The URL can be used to link to this page

Home My WebLink About183-110MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2X-06 KUPARUK RIV UNIT 2X-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 2X-06 50-029-20988-00-00 183-110-0 W SPT 5636 1831100 1500 2840 2840 2840 2840 543 627 623 614 4YRTST P Brian Bixby 6/3/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2X-06 Inspection Date: Tubing OA Packer Depth 1000 1800 1760 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607073902 BBL Pumped:0.7 BBL Returned:0.6 Wednesday, July 26, 2023 Page 1 of 1          MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission g IJ q 716'? TO: Jim Regg 1 6' �2J DATE: Thursday, July 25, 2019 t 1 P.I. Supervisor le 1 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2X-06 FROM: Jeff Jones KUPARUK RIV UNIT 2X-06 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprv' NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2X-06 Insp Num: mitJJ190725103041 Rel Insp Num: API Well Number 50-029-20988-00-00 Inspector Name: Jeff Jones Permit Number: 183-110-0 Inspection Date: 6/2/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2X-06 Type Inj w -TVD 5636 --.Tubing_. 2700 - 2700 - 2700 - 2700 - PTD 1831100 Type Test sPT Test psi 1500 IA 630 2010. 1080 1990. - BBL Pumped: 1.1 - BBL Returned: 1-1 OA 195 318 3'o - ='r Interval .——...-- 4vRTSF I P/F p --- - --- Notes: I well inspected, no exceptions noted. Thursday, July 25, 2019 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,December 03,2015 P.I.Supervisor ` p Z Ict'IG SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2X-06 FROM: Matt Herrera KUPARUK RIV UNIT 2X-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2X-06 API Well Number 50-029-20988-00-00 Inspector Name: Matt Herrera Permit Number: 183-110-0 Inspection Date: 11/29/2015 Insp Num: mitMFH151130101823 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2X-06 - Type Inj W TVD 5636 Tubing 1780 • 1785 1770 • 1780 • PTD 1831100 , Type Test SPT Test psi 1500 • IA 1009 2609 • 2557 ' 2543 Interval 4YRTST P/F P ✓ OA 117 250 - 248 - 239 • Notes: IA tested to 2600 PSI Per CPAI Rep - SCANNED SEP 16 2016' Thursday,December 03,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 16,2015 TO: Jim Regg P.I.Supervisor (Re11 qt 7(,S SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 2X-06 FROM: Johnnie Hill KUPARUK RIV UNIT 2X-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry jig,42--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2X-06 API Well Number 50-029-20988-00-00 Inspector Name: Johnnie Hill Permit Number: 183-110-0 Inspection Date: 6/10/2015 Insp Num: mitJWH150612060515 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 2X-06 • (Type Inj j N-TVD 5636 , Tubing 490 500 - 500' 500 - PTD' 1831100 ' Type Test SPT Test psi, 1500 IA 921 1810 - 1779 - 1774 Interval 4YRTST - PAF P OA 22 23 , 24 23 Notes: 0 7bbls diesel - SCANNED JUS 13 nI`, Tuesday,June 16,2015 Page 1 of 1 Ima~lProject Well History File' C( 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. _~ ~':',~.~ - ~ ,/_ ~_ Well History File Identifier RESCAN DIGITAL DATA [3 Color items: [3 Diskettes, No. [] Grayscale items: '[] Other, No/Type [] Poor Quality Originals: o Other: NOTES: BY: ~ BREN VINCENT SHERYL MARIA LOWELL Project Proofing · BY: BEVERLY BREN VINCENT~~VlARIA OVERSIZED (Scannable) Scanning Preparation Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) "~]'"': Logs of various kinds [3 Other DATE.'..~,~¢ Is/ LOWELL DATE:~"~ Is/ BY: BEVERLY BR~ SHERYL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: '(~ ¢ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES XNO Stage 2 STAGE 1, PAGE(S) DISCREPANCIES WERE'FOUND: ~v"~YYE'~''- NO (SCANNING IS COMPLETE AT THIS POINT UNLE~ SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScan ned.wpO ■ STATE OF ALASKA EIV ALA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS AUG 0 2 203 1.Operations Performed: Abandon r Repair w ell l✓ Rug Perforations j""' Perforate r Other j'C' Alter Casing r Pull Tubing I Stimulate-Frac r Waiver Time Extension ilth.d Change Approved Program '"'"'Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 183-110 . 3.Address: 6.API Number: Stratigraphic r Service 50-029-20988-00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25645 2X-06 4 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: I Total Depth measured 7675 feet Plugs(measured) 7066 true vertical 6401 feet Junk(measured) 7370, 7450 Effective Depth measured 7550 feet Packer(measured) 6818, 7049 true vertical 6289 feet (true vertical)5636, 5842 Casing Length Size MD ND Burst Collapse CONDUCTOR 72 16 103 103 SURFACE 3277 9.625 3308 2860 PRODUCTION 7613 7 7642 6372 Perforation depth: Measured depth: 6942'-6992',7106-7122',7135'-7164' Satit0 NOV 0 5 2013 True Vertical Depth: 5747'-5792', 5895-5908',5919'-5945' G Tubing(size,grade,MD,and ND) 2.875,J-55, 7075 MD, 5866 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6818 MD and 5636 TVD PACKER-BAKER DB PERMANENT PACKER @ 7049 MD and 5842 TVD NIPPLE-CAMCO TRDP-1A NIPPLE @ 515 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in shut-in Subsequent to operation . shut-in shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory E Development r Service Stratigraphic 16.Well Status after work: Oil r Gas WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG For • GINJ r SUSP r SPLUG 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: 313-302 Contact Ian Toomey @ 263-4773 Email Ian.A.Toomey(pconocophillips.com Printed Name Ian Toomey Title Wells Engineer Si nature Phone:263-4773 Date p --....) A'" yL-f' RBDMS AUG - 8 2013 //5---// Submit Original Only Form 10-404 Revised 10/2012 1 r KUP INJ 2X-06 ConocoPhillips Well Attributes Max Angle&MD TD F1x<iSk.7.i[li;. Wollbore API/UWI Field Name Wellbore Status Intl(°) MD(ftKB) Act Btm(ftKB) 500292098800 KUPARUK RIVER UNIT INJ 43.27 3,400.00 7,675.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ••• Well Confp:-2X-06,8/1/201320725 PM SSSV:TRDP Last WO: 7/6/2013 33.99 8/3/1983 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,238.0 6/19/2013 Rev Reason:WORKOVER,Pull Plug/Catcher osborl 7/26/2013 HANGER,26 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd ill saws. CONDUCTOR 16 15.062 31.0 103.0 103.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 4 SURFACE 95/8 8.835 30.9 3,308.3 2,860.3 40.00 J-55 BTC `° Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd PRODUCTION 7 6.276 29.3 7,642.4 6,371.7 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd TUBING WO 2013 3 1/2 2.992 26.1 6,817.9 5,636.4 9.30 L-80 EUE8rdMOD CONDUCTOR, y Upper 31-103 Completion Details - Top Depth (ND) Top Inc! Nomi... NIPPLE,515 3 Top(ftKB) (ftKB) (°) Item Description Comment ID(in)irk- 26.1 26.1 0.67 HANGER FMC TUBING HANGER 2.992 515.0 515.0 0.78 NIPPLE CAMCO'DS'NIPPLE w/2.875 PROFILE 2.875 6,795.9 5,617.5 28.53 LOCATOR BAKER 80-40 LOCATOR 2.990 6,796.9 5,618.3 28.52 SEAL ASSY BAKER PBR SEAL ASSEMBLY 2.990 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING WO 2013 31/2 2.992 6,817.8 7,051.4 Lower 5,844.7 9.30 L-80 EUE8rdMOD SURFACE, 31-3'308 Completion Details _--7 Top Depth (ND) Top Intl Nomi... GAS LIFT, . Top(ftKB) (ftKB) (°) item Description Comment ID(in) 6,741 _---- -'� 6,817.8 5,636.4 27.02 PACKER BAKER FHL PACKER 2.870 II 6,918.9 5,726.5 26.91 BLAST JT BLAST JOINTS(2) 2.992 6,983.5 5,784.1 26.82 SLEEVE BAKER CMU SLIDING SLEEVE w/DS NIPPLE PROFILE 2.810 II 7,034.0 5,829.2 26.84 LOCATOR BAKER 80-32 LOCATOR SPACED OUT 1'OFF NO GO 2.400 LOCATOR, ------ 7,035.0 5,830.1 26.83 SEAL ASSY BAKER 80-32 SEAL ASSEMBLY w/11'SEALS 2.400 6,796 Tubing Description 'String 0... 'String ID.-'Top(ftKB) 'Set Depth(f...I Set Depth(TVD)...'String Wt...!String._'String Top Thrd SEAL A,797 6,787 -- - TUBING WO 1987 2 7/8 2.441 7,048.7 7,075.6 5,866.3 6.50 J-55 EUE8rdABMOD PACKER,6,818 Completion Details - - Top Depth (TVD) Top Inel Nomi... Top(ftKB' (ftKB) r) Item Description Comment ID(in) 7,048.7 5,842.4 26.80 PACKER BAKER DB PERMANENT PACKER 3.250 7,052.4 5,845.6 26.79 SBE SEAL BORE EXTENSION w2 7/8"XO 2.875 GAS uPT. 7,065.5 5,857.4 26.76 NIPPLE CAMCO D NIPPLE NO GO 2.250 II 6,8]1 7,074.8 5,865.6 26.73 SOS CAMCO SHEAR OUT SUB,TTL ELMD 7068'ON SWS(PROF DATED 2.441 3/4/1987 it Other In Hole(W'reline retrievable plugs,valves,pumps,fish,etc.) Top Depth IPERF, _ (TVD) Top Intl 6,942-6,992 = Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) SLEEVE,6,984 - a 7,370.0 6,129.7 26.85 FISH 28'of bar from Kone Bottom of Hole 12/14/1983 0.000 7,450.0 6,200.9 27.42 FISH 30'Vann Gun Fish Bottom of Hole 9/24/1983 0.