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184-129
Imoge Project Well History File Ccl~,~ Page XHVZE This page identifies those items that were not Scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) o Color items: [3 Diskettes, No, [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by T- large scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: r~ Logs of various kinds NOTES: D Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; '/S/ Project Proofing BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE; /S/ Scanning Preparation _~,.__ x 30= ~)(~ + Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: AYES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd HECEIVEL P� STATE OF ALASKA ALA. ,-■OIL AND GAS CONSERVATION COMh_ 3ION DEC 1 6 ?u',ii REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r AOGCC Alter Casing r Pull Tubing 17 Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rf Exploratory r 184-129 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21160-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25667 - 2G-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 7936 feet Plugs(measured) 7620 true vertical 6409 feet Junk(measured) none Effective Depth measured 7837 feet Packer(measured) 7409 true vertical 6329 feet (true vertical) 5997 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 SURFACE 2812 9.625 2849 2708 PRODUCTION 7886 7 7920 6396 Perforation depth: Measured depth: 7590-7604, 7622-7660 c, 2 / a True Vertical Depth: 6136-6147, 6161-6191 SCAN MCD Tubing(size,grade,MD,and ND) 3.5, L-80, 7580 MD,6129 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 7409 MD and 5997 TVD SSSV-BAKER'FVL' @ 1801 MD and 1798 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r • Service r Stratigraphic r 16.Well Status after work: Oil l✓. Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Brett Packer Cad 265-6845 Email J.Brett.Packer@conocophillips.com Printed Name Brett Packer Title Supervising Workover Engineer Signature -% Phone:265-6845 Date f /( /' 3 g. L F RB!;MS DEC 16 2r, Form 10-404 Revised 10/2012 1 /`I /` Submit Original Only ',at ( 04/ F KUP PROD 2G-13 Conoa 'htlIips ft, Well Attributes Max Angle&MD TD Alaska,Inc. Weu WI bore API/U Field Name Wellbore Status ncl(°) MD(ftKB) 'Act Btm(ftKB) ,,,.„.,006," 500292116000 KUPARUK RIVER UNIT I PROD 4780 2,900.00 7,936.0 ... Comment I H2S(ppm) I Date Annotation I End Date KB-Grd(ft) "Rig Release Date 2G-13,12/3/2013 11:20:16 AM SSSV:TRDP 120 11/12/2004 Last WO: 11/10/2013 40.981 10/1/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:TOC 7,622.0 18/302010 Rev Reason:WORKOVER haggea 1 12/3/2013 HANGER;34.9 LII- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-00 WELDED 1 11 ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WVLen(I...Grade Top Thread ..............m,.,.. , ,. i, SURFACE 9 5/8 8.921 37.5 2,849.3 2,706.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Tap(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread PRODUCTION 7 6.276 34.2 7,920.0 6,396.4 26.00 J-55 BUTT Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...WI(Iblft) Grade Top Connection TUBING WO 3 1/2 2.992 34.9 7,581.3 6,129.5 9.30 L-80 EUE-Ord A . -A/CONDUCTOR;38.0110.0• I Completion Details Nominal ID 11'::- Top(ftKB) Top(ND)(ftKB) Top Inc]("I Item Des Corn On) SAFETY VLV;1,80t.5 _ 34.9 34.9 0.14 HANGER CAMERON GEN IV EUE 8rd HANGER 2.992 1,801.5 1,798.5 12.70 SAFETY VLV SSSV,TRMAXX-CMT - 2.813 r,: 7,376.6 5,973.1 40.62 LOCATOR BAKER LOCATOR SUB 2.990 GAS LIFT;2,705.6 7,384.0 5,978.7 40.60 PBR 80-40 PBR 2.990 7,408.5 5,997.3 40.52 PACKER BAKER PREMIER PACKER 2.880 7,4492 6,028.3 40.35 NIPPLE HES LANDING NIPPLE,2.813"'X'PROFILE 2.920 tt 7,580.4 6,128.8 39.37 SOS BAKER SOLID SHEAR OUT SUB 3.000 SURFACE 375-2849.3- l Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/f GAS LIFT;4,257.7 Top(ftKB) Btm(ftKB) (RKS) OMB) Zone Date t) Type Corn 7,590.0 7,600.0 8136.3 6,144.0 A-5,2G-13 9/28/1985 4.0 RPERF 2 1/8"DresserBarKo-0 Deg ph • • 7,590.0 7804.0 6,136.3 6,147.1 A-5,2G-13 8/30/2010 6.0 RPERF Prosector RDX DP 2.5", GAS LIFT;5,379.6 60 deg __ 7,593.0 7,594.0 6,138.6 6,139.4 A-5,2G-13 11/5/1984 1.0 IPERF 4"DA JJ 7,594.0 7,5958 6,139.4 8140.2 A-5,2G-13 11/5/1984 1.0 IPERF 4"DAJJ GAS LIFT 6170 9 7,602.0 7,603.0 6,145.6 6,146.4 A-5,2G-13 11/5/1984 1.0 IPERF 4"DA JJ 7,603.0 7,604.0 6,146.4 6,147.1 A-5,2G-13 11/5/1984 1.0 IPERF 4"DAJJ _ 7622.0 7,660.0 6,161.1 6,190.7 A-4,2G-13 9/28/1985 4.0 RPERF 2 1/8"DresserBarKo-0 Deg ph GAS LIFT:6.8697-- . 7,625.0 7,628.0 6,163.5 6,165.8 A-4,2G-13 11/5/1984 1.0 IPERF 4"DA JJ _ 7,633.0 7,634.0 6,169.7 6,170.5 A-4,2G-13 11/5/1984 1.0 IPERF 4"DAJJ 7,635.0 7,636.0 6,171.2 6,172.0 A-4,2G-13 11/5/1984 1.0 IPERF 4"DA JJ GAS LIFT:7,302.6 7,636.0 7,637.0 6,172.0 6,172.8 A4,2G-13 11/5/1984 1.0 IPERF 4"DA JJ 7,641.0 7,642.0 6,175.9 6,176.7 A-4,2G-13 11/5/1984 1.0 IPERF 4"DA JJ __ 7,647.0 7,648.0 6,180.6 6,181.4 A-4,2G-13 11/5/1984 1.0 IPERF 4"DA JJ LOCATOR:7376 7,654.0 7,657.0 6,186.1 6,188.4 A-4,2G-13 11/5/1984 1.0 IPERF 4"DAJJ Stimulations&Treatments PBR;7,384.0 Mm Top Max Btm r %�1 Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Data "PUMP Corn PACKER,7,408 •5 7,590.0- 7,604.0 6,136.3 6,147.1 FRAC 9/1/2010 PUMP FRAC 110,3259 CARBOLITE PROPPANT INTO FORMATION M Cement Squeezes NIPPLE:74492 Top(ND) Btm(ND) I Top(ftKB) Btm(ftKB) (ORB) (ftKB) Des Start Data Com 7,620.0 7,629.0 6,159.6 6,166.6 CMT PLUG 8/18/2010 PLACED 24 GAL.19.8 PPG CEMENT @ 7616' Mandrel Inserts St III 011 C SOS;7,580.4 011 Top(TVD) Valve Latch Port Size TRO Run m ik _ Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date _ 1 2,705.6 2,603.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 IPERF;7,553.0-7,004.0 _ 2 4,257.7 3,699.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 IPERF;7,584.07,595.0_ 3 5,379.6 4,505.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 RPERF;7,590.0-7,600.0 FRAC;7,590.0 V__= 4 6,170.9 5,087.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 RPERF;7,590.0-7.604.0 = 5 6,869.7 5,5958 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 6 7,322.6 5,932.1 CAMCO KBMG 1'GAS LIFT SOV BEK 0.000 0.0 11/25/2013 IPERF;7.602.07603.0 DCK-2 IPERF;7,603.0-7,604.0 Notes:General&Safety End Date Annotation 10/21/2010 NOTE:View Schematic w/Alaska Schmatic9.0 IPERF;7,625.0.7,6250 CMT PLUG;7,6200 - IPERF;7,633.0-7,634.0 IPERF;7,635 0.7,636.0 IPERF;7,636.07.637.0- RPERF;7,622.07,660.0 IPERF;7,641.0-7,642.0 IPERF;7,647.07,648.0 IPERF;7,654.0.7,657.0.- � PRODUCTION;342-7,920.0 2G-13 Pre and Post Rig Well We'- PRE RIG WELL WORK DATE SUMMARY 7/5/2013 (RWO) : RE-ENERGIZE IC-PO (IN PROGRESS). FUNCTION TEST T& IC LDS (COMPLETE) T-POT (PASSED) T-PPPOT(PASSED) IC-POT(IN PROGRESS) IC-PPPOT(IN PROGRESS). 7/6/2013 (RWO) : MIT-OA(PASSED)TO 1800 PSI, IC POT/IC PPPOT(BOTH FAILED), RE-ENERGIZE IC PO (FAILED). 8/31/2013 DRIFTED TBG. &TAGGED OBSTRUCTION W/2.25 CENT. @ 7320'SLM; MEASURED SBHP (3832 psi)@ 7336' RKB. 9/24/2013 TAG KNOWN OBSTRUCTION @ 7454' RKB & MEASURE BHP (3819 psi). JOB COMPLETE POST RIG WELL WORK 12/2/2013 PULLED SOV @ 7322' RKB. SET 2000 PSI (CSG->TBG)SOV. ATTEMPTED BLOW PLUG WITH REPEATED APPLICATION OF 4500 PSI TO TBG: UNABLE TO SHEAR. IN PROGRESS. 12/3/2013 OPENED SSSV. TAGGED GREY MUD @ 7350'SLM. BAILED MUD @ 7350', NO PROGRESS. READY FOR CTU. 12/6/2013 CTU#6: PERFORM MUD SWAP ON TOP OF SOLID SEAT SHEAR OUT SUB. HOLD PRESSURE ON TUBING AND IA AND ATTEMPT TO RELEASE SOS WITH BAKER 2.12"SI-DI HIPP TRIPPER AND DIESEL IN THE HOLE- UNSUCCESSFUL. CALL IN FOR CONTINGENCY 12 PPG NaBr FROM TANK FARM BUT UNABLE TO GET TRANSPORT DUE TO LACK OF TRUCK AVAILABILITY. IN PROGRESS. Conoc iIIips Time Log & Summary We&len Web Reporting Report Well Name: 2G-13 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/10/2013 12:00:00 PM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase -Code Subcode T Comment 11/10/2013 24hrsummary Nordic 3 Rig camp moved @ 08:00 hrs. Rig release from 3R-26 @ Noon. Rig move from 3R-pad to 2 G-13. Passing 1Q-pad at midnight. 12:30 17:30 5.00 MIRU MOVE MOB P Move Nordic Rig 3 from 3R-26 to E Pit access road 17:30 19:00 1.50 MIRU MOVE OTHR P Set down for CPAI field Crew change 19:00 00:00 5.00 MIRU MOVE MOB P Continue with move, near 1Q pad at midnight. 11/11/2013 Continue with rig move stop at 2C-pad.Wait on weather and phase 3 conditions from 05:00-20:00 hrs. SimOps discussion with CDR2-AC. Continue with rig move.Arrive on 2G pad @ midnight. 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move rig. Stationed at 2- C for crew change out. 05:00 17:00 12.00 MIRU MOVE MOB T Phase 3 conditions-rig move and support equipment on stand by until further notice. 17:00 20:00 3.00 MIRU MOVE MOB T Down to Phase 2 conditions-then Phase 1.Waiting of field wide crew change and flight arrival prior to moving rig. 20:00 00:00 4.00 MIRU MOVE MOB P Start with rig move from 2C to 2G pad.Arrive on pad @ midnight. 11/12/2013 Hang tree in cellar. Spot mats and containment. Spot rig over well, berm up and drop tarps.Accept rig at 07:00hrs 11/12/2013. Pull BPV. Rig up hard line and kill tank. PT line to 250/3000psi Open well up and attempt to circulate through open GLM pocket. Unsuccessful. Rig up HES and fire tubing punch from 7300'to 7310'.Attempt to establish circulation, Unsuccessful. Mobilize slick line to pull station#4 GLM pocket. 00:00 03:00 3.00 MIRU MOVE MOB P Arrive on pad-station near the well, 03:00 04:00 1.00 MIRU MOVE OTHR P Hang tree in cellar and dig out snow from well bore cellar 04:00 06:00 2.00 MIRU MOVE RURD P Lay secondary containment in cellar and 9 rig mats as per Nordic management Spot over well. Berm up and Drop tarps. 06:00 08:45 2.75 MIRU MOVE MPSP P Accept Nordic Rig 3 @ 07:00 hrs Spot cuttings tank, MI shack and Boiler blow down box while warming up lubricator NU lubricator and PT @ 2,500 psi, pull BPV. Lay down and load out lubricator. Page 1of18 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 08:45 11:30 2.75 MIRU MOVE RURD P IPJSM of fluid transfer - Back in and offload KWF from vac trucks RU hardline R har with KDTH, to d , spot and RU Berm and set kill tank. 11:30 12:30 1.00 MIRU WHDBO PRTS P PT kill lines @ 250/3,000 psi-- good test 12:30 14:30 2.00 MIRU WELCTL OTHR P Open up well, SITP= 1,600 psi and SICP=500 psi. SIOCP=80 psi. Bleed SICP off---bled right off Pressure up on IA=25 stks @ .0472 BPS 1.1 bbl's for 1,700 psi on fluid packed IA. Hold IA pressure and bleed TBG to 1,400 psi-flow rate-with no pressure drop on IA. Call Town engineer with facts and discuss options. Decision was made to pressure up on IA to 3,500 psi max in attempt to break circulation thru open pocket in Station#5 @ 7,424-ft. Increase IA pressure to 3,500 psi with 40 psi increase on SITP of 1,500 psi at 41 total strokes. Bleed IA to 1,000 psi with SITP @ 1,550 psi as of 14:30 hrs. 14:30 17:00 2.50 MIRU WELCTL OTHR X Wait on Halliburton E-line to arrive for tubing punch. 17:00 21:00 4.00 MIRU WELCTL ELOG X PJSM,Spot unit. Rig up HES with full pressure control. Pick up Wt Bar, CCL& 10'of2"4 SPF 6.5 gram charge tubing punch. 0°shot phase. Tool length 33.35' Wt 330 lbs Pressure test lubricator to 2500psi. Page 2 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 MIRU WELCTL ELOG Open well up. 1570psi tubing,970 psi IA,80psi oa. Rih with tubing punch on HES to 7323'. Correlate(collar at 7290') Bleed pressure on IA down to 500psi Fire tubing punch shot with top shot at7300'down to 7310'shots in middle of full joint. No pressure change on tubing(1570psi)or IA.(500psi) Bleed pressure on IA down to 50psi and no change on tubing and no continuous returns from IA. Pressure up on tubing to 2000psi with IA closed and no pressure increase was seen on IA. Stop pumping and pressure on tubing came down to 1540psi. Pressure on the IA slowly built to 300psi.Attempted to open choke and attempt circulation again and pressure bled off immediatly and was shut back in and did not build up again. Consult with town engineer and mobilize slick line to pull next dummy in GLM at 6653'. 23:00 00:00 1.00 MIRU WELCTL ELOG PJSM,secure tree and bleed off pressure on surface equipment. Rig down HES. 11/13/2013 Rig down HES. Load pipe shed with 3 1/2"Drill pipe. Rig up slick line.While going in the hole with slick line the Tubing and IA communicated. POOH with slick line. Pump heated sea water around at 1 BPM with LRS. Observe pressures. Pump 12.8ppg mud down tubing. Shut down and observe well.Tubing pressure Opsi IA 1165psi. Continue to pump 12.8ppg mud back to surface. 00:00 02:00 2.00 MIRU WELCTL ELOG X Cont. Rig down HES.All shots fired on tubing punch. 02:00 03:00 1.00 MIRU WELCTL CIRC PJSM,Attempt to circulate down tubing taking returns up the IA. Unsuccessful.Attempt to reverse down backside to stimulate circulation. Unsuccessful. 03:00 03:30 0.50 MIRU WELCTL SFTY P Conduct pre-spud meeting 03:30 07:00 3.50 MIRU WELCTL OTHR P Load pipe shed with 3 1/2"Drill pipe while waiting on slick line to arrive. 07:00 12:30 5.50 MIRU WELCTL SLKL P PJSM, RU Slick line. PT lubricator @ 2,500 psi. RIH w/KOT and was starting to locate when rig floor reported TBG x IA equalization. POOH w/KOT-empty. Hang back Lubricator. Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 19:30 7.00 MIRU WELCTL CIRC P Rig up LRS and pump 65bbls of 180°F sea water 1 BPM 1500psi ICP 1300psi IA. Shut down and strap kill tank. Begin circulate 180°F sea water around with LRS 1 BPM maintain 1700psi on tubing. Pump total of 270bbls get clean sea water back to surface. Shut down and monitor pressures SITP 1032psi SICP 1014psi OA 440psi bleed down to 60psi. 11.8ppg calculated kill wt fluid.With 8.5ppg sea water and 1032psi SITP 12.8ppg gives 319psi over balance. 19:30 21:00 1.50 MIRU WELCTL RURD P Rig down LRS and blow down lines. Line up tree to circulate from the pits taking returns to the kill tank. 21:00 00:00 3.00 MIRU WELCTL KLWL P PJSM,SITP 1032 SICP 1014 OA 60psi Begin pumping 2bpm down tubing with 12.8ppg mud following well kill pressure schedule ICP 1110psi FCP 123psi. Shut down and observe pressures.SITP-Opsi SICP-1165psi. Come back online at 3bpm 400psi on tubing circulate total of 305bbls out to kill tank.Getting 11.7ppg back. Shut down,blow down hard line line up to circulate through the gas buster to the pits. SITP-Opsi SICP-Opsi. Begin circulate back to pits 2bpm 400psi open choke Opsi on choke. Watching returns for 12.8ppg mud 11/14/2013 Continue to circulate and condition mud. Monitor well, IA on vacuum and tubing reading 90psi. Reverse circulate and condition mud to 12.9ppg 13.7ppg coming back at bottoms up. 12.9 in and out. Shut down and flow check-Good. Set BPV. N/D tree, N/U BOPE and test to 250/3000psi. Pull Test dart and BPV. Unseat hanger and attempt to pull out of PBR, unsuccessful. Reverse circulate and condition mud while waiting for HES to arrive for RCT cut. Page 4 of 18 Time Logs Date From - To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 10:45 10.75 .COMPZ WELCTI KLWL P Continue to circulate 12.8ppg down hole and take returns back to the pits. Circulate until 12.7+back. Shut down and check for flow. IA on a vacuum and tubing build to 50psi. Out of balance.Weight pits back up to 12.8 and circulate tubing volume. Shut down and check for pressure. IA on a vacuum and tubing build to 35psi. Condition pits and circulate 12.8+around. Continue to condition well and pits. At 08:30 hrs reverse circulate 240 bbl's @ 4 bpm @ 1,150 psi, lost circulation at 1 point due bleed choke(pack off)regained and continue to Reverse circulate w/1 for 1 returns FCP=900 psi.with 12.9 ppg/56 visc in and 12.9 ppg/78 visc out. seen as high as 13.7 ppg/ 76 visc out while conditioning well. NFT for 30 minutes --Good. Begin conditioning surface volume from 13.0 ppg to 12.9 ppg 10:45 11:00 0.25 COMPZ WELCT[MPSP P Dry rod BPV Conditioning surface volume from 13.0 ppg to 12.9 ppg 11:00 13:00 2.00 COMPZ WHDBO NUND P ND Tree, inspect hanger threads. Install test dart in top of BPV Conditioning surface volume from 13.0 ppg to 12.9 ppg 13:00 15:00 2.00 COMPZ WHDBO NUND P NU BOP 15:00 19:30 4.50 COMPZ WHDBO BOPE P Conduct Initial BOPE @ 250/3,000 psi with 3-1/2 test joint. 24 hr Notice was given @ 18:39 hrs 1 on 11-10-13. Right to witness was waived by Chuck Scheve @ 07:00 hrs @ 11/12/13. 19:30 20:00 0.50 COMPZ WHDBO BOPE P Blow down lines, Rig down test joint. Suck out stack 20:00 20:30 0.50 COMPZ WHDBO MPSP P Verify no pressure on IA,engage test dart/bpv and open poppit.Tubing on a vaccum. Retrieve test dart/bpv. Page 5of18 Time Logs Date From To Dur S.Depth'E. Depth Phase Code " Subcode T Comment 20:30 22:00 1.50 COMPZ RPCOM THGR P Make up landing joint into hanger and verify thread count for full engagement. Make up to Top Drive. BOLDS,verify Opsi on IA. Unland hanger at 50k work weight incrementally up to 145k. Original up wt 48k 80%max pull of 3 1/2"J-55 EUE is 114k+35k blocks=149k Continue to work pipe attempting to pull seals out of PBR with no success. Call HES to mobilize unit on standby, notified the lam the soonest they could dispatch crew due to timing out. 22:00 00:00 2.00 COMPZ RPCOM CIRC P Reverse circulate @6bpm 1200psi MW in 12.8ppg MW out from 11.9-13.9ppg 11/15/2013 Continue to reverse circulate while waiting for HES to arrive. Notified by HES supervisor that crews would not show up at designated time due to equipment failure.Attempt to pull free from PBR, Unsuccessful. Flow check. Rig up HES and RIH with string shot to 7447'and fire.Attempt to run RCT and make cut but could not get arms to catch. POOH with out making cut. RIH with Jet cutter and make cut at 7443'. R/D HES. Confirm pipe is free. Reverse circulate and condition mud. Lay down hanger and begin lay down decompletion. 00:00 03:00 3.00 COMPZ RPCOM CIRC P Continue to reverse circulate 6 bpm @1438psi, 12.8+in 12.8+out. No gains or losses. HES supervisor called and notified that a generator on the e-line unit went down and will be several hours behind schedule. 03:00 04:00 1.00 COMPZ RPCOM THGR T Attempt to pull free from PBR again. Work string up to 145k reciprocating pipe staying 1'above hanger landing profile. Circulate down tubing while working pipe 1 bpm 230psi. 04:00 04:30 0.50 COMPZ RPCOM OWFF T Blow down lines and flow check well Page 6 of 18 Time Logs Date From To Dur S.Death E.Death Phase Code ! Subcode T Comment 04:30 21:30 17.00 COMPZ RPCOM ELOG P Set tubing in slips with120k. Lay down pups above and install 3 1/2" FOSV. PJSM with HES,spot units and off load equipment. 09:00 -11:00 hrs. RIH w/160 gr string shot and set down @ 7,447.5 -ft, pu 2-ft and fire. POOH 11:00-16:00 hrs. Change over to RCT cutter. RIH to 7,445-ft, attempt to set tool-seen tool set then slip, attempt to re set multiple times and same results. POOH w/o firing. 16:00- hrs. MU and PT lubricator-good test. RIH w/2.5" OD Jet cutter, Correlate and fire cutter at 7343'. Indication at surface pipe is cut. POOH with E-line and rig down. 21:30 22:00 0.50 COMPZ RPCOM THGR P Pick up pup and make up to the top drive. Pick up out of slips at 107k and ensure pipe is free. Slack back off and space out so hanger is below top set of pipe rams. 22:00 23:30 1.50 COMPZ RPCOM CIRC P Establish circulation then reverse circulate 2 hole volumes until mud is 12.8+in and out @6bpm 1430psi. No gains no losses during circulation. No noticeable amount of sand or propant over the shakers. 23:30 00:00 0.50 COMPZ RPCOM OWFF P Flow check well-Good 11/16/2013 Lay down decompletion, recover all bands for SSSV. Bent tubing from 7081'to 7443'. Clean and clear floor. Install wear ring. Make up BHA#1. Pick up drill pipe to 7430'.Circulate and condition hole.Service rig. 00:00 00:30 0.50 7,443 7,443 COMPZ RPCOM CIRC P Pump 20bbls of 13.8ppg dry job, chase with 8bbls of 12.8ppg. Blow down lines 00:30 01:00 0.50 7,443 7,425 COMPZ RPCOM THGR P Lay down tubing hanger.Attach control line to spooling unit. 01:00 03:00 2.00 7,425 5,543 COMPZ RPCOM PULL P POOH laying down tubing while spooling control line for SSSV. All 31 S.S. bands were recovered. 03:00 03:30 0.50 5,543 5,543 COMPZ RPCOM RURD P Lay down SSSV and rig down spooling unit remove from floor. Cable and SSSV checked for NORM-ok. 03:30 10:00 6.50 5,543 0 COMPZ RPCOM PULL P Continue POOH with 3 1/2" decompletion watching for scale and corrosion. Bent tubing from 7081'to 7443' Cut joint 11.04'cut joint. OD of cut 3.68" 10:00 11:00 1.00 0 0 COMPZ RPCOM OTHR P Clean and clear floor from trip. Page 7 of 18 Time Logs Date From_To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 COMPZ RPCOM OTHR P Install W/R 6 5/16"ID 6 7/8"OD 9 1/2"Long 12:00 14:00 2.00 0 346 COMPZ RPCOM TRIP P JSA on making up BHA Make up Fishing BHA#1 with T-dog latch and wash pipe 14:00 22:00 8.00 346 7,430 COMPZ RPCOM PULD P Pick up 3 1/2"S-135 Drill pipe and trip in hole with Fishing BHA#1 Fill pipe every 2000' Monitor displacement to the trip tank. 22:00 23:30 1.50 7,430 7,430 COMPZ RPCOM CIRC P Circulate bottoms up and condition the hole @ 6BPM. 12.9ppg in and 12.9ppg out. 23:30 00:00 0.50 7,430 7,430 COMPZ RPCOM SVRG P Service Top Drive and inspect prior to fishing operations. 