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196-177
STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations E Fracture Stimulate r Pull Tubing Fi Operations Shutdown 1— Performed: Performed: Suspend E Perforate E Other Stimulate E Alter Casing F Change Approved Program Plug for Redrill Perforate New Pool I- Repair Well F Re-enter Susp Well E I- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory E 196-177 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22719-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 28243 KRU 1 C-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 17096 feet Plugs(measured) None true vertical 6805 feet Junk(measured) 16520 Effective Depth measured 16680 feet Packer(measured) 16216, 16321 true vertical 6532 feet (true vertical) 6280,6329 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 121 121 0 0 SURFACE 10182 9 5/8 10223 4539 0 0 PRODUCTION 16442 7 16480 6411 0 0 LINER 775 5 17096 6805 0 0 Tie-Back Liner 16175 5 1/2 16212 6278 : tAkP gA ,. RECEIVED Perforation depth: Measured depth: 16663-16727 True Vertical Depth: 6522-6562 JAN 2 7 2016 Tubing(size,grade,MD,and ND) 3.5, L-80, 16337 MD,6336 TVD .BOG CC Packers&SSSV(type,MD,and ND) PACKER: Liner Top Packer 16321=MD,6329+TVD, PACKER: FH Packer 16216=MD,6280=TVD SSSV:NONE 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 Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 86 bopd 245 MSCFD 1714 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations f........ Exploratory E Development F Service r Stratigraphic fl Copies of Logs and Surveys Run E 16.Well Status after work: Oil F Gas fl WDSPL Printed and Electronic Fracture Stimulation Data GSTOR WINJ r WAG E GINJ I SUSP [ SPLUG E 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: 315-700 Contact Theresa Lee@263-4837 Email Theresa.M.Lee@cop.com Printed Name Theresa Lee 2� /-_ Title Wells Engineer Signature , 7 41,1/% / rest LC Phone:2634837 Date (64//4, vii 2fig//G Form 10-404 Revised 5/2015 RBDMS LL JAN 2 7 2016 Submit Original Only KUP PD • 1C-12 ConocoPhithhps 4 t Well Attribut Max Angle TD • 121S r3 I7't; : Wellbore APVUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) C000ditMips" 500292271900 KUPARUK RIVER UNIT PROD 76.64 11,193.86 17,096.0 ° ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-12,1/21/20164:00:33 PM SSSV:NONE 35 11/10/2014 Last WO: 1/4/2016 46.91 12/10/1996 Vemoal scherenhc(actual) ALnasntoTtaatigon r_. •._ End•.- 1 1 Annotatio: • 016 BY HANGER;36.9 ringS XO Reducing;40.0 • •DD::::::: •,•° a r • r I.1 •• Depth : 1 - Depth • 1 • . Grade •• • • I �iCasingDescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...W6Len(I...Grade Top Thread 1 If J SURFACE 95/8 8.835 41.0 10,223.3 4,539.5 40.00 L-80 BTC AAI� �l��l^Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread coNouc?ors;4s.a1z%o I ;III PRODUCTION 7 6.276 38.5 16,480.0 6,411.5 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I. LINER 5 4.276 16,321.5 17,096.0 18.00 L-80 LTC Liner Details I Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 16,321.5 6,328.7 61.40 PACKER LINER TOP PACKER w/TIE BACK SEALS 5.000 GAS LIFT;3,1173 16,335.4 6,335.4 60.91 HANGER BAKER LINER HANGER 5.000 16,342 2 6,338.7 60.64 PBR BAKER PBR 4.000 I'I Tubing Strings GAS LIFT;7,121.9 Tubing Description String Ma...I ID(in) Top(ftKB) Set Depth(ft..I Set Depth(ND)(...Wt(lb/ft) Grade /Top Connection ' 2-7/8"TUBING RWO 2 7/8 2.441 36.9 16,172.4 6,261.0 6.50 L-80 EUE 8rd Mod 2016 Completion Details Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 36.9 36.9 0.00 HANGER FMC Tubing Hanger,TC-1A-EN,6"x 3-1/2"EUE 8rd Box 2.992 x Box,3"ISA BPVG 40.0 40.0 0.00 XO Reducing Crossover,3-1/2"EUE 8rd Mod Box x 2-7/8"EUE 8rd Pin 2.441 SURFACE;41.0.10,223.3-. 16,152.0 6,252.3 65.23 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 5.68') 2.390 GAS LIFT;10,604.0 16,153.0 6,252.8 65.20 SEAL ASSY Seal Assembly,80-32 2.370 I -I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)I..Wt(lb/ft) Grade l Top Connection 5-1/2"LINER RWO 51/2 4.950 36.9 16, 21231 6,278.31 15.50IL-80 IHydril 563 2015 GAS LIFT;12,978.2 Completion Details I4 I Top(ftKB) Top(NO)(ftKB) Top Incl(') Item Des Com Nominal ID (in) 36.9 36.9 0.00 LINER Casing Cut Joint,5-1/2",15.56,L-80,Hydril 563 Pin 4.950 (34.77') GAS LIFT;14,851 7 1 I :� 16,158.2 6,254.9 65.07 XO Reducing Crossover Coupling,5-1/2"BTCM Box x 4.094"National 3.380 Box 16,159.2 6,255.4 65.05 SBE Seal Bore Extension(SBE),80-32,4.094 National Pin x 3.250 Pin GAS LIFT;76,100.0 16,178.7 6,263.6 64.57 XO Reducing Crossover,4.094"National Box x 2-7/8"EUE 8rd Pin 2.440 ,11 16,189.6 6,268.3 64.30 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 2') 2.410 16,190.6 6,268.8 64.27 SEAL ASSY Seal Assembly,80-32 2.410 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/rq Grade Top Connection LOCATOR;16,152.0` ire LOWER 2 7/8 2.4411 16,192.7 16,348.21 6,341.7 6.50 L-80 EUE 8rd Mod XO Threads;16,147.6 „' COMPLETION RWO xo Reducing;16,158.2 2015 _ SEAL ASSY;16,153.0, � Completion Details SBE;78,759.2 :1,,,,,,,,..1 ---- Nominal ID V Top(ftKB) Top(ND)(ft0B) Top Inei(°) Item Des Cont (in) xo Reducing 16,17e7 *' 16,192.7 6,269.7 64.22 PBR PBR,80-32(effective stroke=19.70') 4.000 II 16,215.7 6,279.8 63.65 PACKER FH Packer,4782(40K shear ring) 2.390 LOCATOR;16,169.8 16,266.6 6,302.8 62.52 NIPPLE X NIPPLE 2.313 SEAL ASSY;16,190.8, ta _ 16,307.8 6,322.1 61.68 XO Enlarging Crossover,2-7/8"EUE 8rd Mod Box x 3-1/2"EUE 8rd Pin 2.441 FOR;18,192.7• tri MI 16,315.4 6,325.8 61.52 LOCATOR Locator Sub,GBH-22 2.990 PACKER;16,215.7 "" 16,316.7 6,326.4 61.50 SEAL ASSY Seal Assembly,80-40 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) NIPPLE,16,266.5 16,520.0 6,434.3 54.74 FISH 5.75"SEAL ELEMENT FROM TEST PACKER 12/3/2015al in Perforations&Slots NO Enlarging;16,3076 •a,, Shot Dens Top(TVD) Btm(ND) (shots/ LOCATOR;18,315.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 16,663.0 16,710.0 6,521.7 6,551.4 C-4,C-3,1C- 10/20/1997 4.0 IPERF 2 1/2"HSD ice 12 SEAL ASSY;16,316.616,710.0.7. 16,710.0 16,727.0 6,551.4 6,562.2 C-3,1C-12 1/29/1997 4.0 APERF 2.5"HSD;180 deg. 1I�-1 i Phasing Orientation Not I 1 I Certain am= Stimulations&Treatments I I Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 16,663.0' 16,737.0 6,521.7 6,568.6 FRAC 11/18/200 PRODUCTION;38.5-16,480.0 2 FISH;16,520.0 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com (PERF;16,663.0-16,710.0 FRAC;16,883.0 N1® ®1212EII7_®LIMIII ;KIII_IIIIII' APERF;18,710.0.78,727.0 I ©®®1 ®i ®M®®IM 0.188 1,401.0 lingra_ iIIiMI 'tIIIi' 1•I I • I III 11 1 •1Camco KBMG 1 GAS LIFT • 0.000 0.01/2/2016 LINER;16,321.5-17,098.0 gMNKUP PA D 1C-12 ConocoFhillips • Alaska.Inc.. C2nocoPhllhps 1C-12,1/21/20164.00.34 PM Verdcel schemata°Zectuah HANGER;36.9 Notes:General&Safety End Date Annotation XO Redwing;40.0 1 1 3/25/2011 NOTE:View Schematic w/Alaska Schematic9.0 i 2/3/2015 NOTE: 5 75"SEAL ELEMENT FROM TEST PACKER LEFT IN HOLE. k J ^�)�. -pip i 12/6/2015 NOTE: LEFT IN HOLE-TWO 6"SEALING ELEMENTS(IBP)AND ONE 1"STIFFENER RING AND SOME CONDUCTOR;43.4-121.0 �1I.. f I' 1/4/2016 NOTBANE.7"CASING LEAK located with test packer between 6918'and 7395 RKB. GAS LIFT,3,117.3 ILl IT 4 8 GAS LIFT;7,121.9 CI li I SURFACE,41.0-10,223.3 GAS LIFT,10,604.0 a III GAS LIFT;12,978.2 III GAS LIFT;14,851.7 III GAS LIFT;16,100.0 4 III, LOCATOR;16,152.0` Sti XO Threads'16,147.6 gi XO Reducing 16,158.2— ,■ SEAL ASSY 16,153.0, x SBE;16,159.2 i'� 00 Reducing;18,178.7 LOCATOR,16,189.6 ME SEAL ASSY,16,190.6 PBR;16192.7 I Imo PACKER;18,2157 r' 8 4 11 NIPPLE,16268.5 11' XO Enlarging;16,307.8 ..Itt, LOCATOR;163154 1.1 0. SEAL ASSY,16,316.6 1ee 1`. 1481 IIIIIIIII PRODUCTION;38.5-18,480.0 FISH;16,520.0 IPERF;16,663.0-16,7100 FRAC;166630 APERF;18,710 0-16,727 0 1 LINER;18,3215-17096.0 • 1C-12 DTTMSTAJOBTYP SUMMARYOPS 11/26/15 DRILLING EQUALIZED IBP © 16,683' SLM. JOB IN PROGRESS. SUPPORT- FXP 11/27/15 DRILLING PULLED IBP FROM 16,683' SLM UP TO SEAL ASSEMBLY @ 16,338' RKB WHERE IT HUNG SUPPORT- EXP UP.ABLE TO KNOCK IT DOWN HOLE EASILY. JOB IN PROGRESS. 11/28/15 DRILLING PULLED IBP FROM 16,679' SLM UP TO SEAL ASSEMBLY @ 16,338' RKB WHERE IT HUNG SUPPORT - EXP UP AND STAYED. JOB IN PROGRESS. 11/29/15 ANNCOMM (SEC) : T/I/O = SI 77/54/98. T FL © 156'. IA FL © SURFACE. OA FL © SURFACE. 11/29/15 DRILLING ATTEMPTED TO PULL IBP FROM SEAL ASSEMBLY @ 16,338' RKB, NO SUCCESS, JOB IN SUPPORT- EXP PROGRESS. (SOLD THREE 2" SB DOGS TO THIS WELL) 11/30/15 DRILLING MOBILIZED AND RIGGED UP EQUIPMENT. JOB ABORTED. COMPLETE. SUPPORT- EXP 12/5/15 DRILLING B&C CTU #1: MOVE IN UNIT AND START RIG UP. ENCOUNTER PROBLEMS WITH SUPPORT- EXP POWER PACK DECK ENGINE. WAIT ON MECHANICS TO TROUBLESHOOT AND REPAIR. WO RESTART IN THE MORNING. 12/6/15 DRILLING B&C CTU #1: PERFORM WEEKLY BOP TEST. RETREIVE IBP FROM SEAL ASSEMBLY AT SUPPORT- EXP 16,338' RKB WITH BAKER G-FORCE JARS. WILL RETURN IN THE MORNING TO LOG WO MEMORY BHPS-PDC LOG AND CUT TUBING. **NOTE: IBP MISSING TWO 6" SEALING ELEMENTS AND ONE 1" STIFFENER RING** 12/8/15 DRILLING B&C CTU #1: PERFORM SBHPS AT 16415' RKB (2950 PSI, 143 DEGF), GRADIENT STOP SUPPORT- EXP 16203' RKB (2897 PSI, 142 DEGF) WITH HES MEMORY AND FLAG PIPE FOR CUTTER 12/9/15 DRILLING B&C CTU #1: DRIFT TUBING FOR CUTTER WITH BAKER MOTOR AND 2.70" BO MILL. SUPPORT- EXP TAG AT 9890' RKB AND WORK THROUGH EASILY WITH MILL TURNING. PERFORM UP/ 12/10/15 DRILLING B&C CTU #1: DRIFT TUBING AND RETRIEVE SOME IBP BAND PIECES WITH BAKER 2- SUPPORT- EXP 5/8"VENTURI JUNK BASKET. PICK UP BAKER UNDER REAMER WITH CUTTING KNIVES WO AND CUT TUBING IN FIRST FULL JOINT ABOVE PACKER AT 16315', REFERENCED TO FLAG FROM MEMORY PDC LOG. RIG BACK, WILL RETURN IN THE MORNING TO FINISH Dnnnn 12/11/15 DRILLING B&C CTU #1: RUN IN HOLE WITH NOZZLE TO LAY IN KILL WEIGHT FLUID AND STACK SUPPORT- EXP WEIGHT AT 3759', SUSPECT IBP DEBRIS. ATTEMPT TO JET CLEAR WITH COIL PUMP WO AND ENCOUNTER PUMP ISSUES. WITH DOYON 25 RIG MOVE PENDING, RIG DOWN AND MOVE COIL UNIT OUT OF THE WAY. WILL RETURN AFTER RIG MOVE. 12/14/15 DRILLING B&C CTU #1: LAY IN 570 BBLS OF 9.6 PPG NaCI BRINE WITH COIL FROM 16,400' TO SUPPORT- EXP SURFACE WITH TBG/IA/OA OPEN TO FLOWBACK TANKS. RIG OFF WELL WITH BRINE WO AT SURFACE T/IA/OA. RIG UP LITTLE RED AND BULLHEAD DIESEL FREEZE PROTECT- 15 BBLS DOWN TUBING, 45 DOWN IA, 48 BBLS DOWN OA. WELL NEEDS BPV PENDING PRESSURES. 12/15/15 DRILLING (PRE-RWO): T/I/O = SI 200/110/160, T FL @ SURFACE, IA FL @ SURFACE, OA FL @ SUPPORT- EXP SURFACE. WO 12/18/15 RECOMPLETION Move Nabors 9ES support equipment from 2N-320 to 2M Pad while prepping Sub base for traval 12/19/15 RECOMPLETION Continue to move Nabors 9ES support equipment from 2M Pad to 1C Pad while prepping Sub base for travel and Pulling off 2N-320. Setup Support equipment on 1 C-pad and Road Nabors 9ES Sub base 21.7 miles from 2N-Pad to Oliktok Y 12/20/15 RECOMPLETION Continue to move Nabors 9ES Sub base 5.7 miles from Oliktok Y Pad Access to 1C Pad. MIRU, Berm up and spot all support equipment. Accept Nabors 9ES. Load pits with 9.8 ppg Brine. Hang bridal lines, tie in Top Drive interconnect. Raise Top drive from rotary table. 12/21/15 RECOMPLETION Operationally prep floor. Pull BPV, leaking tree valves. RU circ lines to kill tank. PT lines from well to kill tank. Recover Freeze protect from well. Attempt to circulate with 32 bbls w/no returns, Total pumped = 427 bbls, Total recovered = 150 bbls. Monitor well while lowering KWF from 9.8 ppg to 9.2 ppg Brine. 