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens it Top(ftKB)Bbn(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 6,942.0 6,992.0 5,747.1 5,791.7 C-4,C-3,C-1, 9/24/1983 12.0 IPERF 120 deg.phasing;5"GEO Vann Gun alli UNIT B,2X-06 LOCATOR, 7.034 7,108.0 7,122.0 5,895.3 5,907.8 A-4,2X-06 12/14/1983 4.0 APERF 2 1/8"Kone Gun SEALASSY, 7,135.0 7,164.0 5,919.4 5,945.4 A-3,2X-06 12/13/1983 4.0 APERF Lost 28'of bar in hole;21/8"Kone • 7.035 - Gun r 1 PACKER,7,049 - � Notes:General&Safety :. End Date Annotation r- 1/4/1987 NOTE:WORKOVER 58E,7,052 it 12/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 7262013 NOTE:DEPTH DISCREPANCY for bottom of 2013 WO 8 top of 1987 WO-RIG CHECKING NIPPLE,7,066- 1 • a SOS,7,075 _1 APERF, - Mandrel Details 7,108-7,122 - Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run APERF, N...Top(ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 7,135-7,164 = 1 6,741.4 5,569.8 29.22 CAMCOIKBMG 1 GAS LIFT DMY BK 0.000 0.0 7/17/2013 �p�a,�,.y9.),, 2 6,870.6 5,683.4 26.96 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/5/2013 FISH.7.370 4;,.:...J FISH,7,450 IIIP PRODUCTION, 297,642" TD,7,675 • 2X-08 Pre-Rig Well Work Summa DATE SUMMARY • 5/16/2013 (PRE RWO): T-POT(PASSED); T- PPPOT(PASSED); FT LDS (ALL GOOD); MIT-OA (PASSED)TO 1800 PSI. 6/18/2013 DRIFTED TBG WITH 2.62 LIB; TAGGED WRP @ 6825' RKB. PULLED WRP @ SAME. PULLED CATCHER SUB ON CA-2 PLUG @ 7065' RKB. ATTEMPTED PULL CA-2 PLUG, EST. 1' FILL ON PLUG. IN PROGRESS. 6/19/2013 BAILED FILL OFF CA-2 PLUG @ 7065' RKB. EQUALIZED& PULLED PLUG @ SAME. TAGGED @ 7238' SLM, EST. 110' RATHOLE. MEASURED BHP @ 7064' SLM: 2335 PSI. IN PROGRESS. 6/20/2013 SET 2.25 CA-2 PLUG @ 7065' RKB, SET CATCHER SUB ON PLUG. MEASURED C SAND BHP @ 6931' SLM: 2317 PSI. PULLED DV @ 6800' RKB. COMPLETE. • • ConocoPhillips Time Log & Summary We,Nfew.Web Reporting Report Well Name: 2X-06 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/28/2013 7:30:00 AM Rig Release: 7/6/2013 12:00:00 AM g ply Date m Code ii T. Corn-mht -igl pl ' 06/27/2013 24 hr summary Move rig off well 31-11,spot sub over well, move complexes t/2X pad. mobilze trucks back t/31 pad f/other complexes. 08:30 08:45 0.25 0 0 MIRU MOVE MOB P PJSM, rigging down for move. 08:45 10:15 1.50 0 0 MIRU MOVE MOB P Prep rig for move. 10:15 10:30 0.25 0 0 MIRU MOVE MOB P PJSM with truck drivers, Move modules. 10:30 12:00 1.50 0 0 MIRU MOVE MOB P Jack up pipe sheds and rock washer. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Move rock washer&pipe sheds, Move pits motors&boiler complex away from sub, Move sub&pipe sheds pits&pump room complexs t/ 2X pad. Spot sub over well. 06/28/2013 Work on rig acceptance check list,Accept rig(07:30), RU tiger tank&hard line, kill well w/8.6ppg sea water, N/D tree, N/U BOPE. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P PJSM, Mobilize power pack to 2X pad 02:00 05:00 3.00 0 0 MIRU MOVE MOB P Spot power pack, pipesheds and rockwasher. 05:00 07:00 2.00 0 0 MIRU MOVE MOB P Work on rig acceptance check list. 07:00 12:00 5.00 0 0 MIRU MOVE RURD P R/U scaffolding and tiger tank. SIMOPS take on 8.7 brine,water back to 8.6 ppg. R/U lines in cellar to kill well. (Wait on FMC)(RIG ACCEPTED 0730) 12:00 12:30 0.50 0 0 MIRU MOVE RURD P PJSM,flood high pressure lines to tiger tank and test to 2500 psi. 12:30 15:30 3.00 0 0 MIRU WHDBO RURD P PJSM, R/U lubricator test to 1000 psi for 5 min. (Good)Function lubricator and noticed hydraulic oil leaking around connection. R/D lubricator and tighten leak. R/U lubricator retest to 1000 psi and function hydraulics(good). Pull BPV as per FMC rep.Tubing pressure= 350 psi.R/D lubricator. 15:30 15:45 0.25 0 0 MIRU WELCTL SFTY P PJSM on displacing well. 15:45 17:45 2.00 0 0 MIRU WELCTL KLWL P Displacing well to 8.6 ppg seawater. pupm 265 bbls 17:45 18:15 0.50 0 0 MIRU WELCTL OWFF P Monitor well. Page'[of To" � , � h I �'. Date From :.To Dur° ��S.Depth E.Depth Phase z"'Code Subcoae T Comment 18:15 19:30 1.25 0 0 MIRU WHDBO PRTS P Set BPV and attempt to test to 1000 psi,well would not pressure up, pumped 5 bbls pressured up to 75 psi decision was made to R/D scaffolding and M/D tree. 19:30 20:15 0.75 0 0 MIRU WHDBO RURD P PJSM, R/D scaffolding. 20:15 21:15 1.00 0 0 MIRU WHDBO NUND P Nipple down tree, install blanking plug. 21:15 00:00 2.75 0 0 MIRU WHDBO NUND P Nipple up BOP stack,extend bell _nipple/riser 06/29/2013 R/U for BOPE test,test BOPE,fix annular solenoid, Pull hanger unable t/pull free,Work string unable to pull,call eline, R/U&P/U 4" DP via mouse hole. 00:00 05:00 5.00 0 0 MIRU WHDBO RURD P R/U to test BOPE,SIMOPS extend bell nipple,trouble shoot gaitronics, strap/rabbit tubing. Monitor well through trip tank while waiting on Stat of Alaska rep. 05:00 09:30 4.50 0 0 MIRU WHDBO BOPE P Test BOPE 250/3000 psi for 5 min each w/4"&3.5"test joint.test top pipe rams, manual killl line valve, C.V.#1,#12,#13,#14. Upper IBOP, C.V.#9,#11. Lower IBOP C.V.#5, #8,#10. Dart Valve, C.V.#4,#6,#7. Floor valve, C.V.#2. HCR Choke,4" Kill Demco valve. Manual choke valve.Annular preventer. Blind rams, C.V.#3.Accumulator test:system pressure 2950 psi, pressure after close= 1650 psi,200 psi attained= 45 sec,full pressure attained=207 sec.5 bottle avg=2000 psi. C.V.#5 failed, repacked and retested(Good) test witnessed by State of Alaska rep John Crisp. 09:30 12:00 2.50 0 0 MIRU WHDBO BOPE T Trouble shoot and repair Koomey pressure solenoid for annular. 12:00 13:30 1.50 0 0 MIRU WHDBO BOPE T PJSM,troubleshoot and repair Koomey pressure solenoid for annular. 13:30 15:00 1.50 0 0 MIRU WHDBO BOPE P PJSM,test BOPE w/3.5"test joint to 250/3000 psi for 5 min eac,tested annular and top pipe rams. 15:00 15:30 0.50 0 0 MIRU WHDBO RURD P PJSM, R/D Test eqpt. 15:30 17:15 1.75 0 0 COMPZ RPCOM RURD P PJSM, R/U Casing eqpt to pull hanger(SIMOPS Monitor well) (Static) 17:15 18:00 0.75 0 0 COMPZ RPCOM RURD P Pull BPV, R/U Landing joint. 18:00 18:15 0.25 0 0 COMPZ RPCOM THGR P Back out lock downs. 18:15 21:00 2.75 0 0 COMPZ RPCOM PULL P Attempt to pull hanger to floor with no success,work pipe w/Max pull 114k on tubing, Decision was made to call e-line. 21:00 22:30 1.50 0 0 COMPZ RPCOM PULL P UD pup joint, R/U f/Eline Page 2 of 8 r i i Time i, 41,0110,0„, : Logs , Date o From .To t Dur .S.DeotlitE.,Depth Phase' Code Subcode T ComMent Comment 10- -. 11091 22:30 23:15 0.75 0 0 COMPZ RPCOM RURD P PJSM, R/U to P/U Drill Pipe 23:15 00:00 0.75 0 0 COMPZ RPCOM PULD P P/U 4" Drill Pipe Via Mouse Hole 36/30/2013 P/U drill pipe, R/U&RIH w/Eline string shot,fire string shot @ 6844'POOH,Attempt t/pull on tubing unsuccessful, RIH w/2.5 RCT cut tubing @ 6825' POOH, R/D eline R/U&CBU, R/U tubing equip. Pull hanger t/floor. 00:00 04:45 4.75 0 0 COMPZ RPCOM PULD P PJSM, P/U 4"XT-39 Drill pipe through mouse hole while waiting on Eline. 04:45 05:00 0.25 0 0 COMPZ RPCOM RURD P Clear rig floor. 05:00 05:30 0.50 0 0 COMPZ RPCOM SVRG P Service rig. 05:30 09:30 4.00 0 0 COMPZ RPCOM RURD P Spot Halliburton trucks and prep tools for P/U. SIMOPS P/U 3 stands of collars. M/U X-O tubing and set 20 k tension on tubing string. 09:30 11:30 2.00 0 0 COMPZ RPCOM PULD P PJSM, P/U and M/U wireline. 11:30 12:00 0.50 0 0 COMPZ RPCOM ELNE P RIH w/string shot on wireline as per Halliburton rep. 12:00 12:45 0.75 0 0 COMPZ RPCOM ELNE P PJSM, RIH w/string shot,fire string shot. 12:45 13:30 0.75 0 0 COMPZ RPCOM ELNE P Fire string shot @ 6844'MD. POOH w/Eline. 13:30 14:15 0.75 0 0 COMPZ RPCOM RURD P PJSM, R/D Eline to pull on string. 14:15 14:30 0.25 0 0 COMPZ RPCOM PULL P Pulled on string several times to max of 155k, including block weight of 35k,with no success. 14:30 17:00 2.50 0 0 COMPZ RPCOM RURD P PJSM, R/D string shot tools in cellar and R/U 2.5"RCT cutter. 17:00 17:45 0.75 0 6,825 COMPZ RPCOM ELNE P RIH w/Eline RCT cutter,cut at 6825' MD. 17:45 18:45 1.00 6,825 6,825 COMPZ RPCOM ELNE P POOH w/Eline. 18:45 19:45 1.00 6,825 6,800 COMPZ RPCOM RURD P PJSM, R/D Eline pull on tubing. P/U weight=85k, S/O weight=68k confirming good cut. 19:45 21:00 1.25 6,800 6,800 COMPZ RPCOM RURD P Continue to R/D Eline. 21:00 21:30 0.50 6,800 6,800 COMPZ RPCOM RURD P PJSM, L/D hanger and R/U to Circulate. 21:30 23:00 1.50 6,800 6,800 COMPZ RPCOM CIRC P Circulate Bottoms Up spot Hi Vis pill on bottom @4bpm. SPRs @ 6800 MD, MW-8.6 ppg time 22:00.#1 -30 SPM=220 psi,40 SPM=400 psi. #2-30 SPM=220 psi,40 SPM= 390 psi. 23:00 23:15 0.25 6,800 6,800 COMPZ RPCOM RURD P R/D cement line, R/U to L/D tubing. 23:15 23:30 0.25 6,800 6,800 COMPZ RPCOM OWFF P PJSM, L/D tubing,SIMOPS monitor well(STATIC). 23:30 00:00 0.50 6,800 6,800 COMPZ RPCOM RURD P Install stripping rubber and air slips. 07/01/2013 L/D 3.5"tubing string., P/U Fishing Assy.#1, RIH to engage fish @ 6825'MD, Engage fish,Jar fish loose, 10 k Over pull on string wt. POOH LID Fishing Assy.&Retrieve lower completion packer&seals, Fish total length 288.13'Clear floor. Page 3 of ft Time Logs„r ^*y v,, b. x it ,,, 11 Date From' To Dui- S.Death gEr,Death Phase Code . iTI Comri'�reht ... 00:00 03:30 3.50 6,800 5,000 COMPZ RPCOM PULL P PJSM, L/D tubing and control line. (32 bands) 03:30 03:45 0.25 5,000 0 COMPZ RPCOM PULL P Disconnect control line and L/D SSSV. 03:45 06:30 2.75 0 0 COMPZ RPCOM PULL P L/D 3.5"tubing. (215 jts+cutjt.) (6825.89')Act fill=25.16 bbls,calc fill=23.94 bbls. 06:30 07:15 0.75 0 0 COMPZ RPCOM RURD P R/D power tongs,safety valve and clean and clear floor. 