11/17/2013 Engaged fish and work over while pumping. Pick up and work pipe engaging T-Dog overshot.Work pipe and increase weight up to max pull of 249k and appears packer released.Circulate bottoms up through the choke watching for packer gas. No significant amout seen at surface. Flow check-Good.Attempt to pull, hole swabbing. Circulate and reciprocate pipe across a casing collar to wear packer elements down. POOH hole taking proper hole fill. Flow check at BHA. Lay down packer/PBR assembly. Pick up clean out assembly and TIH tag fill at 7,546'FCO to 7,632'PB TD. 00:00 01:30 1.50 7,430 7,463 COMPZ RPCOM FISH P Up 135k Dn 99k Rot. 101k Tag top of fish at 7436'ORKB attempt to slack off and wash down at 6bpm 2400psi. Unsuccessful. Rotate 20rpm 3400ft/Ibs tq begin to wash over fish.Alternate rotating and static slack off with pumps on and work down to 7463'ORKB. Rotate and set 10k at 7463'constant tq of 42001bs. Shut down rotary and pick up and engage T-Dog overshot at 7456'ORKB. Pull 10k over and bleed jars off. Pull up to 150k and work up to 225k 3x's,pull max at 249k work 3x's and appears packer released pick up and have 15k drag. Pick up 30'and attempt to go back down appears packer hanging up in casing collar.Cannot travel from 7,399'back down to point of original tag at 7,436'. 01:30 04:00 2.50 7,399 7,399 COMPZ RPCOM CIRC P Circulate bottoms up through Poor Boy gas buster as precaution for packer gas. Max mud cut seen 12.6ppg from 12.9ppg. No gains or losses.After bottoms up open circulate conventional at 6bpm 2750psi. 04:00 04:30 0.50 7,399 7,399 COMPZ RPCOM OWFF P Flow check well-Good Page 13 of 18 . ...__.. .__ . .... Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 04:30 06:00 1.50 7,399 7,339 COMPZ RPCOM CIRC P Attempt to pull out of hole,well swabbing. Circulate bottoms up working pipe, finally able to pass back down through a casing collar and reciprocate across it. Set 40k to pass through and pull 20k over back up.Weights drop off and able to pass through easily. Flow check-Good 06:00 12:00 6.00 7,339 346 COMPZ RPCOM TRIP P Trip out of hole watching for swabbing. Hole taking correct hole fill. Drag noticed for 3000'then diminished. POOH to BHA 12:00 12:30 0.50 346 346 COMPZ RPCOM OWFF P Check well for flow-Good 12:30 15:00 2.50 346 0 COMPZ RPCOM PULL P Rack back collars and lay down PBR/Packer assy. All components recovered. Cut joint and tubing pup corkscrewed. Packer dies not all of the way released. 15:00 16:00 1.00 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. 16:00 17:00 1.00 0 363 COMPZ WELCTL PULD P PJSM, Make up fishing BHA#2 17:00 18:00 1.00 363 1,137 COMPZ WELCTL TRIP P Trip in the hole with fishing BHA#2 on 3 1/2"Drill Pipe Monitor hole displacement on the trip tank 18:00 18:30 0.50 1,137 1,137 COMPZ WELCTL SVRG P Service rig, blow down choke line. 18:30 22:30 4.00 1,137 7,546 COMPZ WELCTL TRIP P Trip in the hole with fishing BHA#2 on 3 1/2"Drill Pipe Monitor hole displacement on the trip tank. Tag @7,546' 22:30 00:00 1.50 7,546 7,622 COMPZ WELLPF FCO P Clean out fill from 7,546'to PBD of 7,632'ORKB SLM. Pump at 6bpm 2800psi. Rotate 60rpm 3400tq. Wash last 20'down no rotation and tag cement plug @ 7,632'. Set 10K. 11/18/2013 Circulate and condition hole until clean. Spot 25bbls of corrosion inhibitor. Flow check well. Trip out of the hole 10stands. Pump slug.Trip out and lay down BHA. Pick up bottom completion packer assembly.Trip in hole and tag up at 3971',packer appeared to have set. Consult town engineer,finish packer setting process. Circulate and condition hole clean. Flow check well. 00:00 02:00 2.00 7,632 7,632 COMPZ WELLPF CIRC P Circulate at 7.5 bbl/min.3,540psi rotate and reciprocate pipe at 40rpm. 2 bottoms up. Frac sand and formation sand over the shakers. Circulated until shakers clean. 02:00 02:30 0.50 7,632 7,632 COMPZ WELLPF CRIH P Circulate 25bbls of corrosion inhibitor and spot balanced on bottom. Page 9 of 18 Time Logs Date From To Dur S.Death E. Death Phase Code Subcode T Comment 02:30 03:00 0.50 7,632 7,600 COMPZ WELLPF OWFF P Pick up to top of perforations and no flow check-good 03:00 04:00 1.00 7,600 6,700 COMPZ WELLPF TRIP P POOH to 6700', hole taking correct displacement. 04:00 04:30 0.50 6,700 6,700 COMPZ WELLPF CIRC P Pump dry job 20bbls 14.8ppg 04:30 06:00 1.50 6,700 5,210 COMPZ WELLPF TRIP P POOH with the clean out assembly on 3 1/2"drill pipe. Monitoring displacement on the trip tank. POOH slick. 06:00 06:30 0.50 5,210 5,210 COMPZ WELLPF SVRG P Service rig and blow down choke line. 06:30 08:30 2.00 5,210 393 COMPZ WELLPF TRIP P Continue to trip out of the hole with clean out assembly. Monitoring displacement on the trip tank. POOH slick. 08:30 09:00 0.50 393 393 COMPZ WELLPF OWFF P Monitor well before pulling BHA through the stack-good. 09:00 11:00 2.00 393 0 COMPZ WELLPF PULD P PJSM, Lay down BHA and remove from pipe shed. 11:00 14:30 3.50 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. Rig up rig floor to run completion. 14:30 16:30 2.00 0 244 COMPZ WELLPF RCST P PJSM, Pick up Coil Tubing Drilling preparation completion as per the procedure. 16:30 20:30 4.00 244 3,971 COMPZ WELLPF TRIP P Trip in the hole with bottom packer completion assembly at 60 ft/min as per Baker rep. At 3971'string took weight and set 30k down, attempted to pick up and pulled 115k(15k over). Up wt 100k down wt 75k Appears packer set prematurely.Top of packer @3,781' Notify town engineer and Baker Completion supervisors. Decision made to finish setting packer and fish out. 20:30 21:00 0.50 3,971 3,971 COMPZ WELLPF SFTY T PJSM and discuss change of scope in operation. 21:00 22:00 1.00 3,971 3,791 COMPZ WELLPF PACK T Drop 1 7/16"metal ball and allow to drop for 15minutes. Engage pumps and circulate ball down remainder of the way and pressure up to 1500psi. Hold 1500psi and pick up to 110k and shear out. 22:00 23:30 1.50 3,785 3,785 COMPZ WELLPF CIRC T Pick up 6'. Circulate and condition hole.to 12.9ppg. 23:30 00:00 0.50 3,785 3,785 COMPZ WELLPF OWFF T Flow check well-Good 11/19/2013 Trip out of hole and lay down"J"setting tool. Clean and clear rig floor. Make up packer milling assembly.Trip in hole and mill top set of slips on packer. Circulate B/U,Trip out of hole, rocks and jet cutter debris found in boot baskets.Trip in hole with spear, circulate above fish,engage packer and work free. Page 10 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 3,785 55 COMPZ WELLPF TRIP T Trip out of the hole with 3 1/2"drill pipe racking back. Monitor displacement on the trip tank. 02:00 02:30 0.50 55 0 COMPZ WELLPF PULD T Lay down 3 1/2"pup joint,full joint of drill pipe,and"J"setting tool. No noticeable abnormalities noticed on the setting tool. 02:30 03:00 0.50 0 0 COMPZ WELLPF OTHR T Clean and clear floor 03:00 05:30 2.50 0 345 COMPZ WELLPF PULD T PJSM with Baker Make up packer mill assembly. 05:30 06:00 0.50 345 650 COMPZ WELLPF TRIP T Trip in hole with packer mill assembly on 3 1/2"Drill Pipe from derrick 06:00 07:00 1.00 650 650 COMPZ WELLPF SVRG T Service rig, blow down hard line. Crew change. 07:00 08:30 1.50 650 3,781 COMPZ WELLPF TRIP T Trip in hole with 31/2"Drill pipe to 3781'.Tag top of packer. Monitor displacement on the trip tank. 08:30 12:30 4.00 3,781 3,783 COMPZ WELLPF MILL T Establish milling parameters. Rotational @ 70 RPMs. @ 1300 FTlbs. ICP @ 5 BPM @ 1060 psi. Milled down from 3781 ft.to 3783 ft. Circulated well clean recovered metal shavings 12:30 13:00 0.50 3,783 3,783 COMPZ WELLPF OWFF T monitor well for flow.30 min's 13:00 16:00 3.00 3,783 345 COMPZ WELLPF TRIP T Trip out of the hole to BHA-Flow check 16:00 16:30 0.50 345 0 COMPZ WELLPF TRIP T Rack back collars and lay down Milling BHA Recovered metal shavings on magnets and slip pieces and 1"X 1/2 rocks,and a brass plug in junk baskets. 16:30 18:00 1.50 0 1,760 COMPZ WELLPF TRIP T Picked up&RIH with spear assembly. 18:00 18:30 0.50 1,760 1,760 COMPZ WELLPF SVRG T Service rig and top drive. Crew change. 18:30 19:30 1.00 1,760 3,600 COMPZ WELLPF TRIP T Trip in hole to 3600' 19:30 21:30 2.00 3,600 3,600 COMPZ WELLPF SLPC T Cut&Slip 84'of drill line. Inspect brakes and check crown-o-matic 21:30 23:00 1.50 3,760 3,760 COMPZ WELLPF CIRC T Circulate Hi vis(120)/weighted 13.2# sweep and reciprocate pipe at 8bpm 3,330psi, no significant returns when sweep returned. Pump total of 3 bottoms up. Page 11 of 18 Time Logs Date From To Dur S. Death E.Death Phase Code Subcode T Comment 23:00 00:00 1.00 3,760 3,817 COMPZ WELLPF FISH T Up Wt 87k Dn Wt 77k Circulate lbpm 330psi Engage packer at 3781'and push down to 3817'and set 10k. Pick up and pull 23k over and come free. Pressure come up to 350psi. Shut pump down and pick up hole swabbing. Work packer back down across tight spot and appeared that packer element finally rolled off. Pick up with out pump and hole taking correct fill. 11/20/2013 Circulate B/U @3,817', Flow check well,Trip out of the hole with potential fish, Flow check at collars. Pull BHA and no fish, spear in the released postition.Trip back in hole with spear and engage packer at 4,170' chase to 7,442'bottom. POOH with potential fish, flow check at BHA. Pull BHA and no fish,spear slightly deformed and 1/2 way in the released position. Change out grapple on spear for smaller size. RIH with assembly. 00:00 00:30 0.50 3,817 3,817 COMPZ WELLPF CIRC T Circulate B/U 5 bpm 1448psi 00:30 01:00 0.50 3,817 3,817 COMPZ WELLPF OWFF T Flow check well-Good 01:00 03:30 2.50 3,817 390 COMPZ WELLPF TRIP T Trip out of the hole with spear/packer assembly. 03:30 04:00 0.50 390 390 COMPZ WELLPF OWFF T Check well for flow-Good PJSM on laying down fish 04:00 05:00 1.00 390 0 COMPZ WELLPF TRIP T Continue to POOH No packer recovered.Spear in release postion. 05:00 06:00 1.00 0 1,150 COMPZ WELLPF TRIP T Trip back in hole with spear assembly BHA 06:00 06:30 0.50 1,150 1,150 COMPZ WELLPFSVRG T Service rig,crew change 06:30 14:00 7.50 0 7,442 COMPZ WELLPF TRIP T Trip back in hole with spear assembly. Secure grapple on spear and RIH. Engaged packer @ 4170 taking 5K down&15K up @ csg.collars. pulled up to 3885 ft. no packer indication.continue to RIH to 7442 ft. Up wt.= 132K, Dn Wt. =99K.. up wt.atfer engagement= 136K 14:00 19:00 5.00 7,442 2,990 COMPZ WELLPF TRIP T PJSM, POOH with spear assembly &fish. 19:00 19:30 0.50 2,990 2,990 COMPZ WELLPF SVRG T Service rig, crew change,blow down hard line 19:30 20:30 1.00 2,990 770 COMPZ WELLPF TRIP T Trip out of the hole to BHA 20:30 21:00 0.50 770 770 COMPZ WELLPF OWFF T Flow check well-Good Load floor with tools for clean out run. 21:00 21:30 0.50 770 0 COMPZ WELLPF PULD T Pull out with spear assembly and no fish. Identify where fish was engaged on bottom 3 wickers.Spear in 1/2 released position and slightly deformed. Lay down 4.010"grapple off of spear, inspect spear-Good. Install 3.947"grapple catch 21:30 22:30 1.00 0 312 COMPZ WELLPF TRIP T Run in hole with BHA and drill collars Page 12 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 312 3,030 COMPZ WELLPF TRIP T Check Crown-o-matic Trip in hole with drill pipe monitoring returns to pits 11/21/2013 Trip in hole with#3 Spear run to 6,565'.Circulate and condition the hole.Set Baker retrievamatic and storm valve at 69.5'. Pressure test to 1,000psi. Set test plug,wash stack.Test BOPE to 250/3,000psi witnessed by AOGCC representative John Crisp. N/D BOPE. N/D tubing spool&pull pack-off. No casing growth. Rig up and cut casing off to allow for new generation tubing spool. Set new spool and pack-off and test 250/3,000psi. Install test plug and N/U BOPE. 00:00 02:00 2.00 3,030 6,585 COMPZ WELLPF TRIP T Trip in the hole from 3,030'to 6,585' Monitor displacement to the trip tank. Trip displacement:gtt Calculated displacement 34.5BBLS Actual displacement 34.5 02:00 03:30 1.50 6,585 6,585 COMPZ WELLPF CIRC T Circulate and condition mud.to 12.9#in and out Rate:272gpm Pressure:3200psi Losses:Obbls Highest weight out 13.4# Lowest weight out 12.4# 03:30 04:00 0.50 6,585 6,585 COMPZ WELLPF OWFF T Flow check well-Good 04:00 05:00 1.00 6,585 6,008 COMPZ WELLPF TRIP T Pull 5 stands of pipe for weight/pressure factor for storm packer. 05:00 05:30 0.50 6,008 6,101 COMPZ WELLPF PACK T Pick up Baker Retrievamatic and storm valve and set 69.5'@RKB Up Wt:110k Dn Wt:91k Hang off on packer at 65k 05:30 06:00 0.50 6,101 6,101 COMPZ WELLPF PRTS T Pressure test packer to 1,000psi 7"26#J-55=30.92sq/in ID x 1,000psi test pressure=30,920#+65,000# String weight=95,920#x .035=3,357psi effective casing pressure 80%Burst of 7"26#J-55=3,984psi Page 13of18 Time Logs Date From To Our S. Depth E.Depth Phase Code ! Subcode T Comment 06:00 14:00 8.00 6,101 6,101 COMPZ WELLPF BOPE P Test BOPE to 250/3000 Psi.Tested Alarms,wash BOPE. Land Test plug. Body test BOPE. (1)TD HCR, BLD's,kill #13,Choke 11,12,4, 3.5" Dart. pass. (2)HCR kill,TD man, choke 7,9,10,3, 3.58 IF FOSV. pass. (3)Man kill, Choke 2,5,8, Pass. (4) 3.5 TJ , LPR's, 3.5"8rd FOSV, Choke 6, Pass. (5)3.5"TJ annular, HCR choke, Fail, Isolated annular man kill, retest pass. (6)3.5" Uppers PR's, HCR choke, pass. (7) choke 1 pass. (8) choke 1 flow direction Pass. (9)flow test chokes Man, HCR pass. (10)draw down. IP =3000/2025, 200 drop 18 sec.total recovery 89 sec., nitrgen 1850 psi X 4.Test wittenessed by John Crisp AOGCC. RD testing equipment 14:00 14:30 0.50 6,101 6,101 COMPZ WELLPF OTHR P AAR with crew on BOPE test 14:30 16:00 1.50 6,101 6,101 COMPZ WELLPF NUND P PJSM. ND BOPE 16:00 22:30 6.50 6,101 6,101 COMPZ WELLPF WWSP P RU up PESI.Verify Opsi on OA, ND tubing spool. Pull pack-off. No casing growth. Casing is 1/2"to tall for new generation tubing spool. No seals available for old spool. Use air operated sawzall to cut pipe, not enough stub sticking up to use Wachs cutter. Install new tubing spool and pack-off. Test pack-off to 250/3000psi for 10minutes each.Witnessed by CPAI rep. Install test plug. 22:30 00:00 1.50 6,101 6,101 COMPZ WELLPFNUND P PJSM on Nipple up BOPE. Set DSA Pick stack and set 11/22/2013 N/U BOPE,test breaks to 250/3000psi,set wear ring,equalize and pull storm packer with storm valve.Trip in hole to top of fish and circulate and condition mud. Engage fish and work pipe to confirm catch. POOH with fish and lay down assembly. Clean floor. Safety meeting on pipe shed safety and picking up BHA. Make up clean out run BHA#7. Drill collar in preventer drill. Begin trip in hole with drill oipe. 00:00 02:00 2.00 6,101 6,101 COMPZ WELLPFNUND P N/U BOPE 02:00 03:00 1.00 6,101 6,101 COMPZ WELLPF BOPE P Test all breaks against the blind rams and test plug to 250/3,000psi 5min each-Good 03:00 04:00 1.00 6,101 6,101 COMPZ WELLPF WWSP P Pull test plug and install wear bushing. 6 5/16"ID 6 7/8"OD 9 1/2"Long Page 14 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 6,101 6,000 COMPZ WELLPF PACK P Make up packer retrieving tool. Install TIW and close. Engage storm valve and open.Verify Opsi. Close annular and pick up to release packer. Opsi on back side. Lay down packer and storm valve 05:00 05:30 0.50 6,300 7,430 COMPZ WELLPF TRIP T RIH to TOF @ 7,430' 05:30 07:00 1.50 7,430 7,430 COMPZ WELLPF CIRC T Broke circulation ICP=3220 Psi. @ 5 BPM. Recovered treated mud to cuttings box. 07:00 08:30 1.50 7,447 6,685 COMPZ WELLPF FISH T (Slowed circulation to 3 BPM @ 980 psi worked spear down to 7447'. picked up on fish 30 K over with movement.draging 10 K over. 7410' 50K over pull ,7370' 100K over pull and 50 K-70 k @ csg.collars.. pulled up to 6970 pumped dry job. continue to POOH. lost all drag @ 7140 ft pulled to 6685 ft. Ran back to bottom to validate fish still on. no tag change from full engagement. 08:30 17:30 9.00 7,447 190 COMPZ WELLPF TRIP T POOH with spear assembly. 17:30 19:00 1.50 190 0 COMPZ WELLPF OTHR T Lay down packer and lower assembly, packer assembly milled up, broken packer dies found in tail pipe. 19:00 19:30 0.50 0 COMPZ WELLPF SVRG T Clean and clear rig floor. 19:30 20:30 1.00 COMPZ WELLPF OTHR T Drain stack and look for fish debris. Run test plug in the hole and function each set of pipe preventers and watch for any fish material.=-None observed. Pull test plug. 20:30 21:00 0.50 COMPZ WELLPF TRIP T Get clean out run assembly on cat walk. 21:00 21:30 0.50 COMPZ WELLPF SFTY T Safety stand down-Discuss pipe shed safety with crew and supervisors. Conduct JSA on picking up BHA and mark no entry area in pipe shed. 21:30 23:30 2.00 COMPZ WELLPF TRIP T Make up BHA#7 Clean out run 23:30 23:45 0.25 COMPZ WELLPF SFTY T Conduct Drill Collar in preventer drill. Well secured in 45seconds. Discuss stripping down with a joint of drill pipe across the preventers. 23:45 00:00 0.25 COMPZ WELLPF TRIP T Trip in hole with BHA#7 on 3 1/2"IF drill pipe. Monitor pipe displacement to the pits. Page 15 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11/23/2013 24 hr summary Trip in hole to 7,635'and tag bottom.Attempt to reverse circulate losses too great, Circulate and condition mud, 12.9#in and out. Spot 25bbls of CRW 132 corrosion inhibitor on bottom. Flow check well. POOH LDDP. Lay down clean out run assemb;y. Pull wear ring. Rig up to run completion. Make up completion as per tally and trip in hole picking up tubing form the pipe shed. 00:00 03:30 3.50 500 7,635 COMPZ WELLPF TRIP T Trip in hole with clean out assembly #7 and dry tag TOC @7,635'ORKB. Monitor returns to the pits: Calculated Displacement:39bbls Actual Displacement:36bbls Losses during trip:3bbls 03:30 06:00 2.50 7,628 7,628 COMPZ WELLPF CIRC T Reverse circulate 1 bottoms up with losses factored in. Begin at 3bbl/min attempt 5bbl/min 1680 psi losses @65%reduce to 2bbl/min 1350psi losses slow to 50%. Stop and circulate hole long way due to 50%losses while reversing. ICP:1840psi FCP: 1770 psi Rotate and reciprocate pipe while circulating. 06:00 07:30 1.50 7,628 COMPZ WELLPF CIRC T spoted 25 bbls of CRW-132 treated mud 07:30 15:00 7.50 7,628 300 COMPZ WELLPF PULD P PJSM pooh laying down drill pipe 15:00 17:00 2.00 300 0 COMPZ WELLPF PULD P Laid down BHA clean out mill assembly. 17:00 20:00 3.00 0 0 COMPZ RPCOM OTHR P Change over equipment to run completion string 20:00 00:00 4.00 0 700 COMPZ RPCOM PUTB P Pick up completion assembly as per tally. Baker lock all connections below the packer. Fill pipe every 15 joints with fill up line. 11/24/2013 Continue to trip in hole picking up 3 1/2"tubing completion to 7631.5'. Rig up SLB Digital Slickline with full pressure control for correlation run. 00:00 06:00 6.00 700 3,520 COMPZ RPCOM PUTB P Pick up 3 1/2"tubing completion. Filling every 15 joints due to thick mud and air in tubing with out the ability to circulate.Take displacement to pit#1 filling pipe out of pit#1. 06:00 21:00 15.00 3,520 7,631 COMPZ RPCOM PUTB P continue to pick up completion and RIH filling every 10 jts. Packer is floating running slow to allow for mud bypass. RU Camco to run SSSV control line PT contol line to 5000 psi. continue to RIH to 7631.46'. Last movement was down with 65k on weight indicator. 21:00 22:30 1.50 7,631 7,631 COMPZ RPCOM ELOG P PJSM with SLB Digital Slickline, rig up with full lubricator. Pressure test lubricator to 1,000psi 22:30 00:00 1.50 7,631 7,632 COMPZ RPCOM ELOG P RIH with CCL and Gamma Ray tools for correlation run. Page 16of18 4 ';Time Lags Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/25/2013 24 hr summary Correlate with DSL and adjust pipe tally depth by-7'. Come up 43.19'with string to allign collars with 7"casing collars in CTD side track area. Set packer and test. Shear PBR and space out. Displace hole with sea water then 9.6#CI brine. Flow check.Tested tubing 3,000psi and IA to 3,500psi.Shear SOV.Test SSSV to 1,000psi. Install BPV and test to 1,000psi from below.Wash stack. Inspect rams. Change out annular preventer element. N/D BOPE. 00:00 02:00 2.00 7,632 7,632 COMPZ RPCOM ELOG P Continue to run in hole with DSL—50 ft/min due to heavy mud in hole. 02:00 03:00 1.00 7,632 7,624 COMPZ RPCOM ELOG P Correlate at GLM#6, log from 7,614' SLM, K-1 marker showed at 7,415. -7'correction from original log of 7,408'. SOV corrected from 7,631.46' to 7,624.45. Need to adjust string up 43.19'to put range 3 joints on depth with 7"casing collars. Bottom collar at 7,565, Middle collar at 7,524',Top collar at7483' 03:00 04:00 1.00 7,624 7,624 COMPZ RPCOM ELOG P POOH with DSL and rig down. 04:00 05:00 1.00 7,624 7,581 COMPZ RPCOM PACK P Picked up 43.19'to space out completion. Pressure up on tubing to 3,000psi for 5min and set P acker. Bleed pressure on tubing down to 1000psi and pressure up on IA to 2,000psi and verify packer integrity. Bleed off IA then tubing. Packer set @7,412'center of element, hanging kick out pipe from7483'to 7565'SOV @ 7,581' 05:00 07:00 2.00 7,581 7,581 COMPZ RPCOM HOSO P Pressure up tubing to 2,000psi and pull 122k to shear out PBR. Pick up out of PBR then no go out. Make marks for space out Spaced out completion.6.23'from no go on PBR install hanger.61 stainless bands in hole 07:00 12:30 5.50 7,581 7,581 COMPZ RPCOM CIRC P PJSM RU to circulate out mud. pumped heated sea water with 75 BBL deep clean sweep 35 BBL Hi- Vis sweep. Followed by 250 BBLs of CRW ttreated 9.6 brine. 12:30 13:00 0.50 7,581 7,581 COMPZ RPCOM OWFF P Observered well for flow 30 mins. 13:00 14:00 1.00 7,581 7,581 COMPZ RPCOM HOSO P pulled stack clear of fluids. land hanger. Up wt. 102K Dn wt. 80K 14:00 14:30 0.50 7,581 7,581 COMPZ RPCOM OTHR P RILDS 14:30 17:30 3.00 7,581 7,581 COMPZ RPCOM DHEQ P RU test line. PJSM PT tubing to 3000 psi for 10 min's. PT IA to 3500 psi for 30 min's.chart record. Shear SOV 2385 PSI.Test SSSV from direction of flow to 1000 psi for 5 min's 17:30 18:30 1.00 7,581 7,581 COMPZ RPCOM MPSP P Lay down landing jt. PJSM Install BPV plug . PT to 1000 psi.for 5 min's. Page 17 of 18 Time Logs Date From To Dur S. Death E. Death Phase Code`` Subcode T Comment 18:30 19:30 1.00 7,581 7,581 'COMPZ RPCOM VWWVH P Wash BOPE stack with Swizzle Stick 19:30 22:30 3.00 7,581 7,581 COMPZ RPCOM SVRG P PJSM,change out annular preventer element. 