12/22/15 RECOMPLETION Continuedinake 9.2 ppg brine. DHD performed a fluvel shot: OA= 10', IA= 600', and tubing = W. After 30 minutes an additional fluid leve ot: OA= 10', IA= 600', and tubing = 600'. The well is static. Install 3" ISA BPV. ND the tree, install the blanking plug, and ND the tubing head adapter. NU the DSA and NU the BOP stack. Conduct initial BOPE test to 250/3000 psi: test 3-1/2" x 6"VBR's (upper pipe rams)with 3-1/2" and 4" test joints; test 2-7/8" x 5"VBR's (lower pipe rams)with 3-1/2" and 4" test joints; test annular to 250/3000 with 3-1/2" and 4" test joints; conducted CPAI Koomey drawdown test(all tested passed). The BOPE test was witnessed by AOGCC inspector Jeff Jones. Pull the blanking plug and pull the BPV. MU TD to the lading joint, BOLDS, and PU to 200K. Work pipe several times but the pipe is not free. Attempt to establish returns at 2 BPM with no returns. Consulted with town engineer and decided to pull to 90% of the pipe limitation. MU TD to the landing joint, PU to 220K, and string came free with a PU weight of 135K. RU SLB control line spooler and Weatherford power tubing 12/23/15 RECOMPLETION POOH laying down 3-1/2" tubing spooling control line to the SCSSSV. RD SLB control line spooler. Continue to POOH laying down 3-1/2"tubing removing jewelry. Strap, tally, and removing tubing from pipe shed. Recovered the seal assembly. There were no external or internal evidence of a cut from the under reamer cutter. Finish loading the pipe shed with 4" HT- 40 DP. Load the pipe shed with stack packer completion. Install the wear ring. PU and MU 80- 12/24/15 RECOMPLETION PU and MU stack packer assembly. Two joints of 2-7/8" tubing were bent and had to replace with new joints. RIH with stack packer assembly on 4" DP to 11193' RKB. Held a safety stand down with the crews. Continue to RIH with stack packer assembly on 4" DP from 11193' to 12/25/15 RECOMPLETION Engage seal assembly into SBE, pressure up on the DP to 2600 psi to set the FH packer, and hold for 15 minutes. Attempt to pressure test the IA to 2500 psi but unable to get the IA pressure over 1700 psi and the pressure would not hold. Pressure up on the DP to 1500 psi and PU to 25K over to shear the PBR. Lay down two joints of DP, MU TD, and set test packer at 16127' RKB (center of element). Pressure up on the DP to test the FH/PXX plug combination to 2500 psi for 30 minutes (good test). Circulate the well over to 9.2 ppg brine. Narrow casing leak location to between 13048' to 6489' RKB. Cut and slip 83' of drilling line. 12/26/15 RECOMPLETION Locate 7" casing leak with test packer between 6918' -7395' RKB (477'), TOOH standing back 4" DP, and lay down test packer/seal assembly. PU, MU, and TIH with 7" casing scraper to 13419' RKB at midnight. 12/27/15 RECOMPLETION Continue to TIH with 7" casing scraper assembly from 13419'to 16128RKB (PU = 220K, SO = 75K). PU three joints of DP from the pipe shed, locate out on PBR, and PU to up weight plus 5'. Pump 14 bbl hi visc sweep followed 9.2 ppg brine with 6% SafeLube at 5 BPM. Check new PU and SO with 6% SafeLube in the system (PU = 185K and SO = 90K). POOH laying down 4" DP from 16184' to 10513' RKB. Replace 1" hydraulic hose on the TD. Continue to POOH laying down 4" DP from 10513' to 8040' RKB. TOOH standing back 4" DP from 8040'to 37' RKB. Lay down 7" casing scraper assembly. Install Dutch riser. Spot E-line unit. Bring E-line tools and sheaves to the rig floor. 12/28/15 RECOMPLETION RU E-line. MU 40 arm caliper, RIH to 8100', and log back to surface. RD E-line tools and equipment. RD Dutch riser. Pull the wear ring and install the test plug. RU BOPE testing equipment. Conduct weekly BOPE test to 250/3000 psi: test 3-1/2" x 6"VBR's (upper pipe rams)with 4" and 5-1/2" test joints; test 2-7/8" x 5"VBR's (lower pipe rams)with 2-7/8" and 4" test joints; test annular to 250/3000 with 2-7/8" and 5-1/2"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Chuck Scheve via phone conversation on 12/28/15 at 07:50 hours. RD BOPE testing equipment. Replace TD hydraulic service loop. Pull the test plug and install the wear ring. TIH with 83 stands of 4" HT-40 DP from the derrick to 7909' RKB. 12/29/15 RECOMPLETION POOH laying down 186 joints of 4— HT-40 DP from 7909' to 2002' RKB. PU, MU, and RIH with storm packer and set at 109' RKB (center of element). PT storm packer to 1000 psi for 10 minutes (good test). Pull the wear ring. ND the BOP stack, ND the DSA, remove the test spool, and NU the DSA to the BOP stack. ND the tubing head with Hydratight(no casing growth). Spear 7"casing, PU to 300K(weight of 10200' of 7"26#+ 35K block weight), and re-land in slips. RU Wachs casing cutter and cut off 2.14' of 7" casing. Dress 7" casing stump and install 7" casing pack off. NU 5-1/2"casing head. PT pack off/void to 250/3000 psi (good test). 12/30/15 RECOMPLETION NU the BOP stack and install turnbuckles. Install the riser and air up the air boot. Install the mouse hole. Install the test plug. PT the break and annular with 4"test joint to 250/3000 psi (good test). Pull the test plug and install the wear ring. PU storm packer retrieving head, RIH engage storm packer, release storm packer, POOH, and lay down the storm packer. POOH laying down 63 joints of 4" HT-40 DP from 2002' to surface. Pull the wear ring. Continue to drift, strap, and tally 5-1/2" 15.5# L-80 Hydril 563 casing. PU, MU, and RIH with 80-32 seal assembly, 80-32 SBE, and 5-1/2" casing to 304' RKB at midnight. 12/31/15 RECOMPLETION ContinuedirtIH with 5-1/2" casing from 304' RKB to la' RKB. 5-1/2" casing that was tallied and placgigntside because there was not enough roorWI'the pipe shed was not put in the correct order. The 5-1/2" casing is so out of order, the 5-1/2"will be brought into the shed, re- number, and re-tallied. Continue to RIH with 5-1/2" casing (re-tally while RIH) from 5006' RKB to 16175' RKB. Engage seal assembly into PBR and space out. PU out of PBR and reverse circulate 161 bbls of 9.2 ppg corrosion inhibited brine. SO, engage seal assembly into PBR, split the BOP stack, install the 5-1/2" casing slip, and land the 5-1/2" casing. RU the Wachs cutter and start cutting the 5-1/2" casing. 1/1/16 RECOMPLETION Finish cutting the 5-1/2"casing with the Wachs cutter(cut 4.63' off joint#408; 34.77' in the hole). Change elevators to 2-7/8"tubing. Pull the riser and set the BOP stack back on the stump. Install the 5-1/2" casing pack off and NU new tubing head. PT void/pack off to 250/3900 psi (80% of 5-1/2" 15.5# L-80 casing collapse) (good test). NU 11"x 7-1/16" DSA and NU the BOP stack. PT the break and 5-1/2" casing to 250/3000 psi (good test). RU to run completion and RIH with 2-7/8" gas lift completion. PJSM. RIH with 2-7/8" gas lift completion to11162' RKB at midnight. SimOps: With LRS corrosion inhibit the 7"x 9-5/8" and freeze protect the 5-1/2"x 7" and 7"x 9- 1/2/16 RECOMPLETION Continue to RIH with 2-7/8"gas lift completion from 11162' to 16146' RKB. Engage the seal assembly into the SBE, SO until fully located, and space out. MU landing joint and tubing hanger. Circulate 345 bbls of 9.2 ppg corrosion inhibited brine at 4 BPM. Land the tubing hanger and RILDS. PT the tubing to 3000 psi for 15 minutes (good test), bleed the tubing to 1500 psi, and PT the IA to 2500 psi for 30 minutes (good test). Bleed the tubing pressure to 0 psi and the SOV did not shear. Bring the pressure up on the IA to shear the SOV at 2700 psi. Install the 3" ISA BPV. Pressure up on the IA to 1000 psi to test the BPV from below in the direction of flow (good test). Perform tasks for demobilization as dictated by Nabors Tool Pusher. 1/3/16 RECOMPLETION The following is due to the demobilization of rig Nabors 9ES out of Kuparuk as dictated by Nabors Tool Pusher: Continue to clean and expedite all pipe handling equipment off the floor. Clean the rotary table, draw works, sump, pipe skate sump, EZ torque sump, mouse hole, and sub rack. Clean under the draw works and inspect hatches. Clean mud manifold and choke manifold. Remove upper, lower, and blind rams for the BOP stack and grease elements. Clean ram shaft and coat with LPS3 on upper, lower, and blind ram cavities. Continue work on well 1C-12: Pull the riser and mouse hole. Remove the turnbuckles. ND the BOP stack and set on the stump. Clean and prep the wellhead. Clean up the cellar. RD Koomey hoses from the BOP stack. 1/4/16 RECOMPLETION NU tubing head adapter, PT void/tubing hanger to 250/5000 psi, and NU 3-1/8" tree. Pull the BPV and install the tree test plug with dry rod. PT the tree to 250/5000 psi (good test). Pull tree test plug with dry rod. RU Little Red Service (LRS) and lines in the cellar to freeze protect the well with diesel. Pump 50 bbls of diesel down the IA taking return up the tubing to the kill tank at 2 BPM. RD LRS. Place the tubing and IA in communication allowing the well to u-tube and equalize. Final well pressures: Tubing = 0 psi, IA pressure = 0 psi, OA= 100 psi, and OOA= 100 psi. Install 3" ISA BPV with dry rod. Secure the well and the secure cellar. Release the rig 1/12/16 DRILLING ATTEMPT TO SET CATCHER (TOOLS FELL VERY SLOW) & UNABLE TO PASS 16,166' SLM SUPPORT- EXP (RECOVERED SS BAND IN BHA); CIRC'ED OUT IA X TBG W/240 BBLS OF CRW SW W/65 WO BBLS DSL U-TUBE FP. IN PROGRESS. 1/13/16 DRILLING ATTEMPT TO PULL P-PRONG & UNABLE TO GET PASS 16,184' SLM; DEPLOYED SUPPORT- EXP CATCHER ASSEMBLY; PULLED SOV&SET OV @ 10,604' RKB; PULLED DV'S @ 7122' & WO 3117' RKB; SET GLV @ 7122' RKB. IN PROGRESS. 1/14/16 DRILLING SET GLV @ 3117' RKB (OBTAIN GOOD DDT ON IA); PULLED CATCHER @ 16,178' SLM & SUPPORT- EXP 2.31" PXX PLUG @ 16,267' RKB; TAG © 16,685' SLM. JOB COMPLETE. WO to -V-1-1 • S , WELL LOG TRANSMITTAL#902970076 DATA LOGGED 2../t /2011; ,I.K.BENDER To: Alaska Oil and Gas Conservation Comm. January 8, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC)/ Static Bottom Hole Pressure Survey: 1C-12 Run Date: 12/08/2015 and 12/28/2015 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 1C-12 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22719-00 Static Bottom Hole Pressure Survey 1 Color Log 50-029-22719-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAl244434%-,17) v oF, 7Iy • THE STATE Alaska Oil and Gas � ofA LAsKA Conservation Commission t Situ 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage,GOVERNOR BILL WALKER Main: 907.279.1433 ®FALAS�� Fax: 907.276.7542 SCANNED NOV 2 4 Z015 www,aogcc.alaska.gov Theresa Lee Wells Engineer t -- 111 ConocoPhillips Alaska, Inc. 4 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-12 Sundry Number: 315-700 Dear Ms. Lee: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat y P oerster Chair DATED this / day of November, 2015 Encl. J BDMS hrri 17 2015 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1I 2 C{,iJ APPLICATION FOR SUNDRY APPROVALS 57'-__S. `i/KA_ 20 AAC 25.280 w CO 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 .. Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 1:70, Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing IOther: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. , Exploratory ❑ Development L• 196-177 3.Address: ,Stratigraphic ❑ Service 6.API Number: P.O.Box 10036,Anchorage,Alaska 99510 50-029-22719-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1C-12 Will planned perforations require a spacing exception? Yes ❑ No D J 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28243 • Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): .17096 6805 t -16680 ' 6532 1588 16435 16520 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 16 121 121 Surface 10182 9 5/8 10223 4537 Intermediate Production 16442 7 16480 6411 Liner 775 5 17096 6805 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 16663'-16727' ' 6522'-6562' 3.5 L-80 16369' Packers and SSSV Type: Packer-Liner Top Packer Packers and SSSV MD(ft)and ND(ft): MD=16321'ND=6329 SSSV-Camco TRDP-4E MD=493'TVD=493'- 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12!7/2015 OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Theresa Lee @ 263-4837 Email Theresa.M.Leecop.com Printed Name Theresa Lee 263-4837 Title Wells Eengineer - r i,er(pAeA t / 1 / 1 S Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: --6lS--700 Plug Integrity ❑ BOP Test per Mechanical Integrity Test ❑ Location Clearance ❑ Other: jt! SON) /1 6 d P («t ( m loP ..,..- IS CO a p b e Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes ❑ Noe Subsequent Form Required: /0 -LI CW APPROVED BY Approved by: _ti4. . COMMISSIONER THE COMMISSION Date: //.// rt- Form 10-403 Revi d 11/2015 p r s validfor 12 m the date of a roval. n 1 / hmucatR�&f NIIA0L Dms NOV 1p 7 2015 `W �li3/%,at • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 9, 2015 Commissioner State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover the Kuparuk Producer Well 1C-12 (PTD# 196-177). Well 1C-12 was drilled and completed in December 1996 and was frac'd in the C sands then placed online in February 1997. The C sand was re-frac'd in December 2005. 1C-12 was shut in on December 12, 2014 due to a failed TIFL caused by multiple tubing leaks. The well failed an MIT-T on January 18, 2015 and the LDL indicated a leak at 1 bpm. Tubing leaks were identified from 1,200-1,300', 6,970' and 7,060 RKB'. 