07:15 07:30 0.25 0 0 COMPZ RPCOM RURD P R/U to test lower rams. 07:30 08:30 1.00 0 0 COMPZ RPCOM BOPE P Test 2.875"x5"lower Rams w/4"and 3.5"test joint to 250/3000 psi for 5 min each. 08:30 09:00 0.50 0 0 COMPZ RPCOM RURD P R/D test eqpt,drain stac, install 6.1875"wear bushing. 09:00 10:30 1.50 0 303 COMPZ RPCOM PULD P PJSM, M/U BHA#1 Overshot 3.5" grapple and 3 stds of collars. 10:30 10:45 0.25 303 681 COMPZ RPCOM TRIP P Single in hole 12 jts.4"drill pipe from 303'to 681'MD. 10:45 12:00 1.25 681 1,720 COMPZ RPCOM TRIP P RIH from 681'MD to 1720'MD. 12:00 13:30 1.50 1,720 6,716 COMPZ RPCOM TRIP P Continue RIH to 6716'MD 13:30 14:30 1.00 6,817 6,800 COMPZ RPCOM FISH P Wash down from 6716'MD to 6811' MD @ 1.5bpm= 110 psi, P/U wt 142k, S/0 wt 98k, rot.wt 116k,wash do from 6811'MD to 6817'MD,saw 100 psi increase in pressure indicating swallowing fish,shut down pump, bleed off pressure,set down 10k, P/U to 180k indicating latched on to fish,start jarring @ 180k staging up to 230k,fish pulled free @245k,jarred 8 times total. (New P/U wt 155k, S/O wt 103k) 14:30 16:00 1.50 6,800 6,800 COMPZ RPCOM CIRC P Pull up to 6800' MD,CBU @ 3 bpm =250 psi. @ bottoms up saw some gas,continued to circ gas out. SPRs @6800'MD TVD=5888'MW=8.6ppg, time 1500.#1 30 SPM=220 psi,40 SPM=330 psi.#2 30 spm=290 psi,40 SPM=380 psi. 16:00 16:15 0.25 6,800 6,800 COMPZ RPCOM OWFF P Monitor well(STATIC) 16:15 20:00 3.75 6,800 325 COMPZ RPCOM TRIP P PJSM, POOH form 6800'MD to 325' MD. 20:00 20:15 0.25 325 325 COMPZ RPCOM OWFF P Monitor well(STATIC) 20:15 20:45 0.50 325 0 COMPZ RPCOM PULD P S/B Collars 20:45 23:00 2.25 0 0 COMPZ RPCOM PULD P L/D Fishing tools, L/D Fish(Packer, Gas Lift, 3 jts,3 blast jts,seal assy w/locator) 23:00 23:30 0.50 0 0 COMPZ RPCOM PULD P P/U Overshot and L/D fish. 288.13'of fish recovered. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. Page 4 of 8 • W �. Time Logs iy 1,' wt Datefl-'" From.'To DUr S.Depth Sobcode T r Comment. -"I'Ile. Ile, 07/02/2013 24 hr Summary M/U&RIH w/3.5 Lower completion t/7040'take wt.work string t/7043'pressure test seals t/500 psi seals held,spot Inhibited brine,Attempt t/engage seals, unable t/sting into PBR, Slip cut drilling line, POOH w/ 3.5 completion, L/D, P/U clean out Assy. RIH t/6077' 00:00 00:30 0.50 0 0 COMPZ RPCOM OTHR P Clean&Clear rig floor 00:30 01:00 0.50 0 0 COMPZ RPCOM RURD P R/U power tongs&set wear ring. 01:00 02:15 1.25 0 255 COMPZ RPCOM PULD P M/U lower completion as per detail. 02:15 02:45 0.50 255 255 COMPZ RPCOM RURD P R/D tubing equipment, R/U t/run 4" DP 02:45 06:30 3.75 255 7,040 COMPZ RPCOM TRIP P RIH on 4"DP f/255't/7040' 06:30 06:45 0.25 7,040 7,043 COMPZ RPCOM WASH P Attepmt t/wash down pumps @ 1 bpm taking wt. up t/10k falling off pressure up,shut down pump bleed off pressure.Work string t/7043'. 06:45 08:30 1.75 7,043 7,043 COMPZ RPCOM OTHR P Double check tally,discuss options w/engineer. 08:30 09:15 0.75 7,043 7,043 COMPZ RPCOM PRTS P Pressure up tubing U 500 psi check seals,seals good,bleed off pressure. 09:15 10:00 0.75 7,043 7,040 COMPZ RPCOM CIRC P P/U unsting f/seals spot corrosion inhibited brine on back side around seals&packer. 10:00 11:30 1.50 7,040 7,040 COMPZ RPCOM OTHR P Attempt t/land on seals unable to locate into PBR,Work string apply wraps to orient mule shoe unable to locate. 11:30 12:00 0.50 7,040 7,040 COMPZ RPCOM OWFF P Observe well for flow well static. 12:00 12:30 0.50 7,040 6,945 COMPZ RPCOM RURD P Stand back stand R/U U slip&cut drilling line. 12:30 13:30 1.00 6,945 6,945 COMPZ RPCOM SLPC P Slip&cut drilling line 59' 13:30 14:00 0.50 6,945 6,945 COMPZ RPCOM SVRG P Service Rig 14:00 17:00 3.00 6,945 345 COMPZ RPCOM TRIP P POOH w/lower completion f/6945'U 345' 17:00 17:15 0.25 345 345 COMPZ RPCOM OWFF P Observe well f/flow well static. 17:15 18:30 1.25 345 0 COMPZ RPCOM PULD P UD Lower completion,seal assy. was missing seals and showed damage to mule shoe. 18:30 19:00 0.50 0 0 COMPZ RPCOM OTHR P Clean&clear rig floor. 19:00 21:15 2.25 325 325 COMPZ RPCOM PULD P P/U&M/U BHA#2 clean out Assy. 21:15 00:00 2.75 325 6,077 COMPZ RPCOM TRIP P RIH w/clean out BHA#2 on 4"dp f/ 325'U 6077' 07/03/2013 Finish RIH w/lower completion,Spot Inhibited brine,space out in PBR, Set packer,test tubing&casing U 3000 psi f/30 min,shear PBR, POOH U 1700'M/U storm packer test U 1500 psi, Nipple down stack, Bleed OA pressure off. 00:00 00:15 0.25 6,077 6,737 COMPZ RPCOM TRIP P RIH w/clean out BHA f/6077'U 6737' Page 5 of 8 • Time Logs. , ,,Z ,I' :i ri�� ` i i � Date From To Dur S. Death E. DeothhPhase Code Subcdde T� Commen 00:15 02:15 2.00 6,737 7,044 COMPZ RPCOM WASH P wash down f/6737't/6942'w/294 gpm 700 psi, 5-10k WOB t/wash down 6942 t/6992',work through perferations 3 times,sand returns @ bottoms up,Wash down f/6992't/ 7038'Tag top of packer @ 7038'w/ crossover observe presure increase, P/U 1'mule shoe @ 7044'Circ. bottoms up,sand observed at bottoms up, circ till hole clean. 02:15 03:00 0.75 7,044 7,044 COMPZ RPCOM CIRC P Pump hi vis sweep @ 336 gpm 950 psi sand observed at bottoms up circ till clean. 03:00 03:15 0.25 7,044 6,927 COMPZ RPCOM TRIP P Tag top of packer @ 7038'POOH t/ 6927' 03:15 03:45 0.50 6,927 6,927 COMPZ RPCOM OWFF P Observe well for flow well static 03:45 06:00 2.25 6,927 325 COMPZ RPCOM TRIP P POOH f/6927't/325' 06:00 06:15 0.25 325 325 COMPZ RPCOM OWFF P Observe well for flow well static 06:15 07:15 1.00 325 0 COMPZ RPCOM PULD P Rack back collars L/D clean out BHA. 07:15 07:45 0.50 0 0 COMPZ RPCOM OTHR P Clean&Clear floor. 07:45 08:15 0.50 0 0 COMPZ RPCOM RURD P R/U to run lower completion. 08:15 09:15 1.00 0 250 COMPZ RPCOM RCST P M/U run lower completion. 09:15 12:00 2.75 250 4,491 COMPZ RPCOM RCST P RIH w/lower completion on 4"DP f/ 250't/4491' 12:00 12:45 0.75 4,491 6,946 COMPZ RPCOM RCST P RIH w/lower completion on 4"DP f/ 4491't/6946' 12:45 13:30 0.75 6,946 7,030 COMPZ RPCOM RCST P Wash down @ 1 bpm 100 psi @ 7032 confirm seals engage, bleed off psi locate on packer @ 7038'pull out of seals. 13:30 14:15 0.75 7,030 7,030 COMPZ RPCOM CIRC P Spot corrosion inhbited brine @ 3 bpm 210 psi. 14:15 15:00 0.75 7,030 7,038 COMPZ RPCOM RCST P Run in and locate on no go on packer @ 7038'space out 1'off nogo,pressure up t/1700 psi set packer, presure up t/3000 psi test t/ 3000 psi f/30 min. 15:00 15:30 0.50 7,038 7,038 COMPZ RPCOM PRTS P Pressure up on IA t/3000 psi f/30 min. 15:30 16:00 0.50 7,038 6,760 COMPZ RPCOM PACK P Shear out of PBR, R/D circ. equipment. 16:00 17:45 1.75 6,760 1,700 COMPZ RPCOM TRIP P POOH f/6760't/1700' 17:45 19:00 1.25 1,700 1,700 COMPZ RPCOM PACK P P/U storm packer set&test t/1500 psi f/10 min 19:00 19:15 0.25 1,700 1,700 COMPZ RPCOM SFTY P Pre Job safety meeting on Nippling down stack 19:15 20:30 1.25 1,700 1,700 COMPZ RPCOM NUND P Nipple down stack, rack back. 20:30 00:00 3.50 1,700 1,700 COMPZ RPCOM OTHR P Bleed off OA t/tiger tank and bleed trailer. Page 6of8 Tin ., a � gar �i a. ai,1 ge Logs a fir,.. 6i Date From To roDur,4,, S.Depth E.Depth Phase Code "Subcode T Comment - `,1 37/04/2013 24 hr Summary N/D tubing spool, Problelms backing out lock downs, R/U hydro-tight grow csaing 18.75", P/U spear&spear casing pull 55k tension set emergency slips, R/U WACHS cutter cut casing, C/O tubing spool and packoff, N/U BOP stack&test breaks, Pull storm packer&4" DP, R/U&run 3.5"tubing t/2100' 00:00 01:00 1.00 1,700 1,700 COMPZ RPCOM OWFF P Bleed off OA t/tiger tank,confirm no pressure on annulus f/30 min w/ gauge. 01:00 12:00 11.00 1,700 1,700 COMPZ RPCOM NUND P N/D tubing spool,change out pack off as per FMC rep, problems backing out lock downs, round up wellhead equipment,decision made t/rig up hydrotight tool t/grow casing, R/U&grow casing 18.75" set emergency slips. 12:00 12:15 0.25 1,700 1,700 COMPZ RPCOM SFTY P Pre Job Safety meeting meetin on R/D Hydratight 12:15 12:30 0.25 1,700 1,700 COMPZ RPCOM NUND P Remove old tubing spool&clear cellar of equipment. 12:30 14:00 1.50 1,700 1,700 COMPZ RPCOM PULD P P/U 7"casing spear,spear 7"casing &pull 55k in tension, Slack off in emergency slips release spear. 14:00 14:30 0.50 1,700 1,700 COMPZ RPCOM RURD P R/D WACHS cutter&cut 7"casing as per FMC 14:30 15:00 0.50 1,700 1,700 COMPZ RPCOM OTHR P Prep casing stub f/pack off. 15:00 16:15 1.25 1,700 1,700 COMPZ RPCOM NUND P Install pack off, Nipple up tubing spool. 16:15 16:45 0.50 1,700 1,700 COMPZ RPCOM PRTS P Pressure test tubing spool void t/ 250-3000 psi f/10 min 16:45 17:45 1.00 1,700 1,700 COMPZ RPCOM NUND P Nipple up BOPE 17:45 18:45 1.00 1,700 1,700 COMPZ RPCOM BOPE P R/U&test BOPE breaks on stack& choke line t/250 low 3000 high f/5 min each charted. 18:45 19:30 0.75 1,700 1,700 COMPZ RPCOM TRIP P P/U stand RIH M/U t/storm packer POOH LID storm packer. 