22:30 00:00 1.50 7,581 7,581 COMPZ RPCOM NUND P PJSM, Nipple down BOPE,clean and inspect ram cavities. Clean pits and load out mud product to 3R pad. 11/26/2013 N/D BOPE, NU Tree. PT to 250/5000 psi. pulled BPV. Freeze protected with 75 bbls of diesel.to 2000 ft. set BPV.cleaned cellar. RD kill line. Prep rig,for move. Rig released @ 16:00 hrs 00:00 03:00 3.00 7,581 7,581 COMPZ RPCOM NUND P Continue to N/D BOPE 03:00 08:00 5.00 7,581 7,581 COMPZ RPCOM NUND P Install test dart in top of TWC. N/U tubing head adapter and tree. Test to 250/5,000psi 08:00 08:30 0.50 7,581 COMPZ RPCOM MPSP P Pulled Two way check 08:30 11:30 3.00 COMPZ RPCOM FRZP P Freeze protect well with 75 bbls of diesel pumping down IA ICP=800 psi , FCP=1100 ps. Let equqlize. 11:30 12:00 0.50 COMPZ RPCOM MPSP P install BPV. 0 PSI on well. 12:00 16:00 4.00 COMPZ RPCOM DMOB P Clear lines and broke down load equipment, clean cellar. Rig released @ 16:00 hrs. Page l8of18 • ID • 0.,„\ /7, THE STATE Alaska Oil and Gas ALASKA= -�14 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 SCANNED Ur l 7 1.J Fax: 907.276.7542 Jason Burke � 19' CTD Engineer 1 �' ConocoPhillips Alaska, Inc. ` P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G-13 Sundry Number: 313-627 Dear Mr. Burke: 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, Daniel T. Seamount, Jr. cp Commissioner DATED this day of December, 2013. Encl. STATE OF ALASKA • • ALA"OIL AND GAS CONSERVATION COMM N • APPLICATION FOR SUNDRY APPROVALS A��� E.0 0 4 2013 20 AAC 25.280 Of U 1.Type of Request: Abandon r Rug for Redrill F., • Perf orate New Pool r Repair well r Change Ap • ++r Suspend r Rug Perf orations r• Perforate r Full Tubing r Time Extension r Operational Shutdow n r Re-enter Susp.Well I° Stimulate r Alter casing r Other: E; 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r''./. 184-129 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21160-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2G-13 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25667 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7936 • 6409 ' 7837' 6329' 7620' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 2812 9.625 2849' 2708' PRODUCTION 7886 7 7920' 6396' Perforation Depth4MD(ft): 74c7% 1 Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7590-7604,7622-7866' 6136-6147,6161-6191 3.5 L-80 7581 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER 7"X 3.50"3-1/2"TC-II BOX X MD=7409 TVD=5997 1 SSSV-CAMCO TRMAXX MD=1802 TVD=1799 . 12.Attachments: Description Summary of Proposal Fi. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Service r g Operations: after proposed work: V� 14.Estimated Date for Commencm O erations: 12/9/2013 15. WOeIIIStatu Status Gas r WDSPL Suspended ,`�\4 VA 16.Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Burke @ 265-6097 Email: Jason.Burkena,conocophillios om Printed Name Jason Burke Title: CTD Engineer Signature -'' -- Phone:265-6097 Date /2-3-/ 3 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness SV-," (.t 1-1 Plug Integrity r BOP Test rez Mechanical Integrity Test r Location Clearance r Other: Kd'G p .71-2,-,5 f .7/0 .1 5 L:)(1 if 5/ 4/ t ft p I v pA Ct ,--� 1 app rev- 'Gf p r a C 4/1-& 25112 ( Spacing Exception Required? Yes CI No Subsequent Form Required: /r% — 4 U )p. ED Yi Z 17 ) 13 Approved •-: COMMISSIONER THE COMMMM COMMISSION Date: Approved application is valid tor 12 months trom the date of approval. Form 10-403(Revised 10/2012) J oRIGINAL f K,3 I0ht(13 Submit Form and Attaacchmennts in Duplicat • • • • KRU 2G-13 CTD Summary for Perforating & Plugging Sundry (10-403) Summary of Operations: Well 2G-13 is a Kuparuk A-sand producing well equipped with 3'/2"tubing and 7"production casing. Two proposed A-sand CTD lateral .• •i - - eservoir exposure in the fault block. Prior to drilling,the existing J(• • sans perfs in 2G-13 will be plugged with cement to provi•e a means to ick out of the 7"casing. 0� ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A sand 5 (� 9/1 perfs in this manner. fir The 3-1/2"tubing in the tubing tail will be perforated 3' below the 2.813"landing nipple @ 7449' MD(7452'- 7454' RKB)to allow cement to go above the tubing tail and reduce the risk of contaminated cement at the tubing tail. After plugging off the existing A sand perfs with cement,the 3.5"tubing will be milled clear of cement. A mechanical whip-stock will be placed in the 3.5"tubing at 7545' MD. The 2G-13A sidetrack will exit the 7" casing at 7,554' MD and will target the A4 sand south of the existing well with a 4005' lateral. The hole will be completed with a 2-%" slotted liner to the TD of 11550' MD with an aluminum billet at 8370' MD. The 2G-13AL1 lateral will kick off from the aluminum billet at 8370' MD and will target the A5 sand south of the existing well with a 3180' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11550' MD ran back into the tubing to 7535' MD. CTD Drill and Complete 2G-13 Laterals: December 2013 Pre-CTD Work 1. RU Slick-line. a. Set catcher sub b. Pull SOV and replace with a dummy valve c. Retrieve catcher sub 2. RU Pump truck a. Pressure tubing up to 4500 psi to shear tubing tail shear-out sub 3. RU Slick-line a. Obtain a SBHP b. Drift dummy whip-stock to 7560' MD(EOT) 4. RU Electric Line a. Perform jewelry log and tie into K1 marker b. Punch holes in the 3.5"tubing at 7452' MD 5. RU CTU a. Pump cement to PBTD b. Mill cement down to the bottom of the tubing at 7600' MD 6. Prep site for Nabors CDR2-AC,including setting BPV Rig Work OV1/�`p�� 46c3p5/ 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 1� . P T 3 2. 2G-13A Sidetrack(A4 sand,south) 8/2p a. Mill 2.80"window at 7545' MD. 4 5�!O e 5 i Page 1 of 2 12/3/2013 . • • b. Drill 2.70"x 3"bi-center lateral to TD of 11550' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 8370' MD 3. 2G-13AL1 Lateral(A5 sand,south) a. Kick off of the aluminum billet at 8370' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11550' MD c. Run 2%"slotted liner back into tubing to a depth of 7535' MD 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Turn well over to production Page 2 of 2 12/3/2013 KUP PROD • 2G-13 ConocoPhillips i Well Attributes Max Angle&MD TD Kaska,I11C:. Wellbore APIAIWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(OKS) 500292116000 (KUPARUK RIVER UNIT PROD 47.60 2,900.00 7,936.0 ••• Comment lOS(ppm) Date Annotation End Date KBGrd(ft) Rig Release Date 20.13,12/3/2013921:39 AM SSSV:LOCKED OPEN 120_ 11/122004 Last WO: 11/10/2013 40.98 10/1/1984 Vertical schemata(actual/ Annotation Depth(668) I End Date Annotation Last Mod By End Date _... .._. ..... _.__.. Last Tag,TOC 7,622.0 8/30/2010 Rev Reason:WORKOVER haggea 12/32013 IOiR;34.9 -L-- PW Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(IVO)...Wt/Len(I...Grade Top Thread _ CONDUCTOR 16 15062 38.0 110.0 110.0 62.50 H-40 WELDED 1{ Casing Description OD(in) ID(in) Top(ftK8) Set Depth(ftKB) Set Depth(TAD)...Wt/Len(I...Grade Top Thread w•.,,. ,. 'm SURFACE 95/8 8.921 37.5 2,849.3 2,706.8 3600 J-55 ETC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 34.2 7,920.0 6,396.4 26.00 J-55 BUTT Tubing Strings I Tubing Description I String Ma,..I ID(in) 'Top(ftKB) Sot Depth(ft...1Set Depth(ND))...I WI(Iblk) Grade !Top Connection TUBING WO 312 2.992 34.9 7,581.3 6,129.5 9.30 L-80 EUE-Srd .`,.'CONDUCTOR;38.0-11o,o.m ti Completion Details Nominal ID Top(ftKB) Top(TVD)(ftK8) Top Inc)(•) Item Des Core (in) SAFETY VLV:1.801.5 s;j. 34.9 34.9 0.14 HANGER CAMERON GEN IV EUE 8rd HANGER 2.992 ® 1,801.5 1,798.5 12.70 SAFETY VLV SSSV,TRMAXX-CMT 2.813 7,376.6 5,973.1 40.62-LOCATOR BAKER LOCATOR SUB 2.990 GAS LIFT:2.705.6 7,384.0 5,978.7 40.60 PBR 80.40 PBR 2.990 7,408.5 5,997.3 40.52 PACKER BAKER PREMIER PACKER 2.880 7,449.2 6,028.3 40.35 NIPPLE HES LANDING NIPPLE,2.813"'X'PROFILE 2,920 i 7,580.4 6,128.8 39.37 SOS BAKER SOLID SHEAR OUT SUB 3.000 SURFACE;37.5-2.849.3-• j Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotsrI GAS LIFT;4.207.7-4 Top(ftKB) Btm(BOB) MKS) (ftKB) Zone Date k Type Com 7,590.0 7,600.0 6,136.3 6,144.0 A-5,2G-13 928/1985 4.0 RPERF 21/8"DresSerBarKo-0 Deg ph 7,590.0 7,604.0 6,136.3 6,147.1 A-5,2G-13 8/302010 6.0 RPERF Prosector RDX DP 2.5", GAS LIFT:5.3796 r 60 deg 7,593.0 7.594.0 6,138.6 6,139.4 A-5,2G-13 11/5/1984 1.0 IPERF 4"DAJJ 7,594.0 7,595.0 6,139.4 6,140.2 A-5,2G-13 11/511984 1.0 IPERF 4"DAJJ GAS LIFT;8.170.9 r ----1# 7,602.0 7,603.0 6,145.6 6,146,4 A-5,2G-13 11/5/1984 1,0 IPERF 4"DAJJ 7 7,603.0 7,604.0 6,146.4 6,147.1 A-5.20-13 11/5/1984 1.0 IPERF 4"DA JJ 7,622.0 7,660.0 6,161.1 6,190.7 A-4,2G-13 9/28/1985 4.0 RPERF 21/8"DresserBarKO-0 Deg ph GAS LIFT:6,869.7 t, 7,625.0 7,628.0 6,163.5 6,165.8 A-4,2G-13 11/5/1984 1.0 WERE 4"DA JJ 1-. 7,633.0 7,634.0 6,169.7 6,170.5 A-4,2G-13 '11/5/1984 1.0 IPERF 4"DA JJ € 7,635.0 7,636.0 6,171.2 6,172.0 A-4,2G-13 11/511984 1.0 IPERF 4"DAJJ GAS LIFT,7.3226 7,636.0 7,637.0 6,172.0 6,172.8 A-4,20-13 11)5!1984 1.0 IPERF 4"DA JJ 7,641.0 7,642.0 6,175.9 6,176.7 A-4,2G-13 11/5/1984 1.0 IPERF 4"DAJJ 7,647.0 7,648.0 6,180.6 6,181.4 A-4,20-13 11/5/1984 1.0 IPERF 4"DAJJ LOCATOR,7,3766 fl 7,654.0 7,657.0 6,186.1 6,188.4 A-4,20-13 11)5!1984 1.0 IPERF 4"DAJJ Stimulations&Treatments PBR;7.384.0 i Min Top Max Btm �a Depth Depth Top(ND) Btm(1VD) MKS) (ftK8) (ftKB) (kKB) Type Date Corn PACKER; 770 7.590.0 7,604.0 6,136.3 6,147.1 FRAC 9/1!2010 PUMP FRAC 110,325#CARBOLITE PROPPANT INTO FORMATION Cement Squeezes NIPPLE:7,449.2 Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (086) (ftKB) Des Start Date Coin i 7,620.0 7,629.0 6,159.6 6,166.6 CMT PLUG 8/18/2010 PLACED 24 GAL.19.5 PPG CEMENT @ 7616' Mandrel Inserts 1 St ati c on Top(ND) Valve Latch Port than 7R0 Run o 505:7,560-4 No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (p0) Run Date 01 __ 1 2,705.6 2,603.5 CAMCO KEMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 IPERF:7.593.0-7,59x.0 J 2 4,257.7 3,699.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 IPERF;7,594.0.7,595.0_ °' 3 5,379,6 4,505.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/252013 RPERF;7.59E0-7,600.01 IT... - FRAC;7,590.0_ 4 6,170.9 5,087.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 RPERF:7,590.0-7.604.0 - - 5 6,869.7 5,595.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/25/2013 - 6 7,322.6 5,932.1 CAMCO KBMG 1 GAS LIFT -SOV BEK 0.000 0.0 1125/2013 IPERF 7.602.0.7,603,0 DCK-2 a.-IPERF;7,603.0-7,604.0 Notes:General&Safety End Date Annotation _ 10/21/2010 NOTE:View Schematic WI Alaska Schmatic9.0 IPERF;7,625.0.2826.0 1a�r��w�wvvy. CMT PLUG;7,620.0 MI _: IPERF:7.633,0-7,634.0 IPERF;7,635.0-7,636.0 SERF.7.636.0-7,637,0-. RPERF;7422.0.7,660.0-. IPERF;7,641.0.7,642.0 SERF;7,647.0.7.848.0- SERF:7,654.0.7,657.0 PRODUCTION:34 2.7.920.0 • • Page 1 of 1 Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS (IPBRD)Type Work Code in RBDMS 1. When a Form 10-403 is submitted requesting approval to plug a well for redrill,the initial reviewer(Art or Steve D.)will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked,we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2. On the Form 10-403 if"Abandon" is checked in Box 15(Well Status after proposed work), Art or Steve ✓/ D. will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED,and will date and initial his change. If Steve does not see the"Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D.will also review the list of suspended wells for accuracy. Thanks, Steve D. 0 0 WELL LOG = TRANSMITTAL PmAcdw DlncNWdC S ERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE: Cased Hole/Open Hole Mechanical Logs and/or Tubing Ins ection Cali MTT / 9 / 9 er P ( P/ ) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road X, A NOY 5 2DIU Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 15 -Nov- 1 O 2G-13 1 Report / EDE 50-029-21160-00 2) iC99 d ' , R ' ' Signed: Date '' Print Name::�e PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE AK 99518 PHONE (907)245 - 8951 FAx: (907)245 - 88952 E-MAIL: 3dsanc tcrage(a)merr or4fHOC.com WESSITE : W.W11.MeM0rf109X0M C: \Documents and SettinpUhane Williams \Desktop \Transmit_Conoco.docx Multi- Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2G -13 Log Date: November 15, 2010 Field: Kuparuk Log No.: SO# 7776327 State: Alaska Run No.: 2 API No.: 50- 029 - 21160 -00 Pipet Desc.: 3.5 in. 9.3 lb. J -55 EUE 8RD Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 7,432 Ft. (MD) ' Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: ' This caliper data is correlated to the tubing detail dated November 15, 2090. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good condition with respect to corrosive damage, with no significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions recorded. Although no significant I.D. restrictions are recorded, the caliper recordings indicate slight to ' moderate buckling, increasing in severity with depth from —5,950 to 7,432 feet (end of log). 3 -D log plots of the centered and off - center caliper recordings across this interval are included in this report. This is the second time a caliper has been run in this well and the second time the 3.5 inch tubing has been logged from surface to 3,006 feet. A comparison of the current and previous log (November 1, 2010) indicates a decrease in recorded deposits from 2,734 to 3,006 feet during the time between logs. This summary report is interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 18 %) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. Field Engineer: E Regnier Analyst: C. Waldrop Witness: J. Condio ' ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS(d?memcrylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 PDS Multifinger Caliper 3D Log Plot ' Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 2G -13 Date : November 15, 2010 ' Description : Detail of Centered Caliper Recordings Across Buckling Recorded in 3.5" Tubing. Comments Depth Maximum I.D. 3-D Log (Centered) Image Map (Centered) 1ft.700ft 2.5 inches 3.5 0 0° 90° 180° 270° 0 ' Minimum I.D. 2.5 inches 3.5 Nominal I 2.5 inches 3.5 Joint 190 Joint 191 Slight Buckling 5950 Joint 192 - Slight Buckling Joint 193 6000 Slight Buckling Joint 194 Slight Buckling !. 6050 Joint 195 Slight Buckling Joint 196 _ Slight Buckling 6100 Joint 197 Slight Buckling Joint 198 6150 Slight Buckling Joint 199 Slight Buckling 6200 Joint 200 Slight Buckling _ Joint 201 Slight Buckling 6250 Joint 202 Slight Buckling Joint 203 6300 Slight Buckling Joint 204 ' Slight Buckling 11 ■ ■ ■ ■C� ■ ■ ■ ■■ -, ■ ■�� ■ ■■ ■ ■ ■� ■■ Joint 205 Slight Suckling Slight Buckling Joint 207 Slight Buckling Buckling Joint 209 Buckling ■ ■��!■ 1 65 0 Buckling 6550 Joint 212 Buckling ■■■Fli■■ ■■■M !■■■ Joint 213 6600 ■ ■ ■ ■�! ■ ■■ Buckling ■■■■MMEN Joint 214 Buckling ■■■■Mi■■■■ - Buckling Buckling Joint 217 Buckling Joint 21 Buckling Joint 219 Buckling Joint 220 Buckling ■ ■ ■ ■� ■ ■ ■ ■■ 11 ■ ■ ■ ■tF ■ ■ ■ ■■ 1 1 ■ ■ ■ ■��� ■■ ■ ■ ■ ■fiiii�i . 1 ■■■! ■!■■■■ ■ ■ ■ ■F = ■■■■■ ■■■■A !■!■■ mmmummmmm ■■■■IF,■■■■■ ■■■■KILU■M■■ ■■■■EIi■■■■ ■ ■l:x■■■■■ Joint 229 ■■■■KID■■■■ ■■r4r. ■ Joint 230 Buckling ■■■■I ]I'.!■■■■ ■■■■:�� S Joint 231 ■ ■ ■�1.■ Buckling ■■■m!■■mm _ Joint 232 Buckling ■■■■M■■■■■ ■■■■!NMMMM■ Joint 233 Buckling IMMMFILMMM ■■■tSIMMM- Joint 234 Buckling I MMMOMM ■ ■ ■■ ■■■■IJI ■■ Joint 235 ■■■■ma■■■■ Buckling ■■■■M■■■■■ - - - Joint 236 Buckling IMMMFI-MMM Joint 237 Immmmmmm ■� Buckling ■■■iri!■ ■■ Joint 238 ■■■■iw!■■■■ Buckling ■■■■I'T!■■■■ - ■■■■"WME ■� m Buckling ■■■■m■■ ■■� - - -- - PDS Multifinger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2G -13 Date : November 15, 2010 Description : Detail of Off - Center Caliper Recordings Across Buckling Recorded in 3.5" Tubing. Comments Depth Maximum I.D. 3 -D Log (Off - Center) Image Map (Off- Center) 1ft:700ft 2.5 inches 3.5 276° 0° 90° 180 270° 0 ' Minimum I.D. 2.5 inches 3.5 Nominal I.D. ....................................... ..............................: 2.5 inches 3.5 Joint 190 Joint 191 Slight Buckling 5950 ' Joint 192 Slight Buckling i Joint 193 6000 Slight Buckling ' Joint 194 Slight Buckling . 6050 Joint 195 Slight Buckling Joint 196 Slight Buckling 6100 Joint 197 Slight Buckling Joint 198 6150 + Slight Buckling Joint 199 Slight Buckling 6200 Joint 200 Slight Buckling Joint 201 Sli Buckling 6250 Joint 202 Slight Buckling Joint 203 6300 Slight Buckling Joint 204 Slight Buckling - FROM ■■ ■RIM■■ Joint 207 iqwj, mn Slight Buckling Joint 208 Buckling Joint 209 Buckling Joint 210 Buckling Joint 211 Buckling 6550 Joint 212 Buckling Joint 213 ►�'■! !!� ■!! ■ ■ ■F�! ■ ■ ■■ _ ■ ■ ■�>�i ■ ■ ■■ ■■ ■iii ■ ■ ■■ _ .. ■ ■ ■E� i ■ ■ ■r Buckling Joint 214 Buckling ■ ■ ■! ■ ■ ■■ 6650 - Joint215 ohs, Buckling amm Joint 216 Buckling Joint 217 Buckling 6750 r F'� ■ ■■ Buckling Buckling Joint 220 Buckling Joint 221 Buckling Joint 222 Buckling - . _... a: 1 ■ ■ ■ ■ ■■ ■■■ ■■ . 1 1 ■■aIi�iiii "`N S Joint 226 Buckling M■:: Joint 227 Buckling ■ ■■ Joint 228 Buckling iii■ ■■■■ Joint 229 Buckling i■ii■ -_ Joint 230 Buckling Joint 231 Buckling Joint 232 Buckling :...ter ■��. __� ■ ■ if�i�i ■■ OEM ■■i Joint 233 Buckling ■■ ■ ■■ _m. Jt „ ■■ _■_■_� Joint B k12 ii ■■ Joint 235 Buckling - _- ■■■W MEMO ■-- ■■■F&■■■■■- 73 0 M-kif-MMMM IN Joint 236 iFIi■■■■ --w ` . -. Buckling Joint 237 i■■D iiii■PMI Buckling Emir) Joint 238 Buckling ■i� -"-_ 1 1' Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (542- 7425.9') Well: 2G -13 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: November 15, 2010 Approx. Tool Deviation ■ Approx. Borehole Profile 1 58 25 787 50 1563 GLM 1 75 2367 100 3122 p E GLM 2 Z 125 3901 L o � 150 4671 GLM 3 175 5440 200 6200 ' GLM 4 225 6959 ' GLM 5 240 7426 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 240 PDS Report Overview �. s ,� Body Region Analysis Well: 2G -13 Survey Date: November 15, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 HAL Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 ppf J -55 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) Damage Profile (% wall) penetration body metal loss body penetration body i iiiiiiii metal loss body 0 50 100 250 p 200 150 100 ' 50 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% GLM 1 Number of joints analysed total = 243 pene. 0 136 107 0 0 0 loss 10 233 0 0 0 0 98 Damage Configuration ( body) GLM 2 60 148 ' 40 GLM 3 20 198 O isolated general line ring hole / poss GLM 4 pitting corrosion corrosion corrosion ible hole Number of joints damaged total = 51 GLM 5 51 0 0 0 0 Bottom of Survey = 240 Analysis Overview page 2 I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 15, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 54 0 0.02 8 3 2.94 PUP 1 58 0 0.03 10 2 2.93 2 90 0 0.02 7 1 2.93 3 119 0 0.02 7 3 2.96 ' 4 148 0 0.01 6 2 2.92 5 178 0 0.02 7 3 2.92 6 209 0 0.02 7 2 2.93 7 238 0 0.02 8 2 2.91 8 266 0 0.02 6 2 2.93 ' 9 294 0 0.01 4 2 2.92 10 323 0 0.02 7 2 2.90 11 354 0 0.01 6 2 2.93 12 386 0 0.01 5 2 2.93 13 415 0 0.01 5 2 2.92 14 445 0 0.02 9 2 2.92 15 477 0 0.03 10 2 2.91 16 508 0 0.01 6 3 2.93 17 1 537 0 1 0.02 8 2 2.90 18 567 0 0.02 8 2 2.92 19 598 0 0.01 6 2 2.94 20 630 0 0.02 7 2 2.93 21 661 0 0.02 9 3 2.90 22 693 0 0.02 7 1 2 2.89 23 724 0 0.02 7 2 2.91 24 1 756 0 1 0.02 9 2 2.91 Lt. De osits. 25 787 0 0.01 6 2 2.89 26 819 0 0.01 5 2 2.90 27 850 0 0.02 9 2 2.92 Lt. Deposits. 28 881 0 0.02 8 2 2.94 29 912 0 0.01 6 2 2.93 30 943 0 0.02 7 2 2.93 31 1 975 0 1 0.02 8 1 2 2.90 32 1007 0 0.01 6 1 2 2.90 33 1039 0 0.02 7 3 2.89 Lt. De osits. ' 34 1070 0 0.02 7 2 2.90 Lt. De osits. 35 1102 0 0.02 7 3 2.90 Lt. Deposits. 36 1133 0 0.02 7 2 2.90 37 1163 0 0.02 8 1 2.93 38 1 1193 1 0.02 9 1 2.91 39 1224 0 0.02 8 2 2.89 40 1255 0 0.02 8 1 3 2.89 41 1286 0 0.02 7 4 2.91 42 1316 0 0.02 8 1 2.92 Lt. De osi ts. 43 1347 0 0.03 11 2 2.91 44 1378 0 0.02 7 2 2.93 45 1410 0 0.01 6 2 2.91 Lt. Deposits. 46 1441 0 0.02 9 2 2.91 Lt. Deposits. 47 1472 0 0.02 9 1 2 2.90 Lt. Deposits. 48 1500 0 0.01 6 2 2.93 49 1532 U 0.01 6 2 2.91 Penetration Body Metal Loss Body Page 1 i • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 15, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 50 1563 0 0.02 8 2 2.91 Lt. Deposits. 51 1594 0 0.02 7 2 2.94 52 1626 0 0.02 8 2 2.90 Lt. De osits. 53 1657 0 1 0.03 11 2 2.93 ' 54 1688 0 0.02 9 2 2.92 55 1720 0 0.03 10 2 2.92 56 1750 0 0.02 7 2 2.91 57 1780 0 0.01 6 2 2.93 58 1811 0 0.02 8 3 2.91 ' 59 1842 0 0.03 10 2 2.91 60 1874 0 1 0.02 9 2 2.95 60.1 1905 0 0.01 4 0 2.95 PUP 60.2 1911 0 0 0 0 2.81 Baker'FVL' SSSV Locked Out 04/15/1993 60.3 1925 0 0.01 4 0 2.93 PUP 61 1931 0 0.03 12 2 2.92 Shallow pitting. 61.1 1963 0 0 0 0 N/A GLM 1 Latch @ 8:30 62 1969 0 0.03 13 2 2.93 Shallow pitting. 63 2001 0 0.03 11 1 2.93 64 2032 0 0.02 9 4 2.91 Lt. Deposits. 65 2063 0 0.04 14 2 1 2.93 Shallow pitting. 66 2095 0 0.03 10 1 2.93 67 2127 0 0.03 11 2 2.89 Lt. Deposits. 68 2155 0 0.02 9 2 2.87 Lt De osits. 69 2185 0 0.03 13 2 2.92 Shallow pitting. 70 2217 0 0.03 13 2 2.92 Shallow pitting. 71 2249 0 0.03 13 3 2.90 1 Shallow pitting. Lt. Deposits. 72 2278 0 0.02 8 2 2.91 73 2307 0 0.03 12 2 2.90 Shallow pitting. 74 2335 0 0.02 9 2 2.92 Lt. De osits. 75 2367 0 0.02 9 2 2.90 76 2398 0 0.03 12 2 2.87 Lt. De osits. 77 2430 0 0.03 13 3 2.89 Shallow pitting. 78 2461 0 0.03 11 1 2 2.89 79 2492 0 0.02 9 3 2.88 80 2521 0 0.03 13 2 2.91 Shallow pitting. 81 2553 0 0.03 12 4 2.88 82 2581 0 0.03 10 2 2.92 83 2613 0 0.03 10 2 2.89 84 2644 0 0.03 10 1 2.88 85 2676 0 0.02 9 2 2.91 86 2707 0 0.03 10 2 2.89 87 2737 0 0.03 11 2 2.90 Lt. Deposits. 