1C-12 failed an MIT-IA on January 19, 2015 that showed communication with the OA while pumping fluid into the well. 1C-12 has an open surface casing shoe. After months of diagnostic work we were not able to locate the production casing leak and repeated tests were inconclusive. In March-April 2015 1C-12 was secured with an IBP at 16,435' and kill weight fluid with freeze protect. The proposed workover will reinstate gas lifted production service. The workover scope includes pulling the 3 1/2" production tubing and installing new 2 7/8"tubing after repairing the production casing leak. If the production casing leak is found below 12,000' we will stack a packer to isolate the leak. If the production casing leak is found above 12,000' and in a small section of pipe we will stack a packer and run a 7"expandable metal skin patch over the section. If the production 0;177 casing J casing leak is found above 12,000' and over a large area of pipe we will run a 5 1/2"tie-back liner to . surface. This Sundry application is intended to document the proposed work on the producing well 1C-12 and to request approval to workover the well. If you have any questions or require any further information, please contact me at 263-4837. Regards, Theresa Lee Workover Engineer CPAI Drilling and Wells Theresa.M.Lee@conocophillips.com • • • • 1C-12 Kuparuk Producer Rig Workover (PTD #: 196-177) Current Status 1C-12 was shut-in December 2014 due to multiple tubing leaks and is waiting on rig workover repairs. The well failed an MIT-IA on January 19, 2015 that showed communication with the OA while pumping fluid into the well. 1C-12 has an open surface casing shoe. After months of diagnostic work we were not able to locate the production casing leak and repeated tests were inconclusive. In March-April 2015 1C-12 was secured with an IBP at 16,435' and kill weight fluid with freeze protect. Scope of Work The proposed workover will reinstate gas lifted production service. The workover scope includes pulling the 1r� 3 1/2" production tubing and installing new 2 7/8" tubing after repairing the production casing leak. If the _ / production casing leak is found below 13,000'we will stack a packer to isolate the leak. If the production �!✓' casing leak is found above 13,000' and in a small section of pipe we will stack a packer and run a 7" `rf A expandable metal skin patch over the section. If the production casing leak is found above 13,000' and over `v ✓-a large area of pipe we will run a 5 1/2" tie-back liner to surface. 1,- '01- General Well info ��c MPSP: • 1,588 psi using SBHP and .1 psi/ft gas gradient prior to setting plug 3 Reservoir pressure/TVD: 2,034 psi at 9,914' MD (4,458' TVD) SBHP taken on January 15, 2015 kuv c, a-6Tt'0 Wellhead type/pressure rating: FMC Gen IV 5K BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: , MIT-OA failed due open casing shoe MIT-T failed January 18, 2015 MIT-TxIA failed January 19, 2015 Well Type: Producer Estimated Start Date: , November 1, 2015 Production Engineer: Dana Glessner 265-1308/ Dana.Glessner@conocophillips.com Workover Engineer: Theresa Lee 263-4837/Theresa.M.Lee@conocophillips.com Pre-Riq Work 1. RU Coil/Slickline: Fish 102 2 weeks prior to RWO. Obtain new SBHP.'7 2. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate KWF. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. ci_r- le,ls'S 3. Set BPV& blanking plug or two-way check, PT to 1,000 psi from below if possible, ND tree, NU BOPE & test. ()oz+p s:. 4. Pull blanking plug & BPV or two-way check. 5. RU to pull tubing, MU landing joint, BOLDS's, POOH laying down tubing. a. If Seals/OEJ will not pull free, RU E-line: Cut the tubing in the middle of the first full joint above the PBR/OEJ. RDMO E-line. 7 6. RIH w/overshot, FH packer and test packer on drillpipe. Engage tubling stub, drop ball and rod then pressure up to set packer. Shear PBR. F-# O�41 • • • 7. POOH testing 7" casing to locate leaks. Lay down DP while POOH. 5462" 8. Isolate 7" casing leaks and determine isolation method via stack packer, liner to surface or metal skin patch. r �.� ap+''" z- 9. 9. RIH w/new tubing and stack packer assembly to just above the PBR. �pj'' 10. Spot a balanced pill of corrosion inhibited brine in the Tbg & IA. 11. Slowly cycle the charge pump and look for pressure increase or lack of returns as the seals engage. Shut down charge pump. Space out 1 ft. from fully located. / 8L 12. Drop the ball & rod, pressure up tubing to set the packer. PT the IA to confirm packer is set. Shear the PBR. Space out, mark the pipe, and pull out of the PBR. S 13. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 14. Pull the landing joint, install BPV or two-way check. PT BPV or two-way check to 1,000 psi from below. 15. ND BOPE. 16. NU tree. If BPV is installed, pull BPV& install tree test plug. Test tree. Pull test plug/two-way check. 17. Freeze protect well w/diesel. 18. Install BPV. 19. RDMO. Post-Riq Work: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. Pull plug. 3. Pull and Replace SOV with Gas Lift Design. 4. Turn well over to operations. rip 4ti, Z sz.12- . • 1C-12 ConocoPhillips P&R 2-7/8" Tubing with Stack Packer Camco 2-7/8"x 1" KBMG GLM's Casing-9-5/8"40#, L-80 BTC to 10,223'—► Premier Packer @-13,500' L 1! ' _ l vooc: Tubing-2-7/8" 6.5#, L-80 EUE to-16,300' Gas� �'� — I Baker 80-32 PBR @ -16,200' — r Baker FH Packer @ -16,200' IV. a 2.313" DS-Nipple @ -16,250' I 3-1/2" Overshot @ -16,310' 17 +i 4 2.750" D-Nipple @ 16,330' I' - Baker Liner Top Packer @ 16,321' f— Baker Liner Hanger @ 16,335' fBaker PBR & Seal Assembly @ 16,338' Casing-7"26#, L-80 BTC to 16,480' C-4 Perfs 16,663'to 16,710' C-3 Perfs 16,710'to 16,727'-- Liner-5" 18#, L-80 LTC to 17,096' (Date: September 1,2015 Drawn By: Theresa Lee 1 C-12 ConocoPh.flips _ g x P&R 2-7/8" Tubing with 5-1/2" Liner tb Surface . OPT-) 0 n% 2e- k , ti., ti „ii,.. f./F. c—Si.3 -t y- -A- - le..4 5. MP Camco 2-7/8"x 1" KBMG GLM's 1 t /__. Casing-9-5/8"40#, L-80 BTC to 10,223'--B. Casing-5-1/2" 15.5#, L-80 BTCM to-16 200' IIII . Baker 80-32 PBR @-16,170' A Baker 5" SBE @16,175' Mg 1 f Baker 80-32 PBR @ -16,200' J- Baker FH Packer @ -16,200' a t 2.313" DS-Nipple @ -16,250' Tubing-2-7/8" 6.5#, L-80 EUE to -16,300' --II. t 3-1/2" Overshot @ -16,310' i 2.750" D-Nipple @ 16,330' 1 -if Al Baker Liner Top Packer @ 16,321' A.--- Baker Liner Hanger @ 16,335' -- 4-- Baker PBR & Seal Assembly @ 16,338' Casing-7"26#, L-80 BTC to 16,480' C-4 Perfs 16,663'to 16,710'-0.- C-3 6,710'--C-3 Perfs 16,710'to 16,727'-1.- Liner 6,727'-.Liner-5" 18#, L-80 LTC to 17,096' Date: September 1,2015 1 Drawn By: Theresa Lee KUP PROD ill1C-12 ConocoPhillips 2' \ Well Attributes Max Angle&MD TD Alaska Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cd..0,4MtAps 500292271900 KUPARUK RIVER UNIT PROD 76.64 11,193.86 17,096.0 ... Comment H2S/ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-12,3/22201511:36:11 AM SSSV.TRDP 50 12/16/2013 Last WO 46.91 12/10/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date �� Last Tag: 16,680.0 1/31/2015 Rev Reason:RESET IBP lehallf 3/22/2015 HANGER;36.9 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread l CONDUCTOR 16 15.060 43.4 121.0 121.0 62.50 H-40 WELDED ' LI cI ,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I / SURFACE 9 5/8 8.835 41.0 10,223.3 4,539.5 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.5 16,480.0 6,411.5 26.00 L-80 BTC-MOD CONDUCTOR;43.4121 0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 5 4.276 16,321.5 17,096.0 18.00 L-80 LTC Liner Details SAFETY VLV;492.9 1141 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl p) Item Des Com (in) 16,321.5 6,328.7 61.40 PACKER LINER TOP PACKER w/TIE BACK SEALS 5.000 ` 16,335.4 6,335.4 60.91 HANGER BAKER LINER HANGER 5.000 1 pec, 16 342.2 6,338.7 60.64 PBR BAKER PBR 4.000 ellt Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection 5. TUBING I 31/21 2.992! 36.9!Set 16,369.11 6,352.11 9.301 L-80 IEUE8RDMOD Completion Details GAS LIFT;3,584.9 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 36.9 36.9 0.00 HANGER FMC GEN IV HANGER 3.500 492.9 492.6 4.63 SAFETY VLV CAMCO TRDP-4E SAFETY VALVE 2.813 16,330.4 6,3329 61.10 NIPPLE CAMCO D LANDING NIPPLE 2.750 GAS LIFT;6,946.0 131 16,337.4 6,336.3 60.83 LOCATOR BAKER GBH-22 LOCATOR 3.000 'a 16,338.8 6,337.1 60.77 SEAL ASSY BAKER SEAL ASSEMBLY w/1.62'OF SEALS 8 MULE 3.000 g SHOE Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;9,890.5 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(int 16,435.0 6,386.7 57.16 PLUG 2.5"IMP COE 3/20/2015 0.000 lair 16,520.0 6,434.3 54.74 FISH 5.75"SEAL ELEMENT FROM TEST PACKER 2/3/2015 Perforations&Slots i I Shot Dens Top(ND) Btm(TVD) (shotsk Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 1 16,663.0 16,710.0' 6,521.7 6,551.4 C4,C-3,1C- 10/200997 4.0 IPERF -21/2"HSD 12 SURFACE;41.0-10,223.3-A 16,710.0 16,727.0' 6,551.4 6,562.2 C-3,1C-12 1/29/1997 4.0 APERF '2.5"HSD;180 deg. I Phasing Orientation Not GAS LIFT;12'473'1-14Certain Stimulations&Treatments Min Top Max Btm ' Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com GAS LIFT;14,1420 16,663.0 16,737.0 6,521.7 6,568.6 FRAC 11/18/200 2 Mandrel Inserts St ati GAS LIFT;15,894.1 N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3,584.9 2,652.2 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,301.0 12/7/2014 2 6,946.0 3,654.5 CAMCO KBMM 1 GAS LIFT OV BK 0.188 0.0 12/7/2014 3 9,890.5 4,452.8 CAMCO KBMM 1 GAS LIFT DMY BK5 0.000 0.0'11/11/2002 GAS LIFT;16,285.5 4 12,473.1 5,150.5 CAMCO KBMM 1 GAS LIFT DMY BK5 0.000 0.0 12/19/1996 5 14,142.9 5,645.8 CAMCO KBMM 1 GAS LIFT DMY BK5 0.000 0.0 11/14/2002 13` ''-r 6 15 .16,154.6 CAMCO KBMM 1 GAS LIFT DMY BK5 0.000 0.0 12/19/1996 NIPPLE,16,330.4 17 [t 7 16,285.5 \,6,311.7 CAMCO MMM GAS LIFT OPEN 0.000 0.0 1/30/2015 N t-General&Safety LOCATOR;16,337.4 End Date Annotation 'rel' 3/25/2011 NOTE View Schematic w/Alaska Schematic9.0 SEAL ASSY;16,338.9 - 2/3/2015 NOTE:5.75"SEAL ELEMENT FROM TEST PACKER LEFT IN HOLE. .'s / F PLUG,16,435.0 ISO i PRODUCTION;38.5-16,480.0 ° FISH;16,520.0 IPERF;16,663.0.16710.0 FRAC;16,663.0 APERF;16,710.016,727.0I I LINER;16,3216-17,096.0 le Weatherford' Solid Expandable Systems 4 MetalSkin® Cased-Hole Liner (MCL) 51/2 in. OD, 16.89 lbs/ft x 7 in. OD, 26.0 lbs/ft IIIIIIIIIIIIIIEIEEMIIIIIIIIIIIIIII Liner Specifications Nominal OD 7.000 in. Pre Post Nominal Weight 26.00 lbs/ft Nominal OD 5.500 in. 6.089 in. Wall Thickness 0.362 in. Nominal Weight 16.89 lbs/ft N/A lbs/ft Nominal ID 6.276 in. Wall Thickness 0.304 in. 0.282 in. Drift Diameter 6.151 in. Nominal ID 4.892 in. 5.525 in. t✓ Drift Diameter 4.767 in. 5.433 in. Connection Type FODC-OR'"" FODC-OR"" Max.Connection OD 5.706 in. 6.235 in. Connection ID 4.811 in. 5.488 in. Min.Yield Strength 50,000 psi 60,000 psi Internal Pressure 4,970 psi 5,000 psi Setting System External Pressure 4,340 psi 3,300 psi Maximum Expansion Rate 15.00 ft/min Tension Strength 150,000 lb 150,000 lb Maximum Expansion Pressure 5,000 psi Compression Strength 150,000 lb 75,000 lb Tensile Rating 250,000 lb Maximum Run-in OD 5.830 in. N/A in. Maximum Temperature 300 °F Connection to Work String 3 1/2 IF Liner System Elastomer Thickness 0.150 in. Maximum Dogleg Severity** 12 °/100ft Recommended Inner String Expansion Ratio 12.2 % Size 3.500 in. Shrinkage Percentage 4.1 % Connection Max OD 4.500 in. Make-up Torque(Min) 2,200 ft-lbs ID,Min/Max N/A in. Make-up Torque(Max) 2,600 ft-lbs Connection Lubricant Any Premium Thread Compound that does not include PTFE. Notes: 1.Maximum Temperature:300°F. 2.Post Expansion Pipe OD and Pipe Wall Thickness are based on test and FEA data. 3.Post Expansion Pipe ID is calculated from Post Expansion OD and Wall. 4.Post Expansion Connection OD is based on test data. 5.Post Expansion Connection ID is based on test and FEA data. 6.Pre and Post Expansion Connection Tension and Compression Strengths have been verified by testing. 7.Pre and Post Expansion Connection Internal and External Pressure have been verified by testing. 8.These performance properties are for a fixed-free expansion. **Contact your local representative Form Number-550700MCL260 Form Rev 3 weatherford.eom ©2015 Weatherford.All rights reserved Weatherford products and services are subject to the Company's standard terms and conditions,available on request or at weatierford.com.For more information contact an authorized Weatherford representative Unless noted otherwise,trademarks and service marks herein are the property of Weatherford and may be registered in the United States and/or other countries.Weatherford products named herein may be protected by one or more U.S.and/or foreign patents.For more informatim,contact patents@weatherford.com.Specifications are subject to change without notice.Weatherford sells its products and services in accordance with the terms and conditions set forth in the applicable contract between Weatherford and the client. • • Schwartz, Guy L (DOA) From: Lee, Theresa M <Theresa.M.Lee@conocophillips.com> Sent: Monday, November 16, 2015 9:44 AM To: Schwartz, Guy L(DOA) Subject: RE: 1C-12 RWO (PTD 196-177) Attachments: MCL - 5.50 x 7.00 26.0 ppf.pdf; 1C-12.docx; 1C 12 DirectionaLpdf Guy, I attached the proposed new wellhead equipment and the specs on the Metal Skin patch. 1. Between Steps 12-13 was a typo from trying to merge the different outcomes for this well. Drop the ball & rod, pressure up tubing to set the packer. PT the IA to confirm packer is set. Shear the PBR. Space out, mark the pipe. Space out w/pups, MU hanger. Land the hanger, RILDS. ; _ PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. Of-II Z- 2. 