19:30 20:15 0.75 1,700 0 COMPZ RPCOM TRIP P POOH f/1700't/seal assy. 20:15 21:15 1.00 0 0 COMPZ RPCOM RURD P R/U t/run 3.5 completion. 21:15 21:30 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on running Upper completion. 21:30 00:00 2.50 0 2,100 COMPZ RPCOM RCST P Run upper 3.5"completion as per detail U 2100' 37/05/2013 Finish running 3.5 completion,space out,displace well t/inhibited brine, land on hanger spaced out 3'off NoGo,Test tubing t/3500 psi f/30 min,test ann.t/3000 psi f/30 min. N/D stack N/U tree&test, Freeze protect well w/75 bbls diesel allow t/U-Tube, LID 4"Dp via mouse hole, Realease rig @ 0000 hrs 00:00 03:15 3.25 2,100 6,790 COMPZ RPCOM RCST P RIH w/ 3.5"completion f/2100't/ 6790' 03:15 03:30 0.25 6,790 6,798 COMPZ RPCOM RCST P M/U circ equip. P/U t/6775' establish circ. @ 1 bpm 50 psi,wash down locate PBR,shut down pumps, locate @ 6798', obtain space out numbers. 03:30 04:15 0.75 6,798 6,775 COMPZ RPCOM RCST P UD 3 jts tubing, M/U space out pups 1 jt&hanger w/landing jt. 04:15 05:30 1.25 6,775 6,775 COMPZ RPCOM CIRC P Reverse Circ.225 bbls corrosion Inhibited brine 8.6 ppg @ 3 bpm 250 psi clear lines w/10 bbls brine. Page 7 of 8 J " • TmeLogs ; i' g4 Date 0 , a'"From To Dur ,S�'..Deoth$E.Depth Phase Code` Siibcode T Comment ° o, r 05:30 06:00 0.50 6,775 6,718 COMPZ RPCOM RCST P Prep hanger,drain stack, land on hanger 3'spaced out off locator @ 6718' 06:00 07:45 1.75 6,718 0 COMPZ RPCOM PRTS P Pressure test tubing t/3500 psi f/30 min. bleed off pressure t/2500 psi, pressure test annulus t/3000 psi f/ 30 min. bleed IA&tubing t/0 psi ramp up pressure on annulus t/2800 psi t/ i shear DCK valve 07:45 08:15 0.50 0 0 COMPZ RPCOM OWFF P Observe well for flow f/30 min. well static 08:15 09:00 0.75 0 0 COMPZ RPCOM OTHR P R/D test equipment, back out landing jt, set BPV as per FMC,test BPV in direction of flow t/1000 psi f/10 min. 09:00 09:30 0.50 0 0 COMPZ RPCOM OTHR P Blow down lines. 09:30 09:45 0.25 0 0 COMPZ RPCOM SFTY P Pre Job safety Meeting N/D BOPE 09:45 12:00 2.25 0 0 COMPZ RPCOM NUND P Nipple Down BOPE stack 12:00 12:45 0.75 0 0 COMPZ RPCOM OTHR P FMC prep tree Simops, R/U t/L/D 4" DP 12:45 13:30 0.75 0 0 COMPZ RPCOM NUND P Nipple up tree&install and test seals,t/250/5000 psi f/10 min. 13:30 14:30 1.00 0 0 COMPZ RPCOM PRTS P Pull BPV install tree test plug test tree t/250/5000 psi 14:30 15:30 1.00 0 0 COMPZ RPCOM OTHR P PuIll tree test plug, R/U f/freeze protect 15:30 17:00 1.50 0 0 COMPZ RPCOM FRZP P Test lines t/2500 psi freeze protect well w/75 bbls diesel. 17:00 19:30 2.50 0 0 COMPZ RPCOM PULD P L/D 4" DP via mouse hole, Simops U-Tube tubing&Annulus. 19:30 20:30 1.00 0 0 COMPZ WHDBO OTHR P Install BPV&secure wellhead 20:30 23:00 2.50 0 0 COMPZ RPCOM PULD P L/D 4"DP via mouse hole. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P R/D skate&cattier shutte. Page 8 of 8 2X-06 Post-Rig Well Work Summary DATE SUMMARY 7/17/2013 TAG RHC PLUG @ 6985' RKB WITH 2.78" LIB; SHOWS 2.31" EXTERNAL F/N. PULLED SOV @ 6741' RKB, SET DV @ SAME. MIT IA, PASSED. PULLED RHC PLUG @ 6985' RKB. ATTEMPTED PULL CATCHER ON CA-2 PLUG @ 7066' RKB. EST. 14' FILL. IN PROGRESS. 7/18/2013 BAILED 15'OF MUD, SCALE, METAL& RUBBER TRASH FROM CATCHER ON CA-2 PLUG @ 7066' RKB. PULLED CATCHER, PULLED CA-2 PLUG @ 7066' RKB. COMPLETE. ww � \ I %% 4, THE STATE s a . 11 Gas ®f conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF �. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 N�a yU� 2 2,0a Fax: 907.276.7542 SC'! A� Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 V Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2X -06 Sundry Number: 313 -302 Dear Mr. Toomey: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy P. oerster Chair 5/` DATED this GI day of June, 2013. Encl. STATE OF ALASKA • :07 6/20//3 AC OIL AND GAS CONSERVATION COMMISSION ry �. � '?,. g ; `'� APPLICATION FOR SUNDRY APPROVALS \o . 20 AAC 25.280 i- , Ci i, ~; Cy 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell ' Change Approved Program r Suspend r Plug Perforations f— Perforate r Pull Tubing Time Extension r Operational Shutdow n r Re -enter Susp. Well f— Stimulate r Alter casing r Other: I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fl Exploratory r 183 -110 '' 3. Address: Stratigraphic f Service fr • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20988 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No fir 2X -06 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL -25645 • 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): . 7675 -6401 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 103' 103' SURFACE 3273 9.625 3308' 2860' PRODUCTION 7609 7 7642' 6372' Perforation Depth MD (ft): • Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6942 - 6992,7108- 7122,7135 -7164 5747 - 5792,5895- 5908,5919 -5945 3.5 J - 7075 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP RETRIEVABLE PACKER + MD= 6865 TVD= 5678 PACKER - BAKER DB PERMANENT PACKER ' MD= 7049 TVD= 5842 TRDP -1A - CAMCO Safety Valve < MD =1807 TVD= 1726 12. Attachments: Description Summary of Proposal f✓ • 13. Well Class after proposed work: • Detailed Operations Program 17 • BOP Sketch r Exploratory r Development r Service fir 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/30/2013 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ 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: Ian Toomey Printed Name Ian Toomey Title: Wells Engineer Signature Phone: 263 -4773 Date (o - /7 - /.3 Commission Use Only /� Sundry Number: 3 3 3O t: , Conditions of approval: Notify Commission so that a representative may witness ��.t RBDMS JUN 26 20 . Plug Integrity r BOP Test " Mechanical IntegrityTest h Location Clearance r Other: 3 op 1.-- , r a 3 Z7 U D i, S l , 1 t , 2 C h? ssr NI I T - - l rc�trr c -��r fa �r w ' woski : % 1 Yes 14 sub / d _ ¢r 4 - , r e / ' n Subsequent Form Required: - �unc Pw- k - 1 3 �� ^ � �j APPROVED BY -� ,/ � r Approved by: / �� L COMMISSIONER THE COMMISSION Date: G 3 Form 10 -403 Revis d 1/2010 Submit in Du 'c to '0 VL /J9 /o 30RIGINAL - /g�� (i. • • ' � b ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 17 June 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2X-06 (PTD 183 -110). Well 2X-06 was drilled and completed in August 1985 as an A- and C -sand selective. The well was pre - produced prior to conversion to injection service in November 1985. In January 2010 the well was shut in due to a failing MIT -IA and has remained shut -in ever since. The well has a passing MIT -T above the top packer and a passing MIT -OA. The proposed workover is to pull the existing upper selective, replace the inner casing packoffs, run a new upper selective and a new 3 -1/2" completion. If you have any questions or require any further information, please contact me at 263 -4773 Sincerely, f � Ian Toomey Wells Engineer CPAI Drilling and Wells • • 2X -06 Kuparuk Injector Rig Workover (PTD #: 183 -110) Current Status 2X -06 has been shut -in since January 2010 awaiting a rig workover. Scope of Work The proposed workover is to pull the existing upper selective, replace the inner casing packoffs, run a new upper selective and a new 3 -1/2" completion. General Well info MASP: 1686 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure /TVD: 2263 psi at 6967' MD (5769' TVD) SBHP taken on January 15, 2012 Wellhead type /pressure rating: FMC Gen II, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: MIT -T: Passed on February 15, 2012 MIT -IA: Failed on January 17, 2010 MIT -OA: Passed on May 16, 2013 Well Type: Injector Estimated Start Date: June 30, 2013 Production Engineer: Mike Balog / Deanna van Dam Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey@ conocophillips.com) Pre -Rij Work Requested 1. RU Slickline: a. RIH with dual Panex gauges, obtain combined A &C sand 30 minute SBHP, pull up hole 100' MD and obtain 15 minute gradient stop. b. Set plug in the 2.25" `D' nipple at 7066' MD, set catch on top of plug c. Pull DV from GLM #1 at 6800' MD and leave open. d. RDMO slickline. 2. Set BPV within 24 hours of rig arrival Proposed Procedure 1. MIRU. 2. Pull BPV. Circulate KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV and blanking plug, ND tree, NU 13 -5/8" 5M BOPE and PT (including annular) to 250/3000 psi. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 3 -1/2" tubing. a. If tubing will not pull free, RU E -line: Fire a string shot and cut the tubing in the middle of the first full joint above the OEJ. b. If tubing is cut, RIH with overshot and pull OEJ barrel off of slickstick 6. MU & RIH with overshot dressed for the slickstick, release the packer, and POOH with the upper selective completion. 7. MU & RIH with tandem string mills and clean out down to the top of the Model D packer. POOH standing back DP. -- Proposed Procedure Continued 8. MU & RIH with FHL upper selective completion assembly to the top of the Model D packer. 