t - ' -- t .............. SOUTH--1342 ........... -~ .... , WEST--1120 ....... :. .... ' 'i'-,~'E r _--COC*'~I'I i:i" t ---13~.0-'- FNL.--1210:-FEL. ~EC.--30.- -~ 12N. ~ , [ ...... TD-LOCATION-~-- , i -1378 ~-FNL-.--t-255~ ~" S ~39-D E-G--5:t-~-H f N --~/' t~48~;--: -( -T'-O~-T: ARG_ E T) i · [~ovember 12, 1985 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: t~uparuk River Unit 3F-10 ARCO Alaska, Inc. Permit No. 85-271 Sur. Loc. 22'FSL, 90'FEL, Sec.19, T12N, R9E, ~.!. Btmhole Loc. 1320'F[-,rL, 1210'FEL, Sec.30, T12N, R9E, lib:. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other goverp~ental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~~~! trulM-ffuts , w I" ; '11,4 .f.-?.., _.~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI-~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. !~r. Doug L. Lowery ARCO Alaska, Inc. Post Oftice B,:. ]0360 Aqchorage, Alaska 99510-0360 Teiephone 907 276 !215 November 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 9950] SUBJECT' Kuparuk 3F-10 Dear Mr. Chatterton' Enclosed are' ° An application for Permit to Drill Kuparuk 3F-10, along with a $100 application fee ° Diagrams sh projections ° A proximity ° Diagram and system owing the proposed horizontal and vertical of the wellbore plot description of the surface hole diverter o Diagram and description of the BOP equipment We estimate spudding this well on November 17, 1985. any questions, please call me at 263-4970. Sincerely, d. B. Kewin Regional Drilling Engineer JBK/LWK/tw PD/L186 Enclosures If you have la. Type of work. DR ILL '~'X REDRILL _ -- DEEPEN _ - STATE OF ALASKA ALASKA ~,~L AND GAS CONSERVATION CC.,,MISSION PERMIT TO DRILL 20 AAC 25.005 ..?_ lb. Type of wel EXPLORATORY ~' SERVICE ~ '~.~TRATIGRAPHIIC~- DEVELOPMENT OIL ~[X SINGLE ZONE ~)( DEVELOPMENT GAS :--~ MULTIPLE ZONE ~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 .f 4. Location of well at surface 22' FSL, 90' FEL, Sec. 19, T12N, RgE, UN At top of proposed producing interval 1320' FNL, 1210' FEL, Sec.30, T12N, R9E, UM At total depth 1320' FNL, 1210' FEL, Sec.30, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 93', PAD 56' ADL 25643 ALK 2574 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 3F-10 11. Field and pool Kuparuk River Field Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposeddepth(MD&TVD) 6724' MD, 6248' TVD fept 14. Distance to nearest property or lease line 22' @ surface feet 17. Number of acres in lease 2560 15. Distance to nearest drilling or completed 3F-9 well 25' ~ surface feet 18. Approximate spud date 11/17/85 19. If ceviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1547 feet. MAXIMUM HOLE ANGLE 44 oI (see 20 AAC 25.035 (c) (2) 2712 psig@_ 80°F Surface 3114 _psig@. ~O~Rft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole t Casing Weight i Grade Coupling Length MD TOP TVD MD BOTTOMTVD (include stage data) 24" 16" 62.5# j H-40 I Weld 80' 35' [ . i 35' 115! 