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Home My WebLink About209-029Cono4hillips TRANSMITTAL FROM: Sandra D. Lemke, ATO -704 TO: Abby Bell ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. Th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 1C -07A DATE: 02/11/2019 Transmitted: River Unit Ziebel Cased Hole Mechanical logs - raw data reports (production profile characterization) promptly sign, scan, and e-mail to Sandra.D.Lemkenaconoconhi//ins.com CC: 1 C -07A - e -transmittal well folder //I Receipt: I Date: 02A "� I `� /�J��/J� Alaska/IT-GGRE i C o Phillips Alaska I Office: 907.265.6947; Mobile 907 440 4512 2090`9 30 35 4 RECEIVED, FEB 11 2019 STATE OF ALASKA RECEIVED ALA...,A OIL AND GAS CONSERVATION COM —SION APR 2 9 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell F Rug Perforations r Perforate r Other AO CC Alter Casing r Pull Tubing F 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 r' Exploratory r 209-029 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service - 50-029-20569-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649 , 1 C-07A 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 , 11321 feet Plugs(measured) none true vertical 6468 feet Junk(measured) none Effective Depth measured . 11269 feet Packer(measured) 8646, 8770 true vertical 6476 feet (true vertical) 6364, 6440 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 80 SURFACE 3055 10.75 3087 2601 PRODUCTION 8954 7 8985 6542 LINER A 2244 2.375 11269 6476 Perforation depth: Measured depth: slotted liner from 9434'-11268' f�01 True Vertical Depth: 6525' 6476' sumo �1 U L 1 6 Tubing(size,grade,MD,and TVD) 3.5, L-80, 8722 MD,6410 TVD Packers&SSSV(type,MD,and ND) BAKER FHL PACKER @ 8646 MD and 6364 TVD RBDM4 MAY 1 6 2014 BAKER FHL PACKER @ 8770 MD and 6 TVD CAMCO DS NIPPLE @ 469 MD and 469 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 .+ . 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 Jake Voss(a,265-6935 Email Jake.Voss(aconocophillips.com Printed Name )ake Vo Title Drilling Engineer Signature 6L_,tr VVV Phone:265-6935 Date (il 9%q V L-F .5-/77-/I 4- Form 5-/ /14- Form 10-404 Revised 10/2012 ,"# 1/ 7 Submit Original Only • i KUP PROD 1C-07A ConocoP fillips 0.1 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl("I MD(ftKB) Act Btm(ftKB) corlorril,p upc 500292056901 KUPARUK RIVER UNIT PROD 100.56 9,383.14 11,321.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-07A.4/29/20148.04.56 AM SSSV:NIPPLE 75 12/16/2013 Last WO. 3/24/2014 39.01 4/20/1981 • Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .._....... Last Tag:SLM 8,798.0 2/12/2011 Rev Reason.WORKOVER postojl 4/25/2014 ...._..._...HANGER;28.1-" if Casing Strings .��'.,I •�'' i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len g...Grade Top Thread SURFACE 103/4 9.950 31.2 3,086.5 2,601.3 45.50 K-55 Buttress Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ,MA.CONDUCTOR,.32.080.0 - PRODUCTION 7 6276 31.5 8,985.0 6,566.3 26.00 K-55 BTC R3 POST S/T 111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread NIPPLE;468.9 jam. WINDOW AL1 7 2.740 8,928.0 8,934.0 6,542.