5-1/2" Liner to Surface Procedure after decision point in step 8 of 1C-12 proposed procedure: While POOH with 2,500 ft left to go PU and land a storm packer at -100 ft. Pressure test storm packer. ND BOP and remove tubing head. Grow 7" with hydratight and re-land with additional 5-1/2" casing hanger attached. Pull storm packer and POOH. I + RIH w/ inner casing string'to"jtisibove thePBR/SBE. Reverse circulate corrosion inhibited KWF into the new annulus. Drop ball and rod and set FH packer. Lower casing until seals engage the PBR/SBE, space out. PT new annulus to 500 psi to confirm seals are engaged. Land the inner casing in the air slips. RU Wachs cutter and cut excess casing. Install packoff& new tubing head. PT packoffs. NU BOP to the tubing head & shell test breaks. RIH w/ new tubing and seal assembly to just above the SBE. Slowly cycle the charge pump and look for pressure increase as the seals engage the SBE. Shut down charge pump. Space out, mark the pipe, and pull out of SBE. Circulate corrosion inhibited brine around the Tbg and IA. Install space out pups below the hanger, MU hanger. Land the hanger, RILDS. PT the tubing for 10 minutes. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 3. Expandable casing patch after decision point in step 8 of 1C-12 proposed procedure: Identify casing leak/leaks are in an isolated section with test packer. RIH on DP w/casing scraper down to existing packer. • ! RU DSL/ E-line and run a caliper across leak zone to design upper and lower set points of expandable casing patch in good pipe (less than 1,000' required). RIH w/ metal skin patch on DP, pressure up an expand per Weatherford design specifications. POOH laying down DP. RIH w/new tubing and seal assembly. Circulate corrosion inhibited brine around the Tbg and IA. Install space out pups below the hanger, MU hanger. Land the hanger, RILDS. PT the tubing for 10 minutes. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 4. The pressure on 1/15/15 was taken from 9524' RKB to 9914' RKB because digital slick line could not get any lower due to hole deviation (I attached the directional survey for reference). 5. What we pull post rig will be dependent on what solution we end up with and the post-rig required will be documented in handover form to production. Let me know if there are any other questions. Thanks, Theresa Lee Wells Engineer ConocoPhillips AlasI a Office:907-263-4837 Cell:505-301-6483 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, November 13, 2015 2:52 PM To: Lee, Theresa M Subject: [EXTERNAL]1C-12 RWO (PTD 196-177) Theresa, I am reviewing your RWO procedure. I saw a couple of items: 1. The steps between 12 & 13 don't quite make sense . There is nothing about the final landing of the tubing/RILDS before doing the tubing pressure test. 2. Can you provide more details on option 2 as far as running the 51/2" liner back to surface. There needs to be something about adding wellhead spool and associated steps. (give me the running steps just like option#1). 3. Option 3 with the expandable casing patch should include a simple running procedure also... 2 7/8" GLMs should drift most 7" expandable patches. Details on the patch specs should be included in the sundry. Again a separate running procedure would make the most sense 4. Why is the reservoir pressure taken at 9914' and (4458'TVD) Kup C is around 6500 ft TVD here. ( I get a KWF of about 8.7 ppg) 2 5. Don 't forget to pull ball/rod and RIP body in post rig. ( or is that plug in step 2. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 3 . . Conoc6Phillips Alaska RECEIVED AUG 2 9 2007 Alaska air & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNeD SEP 06 2007 \qb~117 Dear Mr. Maunder: . Enclosed please find a spreadsheet with a list of wells trom the Kuparok field (KRU). Each of these wells was tóund to have a void in the conductor. These voids were filled with a corròsion 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 corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Æ4~~ M.J.¿el~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date - ft bbls ft gal 10-28 204-237 18" N/A N/A N/A 10 8/19/2007 10-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 . 1C-11 199-172 -SF NA NA NA :0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 1229' FNL, 4629' FEL, Sec. 12, T11N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service_ (asp 's 561652, 5969003) 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1C-12 At top of productive interval 1864' FSL, 2507' FWL, Sec. 17, T11N, R11E, UM At effective depth At total depth 3571' FNL, 2486' FEL, Sec. 17, T11N, R11E, UM (asp's 574085, 5961493) 9. Permit number / approval number 196-177 / 10. APl number 50-029-22719 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 17096 feet Plugs (measured) 6805 feet Effective depth: measured true vertical Casing Length Size CONDUCTOR 80' 16" SURFACE 10182' 9-5/8" PRODUCTION 16441' 7" LINER 775' 5" LINER 16931 feet Junk (measured) 6694 feet Cemented 251 sx ASI 1380 sx ASLW & 1110 sx Class G 120 sx Class G 159 sx Class G Measured Depth True vertical Depth 80' 121' 10233' 4539' 16480' 6412' 17096' 6805' Perforation depth: measured 16663' - 16727' true vertical 6522' - 6563' tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 16369' MD. Packers & SSSV (type & measured depth) No packer CAMCO TRDP-4E - FRAC SLEEVE SET 11/17/02 @ 493' MD. RECEIVED DEC 1 1 2002 Naska 0il & Gas Cons. Commissior, Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) 16663' - 16737' Treatment description including volumes used and final pressure placed 78800# 16/20 proppant behind pipe 14. Prior to well operation Subsequent to operation OiI-Bbl 355 Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 743 423 1222 1239 330 Casing Pressure Tubing Pressure 254 254 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Gas_ Suspended__ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Michael Mooned/ Form 10-404 Rev 06/15/88 · gDMS BFL Title: Wells Team Leader DEC 1 9 200 Questions? Call Mike Mooney 263-4574 Date /t~.ff~j ~ SUBMIT IN DUPLICATE Date Comment "-" 1 C-12 Event History 11/18/O2 11/19/02 11/20/02 11/21/02 PUMPED C SAND RE-FRAC. PLACED 78800# 16/20 PROPPANT BEHIND PIPE, DESIGN CALLED FOR 77000#. HAD TSO IN 6-8 PPA RAMP. EXTENDED 8 PPA FLAT STAGE. FLUSHED TO COMPLETION. [FRAC-REFRAC] PERFORMED A JET / REVERSE FILL CLEAN OUT TO 16,931' CTMD. PAID CLOSE ATTENTION TO ALL GLV ON THE WAY TO SURFACE. DIESEL IN WELL BORE TO 16,9311' CTMD. PURGED COIL WITH NITROGEN FOR RELEASE OF EXTENDED REACH COIL. PULLED FRAC SLEEVE @ 493' RKB. DRIFTED TBG TO 9060' WLM. PULLED DV @ 6946' RKB. SET OV BUT LOST PT WHEN SHEARING OFF VLAVE. SUSPECT VALVE PARTIALLY IN POCKET. IN PROGRESS. [GLV] COMPLETED GAS LIFT DESIGN. [GLV] Page I of I 11/25/2002 ConocoPhillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 December 2, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1C-12 (196-177) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1C-12. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Wells Team Leader CPAI Drilling MM/skad RECEIVED DEC 1 1 2002 Alaska Oil & Gas Cons. Commission Anchorage ;SCANNED DE[; 1 ~) 2002 ON-OR BEFORE ARCO Alaska, Inc. Post Office Bo,.. d0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9. 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 '/72 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular b~jection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 SeeNote#1 bet,,,; 25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1C-15 16695 100 0 16795 0 16795 2L-313 8554 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously reported vohtme of 220 barrels was pumped into this annulus during the drilling of the well. This was the vohtme required to_thtsh and freeze protect the annulus during initial drilling operations, not a volume of disposal fluids injected prior to the receipt of authorization t'or annular injection. Total Volumes into Annuli for which Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume ! Volume Injected Status of Annulus 1C-12 34995 100 0 ] 35095 Open, Freeze Protected 1t2-13 26800 100 0[ 26900 Open. Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume Volume I Injected Annulus 2A-22 16749 100 0 16849 Open, Freeze Protected 2F-19 20725 100 0 , 20825 Open, Freeze Protected 3K-27 37173 I 100 0 I 37273 Open, Freeze Protected 3K-26 33970 100 0 i 34070 Open, Freeze Protected 1E-31 33645 100 ] 0I 33745 Open, Freeze Protected 1E-32 45205 100~ 0 45305 Open, Freeze Protected 3Q-22 6245 100 0 6345 Open, Freeze Protected 1Q-24 23158 100 0 23258 Open, Freeze Protected 1Q-26 i 25931 100 0 i 26031 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC' Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 01/21/99 T / RUN RECVD D .............. 96-177 CHIPS #1 C 16672-16687 96-177 CHIPS #2 96-177 DGR/RES-MD 96-177 DGR/RES-TVD 96-177 7948 96-177 MWD SRVY 96-177 MWD SRVY 10-407 DAILY WELL OPS C 16694 - 16750 .~T~"4545-6420 ~PERRY MPT/GR/RES 4~0-17096 Are dry ditch sampleS required? yes ~And received? Was the well cored? ~o Analysis & description received? Are well tests required? yes ~__~ceived? _~' Well is in compliance Initial COMMENTS 01/16/97 FINAL 02~26/97 FINAL 02/26/97 5-8 04/09/97 04/16/97 05/06/97 .% .,'../,../ STATE OF ALASKA Al_A,_.. ,A OILAND GAS CONSERVATION COMMIS~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate Pull tubing Alter casing Repair well 2. Name of Operator I 5. Type of Well: Development X ARCO Alaska, Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1234' FNL, 649' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1864' FSL, 2507' FWL, Sec. 17, T11N, R11E, UM At effective depth 1734' FSL, 2538' FEL, Sec. 17, T11N, R11E, UM At total depth 1704' FSL, 2485' FEL, Sec. 17, T11N, R11E, UM 12. Plugging Perforate X Other 6. Datum elevation (DF or KB) RKB 41 feet 7. Unit or Property name Kuparuk River Unit Present well condition summary Total Depth: measured true vertical 1 7096 feet 6804 feet 8. Well number 1C-12 9. Permit number/approval number 96-177 10. APl number 5o-029-22719-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 1 7 0 0 6 true vertical 6 7 4 3 feet Junk (measured) None feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 10182' 9-5/8" 16441' 7" 774' 5" measured 16663'-16727' true vertical 6522'-6563' Cemented Measured depth 251 SxASI 121' 1380 Sx ASLW & 1 0223' 1110SxClassG&61 SxASI 120 Sx Class G 1 6480' 159 Sx Class G 1 7 0 9 6' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 16369' Packers and SSSV (type and measured depth) Packer: LSA GBH-22 @ 16337'; SSSV: Camco TRDF-4E @ 493' True vertical depth 121' 4539' 6412 6805' 13. Stimulation or cement squeeze summary Perforate "C" sands on 10/20/97. Intervals treated (measured) 16663'-16710' Treatment description including volumes used and final pressure Perforate using 2-1/2" gun w/J UJ charges @ 4 spf, fp was 2500 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 631 334 281 1260 125 Subsequent to operation 1143 1098 564 1260 125 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~rtify .that the foregoing is true and correct to the best of my knowledge. Si~Ined '"TZ'~ _~~/~ Title Wells Superinten .de, rtL .:.., ~_~ , , / I Date SUBMIT~ IN'DUPLICATE ~Jaska 0ii,:.,.r' L;as Cons. Commission A~c, h0!'age ARCO Alaska, Inc. KUPARUK RIVER UNIT A WELL SERVICE REPORT ~. K1 (1 C-12(W4-6)) WELL JOB SCOPE JOB NUMBER 1C-12 PERFORATE, PERF SUPPORT 101 9971655.5 DATE DAILY WORK UNIT NUMBER 10/20/97 PERFORATE SWS 8293 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI (~) Yes (~ No SWS-ELMORE SCHUROSKY FIELD AFC-# CC,~ DALLY COST ACCUM COST Signed ESTIMATE KAWWRK 230DS10CL $1 9,328 $19,328 Initial Tb_q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 850 PSI 1460 PSI 1 100 PSI 0 PSII 200 PSII 0 PSI DAILY SUMMARY '1 PEFORATED 16663'-16710'. 2.5" HSD 4 SPF 31J UJ CHARGES. J TIME LOG ENTRY 08:00 MIRU SWS 8293 ELMORE SAFETY MTG W/PUMPERS. PT 3000#. 09:30 RIH W/GUN 1.7' X 2.5" HSD, 4 SPF, 180 PHASED. 31 J UJ HMX CHARGES. CCL TO TOP SHOT=8.1 ', CCL TO BOT GUN=18.6', OVERALL LENGTH=22.6'. 10:08 BEGIN PUMPING @ .5 BPM/1450 PSI. AT 9900', TOOL STOPPED. UP RATE TO 2.8 BPM/2500 PSI. 11:45 1~200' STOP PUMPING, CHECK UP TENSION BEFORE DROPPING ©!)T OF TiA~.. ~ 400# TENSION. ¢:%iN Pi T'O GET TOOL MOVING DOWN (2.8 BPM/2500 PSI). HAD TO PI @ 3 BPM TO GET TOLL MOVING. 11:50 TI TO SliT JTS, + 8' CORRECTION. TOTAL CORRECTION AFTER 2ND TI PASS= +9.5'. 12:30 14:00 LU SHOOT GUN 1 @ 16703'-16710'. POOH. MAX PI RATE FOR GUN 1' 3 BPM @ 2000 PSI 0NHP). PUMP PRESSURE WAS 2900 PSI MAX. RIH W/GUN 2. 20' X 2.5" HSD 4 SPF. CCL TO TOP SHOT=5.5' , CCL TO BOT OF GUN=25.5' , OVERALL LENGTH=35' 1000'...BEGIN PUMPING 2 BPM @ 2000 PSI. 4500' 3 BPM @ 2500 PSI. 15:20 TI GUN 2. ADD +3'. 15:30 SHOOT GUN. 2 @ 16703'-16683'. POOH. 17:00 RIH W/GUN 3. 