9. Spot corrosion inhibited seawater, sting into the SBE, and set the FHL packer. PT the IA to 3500 psi to confirm the packer is set. Shear the PBR and POOH laying down DP. 10. On TOOH, PU storm packer and set it at —100' MD (PT to 500 psi). ND BOP & tubing head and replace the IC packoffs. NU tubing head and BOP and test BOP. Pull storm packer and continue POOH laying down DP. 11. RIH with new 3 -1/2" tubing completion. Sting into PBR and mark the pipe. PU and load the tubing and IA with 8.6 ppg corrosion inhibited seawater. 12. Space out, land the hanger and RILDS. PT tubing to 3500 psi bleed the tubing to 3000 psi and PT the IA to 3500 psi for 30 minutes and record on chart recorder. Bleed IA and tubing to 0 psi. Ramp up the IA pressure quickly to shear the SOV. 13. Pull landing joint and install BPV. Pressure up on the IA to 1000 psi to test BPV from below. Bleed IA to 0 psi. 14. ND BOP. NU tree, pull BPV, set tree test plug, and PT to 5000 psi. 15. Pull tree test plug. Freeze protect well. Set BPV. 16. RDMO. Post -Rig Work request: 1. Pull BPV 2. RU slickline: a. Pull SOV and run DV. b. Pull catcher sub and plug in the `D' nipple. c. RD slickline. 3. Turn well over to operations. �, KUP 2X -06 ConocoPhillips Well Attributes Max Angle & MD TD Alaska lf� Welibore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) cnrxxr>;+v+6p,, 500292098800 KUPARUK RIVER UNIT INJ 43.27 3,400.00 7,675.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date ••• WellCcnfR: -2X-06, 10(8/20127:01:40AM SSSV:TRDP Last WO: 1/4/1987 33.99 8/3/1983 Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 7,306.0 5/23/2006 Rev Reason: WELL REVIEW osborl 10/8/2012 Casing Strings HANGER. 26 1 i Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String... String Top Thrd CONDUCTOR 16 15.062 31.0 103.0 103.0 62.50 H-40 WELDED awe Casing Description String 0... String ID ... Top (ftKB) 5et Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 4 4 [ , r SURFACE 95/8 8.835 30.9 3,308.3 2,860.3 40.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r1 PRODUCTION 7 6.276 29.3 7,642.4 6,371.7 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3.5 "x2.875" 3 1/2 2.992 26.2 7,075.6 5,866.3 9.30 J -55 EUE8rdABMOD @7052' Completion Details Top Depth (TVD) Top Inc! Nomi... CONDUCTOR, _ 31 -103 - Top (ftKB) (RKB) (e) Item Description Comment ID (In) 26.2 26.2 0.67 HANGER FMC TUBING HANGER 3.500 SAFETY VLV, 1,806.8 1,725.7 33.21 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE (LOCKED OUT FLOW TUBE ONLY 2.812 1.807 - ; 2/4/2008) am 6,840.2 5,656.31 26.99 PBR CAMCOOEJPBR 2.813 6,864.9 5,678.3 26.96 PACKER CAMCO HRP RETRIEVABLE PACKER 2.937 6,944.5 5,749.3 26.87 BLAST JTS AVA STEEL BLAST JOINTS (3) 2.995 7,010.9 5,808.7 26.89 NIPPLE AVA BPL PORTED NIPPLE (21 B, INTEGRAL NO GO) 2.750 7,045.2 5,839.2 26.81 SEAL ASSY BAKER 80-32 LOCATOR SEAL ASSEMBLY 3.000 SU31 - 3RFA,308 CE, . 7,048.7 5,842.4 26.80 PACKER BAKER DB PERMANENT PACKER 3.250 7,052.4 5,845.6 26.79 XO Reducing CROSSOVER 3.5 x 2.875 2.875 GAS LIFT, 7,065.5 5,857.4 26.76 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,800 7,074.8 5,865.6 26.73 SOS CAMCO SHEAR OUT SUB, TTL ELMD 7068' ON SWS (PROF DATED 2.441 3/4/1987 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) PBR, 6,640 1. Top Depth i ✓is-.41 (TVD) Top Inc! PACKER. 6,865 Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) '- [ 7,010.9' 5,808.7 26.89 SLEEVE AVA TPI SLEEVE 11/172001 .2.310 7,370.0 6,129.7 26.85 FISH 28' of bar from Kone Bottom of Hole 12/14/1983 0.000 INJECTION, 7,450.0 6,200.9 27.42 FISH 30' Vann Gun Fish Bottom of Hole 9/24/1983 0.000 6,907 Perforations & Slots I-LE: Shot Top (TVD) B•m (TVD) Dens Top (ftKB) BBs (ftKB) (ftKB) (ftKB) Zone Date (eh°- Type Comment 6,942.0 6,992.0 5,747.1 5,791.7 C-4, C -3, C -1, 924/1983 12.0 IPERF 120 deg. phasing; 5" GEO Vann Gun 6,942E 992 i [ UNIT B, 2X -06 € 9 z 7,108.0 7,122.0 5,895.3 5,907.8 A-4, 2X-06 12/14/1983 4.0 APERF 21/8" Kone Gun f 7,135.0 7,164.0 5,919.4 5,945.4 A -3, 2X-06 12/13/1983 4.0 APERF Lost 28' of bar in hole; 2 1/8" Kone Gun NIPPLE, 7,011 SLEEVE. 7,011 Notes:. General & Safety End Date Annotation 12212010 NOTE: View Schematic w/ Alaska Schematic9.0 SEAL ASSY. 7,045 r PACKER, 7,049 pq NIPPLE. 7,066 ,, SOS, 7,075 tifTh APERF, 7,108 -7,122 - APERF, 7,135 -7,164 E ' . Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run FISH, 7,370 Stn Top (ftKB) (ftKB) (°) Make Model (In) Sery TYpe Type (In) (psi) Run Date Com... 1 6,800.0 5,621.1 28.48 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0 2/16/2012 2 6,906.7 5,715.6 26.92 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 1/152012 FISH, 7,450 PRODUCTION, 247,642 TD, 7,675 • II • Conoco Phillips � � , ,� Alaska , i--= �, YE'I P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 OAR ,j ; � 6,1 y �� 61s,'1 March 9, 2012 "' Commissioner Dan Seamount J 1 1 0 Alaska Oil & Gas Commission �,� 333 West 7 Avenue, Suite 100 -. G Anchorage, AK 99501 �� Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement 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 in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MT Loveland or Martin Walters at 907- 659 -7043, if you have any questions. • . , J Sincerel , f ;' MJ veland 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 Data 3-09 -2012 2A,M,T,X PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitod Well Name API S PTD S cement pumped cement , date inhibitor sealant date ft bbls ft pal 2A-19A 50103201970100 2010830 12" NA 39" NA 15.3 2/1112012 2M-02 50103201790000 1920830 10'5" 1.62 19" 1122/11 5.1 2/112012 2M-29 50103201830000 1920970 SF NA 24° NA 3.4 2/112012 2T-18 50103202130000 1950170 42" 0.50 9" 1122/11 2.55 2/122012 , 2T-28 50103202250000 1950920 9" NA 16" NA 2T-207 50103202780000 1982310 22'3" 3.70 7" 1121/11 2.98 2/122012 2T-215 50103202800000 1982420 181" 2.40 10° 11/22/11 4.25 2/122012 2X-06 50029209880000 1831100 SF NA . 21" NA 2.13 2/122012 I k,13 - t% a 2t ZD(c) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 23, 2012 Attn.: Howard Okland • ••4- 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCA NNED JUN 2 7 2.011 RE: Plug Setting Record: 2X -06 Run Date: 1/21/2012 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 2X -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20988 -00 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: „ �. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 4, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2X -06 SCANNED jUN 2 2.013 Run Date: 1/2/2012 The technical data listed 1 ted be ow 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 2X -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20988 -00 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: -/l k /(2 / Signed: • • S~~Q~C~ 0~ Q~Q~~Q /.E.....~,,~~..o. Mr. Martin Walters Problem Well Supervisor ConocoPhillips Alaska, Inc. -, P.O. Box 100360 f ~`~'° ~ ~'- ~` ~~ ~~~ ~~`e~~''' ~;, Anchorage, AK 99510-0360 RE: Cancellation of Administrative Approval 2B.045 KRU 2X-06 (PTD 183-1100) Kuparuk River Oil Pool Dear Mr. Walters: Pursuant to ConocoPhillips Alaska, Inc. (CPAI)'s request dated August 20, 2010 the Alaska Oil and Gas Conservation Commission (AOGCC) hereby cancels Administrative Approval AIO 2B.045, which allows continued water injection in Kuparuk River Unit (KRU) well 2X-06. This well exhibited tubing x inner annulus (TxIA) communication and CPAI did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. CPAI has not injected into 2X-06 since January 2010 and is not planning to resume injection until a workover can be performed to repair the well. Consequently, Administrative Approval AIO 2B.045 no longer applies to operation of this well. Instead, KRU 2X-06 will be governed by provision of the underlying AIO No. 2B. DONE at Anchorage, Alaska and dated Daniel T. Seamount, Jr. Commissioner, Chair AIO 2B.045 cancel • • August 31, 2010 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. ConocoPhillips ~~~~ ~~ -- P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2010 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 !~' r~~~~ 1 ~~ ~~~ C~~nissiar} ~'rL,`~~t;3q~ Subject: 2X-06 (PTD 183-110) Request for Cancellation of Administrative Approval 2B.045 Dear Mr. Seamount: ConocoPhillips Alaska requests the cancellation of Administrative Approva12B.045. The approval, originally issued December 2, 2009, was for continued water injection with communication from the tubing to inner annulus (TxIA). The well is currently planned to undergo a rig workover so therefore AIO 2B.045 is no longer needed. Please call Brent Rogers or myself at 659-7224 if you have any questions. Sincerely, Martin Walters ConocoPhillips Problem Well Supervisor • • ~~~ L I~. P~ACrive DiagNOSric Seemcrrs, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 1 DO Anchorage, Alaska 99501 (9D7j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Leak Detection - WLD 25zlan-10 2} r~3 - <<v 2X-06 EDE 50-029-20988-00 ~ c~s~ ~~~~~`'~' ~~ ~ ~. ,~ ~ O'i~S l I. V Signed Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (9071245-88952 E-MAIL : "'~i ,~ ». ~ _ ~="~ - - - a[~ ~ WEBSITE `--. _ ;?