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread .11 LINER A(off AL1) 23/8 1.995 9,025.0 11,269.0 6,476.0 4.60 L-80 ST-L II Liner Details I. Nominal ID MANDREL;2.8270 -• Top(61/6) Top(ND)(ftKB) Top not(°) Item Des Com (in) • 9,025.0 6,574.3 83.88 JUNCTION ALUMINUM BILLET JUNCTION 1.995 10,225.9 6,507.4 87.52 DEPLOY DEPLOYMENT SLEEVE 1.995 I 1 Tubing Strings L p Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD))...Wt(Ib/ft) Grade Top Connection SURFACE,31.2-30865 TUBING WO 2014 3 1/2 2.990 28.1 8,722.0 6,410.2 9.30 L-80 EUE Completion Details Nominal ID MANDREL.4.721 2 _ Top(ftKB) Top(ND)((tKB) Top Incl(") Item Des Com (in) 28.1 28.1 0.00 HANGER FMC GEN 5 TUBING HANGER WITH PUP 2.990 468.9 468.9 0.34 NIPPLE CAMCO DS NIPPLE 2.875 8,615.7 6,345.0 52.42 LOCATOR BAKER 80/40 LOCATORS SUB 8 SEALS 3.000 8,623.0 6,349.5 52.39 PBR BAKER 80-40 PBR 4.000 8,646.1 6,363.6 52.27 PACKER BAKER FHL 7"26#PACKER 2.960 MANDREL.6077.2 8,667.8 6,376.9 52.16 NIPPLE CAMCO DS NIPPLE 2.812 I 8,721.0 6,409.6 52.00 OVERSHOT BAKER POORBOY TUBING STUB OVERSHOT 3.600 • Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft../Set Depth(ND)(...Wt(deft) Grade Top Connection MANDREL 7.279.2 1111 TUBING 31/2 2.992 8,721.5 8,83921 6,482.5 9.20 J-55 BTC I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top!min Item Des Com (in) • 8,7365 6,4192 52.00 SBR BAKER'ELA-1'SBR 2.810 MANDREL:8.062.4 8,770.0 6,439.8 52.00 PACKER BAKER'FHL'PACKER 2.937 El 8,801.1 6,458.9 51.99 NIPPLE CAMCO'D'NO GO NIPPLE-MILLED TO 2.80"4/2/2009 2.800 MANDREL;8.558.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) )°) Des Corn Run Date ID(in) 8,830.0 6,476.8 51.62 TBG TUBING PUNCHES FOR CEMENT PLUG 4/24/2009 2.992 PUNCHES LOCATOR;8,615.7 8,928.0 6,538.3 50.96 WHIPSTOCK Baker 3-3/16"whipstock set 0 deg HS in 2.80" 6/5/2009 2.740 Tubing;8,6160 cement pilot hole.Tray does not incorporate P86,8,623.0 ^ overshot taper on top. PACKER;8,646.1 '_',• Perforations&Slots Shot Dens NIPPLE;8667.8 _ Top(ND) Btm(ND) (shotslf Top(ftKB) Btm)ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,434.0 10,221.0 6,525.4 6,507.2 C-3,C-4,1C- 5/25/2009 32.0 SLOTS slotted pipe-0.125"x2.5" II07A @ 4 circumferential 4 adjacent rows,3" centers staggered 18 OVERSHOT;8,721.0 1% ' deg,3'non-slotted ends 11,227.0 11,268.0 6,482.1 6,476.2 C-4,UNIT D, 5/25/2009 32.0 SLOTS slotted pipe-0.125"x2.5" SSR;5736.5 -':a- 1C-07A @ 4 circumferential I adjacent rows,3" centers staggered 18 PACKER;8,7700 :-. ' deg,3'non-slotted ends NIPPLE;86010 Mandrel Inserts st I ati li on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com TBG PUNCHES;8630.0 V 1 2,827.0 2,429.6 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,194.0 3/12/2014 1 2 4,721.2 3,739.8 CAMCO MMG 1 1/2 GAS LIFT OV RKP 0.250 0.0 3/12/2014 WINDOW AL1;8.928.0.8.934.0 3 6,077.2 4,683.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/12/2014 4 7,279.2 5,432.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/12/2014 5 8,062.4 5,986.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/12/2014 PRODUCTION POST S/r; 6 8.558.8 6,310.