20' X 2.5" HSD 4 SPF. CCL TO TOP SHOT=5.5' , CCL TO BOT OF GUN=25.5', OVERALL LENGTH--35' 18:20 TI GUN 3 18:35 SHOOT GUN 3 16663' - 16683'. POOH 21:00 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $4,800.00 $4,800.00 SCHLUMBERGER $14,528.00 $14,528.00 TOTAL FIELD .ESTIMATE $1 9,328.00 $1 9,328.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1997 ORIGINAL Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1C-12 (Permit No. 96-177) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1C-12. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad MAY 6 1997 0il & Gas (:;ohs, ~9iI]Ill[SBi0~: · . .... STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION C,..MMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-177 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-22719 4. Classification of Service Well !5. 12. 17. 22. Location of well at surface ..,r ................ ,~;C},,v;~-~Ti~}~,;~ .~~ 1234' FNL, 649' FWL, Sec 12, T11N, R10E, UM ~ ..... ~ At top of productive inte~al I..~~2~~ 1864' FSL, 2507' FWL, Sec. 17, T11 N, R11 E, UM ~ F[~, ..... ~/; At total depth ~ ~~ ~ 1704' FSL, 2485' FEL, Sec. 17, T11N, R11E, UM .i~';~t~-~~ Elevation in feet (indicate KB, DF, etc.) ]6. Lease Designation and Serial No. RKB 41', Pad 61' j ADL 28243, ALK 3814 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 10-12 11. Field and Pool Kuparuk River Date Spudded i13. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 11/17/96 12/14/96 I ,, 1/29/97 j ..... N/.A... MSq .... One Total Depth (MD+T~)'I~) 118. Plug BaCk ?Pth (MD,+,TVD)119. Directional Survey~20~ Depth Where SSSV set~21~ ThiCkneS,s of Permafrost 17096 6804 FT~ 17006 6743 Pr] I~Yes ~Uo I 493' MDi 1650 (Approx.) Type Electric or Other Logs Run GR/Res, GR/CCL CASING, LINER AND CEMENTING RECORD CASING S~ZE WT. PER FT. SETTING DEPTH il HOLE ToP Bo'FrOM j ..... _S_!.z__E Surf. 121' I 24" Surf. 10223' [___1___2 :_2__5'_'__ Surf. 16480' [_ 8:.5__i~ GF~DE 16" 62.58# H-40 9.625" 40# L-80 26# L-80 5" 18# L-80 16322' Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD 16710-16727' 6552'-6563' 4 spf MD TVD ORIGINAL CEMENTING RECORD AMOUNT PULLED 251 sx ArcticSet I 1380 sx ASLW, 1110 Class G, 61 sx AS I ':1--~ b--~')~-- Oi-~-~ G 159 sx Class G 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 16369' PBR @ 16342' .5I1 ............................... 26. ACiD FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1 671 0'-1 6727' pumped 15595# in perfs and left 583# in pipe 27. PRODUCTION TEST Date First Production 2/12/97 Date of Test iHours Tested 4/10/97 i 12 Flow Tubing!Casing Pressur~ Press. 17~ 0 28. !MethOd of Operation (Flowing, gas lift, etc.) i Flowing PRODUCTION FoR J OIL-BBL GAS-MCF TEST PERIOD ' I 319 274 ~-~(~U L~-'~-'-~-J-Oi~-~-~ ..... GAS-MCF 24-HOUR RATE ] 606 573 CORE DATA I WATER-BBL 115 I -WATER-BBL 230 CHOKE SIZE GAS-OIL RATIO 176 946 I Oi~-'~-R~,-~(-~-A PI (CORR) ~21 o Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 BAY 6 1997 ~Jl & Gas Cons. Commiss,, ~-I~]'10]'agl~ Submit In Duplicate 29. Geologic Marl, .... ' 30. '-- Formation Tests Measured ~ True Vertical i Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 16662' 6521' Annulus left open - Freeze protected annulus with diesel. Bottom Kuparuk C 16806' 6613' Top Kuparuk A 16978' 6725' Bottom Kuparuk A 17089' 6800' 31. List of AttaChme~'ts .................... Summary of Daily Drilling Reports, Surveys i32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Prepared By Name/Number: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 199 7 Date: 2/7/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-12 RIG:PARKER 245 WELL ID: AK8669 TYPE: AFC: AK8669 AFC EST/UL:$ 2460M/ 2952M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:il/17/96 START COMP: WI: 55% SECURITY:0 AP1 NUMBER: 50-029-22719-00 FINAL:12/19/96 11/17/96 (D1) TD: 814' (814) SUPV:GRW DAILY:$ 11/18/96 (D2) TD: 1420' (606) S UP V: GRW DAILY:$ 11/19/96 (D3) TD: 3881' (2461) S UP V: GRW DAILY:$ 11/20/96 (D4) TD: 6130' (2249) SUPV: GRW DAILY:$ 11/21/96 (D5) TD: 6995' (865) S UP V: GRW DAILY:$ 11/22/96 (D6) TD: 7283' (288) SUPV: GRW DAILY: $ 11/23/96 (D7) TD: 8852' (1569) S UP V: GRW DAILY: $ 11/24/96 (D8) TD: 10236' (1384) S UP V: GRW MW: 9.6 VISC: 98 PV/YP: 32/35 APIWL: 9.5 DRILLING Move rig 15' from lC-Ii to lC-12. Accept rig @ 05:30 hrs. 82,211 CUM:$ 82,211 ETD:$ 208,747 EFC:$ .2,333,464 MW: 10.5 VISC: 85 PV/YP: 38/34 APIWL: 6.8 DRILLING PROCESS CUTTINGS, FREEZE PROTECT WELL. POOH TO 157' TIGHT @450' RIH, ICE PLUG FROM 800' WASH/REAM TO 814'. DRILL FROM 814' TO 1363' MADE CONNECTION - PIPE STUCK. WORK PIPE FREE. DRILL 1363' TO 1420' 88,761 CUM:$ 170,972 ETD:$ 246,127 EFC:$ 2,384,845 MW: 10.5 rISC: 82 PV/YP: 36/34 APIWL: 8.2 DRILLING DRILL 1420' TO 3881' WIPER TRIP TO TOP OF HWDP. HAD TO BACK REAM OUT OF HOLE. FIRST 10 STANDS TIGHT. 79,735 CUM:$ 250,707 ETD:$ 397,932 EFC:$ 2,312,775 MW: 10.5 VISC: 94 PV/YP: 31/44 APIWL: 7.8 POOH FOR NEW BIT PUMP LO VIS/HI VIS SWEEP. RECOVERED LARGE VOLUME CUTTINGS/CAVINGS. DRILL FROM 3881' TO 6130'. PUMP- LO VIS/HI VIS SWEEP. 84,732 CUM:$ 335,439 ETD:$ 536,659 EFC:$ 2,258,780 MW: 10.7 VISC: 84 PV/YP: 31/44 APIWL: 6.2 POOH TO CHECK MOTOR PUMP OUT OF HOLE. PU NEW BIT. RIH TO TD. DRILL FROM 6130'-6995' 95,794 CUM'6 431,233 ETD'$ 590,016 EFC:$ 2,301,217 MW: 10.8 VISC: 75 PV/YP: 38/40 APIWL: 4.8 DRILLING @ 7500' Drill from 6995' to 7105'. POOH. Backside blade on bottom stabilizer work away. RIH with new motor and bit %3. Wash and ream from 2394' to 2765', 5755'-6129', 6503'-7015'. Drill from 7105'-7283' 79,964 CUM:$ 511,197 ETD:$ 607,781 EFC:$ 2,363,416 MW: 10.8 rISC: 72 PV/YP: 35/38 APIWL: 4.0 DRILLING @ 9400' Drill from 7283' to 8852' 98,034 CUM:$ 609,231 ETD:$ 704,563 EFC:$ 2,364,668 MW: 10.8 rISC: 72 PV/YP: 35/33 APIWL: 4.0 TOOH FOR CASING Drill from 8852' to 10236' Pump lo vis/hi vis sweep. Pump slug. Short trip to 7075' with no problems. RIH to 10236' with no problems. No fill. Date: 2/7/97 ARCO ALASKA INC. WELL SUMMARY REPORT DAILY:$ 11/25/96 (D9) TD:10236' ( 0) SUPV:GRW DAILY:$ 93,251 CUM:$ 702,482 ETD:$~JaSkR~,~§~0~G~BiS~,371,430 Anchorage MW: 10.8 VISC' 62 PV/¥?: 30/18 A?IWT,. 3.8 CEMENTING Run 9-5/8" casing to 10223'. Prepare to cement. 74,947 CUM:$ 777,429 ETD:$ 791,052 EFC:$ 2,446,377 11/26/96 (D10) TD:10236' ( 0) SUPV:DCL DAILY:$ MW: 0.0 risc: 28 PV/YP: 0/ 0 APIWL: 0.0 DRILL OUT ES CEMENTER Pump cement. Test BOPE equipment to 300/5000 psi. 316,967 CUM:$ 1,094,396 ETD:$ 791,052 EFC:$ 2,763,344 11/27/96 (Dll) TD:10236' ( 0) SUPV: DCL DAILY:$ MW: 8.5 VISC: 45 PV/YP: 12/14 APIWL: 18.6 DRILLING Drill out cement and ES cementer. Test casing to 2000 psi. Pump pill. Drill out cement stringers and cement from 9679' to 10096' Drill out land collar. Drill out float collar and cement to 10140' 121,186 CUM:$ 1,215,583 ETD:$ 791,052 EFC:$ 2,884,531 11/28/96 (D12) TD:12101' (1865} SUPV:DCL DAILY:$ MW: 8.9 VISC: 47 PV/Y?: 13/ 0 APIWL: 7.4 DRILLING Drill out floats, cement and 10' of new hole. Perform LOT. Drilling from 10246' to 12101' 108,791 CUM:$ 1,324,~74 ETD'$ 932,154 EFC'$ 2,852,220 11/29/96 (D13) TD:14476' (2375) SUPV:DCL DAILY:$ MW: 9.1 VISC: 48 ?V/Y?: 16/21 APIWL: 6.6 DRILLING Drilling from 12101' to 14476' 95,203 CUM:$ 1,419,577 ETD:$ 1,111,842 EFC:$ 2,767,735 11/30/96 (D14) TD:15600' (1124) SUPV:DCL DAILY:$ MW: 9.2 VISC: 51 PV/YP: 19/21 APIWL: 5.4 DRILLING Drilling from 14476' to 15571' Circ lo/hi vis sweep. POH to shoe. Tight spot at 13960' RIH to TD. No problems. Drilling from 15571' to 15600' 80,969 CUM:$ 1,500,546 ETD:$ 1,196,881 EFC:$ 2,763,665 12/01/96 (D15) TD:16495' (895) SUPV: DCL DAILY:$ MW: 9.2 VISC: 48 PV/Y?: 20/22 APIWL: 5.4 POH TO RUN CSG Drilling from 15600' to 16495' Circ lo/hi vis sweep. 15 std wiper trip. Tight from 15850' to 15576'. Circ lo/hi vis sweep. 87,150 CUM:$ 1,587,696 ETD:$ 1,264,595 EFC:$ 2,783,101 12/02/96 (D16) TD:16495' ( 0) SUPV:DCL DAILY:$ MW: 0.0 rISC: 47 PV/YP: 17/18 CEMENT 7" CSG RU to run casing. Held pre-job safety meeting. casing to 13000' 76,030 CUM:$ 1,663,726 ETD:$ 1,264,595 EFC:$ AP I WL: 5.4 RIH w/7" 2,859,131 12/03/96 (D17) TD:16495' ( 0) SUPV:DCL DAILY:$ MW: 11.4 VISC: 52 PV/Y?: 26/20 APIWL: 5.2 LD 5" DP RIH w/7" casing to 16485'. Attempt to work pipe. Stuck pipe at 16480' Pump cement. Freeze protect 7" x 9-5/8" annulus. 283,678 CUM:$ 1,947,404 ETD:$ 1,264,595 EFC:$ 3,142,809 Date: 2/7/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/04/96 (D18) TD:16495' ( 0) SUPV:DCL DAILY:$ 12/05/96 (D19) TD:16505' ( 10) SUPV:DCL DAILY: $ 12/06/96 (D20) TD:16607' (102) SUPV: DCL DAILY:$ 12/07/96 (D21) TD:16672' ( 65) SUPV:DCL DAILY:$ 12/08/96 (D22) TD:16672' ( 0) SUPV:DCL DAILY:$ 12/09/96 (D23) TD:16694' ( 22) SUPV:DCL DAILY:$ 12/10/96 (D24) TD:16694' ( 0) SUPV:DCL DAILY:$ 12/11/96 (D25) TD:16750' ( 56) SUPV:GRW DAILY: $ MW: 11.8 VISC: 54 PV/YP: 28/18 APIWL: 4.8 PU 3.5" DP Test BOPE to 300-5000 psi w/annular to 3000 psi. PU and RIH w/HWDP and 3.5" DP. 94,629 CUM:$ 2,042,033 ETD:$ 1,264,595 EFC:$ 3,237,438 MW: 10.1 VISC: 48 PV/YP: 24/16 APIWL: 4.6 CIRC AND CONDITION RIH with 3.5" drillpipe. Drill float collar, cement, float shoe and 10' new formation to 16505' Circulate and clean mud. Perform FIT to 14.0 ppg EMW. Results questionable. Swap out to 11.8 ppg mud. Perform FIT %2 to 14.0 ppg EMW. Thaw ice plug in drillpipe and prepare to drill ahead. 88,659 CUM:$ 2,130,692 ETD:$ 1,265,352 EFC:$ 3,325,340 MW: 11.8 VISC: 49 PV/YP: 30/25 APIWL: 4.4 DRILLING Drilling from 16505' to 16607' Hole started taking mud. Fluid level dropping. Spot 50 bbls 20 ppb LCM. Pressure formation to 720 psi for a 14 ppg EMW. 104,717 CUM:$ 2,235,409 ETD:$ 1,367,490 EFC:$ 3,327,919 MW: 12.0 rISC: 56 PV/YP: 36/26 APIWL: 4.0 RIH Drilling from 16607' to 16672'. No mud loss while drilling. Had break in top of 'C' sand from 16666' to 16672'. Monitor well. No flow. CBU. Oil and gas cut mud at bottoms up. Increase mud weight to 12.0 ppg. Monitor well. CBU. No gas or oil cut mud. Monitor well. OK. 89,555 CUM:$ 2,324,964 ETD:$ 1,464,010 EFC:$ 3,320,954 MW: 12.2 VISC: 58 PV/YP: 37/31 APIWL: 4.2 MU CORE BHA Monitor well. Had slight flow. Hole packing off. Rotate and' reciprocate pipe. Had gas and oil cut mud to surface. Increase mud weight to 12.2 ppg. 82,243 CUM:$ 2,407,207 ETD:$ 1,464,010 EFC:$ 3,403,197 MW: 12.2 VISC: 57 PV/YP: 33/35 APIWL: 4.2 POH W/CORE (22') Wash and ream from 16480' to 16672' Core from 16672' to 16694' 79,327 CUM:$ 2,486,534 ETD:$ 1,496,678 EFC:$ 3,449,856 MW: 12.2 VISC: 58 PV/YP: 34/32 APIWL: 4.6 CORING @ 16700' L/D inner core barrel. Recovered 16 of 22' of core. TIH with another core barrel. 78,981 CUM:$ 2,565,515 ETD:$ 1,496,678 EFC:$ 3,528,837 MW: 12.4 rISC: 62 PV/YP: 35/35 APIWL: 4.4 POOH W/CORE BARREL Wash and ream 16480' to 16694' Core from 16694' to 16700' Monitor well - flowing slightly. CBU. No gas/oil cut mud. Monitor well - dead. Well flowing slightly. TIH. 86,439 CUM:$ 2,651,954 ETD:$ 1,579,834 EFC:$ 3,532,120 Date: 2/7/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 12/12/96 (D26) TD: 16750' ( 0) SUPV: GRW DAILY:$ MW: 12.4 VISC: 58 PV/YP: 33/32 WASHING TO BOTTOM RIH to 16744'. Weight up to 12.4 ppg. No gas/oil BU. L/D core. RIH. 78,712 CUM:$ 2,730,666 ETD:$ 1,579,834 EFC:$ APIWL: 4.2 seen on 3,610,832 12/13/96 (D27) TD:16866' ( 116} SUPV:GRW DAILY:$ MW: 12.4 VISC: 58 PV/YP: 35/34 APIWL: 4.2 WASHING TO BOTTOM RIH to 16480'. Wash and ream and MAD pass to 16750' . Drill from 16750' to 16866' Test BOPE. 126,697 CUM:$ 2,857,363 ETD:$ 1,752,086 EFC:$ 3,565,277 12/14/96 (D28) TD:17089' (223) S UP V: GRW DAILY:$ MW: 12.4 vise: 60 PV/YP: 30/32 APIWL: 4.0 POOH TO RUN LINER RIH to 16770'. Wash to 16866' Drill from 16866' to 16918' Circ/cond gas cut mud. Mud cut to 10.4 ppg. Drill from 16918' to 17089' 80,741 CUM:$ 2,938,104 ETD:$ 2,083,225 EFC:$ 3,314,879 12/15/96 (D29) TD:17089' ( 0) SUPV:GRW DAILY:$ MW: 12.4 VISC: 62 PV/YP: 32/32 APIWL: 4.0 RIH W/LINER Circ/cond gas cut mud. Mud cut to 10.4 ppg. Hold safety meeting. RIH w/liner to 7291' 73,700 CUM:$ 3,011,804 ETD:$ 2,083,225 EFC:$ 3,388,579 12/16/96 (D30) TD: 17089' ( 0) SUPV: GRW DAILY:$ MW: 12.4 VISC: 57 PV/¥P: 27/29 APIWL: 4.0 PREPPING TO L/D D.P. Circ/cond mud. RIH w/liner to 14394' Circ out gas cut mud. RIH w/liner to 17089'. CBU. 79,755 CUM:$ 3,091,559 ETD:$ 2,083,225 EFC:$ 3,468,334 12/17/96 (D31) TD:17089' ( 0) SUPV:GRW DAILY:$ MW: 12.5 VISC: 61 PV/YP: 34/33 APIWL: 4.0 RUNNING TUBING Pump cement. Bump plug and set hanger. Set liner packer. 