-i C,\Documents and Settings`.[hane Williams\Desktop\Tcansmit_Conoco.docx ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~ ~ ~ ~Q~~ n,~~j~~ ~ t ~ ~: Dear Mr. Maunder: 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 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 pum~ed August 20th-Sept 1 lth, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13` ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1C-178 203-041 8' 1.50 8" 9/11/2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11/2008 1Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9!12/2008 1 Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12/2008 1 Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 2X-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 ,~~~ ®~- ~. .:. ~. ~ ~us -.: RE: 2X-06 (PTD 1831100) Rep~of suspect TxIA communication • Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, January 19, 2008 2:26 PM ~~~ 112~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA) Cc: NSK Well Integrity Proj; NS~roblem Well Supv t Subject: RE: 2X-06 (PTD 1831100) Report of suspect TxIA communication Attachments: MIT KRU 2X-06 01-18-08.x1s Tom & Jim, An update on the results of the diagnostics of the suspected TxIA communication. The MITIA and MITOA both passed, however the IA DD test failed. The IA would not bleed down below '1320 psi with 1200 psi on the tubing. In one hour the IA built up to 1440 psi with 1200 psi on the tubing. A one way packer leak is suspected from the top packer of the C sand "' straddle zone. Currently the C sand zone is isolated from injection. Immediate action will be to s in the well and secure with a tubing tail plug for further dia nostics to locate the Peak and add the well to the monthly NIiT report. Fallowing`Te results, ConocoPhillips will plan to submit either a 10-403 Sundry application for repair or an AA for continued water injection whichever may be appropriate unless a RWO is determined to be the appropriate course of action. Attached is the MITIA test form. The test data for the MITOA will be submitted if an AA is sent in for approval. «MIT KRU 2X-06 01-18-08.x1s» Please let me know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 ~~_ __.~~ _a u. From: NSK Problem Well Supv Sent: Friday, January 18, 2008 3:23 PM To: 'tom.maunder@alaska.gov'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2X-06 (PTD 1831100) Report of suspect TxIA communication Tom & Jim, Kuparuk injector 2X-06 (PTD 1831100) was reported on 01-17-08 to have suspect TxIA communication. The operator reported the lA required bleeding to maintain a differential pressure from the tubing when the injection pressure was lowered. The TIO prior to bleeding the IA was 1270/1400/400. Immediate action that will be taken is to perform Tubing and IC packoff testing, a MITIA, an IA DD test and a MITOA for diagnostics. The AOGCC will be updated with the results of the diagnostic testing. It is ConocoPhillips intention to submit the appropriate paperwork pending the outcome of the diagnostics as needed. Attached is a well schematic and a 90 day TIO plot. 1 /22/2008 RE: 2X-06 (PTD 1831100) Repo of suspect TxIA communication • Page 2 of 2 Please let me know if you have anstions. « Fi{e: 2X-06 schematic.pdf» « Fi{e: 2X-06 90 day TIO plot.jpg » Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 1 /22/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov 1 Z~ ~ t'~o OPERATOR: ConocoPhillips Alaska Inc. 1\~~ ~ t FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: Kuparuk/ KRU/ 2X-06 01 /18/08 Greenwood/Colee - AES Packer Dept Pretest Initial 15 Min. 30 Min. Well 2X-06 Ty e Inj. W TVD 5,679' Tubing 1,200 1,200 1,200 1,200 {nterval O P.T.D. 1831100 T etest P Test si X500 Casing 1,220 /,~000 2,960 2,940 P/F P Notes: Non witnessed diagnostic MITIA OA 400 400 400 400 45 min T/I/0=1200/2940/400 Well Ty e In~. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. Type test Test si Casing P1F Notes: OA Well T pe In . TVD Tubing Interval P.T.D. Type test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2X-06 01-18-O8.xls MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Relí' ¡;/7!07 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2X-06 KUPARUK RIV UNIT 2X-06 Src: Inspector /\\0 \CbD FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: 1"'i¡:?1? P.I. Suprv ..:..J9I"- Comm Well Name: KUPARUK RIV UNIT 2X-06 API Well Number: 50-029-20988-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070601 175725 Permit Number: 183-110-0 Inspection Date: 6/112007 /' Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2X-06 Type Inj. G TVD I 5679 IA 970 2060 2040 2040 P.T.D 1831100 TypeTest SPT Test psi ! I~O OA 600 640 640 640 4YRTST P ./ Tubing 3750 3750 3750 3750 I Interval P/F Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. ,,/ ~~ JL}N 2 1 20tH Wednesday, June 06, 2007 Page I of 1 Schlumbepger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 1E-18 I/lj"è it., 1 F-01 IS)... -.1 j c¡ 1Y-06A 19-f-i J 'i 3J-06 ¡ gS'- -I... J 'i 1Y-31 i c/3 - 010 1B-10 /Sí-)Jj" 3G-10 ¡Cít.-- t¿J-( 2Z-23 l qr-~()Iè 2X-06 / g 'l> - j D 2X-07 ¡In ···/13 1Y-04/JJ- G {. L Job # 11015713 11047354 11015712 11056679 11015708 11056671 11056670 11015717 11015711 11015710 11047351 ç·C~.·fi~N-..r.î.r:.:!_·=', ("CD n ro.? r¡'nn¡:: ~~. 1,"'\,1 '''J...,., . .) L ¡ ,J' ~ '-' v.) Log Description LEAK DETECTION LOG PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT PRODUCTION PROFILE W/DEFT INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE (REDO) µoiLJ SIGNED: Date 08/06/05 07/31/05 08/05/05 08/19/05 08/03/05 - 08/12/05 08/11/05 08/10/05 08/04/05 08/04/05 07/27/05 NO. 3456 Company: 08/24/05 Itg3--¡/O Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk DATE: BL Color CD - 1 1 1 1 1 1 1 1 1 1 1 ~ <)" \\ J .it 2..JJ'\j :;-- . dì- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ) } State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission DATE: Monday, August 15,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2X-06 KUPARUK RIV UNIT 2X-06 ."'7 i ¿J./ 1(./11 1 \ ~ 0) TO: Jim Regg P.I. Supervisor 3/\\0 \~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: .j' ':'7.:' P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2X-06 Insp Num: mitJJ050810 115228 Rei Insp Num: API Well Number: 50-029-20988-00-00 Permit Number: 183-110-0 Inspector Name: Jeff Jones Inspection Date: 8/8/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. ---'---T--'--~"""-'''-''-'-------T-'-- --. ··-·-~·--"-·---·I·· ------... Well I 2X-06 ¡Type Inj. I W . TVD I 5679 IA 1500! 2820 I 2800 I 2800 ~p.T. L 18~IIÓ'1fY¡'e~"st-¡SP1!e;t psi ¡ 141~~5 -¡ OA L620_=t=--'~0-L:¡001 .. 700 .. Int~..rval~~TsT ...._..........fLE...___._~. ___ _.._~~~ing .~~:~L __ 2250_..L-==~~_~_._.~250 Notes: 2,1 BBLS diesel pumped. 1 well house inspected, no exceptions noted. 60 Min. i ·1---- i ------··1·----- -i-----j·------- I __..._._..._--L.._..__.____ \ 'i~\\' "'>' (~r:D C;,.! f\ 20P5 ::jÇi<~N~·\fjt;1.J d ~~ b (1 (j - w J I Monday, August 15, 2005 Page 1 of 1 " } C' conocoÞtWIfP.·.....s. Ala. $ka,lnc> , .~tJt.) '. . ... ... >2Xi,Q6 SSSV (1807-1808, 00:3.500) Gas lift 1drel/Oummy Valve 1 (6800-6801, 00:5,940) PBR (6840-6841 , 00:3.500) PKR (6865-6866, 00:6,151) Injection 1drelIDummy Valve 2 (6907 -6908, 00:5,313) Pert (6942-6992) SLEEVE (7011-7012, 00:2,750) PKR (7049-7050, 00:6.151) NIP (7066-7067, 00:2.875 ) TUBING (7045-7076, J 002875. 10:2.441 ) SOS (7075-7076, 00.2.875) Perf (7108-7122) Pert (7135-7164) 28' of bar from Kane (7370-7398, 00:2.125) .>, . i a <I ~ >,'-' ¡ ¡ , .....'.'.'.. ¡, ...'. j I \d."··..·.. ~:.:.:.:,:-:,. '. ., ! I .. r. ,¡, 'J..'::::::::::::::;:.::::::::~;"~ ::::::=;:::::; ',' ::::::::..:", . ¡ ¡ I ! ¡ ¡ · f:JI I IÞ.M I .m J '.' " < ';:::;'. : ..:.: /. ¡ . ...... ! Mil .. ¡ ~ ¡ -+ --+- --t- --ë- --r --0- ~ -+ -+ r ..It. :::::::~::::::: ~ .: g $= I· t- ~' ~1.i·'I' "!ii' 'I~ (]1' II 'egÚl ,~1\~ _l!~M&~ ¡ ) KRU 2X-06 Gas·L¡:ft·Mahd'el~Vàlves St MD TVD Man Man Type Mfr 1 6800 5621 Otis Injection··MaridreISIVålves·, St MD TVD Man Man Type Mfr 2 6907 5716 Cameo KBUG Otl1er(plugs" equip., etc:)·JEWELRV Depth TVD Type 1807 1727 SSSV 6840 5656 PBR 6865 5679 PKR 7011 5809 NIP 7011 5809 SLEEVE 7049 5843 PKR 7066 5858 NIP 7075 5866 SOS 7076 5867 TTL Fish~FISH Depth Description 7370 28' of bar from Kone 7450 30' Vann Gun Fish API: 500292098800 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 7328 Last Tag Date: 6/12/2005 Casirig·Stting..:...AL.L.