115' + 200 cf 12-1/4,,' 9-5/8,, 36.0# ~-55/HF-E~W BTC 3199' 35' I , ' I i 35' ~ 3234! 3033' 840 sx PF "E" & I i 390 sx PF "C" 8-1/2" 7" 26.0# J-55/HF-E W BTC . 6690' 34 I 34' 6724~ 6248' 300 sx Class "G" neat 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6724' MD (6248' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2712 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. The Kuparuk formation will be cored. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F-lO will be 25' away from 3F-9 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet} 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space ~elow for Commission '~se ~ 0 - F' Regional Drilling Engineer DATE CONDITIONS OF APPROVAL Samp!es required Mud log required Directional Survey required APl number ~YES r~-;~O -'YES ~q'40 ~,,YES ~__NO 50-~ '_.,'/-~, Y ~ ' Permit number Approval date -4 ~-'~-',-~I SEE COVER LETTER FOR OTHER REQUIREMENTS ~FPRO¥' ED BY Form, l 0-401 ,COMMISSIONER DATE November 12, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3F-lO (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subseouent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ARCO ~,:ALASKA. - tNC. · PAD 3F. ' WELL-:NO:-- IOL- PROPOSED KUPARUK-FI_ELDF-NORTH' SL.'OPE/_,-~_ALA_SKA~ EASTMAN '-WHIPSTOCK. -- ........0 _ -~---- :-i-:--.- - : ..... ~ .... MAX I MUM AN OL E _ . _ -- __ : 43,-DE¢--4-:3 MIN _ ._ _ _ 1000 __ ' ........ -- - ~ BASE PERMAFROST TYD--1523 ' ....... ............ ~~ --9 '-ToP:U*Nu-SNDS TVD=1888 T.D=1890 DEP=31 ' -- ---,~- 15 - --BUILD 3 DEO ..... . -- - ~_LL--: 21 - --~PER 11::~) FT _: .- ' - --- - ........ 27---ToP--~--SAK SNDS TvD=251'3--TMD=2560 DEP=263 ................... - c 39 K'12 TVD=2833 TMD=2958 DEP=498 - :::.: ~ ~. :[oc...r~.~ess~=~oo4._~E~S~O ..... ..... ~ ~-~-BEGIN ANGLE DROP (9 5/B" CSG PT) TVD=303~-Y~D;323~-~EP;689 . ~ 24 ~e- Kr~ TVD=4503~-4960_DEP=1564 :--.-:::: ...... _:_ ::: . ----: ............... ' - 6- - ~ ............ .... ~ ............... END ANGLE DROP TVD=S6T3 TMD-6149 DEP=1748 .............. ;T7 ZONE C -TVD=SZ7~ TMD-6249 DEP=1748 ..... - ~ ' ' --~T/ ZONE A ~ TVD"5~08 TMD"6384 DEP"1748 ' - ........ ~ - - ~~T~R~--CNT~TVD"59'11 TMD-6387 DEP~-748 i ~ ............. ~ ......... ;T-D-ALOGG[NG- PT)~' . TVD-6248 TMD-6724 DEP-1?48 --- ~ ....... : - .. ~---~ 7F~ ..... ~ ......................... ~_4 ................. ! ............ ~ ............. : ..... ~ .... ..... ~- ...... 000 :77; -.'-: : ~ : ,~:-;-:72, ;7:~:--: ':-- - -- ~ ........ ; .......... ~ ......................... ~ ..... - ..... · ........... .:; ': ::- -:U;~r ':-~U---_ ..... :77: ....... : - ~ ........... ~ ........ ~ ...... PAD-3F,- WELLi-NO,--1-O-?PROPOSED : --KUPARUK4=I-ELD.--NORTH-:-SLOPE; -A[iASKA -' ~ . EASTMAN- iWHI PSTOCI~-- I NC-. i .... -_--_'-_ ::_-__: : -_: _ _ i:--_-J : TD .......... : ..... ............ SEC, : j i , · -- SZ:3 9:DEP,-z5 ~-~N~- ~ O '--_ .... ?1000 . : __ '_ ............. :_:: :: ' ' -SURF_ACE: _LDCATIDN ~ ..... ~-:_-_ '~-c.--tg,--~? ~. ~ _ _- ! ......... _+_ __ ; ~'00 ~ 600 500 400 : ::;300 200 ~ i ' ; ' ' ' t, ' . , :"' . I , . ""'I~' r f ;. f"'~ I :' ' I : ~ I . . . , ': , . . . ' ' ' I ! ' ' ' ~ i ' ' ~ ' I~ I '~ . ' I . , ' i . ' . . ' I . ,I I ' ,--,I '. ! : , - ' . : .' ARCP ALASKA.' INC. ' , :. ' . i '; . ' , ' ,PAD ~3F. WELL NO, 9-10-11k12 PROPOSED ' . . ' I, . . t ' · t t t t ' .':' KUPARUK FIELD. NORTH SLOPE, ALASKAi ! . .. ' ~ . ; ' , '. ~ ' . ' ' ' . ~ t EASTI1AN WHIPSTOCK. INC. . ,.,/¥./ ..:. i . . ,, ':,: I. , , . :: ~ . . I... ..... :,. . , . , .. :.....,,_,:,,.., . / , , ' ,, , ',' ' , ' '."'~ '",'-" , ,,,"," r ,aoo ~ -.!....'-.:.':-!-~ ...... i .... I---~ .... ~--~--: ...... -,--~-.'.--- ..... t ' , -r'"- , , ~ , , t '' ''tt'~' r.! ' . ' / t , , : I ,. , . ,, ! ~ .... / ~11 . : I , . , t ], ,I ... ' ' : I' . . / . , .... ! .. '. . , . 1690 , ., ,. i ,- .I .... ' I -" ' [' . . ' ' / / ' t ............................ / ~ ; .......................... ' , .,,- . ~ ' j' , ' . ' ' ' ' .... ' ' , ' ' . . : , .... . t . ,.. ..~t ~ , ,..-,- .......... I .........I i /'t~/4/. ' ..... · .,, ....... rr",8 , tl 1 / . ~ 14 . ,I I t .... .. ,,.. . . .. . .. , .,.... ,. , .... ,p'. · . ,,,, , , .... , , , ., '" * ....."'"' ........... : - : i . ' ' ' :.-¢ ..... : ...... / ' '/" .... ; I : : i ! ~ ' . . .- ' ;'. I . ;* :'t'"~'" *'? '~'"1 i'T:. ~- - ; ..... ' ' I / ~,/ , , /.....,~ r r ,~ I ' ' ' '/ ' ' ' ' ' ~ ' ' ' I I ' I ' ' /' , '.,,-.,..v.,.,~ ' ' : ' ' ' I ' '-',.,~' [ ! '= -' ...... " " ..... ': , : / ./: . ........ , .... '-!--, .......... ...... t---;-: - , . ~ ' ./ 1' , ' .' . , .... . , , ' , , ':'~':.,..~,-, , - ,~ ......... I ....... ,-.-~-.-~ ........ r-! ..... ~,.~t-",-"~ :.,'-,--.--,--I~+-~-,. ....... ,-...,- - ' . ] / ~ ' , , I .... "-,,- 11- · ''~' t - .[ .1-t ' ' : ' ,,~ ' . I ' , ~' , r,, ;r I 'l . . 