106,437 CUM:$ 3,197,996 ETD:$ 2,083,225 EFC:$ 3,574,771 12/18/96 (D32) TD:17089' ( 0) SUPV:GRW DAILY:$ MW: 12.5 VISC: 61 PV/YP: 34/33 LANDING TUBING Hold safety meeting. Run 3.5" tubing and GLM's. 73,645 CUM:$ 3,271,641 ETD:$ 2,083,225 EFC:$ APIWL: 4.0 3,648,416 12/19/96 (D33) TD: 17096' ( 7) S UP V: GRW DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 R/D RIG Hold safety meeting. Test tubing to 3500 psi for 15 min. Test annulus to 2500 psi for 15 min. Release rig 1/19/96 @ 2400 hrs. 247,171 CUM:$ 3,518,812 ETD:$ 2,093,619 EFC:$ 3,885,193 End of WellSummary for Well:AK8669 G 1997 Oil & 6as Cons, Oommiss,' ~a. nchorage ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A Kl(1C-12(W4-6)) 1C-12 DATE 01/29/97 DAY 5 JOB SCOPE PERFORATE? PERF SUPPORT DAILY WORK PERFORATE F/16~710 - 16~727' ELM OPERATION COMPLEIE [ SUCCESSFUL YES 0 PSII 1200 PSI SUMMARY Initial Inner Ann 0 PSI I JOB NUMBER 1228961549.2 UNIT NUMBER 8283 KEY PERSON SUPERVISOR SWS-JOHNSON BLACK Final Inner Ann ~ Initial Outer Ann Final Outer Ann 1200 PSII 80 PSI 80 PSI DAILY PERFORATE F/16,710 ~ 16,727' ELM W/2.5" HSD @ 4SPF @ 180 DEG PHASING ( 2 SPF ~ 59 DEG F/HI SIDE & 2 SPF - 121 DEG F/HI SIDE). NOTE: UNSURE OF ORIENTATION DUE TO USE OF PETROLINE ROLLERS. TIME LOG ENTRY 08:30 13:00 ARRIVE ON LOCATION, SWS (JOHNSON & CREW) & LRS. SB F/HARDLINE & FLOWCROSS RU. RU SWS & LRS. MU GUN ASSEMBLY - GR/CCL/PETROLINE ROLLERS/20' HSD GUN 03//17' CHARGES)/PETROLINE ROLLERS/WT BAR (TL- 44'). PT BOPE & LINES TO 2500 PSI. TGSM - JOB OVERVIEW, SPILL ISSUES & BLEED TANK USAGE. RIH W/GUN ASSEMBLY W/INITIAL DIESEL PUMP RATE OF 2 BPM. GUN ASSEMBLY STOPPED @ 9980' ELM. INCREASED PUMPRATE TO 4 BPM. TAGGED BOTTOM @ 16,991' ELM. TIE INTO 12/16/96 SPERRY SUN GR. 16:45 PERFORATE +/- 150 PSI OVERBALANCE F/16,710 - 16,727' ELM W/2.5" HSD @ 4 SPF, 180 DEG PHASED ( 2 SPF - 121 DEG F/HI SIDE & 2 SPF - 59 DEG F/HI SIDE ). NOTE: UNSURE OF ORIENTATION DUE TO USE OF PETROLINE ROLLERS. SAW LINE & PRESSURE INDICATION. POOH W/GUN ASSEMBLY & LOG JEWELRY. 18:30 AT SURFACE. ALL SHOTS FIRED. RD SWS & LRS. 19:30 OFF LOCATION & TURN OVER TO PRODUCTION. READY F/SLICKLINE SPF-~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC KRU/1C- 12 500292271900 NORTH SLOPE BOROUGH COMPUTATI ON DATE: 4 / 14 / 97 DATE OF SURVEY: 121296 MWD SURVEY JOB NUMBER: AK-MM-60172 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -102.00 120.00 120.00 18.00 280.86 280.85 178.85 374.76 374.71 272.71 466.64 466.45 364.45 0 0 0 0 0 4O 2 17 4 7 N .00 E .00 .0ON .00E N .00 E .00 .00N .00E N 81.43 E .42 .14N .93E N 76.88 E 1.74 .65N 3.31E N 40.83 E 2.87 3.57N 7.26E .00 .00 .72 2.48 4.32 556.61 556.07 454.07 647.51 646.28 544.28 735.14 732.63 630.63 827.99 823.24 721.24 920.32 912.80 810.80 5 52 8 15 11 19 13 51 14 15 N. 33.34 E 2.07 9.86N 11.90E N 47.60 E 3.23 18.14N 19.28E N 51.47 E 3.59 27.74N 30.66E N 53.63 E 2.76 40.02N 46.74E N 59.37 E 1.57 52.36N 65.42E 4.98 6.92 11.59 18.86 28.31 1007.97 997.47 895.47 1099.07 1084.52 982.52 1191.96 1171.99 1069.99 1285.82 1259.59 1157.59 137'9.25 1346.54 1244.54 15 42 18 32 20 49 21 15 21 42 N 64.84 E 2.31 62.91N 85.45E N 69.91 E 3.52 73.13N 110.23E N 77.15 E 3.58 81.88N 140.21E N 81.96 E 1.90 87.97N 173.32E N 84.94 E 1.26 91.86N 207.29E 39.86 55.61 76.57 101.58 128.48 1473.74 1433.71 1331.71 1567.93 1519.59 1417.59 1660.56 1603.24 1501.24 1753.69 1685.85 1583.85 1849.05 1768.19 1666.19 23 42 24 46 26 4 28 54 31 39 N 89.88 E 2.93 93.44N 243.69E S 84.58 E 2.66 91.62N 282.27E S 80.56 E 2.34 86.44N 321.68E S 77.91 E 3.31 78.37N 363.89E S 75.97 E 3.06 67.47N 410.72E 158.67 192.49 228.77 268.96 314.56 1942.75 1846.64 1744.64 2035.11 1920.89 1818.89 2128.85 1992.00 1890.00 2222.86 2058.61 1956.61 2315.53 2119.89 2017.89 34 37 38 19 42 58 46 47 50 24 S 74.19 E 3.34 54.25N 460.21E S 72.67 E 4.11 38.57N 512.81E S 70.35 E 5.22 19.16N 570.68E S 68.34 E 4.33 4.27S 632.72E S 67.94 E 3.91 30.15S 697.21E 363.64 416.67 476.13 541.25 609.75 2408.04 2176.92 2074.92 2499.34 2229.67 2127~.67 2591.68 2279.55 2177.55 2685.37 2326.90 2224.90 2779.81 2372.13 2270.13 53 28 55 56 58 40 60 35 62 10 S 66.53 E 3.53 58.35S 764.35E S 64.99 E 3.04 88.95S 832.29E S 64.42 E 3.00 122.16S 902.54E S 64.12 E 2.08 157.25S 975.35E S 62.07 E 2.53 194.77S 1049.26E 681.72 755.62 832.85 913.26 995.87 2871.76 2413.24 2311.24 2965.10 2451.72 2349.72 3059.57 2487.85 2385.85 3152.18 2519.83 2417.83 3244.35 2548.06 2446.06 64 41 66 35 68 25 71 10 73 9 S 61.62 E 2.79 233.57S 1121.75E S 59.95 E 2.61 275.07S 1195.94E S 56.31 E 4.05 321.16S 1270.04E S 55.86 E 2.99 369.65S 1342.16E S 55.10 E 2.29 419.37S 1414.44E .1077.94 1162.89 1250.15 1336.98 1424.59 ORIGINAL SPF,~'~-~Y-SUN DRILLING SERVICES ANCHOP=AGE ALASKA PAGE ARCO ALASKA, INC KRU/1C-12 500292271900 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/14/97 DATE OF SURVEY: 121296 MWD SURVEY JOB NUMBER: AK-MM-60172 KELLY BUSHING ELEV. = 102.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3522.08 2632.35 2530.35 3802.65 2718.11 2616.11 4084.90 2802.61 2700.61 4364.10 2887.86 2785.86 4645.28 2979.71 2877.71 71 31 S 53.01 E .93 574.68S 1628.67E 72 52 S 52.96 E .49 735.49S 1841.96E 72 16 S 54.62 E .60 894.57S 2059.22E 72 9 S 55.61 E .34 1046.62S 2277.30E 69 42 S 57.36 E 1.05 1193.36S 2498.83E 1688.43 1954.35 2222.75 2488,16 2753.73 4928.34 3070.10 2968.10 5210.93 3148.69 3046.69 5490.27 3222.80 3120.80 5771.47 3301.08 3199.08 6049.89 3382.46 3280.46 73 2 S. 56.43 E 1.22 1339.86S 2723.48E 74 39 S 55.94 E .60 1490.91S 2948.97E 74 34 S 59.13 E 1.10 1635.46S 3176.18E 73 5 S 55.69 E 1.29 1780.89S 3403.72E 72 54 S 56.10 E .16 1930.18S 3624.18E 3021.83 3293.03 3562.30 3832.29 4098.29 6331.14 3464.85 3362.85 6613.45 3550.14 3448.14 6895.39 3638.27 3536.27 7024.61 3680.48 3578.48 7360.65 3785.99 3683.99 73 1 S 57.93 E .62 2076.56S 3849.72E 71 48 S 58.89 E .54 2217.53S 4078.93E 71 45 S 58.06 E .28 2357.56S 4307.21E 70 6 S 60.47 E 2.18 2419.98S 4412.17E 73 17 S 59.25 E 1.01 2580.18S 4688.02E 4367.09 4636.18 4903.98 5026.09 5344.98 7641.20 3862.29 3760.29 7917.02 3936.25 3834.25 8197.97 4012.99 3910.99 8479.24 4084.87 3982.87 8762.62 4159.47 4057.47 75 9 S 61.86 E 1.11 2712.85S 4923.11E 73 44 S 63.03 E .65 2835.76S 5158.65E 74 34 S 57.44 E 1.94 2969.91S 5393.15E 75 48 S 55.05 E .93 3121.00S 5619.21E 73 40 S 58.19 E 1.31 3271.42S 5847.43E 5614.73 5879.76 6149.78 6421.49 6694.69 9042.54 4232.78 4130.78 9321.24 4305.03 4203.03 9695.76 4404.67 4302.67 9880.08 4450.13 4348.13 10161.44 4522.25 4420.25 76 0 S 51.03 E 2.61 3427.83S 6067.45E 73 57 S 54.73 E 1.48 3590.27S 6282.01E 75 12 S 60.93 E 1.63 3782.34S 6587.48E 76 14 S 56.71 E 2.29 3874.81S 6740.26E 74 3 S 58.02 E .90 4021.45S 6969.21E 6964.04 7231.89 7592.71 7771.29 8043.13 10350.62 4575.11 4473.11 10633.44 4653.64 4551.64 10913.67 4725.04 4623.04 11193.86 4790.81 4688.81 11477.60 4858.61 4756.61 73 30 S 55.88 E 1.12 4120.49S 7121.44E 74 15 S 55.48 E .30 4273.68S 7345.83E 76 12 S 55.50 E .70 4427.18S 7569.09E 76 38 S 55.24 E .18 4581.96S 7793.20E 75 42 S 54.81 E .36 4739.88S 8018.95E 8224.68 8496.06 8766.65 9038.62 9313.65 11757.04 4931.54 4829.54 11939.85 4986.43 4884.43 12220.41 5073.14 4971.14 12487.71 5155.04 5053.04 12759.37 5240.25 5138.25 74 1 S 56.16 E .76 4892.71S 8241.18E 71 1 S 55.93 E 1.65 4990.09S 8385.80E 72 58 S 56.21 E .70 5139.00S 8607.16E 71 20 S 56.46 E .62 5280.03S 8818.90E 72 5 S 55.71 E .38 5423.96S 9032.96E 9583.00 9757.20 10023.76 10278.00 10535.73 SPF'--~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA., INC KRU/1C- 12 500292271900 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/14/97 DATE OF SURVEY: 121296 MWD SURVEY JOB NUMBER: AK-MM-60172 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 13034.46 5321.91 5219.91 73 21 S 55.61 E .46 5572.13S 13308.99 5397.69 5295.69 74 35 S 57.00 E .66 5718.49S 13588.07 5474.24 5372.24 73 34 S 55.39 E .66 5867.78S 13860.48 5556.18 5454.18 71 24 S 54.31 E .88 6017.29S 14136.06 5643.42 5541.42 71 40 S 54.14 E .11 6170.11S 9249.85E 10798.10 9469.36E-11061.74 9692.33E 11329.88 9904.71E 11589.11 10116.79E 11849.81 14408.82 5726.59 5624.59 72 48 S. 54.01 E .42 6322 14680.61 5806.17 5704.17 73 8 S 53.54 E .21 6476 14953.68 5882.99 5780.99 74 10 S 52.88 E .45 6633 15228.47 5957.84 5855.84 74 12 S 55.28 E .84 6788 15505.00 6036.78 5934.78 72 36 S 56.74 E .77 6936 15684.71 6089.14 5987.14 73 30 S 57.02 E .52 7030 15777.92 6116.72 6014.72 72 4 S 58.15 E 1.93 7077 15869.40 6146.03 6044.03 70 33 S 58.36 E 1.68 7123 15960.31 6177.55 6075.55 68 52 S 57.97 E 1.88 7168 16051.75 6211.71 6109.71 67 14 S 60.16 E 2.86 7212 .52S 10327.14E 12108.82 .10S 10536.78E 12367.85 .02S 10746.62E 12628.79 .10S 10960.69E 12892.37 .24S 11180.38E 13157.11 .17S 11324.36E 13328.95 .90S 11399.51E 13417.97 .49S 11473.20E 13504.62 .46S 11545.63E 13589.88 .06S 11618.37E 13674.68 16143.00 6248.32 6146.32 65 26 S 61.28 E 2.26 7252 16234.54 6287.99 6185.99 63 10 S 61.24 E 2.48 7292 16323.85 6329.55 6227.55 61 20 S 62.71 E 2.51 7329 16424.96 6381.01 6279.01 57 27 S 64.10 E 4.03 7368 16525.50 6437.21 6335.21 54 34 S 66.09 E 3.29 7403 .94S 11691.26E .60S 11763.58E .74S 11833.34E .71S 11911.14E .83S 11986.73E 13758.18 13840.56 13919.44 14006.12 14088.91 16621.50 6495.25 6393.25 51 1 S 61.67 E 5.21 7437 16817.32 6619.72 6517.72 50 1 S 61.01 E .57 7509 16914.00 6682.46 6580.46 49 2 S 61.10 E 1.03 7545 17036.42 6764.04 6662.04 47 22 S 60.29 E 1.45 7590 17096.00 6804.40 6702.40 47 22 S 60.29 E .03 7611 .42S 12055.38E 14164.99 .91S 12188.02E 14315.95 .51S 12252.38E 14389.42 .16S 12331.96E 14480.60 .89S 12370.04E 14524.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 14524.42 FEET AT SOUTH 58 DEG. 23 MIN. EAST AT MD = 17096 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 121.58 DEG. TIE-INS SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 17,096.00' MD SPEed-'Y-SUN DRILLING SERVICES Ai~CHORAGE A/_~AS KA PAGE ARCO ALASKA, INC KRU/1C- 12 500292271900 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/14/97 DATE OF SURVEY: 121296 JOB NUMBER: AK-MM-60172 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -102.00 .00 N .00 E 1000.00 989.79 887.79 61.99 N 83.50 E 2000.00 1893.08 1791.08 44.86 N 492.32 E 3000.00 2465.39 2363.39 291.48 S 1223.54 E 4000.00 2776.77 2674.77 847.74 S 1993.29 E .00 10.21 10.21 106.92 96.71 534.61 427.69 1223.23 688.63 5000.00 3091.00 2989.00 1377.76 S 2780.59 E 6000.00 3367.80 3265.80 1903.58 S 3584.60 E 7000.00 3672.17 3570.17 2408.48 S 4392.06 E 8000.00 3959.32 3857.32 2872.94 S 5229.16 E 9000.00 4222.36 4120.36 3402.20 S 6035.15 E 1909.00 685.76 2632.20 723.20 3327.83 695.63 4040.68 712.85 4777.64 736.97 10000.00 4478.66 4376.66 3938.75 S 6837.62 E 11000.00 4745.62 4643.62 4474.67 S 7638.19 E 12000.00 5005.99 4903.99 5021.96 S 8432.92 E 13000.00 5312.04 5210.04 5553.48 S 9222.60 E 14000.00 5600.65 5498.65 6094.45 S 10012.11 E 5521.34 743.70 6254.38 733.04 6994.01 739.63 7687.96 693.95 8399.35 711.39 15000.00 5895.62 5793.62 6659.92 S 10782.15 E 16000.00 6192.08 6090.08 7187.79 S 11577.11 E 17000.00 6739.38 6637.38 7576.88 S 12308.69 E 17096.00 6804.40 6702.40 7611.89 S 12370.04 E 9104.38 705.03 9807.92 703.54 10260.62 452.70 10291.61 30.98 THE CALCUTJ~TION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE'~- '~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC KRU/1C-12 5OO2922719O0 NORTH SLOPE BOROUGH COMPUTATI ON DATE: 4 / 14 / 97 DATE OF SURVEY: 121296 JOB NUMBER: AK-MM-60172 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 102.00 102.00 202.00 202.00 302.01 302.00 402.07 402.00 -102.00 .00 100.00 200.00 300.00 .00 N .00 E .00 N .00 E .00 N .02 E .18 N 1.17 E 1.09 N 4.41 E .00 .00 .00 .00 .00 .01 .01 .07 .07 502.28 502.00 602.83 602.00 703.97 702.00 806.15 802.00 909.17 902.00 400.00 5.53 N 8.94 500.00 13.94 N 15.10 600.00 24.08 N 26.15 700.00 36.97 N 42.65 800.00 50.96 N 63.06 E .28 .21 E .83 .55 E 1.97 1.13 E 4.15 2.18 E 7.17 3.03 1012.69 1002.00 1117.53 1102.00 1224.07 1202.00 1331.33 1302.00 1439.21 1402.00 900.00 1000.00 1100.00 1200.00 1300.00 63.45 N 86.64 75.09 N 115.85 84.41 N 151.34 90.20 N 189.69 93.21 N 230.02 E 10.69 3.51 E 15.53 4.85 E 22.07 6.53 E 29.33 7.26 E 37.21 7.88 1548.56 1502.00 1659.18 1602.00 1772.20 1702.00 1889.07 1802.00 2011.21 1902.00 1400.00 1500.00 1600.00 1700.00 1800.00 92.38 N 274.19 86.54 N 321.08 76.44 N 372.73 62.13 N 431.44 42.88 N 498.83 E 46.56 9.35 E 57.18 10.62 E 70.20 13.02 E 87.07 16.86 E 109.21 22.15 2142.59 2002.00 2287.82 2102.00 2450.79 2202.00 2634.92 2302.00 2845.47 2402.00 1900.00 2000.00 2100.00 2200.00 2300.00 15.96 N 579.54 22.23 S 677.59 72.35 S 796.01 138.12 S 935.87 222.27 S 1100.83 E 140.59 31.38 E 185.82 45.23 E 248.79 62.97 E 332.92 84.14 E 443.47 110.54 3099.08 2502.00 3424.89 2602.00 3747.93 2702.00 4082.91 2802.00 4409.73 2902.00 2400.00 2500.00 2600.00 2700.00 2800.00 341.68 S 1300.71 519.60 S 1554.57 703.99 S 1800.22 893.47 S 2057.68 1071.03 S 2313.17 E 597.08 153.62 E 822.89 225.81 E 1045.93 223.04 E 1280.91 234.98 E 1507.73 226.82 4710.79 3002.00 5037.70 3102.00 5412.01 3202.00 5774.63 3302.00 2900.00 3000.00 3100.00 3200.00 1226.69 S 2550.64 1397.71 S 2810.64 1596.24 S 3111.73 1782.59 S 3406.21 E 1708.79 201.06 E 1935.70 226.92 E 2210.01 274.30 E 2472.63 262.62 SPE~I'-~f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASRA, INC KRU/1C- 12 500292271900 NORTH SLOPE BOROUGH COMPUTATI ON DATE: 4 / 14 / 97 DATE OF SURVEY: 121296 JOB NUMBER: AK-MM-60172 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6116.38 3402.00 3300.00 1965.63 S 3676.94 E 2714.38 241.76 6458.34 3502.00 3400.00 2141.15 S 3952.81 E 2956.34 241.95 6779.51 3602.00 3500.00 2299.33 S 4213.82 E 3177.51 221.17 7088.82 3702.00 3600.00 2449.91 S 4464.75 E 3386.82 209.31 7416.96 3802.00 3700.00 2607.56 S 4734.55 E 3614.96 228.14 7794.70 3902.00 3800.00 2782.51 S 5053.99 E 3892.70 277.74 8156.81 4002.00 3900.00 2948.81 S 5359.57 E 4154.81 262.11 8547.85 4102.00 4000.00 3158.69 S 5673.92 E 4445.85 291.04 8919.83 4202.00 4100.00 3355.67 S 5973.12 E 4717.83 271.98 9310.23 4302.00 4200.00 3584.14 S 6273.38 E 5008.23 290.40 9685.33 4402.00 4300.00 3777.43 S 6578.68 E 5283.33 275.10 10087.73 4502.00 4400.00 3983.92 S 6909.10 E 5585.73 302.40 10445.29 4602.00 4500.00 4171.41 S 7196.59 E 5843.29 257.56 10817.00 4702.00 4600.00 4374.00 S 7491.72 E 6115.00 271.71 11242.29 4802.00 4700.00 4608.82 S 7831.91 E 6440.29 325.29 . 