·STRINGS Description CONDUCTOR SUR. CASING PROD. CASING TubingStriiig . TUBING Size Top 3.500 0 2.875 7045 Perforations Summary Interval TVD 6942 - 6992 5747 - 5792 7108 - 7122 7135 - 7164 5895 - 5908 5919 - 5945 Well Type: Orig Completion: Last w/o: Ref Log Date: TO: Max Hole Angle: INJ 8/3/1983 1/4/1987 Angle ~ TS: 27 deg @ 6941 Angle ~ TD: 27 deg ~ 7675 Rev Reason: TAG FILL Last Update: 6/14/2005 7675 ftKB 43 deg @ 3400 Size Top 16,000 0 9.625 0 7.000 0 Bottom 103 3308 7642 TVD 103 2860 6371 Wt 62.50 45.50 26.00 Grade H-40 J-55 J-55 Thread Bottom TVD Wt Grade 7045 5839 9.30 J-55 7076 5867 6.50 J-55 Zone Status Ft SPF Date Type 4,C-3,C-1,U/\ 50 12 9/24/1983 IPERF B A-4 14 4 12/14/1983 APERF A-3 29 4 12/13/1983 APERF Thread 8RD AS MOD EUE 8RD Comment 120 deg. phasing; 5" GEO Vann Gun 2 1/8" Kone Gun Lost 28' of bar in hole; 2 1/8" Kone Gun lBX VMfr V Type VQD Latch Port TRQ Merla DMY 1.5 RO-5 0.000 0 V Mfr V Type VQD Latch Port TRQ DMY 1.0 SK 0.000 0 Description ID 2.810 2.813 2.900 2.750 2.310 3.250 2.250 2.441 2.441 Date Vlv Run Cmnt 1/15/1986 Date Vlv Run Cmnt 11/19/2004 Cameo TRDP-1A Cameo 'OEJ' Cameo 'HRP' AVA 'BPL' Nipple (21 B,INTEGRAL NO GO) AVA TPI sleeve, 2.75" set 11/17/01 Baker 'DB' Cameo '0' Nipple NO GO Camco Comment Bottom of Hole Bottom of Hole ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRUI 2X 08108/05 Arendl Greenwood Jeff Jones -1./\\0 \%..J Packer Depth Pretest Initial 15 Min. 30 Min. Well 2X-06 Type Inj. S TVD 5,679' Tubing 2,250 2,250 2,250 2,250 Interval 4 P.T.D. 1831100 Type test P Test psi 1500 Casing 1,500 2,820 2,800 2,800 P/F P Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: SGkN!\JE[; AUG 11 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 2X-06 08-08-05.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, ~.-,¢'~ Commissioner THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor FROM: john H Spaulding,~:~'~ Petroleum Inspector DATE: July 22, 2000 SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & lX 1E - 8 wells, 16 components, 1 failure, :9 % failure rate, 12 well house insp. :.2X~-:lOwells,- 20 compnents, 1 failure, 5 % failure rate, 12 well house insp. Attachment: Alas]ca'Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kupamk/Kupamk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL 1 E- 10 1820360 1E-11 1820510 1 E- 12 1820600 SI 1E-14 1820790 1E-18 1830160 91 60 46 P P OIL 1E-19 1830170 1E-20 1830050 91 60, 48 P P OIL 1E-21 1830020 1E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1 E-26 1821660 SI 1E-28 1821580 SI 1 E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 1971510 1E-34 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% [-3 90 my Remarks: 8/7/00 Page 1 of 1 svs kupamk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator ReP: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By:John Spaulding Date: Field/Unit/Pad: Kupamk/Kupamk R./2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X-01 1830840 2X-02 1831030 2X-03 1831090 2X-04 1831180 3000 2000 2000 P P WAG 2X-05 183'1070 3000' 2000 2000 P 4 'WAG ~~ 1831100 3000~ 2000 2000 P P WAG 2X-07 1831 ! 30 3500 2000 2000 P P WAG 2X-08 1831140: 2X-09 1841620 96 70 60 P P OIL 2X- 10 1841630 96 70 65 P P OIL 2X- 11 1841640 96 60 60 P P OIL 2X- 12A 1951760 2X-13 1841740 2X-14 1841750 - 2X-15 1841760 96 70 70 P P OIL 2X-16 1841720 2X-17 1951710 96 60 50 P P OIL 2X-18 1951600 96 60! 50 P P OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% [~ 90 Day Remarks: 5/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls STATE OF ALA~ AL, ~4 OIL AND (3A13 CONE~_RVATION C, OIVI~ ~'ON REPORT OF SUNDRY WELL OPEFrATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate __ ' · Other Conversion 2. Name of Operator ARCO Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 390' FSL, 602' FEL, Sec. 4, T11N, RgE, UM At top of productive interval 1398' FSL, 1648' FEL, Sec. 9, T11N, At effective depth 1441' FSL, 1378' FEL, Sec. 9, T11N, At total depth 1449' FSLr 1320' FELr Sec. 9, T11N, 12. Present well condition summary Total Depth: 5. Type of Well: Development ...__ Exploratory _ Stratigraphic Service X Aia~a On &, Gas Cons Comr~k~ R9E, [JM-' '" 'Ancnorag; 6. Datum elevation (DF or KB) RKP 113 7. Unit or Property name Kuparuk River Unit 8. Well number measured 7 true vertical 6 feet ~X;-06 ' g. Permit number/approval number 83-110 10. APl number 5o-029-20988 11. Field/Pool Kuparuk River Field sio,t(uparuk River Oil Pool 6 75' feet Plugs (measured) 406' feet Effective depth: measured 7550' feet true vertical 6289' feet Junk (measured) Vann Gun @ 7420' Casing Length Size Cemented Measured depth Structural Conductor 1 1 2' 1 6" 248 sx AS II 1 I 2' Surface 3308' 9 5/8" 1250 Sx AS III 3308' Intermediate 250 SX AS I Production 7 6 4 2' 7" 375 sx Class G & 76 4 2' Liner 350 SX AS I Perforation depth: measured 6942'-6992', 7108'-7!_22', 7!35'-7164' true vertical 5746'-5791', 5894'-5907', 5919'-5945' Tubing (size, grade, and measured depth) 3 1/2" J-55 @ 7076' Packers and SSSV (type and measured depth) Camco HR Pkr @ 6865', Baker DB pkr ~ 7049'~ & Camco TRDP-1A SSSV @ 1797' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure True vertical depth 112' 2860' 6371 ' 14. Pressure Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Prior to well operation 50'00 1300 2400 Subsequent to operation 6700 120 3900 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector __ Daily Report of Well Operations Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Wag In!ector Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE STATE OF ALASKA Ab,,,-,~4A OIL AND GAS CONSERVATION ~M'T~,i'4ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program ~X 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 4. Location of well at surface 390' FSL, 602' FEL, Sec. 4, T11N, RgE, UM At top of productive interval 1398' FNL, 1648' FWL, Sec. 9, T11N, R9E, UM At effective depth 1441' FNL, 1378' FWL, Sec.9, T11N, R9E, UM At total depth 1449' FNLt 1320' FWL~ Sec. 9~ T11Nt R9E~ UM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7675' true vertical 64 0 6' measured 7 5 5 0' true vertical 628 9' Length Size 112' 16" 3308' 9-5/8" feet Plugs (measured) feet feet feet 7642' 7" measured 6942'-6992', 7108'-7122', 6. Datum elevation (DF or KB) RKB 113 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2X-06 9. Permit number 83-110 10, APl number so-029-20988 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Junk (measured)Vann Gun @ 7420' Measured depth True vertical depth 248 sx AS II I 12' 1 12' 1250 sx AS III 3308' 2860' 250 sx AS I 375 sx Class G & 7 6 4 2' 6 3 71 ' 350 sx AS I 7135'-7164' RECEIVE[ true vertical MAY 1,5 199 5746'-5791', 5894'-5907', 5919'-5945' Alaska Oil & Gas Cons. C0mr Tubing (size, grade, and measured depth) 3 1/2" J-55 @ 7076' Anchorage Packers and SSSV (type and measured depth) Camco HR Pkr ~ 6865'~ Baker DB pkr ~ 7049'~ & Camco TRDP-1A SSSV @ 1797' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ Convert well from water iniector to WAG injector (Alternating water and immisicible gas). 14. Estimated date for commencing operation [ 15. Status of well classification as: May. 1991 I Oil __ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service WAG I n!ector 17. I herebjf~ertify that the foregoing is true and correct to the best of my knowledge. FOR (:X3MMISSION'USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No. --/ co -- ~issi0n Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE ARCO Alaska, Inc. , Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1987. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have an~ questions concerning the information reported, please contact me at (907) 263-4262. Sincerely, Operations Engineer BBB/SPT-pg:O069 Attachments ,v A 0 i 1--- :987 Naska 0il & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfieldCompany ATTACIIMENT 1 PAGE I KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE q - INJECTIVlTY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL NUMBER APl DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING 50-029 INJECTION SURVEY SURVEY ~URVEY WATER 20968 20973 21157 21208 21228 20982 20987 20988 21qh9 21q63 12/12/85 02/03/87 SPINNER FOLLOWUP A&C S 11/09/85 02/01/87 SPINNER FOLLOWUP A&C S 11/09/85 02/0h/87 SPINNER FOLLOWUP A&C SS 11/22/85 03/05/87 SPINNER FOLLOWUP A&C SS 11/15/85 03/06/87 SPINNER FOLLOWUP A&C SS 11/19/85 02/07/887 SPINNER FOLLOWUP A&C SS 11/0q/85 03/02/87 SPINNER FOLLOWUP A&C SS 11/0q/85 03/0q/87 SPINNER FOLLOWUP A&C SS 05/0q/86 02/08/87 SPINNER INITIAL A&C SS 05/06/86 02/09/87 SPINNER INITIAL A&C SS A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C INJECTION BWPD · Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA AND GAS CONSERVATION CC~MMISSION ALASKA~IL WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~'~ OIL [] GAS [] SUSPENDED [] ABANDONED [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-110 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20988 4. Location of well at surface 9. Unit or Lease Name 390' FSL, 602' FEL, Sec. 4, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1398' FNL, 1648' FWL, Sec. 9, T11N, R9E, UM 2X-6 At Total Depth 11. Field and Pool 1449' FNL, 1320' FWL, Sec. 9, T11N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i ] Pool RKB 106'I ADL 25645, ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/27/83 08/02/83 09/25/83*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey 20. Depth where sssv set 21. Thickness of Permafrost 7675'MD 6400'TVD 7550'MD 6289'TVD ..