177¢ , '. , ' ' ' ' ~ ' ' i i ' , :/ ~. · : ' . ' , , i , , ~ : , , ~ ....... , . r , ,, , r : I .' .%-/~ ~ x.:/ , ~.. ' , , ~ ~t ,' ~ I ' ' , ; [, . . . '~ ~ . ~. .... J ..... ., ~.,'" _ , . I . ~ ~ ~/'"~ It ; ; ~ I' ' ! ' ~ 'LI , ~ ; , I j I ' , ' ' .... ~ , ; . .,',, ,. , . "! ~ , r I ,' t ......... , ..... [ .,,,,.,,.,., ,,; soo: ,. , oo. 200 .,. oc ........ ? J[ [ l]~ i [ I / ' :' I ' I~'~' /' ~ ~ t i .... ' -,- ....... ¢ '. 4-..,- .............. :-' .... ' .... ' .... j" I t , I r I i ' I 0 O. KUPARUK RIVER UNIT 20" DIVF_.BTER SCHEMATIC DE S CR I PT Z ON I. 16 · C~TOR. 2. TAh, I,(OSTARTER t-I~AD. 3. TANKO SAVER SUB. 4. TANKO LO~R QU:[CK-CONt~CT ASSY. 5. TANi<O UPPER OU!CK-C~CT ASSY. 6. 20" 2000 PSI DRILLING SPOC~ W/I0' OUTLETS, '7. 10' NCR BALL VALVES W/lO' DIVERTER LIhlESo VALVES OPEN AUTOMATICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI A~,aJLAR PEEVENTER. 7 6 7 ~.] NTENANCE & OPERAT :[ ON I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. CLOSE ANt'd~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LIhI~S EVERY 12 HOURS. CLOSE ANINULAR PREVENTER IN THE EVENT THAT AN INFLUX OF ~'~ELL~ . FLUIDS OR GAS IS DETECTED. IF hECESSARY, MAhI. JALLY OVERRIDE AND CLOSE APPROPR I ATE VALVE TO ACHIEVE DONNWIND DIVERSION. DO NOT SHUT IN V~ELL UNDER ANY CIRCUMSTANCES. 7 5 DIAGRAM #1 13-5/8' 5CK)O PSI RSRRA BCP STA~ I. 16' - KI~ LI~ 7. i~B' - ~ ~I ~ ' ACC,.MJLATOR CAPACITY TEST 4 3 2 L i ). "ED .: ~ .~.~ 4,'-:,.: ::, :-.~ 3:} 13-5/8" B(~P STACX TEST 1. FILL BCP STACX AhD C~ MANIFCI. D WITH ARCTIC DIESEL. 2. Q-ECX TI-~T ALL LOCX ~ SCRE¥iS IN ~'~ i~D ARE FULLY RETRACTED. SEAT TEST PLUG IN ~ELL~F_AD WITH RLNqI~ Jl' ~ ~ IN L~ ~. LIh~ VALVES AD~ TO !~ STAQ(. ALL ~ 4. PRE~ UP TO 250 PSI AhD Ha_D FCR I0 MINL IN- C~ PEESSLRE TO 3CK30 PSI ~ HCLD FCR t0 MIN. B~m~n F~ TO 0 PSI. ,L[I~ VALVES. CLOSE TCP PIP[ R/~ ~ NC~ VALVES C~ KILL AN:) ~ LIAES. 6. TEST TO 250 PSI AAD 3~X30 PSI AS IN STEP 4. 7. C~II~JE TESTING ALL VALVES, LII~F_S, AhD Q-K~S WITH A 2.50 PSI LC~ A/ND 3000 PSI HIGH. TEST AS iN STD, 4. Do ~rr m~-Rg TrOT ANY a-cx~ THAT ,'rS NOT A FULL CLOSIN~ POSITIVE SEAL Q-K](E. OXt. Y F~ICIN TEST C~ THAT DO NI3T F'LI_LY CLOSE. 8. ~ TCI~ PIPE ~ A/~ CLOSE BOTTCM PIPE RA/~. TEST BOTTCIvt PIP[ RAMS TO 250 PSI A/~ ~ PSI. I0. CL_r~__ BLZt~ ~ AN:) TEST TO 2.50 PSI AhO ~ '~ANZFCI.D AhO LI~ES ARE FULL CF N~INC; FLUID. SET ALL VALVES IN DRILLING POSITICI% 12, TEST STAI~IPE VALVES, K~ ~Yo ~'l~y COCXS, gRILL PIPE SAFETY VALVE, AN) IhE~IDE BCP TO 250 PSI AhD 3000 PSI. 13. RE~ TEST IN:'~TIC~ C~ BLOMAJT I:~ TEST FCla,4, SION, AN:) SE~D TO gRILLING