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4114111 201 WELL LOG TRANSMITTAL DATA Li ,. To: Alaska Oil and Gas Conservation Comm. August 13, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SrP 01 RE: Multi Finger Caliper, Jewelry: 1R-14 AOGGC Run Date: 7/29/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1R-14 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21386-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating SCANNED _ `;)It Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: cfr2valza-#24<-4) 6-40teat ~e Project Well History File' C~ Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~- j_~_~[ Well History File ldentifier RESCAN DIGITAL DATA OVERSIZED (Scannable) ..~a/C°lor items: [] Diskettes, No. [] Maps: [3 Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE,: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: Is~ Scanning Preparation BY: Production Scanning Stage I PAGE COUNT FROM SCANNED FILE' / PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES BY: BEVERLY BREN VINC~MARIA LOWELL DATE¢,/,/0 ~.S/~ Stage 2 IF NO IN sTAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ;.~., ~'/'. ~ES . NO BY: ~REN VINCENT SHERYL MARIA LOWELL (SCANNING IS COMPLETE ~ POINT UNLESS SPECIAL AI-rENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: Quality Checked (done) 10125102Rev3NOTScan ned .wpd MtLEIVED STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMON JUL 1 1 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Perforate r otar9ecC Alter Casing r Pull Tubing Stimulate - Frac r Waiver r Time Extension 1 Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well (" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r 185 - 151 3. Address: 6. API Number: Stratigraphic r Service "° P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 21386 - r` 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25635 ' 1R 9. Logs (List Togs 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 9250 feet Plugs (measured) 8559', 8836' true vertical 6978 feet Junk (measured) 9025', 9027', 9029' Effective Depth measured 9139 feet Packer (measured) 8509, 8623, 8821 true vertical 6892 feet (true vertucal) 6437, 6517, 6658 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 4566 9.625 4603 3779 PRODUCTION 9194 7 9229 6962 ':. V JUL 1 3 CU) Perforation depth: Measured depth: 8694 -8732, 8912 -8920, 8924 -8960, 9032 -9040 True Vertical Depth: 6567 -6595, 6724 -6730, 6733 -6760, 6813 -6819 Tubing (size, grade, MD, and TVD) 3.5, L -80, 8500 MD, 6431 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 8509 MD and 6437 TVD PACKER - BAKER FHL PACKER @ 8623 MD and 6517 TVD PACKER - BAKER DB PACKER W/ SBE @ 8821 MD and 6658 TVD SSSV - CAMCO DS NIPPLE @ 484 MD and 484 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development p" ■ Service r Stratigraphic r 16. Well Status after work: , Oil I Gas r WDSPL f Daily Report of Well Operations XXX GSTOR E WINJ r WAG r GINJ E SUSP ("' 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 Brett Packer 265 -6845 Printed Name Brett Packer Title Sr. Wells Engineer Signature _ 7 Phone: 265 -6845 Date / '-' 06' -t Form 10-404 Revised 11/201 : ®MS JUL 11 2012 '� � „ 7124i- Submit Original Only -Ve i KU P ill 1 R -14 ConocoPhillips Weil Attributes Max Angle MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292138600 KUPARUK RIVER UNIT PROD 50.03 7,100.00 9,250.0 Con000Plellps '°°' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE 10 9/5/2011 Last WO: 6/14/2012 36.79 8/7/1985 Well Confiq - 1 R -14, 6/26/2012 6'.12'.18 AM - chematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,019.0 5/11/2012 Rev Reason: GLV C/O ninam 6/26/2012 HANGER. Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONDUCTOR 16 15.063 38.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd f SURFACE 95/8 8.921 37.0 4,603.2 3,778.9 36.00 J - 55 BTC aetiotri 0... String D op .. VD .... .tri Top PRODU 7 6.276 35.0 9,229.5 6,962. 26.00 J -55 BTC Tubin Strings CONDUCTOR, TC ubing sing DD e scripti scrip on n S String nn 0... String ID I ..... T . Top ( (ftKB) ftKB) S Set et Depth Depth (f. Set Set Depth Depth (T ) ... . String String Wt. String ... S .. String ng Top ThThrd rd 38 TUBING 31/2 2.992 30.0 8,499.8 6,430,5 9.30 L -80 EUE8rdABMOD NIPPLE.484 [ Completion Details Top Depth (TVD) Top loci Nomi... GAS LIFT, i Top (ftKB) (ftKB) (°) item Description Comment ID (!n) 2,887 i ` 30.0 30.0 0.07 HANGER FMC GEN III TUBING HANGER 3.500 484.3 484.3 0.24 NIPPLE CAMCO DS NIPPLE 2.875 8,477.2 6,414.8 45.99 LOCATOR BAKER LOCATOR 2.991 L 8,478.2 6,415.5 45.99 SEAL ASSY BAKER PBR SEAL ASSEMBLY 2.991 SURFACE, ` Tubing Description String 0... String ID ... Top (MB) I Set Depth (f... Set Depth (TVD) ... ng Wt... String ... String Top Thrd 37 - 4,803 STACK PACKER I 31/2 I Str 2.992 8,485.7 8,617.2 I 6,512.6 I Stri 9.30 I L -80 EUE8rdABMOD GAS LIFT r Compl Details 4,771 f Top Depth (TVD) Top Inc! Noml... Top (ftKB) (ftKB) ( °) Item Description Comment 10 (in) 8,485.7 6,420.7 45.94 PBR BAKER 80 PBR w/ 4" SEAL BORE 3.913 GAS LIFT, 6,206 i 8,508.5 6,4372 45.97 PACKER BAKER FHL PACKER 4.001 8,558.9 6,471.9 45.56 NIPPLE CAMCO DS NIPPLE 2.812 8,604.1 6,503.3 44.52 LOCATOR BAKER 80-40 GBH -22 LOCATOR SUB 2.992 GAS LIFT 7.246 t.. 8,605.1 6,504.0 44.51 SEAL ASSY BAKER GBH - 22 SEAL ASSEMBLY w/ MULE SHOE BOTTOM 3.000 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Original 3 1/2 2.992 8,609.7 8,844.4 6,675.4 9.20 J -55 BTC 3.5x 2.875 cAS 8 0168 Completion Details „. Top Depth (TVD) Top lncl Noml... Top (ftKB) (ftKB) I°) Item Description Comment ID (in) GAS LIFT, � ,_ 8,609.7 6,507.3 44.51 PBR BAKER PBR 3.000 8,427 8,623.5 6,517.1 44.49 PACKER BAKER FHL PACKER 3.000 ,r 8,699.8 6,571.5 44.40 BLAST RINGS CARBIDE BLAST RINGS 2.992 LOCATOR, 8,793.9 6,638.8 44.29 NIPPLE AVA BPL LANDING NIPPLE 2.750 8 SEAL 4 8,796.7 6,640.8 44.28 XO Reducing CROSSOVER 3.5 x 2.875" ID 2.441 ", 6.5#, J -55 EUE8rd 2.875 8 L 8- PBR, 8 8,478 .486 1 1 8,820.2 6,658.1 43.89 LOCATOR BAKER LOCATOR 2.441 8,821.3 6,658.8 43.88 PACKER BAKER DB PACKER w/ SBE (3.25 seal diameter and 5' stroke) 4.750 PACKER, 8,509 8,836.1 6,669.4 43.70 NIPPLE CAMCO D NIPPLE NO GO 2.250 Ir a.. 8,843.7 6,674.9 43.61 SOS CAMCO SHEAR OUT SUB 2.441 PLUG, 8,559 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) NIPPLE. 8,559 Top Depth 'I (TVD) Top Inc! Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 8,559 6,471.9 45.56 PLUG 2.25" CA -2 PLUG 6/14/2012 0.000 Mt 8,794 6,638.8 44.29 SLEEVE -C AVATPI 2.75" SLEEVE (NEW STYLE) 9/4/2010 2.310 iraiiiii- SEAL ASSY, _ - ',.. 8,836 6,669.4 43.70 PLUG 2.25" CA -2 PLUG 5/11/2012 0.000 8,605 PBR, 8,810 - 9,025 6,807.9 41.03 FISH Grapple 1.367' Grapple, chased downhole w /SV, unknown 5/31/2003 0.000 PACKER, 8,623 MD on 5/31/2003: gauged TBG to 9025' 5/11/2006. - 9,027 6,809.4 41.03 FISH Metal Junk Chased Metal Junk Downhole Past AVA Profile: 10/2/1993 0.000 PRODUCTION, 8,662 gauged TBG to 9025' 5/11/2006. 9,029 6,810.9 41.03 FISH OV 1.5" OV LOST IN RATHOLE, gauged TBG to 9025' 10/23/2003 0.000 IPERF, 5/11/2006. 8,694-8,732 '' Perforations & Slots NIPPLE, 8,754 Shot SLEEVE -C. N Top (TVD) Btm (TVD) Dens 8,794 .:. Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment I 8,694 8,732 6,567.4 6,594.5 C -1, 1R -14 10/15/1985 12.0 IPERF 120 deg. ph; 5" HJ II Csg Gun LOCATOR, :® 8,912 8,920 6,724.4 6,730.3 A-4, 1R -14 10/15/1985 4.0 IPERF 90 deg. ph; 4" HJ II Csg Gun 8,820 !_ PACKER, 8,821 - 8,924 8,960 6,733.2 6,759.9 A -3, 1R -14 10/15/1985 4.0 IPERF 90 deg. ph; 4" HJ ll Csg Gun MN 9,032 9,040 6,813.2 6,819.2 A -2, 1R -14 10/15/1985 4.0 IPERF 90 deg. ph; 4" HJ II Csg Gun PLUG. 8.836 III , NIPPLE, 8,836 :, IIIII SOS, 8,844 .••• IPERF, Mandrel Details 8.912-8,520 ' Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( Make Model (!n) Sery Typo Type (in) (psi) Run Date Com... 8,924 IPE4,96RF, 0 1 2,886.5 2,575.8 46.43 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,281.0 6/21/2012 2 4,771.0 3,901.1 44.99 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,272.0 6/22/2012 FISH, 9,025 3 6,205.8 4,894.7 45.09 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,262.0 6/22/2012 FISH, 9,027 • 4 7,246.3 5,592.5 49.52 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 6/22/2012 + 5 8,068.0 6,132.4 47.01 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/10/2012 FISH, 9,029 Z 6 8,426.9 6,380.2 46.31 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/22/2012 IPERF, . . 7 8,662.1 6,544.6 44.45 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 7/23/2003 9,032 -9,040 PRODUCTION. 3T1.-225,7 - • • • Time Log & Summary ConocoPhill p s Wellview Web Reporting Report Well Name: 1R Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/10/2012 11:30:00 PM Rig Release: Time logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/09/2012 24 hr Summary Blow down and R/D service lines. Move complexes and rock washer from 2K to 1 R. 16:00 18:00 2.00 MIRU MOVE MOB P Blow down rig and disconnect service lines. 18:00 20:30 2.50 MIRU MOVE MOB P Jack up complexes and pipe shed. 20:30 22:00 1.50 MIRU MOVE MOB P PJSM- Load complexes and rock washer on trucks. 22:00 00:00 2.00 MIRU MOVE MOB P Move complexes and rock washer from 2K to 1R. 06/10/2012 Continued to move from 2K -14 to 1R-14. Spot rig over 1R-14 and rig up. Rig accepted @ 23:30 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move complexes and rock washer from 2K to 1 R. 04:00 05:00 1.00 MIRU MOVE MOB P Hook up and stage pipe shed on pad. Move sub base off well 2K -14, install riding shacks and sterring bar. 05:00 06:00 1.00 MIRU MOVE MOB P Hold on 2K for field change out. 06:00 08:00 2.00 MIRU MOVE MOB P CIO flat tire on sow. Stage pipe shed on 2H pad. 08:00 17:00 9.00 MIRU MOVE MOB P Move sub base to 1 R -14. 1 17:00 20:00 3.00 MIRU MOVE MOB P Lay rig mats, back in pits, motors and boilers. SIMOPS, hook up inner connects between modules. 20:00 21:00 1.00 MIRU MOVE MOB P Lay herculite for rock washer and spot rock washer. 21:00 22:00 1.00 MIRU MOVE MOB P Spot and shim pipe shed. 22:00 23:30 1.50 MIRU MOVE MOB P Continue to rig up. Work on rig acceptance checklist. 23:30 00:00 0.50 COMPZ RPEQP1 RURD P Rig accepted @ 23:30 06/11/2012 Take on brine and rig up to kill well. Spot and rig up tiger tank. PT lines t/ 2500 PSI. observed 750 PSI on tbg. Displace well w/ 311 bbls of 9.2 ppg brine. R/D lines, observed 50 PSI on well. Circulate and increase fluid weight f/ 9.2 ppg to 9.5 ppg though choke. 00:00 03:30 3.50 0 0 COMPZ RPEQP1 RURD P PJSM- R/U circulating lines, take on 9.8 ppg brine. 03:30 04:00 0.50 0 0 COMPZ RPEQP1 PRTS P Flood mud pumps, test lines t/ 2500 PSI. 04:00 07:00 3.00 0 0 COMPZ RPEQPI COND P Condition brine, cut 9.8 ppg brine t/ 9.2 ppg. SIMOPS, grease choke manifold. 07:00 09:00 2.00 0 0 COMPZ WHDBO RURD P Mob lubricator to rig floor. SIMOPS, R/U containment and tiger tank. 09:00 12:00 3.00 0 0 COMPZ WHDBO RURD P R/U scaffolding in cellar. SIMOPS, continue to rig up tiger tank. 12:00 15:00 3.00 0 0 COMPZ WHDBO RURD P Continue to rig up scaffolding. Page 1 of 5 • Time Logs • • Date From To Dar S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 1.00 0 0 COMPZ WHDBO RTWH P PJSM- FMC pressure test lubricator t/ 2500 PSI., pull BPV w/ lubricator. 16:00 18:15 2.25 0 0 COMPZ WELCTL KLWL P PJSM- Pressure test lines t/ 2500 PSI. Kill well, displace diesel to tiger tank. Pump @ 3 BPM, initial circulating pressure = 990 PSI, final circulating pressure= 330 PSI. Pumped 311 bbls from pits w/ 304 bbls returned to tiger tank. 18:15 18:45 0.50 0 0 COMPZ WELCTL OWFF P Shut down pumps and monitor well. (static) 18:45 19:15 0.50 0 0 COMPZ WHDBO RTWH P B/D lines, install BPV as per FMC. 19:15 20:30 1.25 0 0 COMPZ WHDBO RURD P R/D circ lines and scaffolding. 20:30 00:00 3.50 0 0 COMPZ WELCTL KLWL P Hold PJSM on N/D tree & N/U BOPE. Double check tree before nippling down, discovered 50 PSI on tubing. Indicated BPV leaked and well was not dead. Decision was made to line up on choke manifold and circulate increasing fluid weight f/ 9.2 ppg to 9.5 ppg holding 120 PSI on casing when pumping KWF to the bottom GLM. Initial circulating pressure= 470 PSI, Final circulating pressure= 360 PSI. 36/12/2012 Continue circ. KWF 9.5 ppg through choke 126 gpm 370 psi, observe well for flow, slight flow on ann. weight up t/ 9.8 ppg observe well for flow static, set BPV and test t/ 500 psi, ND tree & adaptor flange, NU BOPE, change lower IBOPE, test BOPE 250 low 3500 high, 00:00 00:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM on pumping kill weight fluid through choke 00:15 01:00 0.75 0 0 COMPZ WELLPF CIRC P Cont. pumping kill weight fluid 9.5 ppg (surface to surface) through choke @ 3 bpm, with 120 psi on casing 01:00 02:00 1.00 0 0 COMPZ WELLPF OWFF P Monitor well, slight flow out of annulus. 02:00 02:45 0.75 0 0 COMPZ WELLPF OTHR P Weight up pits to 9.8 ppg. 02:45 04:30 1.75 0 0 COMPZ WELLPF CIRC P Pump 9.8 ppg KWF, (surface to surface) through choke @ 3 bpm with 370 psi 04:30 05:30 1.00 0 0 COMPZ WELLPF OWFF P Monitor well, well static. 05:30 05:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM on setting BPV and testing same 05:45 06:45 1.00 0 0 COMPZ WELLPF OTHR P Set BPV, Rig up and test to 500 psi, Good, R/D testing equipment. 06:45 07:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM onN /D tree 07:00 08:00 1.00 0 0 COMPZ WELLPF NUND P N/D tree and adapter flangg, Install blanking plug. 08:00 08:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM on N/U new adapter flange andf BOPs 08:15 11:00 2.75 0 0 COMPZ WELLPF NUND P N/U new adapter flange and BOPE. SIMOPS getting ready to change out lower IBOP valve. Page 2 of 5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM on changing out lower IBOP valve 11:15 12:00 0.75 0 0 COMPZ WELLPF SVRG P Change out lower IBOP valve 12:00 12:15 0.25 0 0 COMPZ WELLPF SVRG P PJSM with on coming crew on lower IBOP valve 12:15 14:15 2.00 0 0 COMPZ WELLPF SVRG P Finish changing out lower IBOP valve 14:15 15:00 0.75 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor, UD old IBOP valve and put tools away. 15:00 15:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM, on testing BOPE 15:15 16:00 0.75 0 0 COMPZ WELLPF BOPE P R/U testing euipment 16:00 23:00 7.00 0 0 COMPZ WELLPF BOPE P Test BOPE, top & bottom pipe rams, /� blinds & ann. choke valves 1- 14, 5° man. & hcr choke & kill valves, upper � & lower IBOP valves, TIW & DART, „�� „���, 4" demco t/ 250 low 3500 high, accumulator test, gas alarms & pvt tested. Bob Nobel from AOGCC waived witness of test. 23:00 23:15 0.25 0 0 COMPZ WELLPF BOPE P UD test joint and blow down choke 23:15 00:00 0.75 0 0 COMPZ WELLPF OTHR P Drain stack 06/13/2012 Pul BPV, M/U Landing Jt, back out lock downs, pull up to 80% 9 times 200K, came free PUW 107K, pull hanger to floor, circ. bottoms up, gas breaking out at surface, observe well for flow static, Pooh UD 3.5 tubing completion, 272 jts , 5 glms, 2 pups, seal assy. hanger w/ pup, RIH w/ 3.5 upper completion t/ 8621' R/U to reverse circ. Inhibited brine, break circ 126 gpm 400 psi. 00:00 00:15 0.25 0 0 COMPZ WELLPF OTHR P Cont. draining stack, pull blanking plug. 00:15 00:30 0.25 0 0 COMPZ WELLPFOTHR P R/U and pull BPV. 00:30 00:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM on pulling tbg hanger 00:45 01:45 1.00 0 0 COMPZ WELLPF OTHR P R/U landing joint, BOLDS, Pulled TBG hanger to rig floor. 200K 9 times, Pulled free, weight dropped off to 100K, picked up to 107K 01:45 03:15 1.50 0 0 COMPZ WELLPF CIRC P Break circulation with 3 bpm 210 psi stage up to 4 bpm 360 psi and 5 bpm 570 psi, surface to surface. 03:15 03:45 0.50 0 0 COMPZ WELLPF OWFF P Monitor well Static, UD landing joint and hanger. 03:45 04:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM, Pulling and laying down tbg 04:00 12:00 8.00 0 0 COMPZ RPCOM PULL P Pull and UD 3.5 tbg, P/U = 100k, UD 257 joints, 4 GLM, 2 pup joints, 1 DS nipple, Joints 214 - 215 -225 had patches. Actual displacement = 27.8 bbls, Calulated displacement = 26.9 bbls 12:00 12:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM, with New crew UD tbg. 12:15 12:30 0.25 0 0 COMPZ RPCOM PULL P Cont. UD TBG, total joints 272, 5 GLM, 2 pups, Seal assembly and hanger w/ pup. 12:30 15:15 2.75 0 0 COMPZ RPCOM OTHR P Remove all old 3.5" tbg from shed and bring in GLM and packer and flag all joints in running order. Page 3 of 5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 15:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM, P/U new 3.5" completion string 15:30 23:00 7.50 0 8,621 COMPZ RPCOM RCST P RIH with seal assembly, DS nipple with RHC plug installed, 3.5" 5 X 7 FHL packer with min OD = 3.00" and pinned to 60 K shear, Baker 80/40 PBR with 4' seal bore, PBR assembly pinned to 40 K, seal locator, Camco KBMG W /DCK -2 shear valve BK- Latch, 5- Camco MMG dummy RK- Latch, DS nipple, t/ 8621' 23:00 00:00 1.00 8,621 8,621 COMPZ RPCOM RURD P R/U t/ reverse circ. inhibited brine, break circ 126 gpm 400 psi. 100K PUW 75K SOW 06/14/2012 Spot Inhibited brine 280 bbis, drop ball & rod, located space out, set pkr, test ann. t/ 1500 psi f/ 15 min. shear packer 35K over pull, space out land tubing on hanger, RILDS, test tubing to 3500 psi f/ 30 min. bleed pressure off tubing t/ 2750 psi, pressure up on ann t/ 3500 f/ 30 min., bleed tubing off & shear DCK- 2 valve, rig down surface lines set BPV test t/ 500 psi f/ direction of flow, N/D BOPE, N/U Adaptor flange & tree test t/ 5000 psi f/ 15 min. pull BPV, set test plug in tree test t/ 250 low 5000 high, R/U & displace ann. w/ 75 bbis diesel, set BPV, secure wellhead, clean pits rig released @ 2130 hrs. 00:00 00:15 0.25 8,621 8,621 COMPZ RPCOM SFTY P PJSM on Reverse circulating. l/ 00:15 01:45 1.50 8,621 8,621 COMPZ RPCOM CIRC P Reverse circulate inhibited brine 280 bbis 3 bpm 380 psi, as per Baker Rep. 01:45 03:00 1.25 8,621 8,621 COMPZ RPCOM OTHR P Drop 1 -5/16 Rod & ball, Locate, Pick up 5' and set packer, test back side to 1500 psi and bleed off, P/U 20' and break circulation with 1 bpm and slack off and sting into packer, shut down and bleed off. Fully locate 23' in and set down with 5K. 03:00 04:00 1.00 8,621 8,621 COMPZ RPCOM OTHR P Space out, UD three joints, P/U pups 10.07' - 6.08' - 4.68' and one joint above pups, M/U tbg hanger and landing joint. 04:00 04:30 0.50 8,621 8,621 COMPZ RPCOM OTHR P Land TBG and RILDS 04:30 06:00 1.50 0 0 COMPZ RPCOM OTHR P Test TBG to 3500 psi and chart for 30 min, bleed off to 2750 psi and pressure up the IA to 3500 psi and chart for 30 min, Dump TBG side and shear SOV, Monitor well. 06:00 06:45 0.75 0 0 COMPZ RPCOM OTHR P Rig down lines, Set BPV and test to 500 psi from direction of flow. 06:45 07:15 0.50 0 0 COMPZ RPCOM OTHR P Blow down and rig down all circuation lines, blow down kill and choke, clear floor. 07:15 07:30 0.25 0 0 COMPZ WHDBO SFTY P PJSM, on N/D BOPE 07:30 09:00 1.50 0 0 COMPZ WHDBO NUND P N/D BOPE 09:00 09:15 0.25 0 0 COMPZ WHDBO NUND P PJSM, N/U adapter and tree 09:15 11:00 1.75 0 0 COMPZ WHDBO NUND P N/U adapter Flange and tree. Test adapter to 5000 psi for 15 min. 11:00 12:00 1.00 0 0 COMPZ WHDBO OTHR P R/U T -Bar and pull BPV Page 4 of 5 Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 12:00 12:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM, on setting tree test plug 12:15 12:45 0.50 0 0 COMPZ WHDBO OTHR P Set tree test plug and test to 250/5000 psi (Good) 12:45 13:00 0.25 0 0 COMPZ WELLPFSFTY P PJSM, freeze protecting well 13:00 15:00 2.00 0 0 COMPZ WELLPF OTHR P R/U and pump 75 bbls of diesel down annulus up the tbg to rock washer, pump bpm, ICP = 550 psi, FCP = 1100 psi. 15:00 18:00 3.00 0 0 COMPZ WELLPF OTHR P U -Tube, SI MOPS slip on new drilling line from spool. 18:00 19:00 1.00 0 0 COMPZ WELLPF OTHR P Set BPV, Dress tree, Blow down lines. 19:00 21:30 2.50 0 0 COMPZ WELLPF OTHR P Clean pits, Off load water to truck. 21:30 21:30 0.00 0 COMPZ Rig released @ 2130 hrs. R/D Move to 3N -07 Page 5 of 5 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 17, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Patch Setting Record: 1R -14 Run Date: 6/14/2011 & 6/16/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -14 Digital Data in LAS format, Digital Log Image file - ' 3 1 CD Rom 50- 029 - 21386 -00 l V PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. r4 $ E P x 201; Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: / A l / Signed: ILI ler-i5"-/ • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Patch Setting Record: 1R -14 Run Date: 6/11/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21386-00 1 14 St/1R PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com LL Date: 1 co �� �\ Signed: L6k /5' J5/ STATE OF ALASKA ALASKA* AND GAS CONSERVATION COMMISSI• , REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other ✓ Install Patch Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re - enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ConocoPhillipsAlaska, Inc. Development Exploratory r ' 185 -151 3. Address: 6. API Number: Stratigraphic r Service I° P. O. Box 100360, Anchorage, Alaska 99510 — 50 029 - 21386 - 00 — Of) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25635 "' 1R-14 ' 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9250 feet Plugs (measured) None true vertical 6978 feet Junk (measured) 9025', 9027, 9029' Effective Depth measured 9139 feet Packer (measured) 8623, 8821 true vertical 6892 feet (true vertucal) 6517, 6658 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 I SURFACE 4566 9.625" i 3779 PRODUCTION 9194 7 , �' : t* JUL U . i 20 6962 ..y r ��"''�' 3 N 1f E "`. , C . , Perforation depth: Measured depth: 8694'- 8732', 8912'- 8920', 8924'- 8960', 9032' - 9040' it $ l ' True Vertical Depth: 6567'- 6595', 6724'- 6730', 6733'- 6760', 6813' -6819' jj(( qq . i . r j;, IT. IA N16. kiittrtSsiOfll [] icl ti.rfr ' ICI Tubing (size, grade, MD, and TVD) 3.5, L -80, 8637 MD, 6527 TVD I � T � t "pf Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 8623 MD and 6517 TVD PACKER - BAKER DB PACKER W/ SBE @ 8821 MD and 6658 TVD NIPPLE - CAMCO DS NIPPLE @ 515 MD and 515 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data P Y 9 Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ro ✓ Service r Stratigraphic r 15. Well Status after work: ,. Oil (" Gas r WDSPL r Daily Report of Well Operations XXX GSTOR "" WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265-6471 Date .� / © /t i 46.4 ----7---.1. DMS JUL 0 8 z01 Form 10 -404 Revised 10/2010 7 / /8 l/ mit Original Only 1R-14 Well Work Summary DATE SUMMARY 4/13/11 SET CATCHER ON CA -2 PLUG 41136' RKB. PULL DMY VLVS @ 6680' RKB0572' RKB. IN PROGRESS 4/14/11 SET DV @ 6680' RKB. PUMP 150 BBLS INHIBITED SEAWATER & 20 BBL DIESEL FP. SET DV @ 8572' RKB. CMIT 2500 PSI, PASSED. ATTEMPT TO PULL CATCHER @ 8806' SLM, ENCOUNTERED FILL @ 8774' SLM. IN PROGRESS. 4/15/11 BAILED FILL f/ 8772' TO 8805' SLM. PULLED 2.30" CATCHER @ 8836' RKB. IN PROGRESS 4/16/11 PULLED 2.25" CA -2 PLUG @ 8836' RKB. B &F TBG f/ 6650' TO 7200' SLM. DRIFT TBG W/ 2.81" X 19.5' DMY DRIFT TO 7300' SLM W/ NO PROBLEMS. READY FOR FIRST PATCH. 6/11/11 SET 22' long TTS X -Span PERMANENT PATCH FROM 7082'- 7104'. Min ID 2.375 ", running OD of 2.813" TOP MID - ELEMENT SET AT 7082' CCL TO TOP MID - ELEMENT LENGTH WAS 15' CCL STOP DEPTH WAS 7067' 6/13/11 SET D &D ON TOP OF TTS PATCH, PERFORMED COMBO P/T, PASSED. READY FOR NEXT PATCH TO BE SET. 6/14/11 SET 22' x 2.813" run OD TTS X -Span PERMANENT PATCH FROM 6762' -6784' (min ID 2.375 "). THE TOP MID - ELEMENT SET DEPTH WAS 6762'. CCL TO MID - ELEMENT LENGTH WAS 15'. CCL STOP DEPTH WAS 6747'. 6/15/11 RAN 3" D &D HF TO TOP OF 2ND TTS PATCH © 6726' SLM, ATTEMPT CMIT, FAILED. RAN MODIFIED 3" D &D HF TO 6726' SLM, CMIT FAILED. IN PROGRESS 6/16/11 SET 22' TTS X -SPAN PERMANENT PATCH, OD: 2.813 ", ID: 2.375 ", FROM 6737.4'- 6759.4' / LOG CORRELATED TO HES LEAK DETECT LOG DATED 19 SEP 2010. TOP OF PATCH SET AT 6737.4'. CCL TO TO TOP OF PATCH: 10'. CCL STOP DEPTH: 6727.4' - -s P I. KU P • 1 R -14 C � * a Welt Angle Max O MD _TD Wellbore APUUWI Feld Name IWell Statue Inc! ( °) iMD ( K tKB) Act Bim(ftKB) " ,, 500292138000 KUPARUK RIVER UNIT PROD 50.03 1 7,100.00 9,250.0 Comment H2S (ppm) Date __ IAn otation End Date KB (ft) Rig Release Date __ . SSSV NIPPLE 1 75 8/6/2009 Last WO: 8/14/2003 36.79 8/7/1985 WeNO nfig 14-14, 6/1717G11403 -0)PM _ - = ' - - '... Annotation Depth ftKB End Date Annotation [Last Mod... End Date su, entano Actual Last Tag SLM I ) 9 017 0 I 9/4/2010 [Annotation Reason PULL PLUG, GLV CIO, SET PATCH _ mnam 1 6/17/2011 HANGER. 27 'i 4 ._. I Casing Strings Casing Description String 0... String ID.. Top (ft615) Set Depth (f..- Set Depth (ND) ... String Wt... I String ... String Top Thrd CONDUCTOR 16 15.063 38.0 115.0 115.0 62.50 H WELDED C asing Description S tring 0... St ring ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . Siring Wt... String ... String Top T hrd - 9 5/8 8.921 37.0 4,6012 3,778 9 36.00 J - 55 BTC „ - Casing Description String 0... String ID Top (ftKB) Set Depth (f... Set Depth (ND) . String Wt... String ... String Top Thrd i` I PRODUCTION 7 6 276 350 9,229.5 69621 26.00 J55 BTC Tubing Strings Tubing Description '.String 0 String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) .. String Wt... IStrng .. String Top Thrd TUBING WO ' 3 1/22 - 992 27_.2 8,636.9 6,526.6 9.30 I L ABM - EUE CONDUCTOR, 5 Completion Details Top Depth NIPPLE, 515 at (ND) Top 1nel Nomi... ;.. Top (ftK8) (ftKB) (') Item Description Comment ID (in) 27.2 27.2 0.06 HANGER FMC TUBING HANGER 3.500 GAS LIFT, -_ -- ,- 515.2 515.2 0.30 NIPPLE CAMCO DS NIPPLE 2.875 3.148 - 8,624.4 6,517.7 44.49 LOCATOR BAKER G -22 LOCATOR SUB 2.992 8,624.7 6,518.0 44.49 SEAL ASSY BAKER 80-20 SEAL ASSEMBLY 3.000 Tubing Description String 0... String ID... Top MKS) Set Depth (f .. Set Depth (TVD) .. String Wt... String ... String Top Thrd TUBING Ong nal 31,2 2.992 8,609.7 8,8444 6,675.4 9.20 J - 55 BTC SURFACE, 3 2 -875 ) 37-4,603 Completion Details sr Top Depth GAS LIFT, (ND) Top Inc! Nomi... it- 5,133 To p (ftKB) MKS) S ° ) Item Description Comment ID (in) ;. 8,609.7 6,507.3 44.51 PBR BAKER PBR 3.000 lap iii 8,623.5 6,517.1 44.49 PACKER BAKER FHL PACKER 3.000 8,699.8 6,571.5 44.40 BLAST RINGS CARBIDE BLAST RINGS 2.992 GAS LIFT, _. V. • 681 8,793.9 6,638.8 44.29 NIPPLE AVA BPL LANDING NIPPLE 2.750 ON.T. 8,796.7 6,640.8 44.28 XO Reducing CROSSOVER 3.5 x 2.875" ID 2.441 ", 6.58, J -55 EUE8rd 2.875 PATCH, 6,737 - 8,820.2 6,658.1 43.89 LOCATOR BAKER LOCATOR 2.441 8,821.3 6,658.8 43.88 PACKER BAKER DB PACKER w/ SBE (3.25 seal diameter and S stroke) 4.750 PATCH, 6,762 - -- -- 8,836.1 6,669.4 43.70 NIPPLE CAMCO D NIPPLE NO GO 2.250 8.843.7 6,674.9 43 61 SOS CAMCO SHEAR OUT SUB 2.441 PATCH,7,082 - - - -- Other In Hole 'reline retrievable plugs, valves, pumps, fish, etc.) Top Depth i (1Y0) Top loci GAS LIFT. __ ____ - Top (ftKB) (ftKB) (1 Description Comment Run Date ID (in) ],193 _.._. 6,737 5,264.4 49.74 PATCH TTS X -SPAN PERMANENT PATCH 6/16/2011 2.375 6,762 5,280.3 49.77 PATCH TTSX -SPAN PERMANENT PATCH 6/14/2011 2.375 7,082 5,486.5 50.09 PATCH TTS X -SPAN PERMANENT PATCH 6/11/2011 2.375 GAS ss7z UFT, 8, 794 6,638.8 44.29'SLEEVE -C AVA TPI 2.75" SLEEVE (NEW STYLE) 9/4/2010 2.310 i 9,025 6,807.9 41.03 FISH Grapple 1.367" Grapple, chased downhole w /SV, unknown 5/31/2003 0.000 MD on 5/31/2003: gauged TBG to 9025' 5/11/2006. PBR, 8,610 4 9,027 6,809.4 41.03 FISH Metal Junk Chased Metal Junk Downho)e Past AVA Profile: 10/2/1993 0.000 gauged TBG to 9025' 5/11/2006. '- LOCATOR, 9,029 6,810.9 41.03 FISH OV 1.5' OV LOST IN RATHOLE, gauged TBG to 9025' 10/23/2003 0.000 8,624 5 PACKER, 8,623 SEAL san 3 1 / Perforations & Slots Shot Top (TVD) Btm (ND) Dens PRODUCTION, _ Top (ftKB) Bon (ftKB) (ftKB) (ftKB) Zone Date (sh..• Type Comment 8,662 8,694 8,732 6,567.4 6,594.5 C -1, 1R -14 10/15/1985 12.0 IPERF 120 deg. ph; 5" HJ II Csg Gun 8,912 8,920 6,724.4 6,730.3 A4, 1R-14 10/15/1985 4.0 IPERF 90 deg. ph; 4" HJ II Csg Gun IPERF_ '_ 8,924 8,960 6733.2 6,759.9 A 3, 1R -14 10/15/1985 4.0 IPERF 90 8,696 - 8,732,,.. deg. ph; 4" HJ II Csg Gun 9,032 9,040 6,813.2 6,819.2 A -2, 1R-14 10/15/1985 4.0 IPERF 90 deg. ph; 4" HJ II Csg Gun NI SLEEVE - C C 4 , N Notes: General & Safety 8,794 End Date Annotation 9/9/2006 NOTE: Waivered Well due to IA x OA communication LOCATOR, 9/29/2008 NOTE: LEAK FOUND CD 1 9772' BY LDL 8,820 9/192010 NOTE: LEAKS FOUND @ 6772', 6745', 7095' BY LDL PACKER, 8,821 10/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE, 8,836 1 SOS, 8,844 IPERF, 8,912 -8,920 7. 68- 'Mandrel Details Top Depth Top Port IPERF, (TVD) Inc! OD Valve Latch Strs TRO Run 8,9248,980 - Stn To B OMB) ( *) Make Model (in) 5ery Type Type (in) (psi) Run Date Con.... 1 3,148.2 2,756.9 44.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/2/2010 FISH, 9,025 `." ' 2 5,132.6 4,147.4 47.58 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/2/2010 FISH, 9,027 3 6,680.7 5,227.7 49.64 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 4/14/2011 4 7,793.1 5,948.0 4925 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 10/16/2003 FISH, 9,029 5 8,572.5 6,481.4 45.45 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 4/142011 6 8,662.1 6,544.6 44.45 MERLA TMPD 1 PROD DMY BK 0.000 0.0 723/2003 IPERF, 9,032 -9,040 PRODUCTION, 35- 9,229 TD, 9,250 1 • • WELL LOG 1 r - IRS TRANSMITTAL PROAcUivE DiAgNOSric SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road 4611)141VED FFB 1 2U1 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 29- Nov-10 1R-14 1 Report / EDE 50-029- 21386 -00 2) Caliper Report 04- Dec -10 1E-08 1 Report / EDE 50 -029- 20496 -00 t�O -v ao_:l-4 t 5 —15 '7 065c1 Signed : �. Dam. '=� ti l c,. 4F- Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-mAIL : pdsanchoragei )mernorvloq.com WEBSITE : www.rnernorvloa.corn C:\Documents and Settings \Diane Williams \Desktop \TransmitConoco.docx i • III , Multi- Finger Cal r Log Results Summary ,.. 