88 2765 0 0.03 11 2 2.90 Lt. Deposits. ' 89 2796 0 0.03 11 3 2.90 Lt. Deposits. 90 2825 0 0.03 10 3 2.87 Lt. De osits. 91 1 2855 0 0.03 11 3 2.92 92 2884 0 0.03 10 2 2.92 ' 93 2913 0 0.04 14 2 2.93 Shallow Pitting. 94 2942 0 0.03 10 2 2.93 95 2972 0 0.03 13 2 2.93 1 Shallow pitting. Lt. De osits. Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET III Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 15, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins) (Ins.) % (Ins.) 0 50 100 96 3004 0 0.03 11 2 2.92 Lt. Deposits. 97 3035 0 0.04 14 3 2.91 Shallow pitting. 98 3064 0 0.03 12 4 2.92 99 1 3093 0 0.02 9 2 2.92 100 3122 0 0.04 16 2 2.90 Shallow pitting. Lt. Deposits. 101 3151 0 0.03 12 4 2.92 102 3183 0 0.03 12 1 2 2.91 103 3214 0 0.04 14 2 2.91 Shallow pitting. 104 3245 0 0.03 13 2 2.87 Shallow pitting. Lt. De osits. ' 105 3277 0 0.03 12 2 2.90 106 3308 0 0.03 12 2 2.89 Lt. Deposits. 107 3338 0 0.03 13 3 2.91 Shallow pitting. 108 3368 0 0.04 17 2 2.90 Shallow pitting. ' 109 3399 0 0.04 15 1 2 2.91 Shallow pitting. 110 3430 0 0.03 11 3 2.91 111 3462 0 0.03 11 2 2.93 112 3493 0 0.03 11 3 2.91 113 3523 0 0.03 11 3 2.93 114 3554 0 0.03 11 2 2.93 115 3585 0 0.02 9 2 2.90 116 3617 0 0.03 10 1 3 2.90 117 1 3649 0 1 0.02 9 1 3 2.91 118 3681 0 0.03 11 3 2.91 119 3712 0 0.02 8 1 2.91 120 3743 0 0.03 11 3 2.91 121 3775 0 0.02 9 2 2.90 122 3804 0 0.03 12 3 2.92 123 3836 0 0.02 9 3 2.90 123.1 1 3865 0 1 0 0 1 0 N/A GLM 2 Latch @ 2:30 124 3871 0 0.03 10 3 2.90 ' 125 3901 0 0.03 10 2 2.92 126 3930 0 0.02 9 2 2.90 Lt. De osits. 127 3961 0 0.02 9 2 2.91 128 3992 0 0.02 9 4 2.91 129 4022 0 0.03 10 3 2.91 130 4053 U 1 0.03 11 3 2.88 131 4083 0 1 0.03 11 2 2.91 132 4114 U 0.03 11 2 2.91 133 4146 0 0.03 12 3 2.90 134 4177 0 0.02 9 2 2.90 135 4208 0 0.03 12 3 2.88 136 4238 0 0.02 9 2 2.90 137 4270 0 0.03 12 1 3 2.90 138 1 4301 U 1 0.03 10 2 2.91 139 4333 0 0.03 13 2 2.88 Shallow pitting. 140 4361 0 0.03 13 2 2.91 Shallow pittinm. 141 4393 0 0.02 9 2 2.92 142 4425 0 0.03 11 2 2.90 143 4457 0 0.03 11 3 2.89 144 4486 0 0.03 1 11 1 2 2.87 Penetration Body Metal Loss Body Page 3 • PDS REPORT 1 OINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. ' Nominal I.D.: 2.992 in Country: USA Survey Date: November 15, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile Ili , No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) %, (Ins.) 0 50 100 145 4517 0 0.03 11 2 2.92 146 4548 0 0.04 17 3 2.92 Shallow pitting. 147 1 4578 0 0.02 9 1 3 2.88 148 1 4609 0 0.03 11 3 2.89 149 4641 0 0.02 9 2 2.90 150 4671 0 0.04 16 3 2.88 Shallow pitting. Lt. Deposits. 151 4701 0 0.03 10 2 2.90 Lt. De osits. 152 4733 0 0.03 10 2 2.90 153 4761 0 0.04 15 1 2 2.88 1 Shallow pitting. 154 4790 0 0.03 11 2 2.92 155 1 4821 0 0.03 13 ; 2.88 Shallow pitting. 156 4852 0 0.04 14 3 2.89 Shallow pitting. 157 4884 0 0.03 10 4 2.90 ' 158 4914 0 0.02 9 2 2.92 159 4946 0 0.01 5 2 2.93 160 4976 0 0.04 16 1 2 2.92 Shallow pitting. 161 5007 0 0.02 9 2 2.92 ' 162 5039 0 0.04 15 3 2.91 Shallow pitting. 163 1 5070 0 0.03 10 2 2.91 164 5102 0 0.02 9 2 2.93 165 5133 0 0.04 17 2 2.89 Shallow pitting. 166 5165 0 0.03 11 2 2.91 ' 167 5195 0 0.03 11 1 4 2.91 168 5224 0 0.04 14 2 2.90 Shallow 6tting. 169 5253 0 0.04 14 5 2.91 Shallow ittin . 170 1 5285 0 1 0.03 13 2 2.88 Shallow pitting. 171 5315 0 0.01 6 2 2.90 172 5347 0 0.03 10 2 2.88 173 5379 0 0.03 13 2 2.90 Shallow pitting. 174 5410 0 0.04 15 2 2.89 Shallow pitting. 175 5440 0 0.04 17 2 2.93 Shallow pitting. 176 5471 0 0.03 12 2 2.90 Shallow pitting. 176.1 5502 0 1 0 0 0 N/A GLM 3 Latch @ 5:30 177 5509 0 0.03 12 2 2.90 178 5537 t) 0.03 13 2 2.92 Shallow pitting. 179 5566 0 0.04 17 3 2.91 Shallow pitting. 180 5596 0 0.03 11 2 2.91 181 5627 0 0.02 8 1 3 2.89 182 5657 0 0.03 13 2 2.89 Shallow pitting. 183 5688 0 0.02 9 2 2.89 184 5718 0 1 0.02 9 2 2.90 185 5750 U 0.03 10 2 2.90 186 5778 0 0.03 11 2 2.91 ' 187 5807 0 0.02 9 2 2.93 188 5835 0 0.03 11 1 3 2.90 189 5867 0 0.04 14 2 2.89 1 Shallow 6tting. 190 5898 0 0.03 10 3 2.89 ' 191 5929 1 0.03 10 4 2.88 Slight Buckling. 192 5960 0 0.03 11 2 2.88 193 5991 0 0.02 9 2 2.91 Penetration Body Metal Loss Body Page 4 r • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 15, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 194 6020 0 0.03 11 2 2.89 Slight Buckling. 195 6050 0 0.02 9 3 2.88 196 1 6079 U 0.03 10 3 2.88 197 6108 0 0.03 11 3 2.87 Slight Buckling. 198 6139 U 0.03 12 3 2.89 199 6169 0 0.03 11 3 2.91 200 6200 U 0.02 9 2 2.90 Slight Buckling. 201 6231 0 0.04 17 2 2.92 Shallow pitting. 202 6263 0 0.03 12 2 2.88 ' 203 6291 0 0.03 11 2 2.88 1 Sli ht Buckling. 204 6322 U 1 0.03 11 3 2.89 205 6353 0 0.02 9 2 2.92 206 6381 0 0.02 9 2 2.89 Slight Buckling. ' 207 6410 0 0.03 11 2 2.90 Buckling. 208 6440 0 0.03 13 3 2.89 Shallow pitting. 209 6468 0 0.02 9 2 2.88 Buckling. 210 6500 U 0.03 13 4 2.92 Shallow pitting. ' 211 6531 0 1 0.03 10 1 2 2.90 Buckling. 212 6561 U 0.03 10 3 2.90 213 6591 0 0.03 12 3 2.90 Buckling. Lt. De osits. 214 1 6623 0 0.03 10 4 2.91 214.1 6653 U 0 0 0 N/A GLM 4 Latch @ 4:30 ' 215 6660 0 0.03 11 4 2.91 Buckling. 216 6690 0 0.03 13 2 2.90 Shallow pitting. 217 6720 0 0.03 13 1 2 2.90 Shallow pitting. Buckling. 218 6749 0 0.05 18 1 3 2.90 Shallow pitting. 219 6779 U 0.04 16 2 2.91 Shallow pitting. Buckling. 220 1 6809 0 1 0.03 10 2 2.92 221 1 6839 0 0.03 11 3 2.88 Buckling. Lt. Deposits. 222 6870 0 0.03 13 2 2.90 Shallow Ditting. 223 6898 0 0.04 17 3 2.88 Shallow pitting. Lt. Deposits. 224 6929 0 0.03 10 4 2.90 Buckling. 225 6959 0 0.02 9 1 3 2.88 226 6990 0 0.02 8 5 2.89 227 7020 U 1 0.02 8 1 2.91 Buckling. 228 7050 0 0.02 9 3 2.88 229 1 7080 0 0.02 8 3 2.92 230 7111 0 0.01 4 2 2.90 Buckling. 231 7142 0 0.01 5 2 2.91 232 7171 0 0.02 6 1 3 2.90 233 7200 0 0.03 11 2 2.91 Buckling. 234 7232 U 0.02 9 4 2.90 235 7262 U 0.02 9 2 2.90 ' 236 1 7294 0 1 0.04 14 5 2.91 Shallow pitting. Buckling. 237 7325 0 0.04 15 3 2.91 Shallow pitting. 238 7356 U 0.01 4 2 2.90 Buckling. 239 7387 0 0.04 16 6 2.91 Shallow pitting. Lt. Deposits. ' 239.1 7418 U 0 0 0 N/A GLM 5 Latch @ 5:30 240 7426 0 0.02 9 1 3 2.92 Buckling. Lt. Deposits. Penetration Body Metal Loss Body Page 5 KUP 2G -13 ConocoPhillips ell Attributes Wx a Ie &MD I wdlbore APWVA -rid Name writ Status Ind ( ") hL (rMB) AC Bim ptl0) 500292116000 KUPARUK RIVER UNIT PROD 4760 2,900.00 7,936.0 Comnera H2S (ppm) Date Annotation iand Date KB-Grtl (ft) Rig Release Date •• Wea COnfi: -2G- 1310 /311010 1:40.06 PM . - .. SSSV: LOCKED OUT 120 11/12/2004 Last WO: 40.98 101111984 Shcematic -Aaual Amo[atlon Depth (RI(B) End Date Amotalian Last MOd By Entl D Last Tag: TOC 7,622.0 8/30/2010 Rev Reason: TBG OBSTRUCTION, GLV C/O Imosbor 10/3/2010 Casino Strin s String OD 5[dTg ID Set Depth Set Depth (TVD) String Wt String CONDUCTOR, Casing Description On) (in) Top MKB) (MB) (Po(B) (IbSfM Grade String Top Third CONDUCTOR 1 16 15.0621 0.0 110.0 110.0 62.50 H -40 SURFACE 1 95/8 8.765 0.01 2,849.0 2,707.8 36.00 J -55 sarac valve, o PRODUCTION 7 6.151 0.0 7,920.0 6,396.4 26.00 J-55 1,900 Tubing Strings String 00 String ID Set Depth Set Depth (TVD) String wt String GAS LIFT, Tubi Descd - on (in) (in) To (RKB) MKB) (Ibsflq Qade Std T Third 1'952 TUBING 3 112 2.992 0.0 7,512.0 6,0762 9.30 J -55 EUE 8RD SURFACE, O ther In How All Jeweir : Tubin Run & Retrievable, Fish etc. 2.849 Top Depth MM Top Ind To OII(W (') Description Comment Rm Date ID In ' GAS LIFT, 1,900.0 1,893.9 16.23 Safety Valve Baker'FVL' (LOCKED OUT 4 /15/1993) 11/611984 2.810 3,864 1,952.0 1,943.4 17.92 GAS LIFT MMH /3. 5x1 /l /DMY /BTM// /Comment: STA1 8/2512010 2.937 3,864.0 3,421.1 45.20 GAS LIFT MMH /3.5x1 /1 /DMY /BTW/ /Comment: STA2 812512010 2.937 GAS LIFT, 5,503.0 4,595.7 43.70 GAS LIFT MMH /3.5x1/1 /DMY /BTM// /Comment: STA3 8/25/2010 2.937 5.503 6,653.0 5,438.0 43.69 GAS LIFT MMH 13.5x1 /11DMY /BTM/ / 1CommeM: STA4 8/2412010 2.937 ' 7,424.0 6,009.6 40.89 GAS LIFT MMH 13.5x1/1 /0PEN /BK( // Comment: STA 5 916/2010 2.937 GAS LIFT. 7,468.5 6,042.7 40.46 PBR Baker PBR 11/6/1984 2.810 6.653 7,482.0 6,053.3 40.32 PACKER Baker'FHU PACKER 11/6(1984 3.000 7,499.0 6,066.3 40.16 NIPPLE Camco'D' Nipple NO GO 11/611984 2.750 ' GAS LIFT, 7,511.0 6,075.5 40.04 SOS Baker 11/611984 2.992 7.424 7,512.0 6,076.2 40.03 TTL ELMDTTL @ 7503' during OTIS FLUID ID LOG on 11/611984 2.992 12/30/1984 PBR, 7,468 Perforations & Slots Shot ' Top (7110) Bt. (TVD) Dens Top QtK B at. Poch OWN I MK none Date (sh -- Type comment 7,590.0 7,600.0 6,136.3 6,144.0 A-5, 2G -13 928/1985 4.0 RPERF 2 1 /8 "DremerSarKO -0 Deg ph PACKER, 7.4az 7,590.0 7,604.0 6,136.3 6,147.3 A-5, 2G-13 8/302010 6.0 RPERF Prosector RDX DP 2.5 ", 60 deg 7,593.0 7,594.0 6,138.6 6,139.4 A3, 2G -13 11/5/1984 1.0 IPERF 4" DA JJ ' 7,594.0 7,595.0 6,139.4 6,140.2 A3, 2G -13 11/5/1984 1.0 IPERF 4" DA JJ NIPPLE. 7.499 7,602 -0 7,603.0 6,145.8 6,146.5 A5, 2G -13 11/5/1984 1.0 IPERF 4 "DAJJ 7,603.0 7,604.0 6,146.5 6,147.3 A3, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ 909, 7511 _ 7,622.0 7,660.0 6,161.2 6,190.8 A -4, 2G -13 9128(1985 4.0 RPERF 2 1 /8 "DresserBwKo- O Deg ph 7,625.0 7,628.0 6,163.6 6,165.9 A -4, 2G -13 1115/1984 1.0 IPERF 4" DA JJ ' TTL, 7,512 7,633.0 7,634.0 6,169.8 6,170.5 A-4,213-13 11/5/1984 1.0 IPERF 4" DA JJ 7,635.0 7,636.0 6,171.3 6,172.1 A- 4,2G -13 11/5/1984 1.0 IPERF 4 "DAJJ 7,636.0 7,636.0 6,172.1 6,172.1 A -4,2G -13 1115/1984 1.0 IPERF 4 "DAJJ 7,641.0 7,642.0 6,176.0 6,176.8 A4, 2G -13 1101984 1.0 IPERF 4" DA JJ ' 7,593 -77,5 a' 7,647.0 7,648.0 6,180.6 6,181.4 A -4, 2G -13 11/5/1984 1.0 IPERF 4" DA JJ IPERF, 7.594 7,654.0 7,657.0 6,186.1 6,188.4 AA, 2G - 13 11/5/1984 1.0 IPERF 4" DA JJ RPERF, F7 7,990 -7,600 Stimulations & Treatments RPERF, 7,590 -7,604 � Bottom FRAG, 7,590 Mn Top Maax Btm Top Depth Depth ' Deem Depth (ND) (TVD) (fticB) (ftKB) (PoC6) IIII(B) Type Date Comment 7,590.01 7,604.0 6,136.3 6,1473 FRAC 9112010 PUMP FRAC 110,325# CARBOLITE PROPPAiT IPERF, INTO FORMATION 7.602 03 Notes- General & S afety IPERF, End Date Annotation 7,603 -7,604 9/3/2010 NOTE: TUBING OBSTRUCTION @ 7449 CTMD; UNABLE TO GET BY w2" COIL I PERF. 7.625-7,628 IPERF, 7633-7'634 IPERF, 7,635 -7,636 - A IPERF, 7,636 RPERF, 7.622 -7.860 IPERF, 641 -7642 IPERF, 7,647 -7 648 IPERF. 7,6544,657 PRODUCTION, 7,920 TD. 7,a3s WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 3, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MIT Caliper Log: 2G -13 Run Date: 11 /1/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2G13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -029 - 21160 -00 MIT Caliper Log 1 Color Log 50 -029 - 21160 -00 NOV ; ` ulu PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @hallibur-ton com Date: Signed: t WELL LOG TRANSMITTAL s PROAciiw DiAgNOSTic SERACEC, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE: Cased Hale /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 31 -0ct -10 1Y -06A 1 Report / EDE 50 -029- 20958 -01 21 Caliper Report 01-Nov-10 2G-13 1 Report/ EDE 50-029 - 2 1 1 60 -00 203-V3 NU 2 : �- ��`� - rag 0 03q`Y i1 Signed: Date : t Print Name: C i Gas "O"a. �?aM PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAx: (907)245 - 88952 E-MAIL: DdsanchoraQe c9.ra error dog.:om WEsSITE : mmmmemorylog.com CADocuments and Settings \Diane Williams \Desktop \Transmit_Conoco.docx Multi- Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2G -13 Log Date: November 1, 2010 Field: Kuparuk Log No.: SO# 7743992 State: Alaska ' Run No.: 1 API No.: 50- 029 - 21160 -00 Pipet Desc.: 3.5" 9.3 lb. J -55 EUE 8RD Top Log Intvi: Surface Pipet Use: Tubing Bot. Log Intvl: 3,006 Ft. (MD) ' Inspection Type: ResbicSon Inspection COMMENTS: This caliper data is correlated to the tubing tally dated November 5, 1984. This log was run to assess the condition of the tubing with respect to minimum I.D. restrictions. The caliper recordings indicate deposits from 2,734' to 2,935', with heavy deposits recorded from 2,935' to 3,006' (EOL), restricting the I.D. to 2.01" at 3,000'. No other significant I.D. restrictions are recorded throughout the 3.5" tubing logged. A 3 -D log plot of the caliper recordings across the deposits recorded in the 3.5" tubing and a graph illustrating minimum recorded diameters on a joint-by-joint basis are included in this report. The caliper recordings indicate the 3.5" tubing logged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations or areas of cross - sectional wall loss recorded. ' This summary report is interpretation of data provided by Halliburton Well Services. ' MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17 %) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 4 1 /6) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: Heavy Deposits Minimum I.D. = 2.01" it. 96 @ 3,000 Ft. (MD) ' Heavy Deposits Minimum I.D. = 2.18" it. 94 @ 2,961 Ft. (MD) Heavy Deposits Minimum I.D. = 2.25" it. 95 @ 2,974 Ft. (MD) Deposits Minimum I.D. = 2.36" it. 87 @ 2,740 Ft. (MD) Deposits Minimum I.D. = 2.55" it. 93 @ 2,907 Ft. (MD) ' Field Engineer: J. Conrad Analyst: C. Waldrop Witness: B. Boehme ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDScamemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 U Ta c '�q (.Y) 9 03 '4-q ••. • Sam •• Wn Joint 87 • • � f��f�ffffff�iff� -_ f�f�f�f■f�f�>{ ff■f■f� L- 1 1 Deposits • MINIM mm will — , v E�1 = mf■mmm M1 MMMMMMlll — c f■f■f■mmmIf1m Joint 89 Deposits fflf■f�f■f■f■IEIf� • f■f■f■f■�!'�fEt f■f■f■f�f■f■[t1 �f■f■f���IN� -- '� , f■f■f■f■f■f�lf1 f■f■f■f■f■f�lf1 = — f■f■f■f■f■f■liff■f�f� — f�f�f�f■f�f�lEif■ f�f■f■f■f�f■IE7f■� J �����i1E7�i� iiiiiilUMMMI Deposits iiiiiilYliii _ - iiiiiil � iiiiiil! li - iiiiii�lli -_ iiiiiF 1[i � - iiiiic J oint92 Deposits - ` f iiiil =z7iii _ ,►� iiii��. ,1iii iiiil��•zl�ii -- - � Joint Deposits 292 MinAD.=2.6V • iiiiii�li - 293 Joint 94 - iiii is � Deposits ii - iil7 - - iiIUM iiFjWi [ ii`•�7is�i = i=C. -_is ii iC =lilt liii ii = - -.iic liii iiir iitliii Joint 95 - ' ` iMwi E _ Deposits : i iiir�lt - iiC�ii�� - F iii!_'iEli = - .. "• iC.�`�iiC� iii Deposits `�� Correlation Recorded Damage to Borehole Profile ' Pipe 1 3.5 in (42.5'- 2993.6') Well: 2G -13 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: November 1, 2010 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 47 ' 10 311 20 618 30 932 i 40 1244 50 1551 Z C 2 0 60 1863 p GLM 1 ' 70 2206 80 2510 ' 90 2815 i 96 2994 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) ' Bottom of Survey = 96 i 1 Minimum Diameter Profile Well: 2G -13 Survey Date: November 1, 2010 Field: Kuparuk Tool: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters (In.) 1.69 1.94 2.19 2.44 2.69 2.94 0.1 3 6 9 12 15 ' 18 21 24 27 30 � 33 ' 36 39 42 45 48 Z 51 S ' O 54 57 60 60 .3 62 62 65 68 71 74 77 80 83 86 89 92 ' 95 PDS Report Overview ' -�'►. Body Region Analysis Y g Y Well: 2G -13 Survey Date: November 1, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 ppf J -55 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) Damage Profile (% wall) M penetration body metal loss body penetration body metal loss body 0 50 100 80 0 ' 60 40 1 20 1 IV 20 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% ' Number of joints analysed total = 99 pene. 5 74 20 0 0 0 loss 72 27 0 0 0 0 40 Damage Configuration ( body ) 10 60 GLM 1 ' 78 0 isolated general line ring hole / poss ' pitting corrosion corrosion corrosion ible hole Number of joints damaged total = 8 ' 8 0 0 0 0 Bottom of Sury ey = 96 Analysis Overview page 2 II' PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2010 ' joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 .1 42 0 0.02 8 4 2.95 PUP ' 1 47 0 0.03 10 2 2.95 2 78 0 0.01 4 0 2.93 3 107 0 0.02 8 4 2.96 4 137 0 0.02 9 2 2.94 5 166 0 0.02 9 1 2.94 6 197 0 0.02 9 1 2.93 7 227 0 0.02 8 1 2.93 8 255 0 0.02 8 0 2.93 9 283 0 0.00 2 0 2.93 10 311 0 0.01 5 0 2.91 11 343 0 0.02 9 1 2.94 12 375 0 0.02 8 0 2.93 13 403 0 0.01 2 0 2.92 14 434 0 0.03 10 2 2.93 15 465 0 0.01 3 1 2.91 16 496 0 0.01 5 1 2.93 1 17 525 0 0.03 11 2 2.93 18 555 0 0.02 8 1 2.93 19 587 0 0.03 11 3 2.95 20 618 0 0.02 8 3 2.95 21 650 0 0.02 8 0 2.90 22 681 0 0.01 4 0 2.90 LL Deposits. 23 712 0 0.01 3 1 2.4 24 744 0.09 0.02 9 1 2.93 25 775 0 0.00 2 0 2.90 Lt. Deposits. ' 26 807 0 0.01 6 0 2.91 27 838 0 0.02 9 1 2.92 28 869 0 0.03 11 2 2.94 29 900 0 0.02 9 1 2.93 ' 30 932 0 0.03 10 2 2.95 31 964 0 0.02 7 1 2.91 32 995 0 0.01 3 1 2.93 33 1027 0 0.02 8 0 2.92 ' 34 1059 0 0.02 9 1 2.93 35 1090 0 0.02 9 1 2.94 36 1122 0 0.01 5 1 2.95 37 1152 0 0.02 9 1 2.96 38 1181 0 0.01 6 0 2.93 ' 39 1213 0 0.01 6 1 1 2.93 40 1 1244 0 0.02 9 0 2.91 41 1275 0 0.01 3 1 2.92 42 1305 0 0.03 11 2 2.95 ' 43 1335 0 0.01 3 1 2.93 44 1367 0 0.02 9 2 2.94 45 1398 0 0.01 4 1 2.93 46 1429 0 0.03 10 0 2.92 ' 47 1460 0 0.01 4 0 2.93 48 1489 0 0.02 9 2 2.93 49 1520 0 0.00 1 0 2.92 Penetration Body ' Page 1 Metal Loss Body ' PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. ' Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body /o Loss I.D. Comments (% wall (Ins.) (Ins.) % (Ins.) 0 50 100 50 1551 0 0.02 7 1 2.94 51 1582 0 0.02 9 2 2.96 52 1614 0 0.01 4 0 2.94 53 1645 0 0.02 7 1 2.95 54 1676 0 0.03 11 1 2.95 55 1708 0 0.03 12 1 2.92 56 1738 0 0.00 0 0 2.92 57 1768 0 0.02 9 1 2.94 58 1799 0 0.02 9 1 2.92 ' 59 1831 0 0.03 11 2 2.93 60 1863 0 0.02 9 2 2.96 60.1 1894 0 0.00 0 0 2.95 1 PUP 601 1900 0 0 0 0 2.81 Baker'FVL' SSSV 60.3 1914 0 0 0 0 2.96 PUP 61 1920 0 0.04 15 2 2.95 Shallow pitting. 61.1 1952 0 0 0 0 N/A GLM 1 Latch @ 8:30 62 1958 0 0.04 16 1 2.94 Shallow pitting. ' 63 1990 0 1 0.04 17 1 2 2.94 1 Shallow pitting, 64 2021 0 0.03 10 2 2.93 65 2053 0 0.04 14 1 2.94 Shallow Pitting, 66 2084 0 0.02 7 0 2.94 67 2116 0 0.01 2 0 2.92 68 2145 0 0.02 9 0 2.94 69 2175 0 0.01 2 0 2.93 70 2206 0 0.03 11 1 2.93 71 2238 0 0.04 14 1 1 2.92 Shallow pitting. 72 2267 0 0.01 4 0 2.92 73 2295 0 0.03 13 1 2.93 Shallow Pitting. 74 2324 0 0.03 13 2 2.93 Shallow pitting. 75 2356 0 0.02 9 1 2.93 ' 76 2387 0 0.03 12 4 2.93 77 2419 0 0.01 3 0 2.89 Lt. Deposits. 78 2450 0 0.01 6 0 2.90 Lt Deposits. 79 2481 0 0.00 1 0 2.89 Lt. Deposits. ' 80 2510 0 0.02 8 1 2.93 81 2542 0 0.03 13 2 2.90 Shallow pitting. Lt Deposits. 82 2570 0 0.02 9 1 2.93 83 2602 0 1 0.03 12 1 1 2.90 84 2634 0 0.01 2 0 2.91 ' 85 2665 0 0.02 9 1 2.93 86 2697 0 0.01 4 0 2.90 Lt. Deposits. 87 2726 0 0.03 11 1 2.36 Deposits. 88 2755 0 0.02 8 1 2.90 Lt. Deposits. ' 89 2785 0 0.03 10 2 2.61 Deposits. 90 2815 0 0.01 4 0 2.89 Lt. Deposits. 91 2845 0 0.02 9 1 2.75 Deposits. 92 2874 0 0.02 9 1 2.59 Deposits. I 93 2903 0 0.02 9 3 2.55 Deposits. 94 2932 0 0.02 9 3 2.18 Heavy Deposits. 95 2962 0 0. avv De sits. Penetration Body ' Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD Well: 2G -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. ' Nominal I.D.: 2.992 in Country: USA Survey Date: November 1, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 96 2994 0 0.03 11 2 2.01 Heavy Deposits. Penetration Body Metal Loss Body ' Page 3 0 0 Jj s PDS Report Cross Sections IM Well: 2G-13 Survey Date: November 1, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 ' Tubing: 3.5 ins 9.3 ppf -55 EUE 8RD Analyst: C. Waldro Cross Section for Joint 96 at depth 2999.857 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 45 ° ' 1 Finger 15 Projection = -0.636 ins Heavy Deposits Minimum I.D. = 2.01 ins HIGH SIDE = UP ' Cross Sections page 1 ' S PDS Report Cross Sections ' Well: 2G -13 Survey Date: November 1, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 ' Tubing: 3.5 ins 9.3 ppf J -55 EUE 8RD Analyst: C. Waldro Cross Section for Joint 94 at depth 2961.177 ft Tool speed — 43 Nominal ID = 2.992 ' Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 51 ° / 1 Finger 19 Projection = -0.65 ins Heavy Deposits Minimum I.D. = 2.18 ins HIGH SIDE = UP ' Cross Sections page 2 ' KUP 2G -13 cwoca� I Attributes Angle & MD TD Alaska. Inc. re APPUM Flew Name Wea Status NIt MD (RI(B) At Ban (Rte) 500292116000 KUPARUK RIVER UNIT PROD 47.60 2,900.00 7,936.0 Camnrrt H28 Q+ga) Date Amattwn 6W Date IB�rtl (R) Mg Release Date ' ••• W,41 on6 : - -t + + * F.>M SSV: LOCK ED OUT 11/1212004 Last WO: 10/1!1984 AmaDtlon Depth (RIe) End Date Amatatlon Last Mod ey Et1d Date Last Tag: TOC 7,622.0 8/30/2010 Rev Reason: TBG OBSTRUCTION, GLV C/O knosbor 10/3/2010 Casino Strings St Mg DD String ID St Depth St epm(TVD) Sating Wt no CONDUCTOR, Casing Description (W 8N Top (!0 oil" IRKS) 6�RG Grade String Top Thrd 110 CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H40 ' SURFACE 95M 8.765 0.0 2,849.0 2,707.8 36.00 J-55 Serary valve, 6.151 ON 7 6.151 0.0 7,920.0 6,396.4 26.00 J-55 1,900 Tubing Strin s St StZ ID St Depth Set Depm(7VD) a.. Wt String ' GAS LF7, TUEprg Description 8n1 larl Top (DIB) (RIB) MKS) (maRO oracle String Tap W" 1.952 m TUBING 3112 2.992 0.0 7,512.0 6,076.2 9.3u EUE 8RD SURFACE. Other In Hole All Jewelry: Tubing Run & Retrievable, Fish etc. 2.819 TOP Dm (TVD) s+ ToP Inc TOP 0=11 488121 1 PI Description Comment Run Date ID (in) ' GAS LIFT. 1,900.0 1,893.9 16.23 Safety Valve Baker 'FVU (LOCKED OUT 4115/1993) 11/6!1984 2.810 3.164 1,952.0 1,943.4 17.92 GAS LIFT MMH13.5x1 /i1DMY /BTMI! /Comment: STA 1 885/2010 1937 3,864.0 3,421.1 45.20 UFT MMH13.5x1 111DMY 1BTM1// Commem: STA 2 885 10 2.937 GAS LIFT. 5,503.0 4,595.7 43.70 GAS LIFT MMH13.5x111 /DMY /B'rW // Comment: STA 3 8858010 2.937 6'503 6,653.0 ,438.0 43.69 GAS LIFT MMH/3.5x1111DMY 18TH!! /Comment: STA4 8!248010 2.937 ' 7,424.0 6,009.6 40.89 GAS LIFT MMHl3.5xl /l10PEN1BKI // Comment: STA 5 9/6/2010 2.937 GAS LIFT, 7,468.0 6,042.7 40.46 PBR Baker PBR 1116!1 2.810 6,653 7,482.0 6,053.3 .32 PACKER Baker THL' PACK R 11/6/1984 3.000 7,499.0 6,066.3 40.16 NIPPLE Camco'D' Nipple NO GO 11/611984 2.750 ' GAS LIFT, ,511.0 6,075.5 40.04 SOS Baker 11/6/1984 2.992 424 7,512.0 6,076.2 40.03 TTL EL MD TTL @ 750Y during OTIS FLUID ID LOG on 1 V6/1984 2.992 12/3017984 PI 7,468 Perforations & Slots shat IRTOP1411) can POUR (ens T" Mlel MR 6u1B1 RSI RBI zwra Date (tL•• type Comment +r 7,590.0 ,600.0 6,136.3 6,144.0 A-6, 2G-13 98 &1985 4.0 RPERF 2 118 "DreswBarKo - 0 Deg ph PACKER, 7,482 7,590.0 7,604.0 6,136.3 6,147.3 A-5, 2G-13 8/3012010 6.0 RPERF Prosecwr RDX DP 2.5". 