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/12/2014 316-69856 SLOTS;e,981.0s,077.O.. - Notes:General&Safety LINER ALI(o8 main wellbore); _ End Date Annotation 8.819610,567.0 6/27/2009 -NOTE:View Schematic w/Alaska Schematic9.0 6/27/2009 NOTE:WELL SIDETRACKED,Multi-lateral SLOTS;9.434.0-10,221.0 • SLOTS;11,227.0-11,268.0 LINER A(ort AL1);9625.0- 11269.0 11 PRE-RIG WELL WORK SUMMARY DATE SUMMARY 2/1/2013 (PRE RWO) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, FUNCTION TESTED T& IC LDS'S (ALL GOOD). 4/22/2013 C SAND SCALE SQUEEZE. PUMPED 50 BBLS SW AHEAD OF TREATMENT. PUMPED 29 BBLS OF SEAWATER PRE-FLUSH CONTAINING 90 GALLONS OF WAW-5206. PUMPED 155 BBLS OF SEAWATER CONTAINING 850 GALLONS OF SCW-4004. PUMPED 380 BBLS SW OVERDISPLACEMENT. PUMPED 25 BBLS DIESEL FP IN TBG.VOL. NOT SUBTRACTED FROM OD. SINGLE OD, 24HR SI. 8/20/2013 TAG LINER TOP WITH 2.49" @ 8820' RKB. RECOVERED SAMPLE OF ASPHALTINES. MEASURED BHP (2882 psi) @ SAME. JOB COMPLETE. 10/5/2013 (PRE RWO) : MIT-OA PASSED TO 1800 PSI. 1/29/2014 MADE SBHP STOPS @ 8800' RKB (3088.54psi, 157.66 DEG) & 8640' RKB(3047.78psi, 154.7 DEG), BRUSH & FLUSH WRP SETTING INTERVAL FROM 8600' RKB TO 8820' RKB, RAN 2.78"WRP DRIFT TO LINER TOP @ 8820' RKB, IN PROGRESS 1/30/2014 SET 2.78"WFD WRP @ 8807' RKB, DROP 2.70"JUNK CATCHER (OAL- 124")ONTO WRP @ 8807' RKB, PULL DV FROM STA#7 @ 8700' RKB, IN PROGRESS 1/31/2014 CIRC OUT WELL WITH 260 BBLS OF WATER &73 BBLS DIESEL,U-TUBE DIESEL TO IA, CMIT-TxIA TO 2500 PSI, PASSED, DRAWDOWN TEST PASSED, JOB COMPLETE. 2/17/2014 AES PUMPED 240 BBL 10 PPG NACL DOWN TUBING AND UP IA AND 65 BBL DIESEL FREEZE PROTECT. DSL SHOT STRINGSHOT FOR CHEM CUTTER. SHOT INTERVAL 8717'-8725' RKB....JOB IN PROGRESS. 2/21/2014 CHEM CUT TUBING @ 8721' RKB. IN PROGRESS 2/22/2014 ASSIST DIGITAL SLICKLINE PUMP 5 BBLS METH THEN 65 BBLS DIESEL DOWN TBG AND THEN U-TUBE WITH IA, FREEZE PROTECT FLOWLINE WITH 5BBLS METH POST- CI RC-OUT JOB COMPLETE 2/22/2014 FREEZE PROTECT TUBING W/65 BBLS DIESEL, U-TUBE TO IA. FREEZE PROTECT FLOWLINE. IN PROGRESS 2/24/2014 MADE SBHP STOPS @ 8640' RKB (3031.0psi)&8473' RKB (2981.2psi), SET 2.81"CA-2 PLUG @ 1908' RKB, PT IA TO 1000psi, NO PRESSURE CHANGE ON TUBING, JOB COMPLETE 2/25/2014 MIT TBG TO 1500 PSI WITH DIESEL, JOB COMPLETE 2/26/2014 (PRE RWO)T POT-PASSED. T PPPOT-PASSED. IC POT-PASSED. IC PPPOT-PASSED. 3/5/2014 (PRE RWO) : T/IA/OA-DDT IN PROGRESS. 3/6/2014 (PRE-RWO) : T/IA/OA DD (IN PROGRESS). 3/7/2014 (PRE RWO) : BLEED T, IA, OA TO 0 PSI AND LOAD OA W/DIESEL FOR SECURE ConocoPhiIIips Time Log & Summary WNNfaw Web Reporting Report Well Name: 1C-07 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/25/2014 1:00:00 AM Rig Release: 3/29/2014 10:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03/24/2014 24 hr Summary Move rig from 1 D pad to 1C-07A. 18:00 00:00 6.00 MIRU MOVE MOB P Move rig from 1D to 1C pad. 33/25/2014 Rig Accept 01:00 hrs. Move, Spot rig, R/U support equipment,take on fluid, ND tree, N/U BOPE,test 250/3000 psi. 00:00 01:00 1.00 MIRU MOVE MOB P P/U tree hang in cellar-spot rig over well. 01:00 04:00 3.00 MIRU MOVE RURD P **Rig Accept**01:00 hrs. Shime up rig with plywood, spot cuttings tank,spot kill tank. R/U hard line to kill tank. 04:00 08:30 4.50 MIRU WHDBO NUND P PJSM-Bleed down SSSV line. ND tree. Located shorter studs for 3M flange. 08:30 13:00 4.50 MIRU WHDBO NUND P PJSM NU BOPE. 13:00 23:00 10.00 MIRU WHDBO BOPE P PJSM.Test waived ByJohn Crisp p AOGCC. 