1 Company: ConocoPhillips Alaska, Inc. Well: 1R -14 Log Date: November 29, 2010 Field: Kuparuk Log No.: 10258607 ZX70 State: Alaska 1 Run No.: 3 API No.: 50- 029 - 21386 -00 Pipet Desc.: 3.5" 9.3 Ib. L-80 ABM EUE Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 8,794 Ft. (MD) I Pipe2 Desc.: 2.875" 6.5 Ib. J -55 EUE 8RD Top Log Intv12.: 8,794 Ft. (MD) Pipe2 Use: Tubing Tail Bot. Log Intv12.: 8,830 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection I COMMENTS : I This caliper data is correlated to jewelry per customer request. This log was run to assess the condition of the tubing and tubing tail with respect to internal corrosive and mechanical damage. I The caliper recordings indicate a probable hole (85% wall penetration) and a 64% wall penetration in joint 213 at 6,745' and 6,748' respectively. The remainder and majority of 3.5" tubing logged appears to be in good condition with respect to internal corrosive and mechanical damage, with no other significant wall I penetrations, areas of cross - sectional wall loss or I.D. restrictions recorded. A Baker MVRT (October 16, 2010) found external corrosion on the tubing, and an LDL (September 19, 2010) indicated leaks at ± 6,745', 6,772', and 7,095'. The probable hole recorded at 6,745' in joint 213 and the I shallow pit recorded at 6,773' in joint 214 appear to correlate with two of the three leak points indicated in the LDL. If damage reported by a caliper is due to external corrosion that damage would indicate a hole regardless of the reported percentage wall thickness. A 3 -D log plot of the caliper recordings across the leak interval is included in this report. I The caliper recordings indicate the 2.875" tubing tail logged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross - sectional wall Toss or I.D. restrictions recorded. The joint tabulation data and body region analysis for the 3.5" tubing and 2.875" I tubing tail logged are combined. This is the third time a caliper has been run in this well, the second time the 3.5" tubing above the packer has I been logged, and the third time the 3.5" tubing below the packer and the 2.875" tubing tail have been logged. A comparison of the current and previous log (October 23, 2008) indicates little if any increase in overall internal corrosive damage during the time between Togs, with the exception of a probable hole recorded in the current log that was not recorded in the previous log. 1 This summary report is interpretation of data provided by Halliburton Well Services. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS : 1 Probable Hole (85 %) Jt. 213 @ 6,745 Ft. (MD) Isolated Pitting (64 %) Jt. 213 @ 6,748 Ft. (MD) Shallow Pitting (17 %) Jt. 214 @ 6,773 Ft. (MD) 1 No other significant wall penetrations (> 17 %) are recorded. I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659-2314 1 1 1)S - ` 005 1 • • 3.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss > 6% are recorded. 9 ( ) 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. 2.875" TUBING TAIL - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 10 %) are recorded throughout the tubing tail logged. 2.875" TUBING TAIL - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall Toss (> 3 %) are recorded throughout the tubing tail logged. 2.875" TUBING TAIL - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing tail logged. 1 1 1 1 1 1 Field Engineer: M. Biery Analyst: C. Waldrop Witness: B. Boehme ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS ©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 I • • PDS Multifinger Caliper 3D Log Plot I F Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1R-14 Date : November 29, 2010 I Description : Detail of Caliper Recordings Across Interval where LDL (09- 19 -10) Indicated Leaks at 6,745', 6,772' and 7,095' Comments Depth Max. Pen. ( %) Maximum I.D. 3-0 Log Image Map 1ft:340ft 0 100 2.5 inches 3.5 104° 0° 180° 270° 0° Minimum I.D. I--° —I I I . 2.5 inches 3.5 Nominal I.D. i 2.5 inches 3.5 I 1 ■�f� Joint 211 ! - 6675 i E. - -- Flt _ — II Pup Jt ..11M.lig .... s I GLM 3 „� • " . • 1 Pup Jt 6700 .■�.tk�■ -- _ ........< . .: ,., _ , .� — —__ I II o Joint 212 11.111 i . 6725 1 I Joint 213 I i„ Probable Hole _ 85% Wall Penetration 11.11/ , (6,745') 1r �mi t♦ - - ' Isolated Pitting ENURE = 6 4% Wall Penetration E (6,748') 6750 7 ■■`��■ • I Joint 214 6775 ••••••• ■■1113•■■ Shallow Pitting .1.1111.11. ,LFFSs�■■■ _ 17% Wall Penetration 11111111 77 .`.° .■F V■■■ - ..... I 6800 ��E���� ■■uui■u• Ma Joint 215 11111111 ■ ME 111111 a � 6825 - Joint 216 1 j 6850 - ■ 7 1 I ■ I S J Ir oint 217 6875 ■■■■ii.■■ 1 I ■.■ ■Eti■■ I MINIM It �_ ■ ■■■Intl■■ 11111111 I 6900 .111..11111111 Joint 218 ■■■■It;i■■ •■■ •1ii■■ - ■.. ■r.. 6925 •11111•111:11111•1E11 ■■ 1 Joint 219 • ■■■■ia ■.■■ �� ■IJ 6950 1111111 - ■ ■ ■ ■ ■■ ■■■■i i■■ _ ■■■■L�■■. Joint 220 ■ . ■. ■■■■l &I■■ - 6975 ■■■■i uuuu mum I ■■■■ii.■ ■■■ ■■■■i1.■■■■ Joint 221 7000 ■■■ ■f i.■■■■ ■■■■II■■■■■ ___.-,- _, ■■.■itii... I 7025 ■ ■ ■ ■� . ■ ■� - iimirjammiffl 12:: Joint 222 ■ ■ ■ ■��■ ■■■■�■■■■ 7050 ■ ■ ■ ■It ■ ■ ■ ■■ Int Joint 223 ■ ■■• � 7 `` 7� ■■ -- a . ____ .■ ■ ■I7 ■ ■. IIIIIIIIIIIIIIIIII 7075 1 ■■•■k1u■■■. Joint 224 1 L DL (09- 19 -10) ■■. ■`�! _ ( Fo un d Leak ■■■ ■tl I■■ J '- I — 7,095•) 7100 � Joint 225 yy Ill I N ominal I.D. i 2.5 inches 3.5 Minimum I.D. I 1 2.5 inches 3.5 Comments Depth Max. Pen. ( %) Maximum I.D. 3-0 Log Image Map i 1ft:340ft 1 0 100 2.5 inches 3.5 104° 0° 90° 180° 270° 0° I I I . • Correlation of Recorded Damage to Borehole Profile I Pipe 1 3.5 in (51.0' - 8793.8') Well: 1R-14 d Pipe 2 2.875 in (8793.8' - 8828.1') Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: November 29, 2010 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 57 2 5 4 820 I 50 � 1 1601 75 2383 I GLM 1 • - . 3180 -, 1 125 ` 3956 150 4734 0 GLM 2 1 175 5533 Z 200 — 6307 5. 1 GLM 3 3 0 a _ °1 0 225 1 7108 ai I GLM 4 250 j 7901 GLM 5 mom- 1 PM 6 275 - 8731 276.6 8828 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) 1 I Bottom of Survey = 276.6 I I I H1 • • I Maximum Recorded Penetration Comparison To Previous I Well: 1R-14 Survey Date: November 29, 2010 Field: Kuparuk Prey. Date: October 23, 2008 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 10000429 HAL I Country: USA Tubing: 3.5" 9.3 lb L-80 ABM EUE Overlay Difference I Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) I 0.1 0 50 100 150 200 250 -100 -50 0 50 100 150 200 0.1 ■ 8 8 I 17 _ 17 27 - 27 37 = 37 I 47 47 57 - 57 67 = 67 I 77 77 87 87 97 =-- 97 104 04 I 114 14 124 `° 24 E 1 E 34 I z 144 z ' 44 t 154 - e . 54 le 162.2 1E2.2 1 171 - - 71 181 '81 191 = 91 I 201 201 211 211 218 _= 218 I 228 _ 228 238 = 238 246.2 246.2 I 255 ?55 265 265 271.1 -- 271.1 I 276.1 ? 276.1 -48 -24 0 24 48 71 95 • November 29, 2010 ■October 23, 2008 Approx. Corrosion Rate (mpy) 1 I I PDS Report Overview .� � e Body Region ion Anal Y sis I Well: 1R-14 Survey Date: November 29, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 ABM EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins 2.875 ins 6.5 ppf J -55 EUE 8RD 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration(% wall) Damage Profile (% wall) I 300 NNE Penetration body it Metal loss body 0 50 100 250 0 1 200 A 150 1 1 100 50 48 0 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 293) GLM 1 •' I 292 0 0 1 A A 1 Damage Configuration ( body) 146 10 GLM 2 liii 194 a 5 I GLM 3 '- �t 0 242 Isolated General Line Other Hole/ GLM 4 1 Pitting Corrosion Corrosion Damage Pos. Hole [�� PIOf b I Number of joints damaged (total = 3) 2 0 0 0 1 Bottom of Survey = 276.6 I I 1 1 111 • • PDS REPORT JOINT TABULATION SHEET II , 1 Pipe: 3.5 in 9.3 ppf L -80 ABM EUE Well: 1 R -14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 29, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % t_oss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 51 0 0.02 9 1 2.93 Pup 1 I 1 57 87 0 0.03 11 2 2.97 1.1 0 0.02 8 1 2.96 Pup 1.2 93 0 0.02 7 1 2.93 Pup Lt. Deposits. 2 99 0 0.02 9 1 2.95 3 131 0 0.02 8 2 2.95 4 162 0 0.02 6 1 2.96 5 193 0 0.02 7 2 2.97 6 224 0 0.03 11 2 2.97 7 255 0 0.02 8 2 2.96 8 286 0 0.02 8 2 2.95 9 318 0 0.02 7 2 2.96 10 349 0 0.03 12 1 2.96 11 381 0.03 0.01 6 2 2.97 12 412 0 0.02 7 2 2.95 13 443 0.03 0.02 8 1 2.95 14 475 0.04 0.02 6 2 2.96 15 506 0 0.03 10 2 2.96 1 15.1 537 0 0 0 0 2.88 Camco DS Nipple 16 539 0 0.03 11 2 2.95 17 570 0 0.02 8 2 2.95 18 601 0 0.03 10 1 2.96 111 19 633 664 0 0.01 6 1 2.96 20 0 0.02 8 2 2.95 21 695 0 0.02 7 2 2.95 22 726 C) 0.02 8 1 2.96 23 758 24 0 0.02 9 2 2.94 789 0 0.01 6 1 2.96 25 820 0 0.02 9 2 2.95 26 851 0 0.02 6 2 2.95 I 27 883 0 0.02 8 2 2.94 28 914 0 0.02 7 2 2.92 Lt. Deposits. 29 945 0 0.01 6 1 2.95 30 977 0 0.02 8 1 2.95 31 1008 0 0.02 7 2 2.96 32 1039 0 0.03 11 1 2.94 33 1070 0 0.01 6 1 2.94 34 1102 0 0.02 8 1 2.94 35 1133 0 0.02 7 2 2.93 I 36 1164 0 0.02 7 2 2.96 37 1196 0 0.02 9 1 2.95 IN 1226 0 0.02 9 1 2.95 39 1257 0 0.02 7 2 2.94 40 1289 0 0.02 7 2 2.94 41 1320 0.03 0.02 7 1 2.95 42 1351 0.03 0.02 8 2 2.93 Lt. Deposits. 43 1383 0 0.02 7 1 2.96 44 1413 0 0.02 7 1 2.94 45 1444 0 0.02 6 2 2.96 46 1476 0 0.02 7 2 2.96 I Prat Meta l Loss ion Body Page 1 1 I I 9 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 ABM EUE Well: 1R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: November 29, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 47 1507 0 0.02 8 1 2.96 48 1538 0 0.02 7 2 2.95 49 1569 0 0.02 7 1 2.95 50 1601 0.04 0.03 12 2 2.92 Lt. Deposits. • 51 1632 0 0.03 10 1 2.95 I 52 1663 0 0.01 6 2 2.94 53 1695 0 0.02 6 2 2.94 54 1726 0 0.02 9 2 2.95 55 1757 0 0.02 7 _ 1 2.96 56 1789 0 0.02 6 1 2.93. Lt. Deposits. 57 1820 0 0.02 7 2 2.93 Lt. Deposits. 58 1851 0 0.02 7 2 2.93 Lt. Deposits. 59 1882 0 0.02 7 2 2.94 I 60 1914 0 0.02 9 2 2.96 61 1945 0 0.02 7 2 2.94 62 1976 0.04 0.02 9 1 2.95 63 2007 0 0.01 6 1 2.95 64 2039 0 0.02 7 2 2.95 I 65 2070 0 0.01 6 1 2.95 66 2101 0 0.02 7 1 2.94 67 2132 0 0.02 9 1 2.95 68 2164 0 0.02 6 2 2.94 I 69 2195 0 0.01 6 2 2.94 70 2226 0 0.02 8 2 2.95 71 2258 0 0.02 9 1 2.95 ■ 72 2289 0 0.02 9 2 2.95 I 73 2320 0 0.02 8 2 2.96 _ 74 2351 0 0.02 9 2 2.95 75 2383 0 0.02 8 2 2.96 76 2414 0.03 0.02 7 1 2.93 Lt. Deposits. 77 2445 0 0.03 11 2 2.94 I 78 2477 79 2508 0 0.02 8 2 2.95 0 0.02 9 1 2.93 Lt. Deposits. • 80 2539 0 0.02 9 2 2.93 Lt. Deposits. 81 2568 0 0.01 6 1 2.94 3 III 82 2599 0 0.02 7 1 2.93 83 2630 0 0.03 11 2 2.93 Lt. Deposits. 84 2662 0 0.01 6 1 2.95 3 85 2693 0 0.02 8 1 2.96 I 86 2724 0 0.03 11 1 2.94 87 2755 0 0.02 8 2 2.94 88 2785 0 0.02 7 2 2.95 89 2816 0.03 0.02 9 2 2.95 I 90 2848 0 0.02 7 2 2.95 91 2879 0 0.02 7 1 2.96 92 2910 0 0.02 6 1 2.96 93 2942 , 0 0.02 7 2 2.95 94 2971 0 0.02 7 1 2.95 I 95 3003 0 0.03 11 2 2.94 • 96 3034 0 0.02 9 1 2.94 I Penetration Body Metal Loss Body Page 2 I I I • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 ABM EUE Well: 1 R -14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey urvey Date: November 29, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 97 3065 0.03 0.03 11 2 2.96 ■ 98 3096 0 0.03 11 1 2.92 Lt. Deposits. ■ 99 3128 0.04 0.03 12 3 2.95 99.1 3159 0 0.02 8 , 1 2.93 Pup Lt. Deposits. 99.2 3165 0 0 0 0 2.93 GLM 1 (Latch @ 12:30) I 99.3 3173 100 3180 0 0.02 7 0 0.02 8 1 2.92 2.95 Pup Lt. Deposits. 101 3210 0 0.02 7 2 2.96 102 3241 0.03 0.03 11 2 2.94 I 103 3272 104 3304 0 0.02 9 2 2.94 0 0.02 8 1 2.94 105 3335 0 0.03 10 2 2.94 • 106 3366 0 0.02 9 2 2.94 I 107 3398 0.03 0.02 8 2 2.94 108 3429 0 0.03 10 2 2.95 109 3460 0 0.01 6 1 2.95 110 3491 0 0.02 6 1 2.94 111 3523 0 0.02 7 2 2.96 I 112 3551 0 0.02 6 2 2.94 113 3582 0 0.02 6 2 2.93 114 3614 0 0.02 7 2 2.93 Lt. Deposits. 115 3645 0 0.02 7 2 2.90 Lt. Deposits. I 116 3676 0 0.02 8 2 2.95 117 3707 0 0.02 9 1 2.94 IN 118 3739 0 0.02 9 1 2.93 119 3769 0 0.02 7 1 2.95 I 120 3801 0 0.02 9 2 2.93 Lt. Deposits. • 121 3832 0 0.02 9 1 2.93 Lt. Deposits. 7 122 3864 0 0.02 7 2 2.93 123 3895 0.03 0.03 11 2 2.94 I 124 3925 125 3956 0 0.02 9 2 2.94 0 0.02 9 2 2.95 126 3987 0 0.02 8 1 2.94 127 4018 0 0.02 9 1 2.94 • I 128 4049 0 0.02 9 2 2.94 ■ 129 4081 0 0.02 7 2 2.95 J 130 4112 0 0.02 9 2 2.95 131 4143 0 0.02 7 1 2.94 132 4175 0 0.02 9 2 2.95 ■ I 133 4206 0 0.02 9 2 2.93 Lt. Deposits. • 134 4237 0 0.02 9 3 2.93 Lt. Deposits. 135 4268 0 0.02 7 1 2.94 136 4299 0 0.02 8 1 2.95 I 137 4330 0 0.02 7 2 2.94 138 4361 0 0.02 8 2 2.95 139 4393 0 0.02 7 1 2.94 140 4424 0 0.02 9 2 2.95 141 4455 0 0.02 9 2 2.94 I 142 4487 143 4518 0 0.02 7 2 2.95 0 0.02 7 2 2.95 dy I Metal Loss Body Page 3 Penetration 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 ABM EUE Well: 1 R -14 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 29, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 144 4549 0 0.03 10 2 2.95 145 4580 0.03 0.02 8 2 2.93 146 4610 0 0.02 9 2 2.92 Lt. Deposits. 147 4642 0 0.01 6 2 2.95 148 4673 0 0.02 8 2 2.94 I 149 4703 150 4734 0 0.02 9 2 2.94 0 0.02 7 1 2.94 151 4765 0 0.03 10 2 2.95 152 4797 0.04 0.02 7 2 2.92 Lt. Deposits. ' 153 4826 0 0.02 9 2 2.95 • 154 4857 0 0.03 112 2.93 Lt. Deposits. ■ 155 4887 0 0.02 9 2 2.93 156 4918 0 0.02 9 2 2.93 1 ii 157 4950 0 0.02 7 1 2.94 I 158 4981 0 0.02 8 1 2.94 159 5012 0 0.02 7 2 2.93 160 5043 0 0.02 8 1 2.93 161 5075 0 0.02 7 1 2.95 162 5106 0 0.02 7 2 2.94 162.1 5137 0 0.02 6 0 2.93 Pup Lt. Deposits. 162.2 5143 0 0 0 0 2.90 GLM 2 (Latch @ 6:00) 162.3 5152 0 0.02 9 I 2.90 Pup Lt. Deposits. I 163 5158 164 5189 0 0.02 9 1 2.94 0 0.02 7 2 2.96 165 5220 0 0.03 11 2 2.95 166 5251 0 0.02 8 2 2.93 I 167 5282 0 0.02 7 2 2.95 168 5313 0 0.03 11 2 2.94 169 5345 0 0.02 7 2 2.93 170 5376 0 0.03 12 2 2.95 Shallow Pitting. ■ 171 5407 0 0.03 10 2 2.93 Lt. Deposits. IN 172 5438 0 0.02 9 2 2.93 Lt. Deposits. ■ 173 5470 0.04 0.03 12 2 2.93 Lt. Deposits. IN 174 5500 0.03 0.03 11 2 2.93 Lt. Deposits. • 175 5533 0 0.02 9 2 2.94 176 5563 0 0.02 7 2 2.93 Lt. Deposits. 177 5594 0 0.02 8 2 2.92 Lt. Deposits. 3 178 5626 0 0.03 11 1 2.94 179 5657 0 0.02 8 2 2.93 Lt. Deposits. I 180 5689 0.04 0.02 7 2 2.93 Lt. Deposits. 181 5720 0 0.02 9 1 2.94 • 182 5751 0.03 0.03 11 2 2.93 Lt. Deposits. 183 5782 0 0.02 7 1 2.93 Lt. Deposits. I 184 5813 0 0.02 8 1 2.93 Lt. Deposits. 185 5844 0 0.02 7 1 2.94 186 5875 0 0.02 7 2 2.94 187 5906 0 0.02 9 2 2.93 Lt. Deposits. ■ 188 5937 0.03 0.03 12 2 2.92 Lt. Deposits. ■ I 189 5968 0 0.03 11 2 2.93 Lt. Deposits. 190 5999 0 0.02 8 2 2.94 I Penetration Body I Metal Loss Body Page 4 1 I I • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 ABM EUE Well: 1R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 29, 2010 1 II ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 191 6030 (1 0.03 10 1 2.95 192 6062 0 0.02 7 2 2.94 • • � 193 6092 0.03 0.03 11 1 2.93 Lt. Deposits. 194 6124 0 0.03 11 2 2.91 Lt. Deposits. • 195 6153 0 0.02 7 2 2.94 IN 196 6184 0 0.02 9 1 2.94 197 6215 0 0.03 11 2 2.92 Lt. Deposits. • • 198 6246 0 0.02 9 2 2.93 Lt. Deposits. • 199 6277 0 0.02 9 1 2.91 Lt. Deposits. • 200 6307 0.03 0.03 10 2 2.94 • 201 6339 0 0.03 11 2 2.96 • 202 6370 0 0.02 8 2 2.94 1 203 6400 0 0.03 11 2 2.94 • 204 6430 0 0.02 9 2 2.93 Lt. Deposits. 205 6462 0 0.03 10 2 2.95 • 206 6493 0 0.02 8 2 2.96 • • 207 6524 0 0.03 11 2 2.95 • 208 6555 0 0.02 9 2 2.94 ' 2 6585 0 0.03 12 1 2.96 • 210 6617 0 0.02 9 2 2.94 • • 211 6648 0.03 0.03 10 1 2.91 Lt. Deposits. 211.1 6679 0 0.02 7 1 2.90 Pup Lt. Deposits. • 211.2 6687 0 0 0 0 2.92 GLM 3 (Latch @ 11:00) 211.3 6694 0 0.01 6 2 2.91 Pup Lt. Deposits. 212 6701 0 0.02 7 2 2.93 11 213 6732 0.04 0.22 85 6 2.93 Probable Hole! 1:•••■• 214 6763 0.04 0.04 17 2 2.92 Shallow Pitting. Lt. Deposits. 215 6795 0 0.03 12 2 2.92 Lt. Deposits. 216 6826 0 0.02 7 2 2.95 U 217 6857 0 0.02 8 2 2.92 Lt. Deposits. • I 218 6888 0 0.03 10 2 2.93 Lt. Deposits. C 219 6920 0.04 0.03 10 2 2.94 220 6951 0 0.03 10 2 2.94 • 221 6982 (1 0.03 11 2 2.93 Lt. Deposits. • 222 7014 0 0.03 11 2 2.94 • 223 7044 0 0.02 8 2 2.95 III 224 7076 0 0.03 12 2 2.93 • • 225 7108 0 0.02 8 2 2.96 226 7138 0 0.02 9 2 2.94 • • 227 7170 0 0.02 8 2 2.95 IN 228 7200 O 0.03 11 2 2.92 Lt. Deposits. IN 229 7232 0 0.02 9 2 2.94 • • 230 7262 0 0.02 8 1 2.93 Lt. Deposits. 231 7293 0 0.03 11 2 2.93 Lt. Deposits. • I 232 7325 0 0.02 9 2 2.93 Lt. Deposits. • 233 7354 0.04 0.03 11 2 2.94 • 234 7382 0 0.03 11 2 2.91 Lt. Deposits. • 235 7414 0 0.02 8 2 2.93 Lt. Deposits. 236 7444 0 0.02 8 2 2.94 237 7475 0 0.02 9 1 2.94 • ' Penetration Meta l Lo B Body dy ss o I Page 5 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 ABM EUE Well: 1 R -14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: November 29, 2010 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 238 7504 0 0.03 12 2 2.89 Lt. Deposits. 239 7537 0 0.02 9 2 2.93 Lt. Deposits. 240 7568 0 0.02 7 1 2.94 241 7599 0 0.02 6 1 2.95 242 7630 0 0.03 12 2 2.93 Lt. Deposits. I 243 7662 0.03 0.02 8 2 2.93 Lt. Deposits. 244 7693 0 0.02 8 2 2.93 Lt. Deposits. 245 7725 0 0.02 7 2 2.94 246 7756 0 0.02 7 1 2.94 I 246.1 7786 0 0.02 7 0 2.94 Pup 246.2 7793 0 0 0 0 2.93 GLM 4 (Latch @ 11:00) 246.3 7801 0 0.02 6 0 2.93 Pup Lt. Deposits. 247 7807 0 0.02 8 2 2.93 Lt. Deposits. I 248 7839 0.03 0.02 7 2 2.93 249 7868 0 0.02 9 2 2.93 Lt. Deposits. 250 7901 0 0.02 9 1 2.92 Lt. Deposits. 251 7932 0 0.02 8 2 2.94 252 7962 0 0.02 9 1 2.95 I 253 7994 0 0.02 8 2 2.93 254 8025 0.03 0.02 7 2 2.94 255 8056 0 0.02 9 2 2.93 Lt. Deposits. 256 8086 0.01 0.03 10 2 2.93 Lt. Deposits. I 257 8117 258 8147 0 0.02 9 2 2.93 Lt. Deposits. 0 0.03 11 2 2.90 Lt. Deposits. 259 8178 0 0.02 8 2 2.92 Lt. Deposits. 260 8210 0 0.03 11 2 2.89 Lt. Deposits. I 261 8241 0 0.02 9 2 2.93 Lt. Deposits. 262 8272 0 0.03 10 2 2.93 Lt. Deposits. 263 8304 0 0.03 10 2 2.93 Lt. Deposits. 264 8335 0 0.03 12 2 2.93 I 265 8366 0 0.03 10 I 2.92 Lt. Deposits. 266 8398 0 0.02 8 1 2.91 Lt. Deposits. 267 8430 0 0.02 9 2 2.92 Lt. Deposits. 268 8459 0 0.03 11 3 2.93 269 8489 0 0.02 8 1 2.92 Lt. Deposits. I 270 8521 0 0.03 11 2 2.93 Lt. Deposits. 270.1 8552 0 0.02 6 1 2.94 Pup 270.2 8557 0 0 0 0 2.97 GLM 5 (Latch @ 6:30) 270.3 8566 0 0.02 7 1 2.89 Pup Lt. Deposits. 271 8572 0.03 0.02 9 2 2.93 Lt. Deposits. 271.1 8603 0 0.01 6 0 2.91 Pup Lt. Deposits. 271.2 8609 0 0 0 0 3.00 Baker PBR Assembly 271.3 8622 0 0 0 0 3.00 Baker FHL Packer I 271.4 8623 0 0 0 0 3.00 Baker 80 -20 Seal Assembly 272 8630 0 0.02 9 3 2.92 Lt. Deposits. 272.1 8661 0 0 0 0 2.87 Production Mandrel 6 (Latch @ 11:30) 273 8668 0 0.03 11 2 2.90 Lt. Deposits. 274 8699 0.04 0.02 9 1 2.90 Lt. Deposits. I 275 8731 0.15 0.02 9 4 2.96 276 8761 0 0.03 10 2 2.89 Lt. Deposits. Penetration Bo I Metal Loss Body I Page 6 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 ABM EUE Well: 1 R -14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 29, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 276.1 8794 0 0 0 0 2.31 AVA Landing Nipple w/ TIP 2.75" Sleeve 276.2 8797 0 0 0 0 2.88 3.5" x 2.875" Cross-over 276.3 8801 0 0.02 8 1 2.39 Pup Top of 2.875" Tubing Tail U 276.4 8810 0 0.02 10 3 2.36 Pup Lt. Deposits. 276.5 8820 0 0 0 0 4.75 Baker DB Packer w/ SBE 276.6 8828 0 0.01 4 0 2.35 Pup Lt. Deposits. I Penetration Body Metal Loss Body 1 1 I I r 1 Page 7 I I • • I PDS Report Cross Sections VS,. I Well: 1R -14 Survey Date: Tool Type: November 29, 2010 Field: Kuparuk UW MFC 24 No. 10000429 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 ABM EUE Analyst: C. Waldrop I I Cross Section for Joint 213 at depth 6744.920 ft Tool speed = 53 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 95% Tool Tool deviation = 48° I I I � I Finger = 14 Penetration = 0.217 ins Probable Hole 0.22 ins = 85% Wall Penetration HIGH SIDE = UP I I I I I r I S 0 1 PDS Report Cross Sections I Well: 1R -14 Survey Date: Tool Type: November 29, 2010 Field: Kuparuk UW MFC 24 No. 10000429 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 ABM EUE Analyst: C. Waldrop I I Cross Section for Joint 213 at depth 6747.820 ft Tool speed = 53 Nominal ID = 2.992 1 Nominal OD = 3.5 Remaining wall area = 95% Tool deviation = 48° 1 I 1 I I l i-- - ___-- \ 1 I ..----Y I I Finger = 7 Penetration = 0.163 ins Isolated Pitting 0.16 ins = 64% Wall Penetration HIGH SIDE = UP I I I 1 I I ill: . 3 KUP 1 R -14 ConocoPhillips 8 Attributes Ainu.n. W Nlbore APIJUW ogle & MD TD FM MKS) Field name Well stales Inc!(1 KB) Aa Bhn MKS) Lonoci7liaps 50 0292138600 KUPARUK RIVER UNIT PROD 50.03 7,100.00 9,250.0 Lament H2S (ppm) Dale Amadion End Date IB.Q'd Rig Release Dale Wo6 coNn9: -18 -14 ia3ln0101084 ao A14 SV: NIPPLE 75 8/6/2009 Last WO: 8/14/2003 36.79 8/7/1985 ••• Schematic -Ades! aatlon Depth (m(B) pate Amdatlon Last Mod ... End Date t Tag:SLM 9.017.0 9/4/2010 _Rev Reason: LDL, GLV C/O Imosbor 10/31/2010 HANGER, 27 Casing Strings II Casing Description String 0... String ID ... Top (TM) Set Depth (f... Set Depth (TVD) ... String WL.. String... String Top Thrd CONDUCTOR 16 15.063 38.0 _ 115.0 115.0 62.50 H WELDED i Casing Description String 0... String ID ... Top (RIB) Set Depth (L.. Set Depth (TVD) ... String WL.. String... String Top Thrd SURFACE 9 5/8 8.921 37.0 4,603.2 3,778.9 36.00 J BTC Casing Description String 0... String ID _. Top (11KB) Set Depth (L.. Set Depth (7VD) ... String WL.. String... String Top Thrd PRODUCTION 7 6.151 35.0 9,229.5 6,962.1 26.00 J-55 BTC Tubing Strings TUB W nption Suing 2.,. IStrkg9 ...ITo) 2 I 86 3th ._ !Set Depth h6 (0)... IStri9 O ..ISui O... m o_p E Thrd CONDUCTOR, Completion Details 39 Top Depth CM) Top Ind Nomi... NPPLE. 515 -.- Topp11B) ( B) r) Rem Description Comment ID (in) 27.2 27.2 0.06 HANGER FMC TUBING HANGER 3.500 515.2 515.2 0.30 NIPPLE CAMCO DS NIPPLE 2.875 GAS LIFT, 8,624.4 6,517.7' 44.49 LOCATOR BAKER G-22 LOCATOR SUB 2.992 3,149 8,624.7 6,518.0 44.49 SEAL ASSY BAKER 80 - 20 SEAL ASSEMBLY 3.000 Tubing Description String O... String ID... Top (1KB) Set Depth (f... Set Depth (TVD)... String Wt... String ... Suing Top Thad 0 TUBING Original 31/2 2.992 8,609.7 8,844.4 6,675.4 9.20 J-55 BTC I SUR 3.5 "x 2.875" Completion Details FACE, 374,603 Tap Depth (T'D) Top Ind Nomi.- Top (RKB) MB) ("I Item Description Comment ID (In) GAS LIFT. 8,609.7 6,507.3 44.51 PBR BAKER PBR 3.000 5.133 8,623.5 6,517.1 44.49 PACKER BAKER FHL PACKER 3.000 8,699.8 6,571.5 44.40 BLAST RINGS CARBIDE BLAST RINGS 2.992 8,793.9 6,638.8 44.29 NIPPLE AVA BPL LANDING NIPPLE 2.750 GAS LET, � 8,796.7 6,640.8 44.28 XO Reducing CROSSOVER 3.5 x 2.875" ID 2.441', 6.5#, J-55 EUE8rd 2.875 6,681 I ME MI 8,820.2 6,658.1 43.89 LOCATOR BAKER LOCATOR 2.441 8,821.3 6,658.8 43.88 PACKER BAKER DB PACKER w/ SBE (3.25 seal diameter and 5' stroke) 4.750 ME CAMCO 6,669.4 43.70 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT. 7.793 8,843.7 6,674.9 43.61 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TM Top Ind GAS LIFT. OMB) IOW r) Description Comment Rut Date ID ( h a572 8,793.9 6,638.8 44.29 SLEEVEC AVA TPI 2.75 " SLEEVE (NEW STYLE) 9/4/2010 2.310 8,836.1 6,669.4 43.70 PLUG 2.25" CA-2 PLUG SET IN NIPPLE 9/4/2010 0.000 9,025.0 6,807.9 41.03 FISH Grapple 1.367" Grapple, chased downhole w /SV, unknown 5/31/2003 0.000 PER, a 610 ! MD on 5/31/2003: gauged TBG to 9025' 5/11/2006. 9,027.0 6,809.4 41.03 FISH Metal Junk Chased Metal Junk Downhole Past AVA Profile: 10/2/1993 0.000 gauged TBG to 9025' 5/11/2006. LOCATOR. ' 9,029.0 6,810.9 41.03 FISH OV 1.5" OV LOST IN RATHOLE, gauged TBG to 9025' 10/23/2003 0.000 8,624 y , PACKER. 8.623 '�/ 5/11/2006. • SEAL A ,625 t 9,626 Perforations & Slots Shot PRODUCTION. Top (TVD) Sim (TVD) Dens 8,662 Top (RIB) Bhn(MB) IMO) 6t Zone Date lam• Type comment 8,.0 8,.,.,94., - 10/15/ H I Cog Gun 8,912.0 8,920 0 6 4 6 5 Ad -1 , 1R 1R -14 14 10/15/1985 1985 4 12 .0 .0 IPERF IPRF 90 120 deg. ph; . p 4 ; :.5": HJ J ill CI sg Gun IPERF W 8.694 8,924. 8,960.0 6,733.2 6,759.9 A iR - 14 10/15/1985 4 IPERF 90 deg. ph; 4 " HJ II Csg Gun IF ilt 9,032.0 9,040.0 6,813.2 6,819.2 A -2, 1R -14 10/15/1985 4. IPERF 90 deg. ph; 4 " HJ II Csg Gun NIPPLE. 8.797 SLEEVEL� Notes: General & Safety 8,797 End Dde I Amoption 9/9/2006 NOTE: Waivered Well due to IA x OA communication 9/29/2008 NOTE: LEAK FOUND CO 9772' BY LDL LOCATOR, 8,820 OR. 9/19/2010 NOTE: LEAKS FOUND @ 6772', 6745, 7095' BY LDL PACKER, 8 821 _ 10/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0 a I PLUG.8836 - N ii NIPPLE,9836 ;; MI SOS. 8.844 PERF. 8,912 -8,920 IPERF. Mandrel Details 8.924-8,960 - Top Depth Top Part I (TVD) Inc) 00 Valve Latch Size TRO Pm Stn Top (RIB) (RKB) r) Make Model (in) Sere Type Type (In) (psi) Ron Date Com.. FISH. 9,025 1 3,148.2 2,756.9 44.98 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2010 2 5,132.6 4,147.4 47.58 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2010 FISH, 9027 3 6,680.7 5,227.7 49.64 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/7/2010 0 4 7,793.1 5,948.0 49.25 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/16/2003 FISH, 9.029 5 8,572.5 6,481.4 45.45 CAMCO MMG 1 1f2 GAS LIFT DMY RK 0.000 0.0 10/16/2003 IPERF, 6 8,662.1 6,544.6 44.45 MERLA TMPD 1 PROD DMY BK 0.000 0.0 7/23/2003 9,032 -9.040 i PRODUCTION, 35-9,229 TD, 9,250 I • • Page 1 of 1 Regg, James B (DOA) ~ t~5 _~~ I From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, August 17, 2010 4:36 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 Prod Engr; CPF1 DS Lead Techs; Glessner, Dana Subject: 1 R-14 (PTD# 185-151) Report Of TxIA Communication Attachments: 1 R-14 Wellbore Schematic.pdf; 1 R-14 TIO Plot.pdf Jim/Tom/Guy, Kuparuk gaslifted producer 1 R-14 (PTD# 185-151) is suspected of having TxIA communication based upon a failing TIFL. A leaking gaslift valve or tubing patch is the likely leak source, so slickline will troubleshoo~an 'repair if possible. The well will be added to the SCP report and will be fixed or SI by 08/28/10. Attached are a wellbore schematic and 90 day TIO plot. -~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 ,~, , ~,.n; ~~ ~ ~~ ~ ~ ',~ e, `l CI ~ r~ Pager 907-659-7000 #909 8/20/2010 ~ -~~- i~ ~ Well Name 1 R-14 Notes: End Date 8/29/2010 Days 120 Start Date 5%1 '2010 Annular Communication Surveillance 1600 -___ _~ . . WHP .~_. w - - - -. 90 _ IAP _ OAP 80 1400 _ W HT ~ Lc 1/.~6}~T - 70 ?200 ~ 60 ~ 100E 5~ . a~ Q aoo L/~ ~ 40 600 30 - - Sn0 - - - - 20 - - - ~ EGG - -- - - 10 0 0 May-10 Jun-10 Jul-10 Aug-10 iooo ~DGI I soo aoo ~MGI ~ goo o ~PWI m 600 -S,WI aoo ~BLPD • r~ ICJ ~~~ ~ ~~~ ~~~ ~~ KUP ~ 1R-14 ~~t"]OCO~f1t~~lp5 ' i ~ ~ ell Attributes IMax Angle & MD _ - TD - i w lib re APIILIWI Feld N.ma __ _ Well Status Inc! (`/ 1 D i:u:~) Aci Btm (ftK8) ' ' ' " I' '- / 500292138600 KUPARUK RIVER UN IT PROD 50.03 7,100.00 9,250.0 "- C m nt SSSV NIPPLE H2S (ppm) 75 Date Annotation 8/6/2009 LastWO: End Date 8/142003 KB-0rd (ft) 36.79 Rig Release Date 8!7/1985 _ e ~ ~ .. vn ev a ~ .__ _ . Scne,natic -~cwsl - - - Annotation Lasl Tag:SLM Dep 9 th (ttK8) 031.0 End Dete 2/6/2010 Annotation Rev Reason: TAG Lest Motl By Imosbor End Data 221/2010 Casing Strin gs , ~ r -_ atring OD String ID Set Depth - Set Depth (ND) -- String Wt - Strin - - g CONDUCTOR, I ' - ~ ~ Casing Description (in) lin) Top (RKB) (ttK8) (ftK8) (Ibs//t) Orade String Top Thrd 1u ! , CONDUCTOR 16 15.063 0.0 115.0 115.0 62.50 H-40 ~ SURFACE 95/8 8.766 0.0 4,603.0 3,778.7 36.00 J-55 NIPPLE, 515 ~ PRODUCTION 7 6.156 0.0 9,229.0 6,961.8 26.00 J-55 _ p Tubin Strings ~ _ ~~ ~ _ ~ Str rig OD String ID _ ~ Set Depth Sei Depth (NDh ; String W[ ' St in g GAS LIFT, [ "~ Tubing Description lin) (in) Top (ftK8) (RKB) (RKB) (IbsHt) Grade String To Thrd 3,148 - ~ TUBING 31/2 2.992 0.0 8,610.0 6,507.5 9.30 L-80 BrdEUEABMOC TUBING Original 312 2.992 8,610.0 8,794.0 6,638.9 9.30 J-55 EUE 8RD SURFACE, 4.603 TUBING Original 2 7/8 2.441 8,797.0 8,844.0 6,675.0 6.50 J-55 8RD EUE Other In Hole All Jewel Tubin ry~ Run & Retrievable, Fish, etc. .__ -- -- GAS LIFT, ~.~ ? To Dee h p pt ~ - .-__ _._ 5,133 __ (TVD) lop Inc! Tap (RKB) (RKB) (°) Description Comment Run Date ID (in 515 515.0 0.30 NIPPLE CAMCO'DS' NIPPLE set 10/172003 8/142003 2.87 GAS LIFT, sset J L, j l , 3,148 2,756.7 44.98 GAS LIFT CAMCO/MMG/1.5/GLV/RK/.188/1296/ Comment: STA 1 3/12/2009 2.92 ~ 5,133 4,147.7 47.S8 GASLIFT CAMCO/MMG/1.5/GLV/RW:188/1288/Comment: STA2 3/122009 2.92 6,681 5,228.0 49.64 GAS LIFT CAMCO/MMGl1.5/OV/RW.25//Comment:5TA3 3/132009 2.92 PATCH, x,742 I'. 6,742 5,267.4 49.74 PATCH WEATHERFORD PATCH ASSEMBLY OAL 40.23' 11/272008 1.74 d w/SPACER PIPE & SNAP LATCH SEAL ASSY ~'; . , 7,793 5,947.9 49.25 GAS LIFT CAMCO/MMG/1.5/DMY/RW//Comment: STA4 10/16/2003 2.92 GnsuFr, ~~ 8,572 6,481,1 45.45 GAS LIFT CAMCO/MMG/1.5/DMY/RW//Comment: STA5 10/16/2003 2.92 7 793 -- 8,610 6,507.5 44.51 PBR Baker 4.00"Seal 10/17/1985 3.00 8,623 6,516.7 44.49 PACKER Baker'FHL' PAACKER 10/17/1985 3.00 GAS LIFT, 1 ~ 8,624 6,517.5 44.49 LOCATOR BAKER G-22 LOCATOR SUB SET 8/142003 8/14/2003 2.99 8,572 ' 8,625 6,518.2 44.49 SEAL BAKER 80-20 SEAL ASSEMBLY SET 8/142003 8/142003 3.OC ~' 8,662 6,544.5 44.45 PRODUCTION MERLA/TMPD/1/DMYBW//Comment: STA6 7/23/2003 2.8i PBR, 8,610 8,794 6,638.9 44.29 NIPPLE AVA NIPPLE 10/17/1985 2.75 - 8,794 6,638.9 44.29 SLEEVE-O AVA TPC 2.75" SLEEVE (NEW STYLE) 11/192008 2.31 PACKER, 8,623 Y.~l.:,~' 6,797 6,641.0 44.2$ X(J 3 12 8RD x 2 7/8 8RD 7/12/1998 2.8/ LocnroR, 8,821 6,658.6 43.88 PACKER Baker'DB' w/SBE (3.25" seal diameter and 5' stroke) 10/17/1985 4.75 6,624 8,836 6,669.3 43.71 NIPPLE Camco'D' Nipple NO GO 10/17/1985 2.25 SEAL, 8.625 - o owe c c~c n n~ c~ eno nor...... 1D/17/1gRR 7.44 6,694A, 8,794 X0,6,797 PACKER, 6,821 NIPPLE, 6,836 SOS. 8,844 TTL. 8,895 IPERF. 8,912-9,920 IPERF, e.9za6,9so FISH, 9,025 FISH, 9.027 FISH. 9.029 IPERF, 9.032-9.040 `j ~~ ~ I l 9,025 6,807.9 41.03 FISH Grapple 1.367" Grapple, chased downhole w/SV, unknown 5/31/ MD on 5/312003: gauged TBG to 9025' 5/112006. 9,027 6,809.4 41.03 FISH Metal Junk Chased Metal Junk Downhole Past AVA Prorile: 102/1 gauged TBG to 9025' 5!112006. 9,029 6,810.9 41.03 FISH OV 1.5" OV LOST IN RATHOLE, gauged TBG to 9025' 1023. 5/112006. Pertorations & Slots __ _ __ TShot Top (ND) Btm (ND) Dens 70o IRKB1 Btm 1ftKB1 (RKB) (ftK8) Zone I Date (sh.° ( TYPe Comment era! & deg. to IA x PRODUCTION. 9,229 TD, 9,250 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1R-14 Run Date: 4/7/2010 May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 R-14 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21386-00 Production Profile Log 50-029-21386-00 `' °'''''' ~' { ~ ~, Yl:fi,i t_~ i { 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: /~S5'~5 1 ~ ~ <5 rafael.barr Date: MAY 1 i 2010 Signed: ~ \~ ._ °. ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360--- - - February 1, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ~~CEIVED ~A~C 4 ~ 2010 ~tsska Q~ ~i Sar Carts. Cormrission _ - 1~l1Ch~1f3Qe ,~~~ ~ 5 ~, ~ Enclosed please fmd a spreadsheet~with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped December Sd', 2009. The corrosion inhibitor/sealant was pumped December 22nd, 25d`, 26th & 28d', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,~ Klei3f ConocoPhillips Well Integrity Projects Supervisor .~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/1/2010 1 G. 1 L 8~ 1 R Pad Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1G-17 50029229450000 1990620 SF n/a 17" n/a 7.65 12/26/2009 1 L-01 50029211960000 1841730 52' 7.7 31" 12/5/2009 10.15 12/22/2009 1 L-02 50029211930000 1841700 45' 5.7 35" 12/5/2009 10.15 12/22/2009 1 L-04 50029211790000 1841540 40' 3.9 24" 12/5/2009 5.8 12/22/2009 1 L-06 50029211640000 1841330 2'5" n/a 2'S" - n/a 7.22 12/26/2009 1 L-08 50029211750000 1841500 34' 3.7 40" 12/5/2009 10.2 12/26/2009 1L-09 50029220250000 1900340 11" n/a 11" Na 1.27 12/26/2009 1 L-11 50029220340000 1900450 16" n/a 17" n/a 2.25 12/25/2009 1 L-12 50029220330000 1900440 7" n/a 15" n/a 3.4 12/25/2009 1 L-13 50029221500000 1910420 13' 2.2 27" 12/5/2009 5.52 12/26/2009 1 L-17 50029221510000 1910430 26' 4.0 18" 12/5/2009 9.35 12/26/2009 1 L-19 50029220490000 1900610 9' 2.5 19" 12/5/2009 4.25 12/25/2009 1 L-23 50029221670000 1910620 SF n/a 17" n/a 2.12 12/26/2009 1 L-26A 50029221730100 2000150 SF n/a 17" n/a 2.97 12/25/2009 1 R-14 50029213860000 1851510 SF n/a 29" n/a 5.95 12/28/2009 1 R-31 50029225380000 1941680 6" n/a 24" n/a 7.22 12/28/2009 1 R-32 50029225230000 1941460 SF n/a 24" n/a 5.95 12/28/2009 1 R-33 50029225290000 1941560 SF n/a 24" n/a 4.67 12/28/2009 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other ^ After Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Weil Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, 1r1C. Development 0 • Exploratory ^ 185-151 . 3. Address: Strati ra hic Service g p ^ ^ 6. API Number. P. O. Box 100360, Anchora e, Alaska 99510 50-029-21386-00 7. KB Elevation (ft): 9. Well Name and Number. RKB 82' 1 R-14 ' 8. Property Designation: 10. Field/Pool(s): ADL0025635 ' Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9250' - feet true vertical 6978' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' SURFACE 4521' 9-5/8" 4603' PRODUCTION 9147' 7" 9229' ~~ ~~y~ ~t rr~~ Perforation depth: Measured depth: 8694' - 9040' true vertical depth: 6567.4' - 6819.2' Tubing (size, grade, and measured depth) 2_7/8", J-55, 8844' MD. 1.740" ID Weatherford Patch Assembly @ 6742' Packers &SSSV (type & measured depth) Baker'FHL' & Baker "DB" w/SBE 8623' & 8821' SSSV= CAMCO "DS" NIPPLE SSSV= 515' 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 Wafer-Bbl Casln Pressure Tubi 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. Weli 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 NiA if C.O. Exempt: N/A ~.vnwa[ martin vvaaers r esreni rcogers Printed Name Martin Walters ,~- Title Problem Wells Supervisor Signature !~l'IGG~~~'7/J /,'G~~~G~, / Phone 659-7'224 _( Merl (v YY .,. C~ C/~.; p - ~ grax'~i~ ~7 ~ ^i ~~l~d~ Form 10-404 Revis d 04/2004 ~ ~ ,t . , Date 12/16/08 ~~ ~~, , ~ • ~ z. as Submit ngma Only • 1 R-14 DESCRIPTION OF WORK COMPLETED SUMMARY Date .Event Summa 11/25/08 SET WEATHERFORD 3-1/2" ER PACKER AT 6780' MD. TD NOT TAGGED. ___ SET UPPER PORTION OF PAT Y (3 1/2 ER PACKER (2.74" OD) , 30' 11/27/08 SPACER PIPE, AND SNAP LATCH SEAL ASSEMBLY) - (37.19' OAL W/ MIN. ID OF 1.74 ) IN LOWER PACKER @ 6780' RKB (TOP OF PATCH @ 6742 RKB ). 11/28/08~BLED IA PRESSURE DOWN FROM 750 PS TO 300 PSI TO VERIFY PATCH IS HOLDING. Re-TIFL Passed. Initial T/I/O = 325/1300/930. Shut in well and gas lift upon arrival. Shot 12/01/08 initial IA FL @ 5133 ft (Sta #2 GLV). Stacked out T using LG. T/I/O = 1180/1180/830. Bted / IA down and shot second IAFL @ Same location. Final T/I/O = 1190/760/760. Summary Set Weatherford patch from 6742'-6780' and Re-TIFL'd ~~~~~~~~ NO.4914 '1~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ; -, , ATTN: Beth ~.. ~~t':tc..n~-' ,,. ~ +. li~i~t. Well Job # Log Description G~--- Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1 L-23 12097405 SBHP SURVEY 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE ~j .- /L © p L 09/10!08 1 1 3G-25X 12080437 LDL ~ - 3 L/ (p 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE ~ / 09/14/08 1 1 3M-13 12096541 LDL - (~L( r OC-/ 09/10/08 1 1 2Z-13A 12100446 LDL aQ(o- ( O '3U' 09/15!08 1 1 1F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - '~ 5~- 09/22/08 1 1 1C-111 12100451 INJECTION PROFILE ~ p .. 09/20/08 1 1 30-15 12100452 LDL - ~ SQ 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE o 09/23/08 1 1 i R-11 11966277 SBHP SURVEY S- O 09/25/08 1 1 1R-35 11966279 SBHP SURVEY ~ 09/25/08 1 1 i R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE _ 09/30/08 1 1 1 R-34 12080444 GLS gL .- 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .: L ~/ 10/02/08 1 1 1D-01 12097422 GLS 10/03/08 1 1 1R-07 12097425 PRODUCTION PROFILE ~'~%~ -~- ( 10/06/08 1 1 iH-19 12096548 INJECTION PROFILE L 10/03/08 1 1 1 B-16 12097426 GLS ~ - =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE I 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ('~ 10/07/08 1 1 1B-04 12096552 INJECTION PROFILE ~ 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 1B-16 12096554 PRODUCTION PROFILE G)C~ - G 10!10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ,~"~C , 10/11/08 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. :7 • • T~4N~n/I/•4L ~. ProActive Diagnostic Services, Inc. ~1 I.~ To: ACC Christine Mahnken 333 West 7th Avenue , -~i:'`v,~~~:' ~s',' ,r t ,~ Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907j 245-8952 1) Caliper Report 26-0ct-08 3A-06 1 Report /EDE 50-029-21443-00 2) Caliper Report 23-0ct,~08 1 R-14 1 Report /EDE 50-029-21386-00 ~. t ~sS- t5" t t ~C~S' Signed : Date : Print Name: ~,~, nr~~~'t j.~ c _ N/~c.~.~.c10 PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.88952 E-MAIL: ~3~~~n~~7i33'3Q°C~n'~~3's9t3~~J~s3~.Cfl-i] WEBSITE:taf~MA1.133eY~'3d3~',J~t3~.C{3133 /j C:\Doeuroents and Settings\Owner\Desktop\Transmit_Conoco.doc ,~' • • Memory Multi-Finger Caliper Log Results 5umrnary Company: Conoc~Phillips Alaska, Inc. Well: 1 R-14 Log Date: October 23, 2008 Field: Kuparuk Log No.: 7276 State: Alaska Run No.: 2 API No.: 50-029-21386-00 Pipet Desc.: 3.5° 9.3 Ib. L-80 8RD EUE-ABMOD Top Log Intv11.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 8,794 Ft. (MD) Pipet Desc.: 2.875° 6.5 Ib. J-55 8RD EUE Top Log Intvf2.: 8,794 Ft. (MD) Pipet Use: Tubing Tail Bot. Log Intvl2.: 8,813 Ft. (MD) Inspection Type : Patch Candidacy lnspection COMMENTS 1 This caliper data is tied into the AVA Nipple @ 8, 794' (Drill's Depth). This log was run to assess the condition of the 3.5° tubing with respect to internal corrosive and mechanical ' damage to determine patch candidacy. The caliper recordings indicate the 3.5° tubing appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. A 3-D log plot of the caliper recordings across the interval where an LDL indicated a leak at 6,772' is included in this report. This is the second time a PDS caliper has been run in this well, the first time the new 3.5° tubing has been logged, and the second time the original 3.5" tubing below the packer and the 2.875° tubing tail have been logged. A comparison of the current and previous log (December 5, 2002) indicates no change in either the condition of the original 3.5" tubing completion below the packer or the 2.875" tubing tail during the time between logs. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 8%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. ~'~ ~~ ~~~,r ~ ~ 20~ Field Engineer: W. McCrossan Analyst: C. Waldrop Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.`J. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~amemorylog.com Prudhoe Bay Field OfFice Phone: (907) 659-2307 Fax: {907) 659-2314 ~ ~~ l~ ~ d2S l'~ • PDS Multi finger Caliper 3D Log Plot ~, _ . Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 R-14 Date : October 23, 2008 Description : Detail of Caliper Recordings Across Leak Location (6,772) • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (2.2' - 8808.5') Well: 1 R-14 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 23, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 14 2 5 782 50 ~. 1566 75 2352 GLM 1 3152 125 3933 150 4714 .-. GLM 2 ~ ~ 175 5517 E ~ ~ ._ 200 6298 GLM 3 p 225 7099 GLM 4 250 7895 GLM 5 GLM 6 8732 277 8808 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 277 • • PDS Report Overview ~ S, Body Region Analysis Well: 1 R-14 Survey Date: October 23, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldrop _ Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f N-80 2.992 ins 3.756 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body >® metal loss body 200 150 0 1 0 50 0 0 to 1 to 10 to 1% 10% 20% 20 ro 40 to over 40% 85% 85% Number of 'oints anal se d total = 292 pene. 1 198 93 loss 107 185 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 0 48 GLM 1 98 146 GLM 2 194 GLM 3 242 GLM 4 GLM 6 Bottom of Survey = 2 77 Analysis Overview page 2 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf N-80 Well: 1 R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 23, 2008 Joint No. Jt. Depth (Ft.) I'c~n. lll~,~~t iln~.l Pen. Body (Ins.) I'e~n. % ~1c•t~~l I os `i<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 2 t) 0.02 8 1 2.92 PUP 1 14 U 0.03 11 t3 2.94 1.1 45 U 0.02 7 ,' 2.92 P P 1.2 51 U 0.01 4 li 2.91 PUP 2 57 t ~ 0.04 14 ~ 2.96 3 89 ~ ? 0.02 ~) 2.93 4 121 U 0.02 9 2.95 5 152 a 0.03 1 _t ~ 2.95 6 183 ~ ~ 0.03 I 1 2.95 7 214 U 0.03 12 ~ 2.94 8 246 a 0.03 12 `~> 2.92 9 277 U 0.04 14 1 2.95 10 309 l? 0.02 ') 2.96 11 340 i) 0.03 lU -3 2.94 12 372 ~) 0.03 1 ~ _' 2.94 13 403 U 0.03 13 ~1 2.95 14 435 l~ 0.02 i3 ~> 2.95 15 466 U 0.03 lU > 2.95 15.1 497 ~~ 0 U ~~ 2.88 Camc DS-Ni le 16 499 U 0.03 11 -! 2.92 17 531 ~ ~ 0.03 1 ? 2.9 1 562 a 0.02 is 2.94 19 593 ~ 1 0.03 1 1 ~ 2.94 20 625 ~l 0.01 G ~ 2.95 1 656 ~~ 0.02 ~ -! 9 22 688 ~~ 0.02 8 ~ 2.96 23 719 i~ 0.03 13 2.91 24 750 ~ ~ 0.04 14 •t 2.93 25 78 t~ 0.03 l:i k 2.93 26 813 ~ ~ 0.02 t3 2.92 27 845 O 0.02 ~~ 3 2.94 28 878 i ~ 0.02 ~ -1 2.92 29 909 U 0.03 11 ~ 2.93 30 940 t~ 0.02 ~) I 2.93 31 972 ~) 0.03 1(~ -t 2.95 32 1003 a 0.04 1' ~ 2.93 33 1035 U 0.02 ti 2.94 34 1066 ~~ 0.02 ') _' 2.93 35 1097 ~ ~ 0.03 1 U 2.94 36 1129 ti 0.02 ~~ _' 2.94 37 1160 ~~ 0.02 t3 I 2.94 38 1190 U 0.03 1:3 _' 2.93 39 1222 ~) 0.02 ~ 2.94 40 1253 (~ 0.01 t~ ~ 2.93 41 1285 U 0.03 1 ~; 2.94 42 1316 U 0.04 I -~ i 2.93 43 1348 U 0.03 1 Z ~' 2.94 44 1378 l~ 0.03 12 ? 2.94 45 1409 ~ ~ 0.02 ~~ 2 2.95 46 1441 ~ '~ 0.02 `) ' 2.94 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf N-80 Well: 1 R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 23, 2008 Joint No. Jt. Depth (Ft) I'~~n. 111~x~~ {Ins.) Pen. Body (Ins.) Pen. %~ ~tet,~l Ir~tis ,. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1472 t ~ 0.02 ~ 2.94 48 1504 a 0.03 1O ~ 2.93 49 1535 i ~ 0. 3 1 1 ; .95 50 1566 i ~ 0.03 11 ? 2.92 51 1598 U 0.03 1 Z ~' 2.9 52 162 9 U 0.02 ~) i ~ 2.94 53 1661 i ~ 0.03 I 1 2.92 54 1692 U 0.0 I ~ 2 93 55 1724 U 0.02 ') 2.94 56 1755 ! ~ 0.02 ~ -I 2.93 57 1786 t ~ 0.02 ~) 2.92 58 1818 a 0.03 II 2.93 59 1849 U 0.02 8 =4 2.91 60 1881 t ~ 0.03 I Z _' 2.95 61 1912 t ~ 0.02 ~ ~ 4 2.94 62 1943 t) 0.03 I I i 2.94 63 1975 U 0.01 (~ 2.94 64 2006 U 0.02 ~ 2.95 5 2038 a 0.03 1 Q ? 2.94 66 2069 a 0.02 ~~ 3 .93 67 2100 U 0.02 ti 2.94 68 132 t ~ 0.02 ~) ~ 2.9 69 2163 tt 0.02 ~) I 2.93 70 2195 t) 0.02 ~) _' 2.94 71 2226 ~~ 0.03 Iz -I 2.93 72 2257 ~ ~ 0.03 I ~' 1 2.94 73 2289 t~ 0.02 ~> t 2.94 74 2320 i) 0.02 9 ? 2.94 75 2 52 U 0.02 ~3 _' 2.94 76 2383 tl 0.02 ~~ -t 2.94 77 2415 t~ 0.03 l 2.93 78 2446 i t 0.02 9 .! 2.93 79 2478 ti 0.03 11 I 2.94 80 2509 a 0.03 1 U I 2.93 81 2538 ii 0.03 Iii -1 2.94 82 2569 a 0.02 ~~ 5 2.90 83 2600 a 0.03 11 ,' 2. 0 84 2632 (~ 0.02 5 2.94 85 2663 U 0.02 9 2 2.96 86 2694 a 0.02 i3 4 2.95 87 2726 U 0.02 7 4 2.93 88 2756 U 0.03 11 ~ 2.95 89 2787 t) 0.02 ~~ ; .94 90 2819 U 0.02 '~ 2 2.91 91 2850 t) 0.01 -1 ~ 2.94 92 2881 i) 0.02 7 2.94 93 2913 ~ ~ 0.02 ti 4 2.94 94 2943 t~ 0.02 7 ' 2.94 95 2974 U 0.03 It1 2.92 96 3006 t ~ 0.03 1 1 2.93 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf N-80 Well: 1 R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 23, 2008 Joint No. Jt. Depth (Ft.) I'i~n. UI,ti<•i Ilnti.) Pen. Body (Ins.) P~~n. ",6 ,~f~~~,~1 I ~~:~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3037 11 0.03 1 ; 2.94 98 3068 11 0.03 II 2.95 99 3099 ~) 0. 4 I £S I, 2.91 99.1 3131 ~~ 0.03 I1 I 2.89 PUP 99.2 3138 u 0 U ~) N A GLM 1 Latch @ 12:00 99.3 3146 ~~ 0.02 £i 1 2.90 PUP 100 3152 i ~ 0.02 £i ~ 1 2.95 101 3182 ~ ~ 0.04 1 i 3 2.92 102 3214 ~~ 0.02 '? _' 2.94 103 3246 a 0.01 ~~ I 2.94 104 3276 U 0.02 2.94 105 3307 ! ~ 0.03 1 t ~ 2.93 106 3340 t) 0.03 ! i ~, 2.93 107 3372 ~ ~ 0.03 I I 2.93 108 3404 ~ ~ 0.03 I I `~ 2.92 109 3435 t~ 0.02 ~) ~ 2.95 110 3467 n 0.02 i 1 2.94 111 3498 a 0.02 ~) 2.93 112 3527 a 0.02 7 U 2.94 113 3558 a 0.02 £3 I 2.93 114 3589 ~ ~ 0.03 1 1 5 2.93 115 3621 i ~ 0.03 1 U ~i 2.93 116 3652 ~? 0.03 1 U U 2.94 117 3683 t) 0.02 i (1 2.95 118 714 ~~ 0.02 7 _' 2. 3 119 3745 ~ ~ 0.03 12 -' 2.94 120 37 7 t~ 0.03 I U 2.93 121 3809 (i 0.02 £i ~ 2.94 122 3840 ~ ~ 0.02 £3 I 2.93 123 3871 a 0.02 ~~ I 2.94 124 3902 ~ ~ .03 13 -t 2.94 125 3933 i~ 0.02 8 ~~ 2.95 126 3964 U 0.02 8 -1 2.92 127 3995 !~ 0.04 14 2.94 128 4028 a 0.02 ti I 2.94 129 4058 ~~ 0.04 14 2.92 130 4090 (~ 0.02 ~) I 2.93 131 4122 ~~ 0.02 ~i 2.94 132 4153 ~ ~ 0.02 - 1 2.94 133 4184 ~ I 0.02 i Z 2.94 134 4215 U 0.02 9 ~ ~ 2.93 135 4246 11 0.02 8 i 2.94 136 4277 ~1 0.02 I 2.95 137 4309 ~~ 0.02 7 U 2.94 138 4340 ~ ~ 0.02 ~) I 2.95 139 4372 ~ ~ 0.03 1 ~' _' 2.93 140 4404 ~) 0.02 £3 I 2.94 141 443 5 ~ ~ 0.03 1 3 i 2.94 142 4466 l~ 0.02 8 2 2.95 143 4498 ~~ 0.02 9 ~' 2.95 Penetration Body u Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf N-80 Well: 1 R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 23, 2008 Joint No. Jt. Depth (Ft.) I'~•n. l)I~.e( (Ins.) Pen. Body (Ins.) Pen. % ~~1c~l,il I uss ".'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4529 O 0.02 ~) .9 145 4560 a .04 14 -1 2.91 146 45 0 O 0.03 10 1 2.91 147 4621 a 0.03 1 ~ 2.93 148 4653 a 0.04 14 2.92 149 4683 i ~ 0.02 t5 2.94 150 4714 t? 0.02 i 2.95 151 4746 O 0.04 1=t i ~ 2.92 152 4778 U 0 02 8 -I 2.93 153 4807 O 0.02 8 I 2.94 1 4 4838 a 0.03 10 I 2.9 155 4869 U 0.02 8 I 2.93 156 4900 ~) 0.02 8 I 2.93 57 4931 O 0.02 i ~ 2.93 158 49 2 u 0.03 1 u _' 2.93 159 4994 O 0.02 '-~ -1 2. 3 160 502 6 O 0.03 1 Z 2.91 161 5057 i) 0.02 t3 I 2.93 162 5087 a 0.02 ~~ 2.92 162.1 511 i) 0.02 ~ (~ 2.89 PUP 162.2 5127 O 0 t1 ~~ N A GLM 2 atch ®6:00 162.3 5134 a 0.02 t3 2.91 PUP 163 5140 i ~ 0.01 5 2.92 164 5171 n 0.02 ~~ 2.91 165 5203 (~ 0.0 8 2.94 166 5235 a 0.02 8 2.93 167 5 65 U 0.03 1U (t 2.93 168 5279 a 0.03 12 ~' 2.93 16 5330 ~) 0.02 7 I 2.93 170 5360 O 0.02 8 1 2.95 171 391 (t 0.03 1 Z ~' 2.92 172 542 3 (> 0.02 t3 2.91 173 5454 t) 0.05 1 ~3 ~' 2.93 174 5485 ~) 0.02 9 4 2.92 175 5517 0 0.02 8 ~' .91 176 5548 U 0.03 11 (; 2.88 177 5579 ~) 0.02 9 3 2.92 178 5612 ~) 0.02 ~) 2.94 179 56 3 1 ~ 0.02 8 I 2.93 180 5674 ~) 0.02 t3 1 2.93 181 5705 t) 0.02 -l .9 182 5736 tt 0.04 17 1 2.93 83 5767 ~) 0.02 8 _' 2.94 1 5799 O 0.02 7 (~ 2.93 185 5829 U 0.02 8 I 2.93 186 5861 U 0.02 7 1 2.93 187 589 O 0.03 11 t) 2.89 188 5923 ~ ~ 0.03 13 1 2.93 189 5954 ~ ~ 0.02 f 2.92 190 5985 0.02 2.93 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf N-80 Well: 1 R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 23, 2008 Joint No. )t. Depth (Ft.) I'c~n. l )I~u~l (Ins.) Pen. Body (Ins.) I'c~n. `ice Vlc~lal I oss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 191 6016 a 0.02 ~) I 2.93 192 6048 c) 0.02 7 2.93 193 6080 c) 0.02 ti I 2.94 194 111 l1 0.02 Fi -t 2.93 195 6140 t) 0.02 - 2.93 196 6172 t) 0.02 'i I 2.92 197 6205 n 0.02 rt I 2.93 198 6235 a 0.02 I 2.93 199 6 67 c) 0.02 ~) ~ 2.9 200 6298 a 0.03 I (1 ? 2.92 201 6329 U 0.04 1 7 ; 2 91 202 6360 a 0.02 I 2.94 203 6390 a 0.02 ti I 2.93 204 6421 a 0.03 I u _' 2.93 205 6452 t) 0.03 1 i _' 2.91 206 6484 a 0.02 ~) 2.94 207 6514 t) 0.04 1=1 1 .92 208 6545 O 0.03 I-i t~ .92 209 6577 i) 0.03 11 I 2.94 210 6608 U 0.02 ti _' 2.93 211 6640 I) 0.03 I t) I 2.95 211.1 66 1 i) 0.03 I U I 2.88 PUP 211.2 6677 t) 0 U t) N A GLM 3 La ch ~ 11:00 211.3 6686 t) 0.02 9 _' 2.89 PUP 21 669 ~) 0.0 £i I 2.93 213 6724 c) 0.04 17 2.92 214 6754 U 0.03 Li _' 2.91 215 6786 I) 0.03 1 ~ 1 2.91 216 6817 l) 0.02 ~) _' 2.91 217 6849 n 0.02 ~) I 2.91 218 6880 t ~ 0.03 I.3 I 2.92 219 6912 ll 0.02 ~) ~ ~ 2.91 220 6941 t) 0.03 11 I 2.92 221 6972 a 0.02 ~) i) 2.91 222 7004 i) 0.02 8 I 2.93 223 7036 i) 0.02 8 l) 2.93 224 7067 t) 0.03 11 I 2.92 225 7099 i) 0.02 7 1 2.93 226 7130 a 0.02 ~) i) 2.93 227 7161 t) 0.02 ~) i I 2.92 228 7192 U 0.03 I1 1 2.91 229 7224 U 0.03 1 U 1 2.91 230 7255 U 0.03 11 I 2.89 231 7287 i) 0.02 ti U 2.91 Lt De osits. 232 7318 i) 0.03 12 ~ 2.91 Lt. De osits. 233 7347 i ~ 0.02 ~) i) 2.92 234 7375 i~ 0.02 ti it 2.92 Lt. De osits. 235 7408 ~ ~ 0.03 I U i 2.92 Lt. De osits. 236 7439 0.04 I5 -t 2.92 237 7468 0.03 I ' ii 2.90 Lt. De osits. Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf N-80 Well: 1 R-14 Body Wall: 0254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 23, 2008 Joint No. Jt. Depth (Ft.) Pcn. Ill~~c~l fln,.j Pen. Body (Ins.) I'c~n. % 'vletal 1~7tiS ~~ Min. LD• (Ins.) Cornments Damage Profile (%wall) 0 50 100 238 7498 i? 0.02 ~~ _' 2.92 239 7531 c? 0.02 ~ n 2.91 240 7561 (t 0.03 I s 1 2.90 241 7594 U 0.02 ~ 2.91 L . De sits. 242 7627 O 0.02 9 2.93 243 7659 (? 0.02 9 u 2.94 244 7690 l) 0.02 £3 I 2.94 245 7722 (t 0.02 7 I 2.94 246 7752 U 0.03 1l) U 2.92 246.1 7779 O 0.00 1 U 2.92 PUP 246.2 7783 tt 0 U i) N A GLM 4 atch 11:0 246.3 7797 it 0.0 ti 2.91 PUP 247 7802 a 0.02 is I 2.93 248 7832 t? 0.02 ~t I 2.91 249 7864 a 0.03 I u _' 2.90 250 7895 t) 0.02 ') ? 2.91 251 7927 U 0.02 t3 I 2.93 252 7958 (? 0.04 1 ~ _' 2.91 253 7990 a 0.02 ti tt 2.92 254 8020 U 0.02 ') ~ .92 255 8051 tt 0.0 1~' 1 2.93 256 8083 U 0.02 £i 2.92 257 8113 a 0.02 9 I 2.92 258 8144 (1 0.03 11 ? 2.92 2 9 8175 U 0.0 1 291 260 8208 U 0.03 I tl i 2.88 261 8239 U 0.03 13 ~ 2.92 262 8270 t? 0.02 ~ I 2.93 263 8302 t? 0.03 I ~' I 2.92 264 8334 a 0.02 't I 2.91 265 8365 a 0.03 11 i, 2.93 266 8396 t? 0.03 1O ~1 2.90 267 8428 t) 0.03 13 I 2.91 268 8458 a 0.03 IO I 2.91 269 8488 U 0.03 t(1 4 2.90 2 70 8521 t ? 0.03 13 1 2.91 270.1 8552 U 0.02 ~) I 2.91 P P 270.2 8558 (t 0 u ~? N A GLM 5 Latch ~ 6:30 270.3 8566 (t 0.04 t-i ! 2.90 PUP Isolated ittin 271 8573 O 0.02 ti I 2.92 71.1 8603 t) 0.02 2.90 PUP 271.2 8608 t1 0 (? U 2.99 Baker 4" Seal 271.3 8622 U 0 U i? 3.00 PBR 271.4 8623 t? 0 U i? 3.00 Baker'FFiL' Packer 271.5 8625 U 0 O a 2.99 B ker G-2 Locator Sub 271.6 8626 u 0 O it 3.00 Baker 80-20 Seal Assembl 2 72 8631 t ? 0.02 ~ _' 2 90 272.1 8660 i? 0 0 ii N A GLM 6 Latch ~ 11:30 273 8669 U 0.03 11 i? 2.89 274 8701 (? 0.03 I ~ 2.90 _ Penetration Body Metal Loss Body Page 6 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf N~0 Well: 1 R-14 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 23, 2008 Joint No. )t. Depth (Ft.) I'~~n. Uln~~l (lnti.j Pen. Body (Ins.) Pc~n. °/, a1~~t,il I ~~~, ,. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 275 8732 ~~ 0.01 5 2.93 276 8762 11 0.02 f3 a 2.86 Lt. De osits. 276.1 8794 (~ 0 U ~~ 2.75 AVANT le AVATPCSIeeve 276.2 8796 t~ 0 O t~ 2.44 3.5" x 2.875" X-Over 276.3 8799 a 0.01 6 ~~ 2.35 PUP 277 8808 ~~ 0.01 U U 2 35 To of 2.875" Tubin ®Penetration Body Metal Loss Body Page 7 ~~ KUP ~ 1 R-14 Co110eoPhillip 5 ' `- weH Attributes ~ wegbare APW WI Reld rl.ne wag t:lalas trktlnatlon r) ko Irocs) total Depm pncel 500292138600 KUPARUK RIVER UNIT PROD 50.03 7,100.00 9,250.0 Comment SSSV:NIPPLE U+pral Date Oq W g elwse Dale 79 8!7/1965 150 7/12008 Last WO: 8/142003 3fi _ . Last Tag: 9,037.0 4/12008 Rev Reason: GLV C/O 9141'2008 Casin Strin s CONDUCTOR, Dadn9 Desralptlar OD ~) ~ M Tan (KKg) t;et Deem (gKe) Bet Depm ) d~e1 tNt ~~) Dade Top nre.d „e CONDUCTOR 16 15.063 0.0 115.0 115.0 62.50 HJO SURFACE 95/8 8.766 0.0 4,603.0 3,778.7 36.00 J-55 NIPPLE. 515 PRODUCTION 7 6. 56 0.0 ,229.0 6,961.8 26.00 J-55 Tubi 9trin s Gas L Ir , ~9 oesatptlan OD PM D Ihl r 1~1 Bet Depm (TVD) (tee tNt (baalq Grate lap !!read 3,lae TUBING 3 tl2 2.992 0.0 8,610.0 6, 07.5 9.30 L-80 8rdEUF1aBMOD TUBING Original 3 12 2.992 8.610.0 8.794.0 6.638.9 9.30 J-55 EUE 8RD suRFnce. a ti03 TUBING Original 2 7!8 2.441 8,797.0 8,&14.0 6,675.0 6.50 J-65 8RD EUE Other In Hole All Jewel :Tobin Run 8 Retrievab Fish etc. o carnnlert av ~ GAS LIFE. 5.133 515.0 NIPPLE CAMCO'DS' NIPPLE set 10/172003 8!142003 2.875 3,148.0 GAS LIFT CAMCOIMMC>J7.5/GLVIRK/.18&12791 Commend: STA 1 &3012008 2.920 GAS LIFT 5,133.0 GAS LIFT CAMCO/MMGI7.5tGLV/RK/.188I12761 Camnter,t STA 2 8/302008 2.920 . 6,681 6,681.0 GAS LJFT CAMCO MC~/1.5/OV/RK/.788// Comment STA3 &292008 2.920 7,793.0 GAS IJ CAMCO/MMGI7.5IDMY/RKI//Cormlent: STA4 10/162003 2.920 8.572.0 GAS IJF-f C O/MM(iI1.5JDMVIRK!/I Conrnem: STA 5 10/ 82003 2.920 Gns LIFT. ],193 8,610.0 PBR Baker 4.00"Seal 10/17/1985 3.000 8,623.0 PACKER Baker'FHL' PAACKER 10/17/1985 3.000 8.624.0 LOCATOR BAKER G22 LOCATOR SUB Ef 81742003 &142003 2.992 GAS uFr e s7i 8.625.0 SFJ1L BAKER 80-20 SEAL ASSEMBLY SET &142003 81742003 3.000 8.662.0 PROD ION MERWTMPLYI/DMY/BK//I Conxnent STAG 7232003 2.875 8.794.0 NIPPLE AVA NIPPL 70117/1985 2.750 PBR, a 6,0 8,794.0 SLEEVE-O AVA TPC 2.75' SLEEVE (NEW STYLE) set 4/CJ1008 415!2008 2.310 8,797.0 XO 3 12 8RD x 2 7/8 8RD 7112/1998 2.875 PACKER. 9.823 8,821.0 PACKER Baker'DB'wlSBE (325" seal diameter and 5'stroke) 10117/1985 4.750 LouTOa s sze 8,836.0 NIPPLE Car,roo'd Nipple NO GO 10!17/1985 2.250 , 8,844.0 SOS Cameo 10!17/1985 2.441 sEU.e.ezs 6,845.0 TTL Tuhi,g Tai 10117/1985 2.441 9,02 .0 FISH Grapple .367' Grapple, d,ased dotx,hole w1SV, urto,awn MD on 5/312003: gauped TBG ro 9025' 5!112006. 51312003 PROW CTION, e.66z 9.027.0 I H Metal Junk Chased Metal Junk Dowriale Past AVA RoAe: gauged TBG ro 9025' 5/112006. 167/1 3 9,029.0 FISH OV 1.5" OV LOST IN RATHOLE, gauged TBG ro 9025' 5/112006. 10232003 IPERF. 7 Per/Of>«lOnS 9.694 32 r avl Top ITV0) IeKel Ban (rVD) l~el eno 91st Der6 (+~-• ate orrennll NIPPLE, s,7s4 SLEEVEd, 8,694.0 8,732.0 6,567.4 8,594.5 IPERF C-1. 1R-14 12.0 10175/7985 120 deg. ph; 5" HJ II Csg Cam e.T94 8,912.0 8,920.0 6,724.4 6,730.3 IPERF A-4, 1 R-14 4.0 10/1511985 90 deg. ph; 4" HJ II Csg Gun xo, e.7aT 8.924.0 8,960.0 6,733.2 6.759.9 IPERF A-3, 1 R-14 4.0 10/15/1985 90 deg. ph; 4" HJ II Csg 9,032 0 9.040.0 6,813.2 6.819.2 IPERF A-2, 1R-14 4.0 10175/1985 90 deg. ph; 4" HJ II Csg Gun Notes: Gtaleral8 FiW Dale AteldatlM PAGI(FR, e 62, sls2oos r•1oTE: Warvered we. due ro IA x oA corrrrnrvcafion NIPPLE, 8.636 SOS, 8,804 TTL, 8,816 IPERF, 8.912-8.920 IPERF. 6.924 A.960 FISH. 9.025 FISH, 9.021 FISH, 9,029 IPERF, 9.0325.000 PROpUCitON, 9.229 Tp, 9,250 ~ 1 R-14 (PTD 185-151) failed a TI~ ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, August 04, 2008 10:10 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1 R-14 (PTD 185-151) failed a TIFL Attachments: 1 R-14 TIO.jpg; 1 R-14.tif Tom/Jim, :/ Kuparuk gas lifted producer 1 R-14(PTD 185-151) failed a TIFL on 08/03/08 and has been added to the Weekly SCP report. The TIO prior to the TIFL was 200/1275/900. A leaking GLV is sus ected so slickline will troubleshoot the leak and repair if possible. The well is currently on ine and will be repaired before 8/31/08 or SI. Attached is a 90 day TIO plot and schematic. «1 R-14 TIO.jpg» «1 R-14.tif» ./ Please contact me at your convenience if you have questions or comments. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~- ~~ 12/10/2009 KRU 1R-14 PTD 185-151 8/4/2008 TIO Pressures CHOKE FTP FTT IAP OAP Tf110 Plot -1 R-14 goo ~~~~ lzao ......... ............. 150 1000 ............................................................... '?ri'fess~ti~ ` 800 a .................................. .......................................................................... . a~ 100 x 600 -_~.--~~r~- ,~ .. _~ ~. J " .... ... ................ _ .t~ ............. ~, .... ;~ . ~ F 400 ................... ............. i ...........................................................................T¢.ry~ `t:' ~ n - - ~~ zoo .. ~. ........ ~~ .~`V`ti_ ...... ~~, _~~- ,..~_. : ~. 0 0 01-Jun-08 01-Jul-08 01-Aug-08 Date i • ~` ~~ KRU 1 R-14 f Go nc~c~Pt~iilips Al aska, nc. 1R-14 -- _ APL 500292138600 WeII T : PROD An le TS: 45 de 8615 ruelNC - -• SSSV T e: NIPPLE Ori Com letion: 8/7/1985 An le TD: 41 de 9250 (0-8610, OD 3 500 Annular Fluid: Last W/O: 8114/2003 Rev Reason: TAG, SET TPC : . , ID:2.992) F' LL Reference Lo : 27.15' RKB .Ref Lo Date: Last. U date: 4/13/2008 Last Ta : 9037 RKB TD: 9250 ftK6 Last Tag Date: 4/1!2008 Max Hole. Angle: 50 deg a~ 7100 _ _ °~~ . - - __ Casing String -ALL STRINGS ~ __ _ -- , Descri tion Size To Bottom TVD Wt Grade Thread ~~~ PROD. CASING 7.000 0 9229 6962 26:00 J-55 Tubing String -TUBING (New 3.5" TBG stung into PBR)_ _ _ _ ____ Size 1 o Bottom l V U 1Nt Grade Thread 3.500 0 8610 55G~ 9.30 L-80 8rdEUEABMOD PROD. CASING 3.500 8630 8794 66::9 9:30 J-55 EUE 8RD (0-9229, 2.875 8797 884 4 66__7_5_ _6.5_0_ J-55 8__RD EUE oD:7.oo0, Perforations Summar ___ _ _ . _ wr.2s.oo> Interval TVD ..- Zone _ - Status - Ft SPF - - - Date T e __.. - - Comment 8694 - 8732 6567 - 6595 C-1 38 12 1.0!15/1985 IPERF 1.20. deg. ph; 5" HJ II Csg `" ~ ~ Gtxn G " t 8912 - 8920 6724 - 6730 A-4 8 4 10/15!1 985 IPERF HJ II Csg ui 90 d h; 4 " 8924 - 8960 6733 - 6760 A-3 36 4 1.0115/198° IPERF HJ 11 Csg Gul 90 d h; 4 _-~ 9032 - °OQO 6873 -&819 A-2 - - $ - - 4 10/15/1980 IPERF 90 deg. ph; 4" HJ II Csg Gul Gas Lift Mandrels/Valves ~ ~ PBR (8610-6623, OD:3.500) PKR (8623-8624, OD;6.156) LOCATOR (8624-8625, OD:4.500) TUBING (8830-8794, OD:3.500, ID:2.992) Perf (8694-6732) SLEEVE-O (8794-8797, OD:2.750) NIP (8794-8797, OD:3.500) TUBING (6797-66aa, OD:2.875, ID:2.441) sos (8844-8845, OD:2.875) Pert (8912-8920) Perf (8924-8960) Grapple (9025-9026, OD:1.000} Metal Junk (9027-9028, OD:1.000) OV (9029-9030, OD:1.500) Perf (9032-9040) ^ 1. I r CONDUCTOR 16.000 0 115 115 62,50 H-40 SUR. CASING 9.625 0 4603 3780 36.00 J-55 St MD T'JD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3148 2757 CAMCO MMG GLV 1.5 RK 0.188 1300 6/5/2006 2 5133 4148 CAMCO MMG GLV 1.5 RK 0.188 1296 11/2/2006 3 6681 5228 CAMCO MMG OV 1.5 RK 0.250 0 1 11/2/2006 4 7793 5948 CAMCO MMG DMY 1.5 RK 0.000 0 10/16/200 5 8572 6481 CAMCO MMG DMY 1.5 RK Q000 0 10116!2003 Production Mandrels/Valves St MD lVD Man M6 Man Type V Mfr V Type I V OD Latch Port _ TRU Date Run Vlv Cmnt 6 8662 6545 Merla Other (plugs, equip., etc De th TVD T e TMPD DMY 1.0 BK 0.000 .) -JEWELRY _ Descri tion 0 )7/23/2003•_ ID 515 515 NIP CAMCO'DS' NIPPLE-set 10/17/2003 2.875 8610 6508 PBR __ Baker 4.00" Seal 3.000 _ 8623 6517 PKR _ Baker'FHL' 3:000 8624 6518 LOCATOR _ BAKER' G•22 LOCATOR SUB SET 8/14/2003 2.992 8625 6518 SEAL BAKER 80-20 SEAL ASSEMBLY SET 8/14/2003 3.000 8794 6639 NIP AVA NIPPLE 2.750 8794 6639 SLEEVE-O AVA TPC 2.75" SLEEVE fNEW STYLE} set 415/2008 2.310 8821 6658 PKR Baker'DB' w/SBE 3.25" seal diameter and 5' stroke 4.~~v 8836 6669 NIP Camco'D' Ni 1e N0 GO 2.250 8844 6675 SOS Camco 2.441 8845 6676 TTL Tubing Tail ___ 2-441 Fish -FISH De tit Descri lion j Comment 9025 Grapple 1.367" Grappls, chased downhole wlSV, unknown MD on 5/31/2003: au ed TBG to 9025' 511112006. 9027 Metal Junk Chased Metal Junk Downhole Past AVA Profile: gauged TBG to 9025' 5/1 //2006. 9029 OV General Notes Date Note 1.5" OV LOST IN RATHOLE, gauged TBG to 9025' 5/11/2006: 9/9!2006 NOTE: Waivered Well due to JA x OA communication 08/09/06 Scblumbel'ger RECEIVED NO. 3910 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth AUG 1 0 2006 h""'i...l"i'~~'¡ "UG . ''"r-r-,.... ,::r!...d\r";~~';!tJ.t 1\ .,'/ it ¿UUD Ä},~~ OH ,~Gas Cons. Commission ,A,n.chcrage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 l~'~- 15/ Field: Kuparuk Well Job # Log Description BL Color CD Date 1J-127 11216302 US IT 06/05/06 1 1 D-119 11249924 INJECTION PROFILE 07/05/06 1 2L-321 11235382 LDL 07/24/06 1 2V-13 11235385 SBHP SURVEY 07/26/06 1 1Q-13 11249936 INJECTION PROFILE 08/02/06 1 1 Q-26 11249937 PROD PROFILE W/DEFT 08/03/06 1 1R-14 11235386 PROD PROFILE WIDEFT 08/03/06 1 1G-09 11249938 INJECTION PROFILE 08/04/06 1 3N-16 11235389 SBHP SURVEY 08/05/06 1 1 E-112 11285935 MEM INJECTION PROFILE 08/05/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ConoCOPhillips Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 6, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1R-14 (APD # 185-151) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 R-14. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED ..-',' 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pedormed: Abandon E~ Suspend [] Operation Shutdown [~ Perforate r-'] Variance E~ Annular Disp. Alter Casing [~ Repair Well [--] Plug Perforations ~ Stimulate ~ Time E~ension Change Approved Program ~ Pull Tubing ~ Pedomte New Pool ~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ E~lorato~ ~ 185-151 / 3. Address: Stratigraphic ~ Sewice ~ 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21386-00 7. KB Elevation (fi): 9. Well Name and Number: RKB 82' 1 R-14 8. Prope~ Designation: 10. Field/Pool(s): ADL 25635, ALK 2568 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summa~: Total Depth measured 9250' feet true ve~ical 6978' feet Plugs (measured) Effective Depth measured 9099' feet Junk (measured) 8900' true ve~ical 6864' feet Casing Length Size MD ~D Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 4603' 9-5/8" 4603' 3780' PROD. CASING 9229' 7" 9229' 6962' RECEiVeD Pedoration depth: Measured depth: 8694'-8732', 8912'-8920', 8924'-8960', 9032'-9040' J~';'-""~':" I true ve~ical depth: 6567'-6595', 6724'-6730', 6733'-6760', 6813'-6819' Tubing (size, grade, and measured depth) 3.5"/2-7/8", L-80/J-55, 8794' / 8844' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' · BAKER 'DB' W/SBE (3.25" SEAL DIAMETER AND 5' STROKE) pkr= 8623' · 8821' no SSSV , 12. Stimulation or cement squeeze summa~: Intewals treated (measured) 8912' - 8928' Treatment descriptions including volumes used and final pressure: 95195~ of 16/20 proppant 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 569 471 109 - 185 Subsequent to operation 616 369 707 195 14. AEachments 15. Well Class after proposed work: Copies of Logs and Suweys run ~ Explorato~ ~ Development ~ Se~ice ~ Daily Repo~ of Well Operations _X 16. Well Status after proposed work: Oil~ Gas~ WAG~ GINJ~ WINJ ~ WDSPL~ 17. I hereby ce~ify that the foregoing is true and correct to the best of my knowledge. Sund~ Number or N/A if C.C. Exempt: Contact Mike Mooney ~ 263-4574 Printed Name Mike,Mooney Title Wells Group Team Leader / Signature ~,._ ~/~ ~hono Dato ~/~/c~ .~ Form 10-404 Revised 2/2003 · NOV : lll i SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. TUBING 0D:3.500, ID:2.992) PBR (8610-8623, 0D:3.500) PKR (8623-8624, 0D:6.156) SLEEVE (8794-8797, 0D:2.750) Pert (8912-8920) Peri (8924-8960) Perf (9032-9040) KRU 1R-14 1R-14 APl: 500292138600 SSSV Type: NIPPLE Annular Fluid: Reference Log: Last Tag: Last Tag Date: 27.15' RKB ~9099 10~23~2003 Casing String - ALL STRINGS Well Type: Orig Completion: Last WlO: Ref Log Date: TD: Max Hole Angle: PROD 81711985 Angle ~ TS: Angle @ TD: 45 deg @ 8615 41 deg @ 9250 811412003 Rev Reason: Tag, GLV design, Fish Last Update: 1012612003 t250 ffKB 50 deg @ 7100 Description CONDUCTOR Size Top 0 Bottom 16.000 115 SUR. CASING 9.625 0 4603 PROD. CASING 7.000 0 9229 I TVD I V~ 115 I 62. 3780 I 36 6962 126 TUbing String -TUBING (New 3.5" TBG stung into PBR) Size I Top Bottom TVD 3.500 I 0 8610 6508 3.500 8630 8794 6639 2.875 8797 8844 6675 Perforations Summary Interval TVD 8694-8732 6567-6595 8912-8920 6724-6730 8924-8960 6733-6760 9032-9040 6813-6819 Wt IGrade I 9.3o I L-80 I 9.30 I J-55 I 6.50 I J-55 I Gas Lift Mandrels/ValVes St~I MD I TVD I Man I Ma'n I v Mfr I V Type I V OD ]Latch I Po Mfr Type 2151331 41481CAMCO1 MMG I I GLV I 1'5 I RK I0.2 3 I 66811 s2281CAMCOI MMG I I GLV I 1.S IRK I 0.1~ 4177931 59481CAMCOI MMGI I GLV I 1'5 IRK I0'0' $ 185721 64811CAMCOIMMG I I OV I 1.5 IRK 10.0 ProduCtion Mand'relSlValves: · . .. . . ..... .... . :. It ]Grade I Thread soI e-40 I 00 I J-SSI 00 I J'55 I Thread 8rdEUEABMOD EUE 8RD 8RD EUE Zone]Status ]Ft SPF/ Date /TypeI Comment c.1 I 138 112 pO/lS1198q IPERF J120deg. ph;5"HdllCsg Gun Gun I I J I / / IGun t TRO' Date VIv ~ Run / ~ I~ ~0~2~00~ ~ 1~3~8 p~23~200~ "1 0 Fo~2~oo~ ~1 0 F0~2~200~ O l 0 ~0~23~200~ . .... Description Cmnt Vlv Cmnt Closed ID 2.875 CAMCO 'DS' NIPPLE set 10/17/2003 Baker 4.00" Seal 3.000 Baker 'FHL' 3.000 BAKER G-22 LOCATOR SUB SET 8114/2003 2.992 BAKER 80-20 SEAL ASSEMBLY SET 8114/2003 3.000 AVA NIPPLE 2.750 AVA TPI 2.75"x2.31" SET 812212003 2.310 112 8RD x 2 718 8RD 2.875 Baker 'DB' w/SBE (3.25" seal diameter and 5' stroke) NIP Camco 'D' Nipple NO GO SOS Camco TTL Tail 4.750 2.250 2.441 2.441 Depth '1 Description Comment 1.367" Grapple, chased downhole wlSV, exact depth known I 8900 IGrapple now 15/31/2003 8958 I Metal Junk I Chased Metal Junk Downhole Past AVA Profile 8980 I OV 11.5" OV LOST IN RATHOLE Date Comment 1R-14 Event History 07/31/03 08/15/03 08/16/03 08/18/03 08/19/03 08/20/03 08/21/03 08/22/03 08/23/03 10/1 O/O3 LOADED TBG & IA W/305 BBLS OF 9.6# BRINE. SWEPT WELLBORE @ 3.75 BPM WITH 320 BBLS OF SEAWATER THEN LOADED W/BRINE @ SAME RATE. CMIT TO 2000 PSI FOR 15 MINS AT THE END OF JOB, HELD GOOD. BLED BACK TO 1500 PSI PER PROCEDURE. [WORKOVER PREP] DISPLACED WORKOVER MUD FROM WELL. LEFT INHIBITED SEAWATER AND DIESEL CAP IN WELL. DRIFTED TBG TO 8500' WLM; FLUSHED 27' OF MUD OUT TBG TO CSG W/DIESEL; PULLED SOV @ 8554' RKB, JOB IN PROGRESS. [TAG, OTHER STIM] SET DV @ 8554' RKB. BAILED FILL FROM SV @ 8794' RKB. IN PROGRESS. [GLV] UNABLE TO PULL SV @ 8794' RKB. IN PROGRESS [FISH] RECOVERED 2.25" CAT SV FROM 8520' WLM , RECOVERED AVA 2.75" X 2.25" PNR, TAGGED FILL IN TBG @ 8698' WLM, HAVE SAMPLE OF FILL IN PROGRESS. [FISH] TAGGED FILL @ 8682' WLM BAILED EST. 3' (HARD FILL) SET .25" OV @ 8554' RKB, SET GLV'S @ 7775', 5114' RKB IN PROGRESS [OPEN-CLOSE C SAND] INSTALLED GAS LIFT VALVES @ 3130', 5114', 6662', RKB, FLOW WELL TO CLEAN MUD OUT, TOTAL BBLS 280, DRIFT TBG TO AVA NIPPLE @ 8794' RKB, SET TPI SLV @ 8794' RKB, PRESSURE TEST TBG 3500 PSI UNABLE TO BLOW OUT SOS, BEGIN BAILING FILL @ 8769' WLM IN PROGRESS. BALLED EST. 10' OF FILL, SHEARED S.O.S, PULLED 2.25" X 1.81" NIPPLE REDUCER FROM 8797' RKB, TAGGED FILL @ 9075' RKB EST. 35' RAT HOLE, COMPLETE [TAG] TAGGED @ 9077' RKB, EST 37' OF RATHOLE; PULLED GLV'S FROM 3148', 5133', 6681' & 7793' RKB, SET DV'S IN SAME; PULLED OV @ 8572' RKB & LEFT POCKET OPEN. IN PROGRESS. [FRAC-REFRAC] 10/11/03 10/12/03 10/13/03 10/14/03 10/15/03 ATTMEPTED TO PULL TPI DUE TO RESTRICTION, LOST TOOL STRING @ 8794' RKB, IN PROGRESS. [FRAC-REFRAC] ATTEMPTED TO FISH WIRE & TOOL STRING @ 8411' WLM, IN PROGRESS. [FISH, FRAC-REFRAC] DISPL FLOWLINE W/25 BBL DSL, 75 BBL DWN TBG, RECOVERED EST. 250' .108" WIRE, RECOVERED LOST TOOL STRING, IN PROGRESS. [FISH] DISPL TBG W/60 BBL DSL, RECOVERED EST. 30' OF .108" WIRE, PULLED 2.75" AVA SLV, SET 2.25" CA- 2 PLUG @ 8836' RKB IN PROGRESS [PERF] SET 2.75" TPI @ 8794' RKB. LOADED IA W/234 BBLS OF SEAWATER W/2000' DIESEL CAP. SET 1.5" DV @ 8572' RKB. PT TBG TO 3500 PSI W/1500 PSI ON IA, GOOD TEST. PT ON IA FAILED, SLOW ONE WAY LEAK FROM IA TO TBG. WILL RETURN IN A.M. TO CHASE LEAK. IN PROGRESS. 10/16/03 10/17/03 10/18/03 10/19/03 10/20/03 PULLED 1.5" DV @ 8572' RKB.WIRE MARKS ON VALVE INDICATE WIRE IN POCKET. CLEANED POCKET UP W/POCKET BRUSH. SET 1.5" DV @ 8572' RKB. PT TBG/IA TO 3500 PSI WAS GOOD. [GLV, FRAC- REFRAC] BAIL FILL FROM 8790' SLM TO 8803' SLM. PLUG IS SUSPECTED TO BE @ 8809' SLM. IN PROGRESS. BAIL FILL FROM 8802' SLM TO 8808' SLM. PULLED 2.25" A-2 EQ. PRONG & PLUG BODY @ 8836' RKB. TAG @ 9071' RKB, EST 31' OF RAT HOLE. [OPEN-CLOSE A SAND, TAG] PUMPED PRE-FRAC SAND PLUG. 3000' SAND IN 15 BBLS SLURRY, DISPLACED WITH 57 BBLSOF FRESH WATER AND 20 BBL DIESEL. TAGGED SAND PLUG @ 8901' WLM( 8928' ELM) WAS IN THE TARGET AREA. INJECTIVITY TEST OF .7 BBL/MIN @2200 PSI. PUMP FRACTURE TREATMENT USING 30# X-LINKED GEL. INITIAL PUMP RATE = 20 BPM, BUT DECREASED TO 12.5 BPM AT END OF JOB DUE TO MAXIMUM BURST LIMIT ON GLM. PUMP TOTAL OF 95,195# OF 16/20 CERAMIC PROPPANT, PLACING 8 PPA ON PERFS AND 94,053# PROP BEHIND PIPE. PUMPED 30 BBLS DIESEL DOWN WELL DURING FLUSH. RECOVERED ALL TREESAVER RUBBER. 1 O/22/O3 1 O/23/O3 CLEANED OUT WELL TO 9115' CTMD FREEZE PROTECTED TO 3000 WITH SLICK DIESEL [FCC] DRIFT & TAGGED FILL @ 9099' RKB EST. 57' RAT HOLE, INSTALLED OV @ 6678' RKB, GLV'S @ 5135', 3138' RKB. LOST IN RAT HOLE 1.5" OV, COMPLETE [GLV] Page I of 1 10/30/2003 ConocOPhillips Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 August 29, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1R-14 (APD # 185-151) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 R-14. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, . Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend [~] Operation Shutdown [] Perforate [] Variance [~ Annular Disp. [~ Alter Casing r-~ Repair Well [] Plug Perforations [--"] Stimulate r-'] Time Extension ~ Other [] Change Approved Program [] Pull Tubing C~] Perforate New Pool [--1 Re-enter Suspended Well r"-] 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r'~ Exploratory [~ 185-151 ! 3. Address: Stratigraphic [~ Service [~ 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21386-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 82' 1 R-14 8. Property Designation: 10. Field/Pool(s): ADL 25635, ALK 2568 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9250' feet true vertical 6978' feet Plugs (measured) Effective Depth measured 9075' feet Junk (measured) 8900' true vertical 6846' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUP. CASING 4603' 9-5/8" 4603' 3780' PROD. CASING 9229' 7" 9229' 6962' ,.~ , , Perforation depth: Measured depth: 8694'-8732', 8912'-8920', 8924'-8960', 9032'-9040' true vertical depth: 6567'-6595', 6724'-6730', 6733'-6760', 6813'-6819' Tubing (size, grade, and measured depth) 3.5"/2-7/8", L-80/J-55, 8610' / 8844' MD. ,.:' ,. =. ~., Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'DB' W/SBE (3.25" SEAL DIAMETER AND 5' STROKE) pkr= 8623' · 8821' no SSSV no SSSV 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,q Pressure Tubin,q Pressure Prior to well operation 308 114 22 191 Subsequent to operation 516 375 316 189 --,, 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory ~ Development r'~ Service r-~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[-~ Gas[~ WAG r-] GINJE~ WINJ r'-] WDsPLF-] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Mike Mooney @ 263-4574 Printed Name /~OO~~ Title Wells Group Team Leader ~/~¢//o ~ Signature , Phone Date --,, PrgpaF~d bY Sharqn AIl~uDrDrake 263-4612 Form 10-404 Revised 2/2003 · SUBMIT IN DUPLICATE ConocoPhillipS Alaska page 1 of 4 Operations Summary Report Legal Well Name: 1 R-14 Common Well Name: 1R-14 Spud Date: 7/29/1985 Event Name: WORKOVER/RECOMP Start: 8/8/2003 End: Contractor Name: Nabors3SCompanyM @conoco Rig Release: 8/14/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Date From-To Hours Code Code Phase DesCription of Operations 8/8/2003 00:00 - 05:00 5.00 MOVE RURD MOVE Released rig from 1A-28 @ 2400 hrs, 8/7/03. RD and prepare rig to move to 1R pad. Remove flow line. Prepare mast to scope down and lay down. Load DC into pipe shed for ballast. 05:00 - 13:30 8.50 MOVE RURD MOVE :Hydraulic oil spill on road between Spine Road and 1R pad and at 1R. Continue to RD and prepare to move while AP(3 and A(3S clean up spill. Disconnect and move pipe shed & pit modules away from rig. Scope down & lay down mast. Lower rig carrier to ground and move off well. Clean up area around well. 13:30 - 16:00 2.50 MOVE MOVE MOVE Spill cleanup complete. Move rig, pits, & pipe shed to 1R pad. 4.5 mile rig move. 16:00 - 20:00 4.00 MOVE RURD MOVE Spot BOPs behind well. Move rig over well to check alignment and centering. Pull off well. Set mats. Lay out Herculite around well and under back half of carrier. Lay Herculite under pit loading valves, fuel valves, and cuttings box. Move rig over well, jack up and level carrier. Spot pits and pipe shed. Install Hand-Y-Berm around lined area. Hook up lines. 20:00 - 00:00 4.00 MOVE RURD MOVE 2 hands continued rigging up lines, etc. on rig. 2 hands used forklift to offload trailer, cleaning oil off pallets and other items as offloaded. Swept and mopped up oily area at back of trailer. (Trailer to be sent to wash rack when unloaded and wiped down. Roads & pads will clean up oily gravel under trailer when it's sent to wash bay.) 8/9/2003 00:00 - 02:00 2.00 MOVE RURD MOVE RU lines. Take on fuel & water. Raise derrick & scope up derrick. Start RU circulating lines to well. Accept rig @ 0200 hrs, 8/9/03. Finished off loading & cleaning trailer. Trailer taken to wash rack. Roads & pads loader and end dump finished clean up of oily gravel under trailer. Hauled to 1H pit at 0200 hrs. (Trailer returned from wash bay, clean, at 0330.) 02:00 - 06:00 4.00 WELCTL NUND I DECOMP RU circulating lines to kill well. Hook up flowline. Prepare pits to take on kill mud. ;06:00- 06:30 0.50 WELCTL SFTY DECOMP Hold Pre-Spud meeting with new crew. Discussed current well condition and well killing operation, in particular, and overall objectives ;of the workover. 06:30 - 09:00 2.50 WELCTL NUND DE(3OMP 'RU lines to tree and annulus. Test lines & choke to 4000 psi. 09:00 - 10:30 1.50 WELCTL NUND DECOMP RU FM(3 lubricator and pull BPV. 10:30 - 11:00 0.50 WELCTL SFTY DE(3OMP PJSM. Discuss well killing procedure and fluid handling with Rig Crew, Tool Pusher, Company Man, MI Mud Man, and APC vac truck drivers. 11:00 - 13:00 2.00 WELCTL COND DECOMP Fill pit #2 with 12.8 ppg kill mud. Mix 35 Bbl Hi-vis spacer. Line up to circulate kill weight mud. 13:00 - 15:30 2.50 WELCTL CIR(3 DECOMP Choke panel not reading tubing or casing pressures properly. Flush thick mud out of sensing lines. 15:30 - 21:00 5.50 WELCTL KILL DECOMP Panel working OK. Tubing pressure reads good, casing pressure does not read well. Wil call out casing pressure from gauge on tree. SITP = 900 psi, SICP = 1000 psi. Start pumping spacer, taking returns through choke. Pump having trouble with thick fluid. Pump working at 45% efficiency. Monitor pump rate by pit strap. Circ 12.8 ppg mud down tubing at approx. 1 BPM, returns thru choke. Try to hold casing pressure constant at 1300 psi. Casing pressure went as high as 2500 psi. Brought small amount of gas back during circulation. At approx. 220 Bbls returned, started getting sea water for about 10 Bbls. Then brine started coming back again. With spacer near surface began to drop tubing pressure down to 700 psi to keep casing pressure from getting too high down hole. Circulate out spacer and until returns up to 12.6 ppg. Continue pumping kill weight mud, taking 12.6 ppg returns Printed: 8/28/2003 9:18:19 AM ConocoPhillips Alaska Page 2 of 4 Operations Summary Report Legal Well Name: 1R-14 Common Well Name: 1 R-14 Spud Date: 7/29/1985 Event Name: WORKOVER/RECOMP Start: 8/8/2003 End: Contractor Name: Nabors3SCompanyM@conoco Rig Release: 8/14/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase DescriPtion of Operations Date From- To Hours Code Code 8/9/2003 15:30 - 21:00 5.50 WELCTL KILL DECOMP :into pill pit. Shut down when pill pit nearly full (30 bbls) and suction pit down to 35 Bbls of 12.8 ppg mud. Shut down pump and trapped 200 psi on well. 21:00 - 23:30 2.50 WELCTL COND DECOMP Weight up mud in pill pit to 12.8 ppg. Offload contaminated mud/spacer/brine from rig pits to vac truck and rinse walls of pit to prevent contaminating good mud. Clean barite and thick mud out of suction screens while unloading junk fluids. 23:30 - 00:00 0.50 WELCTL KILL DECOMP Resume circulating 12.8 ppg mud into well, taking returns thru choke, 750 psi DP, 250 psi Annulus, returns 12.6 ppg. 8/10/2003 00:00 - 02:30 2.50 WELCTL (ILL DECOMP Continue circulating 12.8 ppg mud into well, taking returns thru choke holding 250 psi back pressure, 750 psi pump pressure (tubing). Return weight increased from 12.6 ppg to 12.8 ppg. Continued circulating one hole volume after getting 12.7 to 12.8 ppg returns to shear and condition mud in hole. Shut down pump. 02:30 - 03:30 1.00 WELCTL OBSV DECOMP Monitor well for 1 hour. Well dead. No flow. 03:30- 04:30 1.00: WELCTL NUND DECOMP Blowdown lines & RD. Set BPV. 04:30 - 07:00 2.50 WELCTL NUND DECOMP ND FMC Gen 3 tree and tubing head adapter. Adapter in good shape. Visible areas of tubing hanger also in good shape, redressable. Remove old studs from adapter to replace same. 07:00 - 07:30 0.50 WELCTL NUND DECOMP Lay tree behind rig. Winch tree around rig cellar and load out on forklift. Sending tree to shop for testing. 07:30 - 08:30 1.00 WELCTL NUND DECOMP Change out choke valves, HCR & manual from 3-1/8" to 2-1/16", 5000 ~si to match line sizes per AOGCC Field Inspector's request. 08:30 - 09:30 1.00 WELCTL NUND DECOMP PU 13-5/8" BOP stack out of cradle. 09:30 - 13:00 3.50 WELCTI. NUND DECOMP NU 7-1/16" X 13-5/8" DSA & BOPE. NU riser, choke line & kill line. 13:00 - 14:00 1.00 WELCTI. NUND DECOMP Install mousehole. Had to dig it back out, due to caving in, before setting mousehole. 14:00 - 15:30 1.50 WELCTL NUND DECOMP RU to test BOPE. Screw test joint into hanger. 15:30 - 22:00 6.50 WELCTL BOPE DECOMP Test variable bore pipe rams, annular, choke manifold, kill line to 250 ~si & 4000 psi (3500 psi on bag). Backed out test joint and blanking plug came with it. Reset blanking plug. Tested blinds to 250 psi & 4000 psi. Pull blanking plug. Witnessing of test waived by Chuck Scheve, AOGCC Field Inspector. 22:00 - 22:30 0.50 WELCTL BOPE DECOMP Check BPV for pressure, none. PU retrieving tool & pull BPV. 22:30- 00:00 1.50 FISH PULL DECOMP PU landing joint. MU into hanger. RU circulating lines. 8/11/2003 00:00 - 01:30 1;50 FISH FISH DECOMP Finish rigging up circulating lines. BOLDS. Pull 3-1/2" FMC Gen 3 hanger to floor, OK. Initial PU at 95K#. Seals pulled free at 105K#. Pulled seal assembly out of PBR with 78K#. 75K# PU weight after seals cleared PBR. 01:30 - 03:00 1.50 WELCTL ClRC DECOMP Circulate bottoms up, 165 SPM, 3 BPM, 800 psi. 12.8 ppg in & out throughout. RU control line spooling unit while circulating. 03:00 - 03:30 0.50 FISH SFTY DECOMP Hold Pre-Job Safety Meeting with Schlumberger spooling hand and rig ~crew on pulling tubing and control line. 03:30 - 04:30 1.00 FISH ClRC DECOMP Tubing coming wet. Mix & pump 30 bbl slug, 1.5 ppg heavier than mud. 04:30- 06:00 1.50 FISH PULL DECOMP LD LJ. LD tubing hanger. RU floor safety valve. RD DP elevators. RU tubing elevators. Sent tubing hanger to have J-55 pup removed and L-80 pup installed. ~06:00 - 11:45 5.75 FISH PULL DECOMP Start pulling 3-1/2" tubing & SS control line. Tubing is very tight. Having to hit collars to get connections to break. First 40 jts laid down hole fill was incorrect due to dry job. After 40 jts, hole fill as predicted. POOH to SSSV. LD SSSV and pups. Recovered 34 control line bands. Original tubing talley shows 32 bands run. Tubing is in good condition. Pins and box threads look good. Internal plastic coating is Printed: 8/28/2003 9:18:19 AM ConocoPhillips Alaska page 3 of 4 Operations Summary Report ,Legal Well Name: 1 R-14 Common Well Name: 1R-14 Spud Date: 7/29/1985 Event Name: WORKOVER/RECOMP Start: 8/8/2003 End: Contractor Name: Nabors3SCompanyM @conoco Rig Release: 8/14/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase DeScription of Operations Date From-To Hours Code Code 8/11/2003 06:00 - 11:45 5.75 FISH PULL DECOMP mostly in good condition. Some wireline damage and small pits in coating. No pits evident in metal on inside or outside of pipe. 11:45 - 12:00 0.25 WELCTL SFTY DECOMP BOP drill. Install TIW valve and simulate hard shut-in. 12:00 - 18:30 6.50 FISH PULL DECOMP POOH laying down tubing and GLM's. 133 joints & 2 GLM out. 18:30 - 20:30 2.00 FISH CIRC DECOMP Hole not taking proper fill. Circulate hole around to circulate out heavy slug and re-balance mud weight. Monitor well, static. Pump small slug. Seal assy/tail at about 4450' MD. 20:30 - 00:00 3.50 FISH PULL DECOMP POOH, LD 3-1/2" tubing & GLM's. 200 joints & 7 GLM's out at 2400 hrs. Tubing patch found in Joint #199, top about 6" below coupling, 22' long patch. Jt #199 is 3rd joint below GLM #7. Found a single corrosion hole at about the middle of the joint. Balance of joint looks good. Pipe pulled so far looks good. Connections are still tight. 8/12/2003 00:00 - 04:00 4.00 FISH PULL DECOMP Continue POOH LD 3-1/2" tubing & GLM's. Out of hole at 0400 hrs. 274 Joints, 1 SSSV, 12 GLM's, & Baker 4" OD seal assembly. Tubing looks good, except for Jt #199. It has a corrosion pit/hole about mid-joint, and an internal tubing patch. SSSV and GLM's look good, however, GLM's were gouged up by tongs due to breaking out very tight connections. Seal assembly looks good, likely redressable. 04:00- 05:30 1.50 FISH PULL DECOMP Clear GLM's off rig floor. Clean up floor. Monitor well, static. 05:30 - 07:00 1.50 FISH PULL DECOMP Unload old tubing from pipe shed. Will NORM test while unloading shed. 07:00 - 11:00 4.00 CMPLTN RUNT CMPLTN Continued NORM testing and unloading pipe shed 11:00 - 18:00 7.00 CMPLTN RUNT CMPLTN Started loading pipe shed with new tubing. Drift all joints w/2.91" poly rabbit. 18:00- 20:30 2.50 CMPLTN RUNT CMPLTN Rig up to run pipe 20:30- 00:00 3.50 CMPLTN RUNT CMPLTN Started RIH w/3.5",9.3#, L80 EUE 8 rd Mod completion. Ran 100 jts tubing and jewelry, approx. 3195'. 8/13/2003 00:00 - 03:00 3.00 CMPLTN RUNT CMPLTN Continued running tubing (160 jts) 5088'. 03:00- 04:00 1.00 CMPLTN CIRC CMPLTN Circulate bottoms up. 04:00 - 05:00 1.00 CMPLTN RUNT CMPLTN Continued running tubing 188 jts. 5981'. Discovered that the 'D' nipple was left out just above seal assembly. 05:00 - 08:00 3.00 CMPLTN PULD :CMPLTN Pulled 12 stands (doubles) out of hole - decided to leave nipple out of completion (nipple not required) 08:00 - 09:00 1.00 CMPLTN RUNT CMPLTN Back to where we were before discovering nipple was left out - begin running joints from pipe shed. 09:00 - 11:00 2.00 CMPLTN RUNT CMPLTN Galled 2.875" DS nipple and joint 257 - broke out nipple and bad joint - replaced with new nipple and joint 297 (same length) out of pipe shed - Lost no time 11:00 - 15:30 4.50 CMPLTN RUNT CMPLTN Completed running tubing - circulate above PBR 20 bbls - sting into PBR and bottom out 12' watching pressure increase - pull up 2' and mark pipe - pull out of PBR and space out pups below joint# 271. Landed tubing hanger and RILDS. 15:30 - 17:00 1.50 CMPLTN DEQT CMPLTN Rig up and test tubing for 15 minutes to 2300 psi - held solid. Bled back tubing to 1500 psi. Pressure up casing to 2400 psi for 15 minutes - held solid. Bled back tubing to zero psi and blew DCK shearout valve. 17:00 - 18:30 1.50 CMPLTN NUND CMPLTN Backed out landing joint, wash out stack and installed a BPV. Crew change. 18:30 - 20:30 2.00 CMPLTN NUND CMPLTN Nipple down BOP's and nipple up tree - prep for circulating out mud 20:30 - 22:30 2.00 CMPLTN SEQT CMPLTN Pull BPV and install test plug - test tree to 5000 psi for 15 minutes - test packoff to 5000 psi for 15 minutes - pulled test plug 22:30 - 00:00 1.50 CMPLTN OTHR CMPLTN Cleaning pits and rigging up to displace drilling mud with seawater. Printed: 8/28/2003 9:18:19 AM ConocoPhillips Alaska Page 4 of 4 Operations Summary Report Legal Well Name: 1 R-14 Common Well Name: 1 R-14 Spud Date: 7/29/1985 Event Name: WORKOVER/RECOMP Start: 8/8/2003 End: Contractor Name: Nabors3SCompanyM@conoco Rig Release: 8/14/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From- To Hours Code Code 8/14/2003 00:00 - 01:00 1.00 CMPLTN OTHR CMPLTN Rig up to displace 12.8ppg mud with seawater. 01:00 - 01:30 0.50 CMPLTN SFTY CMPLTN Pre-job safety meeting for displacement. 01:30 - 05:00 3.50 CMPLTN CIRC CMPLTN Started pumping down IA taking returns thru tubing. Starting pressure .900 psi @ 59 SPM, pumped 30 bbl spacer + 20 bbls seawater. Press continued to increase to 1500 psi. Slowed down pumping rate to 15 SPM and press continued to increase. 05:00- 07:00 2.00 CMPLTN CIRC CMPLTN Shut down, conferred with Eng. on plan forward. Mixed another 30 bbl spacer. 07:00 - 08:00 1.00 CMPLTN CIRC CMPLTN Pumped 30 bbl spacer and 10 bbl seawater down tubing taking returns thru IA. Shut down, installed BPV. 08:00 - 12:00 4.00 WELLSF PLGM CMPLTN Record shut-in pressures (1100 psi tubing - 100 psi 7" annulus) after pumping. Set BPV. Release rig. Clean pits. Begin move phase. Printed: 8/28/2003 9:18:19 AM GConocoPhillips Alaska, Inc. 1R-14 AP1:1500292138600 SSSV Type:I NIPPLE Annular Fluid:I Reference Log:127.15' RKB Last Tag:19075 Last Tag Date:J 8/23/2003 Casing Strin9 - ALL STRINGS KRU 1R-14 Well Type:I PROD Orig18/7/1985 Completion:I Last W/O:18/14/2003 Ref Log Date:I TD:19250 ftKB Max Hole Angle:IS0 deg (~ 7100 Angle L~ TS: 145 deg @ 8615 Angle @ TD:I41 deg @ 9250 I Rev Reason:IWORKOVER Last Update:18/27/2003 I TUBING (0-8610, 0D:3,500, ID:2.992) PBR (8610-8623. 0D:3,500) PKR (8623-8624, 0D:6.156) SLEEVE (8794-8797, 0D:2.750) Perf (8912-8920) Perf (8924-8960) Perf (9032-9040) Description CONDUCTOR Size Top Bottom TVD I Wt I Grade I Thread 16.000 0 115 115 162.501 H-40 I SUR. CASING 9.625 0 4603 3780 I 36.00} J-55 PROD. CASING 7.000 0 9229 6962 I 26.00 I Bottom TVD Wt IGrade I Thread 8610 6508 9.30 I L-80 I 8rdEUEABMOD 8794 6639 9.30 I J-55 I EUE8RD 8844 6675 6.50 I J-55 I 8RD EUE Interval TVDIZone I StatusI Ft ISPFIDate' /Type I Comment 8694-8732 6567-6595 I C-1 I 138112 110/15/1985~ IPERFI120deg'ph;S"HJIICsg I I III I 8912 - 8920 6724- 6730 A-4 8 4 10/15/198 IPERF 90 deg. ph; 4" HJ II Csg [ IIII IGun 8924 - 8960 6733 - 6760 A-3 36 4 10/15/198 IPERF 90 deg. ph; 4" HJ II Csg I 4 I 9032 - 9040 6813 - 6819 A-2 8 4 10/15/198 IPERF 90 deg. ph; 4" HO II Csg I I I I I / IGun Ga:~ Eift:Mahdrels/vaives ::: ::~: :: :: : ::. :::: :: :::: :: ::.::::: :: ::: : : St MD TVO I Man Man V Mf, IV Type I V OD I Latch Port I TRO Date Vlv ' ,"" ~"'?'1 "";"'"'~:":; "':":"' ' I "'"' ' ' ~ I '~;( ' ' '~''~ I '~? ":';;'7--,"' '.','7-i-7:':,':' .".',.: :i :: ','.':'.',':'~; ".'::',', ' : :?,_ : '7 .... I ~, i "-'"2i-' ' ;" .; .~] .... ~ '-'.": I- ....... " 'i' r.'..." ~"~"- ' ' ~'~7" i '.".!:. I'.,;'?-~.. :'. "' . ',. .... ." ............ ' ....... ·' . ,.,_-.]'.-;"' ~'"';":.'.:"I . ,,. I , -. '. '-__ ..--.' ....... I. · .....: .............. .' ....."..::.' :' .' :' :Production Mandrels/Valves St MD TVD ManI Man I'VMfr I VTYpe I VOD I'atchl Port I TROI Date ' Vlv Ufr TypeI I I Run I Cmnt 6186621 65451 MedaI TMPD I I DMY I1.0 I BK 10.0001 0 17'23'20031Clo80d - JEWELRY :: Description ID Baker 4.00" Seal 3.000 Tubing String - TUBING (New 3.5" TBG stung into PBR) Size Top 3.500 0 3.500 8630 2.875 8797 Perforations Summar~ Other (plugs; equip, etc. Depth JTVO I Type B6~o 1650~1 PBR 8623 I 6517 I PKR 8624 I 6518 I LOOATOR 8625 16518 1 SEAL 8794 16639 I SLEEVE 8794 16639 I NIP 8797 16641 I xo 8821 16658 1 PER 8836 166691 Nipple I I Reducer 8836 16669 I NIP 8844 166751 SOS 8845 I 6676 I TTL Baker 'FHL' 3.000 BAKER G-22 LOCATOR SUB SET 8/14/2003 2,992 BAKER 80-20 SEAL ASSEMBLY SET 8/14/2003 3.000 AVA TPI 2.75"x2,31" SET 8/22/2003 2.310 AVA NIPPLE 2,750 3 1/2 8RD x 2 7/8 8RD 2.875 Baker 'DB' w/SBE (3.25" seal diameter and 5' stroke) PETRODAT NIPPLE REDUCER w/CAMCO 'D' PROFILE SET 3/1/2003 4.750 1.810 Camco 'D' Nipple NO GO 2.250 Camco 2.441 Tubing Tail 2.441 FiSh" FISH.:.::..'..:: :.i:'. :.':. :...:..'; ':.~' ." '". ":. 'i .. ...... .'.::...'.:.'..'.'.. :..'" :'.'... '.';'. ;.: . · '.: .'. ' ' ..~ ..' ::'. i . '..?.'.~: "i.. Deptl~ ' '1 Description I Comment ' 8900 I Grapple 11.367" Grapple, chased downhole w/SV, exact depth now known I 15/31/2003 8958 I Metal Junk I Chased Metal Junk Downhole Past AVA Profile Gen'eral:NOtesi ".'.; :::..i.:.: 'i" :'..'.'.... '.:'.':.:... .... '. '.:.: :.'::.' :'.' .... : .' ;...: :' ':.'~: : :.~ Date lNote 11/29/200~HOLE IN TUBING BETWEEN 6185' & 6255' ALASKA OIL AND GAS CONSERVATION COMMISSION ! ] ,,, ,; ? ,,~ FRANK H. MURKOWSKI, GOVEFtNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 31, 2003 Mr. Mike Mooney Wells Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100630 Anchorage, AK 99510-0360 Re' Request for Variance of BOP Requirements at 20 AAC 25.285(c)(2)(B) KRU 1R-14 (185-151) KRU 2F-08 (184-021) Dear Mr. Mooney: Your request for Variance of BOP Requirements of 20 AAC 25.285(c)(2)(B) for the proposed workover operations on KRU wells 1R-14 and 2F-08 is approved. Specifically, you requested to employ 1 set of pipe rams while working over these wells in lieu of 2 sets of pipe rams on wells where the Maximum Anticipated Surface Pressure (MASP) requires a BOP stack rating equal to or greater than APl 5K. Employing a single set of pipe rams in conjunction with the fluid practices of 20 AAC 25.033 will provide an equally effective means of well control. A copy of this variance letter should be kept at the rig site. Please contact Tom Maunder at 793-1250 for further assistance. Sincerely, <::..:.... Sarah--P-alir>) Chair cc: Aras Worthington, CPAI NOTE TO FILE ConocoPhillips Alaska, Inc Variance Request for Single Ram Coverage KRU 1R-14 (185-151) KRU 2F-08 (184-021) ConocoPhillips Alaska, Inc. (CPAI) has made a letter application for a variance to the requirements at 20 AAC 25.285(c)(2)(B). CPAI is requesting to only employ 1 set of pipe rams rather than the required 2 sets required for operations requiring a BOP stack rated equal to or greater than APl 5K. This document analyzes CPAI's request and recommends approving it. CPAI is conducting a 21 well workover program in Kuparuk Field. According to the regulations, when the Maximum Anticipated Surface Pressure (MASP) requires a BOP stack rating equal to or greater than APl 5K, 2 sets of pipe rams must be employed [20 AAC 25.035(e)(3), 25.005(c)(4)(A) and 25.285(c)(2)(B)]. The reason for CPAI's request is only 2 of the 21 wells being worked over have calculated MASPs greater than 3000 psi and due to the nature of the production fluids it is highly unlikely that a full gas column could develop. Using the specifications of 25.005(c)(4)(A) the calculated MASP of 2F-08 is 3097 psi and of 1R-14 is 3625 psi. Since the fluid column in the well would be mostly liquid (water and oil initially), the hydrostatic weight of the column would depress the surface pressure to below 3000 psi. Prior to removing the wellhead assembly, CPAI would kill the well using fluid of sufficient density to overbalance the formation as required by 20 AAC 25.035. In addition, 1R-14 is equipped with a "standing valve", which is essentially a check valve, in the packer upper packer assembly. When sufficiently heavy fluid column is placed above the standing valve, it will close isolating the formation from the wellbore. 