11649.69 4902.00 4800.00 4835.24 S 8155.45 E 6747.69 307.40 11987.73 5002.00 4900.00 5015.46 S 8423.31 E 6985.73 238.05 12318.97 5102.00 5000.00 5191.41 S 8685.48 E 7216.97 231.24 12634.97 5202.00 5100.00 5357.28 S 8935.15 E 7432.97 216.00 12964.93 5302.00 5200.00 5534.51 S 9194.88 E 7662.93 229.96 13325.21 5402.00 5300.00 5727.00 S 9482.47 E 7923.21 260.27 13686.22 5502.00 5400.00 5921.25 S 9769.82 E 8184.22 261.02 14004.28 5602.00 5500.00 6096.83 S 10015.41 E 8402.28 218.06 14325.60 5702.00 5600.00 6275.80 S 10262.81 E 8623.60 221.32 14666.23 5802.00 5700.00 6467.92 S 10525.71 E 8864.23 240.62 15023.40 5902.00 5800.00 6673.50 S 10800.11 E 9121.40 257.17 15388.62 6002.00 5900.00 6875.33 S 11087.52 E 9386.62 265.22 15729.65 6102.00 6000.00 7053.54 S 11360.53 E 9627.65 241.03 16026.37 6202.00 6100.00 7200.27 S 11598.10 E 9824.37 196.72 16265.58 6302.00 6200.00 7305.92 S 11787.87 E 9963.58 139.21 16463.38 6402.00 6300.00 7382.57 S 11940.17 E 10061.38 97.80 16632.23 6502.00 6400.00 7441.38 S 12062.72 E 10130.23 68.86 16789.73 6602.00 6500.00 7499.66 S 12169.53 E 10187.73 57.50 16943.80 6702.00 6600.00 7556.38 S 12272.08 E 10241.80 54.07 17096.00 6804.40 6702.40 7611.89 S 12370.04 E 10291.61 49.80 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS spenn -sur, 0 I=11 I_1_ I I~J r= April 14, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re' MWD Survey 1C-12 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 1C-12 Tie in point at surface, interpolated depth at 17,096.00. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska April 9, 1997 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. C_~(0 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs DS 1C-12, AK-MM-60172 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22719-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:! I I--I-- I I~ G WELL LOG TRANSMITTAL To: State of Alaska February 26, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 1C-12, AK-MM-60172 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 1C-12: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22719-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22719-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office B6x--i00360 Anchora§e, Alaska 99510-0360 Telephone 907 276 1215 TO: State AOGC 3001 Porcupine Anchorage, Alaska 99503 DATE: January 16, 1997 AIRBILL: AL646232 AFT#: ABV07-01-16-01 CHARGE CODE: 18503 OPERATOR: AAI O SAMPLE TYPE: CORE CHIPS NAME: KRU lC-12~ NUMBER OF BOXES: I SAMPLES SENT: CORE 1 16,672 TO 16,687 CORE 2 ~ 16,694 TO 16,750 SENT BY: D.L. PRZYWOJSKI UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: ARCO ALASKA, INC. BAYVIEW GEOLOGIC FACILITY P. O. BOX 100360 ANCHORAGE, AK. 99510-0360 AR3B-6003-93 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John~ DATE: Chairman THRU: Blair Wondzell, .4E~ FILE NO: P. I. Supervisor FROM: Doug Amos, ~ ~ SUBJECT: Petroleum Inspector November 27, 1996 aaxhkzdd.doc Confidential' Yes _, No_X, Attachment Only . BOPE Test Parker Rig 245 KRU lC-12 PTD 96-0177 Tuesday, November 26~ 1996: I traveled to Arco's KRU 1C-12 well, to witness the BOPE test on Parker Rig 245. As the attached AOGCC BOPE Test Report indicates there were no failures. I found the location clean and well organized, the rig clean and all equipment in compliance. Parker Rig 245 and it's personnel continue to set the standard for rig excellence on the north slope. SUMMARY: I witnessed the successful BOPE Test at Arco's KRU 1C-12 well on Parker Rig 245. 3.5 Test Hours 23 Valves Tested No Failures Attachment: AAXHKZDD.XLS STATE OF ALASK/-, OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: ~ Drlg Contractor: Parker Drilling Co. Rig No.(,_245.1 PTD # Operator: Arco Alaska Inc. Rep.: Well Name: KRU tC-12 Rig Rep.: Casing Size: 9 5/8" Set @ I0,223 Location: Sec. Test: Initial X Weekly.. Other~ 96-177 DATE: 11/26/96 Rig Ph.# 659-7670 Donnie Lutrick John Crisp 12 T. 11N R. 11E Meridian Umiat MISC. INSPECTIONS: Location Gen.: P Housekeeping: P PTD On Location Yes Standing Order Posted Well Sign P ~ (Gert) Drl. Rig P · '~ Hazard Sec. Yes '~ Yes ~'' FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure 1 250/3,000 250/3,000 250/3, 000 250/3,000 P/F P P P P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N/A Test Press. P/F 250/3, 000 P 250/3, 000 P 250/3,0O0 P 250/3, 000 P 250/3,000 P 250/3,000 P 250/3,000 P 250/3, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves 16 I No. Flanges 38 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure 250/3,000 250/3, 000 Functioned Functioned P/F P P ACC U M U I_&TO R SYST E M: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2,200 3,000 I P 1,700 P minutes 26 sec. minutes 27 sec. Yes Remote: Yes Psig. Number of Failures: 0 ,Test Time(~3.5,) Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good crew and excellent test!! Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector FI-021L (Rev. 12J94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Doug Amos AAXHKZDD.XLS TONY KNOWLE$, GOVERNOR OIL AND GAS October 8, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi, Drlg Engr Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 1C-12 ARCO Alaska, Inc. 96-177 1234'FNL, 649'FWL, Sec 12, T1 IN, R10E, UM 1603'FSL, 2323'FEL. Sec 17, T1 IN, R11E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry. Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. dlffencl c: Dept ofFish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALA5,¢, OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redriil [] lb Type of Well Exploratory [] Stratigraphic Test E] Development Oil X Re-Entry [] Deepen [] Service [] Development Gas r-1 Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 61' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28243, ALK 3814 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1234' FNL, 649' FWL, Sec. 12, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1890' FSL, 2758' FEL, Sec. 17, T11N, R11E, UM 1C-12 #U-630610 At total depth 9. Approximate spud date Amount 1603' FSL, 2323' FEL, Sec. 17, T11N, R11E, UM 1 1/8/96 $200,000 12, Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 C - 11 17303' MD 2323' @ TD feet 15'@ 280' feet 2480 6873' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 73.6° Maximurnsudace 41 45 psig At total depth (TVD) 4500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD 7'VD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 40.0# L-80 BTC 10115 41' 41' 10156' 4530' 3040 Sx Arcticset III & HF-ERW 910 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 16499 41' 41' 16540' 6437' 100 Sx ClassG 6.125" 5" 18.0# L-80 LTC 913' 16390' 6360' 17303' 6873' 120 Sx ClassG HF-ERW 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: trmueeaSvU~ret~cal I;;I Plugs (measured)0 RI G INA L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor '~ . . , Surface R£C£1 Intermediate Production Liner OCT ~ '~ Perforation depth: measured true vertical A!.,'0,_$k8 0il & GaS O0f'lS, Aqfihcr~.~e 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot F"I Refraction analysis [] Seabed report FI 20 AAC 25.050 requirements X 21 .,~kl hereby certify that the foregoing is true and correct to the best of my knowledge Signe Title Drill Site Develop. Supv. Date · ~ t ~ ' Commission Use Only Permit Number I AP'IJqumber _ I Approval date ,~i ~ /¢'./' I See cover letter for -/? ? 150- o2--9' --- > I //'"¢~- ~ ~J other requirements Conditions of approval Samples required Fl Yes I~ No Mud logrequired I~] Yes ~ No Hydrogen sulfide measures ~] Yes [] No Directional survey required 'l~ Yes r-I No Required working pressure for BOPE E~ 2M Fl 3M I~ 5M r-1 1OM Fl 15M Other: d'¢l~irl~i [)avid W, Johnston Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU lC-12 , . . . . . . , , 10 11 12 13 14 15 16 17 18 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (10156')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 5000 psi. Test casing to 2000 psi. Drill out cement and 10° of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (16,540) according to directional plan. Run and cement 7" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 7" casing to 3500 psi. Drill to core point at top of 'C' Sand. Core 60' section through 'C' Sand top. Drill 6-1/8" hole to total depth (17,303') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run & cement 5" liner. Set 7" x 5" liner hanger and liner - top packer. Run completion assembly. Test tubing & annulus to 3500 psi. ND BOPE. NU tubinghead and production tree. Shut in and secure well. Clean location and release rig. RECEIVED 061'3 1 1996 DRILLING Well FLUID PROGRAM KRU 1C-12 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 12.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2682 psi could be reached. Maximum anticipated intermediate pressure is calculated using a intermediate casing leak- off of 14.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 4145 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 5000 psi. The nearest existing well to 1C-12 is 1C-11. As designed, the minimum distance between the two wells would be 15' @ 280' MD. Drilling Area Risks- Risks in the 1C-12 drilling area include lost circulation and high pressures in the Kuparuk formation, which are addressed: 7" casing will be topset above the Kuparuk and Parker 245 will drill out a 6-1/8" hole, and run a 5" liner to TD. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 12.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to leak-off or to a maximum of 16 ppg EMW upon drilling out of the surface casing. The 7" casing shoe will be tested to an equivalent mud weight of 14.0 ppg upon drilling out of the intermediate casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. Ai,~NULAR PUMPING OPERATIONS WELL KRU lC-12 Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well or the nearest dedicated disposal well (2M-23). (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.