3/25/14. Test BOPE to 250/300 psi.Test#(1)Blind rams, kill line, Choke 11,12,4. 3.5 IF dart. Pass, Fill tubing with 9.6 Brine to displace diesel from tubing to CA-2 plug from 14:30 hrs to 19:00 hrs. (2) Man TD,3.5 IF FOSV, Choke, Kill HCR, 7,9,10,3. Pass. (3)Kill Manual, Choke 2,5,8. Pass.(4)3 1/2"8 rnd FOSV, Choke 6. Pass. (5)LPR 3 1/2"TJ,Choke 1. Pass. (6)Annular, 3 1/2"TJ. Pass. (7) UPR, 3 1/2"TJ, Choke HCR. Pass. (8)Manual Choke. Pass. Draw down test:start 2900/end 1700/15 secs-200 psi/full recovery 90 secs. 4 N2=2100 psi 23:00 00:00 1.00 COMPZ RPEQP1 MPSP P PJSM on RU slick line. RU Dutch Riser, RU slick Line retrieving tool. 03/26/2014 Continue to RU slick line. PT lubricator to 1500 PSI. Pulled Junk catcher&CA-2 plug. RD slick line. Circulated hole with 650 BBLS of 9.6 brine. Flow check.. POOH with current completion to 2500 ft. Set storm Packer. Pressure test. Nipple down BOPE and Tubing spool. Page 1 of 4 Time Logs' Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 03:30 3.50 0 1,913 COMPZ RPEQP1MPSP P Continue RU HES slick-line retrieving tool. Install lubricator and test to 1500 psi. Good test. RIH from surface to 1913'. Retrieve prong. POOH to surface. RIH with retrieving tool to 1,913. Latch CA-2 plug. IA at 0. POOH to surface. Lay down plug. RD slick line tools and equipment. 03:30 05:30 2.00 0 0 COMPZ RPCOM RTWH P PJSM-M/U Hanger retrieving spear. RU Baker double grab,3 1/2" spear,tools and equipment. Sting in below hanger 7'. Observed 130p si on OA. Fluid U-tubing between 9.6 ppg brine in tubing and 6.8 ppg freeze protect in annulus. Bleed down to 0. BOLDS. P/U on tubing string.80K-Hanger, 120k initial pull. 115K-String. RD spear, hanger. 05:30 09:30 4.00 0 0 COMPZ RPCOM CIRC P Prep to circulate. Established circulation conventional @ 5 BPM @ 970 PSI circulated 612 BBLS of 9.6 #brine. 09:30 10:00 0.50 0 COMPZ RPCOM OWFF P Monitor well for flow. 10:00 20:00 10.00 8,721 2,520 COMPZ RPCOM PULL P POOH with production string. Laying it down and tally. Recovered 33 bands above SSSV. 20:00 21:30 1.50 2,520 2,520 COMPZ RPCOM MPSP P PJSM. P/U Storm packer and RIH to 105'. PT to 2500 psi. Test 7' casing to 85%of burst rating for 10 min. Good test. 21:30 00:00 2.50 2,520 2,520 COMPZ WHDBO NUND P PJSM. Flow check. Static. N/D BOPE. N/DN Tubing head. 03/27/2014 Continue N/DN tubing spool. Install new IC pack-off. NU new tubing spool. NU BOPE. Retrieve storm packer. Lay down remaining 3.5"tubing.Off-load tubing from pipeshed. RU and RIH with 7'scraper to top of tubing stub. Circulate stub clean. POOH with 7"scraper from 8,721'to 7,645'. 00:00 01:00 1.00 2,520 2,520 COMPZ WHDBO NUND P Continue N/DN tubing head. R/UP PESI equipment. 7"casing stub measurement=7 3/16". BOLDS. No growth measured or observed on stub. R/DN PESI. 01:00 03:00 2.00 2,520 2,520 COMPZ WHDBO RTWH P Remove IC pack-off and install with new. Install FMC Gen 5,11'5k top flange top x 11"3k bottom flange tubing head. RILDS.Test pack-off void to 3k. Good test. 03:00 06:00 3.00 2,520 2,520 COMPZ WHDBO NUND P PJSM. NU BOPE to tubing head. Set test plug and pressure test wellhead breaks and perform shell test,250/3000 psi. Lay down test plug. Page 2 of 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 2,520 2,520 COMPZ RPCOM MPSP P PJSM. P/U Storm packer retrieving tool and RIH to 105'. Unseat and retrieve. POOH with storm packer, Had to rotate packer thru new tubing spool.Laid down tools and equipment. 