20 AAC 25.285(h) allows the Commission to approve a variance from the requirements of this section if the variance provides at least an equally effective means of ensuring well control. Employing a single set of pipe rams in conjunction with the fluid practices of 20 AAC 25.033 will provide an equally effective means of well control. I recommend approval of CPAI's request to employ 1 set of pipe rams while working over KRU wells 1R-14 and 2F-08. Tom Maunder, PE~ Sr. Petroleum Engineer July 30, 2003 Julj 29 03,03:54p ~ , WELLS GROUP ConocoPhillips SSS 7314 Aras Worthington 700 G Street Anchorage, AK 99501 Office Phone: 907-265-6802 Cell Phone: 907-240-5780 Sarah Palin Alaska Oil & Gas Conservation Commission 333 W,7th Ave, Suite 100 Anchorage, AK 99501 ConocoPhillips Alaska, Inc. will have a dedicated workover rig operating for approximately the next 3 months in the Kuparuk, Tarn, & West Sak Fields. Most of the planned workover wells have a BHP that, less a gas gradient to surface, are under 3000 psi Maximum Anticipated Surface Pressure (MASP). Two of these wells have a BHP high enough to push the MASP over 3000 psi: 1R-14; 4283 psi @ 6581' TVD; Form GOR: 200-600 2F-08; 3687 psi @ 5903' TVD; Form GOR: 2600-5800 ConocoPhillips Alaska, Inc. proposes that the requirement for four preventers (when 5M psi equipment is required) be waived for these two wells. Please note that 1R-14 is a well with a tbg leak above the top packer. There is a standing .valve set below the top packer. With the standing valve in place, the well CMITs to 3000 psi but will not pass a drawdown test. We plan to load the well with Kill-Weight fluid for the workover and do not anticipate having significant fluid losses due to the pressure-testing plug. The upper packer & standing valve will not be disturbed during the workover. 2F-08 has a packer that has apparently fallen downhole with no way to isolate the formation mechanically. We plan to load the well with Kill-Weight Fluid with contingency plans for pumping LCM if fluid losses are high. We plan to puJl the tbg, packer, and run a single completion with a packer. Both wells have relatively Iow Form. GORs so it should be noted that a gas gradient to surface is nigh to impossible (to result in a MASP of over 3000 psi). Please contact me ASAP should you have further questions or need more information. Thanks for your help in,this rgatter, Worthingt~'-n,~r,.,_ "' ...... Aras Rig-Workover Engineer ConocoPhillips Alaska, Inc. 265-6802 Office 240-5780 Cell 5u1:,'29 03 03:54p P~I WELLS GROUP Cono¢oPhillips Alaska ! Kuparuk W~lls Group Kuparuk, Alaska Intercompany Address: NSK 69 II 9~' 659 7314 p.1 Mailing'Address: P.O. Box 196105 '" Anchorage, AK 99519 FAX: 907-659.-7314 II II FAXSIMILE TRANSMISSION.. DATE: TIME: ._. FROM: SUBJECT: '~/~ /~,.~,',.~.~ ~,'.--' ..... PHONE: .... NUMBER OF PAGES: Cover LOCATION: ! ! Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: CONOCO/PHILLIPS ALASKA, INC. December 5, 2002 4904 1 3.5" 9.3 lb. EUE 8RD Tubing 2.875" 6.5 lb. EUE 8RD Tubing Tail Well: 1R-14 Field: Kuparuk State: Alaska APl No.' 50-02~7-01 Top Log Intvll.: Surface Bot. Log Intvll.: 8,797 Ft. (MD) Top Log Intvll.: 8,797 Ft. (MD) Bot. Log Intvll.: 8,812 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.5" tubing is in good condition with respect to corrosive damage. No significant wall penetrations are recorded. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate that the interval of 2.875" tubing tail logged is in good condition with respect to corrosive damage. No significant wall penetrations are recorded. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrat~a")'h'~t"h~ Body R'6~?i-Analysis Page of this report. (;;ANNED APR 3 5 2D03 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 19%) are recorded. 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) are recorded. 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. ProActive Diagnostic Services, Inc. / P.O. I~ox 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1.369 E-mail: PDS@memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-23::1.4 2.875" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 19%) am recorded. 2.875" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 4%) am recorded. 2.875" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. E;AINNEB APR 5 2003 Field Engineer: S. Adcock Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 774.97 Phone: (281) or (888) 565-9085 Fax: (281) 565-.1.369 E-mail: PDSCc~memorylog.com Prudhoe Bay Field Office Phone: (907') 659-2307 Fax: (907) 659-2314 Body Region Ana[ys s We]]: I R-14 Survey [)ate: l)ecember 5, 2002 Fkdd: Kuparuk Too] lype: MFC 24 No. 00387 Company: CONOCO/PltlLLIPS loo[ Size: 1~69 Country: USA No. of Fingers: 24 Analysi: M. Lawrence ~ ~ ]~ 93 ppf EUE 8RD 2.992 ins ~ 5 s 1 2 s 1.2 ins Penetration and Metal Loss (% wall) i N~mffmr c~ts anab~se~ (tota[= 282) i Damage Configuration ( body ) 64 108 0 0 0 Damage Profile (% walk) penetration body ~ metal loss bod 0 50 100 1 50 GLM 1 98 GLM 2 GLM 3 /48 GLM 4 GIM 5 GLM 6 GLM 7 GIM 8 GEM 9 GLM 10 GLM 11 GLM 1,2 Bottom of Survey - 279. Analysis Overview page 2 Body Region AnaLysis Well: 1R 14 Survey Date: Decembe~ 5, 2002 Field: Kuparuk [ool l~ype: MFC 24 No. 00387 Company: CONOCO/PHILLIPS [oo] Size: 1.69 Counb'y: USA No. oF Fh~gers: 24 AnaLyst: M. Lawrence Tubing: Norn. Ot) WeightGrade & [hr'ead Nora. ID Nom. Upsd Upper }on. Lowel len. 2.875 ]lis6.5 ppf t'UE 8RI) 2.441 ins 2.875 ins 1.2 iqs 1.2 ins Penetration and Metal Loss /% wall} 10 - Nu Iber ~fj'oin[s ~analygea. nora] ~ 2) Damage Profile (% wall) penetration body ~ metal bss body 0 50 100 0 , Damage Configuration , body } t3otk)m of Survey = 0.3 Analysis Overview page 2 PDS Multifinger CaIiper 3D Log Plot Company: Co~'iocolPhiMps Field: Kuparuk River Ul~it Well: i R~i4 Date: December 5~ 2002 Joint~98 Jointt99 Joint200 PDS R~RT, JOINT TABULATION SH Pipe: 3.5 ins 9.3 ppf EUE 8RD Well: 1R 14 Wall thickness: Body ~ 0.254 ins Upset = 0.254 ins Field: Kuparuk No ~a D: 2.992 ins Company: CONOCO/PI IILLIPS ~a penetration body Court,W: USA ~ metal loss body Su~x, ey Da~e: December 5, 2002 i No. Upsel Olher i Body [LossiCplng Body ID Comments % jinches j inches inches b 50 I00 2 0 0 2.9I Shallow Colrosion. 0 0 .00 2.9I Shallow Corrosion. 2 I 0 0 2.90 Shallow Corrosion. ~ 0 [ .05 t9 2 0 .01 2.94 [ Shallow pilling. 4 0 .03 2 0 0 2.94 i 5 0 .02 .00 2.96 6 0 i [ .03 10 ] 0 .00 2.92 i 7 i 0 .02 9 2 0 0 2.93 14 0 15 0 [6 0 17 0 0 19 0 20 0 2i o 22 0 23 0 24 0 25 0 26 0 27 0 28 0 29 0 31 0 .03 ] 10 .04 I 7 .04 .04 .04 .03 :03 .02 .03 I 2 .02 9 2 .03 2 .0t i 5 2 2 i 0 i0 .00 .00 .00 ,01 o ,01 0 .00 .00 0 0 .01 3 2 0 .03 1 0 .04 15 2 2.94 2.91 2.93 Shallow Corrosion. 2.90 Shallow Corrosion. 2.90 Shallow Corrosion. Lt. De 2.94 [ Shallow 2.94 2.93 Shallow Corrosion. 2.94 2.92 2.94 2.94 2.95 2.94 0 2.95 0 2.95 .0/ 2.92 [ Sl~a!!ow [ .01 2.95 i 0 2.95 l .00 2.95 iShallow 34 0 · 0 , .04 17 ~ 20 0 292 S a )wp g 38 0 i0 I .0313 i 2 I 0 0 0 i .03 3 ] 0 40 0 0 i .03 I i 0 41 0 0 i .02 2 j 0 42 0 0 2 0 43 0 0 .01 2 0 . 44 · 0 0 [ 2 0 45 0 0 .03l 0 J 2 0 i 46 o o . .o3] t(~ 2 o 47 0 0 .0311 2 0 0 i 2.92 00 ] 2.95 .01 2.94 .00 .0 t 2.90 2.95 0 2.96 .00 2.94 2.93 .00 2.95 pitting. Corrosion. 48 0 0 .01 34 0 .00 2.95 49 0 ) 04 5i 3 ) 2 89 l Sha ow CorFosion. Lt. Deposits. Pipe i abulations page / PDS RE JOINT TABULATION SHEE Pipe: 2.875 ins 6.5 ppi EUE 8RD Well: I R14 Wall thicklless: Body - 0.217 ins Upsel = 0.217 ins Field: Kuparuk Nominal tD: 2.441 ins Company: CONOCO/Pt IILLIPS ~ penetration body Countw: USA ~ metal loss body Survey Date: December 3, 2B02 joint Pene{~ation i~(~aJ~ i~]:&jection Minhmm~ [ ~Damage l'rofile No. Upset ()the~ [ Body [LossCph~g ~ody ID lC ~~e3ts (%wail) inches inches [ i~ches' inches inches ~ ir~ches 5B t00 Damage reporting thleshold - 30 thou irlches deviation in body, 5B ti~ou in coupling. Moda) )i~e lenglh = 0. I 77 feet. PDS RE~T JOINT TABULATION SI--IEE~ Pipe: 3.5 ills 9.3 ppf EUE 8RD Well: 1Rd4 Wall thickness: 8ody - 0.254 ins Upset = 0.254 ins Field: Kuparuk Nomina) ID: 2.992 ins Company: CONOCO/Pt tILLIPS Countll/: USA Sulvey Da~e: December 5, 2002 loh~ ~ ~enetiation )~eta~ Pro ection ~M~nimt rr j Damage No, Upset [ O~her Body ]oss jCpJng ~ody ID Comments ~ (% wail) j inches j inches j Jnches % jinches inches [ h~ches ~) 50 100 ~(~ 0 ~0 3 i 0 .00 2.92 ~Sha]]owCorrosicm. 52 0 i 0 i ,04 0 i 0 .00 2.91 iCorrosion. Lt. DeposiU. ~3 L 0 ~ 0 .04 o:~j 2:92 S~}[ow 54 ] 0 ~ 0 [ .04 t6 3 ~ 0i 2.90 Corrosion. Lt. Deposits. 55 0 [0 [ .03 12 .00 2.95 0 ] .03 0 2.93 57 i0 .04 ,00 2.91 ~Shallow Corrosion. lt. 57.1] [0 ] .03 13] 0 0 2.91 PUPShaiiow 57.2i [0 0 0 2.8~ SSSV 58 0 .04 ] ~ ] .00 ~: ~'~90 iShallowpiUin8 t~::)eposts 59 0 .03 13i 3 [ 2.92 Sba ow Corros on. 59,1 0 i ~ 0 O, 0 , O ~A iGLM 60 0 .04 [15 2 .01 2.90 6 I 0 .03[ 12 3 ] 0 2.90 ;hallow Corrosion. 62 0 .04[ 14 2 .01[ 2.90 Shallow ' ' 63 0 .0~ 13[ 2 0 ,01 2.89 Corrosion. penetration body metal loss body 68 0 0 .04 2 0 .00 orrosion. 0 0 .04 !!!? [Shallow Co,osion. 70 0 0 .04 .00 [ 2.91 i Shallow Corrosion. 71 0 0 2 k 0 i .01 2.91 on'osion. 72 0 I .0~ 10 2 0 5)0 2.92 73 0 [ 05 18 3 )t 2 88 i ShalIow 74 0 i .04 0 . )( 2 90 i Sba low Corros~cm. 75 (~. ~ ~ 0 .01 2.87 iC~r )son. 76 0 .03 3 0 .00 2.89 i Corrosion. 77 ~ ~0 0 .00 2.85 Shallow Corrosion. 78 0 0 )5 ~ 8[ 3 [ 0 [ .00 2.87 Shalk)wpittin~. ~ ~~ ~ .04 16[ 1 0 ~ .00[ 2.89 Shallow 80 0 .05 t8 O ~ 0 .01 2.88 [ Shallow 81 0 .03 13 3 0 i .01 hallow Corrosion. f2 ~ 0 0 .04 14 2 [ 0 .0t [ 2.88 ]Sha[low 83 0 .03 0 ~ 0 .00 2.89 Shallow Corrosion. 85 [ 0 .04 0 0 0 2.87 Con-osion. 86 (} .04 0 0 2.87 Shallow Corrosion. 87 0 .O3[ 1t i 2 i 0 0 2.88 88 0 0 .0313 3 0 .01 2.86 Corrosion. ~9 , 0 , .(4i 17 2 , ) .00 2.84 ~ . 0 , [ .04I I 7 [ 2 0 0 2.87 l Shallow 91 0 ~ .04 3 0 0 Shallow Con'osion. It. Deposits. 92 0 i .04 0 .00 2.85 93 0 [ .03 12 I 0 0 2.85 lsol4ied ~itting. 96 0 PD$ R~P,T IOINT TABULATION $HE~ Pipe: 3.5 ins 9.3 ppf LUE 8RD Well: 1R 14 Wall thickness: Body - 0.254 ins Upset - 0.254 ins Field: Kuparuk Nonlh/al tD: 2.992 ins Company: CONOCO/PHILI IP$ Countw: USA Survey Date: December 5, 2002 joint Penelralion ]M eIal Pro~ection ~Minimum ~ Damage Profile ]Loss]Cplng ~3odyII) Comments , (% wall) % ]inches inches inches 0 50 t00 0 ' .00 2.85 Shallow Corrosion. Lt. De 98 0 0 .04 15 2 0 [2.86 Shallow Corrosion. 99 () 0 [ .04 2 .01 2.86 Corrosion. LL De msits. 101 0 0 .03 132 .00 2.86 Corrosion. 103 0 i 0 .04 ISi 0 0 () 285 S a ow~ ~ t Deposts 0 106 0 107 0 .03 .03 11 3 .03 t3 0 i~t0.~ i 0 0 0 ] 0 jl~l i 0 0 .04 [ ~5 2 I 12 i 0 0 .04 1~4 o o .02 9 2 1 115 0 0 .04 lS 4 i .01 2.86 LL De 0 2.87 .00 2.86 i Shallow Corrosion. 0 2.87 J Corrosion. Lt. )osiu. ~00 2.88 .00 2.89 0 N/A iGLM 2 @9:00) .00 2.90 Shallow Corrosion. I.t. De .00 2.87 l Shallow Corrosion. 165 2.87 ~cgi:~o~io;; Lt, Deposits. .01 2.88 Shallow Corrosion. 0 124 0 125 0 [ 0 129 i 0 130 i 0 [ o 0 i136 137 0 .03I 1 0 .(')4 16 0 .04[ 14 .03 12 .04 14 .03 11 .03 /0 .04 .04 16 .04 .02[ 9 .04 14 2 i .o0 0 .01 3 .01 0 4 .00 2 .01 4 ) .0/ 2 0 4 j .01 0 .01 0 .01 2 .00 3 .00 2.86 jLt: )eposits. 2.87 [Shallow Corrosion. Lt. l)e 2.84 Shallow Corrosion, Lt. De 2.8s 2~90 Corrosion. 2.87 Shallow 2.87 2.88 i 2.88 J Corrosion. LL Deposils. 2.85 [EL De 2.87 ~la}]ow 2.85 Shal]ow Con osk~n. 2.86 2.87 [Shallow 144 0 0 .03 11 0 .01 2.87 R PDS ~RT JOINT TABULATION Skt~ Pipe: A5 ins 9.3 ppf EUE 8RD We]): I Rd4 Wall lhickness: Body = 0254 ]ns Upset = 0.254 ins Field: Kuparuk Nominal ID: 2.992 ins Company: C@NOCO/PI IILLIPS Countw: USA Su~¥ey Date: December 5, 2002 Joint j Petrie/ration ,~etal i ~roject o ~imum [Damage h-of e No. [Upset O~her Body loss C~lng i3ody tD Commen~s (% wa ) incb~ inc:hes inches % % inch(inchesinches h 50 145 0 0 1)4i 15 3 0 .01 2.89 5hallowCorrosion. , , ~ , ~ ~ .0~ !4 ] ~ [ 0 .00 2.87 orrosion. 0 0 .04 16 [ 2 0 .01 2.82 [Shallow Corrosion. 148 0 0 .01 Shallow Conosion. 149 0 0 .04 2 0 0 2.88 Con'osion. Lt. Deposits. 2.87 2,86 penetration bod' mela] }oss body 100 0 17 0 158 0 ( .04 17 3 0 0 .80 .00 2.85 jShallow 2.88 l Shallow Con'osion. 2.89 Shallow Corrosion. LL Deposits. '~ 0 04 i 14 i I [ B 0 2.87 iShaliow Conosiom 167.1 0 j O 171 0 0 Corrosion. Lt. l) 0 0 O 0 GtM 5 (latch@7:00 0 i .00 i 2.85 [Shallow Corrosion. 2 [ 0 .01 2.87 i 2.85 [Shallow Corrosion. 176 0 l) .03 10 2 0 .0Il 2.85 B ] 0 .ozite] 2 i5 ~ .B~j 2.87 180 0 0 181 0 0 181.1 0 0 182 0 0 183 0 0 ~84 [ o o 185 0 0 187 0 0 188 0 B 0 0 190 0 0 19 I 0 0 .03 .04 0 .03 12 .02 .03 10 .0 I .03 10 .03 10 .03 .B3 I I .02 8 0 .06 .00 0 0.00 0.O1 0.00 0.01 00 0,00 0.0 I 2.86 il t. Deposits. 2.87 Shallow pitting, Lt. Deposits. N/A [GLM (, 2.85 2.88 2.88 2.9B 2.86 2.87 2.86 Shallow 2 [ o _ OOl 288 , 3 i 0 i 'Ol l 2.90 3 ] 0 i .01 2.86 Shallow Con-osion. Pipe I'abulations page 4 PDS R~RT/OINT TABULATION SH~ Pipe: 3.5 ires 9.3 ppi EUE 8RD Well: tR14 Wail ti~ickness: 8ody - 0.254 ins Upset - 0.254 ins Field: Kuparuk Nominal ID: 2.992 ins Compally: CONOCO/PI Iii LiPS Counm/: USA Su~ev Date: December 5, 2002 ~ joim ' Penetration ~Metal Pr~ ectiot~ jMinimum ~ Damage Profile inchesinches ]inches inches ~ inches J inches 50 0 .02 3 [ 0 .012.87 0 0 .03 0 .012.87 194 0 0 .02 9 2 0 .002.9O 195 0 0 .04 2 O 2.87 Sba)low 196 0 0 .04 17 I ~ 0 2~86 ;Sha]low 196.1 0 0 0 0 0 [ 0 [ N~A GIM 7 (Law:h ~ 9:0( ~97 o o .03 198 0 0 0 0 ~ 2.87 l Shallow Corrosions. 199 O 0 .02 0 .00 2.89 200 0 0 .03 I3 3 0 .00 2.89 ] Shallow o i © . ?~ ~o; ~ ' o .oo ~.~ 2o~ o ~o .o'l .~ ~ ~ .o~ ~.~ 203 0 0 .03 0 .00 2.87 ~ Lt Deposits. 204 0 0 .0i 2 ~ O 0 2.91 2,83 Corrosion. 1L l)eposils. 2.87 .03 [ 3 ] 0 .00 2.87 10 2 ] 0 .00 2.87 210 i 0 0 .03 1 0 0 2.91 Corrosion. 210.t 0 O 0 0 0 0 ~GLM 8 211 O 0 .03 1 0 0 2.87 Lt. Deposits. 2.89 212 .0 . 0 , .04 6 4 · 0 0 2 I ) 214 215 217 218 0 219 0 [223 0 224 0 0 O .03 3 0 0 .01 3 0 0 .02 9 2 O 0 .03 3 0 0 .03 3 0 .02 2 O .02 8 2 0 .03 13 2 0 .03 11 3 226.1 O 228 0 0 0 O 232 0 0 )3 ] 11 233 0 0 [ .O4 0 0 .0416 ] O .03 2 0 .0415 2 0 0 .03[ 11 2 2 2 237 O 0 .04 0 0 .04 .01 2.88 .00 2.88 .01 2.86 .0t2.87 ~ .0O] 2.85 [Shallow pit~ing. Lt. Deposits. .002.87 I .00 .01 0 0 .00 0 0 0 .00 .00 2.87 j Sha!k)w pi~!!!2~ 2.85 2.85 Shallow Co~!'osio~. l N/A GLM 9 (Latch@9:~0) 2.86 Shallow Corrosion. Lt. Deposits, 2.88 2.8S Sha}}ow Corrob]on. Z86 Shallow Corrosion. 2.87 2.86 2.87 .01 2.86 Shallow Corrosion. 2.86 S a OW Corrosio!l. gr. Deposits, ,00 2.84 0 2.88 Shallow CoFrosio~l. 0 2.86 Sba[low Corros[oa. penetration body metal loss body 100 Pipe ] abu]ations page 5 PDS R~RT JOINT TABULATION SH Pipe: 3.5 ins 9.3 pp( EUE 8RI) Well: tR 14 Wall thickness: Body = 0.254 ins Upset = 0.254 ins Field: Kuparuk Nonfina] I1): 2.992 ins Company: CONOCO/PI tll I IPS Count~: USA Survey Da~e: December 5, 2B02 [ joint r Per~eb-afion 'Metal ' Proiection Minimum JDamage Profile ] No. Upse~ j Oth~'r Body ~ CpHg j~ody [ID C ............ ts (%wall) inches inches ]inches inches [inches j inches ~) 5B 241 242 0 0 0 0 0 0 0 0 0 0 .02 9 .03 1 t [3 0 0 .03 3 246 0 0 .04 247 0 0 .03 248 0 0 .02 0 0 250 B 0 .04 5~i ' o [ ~i .02 255 ~53 ~ o 254 0 '258 £) 0 256 0 0 257 0 0 0 0 258 0 0 2? o , o 260 0 0 0 0 262 0 0 263 0 0 264 0 0 265 0 0 266 0 0 269 0 0 27O 0 0 0 i274.1 274.2 275 i275.~ 276 277 278 2 0 16 0 0 0 0 9 2 0 14 3 0 14 0 B 2 t) t 0 0 i .01 0 i 0 0 .00 2.85 2.85 ] Lt. Deposits. 10 (Latch @ 8:30) 2.87 .BO 2.87 i Shallow Corrosion. .01 .00 ] 2,88 Sha}bw Corrosion. [) 2.86 i .00 ) .00 2.87 S!la]]ow Corrosion. 0[ 2.87 Shai]ow Corrosion. 0i 2.86 0[ 2.84 Sha)bw Corrosion. Lt. l)e .03I 1 0 .03[ 3 0 .0313 2 0 0 0 0 0 .0414 2 0 .03 I 0 .03I 3 0 0 .03I3 .03 0 .03 0 0 .02 1 0 .0313 2 .03 2 3 3 .04 0 .B4 3 .04 0 0 0 .() I 0 0 0 0 0 0 0 0 0 0 0 0 0 .t) O 0 0 2.86 2.84 JEt. [De 2.82 Shallow Corrosion. Lt. Deposits. 2.87 Shallow Corrosion, Lt Deposits. 2.86 2.85 l Sh dlow Co 'ros o 2.86 corrosion. 2.87 2.86 Shallow 2.85 2.86 2.84 2.85 2.86 0 0 2.~73 Sba]low pi ing 0 0 2.84 0 0 2.85 Shallow Corrosion. .04 14 i 0 .B3 i:~' 5 B 0 i0 o o io i0 o 0 0 .B2 0 0 B 0 0 .04 l 7 0 0 .0 / 0 0 .()3 0 0 0 0 0 0 B B 0 4 0 0 2.88 corrosion. .00 2.90 [Shallow Corrosion. I t. DeposiU. 0 N/A [(]EM 12 6:30) .Of 2185 0 [ PBR 0 [PACKER 0 2.87 0 N/A J Production Mandrel 0 2.86 ] Shallow .00 2.88 penetradon body metal loss body Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 1 * pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line length = 0.265 feet. Pipe Tabulations 7 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness: Body-- 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID tD OD feet feet inches inches inches inches I 29.01 31,60 2.989 2.986 2.992 3.500 1.1 60.61 7.64 2.965 2.964 2.992 3.500 2 68.25 30.63 2.972 2.969 2.992 3.500 3 98.88 31.80 3.008 3.006 2.992 3.500 4 130.68 31.47 2.992 2.991 2.992 3.500 5 162.15 31.78 3.005 3.005 2.992 3.500 6 193.93 27.85 3.002 3.000 2.992 3.500 221.78 31.05 2.996 2.994 2.992 3.500 7 8 252.83 32.26 3.013 3.012 2.992 3.500 9 285.09 31.31 3.001 3.000 2.992 3.500 10 316.40 32.24 2.969 2.967 2.992 3.500 11 348.64 29.85 2.997 2.996 2.992 3.500 12 378.49 32.13 2.984 2.981 2.992 3.500 13 410.62 32.04 3.003 3.001 2.992 [ 3.500 14 442.66 31.71 2.996 2.995 2.992 3.500 15 474.37 32.05 2.992 2.990 2.992 3.500 16 506.42 29.92 2.992 2.994 2.992 3.500 17 536.34 29.74 2.983 2.980 2.992 3.500 18 566.08 28.24 3.009 3.006 2.992 3.500 19 594.32 32.26 3.022 3.017 2.992 3.500 20 [ 626.58 31.56 3.020 3.020 2.992 3.500 21 658.14 29.66 2.990 2.987 2.992 3.500 22 687.80 32.23 2.995 2.995 2.992 3.500 23 720.03 32.15 3.017 3.012 2.992 3.500 24 752.18 31.68 3.000 2.999 2.992 3.500 25 783.86 31.53 3.007 3.007 2.992 3.500 26 815.39 31.95 2.999 2.998 2.992 3.500 27 847.34 31.78 3.001 2.999 2.992 3.500 28 879.12 32.05 3.006 3.005 2.992 3.500 29 911.1731.733.0063.0052.9923.500 30 942.9032.123.0123.0072.9923.500 31 975.0231.873.0103.0082.9923.500 32 1006.89 31.25 3.024 3.019 ' 2.992 3.500 33 1038.14 32.00 3.029 3.028I 2.992t 3.500 341070.1428.693.0093.0062.9923.500 Well: Field: Company: Country: Survey Date: 1R-14 Kuparuk CONOCO/PHILLIPS USA December 5, 2002 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 35 1098.83 31.60 3.013 3.010 2.992 3.500 36 1130.43 31.15 3.001 2.999 2.992 3.500 37 1161.58 31.98 2.998 2.997 2.992 3.500 38 1193.56 31.48 2.984 2.981 2.992 3.500 39 1225.04 27.95 3.022 3.020 2.992 3.500 40 1252.99 30.93 3.021 3.019 2.992 3.500 41 1283.92 31.68 3.018 3.017 2.992 3.500 42 1315.60 30.88 2.986 2.984 2.992 3.500 43 1346.48 31.69 3.003 3.001 2.992 3.500 44 1378.17 31.92 3.004 3.003 2.992 3.500 45 1410.09 31.52 3.000 2.998 2.992 3.500 46 1441.61 31.97 3.008 3.006 2.992 3.500 47 1473.58 31.17 3.029 3.028 2.992 3.500 48 1504.75 31.55 3.004 3.006 2.992 3.500 49 1536.30 31.78 2.971 2.969 2.992 3.500 50 1568.08 31.26 2.992 2.992 2.992 3.500 51 1599.34 28.08 2.989 2.989 2.992 3.500 52 1627.42 31.76 2.971 2.973 2.992 3.500 53 1659.18 31.10 2.985 2.984 2.992 3.500 54 1690.28 28.25 2.974 2.972 2.992 3.500 55 1718.53 31.70 2.977 2.975 2.992 3.500 56 1750.23 31.25 3.003 3.002 2.992 3.500 57 1781.48 31.12 2.989 2.987 2.992 3.500 57.1 1812.60 6.43 3.016 3.017 2.992 3.500 ~up 57.2 1819.03 13.25 2.813 2.813 2.813 3.500 ,sv 58 1832.28 31.86 2.979 2.978 2.992 3.500 59 1864.14 30.83 2.982 2.979 2.992 3.500 59.1 1894.97 6.64 N/A N/A 2.992 3.500 Im 60 1901.61 31.51 2.985 2.983 2.992 3.500 61 1933.12 31.34 2.976 2.974 2.992 3.500 62 1964.46 29.80 2.974 2.971 2.992 3.500 63 1994.26 31.53 2.975 2.971 2.992 3.500 64 2025.79 31.37 2.971 2.969 2.992 3.500 65 2057.16 31.10 2.990 2.986 2.992 3.500 66 2088.26 31.93 2.978 2.977 2.992 3.500 SOANNE _) APR g g Joint Tally page 1 PDS REPORT JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf EUE 8RD Wall thickness: Body: 04217 ins Upset -- 0.217 ins Nominal ID: 2.441 ins Joint Depth Length Modal Mean Nominal Nominal [Type No. ID ID ID OD feet feet inches inches inches inches .1 8797.33 - 7.63 2.486 2.489 2.441 2.875 ~up .2 8804.96 4°95 2.402 2.399 2.441 2.875 ~up .3 8809.91 N/A N/A N/A 2.441 2.875 [c,acker Well: 1 R-14 Field: Kuparuk Company: CONOCO/PHILLIPS Country: USA Survey Date: December 5, 2002 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches Joint Tally page 1 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness: Body = 0.254 ins Upset-- 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 67 2120.19 30.67 2.972 2.971 2.992 3.500 68 2150.86 30.15 2.975 2.973 2.992 3.500 69 2181.01 30.15 2.966 2.963 2.992 3.500 70 2211.16 29.54 2.965 2.965 2.992 3.500 71 2240.70 31.09 2.973 2.971 2.992 3.500 72 2271.79 30.68 2.989 2.986 2.992 3.500 73 2302.47 31.56 2.967 2.965 2.992 3.500 74 2334.03 29.05 2.969 2.966 2.992 3.500 75 2363.08 30.53 2.950 2.946 2.992 3.500 76 2393.61 28.41 2.955 2.954 2.992 3.500 77 2422.02 28.50 2.942 2.940 2.992 3.500 78 2450.52 25.19 2.940 2.938 2.992 3.500 79 2475.71 34.23 2.961 2.957 2.992 3.500 80 2509.94 31.50 2.966 2.962 2.992 3.500 81 2541.44 31.30 2.963 2.961 2.992 3.500 82 2572.74 31.19 2.957 2.955 2.992 3.500 83 2603.93 29.36 2.959 2.957 2.992 3.500 84 2633.29 31.13 2.960 2.957 2.992 3.500 85 2664.42 28.30 2.932 2.930 2.992 3.500 86 2692.72 31.50 2.955 2.953 2.992 3.500 87 2724.22 28.17 2.956 2.952 2.992 3.500 88 2 752.39 31.65 2.950 2.945 2.992 3.500 89 2 784.04 29.02 2.940 2.939 2.992 3.500 90 2813.06 30.96 2.962 2.957 2.992 3.500 91 2844.02 31.98 2.946 2.942 2.992 3.500 92 2876.00 29.45 2.955 2.951 2.992 3.500 93 2905.45 31.44 2.946 2.944 2.992 3.500 94 2936.89 31.64 2.945 2.943 2.992 3.500 95 2968.53 28.75 2.943 2.943 2.992 3.500 96 2997.28 31.43 2.956 2.953 2.992 3.500 97 3028.71 30.95 2.956 2.951 2.992 3.500 2.929 2.927 2.992 I 3.500 98 3059.66 31.82 99 ] 3091.48 30.50 2.944 2.941 2.992 3.500 100 ] 3121.98 30.13 2.951 2.946 2.992 3.500 101I 3152.11 31.20 2.954 2.951 2.992 3.500 Well: 1 R-14 Field: Kuparuk Company: CONOCO/PHILLI PS Country: USA Survey Date: December 5, 2002 Joint Depth ILength Modal Mean Nominal Nominal Type No.I ID ID ID OD feet I feet inches inches inches inches 102 3183.31 31.79 2.942 2.937 2.992 3.500 103 3215.10 30.70 2.954 2.952 2.992 3.500 104 3245.80 30.40 2.948 2.944 2.992 3.500 105 3276.20 31.69 2.954 2.953 2.992 3.500 106 3307.89 32.23 2.960 2.953 2.992 3.500 107 3340.12 27.76 2.952 2.948 2.992 3.500 108 3367.88 30.79 2.951 2.949 2.992 3.500 109 3398.67 31.62 2.976 2.970 2.992 3.500 110 3430.29 31.23 2.972 2.969 2.992 3.500 110.1 3461.52 7.14 N/A N/A 2.992 3.500 Im 111 3468.66 28.02 2.949 2.947 2.992 3.500 1t2 3496.68 28.81 2.948 2.946 2.992 3.500 113 3525.49 31.64 2.947 2.943 2.992 3.500 114 3557.13 30.73 2.938 2.934 2.992 3.500 115 3587.86 31.35 2.957 2.953 2.992 3.500 1 t6 3619.21 30.91 2.945 2.942 2.992 3.500 117 3650.12 31.83 2.947 2.945 2.992 3.500 118 3681.95 30.93 2.937 2.933 2.992 3.500 119 3712.88 31.38 2.945 2.942 2.992 3.500 120 3744.26 31.43 2.963 2.960 2.992 3.500 121 3775.69 28.92 2.958 2.955 2.992 3.500 122 3804.61 30.25 2.969 2.964 2.992 3.500 123 3834.86 31.35 2.953 2.948 2.992 3.500 124 3866.21 28.96 2.943 2.940 2.992 3.500 125 3895.17 31.60 2.944 2.939 2.992 3.500 126 3926.77 31.27 2.966 2.961 2.992 3.500 127 3958.04 30.87 2.941 2.937 2.992 3.500 128 3988.91 30.85 2.959 2.956 2.992 3.500 129 4019.76 30.58 2.961 2.956 2.992 3.500 130 4050.34 31.60 2.948 2.946 2.992 3.500 131 4081.94 31.91 2.957 2.953 2.992 3.500 132 4113.85 29.22 2.955 2.953 2.992 3.500 133 4143.07 29.82 2.961 2.954 2.992 3.500 134 4172.89 31.92 2.953 2.950 2.992 3.500 135 4204.81 31.16 2.950 2.948 2.992 3.500 Joint Tally page 2 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness: Body-- 0.254 ins Upset -- 0,254 ins Nominal ID: 2.992 ins Joint Depth Length i Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 136 4235.97 31.26 2.947 2.943 2.992 3.500 137 4267.23 30.30 2,938 2.935 2.992 3.500 138 4297.53 30.58 2.946 2.942 2.992 3.500 138.1 4328.11 6.31 N/A N/A 2.992 3.500 ]m 139 4334.42 30.57 2.961 2.958 2.992 3.500 140 4364.99 31.64 2.944 2.940 2.992 3.500 141 4396.63 32.04 2.956 2.953 2.992 3.500 t42 4428.67 29.68 2.958 2.955 2.992 3.500 143 4458.35 29.82 2.947 2.944 2.992 3.500 144 4488.17 32.59 2.943 2.940 2.992 3.500 145 4520.76 31.08 2.952 2.950 2.992 3.500 146 4551.84 28.67 2.928 2.928 2.992 3.500 147 4580.51 31.68 2.943 2.941 2.992 3.500 148 4612.19 30.92 2.949 2.945 2.992 3.500 149 4643.11 30.40 2.953 2.949 2.992 3.500 150 4673.51 30.64 2.955 2.951 2.992 3.500 151 4704.15 31.82 2.953 2.948 2.992 3.500 152 4735.97 30.43 2.950 2.945 2.992 3.500 i52.1 4766.40 6.63 N/A N/A 2.992 3.500 lm i 53 4773.03 32.93 2.936 2.928 2.992 3.500 154 4805.96 30.59 2.944 2.941 2,992 3.500 155 4836.55 31.21 2.947 2.944 2.992 3.500 156 4867.76 32.14 2.942 2.938 2.992 3.500 157 4899.90 31.09 2.944 2.941 2.992 3.500 158 4930.99 30.69 2.946 2.942 2.992 3.500 159 4961.68 29.66 2,939 2.935 2.992 3.500 160 4991.34 29.66 2.932 2.931 2.992 3.500 161 5021.00 30.44 2.943 2.938 2.992 3.500 162 5051.44 30.58 2.937 2.936 2.992 3.500 163 5082.02 31.12 2.928 2.924 2.992 3.500 164 5113.14 31.06 2.922 2.920 2.992 3.500 165 I 5144.20 31.84 2.956 2.953 2.992 3.500 166[ 5176.04 29.59 2.929 2.928 2.992 3.500 167 I 5205.63 30.08 2.932 2.926 2.992 3.500 167.1[ 5235.71 6.55 N/A N/A 2.992 3.500 Im Well: 1 R-14 Field: Kuparuk Company: CONOCO/PHILLI PS Country: USA Survey Date: December 5, 2002 J~int Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 168 5242.26 32.68 2.941 2.937 2.992 3.500 169 5274.94 31.27 2.939 2.937 2.992 3.500 170 5306.21 29.97 2.937 2.934 2.992 3.500 i71 5336,18 31.52 2.945 2.939 2.992 3.500 172 5367.70 31.00 2.960 2.957 2.992 3.500 173 5398,70 32.04 2.947 2.941 2.992 3.500 174 5430.74 31.36 2.958 2.954 2.992 3.500 175 5462.10 30.85 2.911 2.910 2.992 3.500 176 5492.95 32.06 2.952 2.949 2.992 3.500 177 5525.01 31.78 2.930 2.928 2.992 3.500 ~78 5556.79 31.55 2.928 2.927 2.992 3.500 -- 179 5588.34 31.46 2.958 2.955 2.992 3.500 180 5619.80 30.91 2.966 2.962 2.992 3.500 i81 5650.71 28.44 2.979 2.970 2.992 3.500 181.1 5679.15 1.39 N/A N/A 2.992 3.500 Im 182 5680.54 40.32 2.992 2.927 2.992 3.500 183 5720.86 30.96 2.948 2.945 2.992 3.500 184 5751.82 31.38 2.955 2.954 2.992 3.500 1%5 5783.20 32.91 2.954 2.953 2.992 3.500 186 5816.11 30.80 2.943 2.941 2.992 3.500 187 5846.91 32.18 2.952 2.949 2.992 3.500 188 5879.09 31.32 2.925 2.922 2.992 3.500 189 5910.41 28.17 2.947 2.945 2.992 3.500 190 5938.58 31.90 2.963 2.962 2.992 3.500 191 5970.48 31.54 2.939 2.937 2.992 3.500 192 6002.02 31.66 2.954 2.953 2.992 3.500 193 6033.68 30.41 2.928 2.928 2.992 3.500 194 6064.09 31.42 2.955 2.954 2.992 3.500 195 6095.51 30.70 2.952 2.948 2.992 3.500 196 6126.21 31.40 2.922 2.920 2.992 3.500 196.1 6157.61 6.76 N/A N/A 2.992 3.500 Im 197 6164.37 31.74 2.954 2.950 2.992 3.500 198 6196.11 32.50 2.921 2.920 2.992 3.500 199 6228.61 31.29 2.962 2.959 2.992 3.500 200 6259.90 31.65 2.964 2.962 2.992 3.500 .SCANNED APR g g 2:003 Joint Tally page 3 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Jointl Depth Length Modal Mean Nominal Nominal Type No.J ID ID ID OD feet feet inches inches inches inches 201 6291.55 29.44 2.942 2.941 2.992 3.500 202 6320.99 31.15 2.967 2.962 2.992 3.500 203 6352.14 29.05 2.963 2.960 2.992 3.500 204 6381.19 31.81 2.967 2.967 2.992 3.500 205 6413.00 28.79 2.950 2.948 2.992 3.500 206 6441.79 31.73 2.964 2.958 2.992 3.500 207 6473.52 31.43 2.940 2.942 2.992 3.500 208 6504.95 31.92 2.952 2.950 2.992 3.500 209 6536.87 31.65 2.937 2.933 2.992 3.500 210 6568.52 31.45 2.924 2.920 2.992 3.500 / . . 210.1 6599.97 6.62 N/A N/A 2.992 3.500 211 6606.59 31.26 2.968 2.961 2.992 3.500 212 6637.85 29.83 2.958 2.957 2.992 3.500 213 6667.68 30.45 2.934 2.936 2.992 3.500 . 214 6698.13 31.02 2.956 2.957 2.992 3.500 ... 215 6729.15 29.29 2.956 2.949 2.992 3.500 216 [ 6758.44 29.61 2.941 2.942 2.992 3.500 217] 6788.05 32.18 2.957 2.952 2.992 3.500 218 6820.23 31.68 2.952 2.947 2.992 3.500 219 6851.91 28.54 2.975 2.967 2.992 3.500 220 6880.45 31.37 2.950 2.947 2.992 3.500 221 6911.82 31.64 2.961 2.952 2.992 3.500 222 6943.46 31.67 2.961 2.957 2.992 3.500 223 6975.13 31.40 2.962 2.958 2.992 3.500 224 7006.53 31.20 2.941 2.936 2.992 3.500 225 7037.73 30.98 2.919 2.915 2.992 3.500 226 7068.71 28.95 2.935 2.934 2.992 3.500 226.1 7097.66 6.27 N/A N/A 2.992 3.500 ~ Im 227 7103.93 32.67 2.931 2.926 2.992 3.500 228 7136.60 31.64 2.956 2.948 2.992 3.500 229 7168.24 31.28 2.930 2.926 2.992 3.500 .... 230 7199.52 31.09 2.923 2.923 2.992 3.500 231 7230.61 29.13 2.921 2.921 2.992 3.500 232 7259.74 30.89 2.935 2.934 2.992 3.500 233 7290.63 29.95 2.962 2.954 2.992 3.500 Well: Field: Company: Country: Survey Date: 1R-14 Kuparuk CONOCO/PHILLIPS USA December 5, 2002 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 234 7320.58 33.45 2.962 2.952 2.992 3.500 235 7354.03 26.87 2.927 2.928 2.992 3.500 236 7380.90 32.66 2.928 2.923 2.992 3.500 237 7413.56 30.46 2.957 2.955 2.992 3.500 ~238 7444.02 31.66 2.925 2.922 2.992 3.500 239 7475.68 31.00 2.942 2.938 2.992 3.500 240 7506.68 32.82 2.958 2.951 2.992 3.500 241 7539.50 30.32 2.939 2.935 2.992 3.500 ,241.1 7569.82 4.54 N/A N/A 2.992 3.500 ~,lm 242 7574.36 32.72 2.959 2.956 2.992 3.500 243 7607.08 33.14 2.927 2.927 2.992 3.500 !244 7640.22 28.87 2.943 2.940 2.992 3.500 245 7669.09 31.36 2.937 2.930 2.992 3.500 [.246 7700.45 30.86 2.938 2.941 2.992 3.500 !247 7731.31 28.92 2.922 2.919 2.992 3.500 248 7760.23 31.75 2.949 2.945 2.992 3.500 249 7791.98 31.14 2.923 2.924 2.992 3.500 250 7823.12 32.80 2.914 2.916 2.992 3.500 251 7855.92 27.87 2.924 2.923 2.992 3.500 252 7883.79 32.97 2.942 2.941 2.992 3.500 253 7916.76 31.22 2.956 2.947 2.992 3.500 254 7947.98 32.05 2.923 2.915 2.992 3.500 255 7980.03 31.32 2.931 2.927 2.992 3.500 256 8011.35 30.35 2.943 2.938 2.992 3.500 257 8041.70 30.23 2.923 2.912 2.992 3.500 257.1 8071.93 5.91 N/A N/A 2.992 3.500 Im 258 8077.84 31.63 2.955 2.938 2.992 3.500 259 8109.47 31.25 2.958 2.949 2.992 3.500 260 8140.72 33.61 2.938 2.937 2.992 3.500 261 8174.33 27.29 2.922 2.922 2.992 3.500 262 8201.62 30.50 2.930 2.926 2.992 3.500 263 8232.12 28.73 2.928 2.926 2.992 3.500 264 8260.85 33.18 2.929 2.916 2.992 3.500 265 8294.03 28.09 2.920 2.920 2.992 3.500 266 8322.12 30.79 2.934 2.927 2.992 3.500 Joint Tally page 4 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness: Body = 0.254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length Modal Mean Nominal ,4ominal Type No. ID ID ID OD feet feet inches inches inches inches 267 8352.91 32.12 2.935 2.928 2.992 3.500 268 8385.03 30.38 2.929 2.923 2.992 3.500 269 8415.41 35.66 2.992 2.925 2.992 3.500 270 8451.07 21.48 2.917 2.91.3 2.992 3.500 271 8472.55 33.39 2.931 2.929 2.992 3.500 272 8505.94 29.77 2.932 2.930 2.992 3.500 273 8535.71 35.37 2.951 2.937 2.992 3.500 273.1 8571.08 L97 N/A N/A 2.992 3.500 [ Im 274 8579.05 28.11 2.941 2.936 2.992 3.500 274.1 8607.16 16.48 N/A N/A 2.992 3.500 t~br 274.2 8623.64 9.45 N/A N/A 2.992 3.500 t~acker 275 8633.09 29.12 2.958 2.957 2.992 3.500 275.1 8662.21 5.44 N/A N/A 2.992 3.500 irod mndrl 276 8667.65 31.49 2.908 2.911 2.992 3.500 277 8699.14 31.90 2.952 2.953 2.992 3.500 278 8731.04 28.51 2.977 2.977 2.992 3.500 279 8759.55 37.01 2.931 2.879 2.992 3.500 279.1 8796.56 N/A N/A N/A 2.992 3.500 ~ over Well: Field: Company: Country: Survey Date: 1 R-14 Kuparuk CONOCO/PHILLIPS USA December 5, 2002 JOint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches SCANNED APR $ 280,3 Joint Tally page 5 STATE OF ALASKA ii" ALASKA OIL AND GAS CONSERVATION COMMISSION~ ~, ,~.:~'~ ~'"~" ~. ~'~ 'i, ~,i[, REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate __ PI.Ugging Perforate Pull tubing Alter casing Repair well Pull tubing Other _X 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 516' FSL, 145' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1389' FNL, 1323' FEL, Sec. 17, T12N, R10E, UM At effective depth 1186' FNL, 1050' FEL, Sec. 17, T12N, R10E, UM At total depth 1126' FNL, 983' FEL~ Sec. 17~ T12N~ R10E, UM 12. Present well condition summary Total Depth: measured 9 2 5 0 feet true vertical 6976' feet Effective depth: measured 91 39' feet true vertical 6892' feet Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 4603' 9 5/8" Intermediate Production 9 2 2 9' 7" Liner Plugs (mea, sured) Junk (meaSured) Cemented 6. Datum elevation (DF or KB) 215 Sx CS II 1450 Sx PF"E" III & 350 Sx PF"C" 320 Sx Class G & RKB 82 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-14 9. Permit number/approval number 85-151/9-660 10. APl number 5o-029-21386-00 11. Field/Pool Kuparuk River Oil Pool Measured depth feet RECEIVED FEB 15 1. 