~ The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1C-12 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1C-12 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4327 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4 5 9 ~ 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, Inc. Pad 1C 12 slot #12 Kuparuk River Unit North Slope, ALaska 3-D H I N % H U H D I S T A N C E C L E A R A N C E Baker Hughes INTEQ REPORT Your ref : 12 Version {:)ur ref : prc~ol~2 License : Date printed : 29-0ct-96 Date created : 18-Jun-96 Last revised : 28-0ct-96 Field is centred on nTO 16 18.576, w150 5 56.5:56 Structure is centred on nTO 19 45.1Ti,w149 30 19.124 Slot Location is nTO 19 33.036,w149 30 0.180 Slot Grid coordinates are N 5968999.562, E 561652.586 SLot local coordinates are 1234.00 S 649.00 E Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object weLLpath PGMS <O-9002'>,,lOGI,Pad lC GMS <O-7780'>,,1,Pad lC GMS <O-7615'>,,2,Pad lC GMS <O-9700'>,,3,Pad 1C GHS <O-7575'>,,4,Pad 1C GHS <O'7753'>,,5,Pad 1C GHS <O'10243'>,,6,Pad 1C GHS <O-9784'>,,?,Pad 1C GHS <O-9600'>,,8,Pad 1C HSS <O-?O00'>,,9GI,Pad 1C 11 Version #3,,11,Pad 1C Closest approach with 3-D HinimumDistance method Last revised Distance H.D. Diverging from 5-Aug-92 2:58.3 20.0 20.0 5-Aug-92 140.1 3000.0 3000.0 5-Aug-92 511.3 2350.0 2350.0 5-Aug-92 602,0 1475.0 1475.0 5-Aug-92 418.3 1650.0 1650.0 5-Aug-92 279.5 1881.2 1881.2 5-Aug-92 109.6 1500.0 1500.0 5-Aug-92 99.6 1125.0 1125.0 5-Aug-92 20.7 280.0 17080.0 5-Aug-92 181.8 20.0 20.0 24-Oct-96 15.0 280.0 280.0 A CO ALASKA, Inc. Structure : Pod 1C Well : 12 Field : Kuporuk-'River-Unif, ' Locofion : North Slope, Aleske East (feet) -> C~at~d b~ jo.e~ ~0~: ~ ~e~l ,000 0 ~ooo 2000 ~000 ~000 ~ooo ~ooo 7000 8000 gooo ,aooo 1~000 ,2000 ,~ooo Oot~ ~lot~cd : 29-0ct-9~ I I [ I I I I I I I I I I I I I I I I I I I I I I I I I I Plot Reference ts 12 Version ~5, C~ord[n~tes ~rc [, ~eet reference elot ~12. ~0~~ 1000 True Vertical Depths are torero,ce RKB (Parker ~245). SURFACE LOCATION: 1234' FNL, 649' FWL ~e~o~e I s c. TllN moEI ~_ ~o~ 1000 700 ~ ~ ¢~ ~ooo = TMD=500 DEP=O ~ 9.00 70O ~ BEGIN TURN TO TARGET TVD=794 TMD:800 DEP:4 ~ 0 ~ ~ ~ A ~ ~, ~ ~ 18.66 ~ Q 1400 % 22.71 DLS:3.0OdegperlOOft 14198' (TO TARGET) ~ ~ 27~%. . ,,,P~AN~ OF ~O~OSXL**~ % V C k ~%~95 B/ PERMAFROST WD=1772 7MB:1862 DEP=306 ~ ~uu ~ 5~ .86 ~ 60°` eO00 ~ ~ 71.92 EOC TVD=2582 TMD=5258 DEP=1400 ~ 2800 ~ I o~v. ~/. ~, ~ I ~ 7000 o MAXIMUM ANGLE ooo ~ ~ ~ ~ ~ DEP=14198 0 T/ W SAK SNDS TVB~ TMD=7864 DEP=5816~ O.O U~ ~ ~ B/ W SAK SNDS ~D=4330 TMD=9447 DEP ~ F~ SEC 17 ~11N RllE ~900 V 5600 =~ "~ ~' ~ 7" CSG PT WD=6437 TMD=16540 DEP=14093 ~ ** TAgGET - T/ KUP SNDS (EOD) TVD=6507 TMD=16666 DEP=14198 ~ 72'3~432 DES: 2.00 dog per 100 ft 6500 c-"O ~A_~~~ T/UNITC WD=6509TMD=16669DEP=14201 ¢ ANGLE ,/UNITB WD=6578 TMD=16790 DEP=14299 ' ~ T/ UNiT A ~D=6684 TMD=16974 DEP=14451 7000 ~ ~ %/ UNIT A5 ~D=6696 TMD=16995 DEP=14468 .... B/ KUP SNDS WB=6758 TMD=17103 BEP=14556 ~ i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i I i i i i i i i i i i i i 700 0 700 1400 2100 2800 3500 4200 4900 5600 6300 7000 7700 8400 9100 9800 10500 11200 11900 12600 13300 14000 14700 15400 Ver~icol Secffon (feet) -> Azimuth 121.58 with reference 0.00 N, 0.00 E from slot #12 280 24.0 2OO 16O 120 A Q3 40 (- 0 O Z 40 8O 120 ~0 2OO 240 Creoted by jone~ Fo]': D Pet,~=sh Dote plotted: 2g-Oct-g6 Plot Reference Is 12 Veto[on Coordfnote= ore fn feet reference =lot ~12. True Vert;cel Depth~ RKB ARCO ALASKA, ne. Structure : Pad lC Well : 12 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 20 80 40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 I I I I I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I 28O 2800 1700 1600 1200 240 2700 1600 500 200 1100 1500 2600 160 ~ 1000 4O0 ' . ......................................... O0 120 ' 900 1400 ~ 2500 1700 ~O ~ 1300 1800 ' 800 ~ 1900 %~°~ ~ 2400 7O0 ~ 'i 600 ,,.,"~00 1200 1200 2000 Ao~----,.~ ~ 500/600 ~~°O--'~('~/'500"~L... 1100 2300 ?~ 2100 '~' 1000 gOO 2200 800 1000 ~ 0 700 ~-=~-~ --~ 2100 ~ ~ (} 80 2000 1800 ~ -- ~60 1700 1600 200 I i I I i i i i i I i i i i I i I i i I I i I i t i i i i { I i I I i i I i I I I i I 24O 20 80 40 0 40 80 120 160 200 240 280 320 560 400 440 480 520 560 600 640 680 720 760 Easf (feel) -> A 80 I Z 0 4o ~ 40 ,6 , 13 5/8" 5000 PS! BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 BOP STACK TEST I I 7- '1 I 1. 16"- 2000 PSI STARTING HF_AD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 1. FILL BOP STACKAND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. KUPARUK RIVER U ,I.T 20" DIVERTER SCHEMATIC 6 4 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. __- · ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. OKI311/9/94 · WELL PERMIT CHECKLIST COMPANY/~,-'"d__,~ ~W~. NAME ./~,~ //~-//~-- PROGRAM:expO dev~redrllE] servel wellboreseg Clann. disposal para mq,,~ FIELD & POOL ~'.~r~./'~ INIT CLASS Z~,~.~.-- /-,..-> ~/ GEOLAREA ~,cc:=.~ ~ UNIT# ' //,'/,"'_~' O ON/OFF SHORE.~.~.Z~ ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. ' G~.OLOG__~.Y ........... APP~ D AT.,E ,, Permit fee attached ...................... N Lease number appropriate .................. N Unique well name and number ................ N Well located in a defined Pool ................. N Well located proper distance from ddg unit boundary .... N Well located proper distance from other weEs ........ N Sufficient acreage available in drilling unit. .......... N If deviated, is wellbore plat included ............. N Operator only affected party .................. N Operator has appropriate bond in force ............ N Permit can be issued without conservation order ...... N Permit can be issued without administrative approval .... N Can permit be approved before 15-day wait. ........ N .... REMARKS Conductor string provided .................. (¢~N . ~ ,.- 14. Surface ca~ng protects all known USDWs ......... ~N /~L~ 15. 16. CMT vol adequate to circulate on conductor & surf csg . . . .(.(.(~..~,N 17. CMT vol adequate to tie-in long s~ng to surf csg ...... 18. CMT will cover all known productive horizons. ........ .~N · 19. Casing designs adequate for C, T, B & pen'nafrost. ..... (~ __ __ . 20. Adequate tankage or reserve piL ............... 21. If a re-drill, has a 10-403 for abndnmnt been approved .... ~-N-~' r-,, __ . 22. Adequate wellbore separation proposed ............ (.~N Z3 -- -/ 23. If diverter required, is it adequate ................ 24. Drilling fluid program schemalJc & equip list adequate .... .,;~NC N 25. BOPEs adequate ........................ 26. BOPE press rating adequate; test to ,~'~ psig./~ 27. Choke manifold complies w/APl RP-53 (May 84) ...... ~,.~,, ~.-~ V/ 28. Work will occur without operation shutdown .......... .~:~N 29. Is presence of H2S gas probable .............. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y ~ ,4) //) 31. Data presented on potential overpressure zones ....... Y//N 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ........... /. Y N 34. Comact name/phone for weekly prome~ reports .... ,/.. Y N [~q:,i~r;tory only] ; GEOLOGY: ENGINEERING: COMMISSION: JDH~ JDN -'" Comments/Instructions: HOW/I~ - A.-~FOR~ rev ~ 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. Sperry-Sun Drilling Services LIS Scan Utility Tue Apr 01 11:26:52 1997 Reel Header Service name ............. LISTPE Date ..................... 97/04/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Tape Header Service name ............. LISTPE Date ..................... 97/04/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MM-60172 R.KRELL D.LUTRICK RECEIVED 1C-12 500292271900 ARCO ALASKA, SPERRY-SUN 01-APR-97 A cflor e INC. DRILLING SERVICES MWD RUN 6 AK-MM-60172 R.KRELL D.LUTRICK MWD RUN 7 AK-MM-60172 P.ROBERTS G.WHITLOCK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 8 AK-MM-60172 P.ROBERTS G.WHITLOCK 12 liN 10E 1234 649 .00 102.00 /vi i CR O Fi i. ED GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 60.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 10223.0 8.500 7.000 16480.0 6.125 17089.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1 THROUGH 4 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 5. MWD RUNS 6 THROUGH 8 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. THE INTERVAL FROM 16672'MD, 6527'TVD TO 16750'MD, 6577'TVD WAS LOGGED WHILE TRIPPING IN THE HOLE FOR THE START OF MWD RUN 7. THIS INTERVAL WAS BEING CORED. 7. RATE OF PENETRATION (SROP) DATA FROM 16672'MD, 6527'TVD TO 16750'MD, 6577'TVD IS THE TOOL LOGGING SPEED (SRAT) WHILE TRIPPING IN THE HOLE FOR THE START OF MWD RUN 7. 8. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DENISE PATRASH OF ARCO ALASKA, INC. ON 01/17/97. 9. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17089'MD, 6780'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10184.0 ROP 10236.0 FET 16444.0 RPD 16444.0 RPM 16444.0 RPS 16444.0 RPX 16444.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 17055.0 17090.5 17062.0 17062.0 17062.0 17062.0 17062.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 5 10236.0 16495.0 6 16495.0 16672.0 7 16750.0 16871.0 8 16871.0 17090.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 10184 17090.5 GR 18.3494 396.858 ROP 5.848 1471.57 RPX 0.1572 17.0895 RPS 0.0963 2000 RPM 0.1127 2000 RPD 0.0591 2000 FET 0.0672 142.423 Mean Nsam 13637.2 13814 117.559 13743 176.897 13710 4.16933 1237 5.89408 1237 83.2345 1237 87.3134 1237 18.0705 1237 First Reading 10184 10184 10236 16444 16444 16444 16444 16444 Last Reading 17090.5 17055 17090.5 17062 17062 17062 17062 17062 First Reading For Entire File .......... 10184 Last Reading For Entire File ........... 17090.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10184.0 16443.5 ROP 10236.0 16495.0 $ LOG HEADER DATA DATE LOGGED: 01-DEC-96 SOFTWARE SURFACE SOFTWARE VERSION: ISC 4.88 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 16495.0 TOP LOG INTERVAL (FT): 10236.0 BOTTOM LOG INTERVAL (FT): 16495.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 57.5 MAXIMUM ANGLE: 76.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0609CG6 $ BOREHOLE _AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.20 48.0 8.5 5OO 5.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 54.4 First Name Min Max Mean Nsam Reading DEPT 10184 16495 13339.5 12623 10184 GR 18.3494 396.858 120.562 12520 10184 RO? 7.7586 903.865 181.367 12519 10236 Last Reading 16495 16443.5 16495 First Reading For Entire File .......... 10184 Last Reading For Entire File ........... 16495 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 16206.0 ROP 16240.5 FET 16444.0 RPD 16444.0 RPM 16444.0 RPS 16444.0 RPX 16444.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 16643 16643 16643 STOP DEPTH 16636 5 16672 0 16643 5 16643 5 5 5 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES {PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 07-DEC-96 ISC 4.88 CIM 5.46 MEMORY 16672.0 16495.0 16672.0 51.0 54.6 TOOL NUMBER P0498SP4 P0498SP4 6. 130 6.1 LSND 11.80 49.0 9.5 60O 4.4 3.000 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1.640 2.800 3.600 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 6 AAPI 4 1 68 RPX MWD 6 OHMM 4 1 68 RPS MWD 6 OHMM 4 1 68 RPM MWD 6 OHMM 4 1 68 RPD MWD 6 OHMM 4 1 68 ROP MWD 6 FT/H 4 1 68 FET MWD 6 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 53.9 Name Min Max Mean DEPT 16206 16672 16439 GR 37.7099 252.61 124.211 RPX 0.1572 9.4354 2.53789 RPS 0.0963 2000 7.91129 RPM 0.1127 2000 247.407 RPD 0.0591 2000 259.607 ROP 5.848 1866.8 120.692 FET 1.2748 111.039 30.94 Nsam 933 862 400 400 400 400 864 400 First Reading 16206 16206 16444 16444 16444 16444 16240.5 16444 Last Reading 16672 16636.5 16643.5 16643.5 16643.5 16643.5 16672 16643.5 First Reading For Entire File .......... 16206 Last Reading For Entire File ........... 16672 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 16637.0 16835.5 FET 16642.5 16842.5 RPD 16642.5 16842.5 RPM 16642.5 16842.5 RPS 16642.5 16842.5 RPX 16642.5 16842.5 ROP 16673.0 16872.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMP~ RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 13-DEC-96 ISC 4.88 CIM 5.46 MEMORY 16871.0 16750.0 16871.0 51.0 51.0 TOOL NUMBER P0588SP4 P0588SP4 6.130 6.1 LSND 12.40 58.0 9.0 45O 4.2 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.600 1.500 2.000 3.400 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 RPX MWD 7 OHMM 4 1 68 8 3 RPS MWD 7 OHMM 4 1 68 12 4 RPM MWD 7 OHMM 4 1 68 16 5 RPD MWD 7 OHMM 4 1 68 20 6 ROP MWD 7 FT/H 4 1 68 24 7 FET MWD 7 HOUR 4 1 68 28 8 57.2 First Name Min Max Mean Nsam Reading DEPT 16637 16872.5 16754.8 472 16637 GR 27.3973 106.427 63.7335 398 16637 RPX 2.461 17.0895 5.99229 401 16642.5 RPS 2.6175 16.3708 6.01112 401 16642.5 RPM 2.7279 15.4131 5.83719 401 16642.5 RPD 2.9155 16.3595 6.13532 400 16643 ROP 23.3474 984.49 262.053 400 16673 FET 0.0672 142.534 21.2196 401 16642.5 Last Reading 16872 5 16835 5 16842 5 16842 5 16842 5 16842 5 16872 5 16842 5 First Reading For Entire File .......... 16637 Last Reading For Entire File ........... 16872.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 16829.5 17055.0 FET 16835.5 17062.0 RPD 16835.5 17062.0 RPM 16835.5 17062.0 RPS 16835.5 17062.0 RPX 16835.5 17062.0 ROP 16864.0 17090.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : 14-DEC-96 ISC 4.88 CIM 5.46 MEMORY 17089.0 16871.0 17089.0 47.4 49.0 TOOL NUMBER P0588SP4 P0588SP4 6.130 6.1 LSND 12.40 60.0 9.5 450 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.200 1.300 1.600 3.500 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 RPX MWD 8 OHMM 4 1 68 8 3 RPS MWD 8 OHMM 4 1 68 12 4 RPM MWD 8 OHMM 4 1 68 16 5 RPD MWD 8 OHMM 4 1 68 20 6 ROP MWD 8 FT/H 4 1 68 24 7 FET MWD 8 HOUR 4 1 68 28 8 57.8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 16829.5 42 2586 2 0733 2 0526 2 0113 2 1081 11 7757 0 2198 First Max Mean Nsam Reading 17090.5 16960 523 16829.5 121.05 80.8599 452 16829.5 5.1706 4.01386 454 16835.5 5.1917 3.96377 454 16835.5 4.9286 3.82854 454 16835.5 4.8875 3.93673 453 16836 1471.57 103.16 454 16864 27.4404 5.06588 454 16835.5 Last Reading 17090.5 17055 17062 17062 17062 17062 17090.5 17062 First Reading For Entire File .......... 16829.5 Last Reading For Entire File ........... 17090.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/01 Maximum Physical Record..65535 File Type ................ LO Next File N~me ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/04/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/04/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File