60 deg 7,593.0 7,594.0 6,1 .6 6,139.4A - 5 13 1115/1984 1.0 TPE RF 4 " CIA JJ ' ,594.0 7,595.0 6,139.4 6,14o.2 A-6, 2G-13 111W1984 1.0 IPERF 4" DA JJ NIPPLE. 7.499 7,602.0 7,6010 6,145.8 6,146.5 A-5, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ 7,603.0 7,604.0 6,146.5 6,147.3 A-5, 2G-13 11/5!1984 1.0 IPERF 4" DA JJ 7,622.0 7,660.0 6,161.2 6,190.8 A4, 2G-13 988! 985 4.0 APERF RPERF 21/8"Dre wBarK0-0 Deg ph SOS. 7.511 - -_ - -- 7,625.0 7,628.0 6,163.6 6,165.9 A4, 2G-03 11/5/1984 1.0 IPE F 4" DA ii ' TTL,7,512 7,633.0 ,634.0 ,169.8 6,170.5 A4, 2G-13 11/5/1 84 1.0 IPE F 4 °DAJJ 7,635.0 7,636.0 6,171.3 6,172.1 A4, 2G-13 11/5/1984 1.0 IP RF 4" DA J J 7,636.0 7,636.0 6,172.1 6,172.1 A- 4,2G-13 1/5/1984 1.0 IPERF 4 "DAJJ - 7,641.0 7,642.0 6,176.0 6,176.8 A4, 2G73 11/5/1984 1.0 IPERF 4" DAJJ Imo - 7,647.0 7,648.0 6,180.6 6,181.4 A4,2G -13 11/5/1984 1.0 IPERF 4" DA JJ 7.5937.591 IPERF 7,594 - 7.595 7,654.0 7,667.0 6,186.1 6,188.4 A4, 2G -13 1115/1984 1 1.0 IPERF 4" DA JJ RPERF, 7.596 -7.SDa Stimulations & Treet1►Hmts RPERF, 7.690 -7,604 Bottom FRAC, 7,590 Min Top Max Ban Top Depth Depth Depth Depth (TVD) (TVD) t (RRB) IRKS" (RIB) (R+e) 7ype Date Comment 7,590.0 7,604.0 6,136.3 6,147.3 FRAC 9/1/2010 PUMP FRAC 110,325#C NRBOLITEPROPPANT IPERF INTO FORMATION 7,60 2 -7. 603 Notes: t36meral & Safety IPERF, - _ - End Date F Annotation ? 6037.6« = 9/3/2010 NOTE: TUBING OBSTRUCTION @ 7449 CTMD; UNABLE TO GET BY w8" COIL IPERF. 7,6257,626 IPERF, ' 7.6337.634 - - IPERF. S-7 ' W IPERF. 7,636 RPERF, 7,622 -7,660 I PERF, 7,641 -7,612 IPERF, ?617 -? 618 PERF, 7,654-? 657 PRODUCTION, 7. 920 TD, 7,936 Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.co q'~' l~ Sent: Monday, September 06, 2010 12:26 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); Maun er, Thomas E (DOA) Cc: NSK Problem Well Supv; CPF2 Prod Engrs Subject: 2G-13 (PTD 184-129) Report of suspect TxIA communication Attachments: 2G-13 schematic.pdf Guy, Tom, Jim Kuparuk gas lifted producer 2G-13 (PTD 184-129) has suspected TxIA communication that was noted during routine well work. The well has been SI since October'05. The TIO prior to the work was 2050/2000/330. Slickline is in the process of diagnostic work and will repair if possible. Further diagnostic work will be done as needed, which may include E-line and the DHD crew. Attached is a schematic and 90 day TIO plot. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~,- - ~ ~' X55 ~('~,F ~.~ = z~~ ~~ . ~.~~ r r s ~~~ Pry 1~. _ 12.~ ~~h ~ ~ ~~ 9/7/2010 KRU 2G-13 PTD 1841290 9/6/2010 TIO Pressures Plot • 0, 0. 0. 0. 0. 0. 0. 900 600 300 0 ------------------------ PLOT START TIME MINOR TIME 08-JUN-10 10:24 MAJOR TIME WEER ~C TAG N~![E WL2G-13-CHORE SCRATCH 62 SCRATCH_62 AI-P2G5002-13 SCRATCH_62 SCRATCH_62 DESCRIPTION FLOW TUBING CHORE FLOW TUBING PRESSURE FLOW TUBING TEMP GL CASING PRESSURE INNER ANNULI7S PRES OUTER ANNULUS PRES PLOT DURATION PLO~I } ~> "i T ME ~~~~~ ~~~ PREV WELL DRILLSITE WELL 2g 13 NEXT WELL EN'T'RY TYPE OPERATOR OPERATOR VERIFIED SYSTEM AUTO ENTRY BOTH ANNULUS PRESSURE TRENDS WELL NAMP: WLRRU2G-13 _. ,,, . , ~ - ~ ~ 2G-13 ~ KUP ~~ ~ ( ~Oi10~0~~'tl~~l $ __ _ e & MD TD Well Attributes x P, II l p ; '. . _ _ „ acne) Y.~t Btm (ttKB) Ilb ame W IISWWS I:,GI API/UWf F,eIdN t '~ ""'' ~ C 500292116000 KUPARUK RIVER UNIT PROD 47.60 2,900.00 7,936.0 n (pp ) H2S m Date -Ord (R) Annotation End Date B Rig Release Date alarroioz-aooSFnf -. n 1s w uc zG SSSV:LOCKEDOUT 120 11/12/2004 LastWO. 40.98 10/1/1984 .- - , e n„ Schematic- nc„ai ~ Annotation Depth (RKB) End Date Annotation Last Mod By End Date Last Tag'. SLM 7.575.0 9/11/2009 Rev Reason: DELETE WAIVER Imosbor 4/18/2010 ~ Casin~Strings ~ i ~ y ~ String OD String ID Set Depth Set Depth (ND) String Wi String CONDUCTOR. I ~ Casing Description (in) (in) Top (RKB) (RKB) (RKB) (Ibs/ft) Orade String Top Thrd t1D ~.__ ~ CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H-00 SURFACE 9 5/8 8.765 0.0 2,849.0 2,707.8 36.00 J-55 sareiyvame, 1,900 ~,' PRODUCTION 7 6.151 0.0 7,920.0 6,396.4 26.OO J-55 -- I i ng Strin s _ _ _ Tub _ ~~ _ _ String OD Stn g ID ~ Set D pth Set Dep[h (ND) Sinng Wt Sn ng GAS LIFT, ~ J _ Tubing Description (in) ( ) Top (RKB) i (ftKDI (ft KB) (lbslft) Grade String Top Thrd ~ 1652 ) 9.30) EUE 8RD 512.0 6 992 0-0 7 TUBING 31/2 2 L _ , . t Other In Hole (All Jewelry: Tubin Run & Retrievable, Fish, etc.) _ SURFACE, > Top Depth 2,849 ('. (ND) Top Intl Top (RKB) (RKB) (°) Description Comment Run Date ID (in) cns uFr, ~°"~__-~ ~ I 1,900 1,893.9 16.23 Safety Valve Baker'FVL' (LOCKED OUT 4/15/1993) 11/6/1984 2.810 3,864 _ - 1,952 1,943.4 17.92 GAS LIFT MMHl3.5x1/1/GLV/BTM/.156/1305/Comment: STA 1 12/27/2005 2.937 I 3,864 3,421.1 45.20 GAS LIFT MMH/3.5x1/1/GLV/BTM/.188/1340/Comment: STA2 12/27/2005 2.937 cns -~ I ~ 5,503 4,595.7 43.70 GAS LIFT MMH/3.5x1/1/GLV/BTM/.188/1335/ Comment: STA 3 12/27/2005 2.937 si~ `-~ 6,653 5,438.0 43.69 GAS LIFT MMH/3.5x1/1/GLV/BTM/.188/1325lComment: STA4 12/27/2005 2.937 7,424 6,009.6 40.89 GAS LIFT MMH/3.Sx1/1/OVBK/.188// Comment: STA 5 12/26/2005 2.937 ' _ ~ 7,468 6,042.7 40.46 PBR Baker PBR 11/6/1984 2.810 Gns uFr, 6,653 c.-) ~y- 7,482 6,053.3 40.32 PACKER Baker'FHL' PACKER 11/6/1984 3.000 7,499 6,066.3 40.16 NIPPLE Camco'D' Nipple NO GO 11/6/1984 2.750 __ ~ ~ 7,511 6,075.5 40.04 SOS Baker 11/6/1984 2.992 Gns uFr. r. ~ 7,512 6,076.2 40.03 TTl ELMD TTL @ 7503' during OTIS FLUID ID LOG on 11/6/1984 2.992 7,424 .. 12/30/1984 _ -__. __ . Y. ~ , ___._ _. _ Perforations & Slots PBR, 7,468 ~- -- _ Shot Top (ND) Btm (ND) Dens ~ Top (tg(B) Btm (RKB) (RKB) (RKB) Zone Date (sh... Type Comment l 1 7,590 7,600 6,136.3 6,144.0 A -5, 2G-13 928/1985 4.0 RPERF 2 1/8"DresserBarKo- 0 Deg ph PACKER, 7,482 i-S:b:.i't=r~3:' 7,593 7,594 6,138.6 6,139.4 A -5, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ 7,594 7,595 6,139.4 6,140.2 A -5, 2G-13 11!5/1984 1.0 IPERF 4" DA JJ 7,602 7,603 6,145.8 6,146.5 A -5, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ NIPPLE, 7,499 pp # ,~ 7,603 7,604 6,146.5 6,147.3 A -5, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ (- 7,622 7,660 6,161.2 6,190.8 A -0, 2G-13 928/1985 4.0 RPERF 21/8"DresserBarKo-0 Deg ph -- 7,625 7,628 6,163.6 6,165.9 A -0, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ sos, 7,511 ~ 7,633 7,634 6,169.8 6,170.5 A -0, 2G-13 1.0 IPERF 4" DA JJ -- 7,635 7,636 6,171.3 6,172.1 A -4, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ rrL, 7,512 7,636 7,636 6,172.1 6,172.1 A -0, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ 7,641 7,642 6,176.0 6,176.8 A -0, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ 7,647 7,648 6,180.6 6,181.4 A -0, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ 7,654 7,657 6,186.1 6,188.4 A -0, 2G-13 11/5/1984 1.0 IPERF 4" DA JJ IPERF. - _ 7,5937.594 IPERF, 7,5947.696 RPERF, 7,590-7.600 IPERF, ......... ....... 7,fi02-7,603 _..~ .... IPERF, --- ""_' 7,6037,604 ..... IPERF, 7,625-7,626 IPERF, 7,6337,634 IPERF, 7,635-7,636 '_ IPERF, 7,636 RPERF, 7,622-7,660 ~---• °: IPERF, , 7,641-7,642 IPERF, ,-.. ___ 7.847-7.646 IPERF, - 7,654-7.657 PRODUCTION, 7,920 TD. 7,936 • Cc~narcoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7'~ Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: .k LO~,i ~~'~~ ,. i ,1 ~~~~ ~ ..APR 2 '~ ~01Q ,i~Sk~ t:Jl ~ f~as C;or-s. ~ammissia~ Anchorage f r' ~~ a~ - ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped Apri115, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 2R_ 2F_ 9[, 7H 7K 7M 7V 7W 7Y 77 ~ ZC DArNe I~ ell Name PI # TD'# Initial top o cement Vol. of cement um ed __ __ _~ Final top of cement .~ .~ Cement top off date ., ., ~Y Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/16/2010 2B-08 50029210790000 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF n/a Na Na 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G13 50029211600000 1841290 SF Na 22" Na 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" n/a 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" Na 2.5 4/152010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/152010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/152010 2K-19 50103201180000 1891090 53" 0.50 9" 1/162010 2.1 4/152010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/15/2010 2M-08 50103201840000 1921010 SF n/a 17" Na 2.1 4/152010 2M-20 50103201690000 1920480 SF n/a 17" n/a 2.5 4/152010 2M-22 50103201700000 1920490 SF n/a 17" n/a 2.5 4/152010 2M-28 50103201740000 1920700 SF n/a 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF Na 19" n/a 7.6 4/16/2010 2V-10 50029213100000 1850480 SF n/a 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-03 50029212740000 1850110 SF n/a 37" Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF n/a 17" n/a 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" n/a 2.5 4/152010 2Z-12A 50029213800100 1951480 SF n/a 19" Na 2.5 4/152010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/152010 2Z-19 50029218820000 1881300 SF n/a 16" n/a 2.1 4/152010 3S-O9 50103204320000 2022050 SF Na 45" Na 23 4/17/2010 Schlumbel'ger NO. 3429 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 07/08/05 l cq Lt-t?-if 5Cl~\NNE[ SEP 0 6 20CJ5 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 2G-02 I ~ f.{ -j). t 11047334 BHP SURVEY 06130105 1 f 2G-13 I~:'¡-i)'''' 11047336 BHP SURVEY 07/01/05 1 J. 2G-11 ,g'-, -i (7 11047337 BHP SURVEY 07/01105 1 y 1Y-14)3~~ ù..() 11022907 LEAK DETECTION LOG 06130105 1 ¡j 3H-19 18"7 .../J") 11022907 PRODUCTION PROFILE 06128/05 1 \./, 1 J-03 .~(A - c ).. 'f 11022893 PRODUCTION PROFILE 06117105 1 .J 1 L-09 ,q D·" ~;j V 11022895 PROD PROFILE WIDEFT 06119105 1 '/, 3S-10 ,J. 0;" - 1} 1 11001235 PROD PROFILE WIDEFT 06114105 1 .) 3F-04 ¡/j:J" . )...).8 11022891 INJECTION PROFILE 06115/05 1 1Y-26A íJ,j'II~ 11022892 PROD PROFILE WIDEFT 06116105 1 ;./ 1E-112)( 4-({iI 11047339 INJECTION PROFILE U i (, 07103105 1 j 1E-102 .Á\;~"'J,Jl 11047340 INJECTION PROFILE UiC 07104105 1 SIGNED: 1/1 / ê !;~~ DATE: I. I ÔIIJ~i Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD -' ~ /\ \ ~J '(:I-....... ~-_. f :¿Ô'i J-~' STATE OF ALASKA ALAb,,~ OIL AND GAS CONSERVATION COMMIS5~,.),~; REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 303' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 1375' FSL, 1242' FEL, Sec. 6, T10N, R9E, UM At effective depth 1223' FSL, 1305' FEL, Sec. 6, T10N, R9E, UM At total depth 1167' FSL, 1329' FEL, Sec. 6, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7936 feet Plugs (measured) 6408 feet 6. Datum elevation (DF or KB) RKB 140 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-13 9. Permit number/approval number 84-129 10. APl number 50-029-21160-00 11. Field/Pool feet Kuparuk River Field/Oil Pool None Effective depth: measured 7837 feet Junk (measured) None true vertical 6329 feet 13. 14. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 202 Sx CS II 1 21 ' I 21 ' Surface 2812' 9-5/8" 875 Sx PFE & 2849' 2706' Intermediate 420 Sx PFC Production 7885' 7" 375 Sx Class G 7 9 2 0' 6 3 9 5' Liner Ex 250 Sx PFC Perforation depth: measured 7590'-7600', 7622'-7660' true vertical L 61 35'-6143', 6160'-6190' 0RIGINA Tubing (size, grade, and measured depth) RECEIVED 3.5", 9.3#/ft., Packers and SSSV (type and measured depth) Packer: Baker FHL @ 7482': SSSV: Baker FVL @ 1900' (Locked out) ..... ~ Stimulation or cement squeeze summaw ~ ~ ~ [~[ Fracture stimulate 'A' Sands on 6/28/97. Inte~als treated (measured) 7590'-7600' 7622'-7660' ~ 0il & Gas Cons. Commission - , Anchorage Treatment description including volumes ased and final pressure Pumped 219.2 Mlbs of 20/40, 12/18, & 10/18 ceramic proppant into formation, fp was 4715 psi. Representative Daily Average Production or Injection Data OiI-Bbl G~-~ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 228 85 402 1156 153 Subsequent to operation 565 35 0 773 1164 157 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned /..5 C'~.~f'-~.-¢* m Title Wells Superintendent Form 1'0-404 Date 1 -4 , SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '~, WELL SERVICE REPORT ~ K1 (2G-13(W4-6)) WELL JOB SCOPE JOB NUMBER 2G-13 FRAC, FRAC SUPPORT 0620971810.5 DATE . DAILY WORK UNIT NUMBER 06/28/97 PUMP "A" SANDS RE-FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 ~ ¥~s O"oI ® Yes O No DS-YOKUM JOHNS ESTIMATE KD1302 230DS28GL $1 37,400 $155,111 ,~~~. Initial Tb.q Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial OuteCAnn ! Final O¢~Ann 1342 PSI 2800 PSI 200 PSI 1000 PSI~ 400 PSI[ 500 PSI DAILY SUMMARY PUMPED "A" SANDS RE-FRAC , WITH 219,227# PROPPANT , 12# PPA 10/14 PROP. AT PERFS. FLUSHED PROPPANT TO PERFS , I LEAVING 960# PROPPANT IN PIPE. TIME 07i00 07:34 07:52 LOG ENTRY MIRU DOWELL EQUIPMENT, APC DOWNHOLE PUMP AND APC VAC TRUCK. HELD JOB SITE SAFETY MEETING PRESSURE TEST SURFACE TREATING LINE TO 9600 PSI. 08:22 08:26 08:29 08:31 08:34 08:42 09:32 11:01 11:40 11:53 12:58 13:01 13:06 ~ ~-~JT!AE WHP 1342 PSI, START PUMPING BREAKDOWN 25-BPM ~ 50#GEL AN,r} 7','~;0 PSI. pUMp 1PPA 20/40 SCOUR STAGE, 15 BPM AND 5617 PSI. PUMP CONDITION STAGE 50 BBLS. 2011# PUMP 2PPA 20/40 SCOUR STAGE, 15 BPM AND 4596 PSI. 3860 # PUMP 120 BBL FLUSH. SHUTDOWN FOR ISIP, 1932 PSI. PUMP FLUSH AND DATA FRAC. 5 TO 15 BPM AND 5324 PSI. PUMP 480 BBLS PAD. TO 4377 PSI. PUMP 15,439 # 20/40 PROPPANT TO 2PPA, 15 BPM AND 4715 PSI. DEVELOPED LEAK ON TREATING LINE, SHUT DOWN JOB AND SECURED WELL, REPAIRED LEAK. RESTART FRAC JOB AT 4 PPA., CONTINUE PUMPING WITH A TOTAL OF 193,000 12/18 PROPPANT TO 11PPA. PUMPED 9187# 10/14 PROPPANT TO 12 PPA 15 BPM AND 4834 PSI. PUMPED FLUSH TO PERFS , LEAVING 1000# PROPPANT IN PIPE. SHUT DOWN , RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $700.00 APC $7,900.00 $14,800.00 DOWE LL $129,500.00 $135,519.00 HALLIBURTON $0.00 $4,092.00 LITFLE RED $0.00 $0.00 TOTAL FIELD ESTIMATE $1 37,400.00 $1 55,111.00 ARCO Alaska, In Post Office ,.,ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 ORIGI August 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. Well Action 2G-13 2G-15 2G-08 3H-04 1A-11 1A-16a 1A-04 1F-08 1F-15 Refracture Refracture Refracture Acidize Tbg. Leak Packer Leak Acidize WAG Conversion WAG Conversion If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS:P, jr cc: J. Gruber J. R. Brandstetter L. L. Perini KeEl .4-9 · ATe 1478 ATe 1120 ATe 1130 w/o attachments RECEIVED Alaska 0il & Gas Cons. l;ommissim; ARCO Alaska. Inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ~ ALASKA OIL AND GAS CONSERVA~ON COMMI~I~ 0 REPORT OF SUNDRY WELL OPERATIONS Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Repair well Plugging Perforate __ Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 303' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 3905' FNL, 1242' FEL, Sec.6, T10N, R9E, UM At effective depth 4015' FNL, 1306' FEL, Sec.6, T10N, R9E, UM At total depth 4113' FNL, 1329' FEL, Sec. 6, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 793 6' feet Plugs (measured) 6409' feet None 6. Datum elevation (DF or KB) RKB 140' 7. Unit or Property name Kuparuk River Unit feet 8. Well number ,/3_ 2G- 1 9. Permit number 84-1 29 10. APl number 5o-029- 211 6000 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 783 7' feet Junk (measured) 63 3 0' feet None Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 2849' 9 5/8" Intermediate Production 7 9 2 0' 7" Liner Perforation depth: measured 7590'-7600, true vertical 6136'-6144', Tubing (size, grade, and measured depth 3 1/2", J-55 7512' Packers and SSSV (type and measured depth) FHL @ 7482', FVL @ 1900 (SSSV) Cemented Measured depth 202 Sx COLD SET II 110' 875 Sx Permafrost E 2849' 420 Sx Permafrost C 375 Sx Class G 250 Sx Permafrost C 7920' 7622'-7660, MD 6161'-6191' TVD True vertical depth 110' 2706' 6386' RECEIVED Aladla Oil & Gas Cor Angl ora 13. Stimulation or cement squeeze summary Hydraulically fractured well with 59000# of 16/20 Carbolite, and 1061 bbls gelled water. Job screened out. Intervals treated (measured) 7590'-7600', 7622'-7660' Treatment description including volumes used and final pressure 59000# Carbolite, 1061 bbls gelled water, -~.30 bbls Diesel last WHIP 6200 psi 14. Representative Daily Average Production er Iniection Dat~, OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 665 480 0 1000 120 1227 984 0 500 240 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil _.X. Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · Signed ~ ~ )~ ,.,~2 ~,~.1,~~.,--o'-~-~ 'filJeSR. OPERATIONS ENGINEER Form 10-40,~/Rev 06/15/88 SUBMIT IN DUPLICATE :ARCO Alaska, Ir-"- Subsidiary of Atlantic Richfield Com~ WELL SERVICE REPORT i--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knotsI ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~MISSION i~ ~- APPLICATION FOR SUNDRY APPROVAL J i [ 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 303' FNL, 88' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 3905' FNL, 1242' FEL, Sec.6, T10N, R9E, UM At effective depth 4015' FNL, 1306' FEL, Sec.6, T10N, R9E, UM At total depth 4113' FNL, 1329' FEL, Sec. 6, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 793 6' feet Plugs (measured) 6409' feet None 6. Datum elevation (DF or KB) RKB 140' 7. Unit or Property name Kuparuk River Unit 8. Well number J 2G-13 ,,,,.. c, 9. Permit number 84-1 29 10. APl number 5o-029-21 1 6000 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7837' feet Junk (measured) 6 3 3 0' feet None Casing Length Structural Conductor 1 1 0' Surface 2849' Intermediate Production 7 9 2 0' Liner Perforation depth: measured 7590'-760O, true vertical 6136'-6144', Tubing (size, grade, and measured depth 3 1/2", J-55 7512' Packers and SSSV (type and measured depth) FHL @ 7482', FVL @ 1900 (SSSV) Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 202 Sx COLD SET II 110' 875 Sx Permafrost E 2849' 420 Sx Permafrost C 375 Sx Class G 250 Sx Permafrost C 7920' 7622'-7660, MD 61 61'-6191' TVD 13. Attachments Description summary of proposal _ 110' 2706' 6386' Detailed operation program Fracture stimulate the A Sand with 119000# 16/20 Carbolite 14. Estimated date for commencing operation June 10. 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~d Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned .~//~4~,.~ .~/~ ~'~-""-~"/~ ..~--/%~'~'~Title Sr. Operations Engineer ~L FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance__ Mechanical Integrity Test ~ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH ~\pproved Copy Retul~c~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Commissioner Date SUBMIT IN TRIPLICATE Messrs Lyden and Wad~ June 7, 1989 Page 3 Kuparuk Well 2G-13 'A' Sand Re-Fracture Procedure Charge Code: K80321 1. Obtain a 24 hour well test. . . MIRU Slickline unit. RIH with tubing end Iocator and tag fill. Pull GLV's at 1952', 3864', 5503', 6653' and 7424' and run DVs. RIH with Standing Valve and set in Camco 'D' nipple. Pressure test tubing to 4500 psi to ensure DVs are set. RIH and pull SV. 4. RDMO Slickline. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. If a cleanout is performed, at least 150 feet of rathole is desired. 5. MIRU fracture equipment. Install "Tree Saver". . . Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Lite for fines due to excessive handling. Obtain a sample of the Carbo-Lite and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 3250 psig Fracture Gradient = 0.70 psi/ft Tubing Friction = 300 psi/1000 (6000' TVD) ft (8434' MD) @25 BPM * If treating pressure during the job exceeds 6000 psi, reduce rate to a minimum of 15 BPM. If pressure exceeds 6500 psi, shut down job and confer with Engineering. 8. Rig down frac equipment. Follow attached flowback schedule. . After well has completed flowback, obtain 24 hour well test. Contact Operations Engineering for a new gas lift design when necessary. ~ O- 09 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~"'~3 O-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~ O- 18 Kuparuk Fluid Level Report 3 - 1 7 - 89 Casing "~~OB-09 Kuparuk Fluid Level Report 3-1 7-89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7- 8 9 Casing Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil ARCO Alaska, Inc. Date: March 24, 1989 Transmittal Ct: 7447 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 30-16 Kuparuk Well Pressure Report 1-3-1 89 --- 3 O- 10 Kuparuk Well Pressure Report 2 - 04 - 89 '--- 3 O- 13 Kuparuk Well Pressure Report 2 - 08 - 89 ..,,~30-03 Kuparuk Well Pressure Report I-09-89 · ,,.- 3 O- 15 Kuparuk Well Pressure Report 3 - 04 - 89 · .,..~. 2G-14 Kuparuk Fluid Level Report 3-11-89 ~ 2G- 13 Kuparuk Fluid Level Report 3 - 1 I - 8 9 -',~-2G-09 Kuparuk Fluid Level Report 3-1 1-89 ~ 1 E-0 3 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 "'"' 1 E-0 5 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 3 O- 1 8 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 '""' 3 H - 1 0 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 ~ 3 A- 03 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 ~ 3 H - 0 4 Kuparuk Fluid Level Report 3 - 0 4 - 8 9 ~2 El - 14 Kuparuk Fluid Level Report . 