90 Alaska Oil & Gas Cons. Comm[s' A.n. chorage True vertical depth 115' 115' 4603' 3780' 9929' 6962' Perforation depth: measured 8694'-8732', 8912'-8920', true vertical 6567'-6595', 6726'-6731 ', Tubing (size, grade, and measured depth) 3 1/2" J-55 9.3 #/FT @ 8828' MD-RKB Packers and SSSV (type and measured depth) 8924'-8960', 9032'-9040' MD-RKB 6734'-6760', 6815'-6821' TVD-RKB Baker 'FHL' ~ 8607'~ Baker 'DB' @ 8805', Camco TRDP-1A-SSA SSSV @ 1804 1'3. Stimulation or cement squeeze summary Replaced wireline retrievable, control line operated, SSSV with do~ne pressure operated Macco Storm Choke. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation , Subsequent to operation Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X. 16, Status of well classification as: Oil .... X .. Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,.d ' Form 10-4 06/15/88 ' i ,Title Sr. Operations Engineer Date ? O · SUBMIT IN DUPLICATE Subsidiary of Atlantic c e C~ }NTRAC~~__.~ REMARKS ~ t' WELL SERVICE REPOR1 Z~gZ3~~~~_PERATION AT REPORT TIME ' I'"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report ' 'F "FI' :'~.' knots · ,, . !:'!~7:' ";;' , · ?.', '":,.i,,:': . .~,.,,:... ' ,.. ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 516' FSL, 145' FWL, Sec. 1 At top of productive interval 1389' FNL, 1323' FEL, Sec. At effective depth 1186' FNL, 1050' FEL, Sec. At total depth 1126' FNL, 983' FEL~ Sec. 1 12. Present well condition summary Total Depth: 7, T12N, R10E, UM 17, T12N, R10E, UM 17, T12N, R10E, UM 7~ T12N~ R10E~ UM measured 9 2 5 0 feet true vertical 6976' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 82 7, Unit or Property name Kuparuk River Unit 8. Well number 1R-14 9, Permit number/approval number 85-151/9-435 10, APl number 5o-029-2138§-00 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 91 39' true vertical 6892' Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 4603' 9 5/8" Intermediate Production 9 2 2 9' 7" Liner 1' feet Junk (measured) feet Cemented Measured depth 215 Sx CS II 1 15' 1450 Sx PF"E" III & 4603' 350 Sx PF"C" 320 Sx Class G & 9 9 2 9' True vertical depth 115' 3780' 6962' 13. 14. Perforation depth: measured 8694'-8732', 8912'-8920', true vertical 6567'-6595', 6726'-6731 ', Tubing (size, grade, and measured depth) 3 1/2" J-55 9.3 #/FT @ 8828' MD-RKB Packers and SSSV (type and measured depth) 8924'-8960', 9032'-9040' MD-RKB 6734'-6760', 6815'-6821' TVD-RKB Baker 'FHL' ~ 8607'~ Baker 'DB' ~ 8805'~ Camco TRDP-1A-SSA SSSV ~ 1804 Stimulation or cement squeeze summary Gelled deisel fracture with 20/40 Carbolite was pumped into the A Sand. Intervals treated (measured) i!' 891 2'-8920', 8924'-8960', 9032'-9040' Treatment description including volumes used and final pressure Pumped 30~300 lbs of 20/40 Carbolite into the A Sand, Maximum treating pressure was 5975 psi, Representative Dail.v Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1608 634 17 20O4 766 49 1029 158 1224 231 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .. X. 16. Status of well classification as: Oil ,, X,, Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~-~~6 ~ -'~~'~"('~'~'~TitleForm~10-404 R~0 15/88"/ Sr. Operations Engineer~ ARCO Alaska,~ , Subsidiary of Atlantic Richfield WELL SERVICE REPOR' ~lT ~ OPERATION AT REPORT TIME r"l CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report .F.,, .FI mlle'"l /'0 knot. . . . _ _ .. STATE OF ALASKA { ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate X , Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development * Exploratory _ Stratigraphic _ Service Location of well at surface 516' FSL, 145' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1389' FNL, 1323' FEL, Sec. 17, T12N, R10E, UM At effective depth 1186' FNL, 1050' FEL, Sec. 17, T12N, R10E, UM At total depth 1126' FNL, 983' FEL, Sec. 17~ T12N, R10E~ UM 6. Datum elevation (DF or KB) RKB 82 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-14 9. Permit number/approval number 85-151/NA 10. APl number 50-029-21386-00 11. Field/Pool Kuparuk River Oil P.o. ol~... RECE Vt: 12, Present well condition summary Total Depth: measured true vertical 9250 6976' Effective depth: measured 9 1 3 9' true vertical 6892' Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 4 60 3' 9 5/8" Intermediate Production 9 2 2 9' 7" Liner feet feet feet feet Cemented Plugs (mea"sured) Junk (measured) Measured depth feet 215 Sx CS II 1450 Sx PF"E" II & 350 Sx PF"C" 320 Sx Class G & ;'~ '~.',','~"~- 0il, & ~,as Cons. ,~.~- ' True vertical depth 115' 115' 4603' 3780' 9929' 6962' Perforation depth: measured 8694'-8732', 8912'-8920', true vertical 6567'-6595', 6726'-6731 ', Tubing (size, grade, and measured depth) 3 1/2" J-55 9.3 #/FT @ 8828' MD-RKB 8924'-8960~, 9032'-9040' MD-RKB 6734'-6760', 6815'-6821' TVD-RKB Packers and SSSV (type and measured depth) " Baker 'FHL' @ 8607'~ Baker 'DB' @ 8805'~ Camco TRDP-1A-SSA SSSV @ 1804 13. Stimulation or cement squeeze summary Treated C1 Sand with 13% HCI. The A Sand was isolated. A coiled tubing unit spotted the acid at the perfs. Intervals treated (measured) 8694-8732 Treatment description including volumes used and final pressure 1600 gallons of HCI and 180 MSCF of nitrogen were used. Maximum treating pressure was 4000 psi. 14. Re0resentative Daily Average Production or In!ection Data~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 539 1 44 6 0 1 92 1518 226 1 1190 191 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X. Oil X Gas ,Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404- ~lrev 06/15/88 Title Sr. Operations Engineer SUBMIT IN DUPLICATE ~RCO Alaska, Ir(' Su~bsidlary of Atlantic Richfield Company WELL SERVICE REPOR'I WEL-L //~ -/,/ REMARKS IPBD~/2~ *[I FIELD - DIST/~CT - S.TATE/~/., U. IOPERATI/~N AT RE,~OR/T TIME C.C.' 2~$ ~/ ~ STATE OF ALASKA 0 ~ ALASKA OIL AND GAS CONSERVA~ON COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ 2. Name of Operator Alter casing _ _ Change approved program ~(_ Pull tubing _ 5. Type of Well: Development ARCO Alaska. inc. Exploratory 3. Address I Stratigraphic P. O. BOX 100360, Anchorage, AK 99510 I Suspend _ Operation Shutdown _ Re-enter suspended well _ Repair well Plugging _ Time extension _ Stimulate _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) Service 4. Location of well at surface 516' FSL, 145' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1389' FNL, 1323' FEL, Sec. 17, T12N, R10E, UM At effective depth 1186' FNL, 1050' FEL, Sec. 17, T12N, R10E, UM At total depth 1126' FNL~ 983' FEL, Sec. 17~ T12N~ R10E~ UM 12. Present well condition summary Total Depth: measured 9250' feet true vertical 6976' feet Plugs (measured) Effective depth: measured 9139' feet Junk (measured) true vertical 6892' feet None RKB 82 7. Unit or Property name Kuparuk River Unit feet 8. Well number o 1 R-14 i/'-,, J'--'¢ ~-~ 9. Permit number 85-151 10. APl number S0-0 2~)- 21 386-00 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Lenglfl Size Structural Conductor I I 5' I 6" Surface 4603' 9 5/8" Intermediate Production 9 2 29' 7" Liner Cemented Measured depth True vertical depth 215 Sx CS II 1 15' 115' 1450 Sx PF"E" III & 4603' 3780' 350 Sx PF"C" 320 Sx Class G & 9929' 6962' Perforation depth: measured 8694'-8732', 8912'-8920', true vertical 6567'-6595', 6726'-6731', Tubing (size, grade, and measured depth 3 1/2" J-55 9.3 #/FT @ 8828' MD-RKB Packers and SSSV (type and measured depth) 8924'-8960', 9032'-9040' MD-RKB 6734'-6760', 6815'-6821' TVD-RKB MACCO PB valve with dome pressure of 500 psi. Status of well classification as: Oil X Gas m Suspended_ Baker 'FHL' @ 8607', Baker 'DB' @ 8805'~ Camco TRDP-1A-SSA SSSV ~ 1804 13. Attachments Description summary of proposal ~ Detailed operation program BOP sketch Original SSSV inoperative due to blocked control line. Install 14. Estimated date for commencing operation 15. July 18. 1989 16. If proposal was verbally approved .-.-~j j Name of approver ,/--~ .~ ~ ~ Date approved Service Oil Producer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 10- /-¢ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Commissioner IApproval No. Approved Copy Returned ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Well 1R-14 Application for Sundry Approval July 17, 1989 It is proposed to replace the original tubing retrievable SSSV with a MACCO PB SSCSV with the dome pressure set at 500 psi. The control line to the original SSSV has become plugged and can no longer be used to charge the SSSV and provide well control. The original valve will be locked out and the MACCO vlave will be set in the TRDP profile. The proposed SSSV, shown in the attached drawing, fits in the profile of the original SSSV and is set to close if the wellhead drops below 150 psi. Wireline BOP's will be used and no workover fluid is required. The expected bottom hole pressure is 3000 psi. MACCO PB SUBSURFACE SAFETY VALVE Advantages of Macco PB SSCSV · Large flow area. · No flow through working parts of safety valve. · No hydraulic seals. Closing force is transmitted through liquid-filled bellows. · Predictable and repeatable valve performance. · Snap-action closure. Valve disc does not throttle in flow stream. · Suitable for gas lift wells. · Easily field tested. With use of a convenient test stand,, the PB safety valve can be tested and reset. · No depth limitation. The PB is suitable for a wide variety of special applications. The PB is wireline retrievable and can be suspended and packed off in any standard land- ing nipple with the appropriate locking device. The PB can also be suspended and packed off in the tubing string with a collar lock mandrel. The PB is available in a 50 to 3,000 psi range (PB) and al00 to 10,000 psi range (HP-PB). Features of the PB: · Subsurface control · Wireline retrievability · 50 to 10,000 psi operating range · Bellows protection unit · · Positive closing pressure · Hard and soft disc-seat closing seal The PB can be supplied for Class III service and is certified to OCS/APl specifications. )N ELASTOMERS All elastomers are made of Viton. tBER VITON SEAT 17-4 ph stainless steel. DISC 17-4 ph stainless steel. WIPER SEAL LOCK SPRING LOCKING SLEEVE Holds locking balls in lock groove. LOCKING BALLS Hold disc in open position. CLOSING SPRING Provides closing force. RECOCKING SPRING PRESSURE SENSING PORT Two fine mesh screens filter trash and sand. BELLOWS PROTECTION UNIT Traps fluid in bellows to protect against overextension. TRIP RING Pushes locking sleeve up to release disc. MAIN BELLOWS (3-Ply Monel) Retains fluid and transmits closing force to trip ring and closing spring. LOWER BELLOWS (3-Ply Monel) Retains fluid and transmits dome charge closing force to main bellows. DOME Contains nitrogen charge. PLUG Backs up dome check valve. DOME caP DOME CHECK VALVE Retains nitrogen dome charge. For high pressure valve (HP-PB), this is replaced with heavy-duty ball check assembly. · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator 15. Type of Well: Development X.~ ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P'. O. Box 100360, Anchorage, AK 99510 Service _ Operation Shutdown _ Re-enter suspended well _ Time extension _ Stimulate ~ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) RKB 82 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 516' FSL, 145' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1389' FNL, 1323' FEL, Sec. 17, T12N, R10E, UM At effective depth 1186' FNL, 1050' FEL, Sec. 17, T12N, R10E, UM At total depth 1126' FNL, 983' FEL~ Sec. 17, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 9250' feet true vertical 6976' feet Effective depth: measured 91 3 9' feet true vertical 6892' feet Casing Length Size Structural Conductor I 1 5' 1 6" Surface 4603' 9 5/8" Intermediate Production 9 2 29' 7" Liner Plugs (measured) 8. Well number 1R-14 fe~t , Junk (measured) Cemented 9. Permit number 85-151 10. APl number 50-0 29- 21 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool RECEIVED MAY' 2 6 1989 Alaska 011 & Gas Cons. Commission Measured~eCp~[~r~rue vertical depth 215 Sx CS II I 1 5' 115' 1450 Sx PF"E" III & 4603' 3780' 350 Sx PF"C" 320 Sx Class G & 9929' 6962' Perforation depth: measured 8694'-8732', 8912'-8920', 8924'-8960', true vertical 6567'-6595', 6726'-6731', 6734'-6760', Tubing (size, grade, and measured depth 3 1/2" J-55 9.3 #/FT @ 8828' MD-RKB Packers and SSSV (type and measured depth) Baker 'FHL' @ 8607', Baker 'DB' @ 8805', Camco TRDP-1A-SSA SSSV @ 1804 14. Estimated date for commencing operation June 10. 1989 16. If proposal was verbally approved 9032'-9040' MD-RKB 6815'-6821' TVD-RKB 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch _ Refracture Pump Schodule Status of well classification as: Oil X Gas __ Service Oil Producer Suspended Name of approver Date Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned ~ ~',~2~'z~ Title, FOR ~MMI~N USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance__ Mechanical Integrity Test__ Subsequent form require Approved Copy Returned Commissioner Approved by the order of the Commission IApproval No. SUBMIT IN TRIPLICATE Form 10-403 Rev 5/03/89 ORIGINal. SIGNED BY LONNIE C SMITH Well 1R-14 Application for Sundry Approval May 23, 1989 It is proposed to refracture Well 1R-14's A Sand. The well will be refractured with gelled diesel and 20/40 Carbolite pumped at 20 BPM, and no workover fluid will be used. No BOP is required. A surface manifold with tanks will be present and used to produce the well for the first few days. The expected bottom hole pressure of the A sand is 2500 psi. RECEIVED MAY 2 6 ]989 Na~ 0ii & Gas Cons. C0mmissi0rl Anchorage KUPARUK WELL 1R-14 SAND REFRACTURE PUMP SCHEDULE 5116189 STAGE FLUID CLEAN VOLUME PUMP RATE PRC)P. CONC. PI:IOPP~T PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BP M PPG DESCRIPTION LBS STG/CUM BBLS I GD PRE-PAD 150.0 20 0 NOPf:E)PPANT 0 ,1 50/ 1 50 79 ............................................... SHUT DOWN FOR ISIP ...................................................... 2 GDPAD 325.0 20 0 NO PROPPANT 0 325/ 475 229 3 GDw/2 PPG 23.0 20 2 20/40 M CARBO-LITE 1930 25/ 500 554 4 GD w/4 PPG 29.8 20 4 20/40 M CARBO-LITE 4999 35/ 535 579 5 GD w/6 PPG 39.5 20 6 20~40 M CARBO-LITE 9965 50/ 585 614 6 GD w/8 PPG 40.7 2 0 8 20/40 M CARBO-LITE 13663 5 5/ 64 0 664 7 GD wi10 PPG 34.7 20 10 20/40 M CARBO-LITE 14576 501 690 719 9 , GDFLUSH 78.0 +SV 20 0,,, NO ,PFC, AN?, , 0 , 78/,768,,, 769 TOTAL GELLED DIESEL = 720.6 BBLS +SV 20/40 M CARBO-LITE = 45132 tBS NOTES: Stages I and 9 are Gelled Diesel. Stage 2 is Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 8 hour break. Stages 3 through 7 are Gelled Diesel with 6 hour breaker and without silica flour. Stage 9 should include a volume adjustment for sudace equipment between the wellhead and densitometer. This job is intentionally underflushed by I bbl. The blender tub should be bypassed at flush. All fluids should be maintained at 70 to 90 F on the surface. o ARCO Alaska, Ir Post x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 2, 1987 Transmittal #:6076 TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return on~ signed copy of this transmittal. 3H-17 Kuparuk Well Pressure Report (Otis) 9-13-87 Static 3M-20 Kuparuk Well Pressure Report (Otis) 9-15-87 Static ~-21 ~paruk Well Pressure Report (Otis) 9-17-87 3H-22 Kuparuk Well Pressure Report (Otis) 9-16-87 Static VAt 1R-1 Kuparuk Fluid Level Report 8-22-87 1R-2 Kuparuk Fluid L~el Report' 8-22-87 1R-4 Kuparuk Well Pressure Report(Otis) 8-23-87 Static 'C 1R-6 Kuparuk Well Pressure Report ~amco) 8-23-87 'CT Sand 1~8 Kuparuk Fluid Level ~port 8-22-87 IR-11 Kuparuk ~11 Pressure hport(Otis) 8-23-87 tC~ Sand 1R-13 Kuparuk Well Pressure Report (Otis) 8-22-87 1~14 Kuparuk Well Pressure Report ~tis) 8-21-87 Static 1~1C Kuparuk Fluid Level Report · 8-22-87 ~_~ ,, .. .,. ,, Sand Sand ReceiPt Acknowledged: DISTRIBUTIOn= nil ~ Cons. Oommission Anohoraga D&H State of Alaska BPAE Chevron Hobil SAPC Unocal ARCO Alaek., Inc. is · Subsidiary o! Atl·nll~RlchfleldComlaany ARCO Alaska, Inc. i .... Post Office B, J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-11!9 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. Fin -~3A- ~3A- 3A-15 3A-16 ~,~--~3C- 15 ~'~3C-16 -~3F-1 3F-10 ~3F~11 ~3J-4 3J-6 ~3J-9 al Prints: 14 14 14 1 2 3 CET/CEL 10-12-85 Run #2 8600 CET/CEL 10-13-85 Run #3 85.50 CET/CEL 10-02-85 Run #1 6795 CET/CEL 10-01-85 Run #1 7550 CET/CEL 10-01-85 Run #1 6680 CET/CEL 10-01-85 Run #1 6080 CET/CEL 12-30-85 Run #2 6400 CET/CEL 12-30-85 Run #2 7300 CET/CEL 10-!5-85 Run #1 5887 CET/CEL 10-15-85 Run #1 3995 CET/CEL 10-17-85 Run #1 7000 .CET/CEL 12-19-85 Run #1 5166 CET/CEL 12-19-85 Run #1 6950 CET/CEL 10-05-85 Run #1 6860 CET/CEL 10-19-85 Run #1 7000 CET/CEL 12-18-85 Run #1 36 Receipt Acknowledged: - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 - 6678 x Alaska Oil & Gas Corm. 6ommissJon. Anchorage State of.Alaska(+ 1 sepi~,a)~SK Drilling Vault(1 film) _ ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 21, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an intent notice on the following Kuparuk River Field- Well Action Anticipated Start Date 1R-14 Stimulation February 26, 1986 If you have any questions, please call me at 265-6840. Sincerely, well G. B. ~mallwood Senior Operations Engineer GBS-pg'O008 Attachment cc' F~le KOE1.4-9 RECEIVED FEB28]986 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfJeldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COrwMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of Well SURFACE LOCATION: 516' FSL, 145' FWL, SEC. 17, T12N, RIOE, LN 5. Elevation in feet (indicate KB, DF, etc.) 82' (RKB) 12. 7. Permit No. 85-151 8. APl Number 5o- 029-21386 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1R-14 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RIVER 0IL POOL ADL 25635, ALK 2568 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). It is proposed that the "C" Sand in Kuparuk Well 1R-14 be acidized to improve production. The treatment will consist of 1600 gals of 12% HCL. ANTICIPATED START DATE: February 26, 1986 RECEIVED FEB 28 ]986 Arlchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ig. ed. ,~/~/~/ /~ ~/ Title Kuparuk The space below f6r Commission use Sr. Operations Engr. Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 01-23-86 TRANSMITTAL ~ 5530 itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ CET-CEL'S/ One * of each ~,~JlR-14 08-12-85 Run #1 7494-9104 ¥1R-15 08-22-85 Run #1 5543-7306 ~/2Z-9 08-20-85 Run #1 5095-7186 ~2Z-10 08-20-85 Run #1 5689-7696 /2Z-ll 08-08-85 Run #1 5793-7377 ~3C-7 08-06-85 Run #1 6481-8748 ~3C-7 08-19-85 Run #1 4776-8748 Post Squeeze Receipt Acknowledged: State of AK*bl/se NSK Clerk*bl Vault*films Ab~a 0il & Gas Co~s. Gommission Anch~e: Drilling*bi ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompsny ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 12-05-85 TRANSMITTAL NO: 5469 JTURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS kECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING ~JkN SMI T TED ]CEIPT AND 1{~TUHN ONE ~NAL PRINTS/ SCHL/ CEMENT LOGS/ HEBIE~ITH A}~E THE FOLLOWING IThlv~S. PLEASE ACKNOWLEDGE SIGNED COPY OF ONE * THIS TRANSMITTAL. OF EACH 09-09-85 RUN #1 7288-~429 09-08-85 RUN %1 7988-9183 10-19-85 RUN %2 8439-8830 10-09-~5 RUN ~1 7050-7250 09-22-85 RUN ~1 5331-7402 10-11-85 RUN ~3 6740-7164 10-12-85 RUN ~1 8800-9000 09-23-85 RUN# 1 6530-8016 09-24-85 RUN %1 8750-9000 RUN %2* 8700-9000 THE CORRECTION CAN i-2'~'' CET/CEL ~-24'''' CET/CEL ~,-34-~''' SQUEEZE/ CEbIENT }<TNR tcECORD ~-3~ CET/CEL . ~-3 (POST SQUEEZE%2) CET/CEL lR-l~ SQUEEZE/ CEMENT RTNR ~CO~ =-15~ CET/CEL ]-12 ~ SQUEEZE/ CEI~NT RTNR RECO~ ~Z-12~'SQUEEZE/ CEMENT RTNk RECORD 09-26-85 ~EASE NOTE--THIS LOG SHOULD DE LABELED AS RUN %2. BE WRITTEN IN. THANK YOU. -!2~'' CET/CEL 09-26-85 RUN ~2 8550-8999 -12~ CET/CEL 09-28-85 RUN ~3 8550-8900 -!"" CET/CEL 09-30-85 RUN ~1 6351-8160 -3~/ CET/CEL 09-30-85 RUN ~1 6250-7966 -4~ CET/CEL 09-22-85 RUN ~1 3708-7531 -16~''CET/cEL 09-29-85 RUN ~1 2995-3692 -3'"" CET/CEL 10-17-85 RUN ~1 6300-7751 -1~-"- CET/CEL 09-19-85 RUN #1 7686-9510 -8 ~ CET/CEL ' 10-19-85 RUN #1 5700-6950 ~EIPT' 3~CKNOWLEDGED: DISTRIBUTION: E DRILLING*BL W. PASHER · CUKRiER L. JOHNSTON EXXON VRON' HOBIL PHILLIPS OIL M NSK CLEtLK*BL J. RATHMELL ... Alaska Oil & Gas Cons. Commission DATE: Anchora~oe SOHIO ~SE_~ .UNION VAULT/ANO* FILMS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DeCember 2, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-14 Dear Mr. Chatterton: Enclosed is a copy of the 1R-14 Well History (completion details) to include with the Well Completion Report, dated 11/15/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L100 Enclosure cc: 1R-14 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 604640 WWS #1 ICounty, parish or borough North Slope Borough Cease Or Unit ADL 25635 . Title Completion State Alaska no. AP1 50-029-21386 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 10/9/85 [Hour Date and depth as of 8:00 a.m. lO/lO/85 10/11/85 lO/12/85 thru 10/14/85 10/15/85 lO/16/85 Complete record for each day reported The above is correct ARCO W.I. IPr or status 56.24% if a W.O. 2000 hrs. 7" @ 9229' 9139' PBTD, NU flow in 10.4 ppg NaCl/NaBr Accept ri~ @ 2000 hfs, 10/9/85. ND tree, NU & tst BOPE to 250/3000 psi. RU $chl, tst lub to 1000 psi. RIH, perf w/4" gun, 4 SPF, 90° phasing f/8876'-8878', RD Schl. 7" @ 9229' 9139' PBTD, WOC 10.4 ppg NaC1/NaBr RIH w/3½" DP, set Champ pkr @ 8620', sqz 150 sx C1 "G" w/.95% _ D-28, .2% CD-31, .2% A-2 & .1% D-6. Rev out, POOH, WOC. RIH, tag top of cmt @ 8621', WOC. 7" @ 9229' 9123' PBTD, POOH 10.3+ ppg NaC1/NaBr Fin WOC, DO cmt f/8821'-9125', att .to tst csg to 2000 psi; no tst, circ, POOH. RU Schl, rn CET log f/9125'-8600'. Perf f/8851'-8853' w/4" gun, 4 SPF, 90° phasing, POOH. RIH w/EZSV BP, set @ 8900', POOH, RD Schl. RIH w/Champ pkr on DP, set @ 8617'. Sqz perfs w/150 sx C1 "G" blend cmt. Rev out, POOH. RIH w/bit, WOC, DO cmt f/8620'-8870'. Attempt to tst csg to 2000 psi, bled off to 1375'/15 min, circ, POOH. Rn CET log f/8900'-8550'. RIH w/bit, DO BP, POOH. 7" @ 9229' 9123' PBTD, Perf 10.3+ ppg NaC1/NaBr POOH, LD JB. RIH w/scrpr to 9123', rev out, POOH. RU Schl, tst lub to 1000 psi. RIH w/4" gun, 4 SPF, 90" phasing, perf 9032'-9040', 8940'-8960', 8924'-8940', 8912'-8920'. 7" @ 9229' 9123' PBTD, RIH w/3½" tbg 10.3+ ppg NaC1/NaBr Perf w/5" gun, 12 SPF, 120" phasing f/8714'-8732' & 8694'-8714'. Make 6.125" gauge ring/JB rn; unable to get past 8650', POE. Make 5.99" gauge ring/JB rn to 8850', POH. RIH w/DB pkr, set @ 8805' WLM, RD Schl. RIH w/3½" tbg. RECEIVED Alaska Oil & Ga~ ~r,r,~ ~ ....... Signature For ~orm preparmlon 8nd-distributi~, see Procedures Manual, Section 10,' Drilling, Pages 86 and 87. Date ] Title inchoraoe /1-~0-~'" Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25635 Auth. or W.O, no. ~Title AFE 604640 I Completion WWS #1 API 50-029-21386 Operator ARCO Alaska, Inc. cOSt center code Alaska JWell no. 1R-14 Spudded or W.O. begun IA.R.Co. W.I. 56.24% IDate 10/9/85 Complete Date and depth as of 8:00 a.m. 10/17/85 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W,O. 2000 hrs. I 7" @ 9229' 9123' ?BTD, RR Diesel in tbg & ann Fin rn'g 277 jts, 3½" compl string & lnd w/SSSV @ 1820', FHL/pkr @ 8623', DB Pkr @ 8821', "D" Nipple @ 8836', TT @ 8844'. Drop ball, set pkr, press up tbg to 1500 psi; press bleeding off @ 1000 psi. Shear off PBR. RIH w/blind box to 8820', repress tbg; bleeding off @ 1500 psi. Indication of ball lodged in dn hole compl equip. Drop 2nd ball, repress up tbg to 1500 psi, press bled dn to 1000 psi. Circ dn ann thru orifice vlv w/good rtns. Repress up tbg to 1700 psi; press bled dn to 1000 psi. RIH w/std'g vlv, set same in "D" Nipple. Tst tbg, OK; tst ann & pkr, OK. POOH w/std'g vlv, press up ann & tst SSSV; OK. Shear out 2nd ball. Set BPV, ND BOPE, NU & tst tree; OK. Displ well to diesel, tst tbg & orifice vlv; OK. Set BPV. RR @ 0400 hfs, 10/17/85. Old TD Released rig 0400 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing I New 9123 ' PBTD TD PB Deplh Date I K nd of rig 10/17/85 J Rotary Typ .... pletio. (single. dual, etc.)Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Pf~a/li~l~J~ i~il ~ ,,. Oil on test -' ''~ U~pe~,,d,§¥S'~''' Pump size, SPM X length Choke size T.P. O.P. Water % GOR Gravity Allowable Effective date corrected iS,Won The above is correct For form preparation and distr~oution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, IDate JTitle i l- f/J-gS' Drilling Superintendent ARCO Alaska, Inc. ,~--- Post Office B ;..)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action Date Performed 1B1 Frac 11/6/85 1E8 Frac 1 2 / 6/85 1E-1 9 Convers i on 1 0/1 7/85 1 E-21 Convers ion 8/1/85 1E.-23 Convers i on 1 0/23 / 85 1G-2 Frac 1 2/6/85 1R1 Frac 11/5/85 1R2 Frac 11 / 5 / 85 1R4 Frac 11/6/85 1R6 Frac 11/6/85 1R1 3 Frac 11/1/85 1R1 4 Frac 11 / 1 / 85 2D-5 Ac idi zed 6/1 8/85 2D-6 Acidi zed 6/18/85 2V5 Convers ion 7/6/85 on the If you have any questions, please call T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany P, ECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Na~e~pe~t~SKA' INC. 3. Ad,ess O BOX 1 00360 ANCHORAGE ALASKA 9951 0 · i · · 4'L°~l[~:~l~/~ LOCATION-516' FNL, 145' FEL, SEC. 17, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 82' (RKB) 6. Lease Designation and Serial No. ADL 25635, ALK 2568 7. Permit No. 85-151 8. APl Number 50- 029-21 386 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1R-14 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: {Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation I~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 1, 1985, the "A" sands of Kuparuk we l I 1R-14 were hydraulical ly fractured and propped to improve production. The treatment consisted of 203 BBLS of gel led diesel as pad and carrying fluid and 756# of 100 mesh and 8988# 20/40 sand as proppant. 78 BBLS of gel led diesel was used as a flush. Prior to pumping· equipment and lines were tested to 7000 psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~,'//r~:~'X~'' t~/f'~~ Title KIJPARUK The space below for Commission use Op~pA-r I Conditions of Approval, if any: Date 1 2/6/R~, Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" i,~ Triplicate Form 10-403 I~u 7-1-,ql~ and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska- Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-14 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 1R-14. received the Well History (completion details). forward a copy to you. I have not yet When I do, I will If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L85 Enclosure RECEIVED Oil & (]as Oons. Con~mi,ssio~ Anci]oraoa ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~-" ALASKA £ _ AND GAS CONSERVATION CO, /llSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-151 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-21386 4. Location of well at surface--- 9. Unit or Lease Name 516' FSL, 145' FWL, Sec.17, T12N, R10E, UM ~ LocA~IONS~ Kuparuk River Unit ~ VERIFIED At Top Producing Interval ~ ~_ ~'i 10. Well Number 1389' FNL, 1323' FEL, Sec.17, T12N, R10E, UM lSurf 1R-14 I At Total Depth ~B. H. ~.~--- 11 Field and Pool ! - ' 1126' FNL, 983' FEL, Sec.17, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB. DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 82' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/29/85 08/06/85 08/07/85*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9250'MD,6976'TVD 9139'MD,6892'TVD YES I~X NO []I 1820 feet MD 1650' (approx) 22. Type Electric or Other Logs Run DIL/SFL/$P/GR, FDC/CNL/SP/Cal, DIL/SFL/SP/GR, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,., 16" 62.5# H-40 Surf 115' 24" 215 sx CS II .. 9-5/8" 36.0# J-55 Surf 4603' 12-1/4" 1450 sx PF "E" & 350 s:~ PF "C" 7" 26.0# J-55 Surf 9229' 8-1/2" 320 sx Class G & 250 s:¢ PF "C" 24. Perforations open to ProduCtion (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9040' - 9032' 3-1/2" 8844' 8623' & 8821' 8960' - 8924' 4" 4 spf, 90° phasing 8920' - 8912' '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8732' - 8694' 5" 12 spf, 120° phasing 8876' - 8878' 150 sx Class "G" 8851' - 8853' 150 sx Class "G" · . 27. N/A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED (.,.~,£~, , - Alaska 0il &A G'a.si~r.~.~.0r, ns. Cormni'-;.Sion Form 10-407 * NOTE: Tubing was run and the well perforated 10/17/85. DRH/WC45 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE "~ i ~' i ~.