SL~ISCR. WE]D<LY THEREAFTER ~ICI~N.LY CI=ERATE BCI=E DAILY. ARCO Alaska, Inc -- Post Office= x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3F Pad Wel 1 s 1-16 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUll/L22 Enclosure If RECEIVED OCT 2 Alaska 0il & Gas Cons. C0mmJssi0n ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AS BU' C{)NIX/CTORS ~-~1 IN SECTION Z~ 1- Y=5, .dS, 734.9~ ~T=70°22' 20.0858'' X= 508,662.35 LONG=149°55 ' 46.5a9'' 89 FNL, 162 ~L, 52 O.G., 56.1 PAD' 2- Y=5,985,7~5. iO LAT=70°22 ' 20. ~85b'' X= 508,638.99 LONG=la9°55' 47. 233'' 78 FNL, 139 ~L, 52 O.G., 56.3 PAD 3- Y=5,985,754.79 LAT=7OO22 ' 20.2812'' X= 508,616.29 LONG=149°55' 47.896'' 69 FNL, 116 FWL, 52 O.G. 56.3 PAD ~ Y=5,985,764.77 LAT=70°22 ~ 20.3796'' X= 508,593.66 LONG=149°55' ~8. 558'' I 59 FNL, 93 ~L, 52 O.G. 56.2 PAD '~ 5- Y=5,985,774.87 LAT=70°22 ' 20. 4792'' X= 508,570.43 LONG=la9°55' 49.237 ~ 49 FNL, 70 ~L, 52 O.G. 56.2 PAD 6- Y=5,985,784.84 LAT=70°22'20.5776'' ~ X= 508' 547' 58 LONG=149°55' 49' 90~" NOTES 39 FNL, 48 FWL, 52 O.G. 56.1 PAD I. COORDINATES ~RE A.S.R,ZONE4. 7- Y=5,985,794'93 LAT=70°22'20'6771" 2. SECTION LINE DIST~N~, ~RETRUE. X= 508'524'~4 LONG' l~9°55 ' 50' 582" 28 FNL, 24 ~L, 52 0.G.,55.9 PAD 3. HORIZONT~LAND VERTICAL POSITIONS ~RE '~SED 8_ y=5,985,804.81 LAT=70o22,20.77~,, ON MONUMENTS 3F-MIDDLE 8 3F-EA~PERL.H. DS~. X= 508,501.41 LONG=149o55,51.256,, 4. O.G. ELEV~TIONS IN~RPOL~TED F~O, S/C DWi. NO. 18 FNL, 1 FWL, 52 O.G.,55.9 PAD cED-.,xx-~o~o .~~.~. ~s ~U,~T CO.~UCTO.. ,-,, ,. sEc~,o. ,, *3~OF AL~. 9- ?=~,985',83~.85 LAT=70°22'21.0708'' ~~- ...... ..~'~ X= 508,432.81 LONG=149°55' 53.26~'' ff ~/ 4 9 ~ ~ 10- Y=5,985,Saa.70 LAT=70°22'21.1678'' ~eee~eeeeeee~e~/- ....... ~ X= 508,410.73 LONG=149°55' 53. 908'' ~~ 21' FSL, 89 FEL, 51.20.G., 56.2 PAD ~ . .OWA~J.'~"A · .~ ~ 11- Y=5,985,855.14 LAT=70°22'21.2708'' **f~%. azeo.s ..':~ X= 508,387.41 LONG=149°55'54.590'' ~~~ - 12- Y=5,985,865.19 LAT=70°22'21.3699" ~~~ X= 508,364.05 LONG=149°55' 55.273'' I HEREBY'CERTIFY THAT I AM ~~Y~S~D 42 FSL,136 FEL,51.1 0.G.56.2 PAD A~ LIC~$ED TO PRACTICE LAN~ B~EYIN'IN 13- Y=5,985,874.97 LAT=70°22'21.4663'' ~E.STA~ OF A~~ ~AT ~1~ ~T ~~~NT8 X= 508,341.36 LONG=149°55' 55. 937" A 8U~YEY ~DE U~ MY DI~GT~~Y~ AND 52 FSL, 158 EEL,51.10.G., 56.3 PAD THAT CQND~TO~ I ~ · A~.C~CT A~ ~ 14- Y=5,985,885.08 LA~=70°22'21.5660'' $EP~ER 19,1~ A~ .C~T~ · ~U le A~ COR~CT A8 ~ ~~ER ~,1~. X= 508,318.27 LONG=l~9°55' 56.612'' 62 FSL, 181 EEL, 51.1 0.G.,56.3 PAD T~LI~. 15- Y=5,985,894.96 LAT=70°22' 21.6635'' 19SU 2 X= 508,295.72 LONG=lag°55' 57.271'' ~~~ 72 ESL, 20~ FEL, 51 O.G. 56.1 PAD - ao ~ . ~7~ 251985 ~*-x: ~os.2~2.