3 - 13 - 89 "~--30-13 Sub-Surface Pressure Survey 2-08-89 e,,,,,30-10 Sub-Surface Pressure Survey 2-04-89 "'-- 3 O- 16 Sub-Surface Pressure Survey 1 -.31 - 89 ~' 1 B- 07 Kuparuk Fluid Level Report 3 - 31 - 88 ~1 B - 03 Kuparuk Fluid Level Report 1 - 27 - 88 ~ 1 B - 05 Kuparuk Fluid Level Report 1 - 27 - 88 '"'"~1 B - 07 Kuparuk Fluid Level Report 4 - 27- 88 ~ 1 B - 07 Kuparuk Fluid Level Report I - 27 - 88 ~ 1 L- 08 Kuparuk Fluid Level Report 2 - 1 2 - 88 ~,,,~1 L- 04 Kuparuk Fluid Level Report 2 - 1 2 - 88 ~"~3 H - 10 Kuparuk Fluid Level Report 3 - 1 7- 89 "'~.-3M- 01 Sand 'A' Sand 'A' Sand 'A' Sand 'A' Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing Tubing .C..as£ng Kuparuk Fluid Level Report 3-1~ ir~ FI j~j~ ,_.. 'k,., I,,,. I A~chorage ARCO Alaska, Inc. Posl Ollice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 28, 1987 Ms.'Fran Jones Alaska Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Conservation Commission Subject: Miscellaneous GCT Surveys Dear Fran: Enclosed are additional copies of the 1L-6 2A-2 1L-15 2A-3 1L-16 2A-4 L1-1 2D-11 L2-28 2D-12 questions, please call me at If you have any Sincerely, Gruber Associate Engineer JG:pk JG/78 Enclosures fol lowing 2G-8 2G-10 2G-13 GCT surveys: 263-4944. R£CEIVEo JUL .~ I 1~87 0il & Gas CoDs. Commlsslojf ~chorage ArICO Aln~k;~, Inc. Is ~ Subsldlm'y of AllenllcRIcltlleldCompany ARCO Alaska, Inc. Post Office Box )360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed on the 2C-2 Perforate 9 / 28/85 2G-1 3 Reper forate 9/28/85 2G-1 4 Reper forate 9/28/85 2G-15 Reper forate 9/30/85 2G-1 6 Reper forate 9/30/85 If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. C£1v£b 0C7'1 1 1985 ,,/ ~ 6as Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~( OTHER [] 2. Name of Operator ARCO ALASKA, ! NC. 3. Address P O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 303' FNL, 88' FEL, SEC. 6, T10N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) lq0 ' (RKB) 12. 7. Permit No. 84-129 8. APl Number 50- 029-21160 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 2(3-1 3 11. Field and Pool KUPARUK RIVER F! ELD I 6. Lease Designation and Serial No. KUPARtJK RIVER O I L ADL 25667 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On September 28 1985, the "A" sands of Kuparuk well 2G-13 were reperforated fo~ production. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. Interval (MD). 7590'-7600' (4 SPF) 7622'-7660' OC 1985 Alaska 0il & Gas Cmos. Anchorage 14."1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'/~ ~~ Title KUPARUK OPERAT i ON$ COORDi NATOR The space below for Commission use Conditions of Approval, if any: Date 1 0 / 9 / 85 Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Im Post Office Bo~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 23, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive · Anchorage, AK 99501 Dear Mr. Chatterton: Attached is our notice of intention to perforate Kuparuk field wells 2G-13, 2G-14, 2G-15 and 2G-16. If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD:ps:File Attachment (In Triplicate) RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-129 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 5o-029-21160 OTHER [] 4. Location of Well 303' FNL, 88' FEL, Sec.6, TiON, RgE, UH 5. Elevation in feet (indicate KB, DF, etc.) RKB 140' PAD 104' 6. Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name Kuparuk River Ilnit 10. Well Number 2G-13 11. Field and Pool Kuparuk River Field Kuparuk Riber 0il Po01 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stim u late [] Abandon [] Stim u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.} SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 2G-13 be reperforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. Proposed Intervals (MD)- 7590-7600' (4 SPF) 7622-7660' ANTICIPATED START DATE- 9/25/85 RECEIVED Alaska Oil & Gas Cons. Comrnissior, Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,, ~11~~ Title Kuparuk 0perations Coordinator Date The space beloWfor Commission use 9/23/85 Conditions of Approval, if any: Approved by COMMISSIONER ~proved Colby p,®turned By Order of the Commission Date _ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bo,, 100360 ._ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 6, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells- 2G-13 2Z-8 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU9/L39 Enclosures &Ec£ VED NasV, a Oi~ & GaS Cons. Con~m'tsston Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany "'~' -- STATE OF ALASKA ALASKA t _ AND GAS CONSERVATION O,~-'AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-129 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-21160 4. Location of well at surface 9. Unit or Lease Name 303' FNL, 88' FEL, Sec.6, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 3905' FNL, 1242' FEL, Sec.6, T10N, RgE, UM 2G-13 At Total Depth 11. Field and Pool 4113' FNL, 1329' FEL, Sec.6, TION, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 140' RKB ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/25/84 09/29/84 11/06/84I N/A feet MS LI 1 , 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7936'MD,6408'TVD 7837'MD,6329'TVD YES [] NO [] 1900 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL/Cal, Gyro, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2849' 12-1/4" 875 sx Permafrost E & 20 sx Permafrost C 7" 26.0# J-55/L-80 Surf 7920' 8-1/2" 375 sx Class G & 250 s; Perm~fr0s~; (; . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7657' - 7654' 7628' - 7625' 3-1/2" 7512' 7482' 7647' 7603' - 7602' w/1 spf, 7641' 7594' - 7593' 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7636' - 7635' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7633' See attached Addendum dated 5/2/85. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I '-Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor~) Press. 24~HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water, Submit core chips. NONE CEIVED I"~ L-~ J U N 1 i 1985 Ala~ltS u,i & Gas Cons. Commission Anchorage Form 10-407 GRUg/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · '~ ~ '" ':' (~'EoLo'~3i'(J M/~,RKEI~IS 'I ;' F0i~MAT'i0~ TEs:I-S . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH ~TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk B 7508' 6072' N/A Top Lower Sand 7571' 6120' Base Lower Sand 7732' 6246' 31. LIST OF ATTACHMENTS Addendum · 32. I hereby' certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 10/5/84 2/06/85 2/07/85 2/11/85 2/12/85 2/13/85 4/12/85 2G-13 Arctic Pak w/45 bbls PF "C", followed by 59 bbls Arctic Pak. Pmp 2000 gals acid, followed by 70 bbls diesel. Final pmp press = 2500 psi. Flow well to tst tank. Flowed back 64 bbls diesel, well died. Wellhead press built to 600 psi in 5 hrs. Open well, flowed back 22 bbls, well died. SI to build tbg press. Flowed well after acid breakdn. SI well. Pmp'd 136 bbls gelled diesel in 3 stages. "A" sand frac grad average 0.72 psi/ft. Frac well in 7 stages w/total of 323 bbls gelled diesel & 1600# of 100 mesh & 13,456# of 20/40 mesh. RU WL, rn temp log f/7700'-7450'. Rn temp log f/7700'-7450'. Turn over to Production. Frac'd well in 8 stages w/377 bbls gelled diesel, 1058# 100 mesh & 13,944# 20/40 mesh. Drillin~ Superintendent RECEIVED JUN 1 i l~B5 Oil & Gas Cons. Commission Anchorage Date ARCO A!ask~, Ira,. Post Office box 360 Anchorage, Alaska 99510 TelePhone 907 277 5637 ' ., ,.r.- i',! · R ,::. 'T U R 'f' 0 'A r." p 0 ATTU A']" O' - " P'i, O. ,-"~ H C ~"1 .. . . t .. /"-~ ?.! ,',' ii 1 l"'f"E D H E R E Ii-"(,.7, I=': I I::"T A iq D I-';: ET U ... AI...A,?K A, I NC'.., : R E (:: 0 R D,7 C I._ _,r:..: F..' l"..' 'J t' '1 _:.:,ox ':i'o ,e :.,,,'::. e ........ Cf!;.:AGE., A,I< 99!i:; i ,3 --,. . .. W I l'H A RI:::. TI' IE I::' 0 L. I... 0 W I i'J C; R N 0 NIF. 5' I..C N Ii!; D C, (3 F:' Y 0 I""' .. T' F:;,'-'t.', N.:.-;' H :1; 'f' '[' A I... J'.! 0 ' i ." .'" ' "! _,' t 0 r 1',.? F'L (J.S' I... 0 (;- 2 (:..".-. 4/' · . ., , F'O,':{'r F:' E F:..' F" C;- A,? li;:i"~'l-F;:. Y ,-.- .... o-" ,: .... I', L.I I-.!-,,. 'i IR E" :z I:' I;.'-. I::: F:" C; ,' '5' A N D ...... O0 ")") .... r:~r.r' -'- --'. .....'::...; R 11 i"-! :ii: '') ... .,..'.. E--A b7. EN:f'r:_'Y ...... 0~ 'i 9 .... ",~'r'r~:.~.,,. ' ' · ,'.. "' '.:) ,2 ¢\ ~.., 1 ".. 'n' '~ I'"' 0 S"f' F:' I:~'. A C TIE i'i F:' C,.-~l'~(., 0 8 5 0'3 .... 8 6.5: Ci ....C I"1 I... U H B E R r; [.: ( N 0 5' I H C I... IZ I i".! TEI :: V L., ) (;;: A ;,'i C 0 .... 8 :;:f, 0 0 .... 8 6.5 0 C, A H C 0 7,.., 'z ~'-;... 0 ..... .... 785 o · ....- .....: . .., . D 1.1.' lii;,:-..7,S'E I.? A.T' !.. A <:> .j % (::, ._. o .8 r:, o t.J .... t..~,,.. · .... · O'f' I ,~-..? ' ' "' '7 4...-.":' 0. .... 7'7 ;';~, 0." ' ,; .-..I. ':T..r...> .... ,' '7..~':; 4 C A i".i C 0 74::;0 .... 7'70(.:) ARCO Alaska, In~ Post Office., ; 100360 Anchorage, Alaska 99510-0360 TelePhone 907 276 1215 March 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 2G-9 2G-10 2G~1:3 2G-14 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L51 Enclosures '.,'. ;:' 1985 ^laska Oil & t~a$ Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanlicRichlieldCompany ,. --~ STATE OF ALASKA J~-- '" ALASK _ AND GAS CONSERVATION C_ iVIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I-~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-129 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21160 4. Location of well at surface 9. Unit or Lease Name 303' FNL, 88' FEL, Sec.6, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 3905' FNL, 1242' FEL, Sec.6, T10N, RgE, UM 2G-13 .,_ At Total Depth 11. Field and Pool 4113' FNL, 1329' FEL, Sec.6, T10N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/25/84 09/29/84 11/06/84 N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-PVD)19. Directional Survey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 7936'MD,6408'TVD 7837'MD,6329'TVD YES [~ NO [] 1900 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL/Cal, Gyro, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 ~; Cold ~¢t II 9-5/8" 36.0# J-55 Surf 2849' 12-1/4" 875 sx Permafrost E & 120 ~x Permafrost C 7" 26.0# J-55/L-80 Surf 7920' 8-1/2" 375 sx Class G & 250 s~ Permafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7657' - 7654' 7628' - 7625' 3-1/2" 751:2' 7647' 7603' - 7602' w/1 spf, 7641 ' 7594' - 7593' 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7636' - 7635' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7633' See attached Add~dum. 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10~407 GRUS/WC18 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. '-- . ,..30~ · ' '~ - . . ;,~ - . . - .. -. : .... - ,, ~- -~ ~ .-, . ,., . . - . ...:.. -. · ,. ~. . :~ -. - ':~ '"' ' FORMATIONTESYS · ' .. NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk B 7508' 6072' N/A Top Lower Sand 7571' 6120' Base Lower Sand 7732' 6246' 1 31. LIST OF ATTACHMENTS Addend.m 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~/~/ ..~ ~.M~_.. Title Associate Engi neet Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 10/5/84 2/06/85 2/07/85 2/11/85 2/12/85 2/13/85 2G-13 Arctic Pak w/45 bbls PF "C", followed by 59 bbls Arctic Pak. Pmp 2000 gals acid, followed by 70 bbls diesel. Final pmp press = 2500 psi. Flow well to tst tank. Flowed back 64 bbls diesel, well died. Wellhead press built to 600 psi in 5 hrs. Open well, flowed back 22 bbls, well died. SI to build tbg press. Flowed well after acid breakdn. SI well. Pmp'd 136 bbls gelled diesel in 3 stages. "A" sand frac grad average 0.72 psi/ft. Frac well in 7 stages w/total of 323 bbls gelled diesel & 1600# of 100 mesh & 13,456# of 20/40 mesh. RU WL, rn temp log f/7700'-7450'. Rn temp log f/7700'-7450'. Turn over to Production. Drilling ~Superintendent ARCO-Alaska, Ir),'-'-'~. Post Offk ,x 360 Anchorage, .-,laska 99510 Telephone 907 277 5637 Transmittal No: 4842 EE~ TO: -. ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the follbwing items. Please acknowledge receipt and return one signed copy of this transmittal. PL Fl~ rk~ Dresser Collar Log 11/05/84 Run 1 7550- 7746 /~GL13 '4" Perf" - yZlE-8 " " "JB/G Ring/Set Packer" 10/30/84 Run 1 6844 -,7221 Otis /2V-6 SpirmerLog 8/21/C~..: P~n 1 5900 - 6400 Schl~m~o. er~er ~' 2X-5 Dus_l Spacing Thermal Neutron Dec~y ~ 11/02/84 Run 1 8210- 8658 20 Temperature ' ~refrac" / 2D-10 1L-1 Ten~p "Spinner Log" "HP/FD" " " " "Fluid Density" n/09/8 mm 1 8130- 8500 11/09/84 Run 1 7160- 7450 11/06/84 Run 1 3620 - 6620 11/08/84_ Run 1 6800- 7080 /cat Receip: Acknowledged: B. Currier BPAE Chevron D & M Drilling Geology Mobil NSK Ops. DISTRIBUTION W. Pasher State of AK G. Phillips Sohio Phillips Oil Union J. Rathmell Well Files ARCO Alaska, Inc, Post Office buX 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETtYRlq TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date:l/29/85 Transmittal No: 5009 PAGE 1 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger 2"/5" FDC-CNL/GR "Poro" 9/30/84 Run 1 7300 - 7889 2"/5" " "Raw" 9/30/84 " 7300- 7889 " 2"-~5" DIL-SFL/GR 9/30/84 " 2847 - 6914 " CPL Cyberlook 9/30/84 " 7300 - 7874 ,~,,!,,1L~ 2"/5" FDC-CNL/GR !'Poro" 10/17/84 Run 1 7100 - 7780 J " 2"/5" " "Raw" 10/17f84 " 7100 - 7780 " 2"/5" DIL-SFL/GR .. 10/17/84 _ " 4012 - 7820 " CPL Cyberl°ok 10/17/84 " 7100 - 7780 1L-8 2"/5" FDC-Ch~/GR "Poro" 9/04/84 Run 1 2392 - 7742 " 2"/5" " "Raw" 9/04/84' " 2392 - 7742 " 2"/5" DIL-SFL/GR 9/04/84 " 2392 - 7782 " CPL Cyberlook 9/04/84 " 7100 - 7742 _/cat Receipt Acknowledged: DISTRIBUTION B. Currier BPAE · . Drilling W. Pasher G. Phillips State of AK ~ Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. Post Office. 360 Anchor3ge ..... ska 99510 Telephone 907 277 5637 ' RETURIN TO: Date: 1/29/85 Transmittal No: 5009 PAGE '2 of 2 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ,fl Q.i/1L~3 2"/5" FDc-cNL/GR "Poro" 9/20/84 Run 1 3600 - 8452 .... " 2"/5" " "Raw" 9/20/84 '" 3600 - 8452 " 2"/5" DIL-SFL 9/20/84 " 2074 - 8452 " CPL Cyberlook 9/19/84 " 3600 - 8150 Q~2G;~2 2"/5" Density NeUtron/GR "Poro" 9/J3/84 " 2" '" " "Raw" 9/23/84 " " 5" "' " "Raw" 9/23/84 " 9/23184 9/23/84 " .2"/5" DIL, SFL/GR . · o " CPL Cyberlook Run 1 7290 - 8125 7290 - 8125 2884 - 8125 " 2884 - 8148 " 7450 - 7750 /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M .. Drilling .. Geology DISTRIBUTION W. Pasher -' G. Phillips · Alaska Oil & Gas Cons. comm~ssmr~ Anchorage State of AK Sohio Mobil Phillips Oil Union NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldComl3any ARCO Alaska, Inc. Post Office Bo.: 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 26, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-13 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2G-13 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L20 Enclosures Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -' -- STATE OF ALASKA · ALASKA _AND GAS CONSERVATION C. ,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [-~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-129 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21160 4. Location of well at surface 9. Unit or Lease Name 303' FNL, 88' FEL, Sec.6, T10N, RgE, UN ~A .... ~r.~..~I Kuparuk River Unit At Top Producing Interval IVE[~iFiF-D t 10. Well Number 3905' FNL, 1242' FEL, Sec.6, T10N, R9E, UN ~ur,. ~---'~~-J 2G-13 At Total Depth ~B. H. ~- _J 11. Field and Pool 4113' FNL, 1329' FEL, Sec.6, T10N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/25/84 09/29/84 11/06/8#I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+l-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7936'MD,6408'TV'D 7837'MD,6329'TVD YES IT1 NO [] 1900 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL/Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SE-ITING DEPTH MD CASING SlZEI WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2849' 12-1/4" 875 sx Permafrost E & 420 sx Permafrost; 7" 26.0# J-55/L-80 Surf 7920' 8-1/2" 375 sx C]ass G & 250 s~ Permafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7657' - 7654' 7628' - 7625' 3-1/2" 7512' 74~' 7647' 7603' - 7602' w/1 spf, 7641' 7594' - 7593' 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7636' - 7635' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7633 ' N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD 1~ Flow Tubing Casing Pressure CALCULATED.L OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Alaska 0il & Gas Anchorage Form 10-407 GRU3/WC13 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - . . ; · .: ..... - · '"' ' . ': "' ":, 'GEo~i:C:MAF~K~RSi '!::-'i~''!' ~i': -'""~;:-.':;' ':: ':7"-.-_~:'-!~`- ':; ;~'::~':"':' ":'" '~'~ "'F"0RMATION TESTS· -. · ' . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH . GOR, and time of each phase. Top Kuparuk B 7508' 6072' N/A Top Lower Sand 7571' 6120' Base Lower Sand 7732' 6246' 31. LIST OF ATTACHMENTS W~ll -Hi_~t-nry~ Cyro?opic Survey (? copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'/~J',~--i ~_~JLL~-"~?L__- Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' ClasSification. of Service Wells:. Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". AtlanticRichfieldCompany '~' Daily Well History-Initial Report Instructions: Prepare and submit the "Initial Rel~elt" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, DistrictAlaRka County or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no. T tie AFE 901083 North Slope Borough IState Alaska ADL 25667 Drill JWell no. 2G-13 Doyon 9 API 50-029-21160 Operator ARCO Alaska, Inc. Spudded or w.O.spuddedbegun Date Date and depth as of 8:00 a.m. 9/25/84 Complete record for each day reported 9/26/84 9/27/84 9/28/84 The above is correct 9/25/84 Signature ~ . For form prep~r~ion and distribut~rn~- ~ see Procedures Manual, Ssction 1~ Drilling, Pages 86 and 87. IHour 0001 IA.R.Co's W.I. Prior status if a W.O. 16" @ 110' 1464', (1354'), Drlg Wt. 9.0, PV 27, YP 43, PH 8, WL 12.6, Sol 6 Accept rig @ 1830 hrs, 9/24/84. NU 20" Hydrl & diverter. well @ 0001 hfs, 9/25/84. Drl 12¼" hole to 1464'. Spud 16" @ 110' 2870', (1406'), Rn'g 9-5/8" csg Wt. 9.7, PV 24, YP 17, PH 8, WL 12, Sol 10 DD & surv 12¼" hole to 2870', wiper trip, POH. RU & RIH w/71 jts, 9-5/8", 36#, J-55 csg. 1415', Assumed vertical 1696', 9.4°, Sll. IW, 1695.06 TVD, 22.87 VS, 22.59S, 4.43W 2280', 25.5°, S15.2W, 2247.70 TVD, 206.22 VS, 203.10S, 41.88W 2829', 46.3°, S15.8W, 2693.29 TVD, 522.91VS, 507.78S, 128.85W 9-5/8" @ 2849' 2993', (123'), Make up BHA & RIH Wt. 8.8, PV 4, YP 4, PH 9, WL 10.8, Sol 2 Rn 71 its, 36#, BTC L-80 csg w/FS @ 2849', FC @ 2766'. Cmt w/875 sx lead, followed by 420 sx tail. Bumped plug. CIP @ 1100 hrs, 9/26/84. ND 20" diverter, NU & tst BOPE; OK. TIH w/8½" BHA, DO cmt, FC, FS + new formation to 2879'. Conduct formation tst to 12.5 EMW. Drl 8½" hole to 2993'. Survey. POH. Make up BHA & RIH. 2829', 46.3°, S15.8W, 2693 TVD, 522 VS, 507S, 128W 9-5/8" @ 2849' 5933', (2940'), Drlg Wt. 9.3, PV 10, YP 9, PH 9.5, WL 7.2, Sol 6 Drl & surv 8½" hole to 5933'. 3240', 44.6°, S15.7W, 2981TVD, 815 VS, 789S, 208W 3974', 45.1°, S15.7W, 3501TVD, 1332 VS, 1287S, 348W 4847', 44°, S16.2W, 4123 TVD, 1944 VS, 1876S, 516W 5788', 42.1°, S17.6W, 4811TVD, 2587 VS, 2491S, 703W RECEIVED Alaska Oil & Gas Cons. Commission. Anr:.h. or~go IDate I Title lO/12/84 56.24% Drilling Superintendent AR3B-459-1-B Number all daily well history forms consecutively as they are prepared for each well. i Pag~ nc. ARCO Oil and Gas COmpany Daily Well History-Final Report Instructions: Prepare and submit the ,,FleXi R~eort" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold, "Final Report" should be submitted also who, operations are suspended for an indefinite or appreciable length of time. On workovers when an olficial test is not required upon completion, report completion alld representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I,n. ccounting cost center code state Alaska I WoII no. 2G-13 District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25667 Auth. or W,O. no. T t e AFE 901083 Drill Doyon #9 API 50-029-21160 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 9/25/84 I otal number of wells (active or inactive) on thisI Dst center prior to plugging and bandonmentour 000Df thisl well Prior stalus if a W,O. Date and depth as of 8:00 a.m. 9/29/84 thru 10101184 10/02/84 Complete record for each day reported 9-5/8" @ 2849' 7392', (1459'), Circ Wt. 10, PV 17, YP 9, PH 8.5, WL 8.0, Sol 10 Drl & surv 8~" hole to 7208', losing mud, SI well & observe. Open well, circ& observe; OK. (Lost 40 bbls total.) Drl & surv to 7936', C&C f/logs, POOH. RU Schl, att to log, tls stopped @ 4517', RD Schl. RIH, make wiper trip, C&C f/logs. RU Schl, rn DIL/SFL/GR/SP f/7914'-2847', FDC/CNL/CAL f/7889'-7300', RD Schl. RIH to 7634', wsh & rm to 7936', C&C f/csg, POH. 6581', 43.7°, S18W, 5392 TVD, 3126 VS, 3005S, 868W 7043', 42.3°, S17.6W, 5730 TVD, 3441VS, 3305S, 964W 7800', 38°, S24W, 6308 TVD, 3928 VS, 3760S, 1137W 7" @ 7920' 7837', (0'), RR 11.2 brine Rn 201 jts, 7", 26#, L-80 J-55 tbg to 7920' w/FC @ 7837'. M&P 375 sx C1 "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ w/brine, bump plug. CIP @ 1500 hrs, 10/01/84. ND BOPE, instl pack-off, NU tbg head & tst to 3000 psi. RR @ 2100 hrs, 10/1/84. Old TD J New TD Released rig I Date 2100 hrs Classilications (oil, gas, etc.) Oil PB Depth 10/01/84 Ki.d of ,ig Rotary Type completion (single, dual, etc.) S lng le Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential lest data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Eftectlve Oate corrected The above is correct Signature z,,).,a'/~..