-'. ': t. ': GEOI'OGI~tM~RK~RS~- '~' ~; :: FO~MATION'TEs~-S ' ; ' NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT: DEPTH GOR, and time of each phase. Top Upper Sand 8615' 6509' N/A Base Upper Sand 8738' 6597' Top Lower Sand 8892' 6708' Base Lower ~and 9044' 6821' . 31. LIST OF ATTACHMENTS Well History, Gyroscopic Survey (2 copies) 32. ~ I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~~.~ Title Associate Engineer Date /1-/5-~* INSTRUCTIONS General: This form is designed f.o.r 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 °nly 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". ARCO Oii and Gas Compan~,~-...~, InStructions: Prepare and submit the "Initial Rei ~ the first Wednesday after a well is spudded or workover Daily work prior to spudding should . ,ammarized on the form giving inclusive dates only. ~pll History - Initial Report- Dally are started, District Alaska Field Kuparuk River Auth. or W.O. no. AFE 604640 Doyen 9 ICounty. parish or borough North Slope Borough I Lease ADL 25635 or Unit ITitle Drill IState Alaska IWell no. IR-14 API 50-029-21386 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 7/30/85 7/31/85 8/01/85 8/02/85 8/03/85 thru 8/05/85 Date and depth as of 8:00 a.m, RECEIVED Oil & ¢~a$ Cons. Corn. re!ssi _ The 86'6~{ii ~;qi~ct Date [Hour 7/29/85 Complete record for each day reported ARCO W.I. Prior status il a W.O. 1900 hrs. 56.24% 16" @ 115' 1170', (1055'), Navi Drl Wt. 9.3+, PV 20, YP 23, PH 9.0, WL 14.4, Sol 7 Accept rig @ 1400 hfs, 7/29/85. NU diverter sys. Spud well @ 1900 hrs, 7/29/85. Drl 12¼" hole to 650', kick off, drl & surv to 1170'. 585', .6°, N72-1/4E, 585 TVD, 2.8 VS, 1N, 3E 936', 5.2e, N47-1/4E, 936 TVD, 15.3 VS, aN, 14E 16" @ 115' 2420', (1250'), TIH Wt. 9.5+, PV 18, YP 20, PH 8.5, WL 12.8, Sol 8 Navidril f/1170'-1242'. Angle not building, POOH, LD Navidril. PU Mach III & 2~ bent sub. Navidril f/1242'-2420'. POOH, PU assy, TIH. 16" @ 115' 4640', (2220'), POOH Wt. 9.7+, PV 26, YP 24, PH 9.5, WL 10.4, Sol 10 FTIH. Navi drl f/2420'-4640'. Short trip. POOH f/Open Hole logs. 2554', 47.7~, N42.25E, 2345 TVD, 703 VS, N458, E534 2869', 46.2~, N44.25E, 2560 TVD, 933 VS, N626, E691 3715', 41.8~, N51.25E, 3154 TVD, 1533 VS, N1041, El126 4400', 46.1e, N46.25E, 3633 TVD, 2022 VS, 1373N, 1485E 9-5/8" @ 4603' 4640', (0'), NU POPE Wt. 9.5+, PV 18, YP 16, PH 9.5, WL 10.8, Sol 8 FTOH. RU & log w/DIL/SFL/SP/GR f/4639'-115'. RU & rn 106,its 9-5/8" csg, 36#/ft, J-55 BTC csg w/FS @ 4603' & FC @ 4513 . Cmt csg w/1450 sx PF "E" & 350 sx PF "C". RD diverter, NU BOPE. 9-5/8" @ 4603' 8760', (4120'), Drl to 8760' Wt. 10.4, PV 20, YP 15, PR 9.5, WL 4.8, Sol 12 Tst BOPE, RIH & drl cmt & float equip + 10'. Tst form to 12.5 ppg EMW. Trip f/BHA, drl to 6340' Navi Drl f/6340'-7797'. Trip f/bit, ream 45' to btm. Navi drl f/7797'-8522'. Navi Drl stopped drl. Trip f/BHA, drl f/8522'-8760'. 4575', 43.7", N48.25E, 3757 TVD, 2146 VS, N1457, E1576 5221', 46,8°, N46.25E, 4206 TVD, 2610 VS, N1767, E1922 '6468', 44,7~, N48.25E, 5089 TVD, 3510 VS, N2384, E2577 7016', 49.8e, N51.25E, 5441TVD, 3911VS, N2640, E2886 7518', 49.6°, N50.Z5E, 5765 TVD, 4294 VS, N2882, E3182 8054', 47.0°, N49.25E, 6120 TVD, 4695 VS, N3139, E3492 Signature For form preparation and distril~tion, see .Procedures Manual, Section' 10, JDate I Title lO- f ?-~5 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit ]Well no. Kuparuk River ADL 25635 I 1R-14 Auth. or W.O. no. Title AFE 604640 Drill Doyon 9 API 50-029-21386 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Date Spudded [ 7 / 29 / 85 Date and depth Complete record for each day reported as of 8:00 a.m. 8/06/85 8/07/85 I otal number of wells (active or inactive) on this cst center prior to plugging and ~ bandonment of this well our ~Prior status if a W.O. 1900 hrs. I 9-5/8" @ 4603' 9175', (415'), RD SOS Wt. 10.4+, PV 18, YP 12, PH 9.5, WL 5.0, Sol 12 Drl f/8760'-9175', POOH. Run DIL/SFL/SP/GR f/9166'-4601' & FDC/CNL/S~/CAL f/9166'-8600'. RD SOS. 7" @ 9250', (75'), Rn'g Csg Wt. 10.5, PV 18, YP 14, PH 9.0, WL 5.6, Sol 13 RIH, drl f/9175'-9250'. POOH, LDDP, RU & rn 7", 26#, J-55 BTC csg w/185 out of 212 in hole. 9-5/8" @ 4603' 9139' PBTD, (0'), RR 10.4 Brine Rn & land 212 ]ts 7" 26#, J-55 BTC csg @ 9229', FC @ 9139'. Cmt w/320 sx Class "G" cmt. ND BOPE, set slips, install lower packoff. NU tbg head & tamp tree. Tst packoff to 3000 psi; OK. Displ w/brine, bmp plug, tst csg @ 3000 psi; OK. Release 8/08/85 Rig @ 1330 hrs, 8-7-85. Old TD New TD 9250' (8/6/85) Released rig Date t Depth PB 9139' PBTD Kind of rig 8/7/85 Rotary Type completion (single, dual, etc.) Single 1330 hrs. Classifications (oil, gas, etc.) Oil Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature,~ //~ .,~ .]Date/^ #'~,,~ .--.~- ]Title ARCO Alaska, Inc. - Post Office c,,~x 1.00360 'Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-24-85 TRANSMITTAL NO: 5365 PAGE 2' OF 2 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HER5%qITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE BLUELINE OF EACH OPEN HOLE LOGS 1R- 1~.~ CYBERLOOK 08-06-85 RUN #2 ~5" DENSITY NEUTRON GR (RAW) 08-06-85 RUN ~2 ~'~'~2" DENSITY NEUTRON GR (RAW) 08-06-85 RUN ~2 ~c~_.~'~5'' DENSITY NEUTRON GR (PORO) 08-06-85 . RUN #2 '~2" DENSITY NEURTON GR (PORO) 08-06-85 RUN #2· --~~" DIL/SFL-~R 08-06,85 RUN #2 "DIL/SFL-GR 08-06-85 RUN #2 8500-9109 4800-9132 4800-9132 4800-9132 4800-9132 4602-9158 4602-9158 3J-1 "~ -~':' CYBERLOOK 08-22-85 ~-'~'~5" DENSITY Nv. UTkON ~R (RAW) 08-22-85 ~ 2" DENSITY NEUTRON~ GR (~AW) 08-22-85 ~~5~ "DENSITY' NEuTRoN GR (PORO) 08-22-85 ~" DENSITY NEUkTON GR (PORO) 08-22-85 ~ ~" DIL/SFL-GR 08-22-85 ~" DIL/SFL-GR 0~-22-85 3C-~~ CYBE~OOK 07-31-85 ~ ~~5" DENSITY NEUTRON GR (RAW) 07-31-85 .~ ~2" DENSITY NEUTRON GR (RAW) 07-31-85 " DENSITY NEURTON GR (PORO) 07-31-85 ~ ~~" DIL/SFL-GR " DIL/SFL-GR RUN #2 7800-9525 RUN #2 4576-9548 RUN #2 4576-9548 RUN #2 4576-9548 RUN #2 4576-9548 RUN #2 4576-9574 RUN #2 4576-9574 RUN #1 8150-8683 RUN 91 8100-8816 RUN #1 8100-8816 RUN ~1 8100-8816 RUN #1 8100-8816 07-31-85 RUN 91 4639-8842 07-31-85 RUN #1 4639-8842 08-12-85 08-12-85 0~-12-85 DENSITY NEUTRON GR (PORO) 08-12-85 DENSITY NEURTON GR (PORO) 08-12-85 DIL/SFL-GR 08-12-85 DIL/SFL-GR 08-12-85 RUN #1 6776-7365 RUN #1 3802-7388 RUN #1 3802-7388 RUN #1 3802-7388 RUN #1 3802-7388 RUN #1 3802-7414 RUN ~1 3802-7414 RECEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE DRILLING* W. PASHER B. CURRIER L. JOHNSTON EXXON CHEVRON MOBIL P~ILLIPS OIL D & M* NSK CLERK* J. RATHMELL* ** ONE BLUELINE COPY AND ONE SEPIA COPY *** ONE MYLA~ FILM COPY DATE: ' -~TATE O~_~A~ A~hom~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 25, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-14 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the tubing details will be submitted when the well is completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L132 Enclosure RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA " ' ALASKA C.-AND GAS CONSERVATION CO ,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-151 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21386 4. Location of well at surface 9. Unit or Lease Name 516' FSL, 1/+5' FWL, Sec.17, T12N, R10E, UN '~ LOCATION~ Kuparuk River Unit At Top Producing Interval~~'i VE",iFJ~ 1 10. Well Number 1389' FNL, 1323' FEL, Sec.17, T12N, R10E, UM i~urf._~---~-[I 1R-1/+ tB.H. ~t 11. Field and Pool At Total Depth 1126' FNL, 983' FEL, Sec.17, T12N, RIOE, UM~l Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 82' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/29/85 08/06/85 08/07/85I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9250'MD,6976'TVD 9139'MD,6892'TVD YES I~X NO []I N/A feet MD 1650' (approx) 22. Type Electric or Other Logs Run DI L/SFL/SP/GR, FDC/CNL/SP/Cal , DIL/SFL/SP/GR, CRT, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-/+O Surf 115' 24" 215 sx CS II 9-5/8" 36.0# J-55 Surf /+603' 12-1/4" 1/+50 sx PF "E" & 350 s: PF "C" 7" 26.0# J-55 Surf 9229' 8-1/2" 320 sx Class G 24. PerfOrations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Alaska 0il & Gas Cons. C0mmissi0fl Anchorage Form 10-407 Rev. 7-1-80 TEMP2/WC27 CONTINUED ON REVERSE SIDE Submit in duplicate 29. --; ;-" ~ ~:';' ,-' -'-: "' ':' : ' · "'2 " ' ' '" : ~ '" ~; GEOLOGICMARKER~ -' ':- ~' ' ; ' ' ' FORMATION TES~-S , NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VEIRT. DEPTH GOR, and time of each phase. Top Upper Sand 8615' 6509' N/A Base Upper Sand 87:~8' 6597' Top Lower Sand 8892' 6708' Base Lower Sand . 9044' 6821' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~~ Title '~ss°(?iate Erlgineer' Date L_ 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". Fnrm I [~]UIDANCE SUB- URFACE DIRECTIONAL: SURVEY J~JONTINUOUS I~]'OOL Company Well Name Field/LoCation Job ReferenCe Ng: 70749 Lom3ed BY: HALFACRE ARCO ALASKA INCORPOR~, TED -. . , 1R-14 ,(516' FSL~, 145',,Y-~.. S17. Ti2N. Ri~.. TrM5 . ,KUPA~, UK, NO, RTH $I~OPE. AI.~gKA , · Date · 22-AUGUST- 1985 Computed BY; OGDEN ~ $CHbUMBERGER ~ ~CT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC, 1R'14 KUPARUK NORTH SLOPE,AbA$~A SURVEY DATE~ 12-AUG-B5 ENGINEER) HALFACRE ( ', METHnDS OF COMPUTATION TOOL bOCATION: TANG~NTIAS- averaged deviation'and azimuth TN~E~POLAT~ON: LINEAR VERTICAL SECTION: HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH '47 PEG 56 MIN EAST CONPUTATION DA?El 22-AUG-85 PAGE 1 ARCO AbASKA, INC, DATE Or SURVEY= 12-AUG-85 1R-14 ' KEbb¥ B. USHING EbEVATZONI KUPARtlK NORTH &bODE,ALASKA ENGZNEERI HAbFACRE TERPOLATED VAbUES FOR EVEN 100 rg£T or MEASURED DEPTH TRUE SUB-SEA' ~',' ~ COURSE VERTTCAb DOGbEG RECTANGUbAR COORDXNATE6 HORI,Z~:,.:DEPARTURE SECTXON SEVERZT¥ NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET · ,.~. ,. IERSURFD V~RTZCAL VERT~CRb .DEVXATXON AZIMUTH DEPTH' 'DEPTH DEPTH.' DEG..MIN DEG MIN 0.00 100.00 oo:§o 300 0 400,00 500'00 600:00 700.00 ~00.00 900,00 0 O0 -82,00 0'.' 0 99:90 17,90 :.'07'.:18~ 199'90,I~.90 ": 3 299.90 2 ,90 8 399 90 317,90 ' "0 1~ 4q9 90 417.~0 0 16 599 89 517,89 O~ 29 699 88 617,88 0 54 799 87 71 87~: 1' 19 899788178329 N 0 0 E 0.00 S 52 2O E 0.09 N 20 12' E ' 0,41 N 4 34 W 0.63 N 21 35 E 0.88 N 53 5 ~ 1,26 N 68 42 E 1.90 N 67 31 E 3,05 N 67 3 E 4,88 N 55 27 E 8,59 1000 O0 999 40 llOO:OO lO9e 1.200 O0 1198 1300 O0 129~ 1400 O0 '1394 1500 O0 1490 O0 1678 1800 O0 1768 1900.00 1856 88 140888 1657 N 4837 E 58 1503,58 2022 N 4835 E 36 1596,36 23 22 N 48 43 E 73 1686.73 27 6 N 49 55 E 19 1774,19 30 55 N 49 49 E 17,21 2802 4O 53 .5652 7789 10401 13605 17333 21608 264,51 2000.00 1940 21 1858 21 34 39 2100.00 2020 2200.00 2097 2300'00 2171 2400.O0 2241 2500.00 2312 2600,00 2379 2700.00 2447 2800.00 ~515 29OO.O0 2584 N 5O 51E 76 1938 76 37.59 N 50 50 E 64 2015 64 41 17 N 49 55 E 37 2089 37 43 51 N 49 27 E 84 2~59 84 45 33 N 50 29 E 05 2230 05 46 5 .N 48 37 E 96 2297 96 47 3~ N 44 11 E 49 2365,49 4728 N 4430 E 46 2433,46 46 45 N 44 47 E 33 2502.33 46 27 N 44 56 E 318,65 377,98 441.65 509,18 580.07 651,22 72 ,54 798,15 871,38 .943,79 3000,00 3100.00 3200.00 3300,00 3400.00 3500,00 3600.00 3?00.00 3800.00 3900.00 2652,91 2570,91 46 34 2722,33 2640,33 45 34 27~2,47 2710,47 4510 2863,08 2781,08 45 32 2931,90 2849.90 47 6 2999,84 2917,84 46 56 3069.76 2987.76 44 0 3142.84 3060.~4 42' 3 3217,49 3135.49 41 50 32q1,03 3209,03 43 27 N 44 56 E 1016,45 N 44 52 E 1088,34 N 44 43 £ 1159.51 N 45 54 E 1230,22 N 48 10 E 1302.77 N 48 27 g 1376,14 N 49 38 E 1447.60 N 50 53 E 1515.79 N 51 55 E 158~,19 N 48 56 E 1649.86 0 O0 0 34 0 34 011 011 011 0 3'0 0 47 0 52 3 43 057 089 21'/ 393 260 390 362 409 358 414 360 359 3 O1 3 70 I 8 0 28 0 33 0 87 0 87 0 58 0 25 0 93 2 79 0 38 I 69 88 t~ 02 I 33 0 O0 N 0 21 S 0 8 S 0 ~3 N 0 53 N 084 N 5 N ! N 2,31 N 4,13 N 9 88 N 24 ~6 N 33 1N 46 96 N 63 80 N 85 3 N '109 ~7 N 137 168 0 O0 E 0 31 E 0 63 E 0 64 E 0701: 0 93 E I 52 E 2 69 E 4 49 E 784£ 82,00 FT 14 27 E 22 32 45 62 82 t06 134 52 N 16 83 N 0'0'"".',~ 0 0 E ':.?;i.698 2 2593 SE 88/..:;~ 5249 5643 Er ! N 5941 ~ ~5 N 6247 E 86 N 6214 E 1735 N 55 17 E 11 N 52 19 E 65 N 5~ ~8 E 79 N 5 7 E 21 N 53 5 E 32 N 52 17 E 30 N 51~2 E 55 N 50 6 E 30 N 50 31E 75 N 5022 E 25 E 28 24 E 40 63 E 56 54 E 78 53 E 104 49 E 136 46 E 173 96 E 216 93 E 264 203 52 N 245 56 E 318 94 N 50 20 E i~ ! ~ 2730 EE 52 N 29 82 E 378 16 N 5~ ~ 45 N 34u 91Z 44208 N 5 32564 N 392 O0 E 509 61 N 50 16 E 37113 N 44644 E 58055 N 5015 E 416 75 N 50 14 r 468 520 573 624 5O 7092 NN 55t 79 N 605 O0 N 656 31 N 707 06 E 651 60 E 724 13 E 798 66 E 871 88 E 943. 92, N 49 47 .) 38 N 49 i7 k' 51 N 48 53 E 85 N 4835 E O N810 09 E 1086 34 N 48 6 E 726 777 827 876 925 972 10i5 1057 39 N 860 38 N 910 48 N 963 25 N 1018 27 N 107 91 N.1121 28 N 1177 27 N 1229 44 E 12 86 E 1302 67 E 1376 49 E 1447 97 E 1515 08 £ 1582 43 E 1649 51 N 4753 E 23 N 4744 E 78 N 4743 E 14 N 4745 E 60 N 4748 E 79 N 47 54 E 20 N 48 4 g 88 N 48 tO g COMPUTATION'DA~E: 22-AUG-85 ARCO AGASKA., INC, 18'14 KUPARUK NORTH SLOPE,ALASKA OF, SURVEY1 12-AUG-85 BUSHING EbEVATIONI 82,00 FT ENGINEERI HALFACRE INTERPOLATED VALUFS FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB~ n SEA ' ' COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOR~Z,~ DEPARTURE !EASURFD VERTICAL VER_~CA, DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DEPTH DEPTH DEPTH' )EG N~N DEG NTN FEET DEG/IO0 FEET FEET F E 4'00:00 3431 53 33.=,53 47 56 N 47'44 g 179~.07 0 67 119, 70 N 1335 76 E 1792 09 N 48 11 E 4~00.00 3498 40 3416.40 47 57 S 47 55 E 1866.42 0 45 124658 N 1390 90 1390 52 ~ 9 4300.00 3565 78 47 10 4400.00 3634 5, 4~'00.00 3704 66 3622,66 44 43 4600.00 3776 43 3694,43 43 24 4700.00 3849 22 3767,22 43 50 4800.00 39~0.38 3838,38 45 28 4900.00 3989,36 3907,36 47 0 N 47 50 £ 1940,31 3 201~.94 ~ 48 0 ~ 2084.20 N 48 9 E 2153,84 N 47 44 E 2.222.40 N 47 53 E 2292.65 N 47 2.5 E 2365,05 1 35 0 1 33 2 49 I 66 2 14 0 91 1294 1~37 1482 1530 1578 44 14 N 1.49~ 85 N ! 1552 02 N 1~04 98 N 1655 11N 1707 89 N 1760 72 g 1940 58 E 2012 55 E 2084 38 E 2153 26 E 2222 36 E 2292 86 E 2365 3~ N 48 ,9 g 96 N 48 9 g 22 ~ 48 85' 48 8 41 N 48 8 67 N 48 8 ~ 06 N 48 7 E 5000.00 4056.93 3974 93 47 59 5,.00.00 4123.92 404,:92 47 48 5200.00 4191.30 4109,30 47 7 5300.00 4259,89 4177,89 46 26 5400.00 43~9.0! 4247.01 46. 9 5500.00 4398,43 4316.43 45 53 5600.00 4468,13 4386.13 45 47 5700 O0 4537.99 4455,99 45 37 5800:00 4607,88 4525,88 45 36 5900,00 4677,92 4595,92 45 28 N 47 7 E 2438,76 N 47 21 E 2513 O0 N 47 32 E 2586 89 N 47 37 E 2659 65 N 47 26 £ 273! 92 N 47 15 E 2803 89 N 47 6 E 2875 59 N 47 ! E 2947 13 N 46 49 E 3018,64 N 47 4 g 3090.01 0,80 162~ 0,59 167 1,47 1729 0,17 1778 O, 3 1827 0,42 1875 0,48 1924 0,14 1973 0,22 2022 0,30 2071 89 N 1815 03 E 2638 77 N 48 5 E 40 N 1869 35 N 1923 44 N 1977 20 N 2030 99 N 2083 71N 2136 47 N 2188 30 N 224 03 N 229~ 44 E 2513 89 E 2586 61 g 2659 94 E 273 87 E 280{ 48 E 2875 83 E 2947 10 E 3018 26 E 3090 01, N 48 3 E 90 N 48 2 E 66 N 48 2 E 92 N 48 I E 89 N 48 0 E 59 N 47 59 g 13 N 47 57 E 64 N 47 56 E O1 N 47 54 Z 6000.00 4748 12 4666.,2 45 18 6100,00 4818 50 4736,50 45 17 6200.00 4888 89 4806,89 45 10 6300.00 4959 50 4877,50 45 6400.00 .5030 ~9 494~.19 44 57 6500,.00 5101 O8 5019,08 44 45 6600,00 5171 84 5089,~4 45 58 6700.00 5238,44 5156.44 49 40 6800.00 5303,04 522~,04 49 49 6900.00 5367.43 5285,43 49 57 N 47 15 E 3161,23 N 47 23 E 3232,26 N 47 21 E 3303,29 N 47 40 E 3374.10 ~ 47 33 E 3444,82 N 47 29 E 3515.35 N 48 8 E 3586,00 ~! 50 50 E 3660,53 N 50 57 E 3736,75 N 51 6 E 3813.15 071. 0 22 0 44 0 14 0 22 0 85 4 57 I 08 0 78 0 49 2 1.9 2[67 2215 2263 2311 2358 2406 2454 25O2 2550 6O N 2 71N 2449 52 N 2502 16 N 2554 83N 2606 49 N 2658 72 N 2715 80 N 2774 94 N 2834 0'E316 t E 323~ 97 E 3303 20 E 3374 48 E 3444 46 E 3515 62 E 3586 48 £ 3660 76 E 3736 23 g 3813 23 N 47 53 £ 26 N 47 53 E 29 N 47 52 E 0 N 47 52 E 3 N 47 51E 35 N 47 51 g 01 a 47 50 ) 53 N 47 53 ~' 75 N 47 56 E 16 N 48 0 E 7000.00 5431.83 5349.83 49 53 7100.00 549b.20 5414,20 50 2 7200.00 5560,67 5478.67 49 41 7300.00 5625,56 5543,56 49 20 7400,00 5690,55 560~,55 49 24 7500.00 575.5.56 5673,56 49 30 7600.00 5820,50 5738,50 49 29 7700.00 5885,46 5803,46 49'2q 7~00.00 5950,54 5868.54 49 ~4 7900.00 60~6.95 59~4,95 47 50 N 50 58 E 3889,53 N 50 56 E 3965.96 ~ 50 45 E 4042.30 ~ 50 40 E 4118,29 N 50 31 E 4~94.2! N 50 27 E 4270.,3 N 50 27 E 4346,10 N 50 27 g 442~.05 N 50 12 E 4497.90 N 48 37 E 4572,64 0 47 0 45 0 45 0 38 0 92 0 61 ~0 72 0 58 I 48 I 39 2598 95 N 2893 78 E 3889 54 N 48 4 g 264"/ 2743 2791 2840 2888 2936 2985 3034 N 2953 19 E 3965 59 N 307~ 40 E 4118 78 N 3130 18 E 4194 18 N 3188 76 E 4270 63 N 3247 37 g 4346 99 N 3306,03 E 4422 35 N 3364,56 E 4498 10 N 3421,24 g 4572 98 N 48 7 £ 35 N 48 13 g 29 N 48 16 E 22 N 48 18 g 21 N 48 20 E 19 N 48 22 E 07 ~ 48 25 £ 81 N 48 25 g COYPU?AT,ON DA?;; 22-AUG-85 PAGE 3 ARCO ALASKA' 'KUPARUK NORTH SLOPE'ALASKA DATE OF SURVEY1 12-AUG-85 Kgbb¥ BUSHZNG ~;VA~ZONi ENGZNEERI HAL~ACRB 82,00 ZNTERPOLATED VASU~S FOR EVEN 100 FEET OF MEASURED DEPTH T~UB SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HeR iE~SURED VERTICAL VERTTCAL:;DEV~ATION AZZ~0TH ~ECTION SEVERZT¥ NORTH/SOUTH EAST/WEST DIET DEPTH DEPTH OEPTH '::,DEG 8000.00 6084,49 6002,49 '47 19 8~00.00 6~52.54 6070,54 46 5~ 8900.00 6291,20 6~,39,90 :',.46 29 8300.00 6290,X4 6908,~4 '46 18 8400.00 6359.52 6977,52 '45 58 8500.00 6429.04 6347,04 45 5! 8600.00 6498.83 6416,8,3 45 ~3 870~,00 6569.86 6487.86 44 24 8800,00 6641,41 6559,4! 44 17 8900.00 67~3.57 ~63~,57 42 57 FEET DEG/IO0 N 48 23 E 4646,38 N 48 35 E 47~9,65 N 48 4~ £ 479~.35 N 49 3 E 4864.77 0,27 0 88 0 51 0 62 N 49 2 E 4936,78 N 49 26 E 5008 64 N 50 7 E 5080:~3 N 50 59 E 5~50,53 N 51 4 E N 51 57 ~ 5289,~9 0 63 0 39 332 2 43 336~ 0 86 3412 0,68 3456 2,56 3499 N 47 N 3749 89 N 3803 47 N 3858 40 N 3912 62 N 3966 19 E 5008 73 E 5080 21 E 5150 52 E 5220 60 E 5289 DEPARTUR~ XMUTH IEG MXN 8 25 E 8 25 E 48 26 E 6 E 6 '~ :,'.",.N 46 60 N 4,8 30 ~ 59 N 46 32 E 73 N 48 34 E 9000.00 6787,58 6705,58 41 46 9100,00 6862.79 6780,79 41 2 9200.00 6938,2~. 6856,91 41 9 9250,00 6975,92 6893,92 41 2 N 52 57 E 5356,41 N 53' 25 E 5422,02 N 53 25 E 5487,39 N 53 2~ E 5520,07 1,65 3540,41 N 4020,06 E 5356,8! N 48 37 E 0,00 3579,78 N 4072,91 E 5422,49 N 46 ~I E 0,00 3618,90 N 4125,65 £ 5487,94 N 4844 E 0,00 3636,47 N 4152,02 E 5520,67 N 46 46 E ARCO A[~ASKA, INC. 1R-14 KUPARUK NORTH SLOPE,ALASKA TRUF SUB-SEA COURSE [EASURED V~RTICAL VERTICAL DEVIATION AZIMUTH COMPUTATION DATE: 2~-AUG-85 PAGE 4 DATE OF SURVEY1 ~2-AUG-85 KE~Y BUSHING E~EVATIONI ENGIN£ER: HA~FACRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF HEASURED DEPT .~ , VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ~.p DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,:'.' AZIMUTH DEG ~IN FEET DEG/IO0 FEET FEET FEET. i,>.:,.:i. DEG MIN DEPTH DEPTtt DEPTH DEG 0.00 0.00 -82.00 0 0 1000.00 999.40 917,40 5 56 2000.00 1940.21 1858,21 ]4 39 3000.00 2652 9~, 2570.9~ 46 34 4000.00 ~363 ii 3281,13 ~44 5~ 5000,00 4056 93 3974.q3 4'7 59 6000.00 4748 1~ 4666.12 45 18 7000.00 543! 83 5]49.83 49 5] 8000,00 6084 49 6002,49 47 ~9 9000.00 6787 58 6705.58 41 46 9250.00 6975.92 6893.92 41 2 N 0 0 E 0.00 N 46 14 E 17,~I N 50 51E '18.65 , 44 56 ~ 1016.45 N 48 39 E 1719.14 N 47 7 E 24~8.76 N 47 15 E 3161,23 N 50 58 E 3889.53 N 48 23 E 4646.]8 N 52 57 E 5356.41 N 53 25 E 5520.07 0.00 0 7 0 58 0 80 0 71 0 4'/ 0 27 0,00 0 O0 N 9 203 67 1628 2119 2598 3083 3540 0 O0 E 52 N ~ 84 ~ 6q N 12~ 89 N 1815 43 N 2345 95 N 2893 08 N 3476 4! N 4020 0 27 E 17 56 E 318 25 E 1016 57 E 1719 03 E 2438 50 E 3161 78 E 3889 36 E 4646 06 Z 5356 82,00 FT O0 N 0 0 E 35:' N 5517 E 94: N 50 20 E 46 N 4 1E 54 N 48 4 ~, 56 N 48 25 E 3638,47 N 4152,02 E 5520,67 N ~8 4~ E ARCO ALASKA, TNC, 1R-14 KUPARUK NORTH SLOPE,ALASKA CONPUTA?ION DATE= 22-AUG-85 TRUE SU~-SEA COURSE ~EABURFD VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH PEG HIN DEG NZN 0,00 82 O0 1,82 O0 282 O0 382 OO 482 O0 592 O0 682,00 782,00 882.00 0.00 82.10 182.20 282.].0 ~82.]0 482.10 582.1! 68~.11 78~.13 88~.19 DATE OF SURVEY1 12-A UG-85 KELLY BUSHING E~EV ATZONI ENGINEER~ HA6FACR£ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HOR SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST FEET OEO/lO0 FEET FEET FE q8~.~O 982,00 108].08 1082,00 1183.83 1182.00 1~85.05 128~ 1387,~9 138 1490,72 1482 70 .08 1682 1814.~2 1782 1930.26 1882 -82.00 0 0 N 0 0 E 0.00 0,00 0 7 S 31 22 E 0.09 100.00 0 14 N 35 25 E 0.35 200,00 0 9 N 6 52 W 0,~0 300.00 0 1~ N 18 5 ~ O, 3 400.00 0 15 N 48 11 E 1.17 500.00 0 27 ~ 67 14 E 1 76 600,00 0 51 N 69 40 ~ 2,79 700.00 1 16 N 67 13 E 4,50 800.00 2 56 N 58 34 E 7,61 N 4b 5 E N 48 47 E N 54 43 E N 55 25 E N 51 20 E N 48 49 E N 48 35 E N 48 45 E N 49 50 E N 49 59 E 15.41 26 10 53 ~4 74 4 101 ~9 134 ~4 174 4 222 ~0 280 1 N 51 35 E 348.43 N 50 6 E 428.04 N 49 42 E 519,50 N 50 11 E 620.56 N 44 11 E 726,77 N 44 37 E 835,55 N 44 56 E 941,34 N 44 56 E 1046,96 N 44 45 E 1148.97 N 4~ 50 E 1249,69 N 48 24 E 1356 90 N 49 54 E 1459 31 N 51 35 E 1550 70 N 49 13 E 1641 31 N 48 12 ~ 1738 19 q 47 56 E 1848 20 , 47 48 E 1957 71 N 47 58 Z 2061.59 N 48 8 E 2159,12 N 47 52 E 2254,~0 9 O0 5 46 1100.00 7 42 09 1200.00 10 21 oo 1300.00 13 22 oo 1400.00 16 36 09 15oo,oo 20 14 O0 1600.00 23 32 O0 1700,00 27 3R OO 1800,00 32 3 2051.35 1982.00 1900 O0 36 20 2179..26 2082.00 2000:00 40 45 2314.~I 2182.00 2100.00 44 27 2457,06 2282,0.0 2200.00 45 15 2603.02 238~,00 2300 O0 47 37 2750.94 248,,00. 2400:00 47 12 2896.62 2582,00 2500.00 46 25 304~.]8 9682,00 2600.00 46 8 3185.]3 2782.00 2700 O0 45'18 3327.15 2882.00 2800:00 46 7 0 O0 0 2.5 0 39 0 15 0 11 0 27 0 26 0 34 0~27 3.11 1,43 1,28 I 73 2 73 2 67 4 02 3 42 4 05 3 52 3 21 3 51 2 61 3 61 7 0 0 34 0 81 0 89 0 70 1 59 I 02 2 32 5 82 0 2i ,1 '1 57 274 I 37 · 0 O0 N 0 S 0 18 N 0 48 N 0 19 N ! 0 N I 47 N 2 15 N 3 59 N 1~ 64 N 92 N 23 50 N 32 25 N 45 1! N 0 O0 E 0 28 E 0 60 E 0 6'4E 0 68 E 0 87 E 1.38 E 2,43 E 4,12 E 7,01 E 12 97 E 20 79 E 30 43 E 43 38 E 60 23 E 82,00 FT 62 84 110 1 O0 N 80 N 10 91 N 172 ~01 N 216 50 E 101 51 E 134 19 r. 02 E 280 DEPARTURE AZIMUTH PEG .,. 0 Ni: 0 0 E "57 11 g 0, S' 75 58 g 0 'N ,,74 2 E 47 43 I 5i 36 2 84 N 58 52 ,.. 4 65 N 62 23 7 87 N 62 52 E 15 58 h 56 20 £ 26 19 N 52 33 E 38 45 N 52 19 E 54 05 N 53 22 E 75 25 N 53 I0 E 332 396 469 547 622 697 769 840 9t 1037 1094 1158 1232 1305 1375 1440 1504 60 N 52 23 E 99 N 51 24 E 16 N 50 45 E 13 N 50 30 E 55 N 50 21 E 222 16 N 268 86 E 348 77 N 50 25 E 272 73 N 330 45 E 428 46 N 50 27 E 86 E 519 70 E 621 15 E 727 41 E 835 15 E 941 83 E 1046 87 E 1148 53 E 1249 93 N 50 ,16 E 09 N 50 16 E 14 N 49 46 E 72 N 49 4 E: 41 N 48 35' ) 97 N 48 13 99 a 47 55 E 70 N 4? 42 £ 98 E 1641 83 E 1738 37 E 1848 61E 1957 75 E 2061 32 E 2159 89 E 2254 28 E 1356 91 N 47 44 44 E 1459 32 N 47 49 24 E 1550 70 N 47 59 E 3473.76 2982,00 2900.00 47 14 3616.95 3082.00 3000.00 43 37 3752,~0 3182,00 3100,00 41 37 3887.56 3282.00 3900,00 43 21 4026,81 3382,00 3300.00 46 3 4175.49 3482,00 3400.00 48 1 4323 79 3582,00 3500.00 46 52 4467"q9 3682.00 3600 O0 45'10 4607:68 3782,00 3700~d0 43 15 4745.74 3882.00 3,00.00 44 34 32 N 399 93 N 477 62 N 555 49 N 631 58 N 706 46 N 780 89 N 852 83 N 924 48 N 1004 84 N 1081 79 N 1152 65 N 1222 53 N 1295 37 N 1377 81 N 1458 39 N 1535 55 N 1608 42 N 1678 32 N 48 10 £ 21 N 48 12 E 22 N 48 10 E 73 ~ 48 9 g 61 N 48 9 g 14 N 48 8 E 32 'N 48 8 g ARC~ AEASKA, INC, 1R-14 KUPRRUK NORTH SbOPE,AtASKA TRUF. SUB-SEA COURSE MEASURED VERTICAL VE. RTICAb' DEVIATION AZIMUTH DEPTH . DEPTH DEPTH::',,DEG,, MIN DEG MIN 4889.~2 3982 O0 3900,00:'.~46 53' 5037.47 4082 O0 4000,00 ~47 58 4100,00 .47. ~7 5186.30 ,4182 5332.04 4282 5476 37 4382 561q:87 4482 5763.01 4582 5905.83 4682 6048.13 4782 6190.23 4882 COMPUTATIDN DATE) 22-AUG-S5 DATE OF SURVEY1 12-AUG 85 ENGINEERI HAbFACRE INTERPOtATED VAbUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAE DOGbEG RECTANGUEAR COORDINATES 8£CTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET N 47 26 E 2357 18 N 47 4 E 246 ' 616 N 47 29 E 2576 82 N 47 36 E 2682 84 N 47 16 E 2786 92 N 47 3 E 2989 83 N 46 56 E 2992 22 N 47 4 E 3094 ~7 N 47 18 E 3195 41 N 47 20 E 3296.36 O0 O0 O0 4300 00 · 45 O0 4400:00 '4'5 43 O0 4500.00 45 41 00 4600.00 45 28 O0 4700 00 45 15 O0 4800:00 45 6331.84 4982.00 4900,00 45 2 N 47 41E 3396 63 6473.145082,00 . 5000,00 44 48 N 47 27 E 3496 44 oo.oo , 48 oo.oo . 371, oo oo.oo , 38 o ? 3 .oo oo oo.oo , , o67 7540.74 5782 O0 5700,00 49 30 N 50 24 ~ 4301 09 7694,67 5892 O0 5800,00 49 31 N 50 27 £ 4418 01 7847.77 5992 O0 5900.00 48 16 7996.33 6082 O0 6000.00 47' 19 8142.98 O0 6100 O0 46 37 O0 6200 O0 '46 21 O0 6300 O0 45 59 O0 6400 O0 45 36 O0 6500 O0 44 17 O0 6600,00 43 48 O0 6700,00 41 51 O0 6800,00 41 2 N 49 14 g 4533 83 N 48 23 E 4643 N 48 36 E 4750 N 48 58 E 4856 N 49 8 E 4960 N 49 45 E 5063 N 51 2 E 5162 N 51 22 E 5259 N 52 53 E 535~ N 53 25 68 95 24 07 12 39 59 43 E .5438,66 6182 8288.20 6282 8432.37 6382 8575.99 6482 8716.98 6582 8856.54 6682 8992,51 6782 9125.47 6882 0 60 0 17 I 20 .0 40 0 36 0 31 0 96 0 31 0 26 0 52 0 18 0 60 O9 0 $0 I $4 0 98 0 25 0 59 2 77 0 29 0 54 0 53 0 63 I 56 0 79 I 88 I 39 0 O0 0,00 9250,00 6975.92 6893.92 41 2 N 53 25 E 5520,07 1573 56 N 1755 07 E 2357 1647 85 N 1835 43 E 2466' 9 6 17~ 55 N 19~4 17 1864 1934 2004 2073 2142 2211 N 207 85 N 2 64 N 237O 02 N 2444 2561 2636 2'71 278~ 2859 2934 3008 3081 3152 3221 3289 3356 3419 3481 3537 3589 PAGE 6 82,00 FT :.'DEPARTURE ~EG MIN N':,48 7 E 48 4 E 47 E 2576 ,i, 48 3 E 4 E 2682' 48 1E 79 E 2786 48 0 g ~0 E 2889 47 58 E 81 £ 2992 ~3/.;.'N 47 56 ) 0 E 3094 7 N 47 54 I Z 3195 42~ a 47 53 ~ 88 E 3296 36 N 47 52 E 69 N 2518 05 N 2592 56 N 2666 I N 2755 ~4 N 2 47 51N 2~40 4N 303 3 N 312~ 92 N 3212 41N 3302 86 E 3396 63 N 47 51 E 53 E 3496 59 E 3596 75 £ 05 E 394~ 0! E 406 46 E 4184 65 £ 4301 91 E 44t8 45 N 47 51 E 66 N 4'/ 51 E 91 N 4? 55 E 50 N 48 I E 06 N 48 6 E 49 N 48 11 E 30 N 48 15 E 20 N 48 19 ~ 14 N 48 2'2 E 57 N 3392 O! E 4534 O1 N 48 25 E 29 N 3474 34 E 4643 85 N 48 25 E 32 N 3554 73 E 4751 13 N 48 26 E 75 N 3633 80 N 37i 87 N 379~ 95 N 3867 08 N 394 39 N 401~ 74 N 4086 91E 4856 5 £ 496O 4 E 5063 43 E 5162 E 5259 ~ E 5351 i4 E 5439 43 N 48 26 E 28 N 48 27 E 35. N 48 28 r. 66 L'd 48 30 91 N 48 33 ,~ 83 N 48 37 E 1.6 N 48 42 E 3638,47 N 4152,02 E 5520,67 N 48 46 E ARCO AbASKA, TNC. 1R'~4 KUPARUK NORTH $LOPE,AbASKA ~ARK~R TOP UPPER SAND BASE UPPER ~AND TOP EO~ER SAND BAS~ LOWER SAND PBTD TD-DRILSER COMPUTATIDN'DATEI 22-AUG-g5 PAGE DATE OF SURVEY: 12-AUG-85 KEbbY BUSHING EbEVATIONI ENGINEERI HAbFACRE 82,00 INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH · .' , BELOW KB , 8615.00 873g.00 8892.00 9044.00 ' 9139,00 9250.00 SURFACE bOCAT~ON ORIGIN: 516' FSL, 145' rW[,. $~C 17,:~T!2N' RIOE TVD RECTANGUbAR COORDINAT£~ FROM KB SUB-SEA NORTH/SOUTH:,',.:,:~A~T/WEST 6707.72 662 72 3496 24 N 3 3~ E 56 3557 86 N 38 g ~ 2! 3595 04 N 409 48 E 6892 21 68 6975:92 6893 92 3638 47 N 415 02 g UM ARCO AbA.SKA, TNC. IR']4 KUPARUK NORTH SI]OPE,ALASKA MARKER TOP UPPER SAND BRSE UPPER SAND TOP breWER SAND BRSF LOWER SAND PBTD TD.-DRI bi,ER COMPUTATION DATEI 22-AUG-85 PAGE DATE OF SURV£¥1 12-AUG-85 KEbb¥ BUSH'lNG ~bE. VATZONI ENGIN£ER~ HAbFACR£ SURFACE. MEASURED DEPTH BEbOW KB ORIGIN: 516' FSb, 145' FWb. SEC 17 TVD RECTANGUb FRDM KB SUB-SEA NORrTH/BOUT 8615,00 8738,00 8892,00 9044,00 9119,00 9250,00 6509.44 6597,06 6707.72 6820,56 6892,21 6975.92 6427 44 6515 06 6625 72 6738 56 6810 21 6893 92 3496 24 N 3557 g6 N 4 3595,04 N 4 3638,47 N 415: 82,00 FT ~ON u. )INAT WEST 89 E 84 ~. FINAL WELb bOCATION AT TD: TRUE 8UB-SE~ MEASURED VERTICAL VERTICAb DEPTH DEPTH DEPTH 9250.00 6975,92 6893.92 HORIZONTAb DEPARTURE DISTANCE AZIMUTH Fg£T DEG MIN 5520.67 N 48 46 E D RECTIONAL. SURVEY . -. _. - _ ARCO ALASKA INC COMPANY . WELL -. - .. - 1 R- 14 . Ft ELD : KUPARUK - COUNTRY USA . . RUN ' ONE. _ '4' B~TE LOOOEB 'I2'AU0-85 REFERENCE 0000?0?49 ~. WELL: NAME: IR- 14 SURFACE ' ~" LOCATION: ..... :--".' . -. 1000 - ' . ' FSL,. 145' FWL, S17, T12N, RI UM - . VERTICAL PROJECTION . 90DO 40O0 50120 6000 iii i ! i I %t!-i 'i i ~ i ~ i i i. i i 1 i i I I i i t I ~ i i i I i i i I i [i 1 ' : ' , ' : ' ' i : ' ~ i i : I i i Ii ! i ii I ' i i I ' i ' !iii, iii i'l i I i ' I i. II ' z! ! ~ · ' ~ ' ~ ' : I i ! 1 ' : i i I · i .... ~,.. ~ · ~ .... ! I ! I '-~ ! : : : : : : , ! ! ~ ~ ' · · , , , ..~ ' ' ' - · - i .... : : t I i i I i i I ! · ---- -~I11 . , . . ~ ' ~~ :~'.:- : : : :- ~~~~~~ ~ ~~ L~ , :: ~ ~ ~,; : :. :. :._ ,. :. ::;.~~~~ , ~ ~ . , . :. . ! , i i ! ' ' ' ' ~ '-~ ~ · - ~ · · ~ .... ~ I : : : ; : : , ; : : ' ;~ . ~: : : ' ' : : : ' i , i ::::J : ....... : ~ : : : : ;-~~~~~ ~ i ~ i i i · '~ : : i i : i ~ i : ~ ~ : i ~ ~ ! : : :~: : ~ : i I i I i i i iii i ~ ! ! i i ! ~ : i~ ' ~ ~ I ~ i 1 ~ ~.~_, ~l'i~ ~D~:' ~ '.~ i;;;!,~;:; ', ~', iii ! ifil i il i H~-'~'~ii i ii~ ii ii t i~ m~ iii !!!._il !! !! ! ! ~.F;.F--i4-~..i--.,.-i.-+.%-.-.¢-+-~+. ~I~i~ : :: i: : ~i~!:: 'TT~j~F -:;74.-~F~-rS --H--H-+-~- H-~-i-h~-'Sift 1-~fiX::-'t-'J;L;%::.~L.L ::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::: : ' * ~ * * ~r:~-??--,--?-??-.-t t : / ~ f ~ I ~ : ~ * * ~ i : ~ : ' ' : [ ' ' HORI~ SCALE 1/lOOO IN/FT 'PROJECTION ON vERTICAL PLANE 47. - 227. SCALED IN VERT IC¢~. DEPTHS 7000 4T. 6OOO SURFACE LOCATION: 1ooo -1ooo -2000 HEST REF 0000'/0749 -- -" 8Ct:1g£ = 1/1000 IN/FT 516' FSL, 145' FWL, S17, T12N, Ri0E' UM ' . HORIZONTAL --:'O'ECTION -i"~. J · '" - . ,, !,,i . ~' ,~,, {~' ' ~ i Jill ilii Iii ,,,,, i'Ill i~, Jlii I i lli 1ii! IIII liti il ;'' , '' ' ' I "ilt Iiit iiii I III ilii !!I1 ........... , I1~ ii1! ,1i i,,, ~ii i!i llii II 1! i!i, i i 1. t i I i I i i i ! '!I I ii I!ii iiii II I II t I i ! 4" J J [ J ~l l i~T~ 1i 1 ~i + II : Iii ' I I i I I I I., i i I i I I!1! !!illiiii ' I'I' !i!'ii~'~ i '!_~ _ ,I 1t!i II ~111 iII~ · I-i .iii liii~ii..Li 1i Iii i! i!! ~ ~ ~.~I I ~ ~ ~ i Ii! I I ~..__., ,~ ! ! ! !~ !i$i 'Ill i~ ..... ~ii fill'''~'II I! iiF~-"~Ti:i ~ .... "~-'-~" ~'~"-*-'*'"~ ...... ~"~ -~-!-ii~ ~'!~'~'~~ -iii] /~ ~ Iltllili ~i..,~i ..... ~,,.~.i,.-1.,....~,.,4.,.i-i...&..-i.., i...~..-~, ,~ -~- . : - .. - . - ': ..... :~-~ ... ~;.- ~ . . . . : . . - ~: : i - ~ '. ? h :' - · - ~ .... :-.'_ :.2 ~ _ . .* - . . 6000 EAST -2000 - 1000 0 ! 01:8 2000 ~lO00 4000 SOO0 . _ . . .. _ .. : · . · . . . - ...,~.~ - .. . Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. O~PERATOR, 'WE]fL NIXIE AND NUMBER- Reports and Materials to be received by: Date Required Date Received Remarks C°mpleti°n Rep°rt sam'ples --7: ! Core Chips Core DescrSprSon Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports . Log Run Digitized Data ARCO Alaska, Inc. Post Office B~....~J0360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 13, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the August monthly reports for the following wells- 2A-15 3C-7 1R-14 6-9 (workover) L1-2 L3-5 2A-16 3J-1 1R-15 6-10 (workover) L1-14 WSP-4 3A-1 3J-2 1R-16 9-30 L2-20 WSP-6I 3C-4 1R-1 2Z-9 9-31 L2-24 WSP-20 3C-5 1R-2 2Z-10 11-9 (workover) L2-26 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L62 Enclosures RECEIVED Alaska 0i% & Gas Cons. gom~SS~'°n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO-,,,~IISSION MONTHLY RE ORT OF DRILLING AND WORKOVER OI ERATION$ wel~(~ Workover operation [] Drilling 2. Name of operator 7. Permit No. ARCO Alaska, Inco 85-151 3. Address 8, APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21386 4. Location of Well at surface 516' FSL, 145' FWL, See.17, T12N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 84' RKB ADL 25635 ALK 2568 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1R-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of August , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1900 hfs, 7/29/85. Drld 12-1/4" hole to 4640'. Ran logs. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 9175'. Ran logs. Continued drlg 8-1/2" hole to 9250'TD (8/6/85). Ran, cmtd, & tstd 7" csg. PBTD = 9139'. Secured well & RR ~ 1330 hfs, 8/7/85, 13. Casing or liner rpn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Cmtd w/215 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4603'. Cmtd w/1450 sx PF "E" & 350 sx PF "~'. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 9229'. Cmtd w/320 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/4639' - 115' FDC/CNL/SP/Cal f/9166' - 8600' DIL/SFL/SP/GR f/9166' - 4601' CET f/9110' - 115' GCT f/9110' - 115' 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---Report~n 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/MR01 Submit in duplicate ARCO Alaska, Inc. Post Office ~ 100360 Anchornge. Alaska 99510-0360 Telephone 907 276 1215 r. DATE: 08-30-85 TRANSMITTAL NO: 5317 RETU~ TO: ARCO ALAbKA, INC. KUPARUK OPERATIONS RECORDS CLERK t~TO-11 P.O. SOX 100360 ANCtlORAGE, AK 9951U ENGINEERING. TItANSHITTED tIERE~ITIi ARE TltL FOLLOWING ITEMS. ]<ECEIPT AND lkETUI{Iq ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE LIS TAPES AND ~.ISTING/SCHL/ONE COPY OF EACH 2Z-9 08-11-U5 RUN #1 3487.0-7357.0 REF # 70730 2~-10 0~-04-85 RUN #1 3790.0-7866.0 REF ~ 70712 3{--8 07-23-85 I{UN #1 5184.0-10065.5 REF # 70683 1R-16 08-19-~5 RUN #1 4062.5-8463.5 RhF # 70754 1R-15 08-12-85 RUN #1 3788.0-7442.5 REF # 70738 1R-14 08-06-85 RUN 4i2 4602.0-9158.0 REF ~f 70726 2A-16 08-18-85 RUN #1 8979.0-9789.5 R£F # 70753 2A-14 07-28-85 RUN ~1 7170'5-7871.5 R£F # 70705 2^-15 08-0~-85 RUN #1 7420.0-8142.0 REF # 70731 PLEASE ACKNOWLEDGE . RECEIPT ACKNOWLEDGLD: · DISTRIBUTION: UPAE DRILLING W. PASHER CURRIER. L. JohNSTON EXXON CI~EVRON [,~OB1 b PilILLIPS OIL N NSK CLEI<K J. RATIlHELL &_G~,s Cons. C, ommisS~on 501110 UNION K. TULIN/VAULT AflC'.';q AI.3~I~. I.r ~ ;~ .c;Ilbsidi~3r¥ O! /~llanticrl,~'hl.~ ' ' ; MEMORANOUM S'tate of Alaska TO: THRU: ALASKA OIL AND GAS CONSERVATION COMI~ISSION C. V rton DATE: Chaiinn~ .. : i ./- FILE NO: Lonnie C. Smith " ~:' Co--is s ioner TELEPHONE NO: August 7, 1985 D. HPd{. 48 . ," SUBJECT: FROM: Harold R. Hawkins Petroleum Inspector .;?;'/:~-' / BOPE Test ARCO, K.R.U. iR-14 Permit No. 85-151 Kuparuk River Field Friday~ August 2, 1985: I left AP, CO's 2Z-10 pad sub!ect of another report, t~ ~[RCO's KRU %R-14 well to witness a B.O.P.~. Test. I witnessed the B.O.P.E. Test and there were no failures. out an A.O.G.C.C. Report which is attached. I filled In summary, I witnessed the B.O.P.E. Test on ARCO's Well No. IR-t4 which Doyan 9 crew performed satisfactorily. Attachment 02-00IA(Rev. 10179) S"rAT OF ir,^$r4 ALASKA OIL & GAS CONSERVATION COMMISSION B,O,P,E, Inspection Report Loc,:~,~ ion: s e c/_7.... General Housekeeping~Rig BOPE Stack 11 Test Pressure Annular Preyed:teL C~oke Line Valves Kill L~ne' Valves ~:_~Ld_.~S v. ~ ~: em~V i ~ ua 1 Au d io Trip Pit Gauge ~ ~ ~ ...... Flow Monitor Oa~ Detector~ ACCUMULATOR SYSTEM ' Full Charge Pressure~~'f~ psig~ Pressure After Closure_ .,/~_ ~_ psig Pump incr, clo~, pre~. 200 psig'--'- Full Charge Pressure Attained: Controls: Master._._~/f Kel!y__~nd. Floor Safety Valves Upper Kelly: _~___Test Pressure .... Lower Kelly Teat ?ressure_ff_~?~_X: Ball Type _ ~est Pressure...~: ~o'g, Inside BOP Test Pressure~~___ Choke Manifold valves _ . No. f langes_..ff_ _~.___ Adjustable Chokes~~ rdrauicall, rated choke Test Pressure~~ ~ lest P, epair or Replacement of failed equipment to be made within ~ ' days and In~pectvr/ ~o~.m, ission office notified. ~/~ Distribution o-~i~--q-.- AO~O--------CC cc - Operator cc - Supervisor July 2, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 1R-14 ARCO Alaska, Inc. Permit No. 85-151 Sur. Loc. 516'FSL, 145'FWL, Sec. 17, T!2N, Rt0E, L~M. Btmhole Loc. 1090'FNL, 1066'FEL, Sec. 17, T12N, R10E, U~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the~regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~in Kuparuk River Unit 1R-14 -2- July 2, 1985 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. ~?aere 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver~l. truly yours, / Harry W. Kugier Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION b~ Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B~,...~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1R-14 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill a $100 application fee o Diagrams showing the proposed horizontal projections of the wellbore o A proximity plot ° A diagram and description of the system ° A diagram and description of the We estimate spudding this well on July questions, please call me at 263-4970. Si ncerely, Area Drilling Engineer JBK/HRE/tw PD/L112 Enclosures Kuparuk 1R-14, along with and vertical surface hole diverter BOP equipment 19, 1985. If you have any RECEIVED JUN 2 8 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION C~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL FXI× REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I~ SINGLE ZONE ~ MULTIPLE ZON E<t~] 9. Unit or lease flame Kuparuk R~ver Unit 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 516' FSL, 145' FWL, $ec.17, T12N, R10E, UH At top of proposed producing interval 1386' FNL, 1393' FEL, Sec.17, T12N, R10E, UH At total depth 1090' FNL, 1066' FEL, Sec.17, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 84', PAD 47' ADL 25635 ALK 2568 10. Well number 1R-14 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. P r o p O~J- d ~p-t~-'(~-D- ~1- V D ) 9121' MD, 6936' TVD fe~t 14. Distance to nearest property or lease line 1066' @ TD feet 17. Number of acres in lease 2560 15. Distance to nearest drilling or completed 1R-13well 45' @ 1037'TVD feet 18. Approximate spud date 07/19/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2885 KICK OFF POINT 650 feet. MAXIMUM HOLE ANGLE 45 oI (see 20 AAC 25.035 (c) (2) 3312 psig@ 80°F Surface psig@ 6b, 94 ft. TD (TVD) 21 ! Proposed Casing, Liner and Cementing Program ~ SIZE SETTING DEPTH QUANTITY OF CEMENT i Hole 24" r:l 2-1/4" Casing 16" Weight 9-5/8" 62.5# 36.0# 18-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade I C°uplingl Length H- o / Weld l / I-"/HF-ETW RTe/ 9087' M D TOP TV D 80' 35' I 35' I 35' 35' t 34' I 34' MD BOTTOM TVD 1151 115' 4692~ 3800' I 9121~ 6936' I I (include stage data) + 200 cf 1450 sx PF "E" & 350 sx PF "C" 270 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9121' MD (6936' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thePeafter. Expected maximum surface pressure is 2885 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 1R-14 will be 45' away from 1R-13 at IO~?¥D. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certify~t the foregoing is true and correct to the best of my knowledge // TheSIGNEDspaceb-~-o',~H~/- - r'~o~n~sCn ~/ _ _ TITLE Area Drilling Engineer DATE CONDITIONS OF APPROVAL Samples required Mud log required I DirectionaI Survey required ~ APl number ~YES ~O ~YES ~O I] ~S ~NO I Approval date Permit number ~~ / ~~~~ I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY _ ,COMMISSIONER DATE3u1~ 2, 1985 by order of the Commission Form 10401 (HR~PD/PD112 Submit in triplicate PERMIT TO DRILL 1R-14 (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" x 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED j U N 2 8 ~s~ u~t ~ Gas Cons. Commission AnChorage HORI' 'NTAL PROJECTION ..... S~"~LE ! I N. = ! 000 FEEl' "'--~. ........... 500Q.. ..... 3000_ _ 1 000: _ 1000 . EASTHAN klHiPSTOCK. 1R, k'ELL NO, 14 PROPOSED KUPARUK FIELD. NORTH'SLOPE. ALASKA .: INC. : WEST'EAST ·I . 1000 0 1000 2000 ' 3000 4000 I TARI~:T CENT~ : TVD-6592 - OEP-SI 40 - (L,I)G~I NG PT--*) ~ 3~o' F#L:. t 32o' FL=I. NORTH 3444 - EAST' 38'15 $000 I SURFACE LOCATION, SEC. IT. Tt2N. tOE Iq 47 DEC 51 40' (TO 56 MINE TARGET) RECEIVED jUN 2 8 ~S85" ~ ~ Alaska~ Oil &_ Gas _Cons..,_ eommissi°n 'Anchorage ,- PAD- 1IR. 14 NO~ 14, PROPOSED K~ARUK FIELD, NORTH SLOPE, ALASKA EAJTJI~I~I- I,IHiPSTOCt~J. I, NC. KOP' TVD""650 THD'6$0 DEP'O ..................... ~ UONU SNDS TVD-2734 T~ 3186 DEP 129~ . .......... . . ~'T TVD-~800 T~-4692 DEP 2354 AVERAGE _ANGLE .... 44. DEG. 55 ,I..N ...... TVD-6686 TI"ID-8768 DEP-5233 ~,, '"~,, TVD-6794~ THD-8921 DEP-5341 '"'-- TVD-6936 Tt'ID"9121 DEP-5482~ TOP LOI,/R SNDS BASE KUP SNDS TD (LOGG]:NG PT) 1000 =ooo =ooo vE.,~c^L sEc,~o,- ElY JUN 2 8 !985 ~iaska Oil $ ~as Cons. GOmmission Anchorage NO'RTH 0 I00 '00 _ ~00 _ SOO _ 4'00 _ 300 _ 200 _ lO0 200 300 400 I I I I 3 2 · I ! . /",'o, : / /,,,, 500 I 8383 83O2 3302 . 28T? 60O 3055 3141 3223 33?8 700 I AR'CO ALASKA, INC. PAD 1R~ WELL N.O~ 13"14-15-16 PROPOSED tKUP^EUK FIELD. 80E78 SLOPE. tEASTHAN WHIPSTOCK. INC. ;NOTE~ WE~L PATHS EXTEND BEYOND THIIS VIEWING 'WINDOW . .800 I .. 900 = 1000 3684 · · o · SurFace ].6" -~.000 psi T~nkco st~ing head. Tankco quick connect assy. I6' x ~0' ZOO0 ps~ double s=ud~ed adap~e~. 20' 2000 psi ~rtlling. spool w/lO' side outl e~. · ~0' b~ll. valves, hydraulically actuated, w/20' lines to ~se~/e pit. Valves ~ open ~uto~icmlly upon closure of annular p~vencar. ZO" ZOO0 psi annul~'p~venCer. ~0" bell nipple. . Mmt ntenmnce & oDermti on, Upon tntttml tns~llation close annular preventer and verify that ball valves have opened properly. Close annular preYenter and blow air through dtverter lines 'every 12 hours. Close-annular preventer in the event-that gas or fluid flow to surtrace is detected. If necessary, manually ovem-tde and close ball valve to ugwind divertar line· Do not shut in well under any ¢trcu~tances. Conductor · RECEIVED JUN 2 8 A!aska Oil & Gas Cons. Commission Anchora~ L U 5 . 3 2 DIAGRAM #1 13-5/-~-~5000 PSI RSRRA BOP STACK I. 16' - 2000 PSI TAttOO STARTING HEAD 2. 11 · - 3000 PSI CASING HF_AD 4. 13--5/8" - 50(30 P<3I PIPE 5. {3-5/8' - 5000 PSI B~ILLING SPOOL W/Q-~ ANO KILL 6. {3-5/8' - 5000 PSI ~E R/~ W/PIPE ~ ON TOP, 7. 13-5/8' - 5000 PSI A~ ACCt. NtJLATOR CAPACITY TEST I. CMEC~( AhD FILL A(X~TOR RESERVOIR TO P~ LEVEL WITH HYDRAULIC FLUID. 2. A~ THAT ACCt~T~R P~ESSI~ IS 5000 PSI WITH 1500 PSI ~TREAM OF THE RE(~JLATC~. 3. O~VE TIN~, T~ CLOSE ~ ~ITS SIXThlY ~~ ~ ~ ~T, ~ A~T~E L~ LI~IT IS ~5 ~~ ~I~ TI~ ~ ~2~ PSI ~INI~ 13-5/8'" BOP STACK TEST I. FILL BOP STACK AhD Q4OKE MANIFOLD WITH ARCTIC DIESEL. 2. CIE(:]< THAT ~ L~ ~ ~ IN ~~ ~Y ~RA~. ~T T~T ~ IN WI~ ~I~ ~ ~ ~ IN L~ S~. 5. ~ ~ ~ ~ ~ KILL ~ ~ LI~ V~VES ~~ TO B~ STA~ ~L V~S ~ ~S ~~ ~. 4. ~~ ~ TO ~~ F~ I0 MIN. ~ ~~ T~P~~ ~ F~ I OMIN. ~ ~~ TO ~ 5. ~ ~ P~~ ~ ~ K2~ ~ ~E LI~ VALVES. ~ T~ PI~ ~ ~ ~ VALVES 6. TEST TO 2~ PSI ~3~ PSI~S IN ST~ 4. T. ~2~ TESTI~ AL~~LI~S, ~ ~S WI~ A ~ PSI L~ ~ 3~ PSI H]~. TEST AS S~ 4. ~ ~T ~~ TEST ~ ~ ~T IS ~T A ~L ~I~ P~ITIVE ~ ~. ~Y ~I~ TEST ~S ~T ~ ~T ~LY ~E. 8. ~ T~ PI~ R~ ~ ~ BO~ PI~ TEST BO~ PIPE ~ TO 2~ PSI ~ ~ PSI. 9. ~ BO~ PI~ R~, BA~ ~ ~I~ ~ ~L ~ ~ ~E. I0. ~ ~I~ ~ ~ TEST TO 2~ ~I ~ PSI. I.. ~ ~I~ R~ ~ ~RI~E TEST ~. ~ S~ ,~IF~--~ .LI~S ~ ~L ~-~~I~ ~UID.' ~ A~ 'VALVES IN ~I-LLI~-P~.ITI~, 2. - TEST ST~I~ VALVES, K~Y, K~- LY ~S, .~I~ PI~ S~E~ VALVE, ~ I~I~ 8~ TO ~ PSI 3~ PSI. 13. RE~ TEST I~TI~ ~ ~~ P~~ TEST F~, SI~, ~ ~ TO ~ILLI~ ~IS~. 14. P~~ ~ETE B~ ~ST ~ NI~I~ ~ A~ ~Y TH~~ ~I~LLY ~TE B~ DAILY. RECEIVED Alaska Oil & 6as Cons. Commission Anchorago 510084001 REV. 2 MAY 15.1985 ARCO Alaska, In¢ Post office'%o-o~( 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 1R Pad Wel 1 s 1-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRU6/L115 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany i i ii i i , ......J- WELL I ......' ¥-' 5,991,050.09 Let. = 70°23'11.370" X = 539,829.76 Long.= 149o40'$3.808" ~ SEC. 20 -- 154'FNL, 139'FWL N O R T H VE' I' LL 2 Y= 5,990,990.16 L~. = 70°23'10.78l" X; 539~829.82 Lon~. = 149°40'33.816" '~ SEC. 20-- 214'FNL, 138'FWL * WELL 3 Y= 5,990,930.24 Lat = 70°23'10.192" I X : 539,829.78 Long,: 149°40'33.826" i SEC. 20 -- 274'FNL~ 138'FWL .~,2 II ~ WELL 4 Y= 5,990,870.26 Lot. = 70023'09.602 i ' X= 539~829.77 Long. = 149°~'33.836" ii : I 14~/ SEC. 20 -- 334' FNL, 137' FWL ,o ,. WELL 5 ~=5.~0.570. z~ L,t. = 70°2~'09.~2°" 9 16~ X= 539~469.75 Long.= 149°~'44.377" ' SEC. 19- 332'FNL, 225'FEL i WELL 6 Y= 5,990,930.21 Lot. : 70°2~'10.zi0'' I X= 539~469.74 Long. = 149°~'44.368'' I SEC. 19 -- 272' FNL~ 222'FEL ' : WELL 7 Y= 5,9~0,990.23 Let.-: 70°23'10.800'' ~ X = 539~9.76 Long.: 14g°~'~.358" SEC. 19 ~ 212' FNL~ 222'FEL ' ~'.s~o~ WELL 8 Y=~,~,o~o.~o L~. = ~0°2~'~.~0" X = 539,469.73 Long.: 149°40'~.350" I . s c.,e- ,~ - - WELL 9 Y= 5,991,600.16 Let. = 70°2~'16;8~'' :~7 i ' ]a~ X: 5~9,~9.91 Long.= 149°40'44.259 ' SEC. 18 -- 398' FSL, 216'FEL ~ ,~ WELL 10 y= 5,99i,~60.~1 L,t. = 70°2~'i7.3a9" ~ ~ X = 559,469.82 ~ng.: 149°40'~.253" ,iSEC. 18 -- 458' FSL~ 216'FEL ~ , I WELL ii Y= 5,991,720.17 L~t. : 70°23'17.980'~ ~ ~ ~ , ~ X = 539,~9.81 Long.: 149°~'44.2~4" I 1 ~ SEC. 18 -- 518' FSL, 215'FEL : WELL 12 Y: 5,991,780.16 ~t. = 7~25'18.570" X = 539~469.78 Long. = 149°40'44.2~5" SEC. 18 -- 578' FSL~215'FEL DRILL SITE IR ,c,,,: ,"=~oo' WELL 13 Y= 5,991,780.16 Lat. : 70°2~'18.551" .... X: 539,829.7~ Long.: 149o40'33.695" AS-BUILT CONDUCTOR L~ATIONS SEC. 17 -- 576'ESL, 145'F~ WITHIN SECTIONS 17,18,19 a 20, TI2N,RIOE,U.M. WELL i~ Y=5,991,720.13 Lot. = 70°2~'17.961 X = 5~9,829.71 Long.= 149°40'33.705" NOTE: SEC.17 -- 516' FSL, 145'FWL COORDINATES ARE ALASKA STATE PLANE, ZONE 4. WELL 15Y: 5,991,660.19 Lat. SECTION LiNE DISTANCES ARE TRUE. X= 539,829.71 Long.=-149°40'33.715'' HORIZONTAL ~ VERTICAL POSITIONS PER L.H.D. SURVEYORS, SEC. 17 -- 456'FSL, 144'FWL DOCUMENT N0.129:NI9+69 NI7+25 WELL 16 Y=5,991,600.20 Lot. = 70°23'16.781" E 9+56 a E 15+25 X = 539~829.77 Long.= 149°40'33.722" EL.50.39 EL.38.75 SEC. 17-- 396'FSL, 144'FWL i CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND ~~~ ~ - SURVEYING IN THE STATE OF ALASKA ~D THAT _. ' THIS PLAT REPRESENTS A LOCATION SURVEY ~~,''"'t'''. ~.0 [~' MADE BY ME OR UNDER MY SUPERVISION ~ AND ~ '~i;~' - ............. ~. ~-~..,-.'.--..'-~;.. · ..11SURVEYEDFOR: ARCO Aloske, Inc IEll. ~DATE MAYg,Ig851 ": ;,'-. = ~Rfl~, ,.~ .~ ~.o.s. ol- esi SERVICES ~-,,:,,~ ,~, ~ ,.. I, ~_..~ ...~ ~.:~!?"~ECK!~'ST "FOR NEW' WELL PERMITS. ...... ' ~ ::':'~ .... Company ITEM. APPROVE DATE (2) Loc' g (~ thru8) (3) Admin(~/_.o~ ~v~'~..~ 9. ru 12) 10. 11. (16 and 12) 12. 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 ..... iilli 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 .................... Lease & Well No..' YES NO REMARKS . (13 thru 21) (22 thru 26) 13. 14.. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 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 sur~;ce ] i]... 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 adequat'e safety in collapse, tensi~n'i~ bu[st'. 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 attach;~ .... i Does BOPE have sufficient pressure rating - Test to_~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. AdditiOnal requirements ............................................. Additional Remarks: O H O H Geolo : WVA JAL _Engineering: LCS -- BEW~ MTM~HJH/ 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. N - 04A PRUDHOE BAY ; ~ :~ . i~; :::: ::::::::::::::::::::::::: ....... . .............. ......... ,..= ....... , .... ~.. .9 .... ,...0- ===================================== ::::::::::::::::::::::::: ~::::::: --**-t--; .......... ::::::::::::::::::::::::::::::::::::: -;;:% ...... Run 1' 12 - July - 1996 CNIGR Cased Hole WESTEI?A~I ATLAS 10403' Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING N-04A 500292139200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 07-AUG-96 2373.06 R. ECK M. MARTIN 8 llN 13E 1804 560 80.81 79.80 43.30 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 9871.0 47.00 7.000 10610.0 26.00 5.500 9566.0 17.00 4.500 10130.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 07-JUL-85 SWS BASELINE DEPTH 9845.0 9897.0 9898.0 9899.0 9900.0 9910.5 9911.0 9912.0 9913.0 9934.5 9938.5 9939.0 9940.0 ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 9846.5 9898.5 9899.0 9900.0 9900.5 9913.5 9914.0 9914.5 9915.0 9936.5 9941.0 9941.5 '9942.0 9941.0 9943.5 9957.0 9964.5 9965.5 9968.0 9969.0 9971.0 9971.5 9982.0 9982.5 9983.0 9985.0 9988.0 9989.0 9991.5 10019.5 10029.0 10029.5 10037.0 10038.0 10071.0 10072.0 10079.5 10103.0 10127.5 10157.0 10264.5 10267.0 10268.0 10268.5 10275.5 10276.0 10293.5 10294.5 10330.0 10331.0 10358.5 10359.0 $ REMARKS: 9943.0 9947.0 9960.5 9967.0 9967.5 9970.0 9970.5 9972.5 9973.5 9984.0 9985.0 9985.5 9987.0 9990.0 9990.5 9993.0 10019.0 10028.5 10029.5 10037.0 10037.5 10070.5 10071.0 10078.5 10103.0 10128.5 10156.5 10264.0 10266.5 10267.0 10268.0 10275.0 10276.0 10293.5 10294.0 10330.0 10331.0 10356.5 10357.0 CN/GR (Cased Hole). TD TAGGED AT 10405 FT / 2.75 IN. TOOL USED. WELL WAS SHUT-IN BEFORE LOGGING. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAM]4A RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH lA. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: i START DEPTH STOP DEPTH 9800.0 10394.0 9800.0 10403.0 BASELINE DEPTH NPHI 9845.0 9846.5 9897.0 9898.5 9898.0 9899.0 9899.0 9900.0 9900.0 9900.5 9910.5 9913.5 9911.0 9914.0 9912.0 9914.5 9913.0 9915.0 9934.5 9936.5 9938.5 9941.0 9939.0 9941.5 9940.0 9942.0 9941.0 9943.0 9943.5 9947.0 9957.0 9960.5 9964.5 9967.0 9965.5 9967.5 9968.0 9970.0 9969.0 9970.5 9971.0 9972.5 9971.5 9973.5 9987.5 9989.0 10019.5 10019.0 10029.0 10028.5 10029.5 10029.5 10037.0 10037.0 10038.0 10037.5 1007'7.0 10077.0 10103.0 10103.0 10127.5 10128.5 10157.0 10156.5 10264.5 10264.0 10267.0 10266.5 10268.0 10267.0 10268.5 10268.0 10275.5 10275.0 10276.0 10276.0 10293.5 10293.5 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH - 10294.5 10330.0 10331.0 10358.5 10359.0 $ RENARKS: 10294.0 10330.0 10331.0 10356.5 10357.0 PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCHIB. OUT $ CN : BP EXPLORATION WN : N - 04A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH 2418 68 i GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 i CPS 4 4 NUCT 2418 68 i CPS 4 5 TENS 2418 68 i LB 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 i 2O * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 30 Tape File Start Depth = 9795.000000 Tape File End Depth = 10405.000000 Tape File Level spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7327 datums Tape Subfile: 2 230 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: i START DEPTH STOP DEPTH 9800.0 10394.0 9800.0 10403.0 BASELINE DEPTH GRCH 9853.5 9854.5 9859.0 9860.0 9872.5 9874.0 9900.5 9902.0 9901.0 9901.5 9902.5 9903.0 9906.5 9907.0 9908.0 9911.0 9913.0 9916.0 9916.0 9918.5 9917.0 9919.5 9919.0 9921.0 9919.5 9922.0 9923.0 9924.5 9929.0 9929.5 9931.5 9930.0 9932.5 9940.0 9942.5 9940.5 9943.5 9941.0 9944.0 9943.5 9947.0 9947.5 9949.5 9961.5 9965.0 9962.5 9965.5 9964.5 9967.5 9965.5 9968.0 9968.5 9971.0 9969.5 9971.5 9972.5 9974.5 9973.0 9975.5 9973.5 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 9903.0 9903.5 9904.0 9905.0 9908.5 9910.0 9922.0 9924.5 9925.0 9925.5 9930.0 9947.0 9949.0 9975.5 9978.5 9979.0 9979.5 9980.5 9991.0 9992.0 9992.5 9995.5 9997.0 10018.5 10024.5 10038.0 10038.5 10042.5 10056.5 10060.0 10060.5 10071.0 10078.0 10079.0 10080.5 10081.0 10085.0 10093.5 10102.5 10103.0 10105.0 10105.5 10109.0 10110.0 10111.0 10120.5 10121.5 10124.0 10125.5 10130.5 10131.0 10134.5 10135.5 10140.0 ~o15o.5 10153.5 10154.5 10183.5 10196.0 10198.0 10226.5 10230.5 10231.5 10238.5 10239.5 10240.0 10267.0 10267.5 10268.0 10278.5 10288.0 10289.0 10290.0 10291.5 9993.5 9994.0 10018.5 10038.0 10039.0 10070.5 10084.5 10094.0 10105.5 10106.5 10121.5 10122.0 10124.5 10126.5 10131.5 10132.5 10141.5 10151.0 10154.0 10154.5 10183.5 10196.5 10198.5 10266.5 10267.0 10268.0 10278.5 10288.5 10289.5 10290.0 10291.5 9980.5 9981.5 9982.0 9982.5 9993.0 9993.5 9994.0 9996.5 9998.0 10023.0 10043.0 10057.5 10060.0 10060.5 10077.5 10078.0 10079.5 10080.5 10102.5 10103.0 10110.0 10111.0 10111.5 10135.0 10135.5 10226.5 10231.5 10232.5 10239.0 10240.0 10241.0 10292.0 10292.5 10298.0 10301.0 10301.5 10302.5 10316.0 10317.5 10332.5 10356.0 10364.0 10385.0 10388.5 10390.5 10395.0 10395.5 $ REMARKS: 10292.0 10292.5 10298.0 10302.0 10302.5 10303.5 10315.0 10317.5 10332.5 10332.5 10354.5 10354.5 10362.5 10362.5 10385.0 10385.0 10388.5 10388.5 10389.0 10389.0 10393.5 10393.5 10394.0 10394.0 PASS 2. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH2A. OUT /??MATCH2B. OUT $ CN : BP EXPLORATION WN : N - 04A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units I GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 i CPS 5 TENS 2418 68 i LB Size * DATA RECORD (TYPES 0) Total Data Records: 30 1014 BYTES * API API API API Log Crv Crv Length Typ Typ Cls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 20 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 9795.000000 10405.000000 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7327 datums Tape Subfile: 3 177 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9800.0 10394.0 9800.0 10403.0 BASELINE DEPTH 9854.0 9859.5 9871.0 9896.0 9897.0 9897.5 9898.5 9899.0 9899.5 9900.5 9902.5 9905.5 9912.0 9912.5 9916.5 9917.0 9918.0 9919.0 9919.5 9927.5 9928.0 9929.0 9929.5 9930.0 9946.0 9948.5 9949.5 9952.0 9953.0 9953.5 9957.5 9958.5 9964.0 9965.0 9967.5 9968.5 9973.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH NPHI 9855.5 9855.5 9861.0 9861.0 9873.0 9873.0 9898.0 9898.0 9898.5 9898.5 9899.0 9899.0 9899.5 9899.5 9900.0 9900.0 9901.0 9901.0 9902.0 9902.0 9904.5 9904.5 9908.0 9908.0 9914.5 9914.5 9915.5 9915.5 9918.5 9918.5 9919.0 9919.0 9919.5 9919.5 9920.5 9920.5 9921.5 9921.5 9929.5 9930.5 9931.5 9932.5 9930.0 9950.0 9951.5 9953.0 9955.5 9956.0 9957.0 9961.0 9961.5 9967.0 9967.5 9970.0 9970.5 9975.0 9973.5 9976.5 9983.0 9984.0 9991.5 10017.5 10018.5 10019.5 10020.5 10030.5 10031.0 10038.5 10058.5 10059.5 10060.0 10071.0 10080.0 10080.5 10081.5 10087.5 10088.5 10089.5 10091.5 10093.0 10101.5 10107.5 10110.0 10114.0 10114.5 10116.5 10117.0 10123.5 10125.5 10129.0 10129.5 10130.0 10133.0 10135.0 10136.0 10136.5 10137.5 10138.0 10153.0 10155.0 10159.0 10165.0 10167.0 10167.5 10177.0 10178.0 10180.0 10180.5 10182.0 10199.0 10199.5 10211.0 10218.5 10230.0 10239.5 10265.0 9976.0 9985.5 9986.0 9993.5 10018.5 10019.5 10020.0 10030.0 10031.0 10038.5 10070.5 10081.0 10089.5 10091.5 10093.5 10102.0 10108.5 10111.0 10117.5 10124.0 10126.5 10138.5 10153.0 10155.5 10159.5 10164.5 10166.5 10167.5 10177.0 10177.5 10179.5 10180.5 10182.0 10265.5 9979.0 10016.5 10038.5 10057.5 10058.5 10059.5 10079.5 10080.5 10081.5 10088.5 10089.5 10090.0 10114.5 10117.5 10119.5 10130.0 10130.5 10131.5 10134.5 10135.5 10136.0 10136.5 10137.0 10137.5 10199.5 10200.0 10211.0 10218.5 10230.5 10239.0 10266.0 10266.5 10267.5 10269.0 10274.0 10277.5 10278.5 10279.0 10288.5 10289.0 10290.0 10290.5 10291.0 10291.5 10294.5 10297.0 10299.0 10299.5 10300.0 10315.5 10316.0 10317.5 10338.5 10355.0 10355.5 10356.0 10358.0 10359.0 10360.0 10360.5 10385.5 10386.0 10390.5 10395.0 10395.5 $ 10266. 10267. 10268. 10269. 10277.5 10278.0 10278.5 10289.0 10289.5 10290.0 10290.5 10291.0 10291.5 10294.5 10316.0 10318.0 10354.5 10384.0 10385.0 10389.0 10393.5 10394.0 10274.5 10279.0 10297.0 10299.0 10300.0 10300.5 10316.0 10338.5 10353.0 10353.5 10354.5 10356.5 10357.0 10358.0 10358.5 PASS 3. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH3A. OUT /??MATCH3B. OUT $ : BP EXPLORATION : N - 04A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: AP1 AP1 AP1 AP1 Name Tool Code Samples Units Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-$ 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 i LB * DATA RECORD 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 2O (TYPES 0) 1014 BYTES * Total Data Records: 30 Tape File Start Depth = 9795.000000 Tape File End Depth = 10405.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14654 datums Tape Subfile: 4 196 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass i gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ CN : BP ExpLORATION WN : N - 04A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 2 NPHI CNAV 68 1 PU-S 3 FUCT CNAV 68 1 CPS 4 NUCT CNAV 68 I CPS 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 25 Tape File-Start Depth = 9795.000000 Tape File End Depth = 10405.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13433 datums Tape Subfile: 5 48 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: i DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9800.0 2418 9800.0 $ LOG HEADER DATA STOP DEPTH 10408.0 10410.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CCL PCM GR CN $ SWIVEL CASING COLLAR LOCATOR PULSE CODE MODULATOR GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 12-JUL-96 ECLIPSE 2.2 1051 12-JUL-96 10566.0 10405.0 9800.0 10403.0 1800.0 YES TOOL NUMBER 3913XA 8248EA 8250EA 8262XA 2418XA 0.000 10610.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 9100.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1600 NEAR COUNT RATE LOW SCALE (CPS): 800 NEAR COUNT RATE HIGH SCALE (CPS): 16800 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : N - 04A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 -68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MI~ 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 4 4 42 635 99 1 36 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 98 Tape File Start Depth = 9800.000000 Tape File End Depth = 10410.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 39065 datums Tape Subfile: 6 Minimum record length: Maximum record length: 174 records... 62 bytes 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9800.0 2418 9800.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL CCL PCM GR CN $ STOP DEPTH 10403.0 10410.0 CASING COLLAR LOCATOR PULSE CODE MODULATOR GAMMA RAY COMPENSATED NEUTRON 12-JUL-96 ECLIPSE 2.2 1120 12-JUL-96 10566.0 10405.0 9800.0 10403.0 1800.0 YES TOOL NUMBER 3913XA 8248EA 8250EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10610.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 9100.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 1600 NEAR COUNT RATE LOW SCALE (CPS): 800 NEAR COUNT RATE HIGH SCALE (CPS): 16800 TOOL STANDOFF (IN'): 0.0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : N - 04A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 i PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 i LB 9 TEN 2418 68 i LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 4 4 42 635 99 1 36 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 98 Tape File Start Depth =' 9800.000000 Tape File End Depth = 10410.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 37844 datums Tape Subfile: 7 Minimum record length: Maximum record length: 174 records... 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9800.0 2418 9800.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10410.0 10410.0 12-JUL-96 ECLIPSE 2.2 1145 12-JUL-96 10566.0 10405.0 9800.0 10403.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CCL PCM GR CN $ SWIVEL CASING COLLAR LOCATOR PULSE CODE MODULATOR GAMMA RAY COMPENSATED NEUTRON TOOL NUMBER 3913XA 8248EA 8250EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10610.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 9100.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): M3%TRI X: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 1600 NEAR COUNT RATE LOW SCALE (CPS): 800 NEAR COUNT RATE HIGH SCALE (CPS): 16800 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN : BP EXPLORATION WN : N - 04A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 4 4 42 635 99 1 36 * DATA RECORD (TYPE# 0) Total Data Records: 98 1006 BYTES * Tape File Start Depth = 9800.000000 Tape File End Depth = 10410.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 63476 datums Tape Subfile: 8 Minimum record length: Maximum record length: 174 records... 62 bytes 1006 bytes Tape Subfile 9 is type: LIS 01 **** REEL TRAILER **** 96/ 8/ 8 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu $ AUG 96 10:38a Elapsed execution time = 16.32 seconds. SYSTEM RETURN CODE = 0 LiS TAPE V~ R-I FIC. ATIO.~ LI S'T IN.G' LVP 010.HOZ VEPI¢ICATI3N LISTING PAGE I ** TAPZ HE~DER ** S~F,V~.C~ NA~,~ :EDIT .DATE :a5/08/ 9 ORiGiN :OOD0 ~TAPE N~M~ :0726 C~NTiN~ATI2N .~ :Ol ~ :R,~ iCeS TtP:E : GMMEN'TS :L!~R,~RY TA -,-.,- :NFSR!4A"T!ON REC3R'DS ~ 0O0 0'00 O0"T 0'--~ 5 0 0:'0 0'90 '0'0:"~,. :06 5 000 000 00~ 0'65 O,.O,O O....O.;O: 002 '0'0'0 0'0"0' 012 0"~5 0,0.0 O. ~0' 0':0~.6 OOO 000 0.04~ 06.5 UN'IT TYPE CATE SIZE CODE : ALASK~ C~PUTZN.S CEN'TER ~ = ~TLANTZ2 R,ZCHFZ~L~ COMPANY .. '.Y. ?.'E. F"L.U'Z g. tN~M' S,:RVI'CE S~RVICE UNiT A~i ,~Pi APl lP'l FIL~E ,~Iz.= ~ ~. REPR PROCESS ?~'~ ORDER ~ LnG TYPE CLASS ~OD NO " O~iMM O0 220 Sm.MM GO .120 OM. 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