09:00 13:00 4.00 2,520 0 COMPZ RPCOM PULL P continue to POOH with production equipment.Cut is clean. Kick out production equipment. TOP of stump @ 8743.39 ft. 13:00 21:00 8.00 0 8,718 COMPZ RPCOM PULD P PU BHA#2 Scraper assembly.& pick up RIH with 3.5"L-80 EUE 8rd AB-M from surface to 8,718'. Obtain parameters, PU 100k, SO 85k. 21:00 21:30 0.50 8,718 8,725 COMPZ RPCOM CIRC P Circulate 2 BPM at 100 psi. Slack- off to observe pressure increase. Locate top of cut tubing stub at _8,726'. Repeat process to verify. 21:30 22:30 1.00 8,725 8,721 COMPZ RPCOM CIRC P PU to 8,721'and reverse circulate at 8 BPM, ICP 1,340 psi, FCP 1,200 psi. Circulate clean, 3x bottoms up. Total 243 BBLS. 22:30 23:00 0.50 8,721 8,721 COMPZ RPCOM OWFF P Flow check,static. Fill trip tank, blow down top drive. 23:00 00:00 1.00 8,721 7,645 COMPZ RPCOM TRIP P PJSM. POOH from 8,720'to 7,645' . Racking back tubing in derrick. PU 100k to 8,000',95k to 7,645'. 03/28/2014 Continue POOH with BHA#2 scraper run. R/UP and RIH with 3.5"completion and No-go overshot to 8,731'. R/UP and circulate/spot 152 bbls corrosion inhibited brine.to 4,400". Followed by 44 bbls of untreated. R/UP and set packer at 8,664'.Test packer and IA. Shear seals from PBR. Perform space out. M/UP tubing hanger and land in well head while engaging seals into PBR. R/UP lines and pressure test tubing and casing.Back out landing joint,set BPV. Flush BOPE. N/DN BOPE. 00:00 03:30 3.50 7,645 0 COMPZ RPCOM TRIP P Continue POOH from 7,645'to Surface' . Racking back tubing in derrick.Lay down BHA#2. Off load BOT. 03:30 06:00 2.50 0 970 COMPZ RPCOM RCST P PJSM. RU and RIH with 3.5" completion, 06:00 11:30 5.50 970 8,738 COMPZ RPCOM RCST P continue to RIH with completion No Go over shot @ 8731'with overshot tail @ 8738 11:30 13:00 1.50 8,730 8,730 COMPZ RPCOM CIRC P Ru to circulate and spot 152 BBLS CRW 132 treated 9.6 Brine to 4400 ft and displace with 44 BBLS untreated @ 3 BPM @ 250 PSI. 13:00 14:30 1.50 8,730 8,730 COMPZ RPCOM PACK P Ru to set Baker FHL 7"26#packer @ 8664 ft. Pressured up on packer to 2500 psi. held for 10 Min,s. bled pressure down to 1150 psi. PT IA/ packer to 1650 psi for 10 mins. Good test.shear Seals from PBR. 14:30 16:00 1.50 8,730 8,730 COMPZ RPCOM HOSO P Lay down setting jt. Space out tubing. install hanger. Up wt. = 100K Dn wt.=83K engage centrifugal and ease seals into PBR. Shut down pump. Drain stack. Land hanger with 7 ft of seal out of PBR. Page 3 of 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 18:00 2.00 '8,730 8,730 COMPZ RPCOM OTHR P RU lines to PT tubing&casing on chart. PT tubing to 3000 PSI fpor 15 min's.bled off to 1500 psi. PT IA to 2500 psi for 30 min's. Shear SOV @ 2100 psi. 18:00 19:00 1.00 8,730 8,730 COMPZ WHDBO PRTS P PJSM. Back out landing joint. Install BPV. Pressure test IA to 1000 psi from below. Bled IA to 0. 19:00 21:00 2.00 8,730 8,730 COMPZ WHDBO WWWH P Wash out BOPE and well head. Flush and drain all lines. 