~.~ For fo-tm p-~eplra,~o~ ~nd ~trib-ut~'o~.-- see Procedures Manual, S~Yction 10, Drilling, Pages 1~6 and te E C ~l~f8E ~e Dr-I llinB Superintendent [OEO 2 Alaska 0il & Gas Cons. Commission Number all daily well history forms Anchorage as they are prepared , ..... h well. c ...... tively .... iPage no. 2 SUB-SURFA CE DIRECTIONAL SURVEY ~-~ UIDANCE ~-~ ONTINUOUS [-~ OOl Company ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2G-13 (303' FNL, 88' FEL~ S6~ TION, R9E~ UM) KUPARUK~ NORTH SLOPE, ALASKA Job Reference No. 69657 Logged By: PEPPEL Date NOV-28-84 Computed By: STEVENS ! r', C q' ~ 1 Ir, ~i (7 'J' I ~' !',; 3 I, $ L~ f? V K ¥ 1- f", h ? (;-- ,[ 3 j. 7 r)~'c. 4 1 I:"OR gV[,jt, ] (~(:, FFI<'I' 12 1 o 45 23 44 4P 4 4 47 ~ 4 4 ~ 45 11 ab 26 ab 45 11 t"F t:' ?' r', E (; / 1 t; 6 P A (; t{: 1 DEPARi'[IIRE A Z 1 MUTH liE(; O.(,i() ~,' t,),VO f< 0,,00 (~.02 F 0.14 E o.15 ~).(,6 ~,: 2.'77 F, 2.'17 ,,).3h i',,, 4.1,~ F: 4,20 t~.36', r,, 5.50 F: 5,t)1, (.~.SH ',' b.9o F' 7.01 t).t>7 r 9,97 FJ 9.99 ,,.hR ~', 12.06 F; 12,0R <;.b5 " 14.50 [" 1L4,b1 U.b7 !,,' l.b. H8 E lb.90 U.'.>I t,,; lt~.~7 F. lb. BR l,t)'; S 22.51 E 22.53 2.9q $ 23,94 E 24.12 8.b.~ S 24.9~ F 26.37 ~(;.bH S 23,~6 F: 31,58 39.27 S 20.b4 E: 44,36 6,4.14 S 17.b7 E f. 6,53 N 86 40 E ,~ 87 2 g N 88 2'1 g $ 8g 41 g S 82 53 g S 71 '1 g ,540 5 g S 27 42 g ~ 15 24 g [+4.b5 S 12,33 f< q5.35 lYb. O0 ,':; 3.cjR F 128.06 16,1,37 .% o.34 W 1.64.~9 2C4.'t5 S 1't.97 ~ 205.b4 249.b5 S 3l.l~ w 2fil.7q ~;.99.td.~ $ 45,98 y' '103.33 354.1% $ f;2.54 W 360,22 414.~ 5 81,12 w 422.13 479.%:6 ~, 101,77 w 490.03 bz~9. ~ 4 F 1~4.3] W 563.04 S 7 25 E $ 1 46 E S 2 12 w $ 8 43 W S 9 59 w S 11 58 W S 12 45 w ~.l~;,t;? $ 147.36 W 635..:t5 b~5.15 $ 169.44 w 70b,'19 '?~.2.2~ ,%.' 191.14 w 77o.14 ~19.>.'6 .',, 212.59 W 84b.3g brio. ..S°... ,,~ 134,01 "~.. 916.76 91,3.5~ S 255,33 ~: 987,18 1~>~b.78 $ 2c;k.l~ 'r 1. l~.B6 llf.b.o3 F 319.57 W 1199.95 127a.,11 $ 34(¢.B3 ~' ~270.96 S 13 24 W 5 13 53 w S 14 15 w S 14 32 w S 14 47 W 6 14 59 W 515 9 ~ S 15 18 w S 15 26 ~, S 15 33 w :Z.(;- 1 3 ',r Pi, r, v F R q' t "'/;. I, C f ~ L, 1:,';-, F' VFjPTI C/~[, f' !(';I.F(, i' r:: V I A q' [ !" r,, A 7 I u t~ 'T t; ,b I< C ,r j o r,,~ [; t'j ¥ [:, P, .1, T .f t,f;'~; ,,¢i I ¢*J l;l<t, b T ;\, ~"~';b q' T')F,(;/ 1 5i n7. 5253,9r'; 532b. 31¢.) 53q8.'/5 5~71 g543.5~, 5bqO. 1C 5'16,t. I P =,913.94 591:t9.82 6060.05 f~Zgt'. 8~ ~, 3'I'~. 3[` [>AGE 2 2 22 ? .I. , ,r 5"4 lb, Yb'tl. ;:,I~L,,~R (.f'~t,iPt;l~'qATE$ t.ir'IRIZ. DEPAR'rtlRE ,:> ~ '~ t t 'I' I-,' ,L A ;:, T / W I";S'iL' I).i. $'l'. AZIMUTH 1' t.'F,F;T F'k:ET BEG M IN 9() 5 3~'2.1b w 1.341.t~9 S 15 39 ~ 5q Y-; 3S3.,t0 w !412.b2 S 15 44 W ~,~ ?, 4o4,51 ~, 1483,11 5 15 49 W ':~9 5 4.7b.60 W 1553.36 S 15 54 w '1~I Y, qat.,.'i9 w 1623.47 S 15 58 W io S 4~"9.42 W 1763.48 S ~6 ~ ~ G7 5 51().So w 1833.27 S 16 lO W v7 S 5~2.28 W 1902,93 S 16 14 W lb S b53,91 W 1972,b~ S 16 t8 w 17 $ 575.53 t,: 2041,95 S 16 22 w t~7 5 5<~'1.20 ~' 21 I 1,20 S 16 25 I~ b2 5 £1, H.97 w 2tP0.33 S 16 29 w 91 S f,4U.90 ~' 2249,16 S 16 33 W (,)n >: t, 63.00 W 231'1,90 S 16 37 W u4 F t,¢5.2o ~' 23~b.55 S 16 41 W 6! $ 7n7,'10 ~ ~45b.05 fi 16 4b W :1~, b 33(),t5 w 2523,11 S 16 49 w b9 5 7~2. I1 W ~590,46 S 16 53 W 50 S ',?b,33 w 2657,13 S 16 57 W '79i~.15 i,, 2774.18 S 17 2 W ~-;2t.loSIK w 2/9'1.74 S 17 5 h ~4:3.(',2 ~' 2859.34 b 17 9 W x6b. U7 t,~ 2927.37 5 17 13 W ~.~('~.89 ~: 29()5.80 S 17 16 W 913.17 W 3064.b2 S 17 20 W 93~.46 W ~133.bo 5 17 2] W 95~,51 w 3202,01 b 17 26 W 9R2.]7 w 3271.46 S 17 28 ~ !t)O4,Tq ~' 333q.b6 S 17 30 w .,~ :.', lt)7'/.10 w 3~0/.51 S 17 32 W ,>n ,'4 !049,07 v, 3,i74.06 5 17 34 W · ,~ :. 107u,80 w ]541.33 S 17 3b w ~,'1 :, 1t)q2.2] ~.' ~ho'/.17 S 17 37 W i:) ,': 1,113,40 w 3672,27 S 17 38 ~ ~)/! & 11.36.U6 W 373t>.92 S 17 41 W t~'l A I ~ab,3a ~ ]86J,u1 S 17 52 W t'7 :: !,~o~. /1 t.. 3923,97 S 17 56 w 't' r., t.1 ¥ VFiiT P^(;E 3 140o00 DEPARTIIRE: ~,ZT MUTH DEG UIN P A c; E 4 F,:'t.,t,~t,¥ r I!~)ftTN('; F:L~F:v.,r:~'/TLJN.* 140.gO ~,:: ~ i,, I ~ P' h, l"' "' l.',~ F: P P i"] 1, ,I, P i $ 't. DEPAR'.ITURE A Z T MII'].'H :, IIt;'rli rt L P T, I1 I!MI' '"' ~! r'~ [< 1' '.l, I.~ q40. lO 940.(;c' 104o.14 1240.!8 I 1,~0. PC, 134.{).un 144C~.22 l~4n.?~ 154U.t~(' 1741.~t.) 1 '/4U I f~44.')X .31 ~:,I. ?t? ?.940. UO 312',.nt 34t,!:,. 02 314.0.00 ~. 6 ~ "7. -'~ z ~240.Uo ~n,ql ,'lb 3440.0P .103 ?. t-,l 3540.Vr 'l 1 'I 4, g 9 'I.. ~, .'~ t,. L, r 2 h -" r:' IV- ~ 4. 1' }t:l":(' ~l[;' 8ti}-:-,"';i,.,?, f)~:l' t 5.41 F '2..2] ',, 1,1.45 w 2L4.91 '~ 46.05 V 02.20 ',~ 124.05 ~, 156..96 W .I f,,17.73 21'1.95 248.06 27,3.36 308.76 339.0F1 :i¢',,9.30 ,~ ? r.;. ~7 z', q .-.; . t: 4 D 1 $ T, F' L I': T 0. U 0 0.00 3,3~ 4 . '/4 b.21 '1.52 8.96 10,15 DEPARTURE AZTMLITH D F:(; ~ .l N N 0 0 g N 90 0 E 8 t::14 44 g N 86 32 g N 87 14 Ir.; N 85 11 g I,; 86 23 E: N 84 42 g t,,,85 ,1.9 g i'~ 86 36 F. 13.0,~ h 86 47 g 15.61 N 86 3'7 E 17,71 N 87 30 E 1.9.70 i,i 89 '1 g ?1.55 8 8B 51 E 23,14 .5 85 59 E 2q,.US 8 79 33 E 27,99 8 62 54 E; ]5.66 S ~9 4 E 5t.1~ 8 21 24 E 79,06 112.85 150,02 lqJ.t4 3n3.57 374.26 459,4~ 5(;2.16 br, 5 · 82 511 9 g 8 4 6 E S 0 51 W 8,' 4 17 w $ 6 48 i~ 8 R 43 W S 10 15 W 8 11 34 w $ 12 44 W 8 13 38 W 3 F: C'r' 1 r ~ t, l,'1¢ L T t"h Ki' P A (; E 6 n/tT},, ()r,' SL.~PV[.tY: 23-(ICT-~t4 KCf,I,'f t',[,Y,~,]i',,q FI,.,F;VATILiNI 140.0o F':.I' c.r'(..; 1 [4F:F fO: F, F: V I., P I.T¥ U. 77 0.t7 (). '~,. ~ (.). (; 5 U. 34. t.), '3 F I. '! 1 , t~ [-IOR l Z. P, I S r. I:' B E 1' P E P A R T I,I ¢ F: A Z 1 I~lj TH DEC ~ I N 176u.54 1 8 5 '1.9 5 ! 954,99 214"1. bl 2242, b7 233'1.35 2431 .b7 252,1. U5 261 5.81 516 OW 5 16 12 W L-; 16 17 ~, ,':3 16 22 ~ $ 16 2'1 Z, & 16 32 ~ $ 16 43 v, 5 16 49 w 5 16 55 W 276(). 13 293?. b'¢ 302 I, h 2 311't.3t 32 0 b. 3 7 32 q .t. ~t g 3 37b . (.,5 7ql,Tq ~ ~,; 5 3,70 W b~4b 45 t~l'l.b5 W 9'19,08 W 9~ 1,27 ~,' U11 .91 ~ t) 7 I . 1 f'~ 2705.41 5 17 1 w 2'lg7.OR S 17 b W 2889,14 8 17 11 ~ 29~2,hg 5 17 16 ~ 307'1,56 5 17 20 w 3~7~ 07 S ~7 24 ~ 3268:12 5 17 28 W 3361.30 $ 11 31 ~ 3452,84 b 17 33 W ~542,48 S 17 36 w APC{'~ AI, A,'5. FA, Tr, iC. ~'~ (~ R q't ,%.' T, (3 P L ~ ,h i, ^ ;5 l',: A 1.1'!I t,'~:P~;l AWt:.I~ VAT ~;l'i-, t/Ok CH(};iI:;~i I,p.;P.IZIiI,:;) T \/t) F'r $ l.J R t"ACE I,I, jC AT 1ON t~T U R'I' I-t / $ Ol1';f H EAST/WEST 38 O0 ~ 53 B1 w 92 84 w 17 36 w 40 51 w 1',I Z:5t,'& T r'~ ], A L, t3 [" P T H F i I~' A 1'. ~'1 F: A $ b P E I) r) [.:p 7 b 36. (,) IL, I.~r'?C~T][I~, ]'F U [; VF'HT '.2,., 7571.01'~ 7 t 32. ,:JO I'~ i'J P '.1' F 6077.1 i,~ b24f' . ~,,I (') 7 & d t~'~" RCI~: [..,uC A T ,1. ON Al" %9.32.,I, 6 3,r,'~4,.n2 ~ .1.138 O0 'Sg~(,). 41 3fi02. :1. 2 ,% 11,53-'81, 6", .J. (.'t'.,. L,J7 369a, fl8 .," 1192: 84 ~]f~9. :1~; 3753.q5 6 1217.36 (',2f,"1,'~2 3ROa. Sb ,5 1240o51 SCHLUhlBEROER ARCO ALASKA, INC. KUPARUK NORTH SLOPE, ALASKA OCTOBER 29, 1984 TVN PLOT FROH OCT DaTA JOB REFERENCE 69657 WELL' 2G-13 SURFACE LOCATION' 303' FNL, 88' FEL, S6, TION, R9E, UM HORIZONTAL PROJECTION NORTH ] 000 - ] 000 -2000 -BO00 -4000 -SO00 -6000 SOUTH -7000 -7000 wEST REP 696~7 SCALE = ]/1000 IN/FT , , , . . -6000 -SO00 -4000 -3000 -2000 - 1000 0 l O0%AST WELL' 2G-13 SURFACE LOCATION: 303' FNL, 88' FEL, S6, TION, R9E, UM VERTICAL PROJECTION PROJECTION ON VERTICAL PLANE OF AZIMUTH 198 SCALED IN vERTICAL OEPTHS HORIZ SCALE = l/lO00 IN/FT $ UB-$ URFA CE DIRECTIONAL F'~ UIDANCE SURVEY F~ONTINUOUS ~-f~ OOL 'Company- Well Name ATLANTIC RICHFIELD COMPANY Nas~ Oil & GaS Cons. Coramiss'to~ 2G-13 (303' FNL, 88', FEL~ S6~ TION, RgE, UM) Field/Location KUPARUK~ NORTH SLOPE~ ALASKA Job Reference No. 69657 Logged By: PEPPEL Date NOV-28-84 Computed By: STEVENS OCT DX'RECTZONAL sURVEY CUSTOMER I,,ISTING FOR ARCO ALASKA, INC. 2G-13 KUPARUK NORTH SLOP~, At, ASKA SURVEY DATE= 23-0CT-84 EN~ZNEERt PEPPEG METHODS OF COMPUTATION TOOb bOCATION= TANGENTZAb- averaged deviation and azimuth ~NTERpOLATZON= LZNEAR VERTICAL SECTION= HORXZ, D~ST, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 17 DEG 41MIN WEST "J~;~'~)} ;~:~.'.. KELLY B~SHING ELEVATION SLOPE, ALASKA . ;' ' ~'';'' ENGINEER: 'PEPPEL IRUE SUB SEA .COURSE VEl TICAb DOG[.EG RFCTANGULAR COORDINATES HORIZ, ~gSI. IRED VERTICAL VERTICA5 DEVIATION AZ~MU'TH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,' DEPTH D~PTH DEPTH DEG ~ FEET DEG/1 O0 FEET FEET FEET :,,o,oo ooo -14o ,tioo,,'oo ' 0 299.9g ':'." 1 O' 4^0.00 3q9 97 259,97 0 45. N 8~ 35 E '1 61 ' t,00 499~96 359.96 0 52 S 8, 31E -2 05 uO.O0 599.95 459,95 0 43 N 75 8 E -2 68 00.00 699.94 559,94 0 49 N 89 48 E -3:24 800,00 799.93 659,93 1 4 S 86 51E -3.67 900.00 899,90 759,90 I 23 N 86 38 E -4.30 1 27 111 LO00.O0 999.87 859,87 LIO0,O0 1099,85 959,85 [ ~00,00 1199.83 1059.83 L400.O0 1399179 1259-9 L oo.oo t oo oo 270o:00 t oo.oo oo oo [900.00 1893 1 11 I 8 5 8 52 80 1753 80 16 14 0 O0 0 96 0 3O 0 53 0,29 0,19 0,14 0'18 0.12 0.33 ,000.00 1988 89 1848,89 19 29 ,100,00 2082 76 1942,76 21 ,200.00 2175 32 2035 32 :23 26 Z300.Oo 2260 05 212i 05 26 2~ 24~o,00 2354 31 221 31 :29 3 ' 64 33 2 ! ~, 00 2 ~i'{ ~i~i.~. 229 10 ~TvO.O0 252,,1'.~5,~ ~700.oo 259 ', .. <'~::j~238 ~} 36 2900. O0 27'4~j:;.:'12600 47 3 3000.00 28091g~f.?'2669 54 45 23 2740 44 1300.00 ]O{~]~c' ~' ;:~'2882 26 .44 3400,00 301~z~; 2953 20 44 45 3094,77 45 3700.00 3305.16 3165,16 45 20 3800,o0 3375.45 3235.45 45 19 3900,00 3445.81 3305.81 45 11 85 37 E '5,24 84 30 E '5..96 76 13 E '6.22 67 8 E '6.22 4935 E =5.84 :23 57 E -4.42 2 28 E 0,55 10 49 w 12,45 7 34 W 31,15 8 0 W 55.74 0,07 0,08 0,20 0.17 1,59 4 b5 4~b9 3,98 3.65 $ 11 44 W 86,34 S 15 22 W 120.75 $ 16 0 W 158,53 8 16 9 w 200,54 $ 16 29 W 247,52 $ i6 34 W 299.63 8 16 55 W 356,99 $ 17 23 W 419,91 8 17 50 W 488.20 $ 18 20 W 560.96 2 62 2]73 2,44 3.00 3,24 4.16 3,80 3,42 3.18 0.6! $ 18 25 W 633,58 8 18 3 W 704.25 41 w 845.12 8 17 39 W 915,59 S 17 36 W 986.08 S i7 36 W 1056,87 8 1 8 W 0 ,03 S ]7 29 W 1270,09 1.90 0.29 0.49 0.17 0.16 0 23 0~33 0.23 0,29 0.17 PAGE 1 140,00 FT DEPARTURE AZIMUTH PEG MIN' 0,0,0 N 0,00 E 0,02 S 0,14 E 0,08 N 1,34 E, O;06N 2,77 E 0,36 N 4,18 E 0,36 N 5.59 E 0,58 N 6 99 E 0.75 ~ 8~32 E 0,67 ~ 9,97 E 0.66 N 12,06 E 0.85 U 14.59 0,87 ~ 1b.88 0.51N 18,87 0,11 S 20.81 1,04 $ 22.51 2,99 S 23.94 8,53 S 24,96 20,68 S 23,86 39,27 S 20,63 64,14 S 17.67 0,00 N 0 0 E 0.15 S 81 47 E 1,34 N 86 40 E 2,77 N 88 40 E 4,20 N 85 7 E 5,61 a 86 16 E 7,01 N 85 15 E 8,36 N 84 50 E 9,99 N 86 9 E 12,OR N 86 51E 14,61 N 86 40 E 16,90 a 87 2 E 18,88 N 88 27 E 20,81 S 89 41 E 22,53 $ 87 21 E 24,12 S 82 53 E 26'37 S 71 7 E 31 58 $ 49 5 E 44136 S 27 42 E 66,53 $ 15 24 g 95.35 S 7 25 E 94,55 S 12,33 128,00 S 3,98 164,37 S 6,34 204,75 24'9,85 S 31,19 299,83 S ~ 45,.98~W 354.75 414,88 S >~=81,12 479,96 S i01,77 549,14 S ,. E 128,06 S 1 46 E 164.49 S 2 12 w 205,54 S 5 0 w 51.79 $ 7 6 W ~03.33 S 8 43 W 360,22 $ 9 59 W ) 422.73 S 11 3 W 490 63 S I1 58 W 563~04 S 12 45 ~ 618,02 S 147,'36 W 635,35 S 13 24 W 685,15 S ~69,.44 W 705,79 $ 13 53 W 752.23 S I91:."I'4 W 776.14 $ 14 15 W 8~9,26 S ~2., 846, 95 3,58 S 255,33 W 987,18 S 14 59 W 1021.04 S 276.96 W 1057,89 S 15 9 W ~088'78 S 298.16 W 1128.86 S 15 18 W ~156,63 S 3~9.52 W 1199.95 $ 15 26 W 12~4,41S 340,83 W 1270.96 S 15 33 W ~,RCO ALASKA, 1;NC. tG-13 ~IORTH SLOPE, AL, ASKA TRUE SUB-SEA CASURED VERTICAL VERTICAL DEVZA DEPTH DEPTH DEPTH DEG iO0:~,O0 3516,27 ie"o,00 3800'24 3660 24 44 29 t& ~.00 3871,58 3731 58 44 27 16u0 00 3943,00 3803 00 44 {700:00 44 13 4014.6o 3874,60 t800.o0 4086,31 3946,3! 44 9 {900.0o 4158.09 4018,09 44 5000,00 423o.02 4090,02 43 54 51o0,00 4302,14 4162,14 43 49 520o 00 4374'36 4234,36 43 35 5300:00 4446,85 4306,85 43 28 i400 00 4519,43 4379,43 43 26 , 500.00 4592.10 4452,10 43 21 4524,90 43 10 5600.00 4664 90 5700.00 4738:10 4599,10 42 37 5800.00 4811.96 4671,96 42 13 Lq00.00 4886,41 4746,41 41 44 500o,00 5100.00 5200.00 5300.00 Ss'q.00 5' ,~ 00 5700.00 58oo.no 5900.00 7OOO 0o ooioo 7200.00 730o 00 ?400100 7500 O0 7600:00 7700.00 7800.00 7900,00 4960.51 4820 51 5034,18 4894 18 5107,82 4967 82 5181,04 5041 04 5253~90 5113 90 532.&;~.9:~ 5186 39 5 ? 5~6 j~?< 54?'6,65 , ,~.~:'t~. ~,, ~; 59,i3 '9~/~'5773,94 6220 86 60~0o86 6299 98 6159o98 6379 35 6239°35 COMPUTAT INT£RPObATED VAbUES , 42 30 42 33 42 4~ 43 43 22 43 37 43 43 43 32 43 ~2 42 5g 42 30 42 3 41 20 40 5~ 40 33 40 q 39 1~ 38 q 37 28 37 2n 8 17 38'W 75 17 42 W 1 82 17 47 W 1 82 $ 17 52 W 1 64 S 18 2 W 1902 33 S 18 8 W 1971:95 6-NOV-84 PAGE 2 DATE OF SURVEY~ 23-00T-84 KELLY BUSHING ELEVATION: 140,00'FT- ENGINEER: PEPPEL 100 FEET OF MEASURED DEPTH CAI., DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE ,ECTION SEVERITY NORTH/SOUTH EAST/WEST DIS'f, AZIMUTH FEET. DES/lO0 FEET FEET FEET DES MIN 0.44 ' 1 S 18 9 W 2041,42 S 18 16 W 2110,69 S 18 25 W 2179.86 S 18 39 W 2248,73 S 18 52 W 2317,51 S 18 59 W 2386,192 S 19 8 W 2454,7 $ 19 23 W 2522.82 S 19 42 W 2590,21 S 19 54 W 2656,02 S 19 42 w 2724.01 S 19 37 W 2791,60 $ 19 42 w 2859.23 $ 19 51 w 2927.28 S 19 43 w 2995 73 S 19 46 W 3064:57 S 19 37 W 3133.55 S i9 25 W 3202.58 S 19 1! W 3271,44 $ 19 1~ W 3339,65 $ 19 8 w 3407.50 $ 19 1 w 3474,65 8 19 0 W 3541.32 8 18 56 W 3607,1b 8 19 17 W 3672,27 8 22 3 W 3736.92 $ 23 2 ~ 3800,69 8 22 35 W 3862,99 8 22 36 W 3923,93 8 22 36 W 3984.~5 0,16 0,~2 0,28 0,18 0,14 0,16 0.52 0,46 0,12 0,28 0,32 0,20 0.44. 0,40 0.64 0.32 0,23 0,55 0.43 0,78 0.53 0.39 0,79 1.27 0.91 0,89 0,31 1,03 0,81 0.93 2.20 1,04 i.06 0,00 0.()0 3292,09 S 362 15 W 1341,89 $ 15 39 1.3~.9,:59 S 383 40 W 1412 62 S ii 44 W 1493t' :2 8' ~z~ 60 W 1553 54 W 1560,78 S 446 79 W 1623 47 S 15 58 36~7'55 S 468.07 w 1693 52 ~694,20 S 489,42 W 1763 48 1760~67 S 5~.0,80 W 1833 27 S 16 10 1826.97 S 532,28 W 190'2 93 1~93,15 S 553'91 W 1972 52 $ 16 18 W ~959,17 $ 575,53 W 2041,95 S ~6 22 W ~024,97 S .597,20 W 2111,20 S 16 25 ~090 62 $ t18.97 w 2180 3] S 16 29 ?155:91 S 640.90 W 2249:16 S 16 33 ~221,06 S 663,00 w 2317,90 $ 16 37 W 22~6.04 S ~85.29 W 2386,55 S 16 41 W 2415,15 S 730~1 w 2523 ll 747~,69 S 752 71 w 2590 46 S 16 53 7541,50 S 775,33 W 2657,13 S 16 57 W 2604,64 S 79~ 15 w 2724,18 2668,34 S 820:86 w 2791,74 2732 06 S 843,62 w ~859.34 $ 17 9 W ??96 14 $ 866.b7 W 2927,37 $ 17 13 W 2860 58 S 889,89 w 2995,~0 2925 41S 913,17 W 3064,b2 S 17 20 ?990 39 $ 936,46 W 3133,59 3055 49 $ 959,.51 W 3202,61 3120.48 S 982,3'7 w 3271,46 S 17 28 31~4.92 S 1'004,79 W 3339,66 S 17 30 .', .. 3312,50 S 10 9i~ W 3474,66 3375,56 S 1070 W 3541 33 S 17 36 W 3437,83 S 1092,.23 W ]607~17 34q9,42 $ 1113,40 W 3672,27 S 17 38 3560,04 S 1136,06 W 3736,92 S 17 41 3619.02 S 11'61,03 W 3800,70 S 17 47 3676,67 S 1~85,30 W 3863,01 S 17 52 3733.17 S 1208,71 W 3923,97 S 17 56 37~9.34 S 1.232.10 w 3984,61 S 18 0 IRCO ~L~SKA, .INC. ~,UP~RUK IORTH SLOPE, AI,ASKA COMPUTATIONal' ?!~26-MOV-~4 PAGE 3 DATE OF SURVEY% 23-OCT-84 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 140,00 FT iNTERPOLATED VALUES 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ~, ' '~i~CAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE '{~SURED VERTICAl, VERTICAL DEViATiON AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN PEG. .. FEET DEG/IO0 FEET FEET FEET DEG '936,00 6407,9~ . 62~7,9~.... ~'7...28 ...~06,]7. 0,00 3809,56 S ~240,51 w 4006,44 >~3:.. ~....'. '~. :.~' . ~RCO ALASKA ~g,.- 13 ~UPA[tltK .,'.,., ,:,.., .. '~ ', ...L. 'V.'.~'w'' ' ~a~Tr~"' ' ..:'~4C~ ,~ ,. INTERPOLATED VALUES F:~:'g',~:~i, EN;: 1000 TRUF, SUB-SEA COURSE ;ASUR~D V~RTICAI, VgRI'ICAb D£VIATION AZIMUTH hEPTH DF..PTH DEPTH DEG M~N . DES MIN PA ,,g 4 DATE OF SURVEY: 23-0CT-~4 KELPY BUSHING ELEVATION: ENGINEER: PEPPEI, FEET OF MEASURED DEPT 140,O0~FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DES/100 FEET FEET FEET DES ~IN 0.00 0.00 -140,00 0 0 N 0,, ;:, 0 00 .000,00 999,87 859,,~!'..: ',1:2~, ) .00 2809: 266~,5" 3 ~0"~.00 3516.27 3376,27 45 8 $ 17 28 W 134~. 05 i(~ .o0 4230.0~ 4090.02 43 54 $ ~8 9 W 2041,42 ~OuO oO 4960.51 482o,5! 42 30 S 19 42 w 2724,01 )000~oo 56o0.10 555o,10 42 30 S 19 8 W 3407,50 )936.00 6407,92 6267,92 37 2~ S 22 36 W 4006,37 0,00 0,07 2.62 1.90 0.44 0,16 0.32 0.00 0,00 ~I 0 O0 E 0,00 N 0 0 E 0 85 N 14 59 E !4,61 N 86 40 g 94~55 S 'I2 33 E 95,35 S 7 25 E 618,02 S 147 36 W 635.35 S 1] 24 W 1292°09 $ 362 15 w 1341,89 $ 15 39 w 1.959.17 S 575,53 w 2041,95 $ 16 22 W 2604 64 S 79B 15 W ~724,18 S ~7 2 W 3249:03 S 1~i27:10 W 3407,51 S 17 32 W 38(19.56 g: ~240.51 w 4006,44 S 18 2 W RCO {%b~$KA, TNC. C;-13 IJPARUK ORTil SI,OPE, ALASKA CO~tPUTAT I ON'"'i!l~ INT£RPOhATED VALUES F?~ TRUE SUB-SEA COURSE ASURED VERTICAL VERTICAl, DEVIAT.~ON AZIMUTH DEPTH DEPTH DEPTH DEG M~N" DEG M~N '. FEET ~i~"~¥'~ii"'';'';?~!,: D A T E O F $ U R V E Y: 2 3 - O C T- 8 4 ~..i~)~'i~:?,~,.:' KELLY BL!$HING ELEVATION= 140,00 ~T ~, ~, ,,,~ :":<" ~71.00 F ET OF SUB'SEA DEPTH ERTICAL DOGbEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZTMUTH DEG/IO0 FEET FEET FEET DEG MIN 0,00 0,00 '140,00 0 0 iN . 0,00 40, OO 40, OO - 1 O0,00 0..:>..,.'4: O0 140.,00 140,0.0 .' :.. :.... ~4O.Ol 24, o oo 3'n 02 340,00 200,00 0 50 4, :03 440.00 300.00 0 47 540,04 540.00 400,00 0 50 N 82 42 E -2 25 640 05 b40,O0 500,00 0 45 N 79 57 E -2:94 740:06 740,00 600.00 0 54 $ 8b 48 E -3,41 A40,08 H40,O0 700,00 1 q S 88 54 E -3.R7 N 85 48 E -4,66 N 87 39 g -5.61 8 80 46 E -6.11 S 74 7 E -6,27 S 65 7 E -6.14 S 39 29 E -5.47 S 14 ~ E '3,13' $ 3 19 W 4,57 S 10 30 W 19,55 S 6 20 W 41,28 940.{0 940,00 800,00 1 27 040 14 1040.00 900.00 1 20 140~16 1140,00 1000,00 I ~ 240,~.8 1240,00 1100,00 1 1~. 340.~0 1340,00 1200,00 1 6 ~0 22 1~40,00 1300.00 1 18 0:28 1540.00 1400,00 2 49 640.64 1.640,00 1500,00 6 43 741 80 1740,00 1600,00 ]0 38 R44~72 18~0,.00 170o,00 14 1~ 94fl.34 1940,00 1800,00 17 5 054,36 2040,00 1900,00 20 161 65 2140.00 2000,00 22 28 271:04 2240.00 2100,00 25 29 ~"~.60 2340,00 2200,00 29 i ,43 2440~ ;'..' 2300.00 33 Il ~23,27 2540, ~..2400,00 37 53 '755.01 ~64'0~ '~"~1,2500,00 43 18 :89R.~0 2740~ ~ 2600,00 47 37 ;043,1b ~84~ '2700,00 44 57 800,00 900,00 ,00 45 12 44 49 44 49 44 52 3200,00 45 20 3300 O0 45 12 3400 O0 45 4 O0 44 47 O0 44 33 O0 44 30 S 9 55 W 69,79 S 14 17 W 104.78 S 15 55 W 143.60 S 16 7 W 187.89 S 1~ 27 W 239,51 $ 16 35 W 290,07 S 17 ! W 371.12 S 17 37 W 456.8{ $ 18 19 W 560.08 S 18 13 W 66~.16 S 17 52 W 763,61 S 17 42 W 862.75 S 17 35 W 962.02 S 17 35 W 1062,14 $ 17 27 W 1163,19 S 17 29 W 1264,23 S 17 2~ W ~64,B5 $ 17 24 W 1464,66 $ 17 32 W 1563.48 S 17 40 W 1661,82 [174 89 3640 O0 3500 [315:49 3740 O0 3600 [455~ 74 3840,00 3700 0,00 0.00 N 0,00 0,00 0,00 N 0 O0 0,70 0,05 S 0:55 0,4.9 0.11 N 1,87 0.29 0,16 ~.] 3,38 0,31 0,40 N 4,7~ 0.53 0.39 ~.! 6.20 0.25 ().69 ~ 7,49 O.1R 0,73 N 8,93 0~53 O,b4 N 10,73 0.13 0.73 N 13.06 0.68 0.92 ~ 15.58 0.31 0.77 N 17,70 0,49 0,30 ~,~ 19 70 0.30 0.43 $ 21:54.E 1,16 1.62 S 23,09 3,21 4,50 S 24,44 .4.23 12,74 S 24,92 3,44 27,68 $ 22,48 3.83 49.52 S 19.42 3,91 78.i6 1,5!. 112,56 2,52 150,01 3,01 192.b0 2,97 242.17 4,14 300,06 3,~1 368,27 4,64 450,07 0.53 548,30 0.70 647,05 0,41 0,20 0,33 0,28 0.30 0,23 0,05 0.22 0.15 0,18 0,00 N 0 0 E 0,00 N 90 0 E 0,55 S 84 44 E 1,87' N 86 32 E .3,38 N 87 14 E 4,74 N 85 ll E 6,21 N 86 23 E ') 7.52 N 84 42 E 8.96 N 85 19 E 10,75 N 86 36 E 13.0~ N 86 47 g 15.61 N 86 37 E 17 71 N 87 30 E 19:70 N 89 7 E 21155 S 88 51E 23,14 $ 85 59 E 24,85 S 79 33 E ~7 99 $ 62 54 E 35~66 S 39 4 E 53,19 $ 21 24 E 15,41 E 79,66 S ll 9 E 8,09 E 112.85 S 4 6 E 2,23 w 150,02 S 0 51 W 14.45 w 193.14 $ 4 17 W 28.91 W 243.89 $ 6 48 W 46 05 g 303,57 S 8 43 W 66 67 W 374.26 $ 10 15 W 92 20 W 459,42 S 11 34 w 124 05 W 562,16 S 12 44 W 156 96 W 665'82 S 13 38 W 741.63 S 1:8'7,73'w 765,02 S 14 12 W 836,05 S 217,95 W 863,99 S 14 36 W 930,65 $ 248,06 W 963,14 $ 14 55 W 1026.07 S 278,36 'w 1063,15 S 15 10 W 1122,44 S {08,76"W 1164,13 $ 15 22 W ~218,83 S ~39',08 W 1265,11 $ 15 32 W 1314.79 S 369,30 W 1365,b8 S 15 41W 141o;01S 399,22 W 1465,44 $ 15 48 W 1504,28 $ 428,87 W 1564,22 S 15 54 W 1598,01 $ 458.64 W 1662.52 $ 16 0 W C,-13 O~TH SLOPE:, COMPUTATION PAGE 6 DATE OF SURVEY: 23-OCT-84 KELLY BUSHING ELEVATION: 140,00 '*FT INTERPOLATED VALUES ENGINEER: PEPPE[, 100 FEET OF SUD-SEA DEPTH TRUE SUB-SEA COURSE ASURED YERTICA[, VERTICAl, DEVIATION AZIMUTH DEPT~ DEPTH DEPTH DEG MIN DEG MIN . VERTICAL DOGLEG RECTANGULAR COOROINAT£S HORIZ, DEPARTURE SECTION SEVERITY NGRTH/$OUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 595 80 3940.00 3800.00 44 21 .$ 47 W 1'759 88 ' 11'~i,",:,8 .' <'8'7 3'3 874 81, 4140~00 4000 O0 ,.,:, 013~5 4240,00 4100 00' Ir'n 48 4340 O0 4200 OC 43 47 S 18 20 W 2147 02 , 2 .56 4440.00 4300 O0 43 28 S 18 38 W 2242,23 428.31 4540.00 4400 O0 43 24 $ 18 54 W 2336,96 565.~3 46~0.00 4500.00 43 14 $ 19 6 W 2431,34 702.57 4740.00 4600 O0 42 36 $ 19 24 W 2524.56 ~37,83 48d0,00 4700:00 41 56 S 19 46 W 2615.57 972 !.7 4940.00 4~00.00 42 24 107 ~9 5040.00 4900'00 42 3~ .243 ~8 5140.00 5000 O0 42 55 .380 ~8 5240.00 5100:00 43 19 5200,00 43 36 .518 78 5340.00 ~657 '2 5440,00 5300.00 43 41 .795 12 5540.00 5400.00 43 16 ,931i83 5640.00 5500:~0 42 46 '067 43 5740.00 5600 0 42 7 '201.75 5840.00 5700,00 41 28 19 49 W 2705.22 19 37 W 2796,93 19 45 W 2889,03 19 45 W 2982.61 19 46 W 3077.5'0 1.9 27 W 31 73,03 19 12 W 3268,10 19 11 W 3361'29 19 3 w 345~ 83 19 0 W 3542~48 '334,~0 5940,00 5800.00 40 40 '465.05 6040.00 5900.00 40 12 '596.34 6140 O0 6000 O0 39 13 '724. 