~ ~o.c:~*°~'~.~a'' , ~2 FSL~ 22~ FEL~ 51 O.G. 56 PAD 4 ~6 ~' '~ ~b ARCO A~k~ I~. . ~CS ~' Kupo~ ~oJoct ~ x ~s ~ I' DRILL SI~ ~ F CONDUCTORS I THRU8 LOCATED IN PRO,ACTED CON~CTORS 9 THRU 16 LO~D IN P~TR~D SEC. 19, T. 12N.,R. gE.,U. MER. ~.~~ Drl~ed by: Sydney2 ~ ~. N~85-26 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc ~'2 thru 8) (3) Admin (~~ (9'"th-ru 12)~ , (10 and (13 thru 21) (5) BOPE (22 thru 26) (6) Ad d: ~ //- ~-~c"' 1. Is the permit fee attached ........................................ 2. Is well to be located in a defined pool ......................... 3. Is well located proper distance from property line ..~ .... 4. Is well located proper distance from other wells ..... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .............. 7. Is operator the only affected party ............................... 8. Can permit be approved before ten-day wait ........................ 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO · ~, Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~-- Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to .~O~o psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. REMARKS ., Additional Remarks: Geology: HWK ~rA~~'- JAL ~ ,'~.. Eng$~neering: LCS ~ BEW .... rev: 03/13/85 6.011 INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS AREA NO. SHORE ~ , , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ,F fl ,. . - -- . -,,;T .,v ' , T .2 'f [ L v! .. , · . , · ,,. :) _ ,., ? ,. ', _.,) j, . 3 . .q } .~ .- · ; ~, :;. i 7'" ~ ' ',. _. _ ' .- D T ",i ':' "i i '. ,Dr , ~. 7' ..~ .,-~ ]-., ,,)' ~ 1" '.~ '-~d ~ -, .I. · ] '+ '; i . . · · · · . · 1 -'?'. ,. ,7. · -. : . ',j 7 7 - ~ ?'~._ "]0 -~')). :;,)C :) ..' . · '+ · . ? . -.. ~ ',: !.7..12. I ; -. !:;; ~::,. -'~.~. ?':.S3 ~ ., -, _. , 7., ..... ~ · ,:" .),.: I :.. 7.. ' _., ~. 1 ~' ] :. ') -- ? ;', f · . ...~ "" ~.,., ~... · "; 7 ': ~ · .... ..,+uT L''~ -., '~ ~ o ' '~ '~ ~ I ' - ~ ) ] ,. .~. ..~ .~ .. -- ., . ., · . . ..~ ') ,- .~ -. , ..... -" ~." ]0 c - ' .,~ ~. :' "):], '~" . . - ! ;, -) . :' ,-~ ,~ ,.., !. :.'~ '!1 ": L'l -';. )'~.L :']" "-~L: - ,: .~ ::, .., ...; ") ' 7.~ '; - · ~ [',_ "1 · - "' '~" P 4 -; '9.': ::'.]::) :-~ I "] ? "i TI '.~ -:?.-"?. £ ' ]J ;:~L'; -~ ,; .;. ':: :).'] .,., - '.4 ") :,. '; ':~ ]..] ".i L; -'; -: '~. ii:.; J ..) '-~' - ~ ~. :~ · ') ~'~.. ~ ' .,~'~ I ," ~; '~. · -~,~ ,, ,, -- ~ -, '. ·" ;, ] J _ ~ , "' 7 -r ' :,' .:~. ? 3.', " ~ ] 1,.l ' I '.4 . · ..) .... -.'? ." ?. ?., ,.) ' : :. u .i. -.~r i' '. ,7:,,~ ~ ",:',~. ;: - :~.:~ ~. - ,: ]. ] '.' ,: :7