21:00 00:00 3.00 8,730 8,730 COMPZ WHDBO NUND P PJSM. Change out lower pipe rams to 2 7/8"x 5"VBR's. N/D BOPE. X3/29/2014 Test tree,250/5000 psi. passed. Freeze protected well to 2000 ft with Diesel.Secured well. RDMO. Rig released @ 10:00 hrs. 00:00 02:30 2.50 8,730 8,730 COMPZ WHDBO NUND P N/UP adapter and tree. 02:30 03:00 0.50 COMPZ WHDBO OTHR P Test tubing hanger pack-offs. 250/5000 psi. Good test. 03:00 03:30 0.50 COMPZ WHDBO SEQP P Set TWC. 03:30 04:30 1.00 COMPZ WHDBO OTHR P Test Tree.250/5000 psi. 04:30 05:00 0.50 COMPZ WHDBO SEQP P Pull TWC. 05:00 09:00 4.00 COMPZ WHDBO FRZP P PJSM. RU LRS and reverse circulate 76 bbls of diesel to freeze protect well down to 2,168'.Allow to U-Tube. 09:00 10:00 1.00 DEMOB MOVE DMOB P Secured well RDMO. Rig released @ 10:00 Page 4 of 4 1C-0- )ST RIG WELL WORK SUMMARY DATE SUMMARY 4/1/2014 ASSIST VLV CREW IN PULLING BPV; PULLED SOV&SET OV @ 4721' RKB; PULLED DV&SET GLV @ 2827' RKB; MIT TBG 2500 ( PASS) IN PROGRESS. 4/2/2014 PULLED BALL& ROD/RHC PLUG BODY @ 8667' RKB; PULLED JUNK CATCHER&WRP @ 8807' RKB; DRIFT TBG W/2.25" BAILER TO LINER TOP @ 8820' RKB. JOB COMPLETE. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 + ti . , RE: Plug Setting Record: 1C-07 ! r. ` ' Run Date: 7/26/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C-07A Digital Data in LAS format, Digital Log Image file l c( , l0 8 1 CD Rom 50- 029 - 2056930 0( PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. . Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 -273 -3535 klinton.wood @halliburton.com Date: Signed: V 611 2 C - O. Vi . • • ConocoPhillips Alaska F P.O. BOX 100360 P it `+ # ' - -- ANCHORAGE, ALASKA 99510 -0360 JAN 0 .4 2011 December 30 2010 ` ' . a a, n* 2 G'" Cart& CT Sion ICA -die Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 JAN 4 2011 Anchorage, AK 99501 0 Commissioner Dan Seamount: 1 C — 0 7 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 September 8 2010 and the corrosion inhibitor /sealant was pumped December 21 22 23 24 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. Sincerely, Perry Klein ' ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 12/30/2010 1C, 1E, 1F, 1G & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal (e „--1C-07A 50029205690100 2090290 3'2" n/a 32" n/a 4.3 12/23/2010 1E-09 50029207200000 1820280 13' 1.00 13" 09/08/2010 3.8 12/22/2010 1E-15A 50029207690100 2100130 3'9" n/a 3'9" n/a 11.6 12/22/2010 1 E -16 50029207770000 1821100 4' n/a 4' n/a 13.7 12/22/2010 1E-17 50029207930000 1821160 3'11" n/a 3'11" n/a 8.5 12/24/2010 1F -13 50029210200000 1831440 6" n/a 6" n/a 3 12/23/2010 1F:17 50029226570000 1960470 SF n/a 18" n/a 7.65 12/23/2010 1F-20 50029226610000 1960530 6" n/a 20" n/a 6.1 12/23/2010 1G -13 50029210160000 1831400 13'10" 1.50 30" 09/08/2010 2.5 12/24/2010 1Y -01 50029209330000 1830500 SF n/a 6" n/a 1.9 12/21/2010 1Y -03 50029209430000 1830610 SF n/a 6" n/a 1.7 12/21/2010 1Y-04 50029209480000 1830660 SF n/a 6" n/a 1.7 12/21/2010 1Y-11 50029209260000 1830410 9" n/a 9" n/a 2.6 12/21/2010 1Y-12 50029209130000 1830260 4' n/a 4' n/a 8 12/21/2010 1Y-13 50029209030000 1830150 15" n/a 15" n/a 1.7 12/21/2010 1Y-14 50029209100000 1830230 24" n/a 24" n/a 1.7 12/21/2010 1Y-16 50029209270000 1830420 12" n/a 12" n/a 1.7 12/21 /2010