30 6240:00 6100~00 37 55 '~'~'42 6340.00 6~00,00 37 28 ,¢ ~00 6407~92"~i", 6267,92 37 28 S 18 55 W 3629.61 S 20 55 W 3715,03 S ~3 4 W 3798.39 S 22 26 W 3877.92 S 22 36 W 3954.50 S 22 36 W 4006.37 0,29 0,27 1784 0,23' ~876 0,13 1968 0,39 O,J? 0.34 0.34 0.45 '1.10 0,77 0,17 0.48 0,65 0,29 0,34 1,33 0,19 0,39 0,96 0.53 2,30 1.19 1.03 0,00 0.00 1691 40 S 488 52 W 1760 54 $ 16 6 W 17 S 518i39 W 1857i95 $ 16 ~2 W 49 S ~$~ 45 W 1954 99 S 16 7 W 29 S ,52 W 2051 55 S 16 2 ~ 2059 46 S b08,62 W 2147 51 S 16 27 W 2149 76 S 638,83 w 2242.67 S 16 32 W 2239.47 S 669,30 W 2337,35 S 16 38 W } 2328,73 $ 700.03 W 2431.67 S 16 43 ~ 7416,80 S 730.72 W 2524.85 S 16 49 ~ 2502,57 S 761,29 W 2615,8~ $ 16 55 W 2586,95 5 791.79 w 2705.41 S 17 1 W 2673.37 $ 822,65 W 2797 08 S 17 6 W 2760,13 S 853,70 W 2889 14 $ 17 1! w ?848,23 S 885.45 W 2982 69 $ 17 16 W 2937,59 S 91'1.55 W 3077 56 $ 17 20 W 3027,62 S 949.68 W 3173 07 S 17 24 W 3117,33 S 981,27 W 3268 12 S 17 28 W 3205.37 S 1011.91 W 3361 30 $ 17 31 W 3291,88 S 1.041.95 W 3452 84 S 17 33 W 3376.65 S 1071,18 W 3542,48 S 17 36 W 3459,07 S 1099.52 W 3629.62 $ 17 38 W 3539.64 $ 1128,01 W 3715,03 S 17 40 W 3616,89 $ 1160.13 W 3798.40 $ 17 47 W 36g0.51 & 1191,04 W 3877,94 S 17 53 W 3761.49 S 122U,50 w 3954.55 S 17 58 W 3809,56 $ 1240,51 W 4005,44 $ 18 2 W CO~PUTAT! <26 - N 0 V - 84 ~RCO ALASKA, INC, '.UPARIlK IORTH SLOPE, ALASKA INTERPOLATED VALUES N HORIZONS MARKER LOWER SAND" ' 'SE bOWER SAND TOTAL DEPTH 77~i oo 78 oo ?936 O0 ORIGIN= 303' TVD '~eo~ K~ SUB-SEA 1 59 ,41 6246.07 6106 07 6329,35 6159[35 6407.92 6267,92 PAGE 7 DATE OF SURVEY~ 23-OCT-84 KELLY BUSHING EbEVATION{ 140,00 FT ENGINEER~ PEPPEL SURFACE LOCATION AT FNL, 88' FEb. SEC 6, TION~ RgE. UM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 564',82 $ 1138 ~602,12 S li53 3694,88 $ 1192 3753.g5 $ 121~ 3809.56 G 124 O0 W 81 W 84 w 36 W 51 W r~UPARI~K ~IORTH SLOPE MARKER M "~$E LOWER SAND TD TOTAL DEPTH 773:O0 783' O0 7931 O0 PAGE 8 · · DATE OF SURVEY: 23-0CT-84 KELLY BUSHING ELEVATION: 140.00~FT ENGTNEER: PEPPEL FROM KB 6246°07 6329.35 6407.92 ORIGIN: 303' FNL, TYD SUB-SEA 5932,16 598 ' 6189,35 6267.92 SURf'ACE LOCATION FEb, SEC 6, TION~ AgE. UM RECTANGULAR COORDINATES NORTH/SUUTH EAST/WEST 3564 82 S 3602 12 S 3694 88 $ 3753 95 S 3809 56 S 13~ OOW 15 81 W 1192 84 w 1217 36 W 1240 51 w FINAl,, WELL LOCATION AT TO{ TRUE SUB-SEA MEASURED VEHTiCAL VERTICAL DEPTH DEPTH DEPTH 7936.00 6407,92 6267,92 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 4006,44 S 18 ~ W SCHLUMBERGER RRCO RLRSKR. INC ' KUPRRUK NORTH SLOPE, RLRSKR OCTOBER 2:9, 1984 TVW PLOT FROM OCT ORTR JOB REFERENCE GgGS? SURFACE LOCATION: '03' FNL, 88' FEL, S6, TION, R9 'UM~ HORIZONTAL PROJECTION NOR'tH !000 REF 69657 $CP, LE = I/lO00 IN/FT -4000 1000E~ST WELL: 2G-13 SURFACE LOCATION:'._~03' FNL, 88' FEL, S6, TION, R9.. UM VERTICAL PROJECTION -4000 -]000 -2000 -1000 0 0 I000 ~000 ~ PROJECTION ON VERTICAL PLANE OF AZIHUTH 198 SCALED IN V£R?ICAL D£PlH~ HORIZ SCALE = 1/1000 IN/FT I Suggestea form to be insertcd in each "Active" well folder to d~.eck for timoly cc~liance wi~h our' regulations. O~erator, ~ell Nan~ ~nd Number Reports and Materials to be received by: l~te Required Date Received Remarks · _Ccmpletion Report Yes ~/' ~c~,,. ~ ~-~ ~!i~'-~ ~> ~ /_~, / "~., Well History Yes .__ _ ~- o?.. (.. .,2,~/TM . .. · Core ~scrip~on ~.-.-':/~h.::/':~ Registered S~ey Plat ~C~ Inclina~on S~ey A':'"'? · / .. ./' ARCO Alaska, In,'---- Post Offic. "" 360 Anchorage, ,.,aska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETURN TO: ARCO ALASKA, INC. = ATTN: Records Clerk AT0-1115B P.O. Box 100360 Anchorage, AK 99510 . ~/Transmitted herewith-are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL's/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 ,I ,1 ,! ,, II 11 ,1 I! TI 11 ,1 I! II oO I1 !1 II I1 II II II II 11 11 II "GCT" 10/07/84 " "GCT" 10/07/84 " "GCT/JB/GA" 9/31/84 " "GCT/JB/Eing 9/17/84 " "GA/JB/GCT" 9/19/84 " " 9/17/84 " ,GCT" 7/21/84~ " "GCT" 9/21/84 " "GCT/GA/JB" 9/14/84 " " ~/15/84 " · "GCT/JC" 10/i2/84 " " 1o/15/84 " " lo/12/84 " " 10/13/84 " "GCT/~-B/GA'' 10/22/84 " " 10/22/84 " "JB/GA" 8/19/84 " " 8/20/84 .aun 3 9/21/84 Run 1 "GCT/JB" 10/14/84 Run 1 " lO/14/84 " " lO/O5/84 " "OCT" 10/05/84 " "Perf 4"~ 9/10/84 Run 2 5 l/2"/P?s/J~" 11/05/84 Run 1 Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: B. Currier BPAE Chevron DISTRIBUTION · Drilling W. Pasher Mobil Phillips Oil 6597 - 8292 ~2B-3/ 7000 - 8460 J2B-!6~/ 4950- 7004 >2B-13v~ 5750 - 8408 ~2B-14~ 5700 - 7970 '~2B-15,× 5348 - 6824 '-2B-2 ~ 7250 - 9182 ,-~B-4 ~ 5055 - 6487 --2B-l~ 6200 - 7866 ~2D-5~ 6800 - 8954 --2D-6 ~ 5054 - 6650 ~2Di?/ 5597 - 8084 --'2D-~8-/ 5650 - 7951 --2G-9~/ 5840 - 8524 --2G-11~ 4940 - 6765 ~2G-10~ 5730 - 7950 ~-2G-12~ 5790 - 7814 -- 2G-13~/ 5989 - 8624 --2G-14~ 8650 - 9334 ~tF-6~/ 8650 - 9562 ~' 1F-6~ 5692 - 6742 --1Y-5~/. 5150 - 7252 ~iL-1/ 4500 - 6550 ~lL-2~/ 6800 - 7518 iL-4~, 7000 - 8210 --1L-3v/ 7961 - 8941 '--2V-8A 6100- 6992 -~1E-24 Sohio Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, ,. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Monthly Reports Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells' 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Sincerely, Area Drilling Engineer JBK/SH/tw. HILL/01 Enclosures RECEIVED NOV 0 Oi, & Gas Cons. Commlsdml Anchorage /tlit"t~ ~1==1~= Iht, I* n -~.h_~ldi~rv of AtlanlicRichfieldComparly STATE OF ALASKA ALASK, .)IL AND GAS CONSERVATION L ~MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wetl~ Workover operation [] Name of operator 7. Permit No. ARCO Alaska, Inc. 84-129 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21160 9. Unit or Lease Name 4. Location of Well at surface 303' FNL, 88' FEL, Sec.6, T10N, RgE, UM 5. Elevationinfeet(indicateKB, DF, etc.) 140' RKB, Pad 104' 6. Lease Designation and Serial No. ADL 25667 ALK 2588 For the Month of September , 19 84 Kuparuk River Unit 10. Well No. 2G-13 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12· Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0001 hr, 9/25/84. Drld 12-1/4" hole to 2870'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 7936'TD as of 9/29/84. Ran logs. Ran, cmtd & tstd 7" csg. Secured well and RR @ 2100 hrs, 10/1/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36# L-80 BTC csg w/shoe ~ 2849' Cmtd w/875 sxs PF "E" + 420 sxs PF "C" 7" 26# L-80 + J-55, BTC csg w/shoe @ 7920' Cmtd w/375 sxs Class "G" 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP f/7914' - 2847' FDC/CNL/Cal f/7889' - 7300' 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED NOV 0 Alaska 0il & Gas Cons. 00mmissl0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED . *' '~" TITLE Area n,~ 11 ~ ~g :"'~¢ -~r DATE NOTE--R~"" "" ' ' 'required foreach ca!endar month, regardless of the status of operations, and must be Oil and G~mission by the 15th of the succeeding month, unless otherwise directed. Pnrrn 1 N~.nzt ..... , filed i~ duplicate with the Alaska Submit in duplicate ' TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Stato ~ Al~?,ka '- Ala~lm iYtl ~1 Gas Conservation U, ommi~o~ · 8001 Porcupine Drivo Anchonnge, Alaska ~0,501 Receipt of the .. following material which was transmitted via ~4~] / is hereby acknowledged: QUANTITY DESCRIPT%ON RECEIVED: DATED: Copy sent to sender _X NO ARCO Alaska, _-, .:. ;-- Date: 10/19/84 Transmittal No: 4774 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Schlumberger Tape ~9576 2I)-4 9/29/84 tkm 1 3935 - 8641 ~69551 2D-5 9/18/84 " 3828 - 7988 ~69574 2B-14 9/26/84 " 3388 - 8617 ~69579 2G-13 9/30/84 " 2830.5-7939 ~69555 1L-3 9/20/84 " 2027 - 8493.5 /cat Receipt Ackn¢ B. Adams F.G. Baker P. Baxter BPAE Chevron D & M Drilling Geology Mobil NSK Operations W.¥. Pasher "" ' · ,- .~t~'~ !_~l '~ ' .-- C. R. Smith G. Phillips State of Alaska Phillips Oil Sohio j.j. Rathmell Union R & D Well ~iles MEMORANDUM Sta e of Alaska ALASKA OIi~ AND GAS CONSERVATION COPR~ISSION TO: C. V/. ~tterton DATE: September 28, 1984 Cha~u~/~--~/ , .... ./ FILE NO: D. 1 I. 38 ~dRU: Lonnie C. Smith ~ ~ -~'-~ V ~' SUBJECT: Witness BOPE Test on FROM: Ben LeNo~n Petroleum Inspector ARCO' s Kupa~k 2G-13, Sec. 6, T10N,R9E,~{, Kupa~k River Unit. ~ednesday, September 26, 1984: I departed my home at 1:50 pm for a ~-~-~s~owhP: a~-'3i~O'pm departure via Alaska Airlines, Flt. #57 for Deadhorse arriving at 5:00 pm. Weather: +34°F, high overcast, light wind. Tests began at 6:50 pm and were completed at 7:40 pm. BOPE inspection report is attached. Thursday, September 27, 1984: I departed Deadhorse at 5:40 pm via A--I~a~ka Ai~ii~-es, ~'lt~ #~--,-~rriving in Anchorage at 7: 30 pm and at my home at 8:30 pm. In summary, I witnessed successful BOPE tests on ARCO's Kuparuk 2G-13. Attachment 02-00IA(Rev. 10/79) O&G -,#4 4/81 STATE OF ALASI~ OIL & GAS CIDNSERVATION COVlb~SION B .O. P .E. Inspection Report Operator. ,/~;~ ~ ~tion: Sec ~ T/L~R f~3'M ~'~ ~illing ~n~a~or ~C ~~ Rig ~ '~ Representative ~ ~asing Set Representative Location, Genera] Well Sign C~neral Housekeeping Reserve pit ACCUMULATOR SYSTEM Ful 1 Charge Pressure ~ Pressure After Closure Pump incr. clos. pres. 200 psig. Test Pressure psig psig Annular Preventer Pipe Rams Blind Rams. Ch°ke Line Valves.__ H.C.R. Valve Kil 1 L~ ne Valves Check Valve Full ,~harge ,.P~,_~e,ssure Attained: ...~2. N2 ~ .~,ju~_j~ ~ .~ ~ .~- psig Controls: Master O ~ Remote O/~Blinds switch cover Kelly and Floor Safety Valves - min .~, ~. sec. min. / ~7 sec. Upper Kelly Test Pressure Lower Kelly Test Pressure Ball Type. . Test Pressure Inside BOP Test Pressure Choke Manifold, Test Pressure valves.__ No. flanges ~ Adj ustab le Chokes Hydrauically operated choke ! Test Results: Failures. . ~3 Test Time'~ hfs .... Repair or Replacement of failed equipment to be made within, days and Inspector/Ccmmission office notified. Distribution orig. - AO&GEC ~,/-~ ,o .~( CC - Operator ...~' cc - SupervisOr Inspector . July 31, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~chorage, Alaska 99510-0360 Re .. Kuparuk River Unit 2G- 13 ARCO Alaska, Inc. Pemit No. 84-129 Sur. Loc. 303'FNV~, 88'FEL, Sec. 6, T10M, RgE, IIM. Btmhole Loc. itll'FSL, !321'FEL, Sec. 6, TI0N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25. 050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except ex. perimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for' the spawning or migration of anadromous fish. Operations in these areas are subject to A~ 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution. of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended Prior to commencing operations you may be contacted by a representative of the Department of Envi~onmenta! Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. K~win Kuparuk River Unit 2G- 13 -2-- July 31, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, '-0~. ~.r' ' Chaimn of Alaska Oil and Ga~ Conservation BY ORDER OF THE COMMISSION be EnClosure cc: 'Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. i ~_ Post Office B ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2G-13 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2G-13, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on August 19, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Ke~[ Area Drilling Engineer JBK/JG/tw GRU8/L62 ~ss~ 0i~ & G~S Co~S. r~omm'~ss~O~ Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. '-- STATE OF ALASKA ALASKA b,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL DRILL il(iX REDRILL [] DEEPEN [] 20 AAC 25.005 EXPLORATORY [] SERVICE [] STRATIGRA~.,~I~ DEVELOPMENT OIL [~X SINGLE ZONE~X DEVELOPMENT GAS ~ MULTIPLE ZON~ 9 Unit or lease name Kuparuk River Unit lb. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 303' FNL, 88' FEL, Sec.6, T10N, R9E, UM At top of proposed producing interval 1396' FSL, 1230' FEL, Sec. 6, T10N, RgE, UM At total depth 1111' FSL, 1321' FEL, Sec. 6, T10N, R9E, UM 10. Well number 2G-13 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 140', PAD 104' I ADL 25667 ALK 2588 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 303 feet ~.~-~.~ell ~-~Lg~)I ~) ~,~"~l~e~ feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7937' MD, 6388' TVD feet 2501 08/19/84 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2774 psig@__80°F Surface KICK OFF POINT 1370 feet. MAXIMUM HOLE ANGLE 44 oI (see 20 AAC 25.035 (c) (2) 3185 psig@ 6243 ft. TD (TVD) 21 SIZE I Hole Casing i 2~" 16" I12-1/4" 9-5/8" 8-1/2" 7" Weight 62.5# 36. O# 26.0# Proposed Casing, ;ASING AND LINER Grade Coupling/ H-40 / Wel~ / .iner and Cementing Program SETTING DEPTH Length M D 80 36' I 36' 2792 35' I 35' 7904 TOP TVD I 33' I 33' I MD BOTTOM TVD 116i 116' 28271 2690' I 7937q 6388' I QUANTITY OF CEMENT (include stage data) ± 200 cf 770 sx Permafrost E & 370 sx Permafrost C 300 sx Class G 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7937' MD (6388' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter, Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2774 psi, Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2G-13 will be~(~)away from 2G-I~ at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the workover rig, using 3-½", · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge //l a · .- Area Dril ling Engineer below //' i~-~'~ -'"-~/~1~ /~ C~nuse/ '/ "~'~ SIGNED ..~ TITLE for/~ommissio/ r CONDITIONS OF APPROVAL The space DATE Samples required I--lYES Permit number APPROVED BY Form 10-401 Mud log required []YES I~-NO Approval date Directional Survey required APl number []~YES I-lNG 50- ~ 7,,~ -'7..I ) (~ 0 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER. DATE July 31; 1984 by order of the Commission Submit in triplicate Permit to Drill 2G-13 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED ,JUL 2 5 l~lll~ Anchorage i, - ' - ~ .... ~ - · J · · - _ . ~ ~ . _ . ............. ~ -- ~ ~ ~ .~_._ . ~ _ ~ ............ , -.. ............... ~. · . } ............. ~ · . . ~... ~ .i . ~ .. ' 'I · ' J ' ' ', . ~ ' . ~~ X ; .... ,........ ~ .... ~ -~. . ~" , " ~ '. ~ ..~ ...... ~ - + i ~nn , .::: ,, ~ . ~ , ,:_ ,:;, ;, _ ~ .... ~ _~,__. - -; -- ' - ~ .... ~ ................ i- .. + .... i, ~ - . . t .. . ~ .... - ~ .... ._ _ ~ ~-. , - ~ ~ - ~ 1 ~ ~i~ . ~ ............................... : - I I I J Il ~ L [ I ] I I I ' ......... .............. . ............ ~ ....................... ~ ...... [ ..............t ........ i ~ ........ ~ . ~ ~ ....... i ...... ~ ........... . 0o:: oo' soo ~ 0 .... 1 ~ · 2;I ..................... ', ! i ! ~ .... ', ....... ~ ,, ! ~ ~ ! , , .... i i "= : ' ~ ; , , WELL PATHI EXTi~ND BI:YOND" .~.~ ....... +-~ ...... ~.-. . , ~- =-~ ..... ~ .......... ~ ....... .= ~ , , ~ ~ , ~~-- ~ ~ ~ ' ; ~ , : . . ' i , ~ ~-~-t-'~ .... ; 4 ~ ~-~-~ ~-~-'~r'~-' ~-' , , : , : ~ . , ..... ~ ~3~L- , , ~ ' , * , . ~ ; ~ ~ , ' ~ , , ' ; ~ · + ~ ~ ' ' ~ * ' t~ ...... ' , ' '~ i ~ --- -- : ~ L ~, . ~,.. ' i ' i : , , , : , ~ ~ ~ ~ ' ~-- I L ~ ............... ' t ..... ~ ~ ' : * ' ' ' ~ ~ ' + f ' ' ' ' ~ . i ~ , , , ~,,,::..t~:+, ::.,~,: ............ : : ;,, .:~:~rl:~ r~' ::;/ : ~ ::;:' ::' '::: :,:::'.:: 'C, ":':.'.' .... " , , , . ~ ~ ........ , , , , · ...................... , , · ~ ~ ~~' "~ . ~ , ~:~ ..................... · ~ ......... ,., ~ : , ~ ....... ~,',~ ..... :': ............................. : '' ............ ~' :r~ ............................................ ' ........... f ' .... ; ~ ~_, .......... ~ ..... ~ , ., , .... ~ ................................. ; ..... ~ ..................... ~ .............. ~ ..... ~ ............ ~ - · .... ::, : .................................... ...... , .......................... ~ ........ ~ . , , ......................... , ......... ,, ,, ..... ,, ., ..... . . PREYENTER BLINI) o ~ DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3, 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4, 12-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 12-5/8" - 5000 psi pipe rams 6. 12-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 12-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 12-5/8" -.5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTRF. jm),M 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 NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MA~IIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND I)ON~T TEST A~INST ~OS~D ~S 4. TEST ALL COMPONENTS TO 250 PSI ~D HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0 B. ~~'P~SS~ m~ST~ OF ~ I~TION V~S~ TO ZERO PSI TO TEST VALVES. TEST RE~INING UNTESTED ~NIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTRE~ OF VALVE AND ZERO PSI DOWNSTRE~. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP S~ OF PIPE ~MS AND CLOSE BOSOM SET OF PIPE R~S. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOSOM SET OF PIPE ~MS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND R~S AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. 12. OPEN BLIND ~S AND RECOVER TEST PLUG. MAKE SURE ~NIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 1~. RE~ORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. TIONALLY OPE~TE BOPE DAILY. JUL251 A)~ Oil & 8a~ Cons. Commission AnChorage m Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. .16" X-20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserv~ pit. Valves to open automatically upon closure of annular preventer. G. 20" 2000 psi annular preventer. 7. 20" bell nipple. ,h Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. ~f necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 1 6" Conductor RECEIVED J U L 2 5 1984 Anchora. g~ :~sJon ARCO Alaska, Inc. Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2G Pad Wel 1 s 5-16 Dear Elaine- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L26 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany ~ 49th = 5 DS 2G .6 · 5 TIO~ I HEREBY CERTIFY THAT I AM P£OPERLT REGISTEKED AND LICENSED TO PKACTICE LAI~D SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRES~TS A SURVEY. MA.DE UNDER MY DIRECT SUPERVISION AND T~AT ALL DETAILS ARE COKRECT AS OF: ~?~'~ .=-- A 5~7G- $ A!ask~ 5. Y"'5944195.05 I..~T- 70-15-31.5000 F~L 5.TI 272 FWL 303 FNL LOC~'~ED IR SECTIOII 6,TION,R~E,U.M., X- 50~609.92 ~N~149-55-49,504 88 ~ 303 ~ 14. Y-~943~qS.15 L.AT- 70-15-23.1441 L,ONG.- 149-55-49,502 243 FNL I5. Y-594S405.25 LAT- 70-15-23.7353 X- 50S609.95 LONG-Iq9-'55-49.499 ':~2~ 88 ~ 183 ~ ~X E C E ] ~/-,6. Y-~9i~465.22 ~T- ~0-15-243252 1- 508609.9~ LON~149-S5-49.49~ ~il 87~ 123 ~ pu .'~. q~q O~,,;& p.¥'?-~5,:ei~n ...... ---- D,~ 2, G CONDUCTOR~ 5' 16 AS- BUILT ~ -1 m mil - ~,t.' 6.~.04 ~c,~.'None X* 50~969.91 LONG-Iq9-55-39,024 273 FWL 123 FNL !0. Y-594~40~.10 ~T- 70-15-23,72~7 X- 5089~,75 LON~149-55-39,031 272 ~L 183 ~ 11. Y-5943345.24 ~T- 70-15-23.14~ X- 508969.92 LON~ 149-55-39.028 ~72~L 243 ~Z 12. Y-5949285.17 ~- 70-15-22.5500 (2) Loc thru 8)' (3) Admin'(~-t~-~ ~,5'~ (9/thru 11) (10 and 11) (12 thru 20) (5) BOPE ~~ 7-,~-~/ (21 thru 24) (6) Add: Company Lease & Well No. /~]7~''~I~ ~- t..~ ' ' xes NO ~. IS the permit fee attached ....................................... · · , ' ee ' · 2. Is well to be-located in 'a defined po°l ....... .... Is well located proper distance fr°m property line l 4. Is well located proper distance from other wells .................. 5. Is Sufficient undedicated acreage available in this pool .......... 6. Is well to be deviated and is well bore plat included ............. ?. Is operator the only affected party ............................... 8. Can permit be approved before ten-day wait ........................ . 10. 11. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ....................................... Is enough cement, used to circulate on conductor and surface ........ Will cement tie in surface and' intermediate or production strings .. Will cement cover all known productive horizons .~ .................. Will surface casing Protect fresh water zones .................... ~.. Will'all casing give adequate safety in COllapse~ tension and burst. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ........... Is adequate well bore separation, proposed .......................... Is a diverter system required ......... · ........................... ,~ Are necessary diagrams of diverter and ~$~'equipment attached Does BOPE have sufficient pressure rating - Test to ~?t~ psig .. /~zT'~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional r~quirements ............................................. Additional Remarks: /%)._~'/./.. ~2/~-/3 WI,Z/._ ,f~',~'- ~&jDzF/~ZD/M? ~2~-/~l }=/~zg/~f 1.2. 13. 14. 15. !6. 17, 18. 19. 20. 21. 22. 23. 24. 25. o ~.] HO Geology: HWK ~ LCS WVA~ JKT re'r: 12/08/83 6. CKLT Engipe_erin~: BEW INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to Simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. · .... SC~LU~ERGEN .... ~ YERIFT,,CgT~ON LISTING : 1 ()? 4 T¥ [, 8I'Z£ (; o 5 0o5 a]PEC ! .F 1C,t, T.I '(]~4 & F. i,{ V ] C E S [( R V I C t.![; ij ~ 1 APl AP1 APl 0 0 (l 0 0 0 0 2 ~ ('... () !, 0 0 ~20 46 0 0 120 ,14 o 0 0 ~ 0 0 t 0 0 3 r ~ 0 1 () ~I, 0 O1 0 0 3%.: 6 ~"., t () 0 420 0 0 0 t) 0 ('~ O f! 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'? ,~,~. 5625 ~: i.~ b .t 2.8477 kr',lE A 8 7 6,0 t; 0 (,' 100.3"150 (,'.ALI 499.0[)00 I .8975 116.0(.10:3 f:AI ] 3.'?18~ R~xRA 474.0 ~.; (; ~ 2, '? 2, 85 1 3500 22. 428, '/BOO 4.53-'52 106 81.25 [,"~bI ., q ,':) q ' .2 500 -999,2500 2..l 0,16', 5, ~36';' .~. 2 2 O '7 2. 9.4609 3.494]. !0.17!9 9.359~I 3.13B7 2.35!6 t0.3934 ;i:. 4 7 66 I .9717 ! 0.1 2 5 0 923~ 03 .1, 4 3,6406 1. 0.14:[)6 -999,25C)n 10,9453 -999. 2500 2.7617 '1 i~. I 40 -99~. 2500 4.. 5625 ,-, 9 q' 9 · ¢ :50 0 OEP']' 6bu9,0000 S k' ,-- i ~, {-, o 75 L) !.) (.; ~< $ P - 158, ',') u 0 O G i{ R 'H t..! i.' - 9 g 9. :it 5 ~.~ 0 :'3 r~ ~, a E P T 5800. 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