- YES E~ 'NO [] 1807' feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/CNL/GR/SP/Cal/FDC, CBL/VDL/CCL/GR, Gyro , 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE ITOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 112 ' 24" 248 sx AS I I 9-5/8" 40.0# J-55 Surf 3308' 12-1/4" 1250 sx AS Ill& 250 sx iS i 7" 26.0# J-55 Surf 7642' 8-1/2" 375 sx Class G & 350 sx AS I · 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) 6942'-6992'MD w/12 spf 3-1/2" 7076' 7049' 7108'-7122'MD w/4 spf 7135'-7164'MD w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5746'-5791 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5894'~5907'TVD See attached Adden~um~ dated 01/20/87, 5919'-5945'TVD for Fracture data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test HoursTest~d PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHoKEsIZE IGAS-OILRATIo TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE air 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED .:, o 6 1987 Alaska Oil & Gas Cons. Commission Anchorage *Note: Well was worked over 01/03/87. Form 10-407 WC2:013:JG Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 29. ,~ .. ,. ..... N~ME,-. - ......... Include interval t~Sted, pressure data, all fluids r~over~ and gravis," , "~ ' '-': ' MEAS~ DEPTH TRUE VERT. DEPTH GOR,and time of each phase. -. . -.~ , .-- -.~ ... -- . .... . : ,- . : . ~ ,~ - . _ . Top Upper Sand' 69~1' ' 57~6~ N/A ........ Base Upper Sand :698~~ 578~~ Top Lower Sand 7087~ 5876~ Base Lower Sand~.. ? - .- _ 72~0~ 600~~ ~;.~:L:-,, ;'..~-: ..z ~ ,.; ;~ ..: . . .- .: . ,., : .~ . .~.: :. ..-.~ .... .... :: -: . i ... ,.: :~ . )- .. ; . - , . . - . . . . . . . . 31. LIST OF ATTACHMENTS : Aodendum ' (dated 01/20/87). 32. I hereby certify that the foregoing is true and correct to the best of m~ knowledge ' "' ~'~: ' ' ........ . . : - . . ,.. . .::t ; . . : ; , Signed } ~ ~~ Title Assooiate Engineer 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:vAttache, c~isupplemental records for this well should show the details of any multiple stage cement- ing ahd'the: Iocatfon of the cementing tool. Item 27i Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jecti.o,.n, Gas Injection, Shut-in, Other-explain. .:' ' .-:;~ :~ .? Item 28' If no 'cores taken, indicate 'none". · _ . Form 10-407 ADDENDUH WELL: 1/1~/~? 2X-6 Frae Kuparuk "A" sand perfs 7108'-7122' & 7135'-7164' in seven stages per procedure dated 12/24/86 with the following treatment: Stage 1: 40 bbls 140° diesel w/5% Musol @ 5 BPM, 2070 psi Stage 2: 71 bbls gelled diesel @ 20 BPM, 4200-3270 psi Stage 3: 18 bbls gel diesel w/l# 100 mesh @ 20 BPM, 3270-3160 psi Stage 4: 20 bbls gelled diesel spacer @ 20 BPM, 3160-3180 Stage 5: 19 bbls gelled diesel w/3# 20/40 "Fly" @ 20 BPM, 3180-3170 psi Stage 6: 29 bbls gelled diesel w/8# 20/40 "batch) @ 20 BPM, 3170-3440 psi Stage 7: 60 bbls gelled diesel flush @ 20 BPM, 3440-2920 psi Intentionally underflush 2.5 bbls. Avg Pressure = 3000 psi Fluid to recover = 257 bbls Sand in Zone = 800# 100 mesh & 11,478# 20/40 mesh Sand in Csg = 672# 20/40 Job complete @ 1015 hfs, 1/19/87 Dr~hg Supervisor STATE OF ALASKA ALASI~:~.-OIL AND GAS CONSERVATION COMM._~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other 2. Name of Ooerator ARCO- AT~s'l~a, Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 390' FSL, 602' FEL, Sec. 4, TllN, RgE, UN At top of productive interval 1398' FNL, 1648' FWL, Sec. 9, T11N, RgE, UN At effective depth 1441' FNL, 1378' FWL, Sec. 9, TllN, RgE, UM At total depth 1449' FNL, 1320', FWL, Sec. 9, T11N, R9E, UN Stimulate [] Plugging [] W0RKOVER Perforate g, Pull tubing~ 5. Datum elevation (DF or KB) RKB 113' 6. Unit or Property name Kuparuk R~ver Unit 7. Well number 2X-6 8. Approval number 5~1 9. APl number 50-- 02.9-2098{~ 10. Pool Kuparuk River 0il Pool Feet~ 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 112' 3308' 7642' Casing Conductor Surface Production 7675 'MD 6406 ~ TVD 7550 ' MD 6289 ' TVD Size 16" 9-5/8" 7" feet Plugs (measured) feet feet junk (measured) feet None Vann Gun @ 7420' Cemented 248 sx AS II 1250 sx AS III 250 sx AS I 375 sx Class G & 350 sx AS I Measured depth 112'MD 3308'MD True Vertical depth 112'TVD 2860 ' TVD 7642 'MD 6371 'TVD Perforation depth: measured true vertical 6942'-6992'MD 7135'-7164'MD 7108' -7122 'MD 5746'-5791'TVD 5919'-5945'TVD Tubing (size, grade and measured ~sg07'TVD 3-1/2", J-55 @ 7076' Packers and 888V (type and measured depth) DB pkr @ 7049', & TRDP-1A SSSV @ 1807' RECEIVED 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure ,', 2 i987 Alaska 0il & Gas Cons. ~;ul~mission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations .~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~.L~ Title Associate Engineer Date Form 10-404 Rev. 12-1-85 (~ (DANI) SW0/161 Submit in Duplicate Prepare and submit the "Initial Repo~' 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. i District ICounty, parish or bgh .... rtate Alaska Alaska North Slope Borough Field ILease or Unit IWell no. Kuparuk River ADL 25645 2X-6 Auth. or W,O. no. ~Title AFE AK1843 I Recompletion Nordic 1 API 50-029-20988 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun Date IHour IPrior status if a W.O. Workover 12/30/87 I 0500 hrs. I Date and depth as of 8:00 a.m, 12/30/86 12/31/86 1/01/87 thru 1/02/87 Complete record for each day reported 7" @ 7642' Diesel Accept Rig @ 0500 hfs, 12/30/86. lines. Clean pits & hook up kill 7" @ 7642' 7560' (W-bM) PBTD 9.8 ppg NaC1 Pull BPV. Pump Litesal pill into perfs & displ w/9.6 brine. Circ 9.8 brine, ND tree, NU BOPE & test same. Shear OEJ & pull 3-1/2" tbg. 7" @ 7642' 7560' (WLM) PBTD 9.8 ppg NaC1 POH 3-1/2" tbg - change out collars to AB Mod, 7 GLMS, 214 jts tbg, Camco OEJ sleeve. Changed out hyd pump, PU retrieving tool, jars, collars & 3-1/2" DP. RU Dresser. MU backoff shot & RIH on WL w/collar locator. Turned pkr & work up hole. POE w/WL. LD Kelly. POH w/pkr. MU bridge plug & RIH w/3-1/2"'DP. Set BP @ 6810'. 56.24% RECEIVED JAN 2 1987 Alaska Oil & Gas Co,~s. u,~--,,..w,s:-;~or~ /~mchorage see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor r ¸r ARco Oil and Gas Company Daily Well~Histo~- Final Report Inetructlona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be subm/Ited also when operafions are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I or Parish Alaska County Field ILease or Unit Kuparuk River Auth, or W.O. no. JTitle I AFE AK1843 North Slope Borough ADL 25645 IAccounting State cost center code Alaska JWell no. 2X-6 Recompletion Nordic 1 API 50-029-20988 Operator 1A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun J Date Workover I 12/30/86 Date and depth Complete record for each day reported as of 8:00 a.m. 1/03/87 thru 1/04/87 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 0500 hrs. I 7" @ 7642' 7560' (WLM) PBTD, RR 6.8 ppg Diesel Tst BP to 2000 psi - OK. RIH, set RTTS @ 300', ND BOPE. Chg out tbg head, NU & tst BOPE. RIH, retry RTT's. Tst 7" csg to 3500 psi; OK. RU Schl, make 6" JB/GR rn to 7319'i unable to go deeper. RIH w/DB pkr, set @ 7039' (WLM), POH, RD Schl. RU & rn 219 its, 3½" EUE, 8RD, AB Mod tbg w/SSSV @ 1807', DB pkr @ 7049', TT @ 7076'. ND BOPE, NU & tst tree to 250/5000 psi. RR @ 1445 hrs, 1/3/87. RECEIVED JAN 2 3 !987 Alaska 0il & Gas~r~. '~ -' ~.~mi~sion Anchorage Old TD New TO 7560 ' ?B~D Released rig Date 1445 hrs. Classifications (o11, gas, etc.) O±l Producing method Flowing Potential test data J PB Depth Kind of rig 1/3/87 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Weli no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR correctedGravity Allowable Effective date The above is correct Signature ~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date / [Title // Drilling Supervisor STATE OF ALASKA ALASKA--~IL AND GAS CONSERVATION COMMI~...~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_r~ Suspend ~ Operation Shutdown .~ .~' Re-enter suspended well,r~- Alter casing Time extension .~ Change approved program [] Plugging [] Stimulate ~.-Pull tubing ~...J~mend order ~ Perforate ~her 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360 Anchorage: AK 9g5l(3-nRR0 4. Location of well at surface 390' FSL~ 602' FEL~ Sec. 4, T11N, R9E~ UH At top of productive interval 1398' FNL, 1648' FWL, Sec. 9, TllN, R9E, UM At effective depth 1441' FNL, 1378' FWL, Sec. 9, T11N, R9E, UM At total depth 1449' FNL, 1320' FWL, Sec. 9, T11N, RgE, UM 5. Datum elevation (DF or KB) 113' RKB 6. Unit or Property name ~,,r~r,,~ R~v~r IIn;~- 7. Well number 2X-6 8. Permit number 83-110 9. APl number 50-029-20988 10. Pool Kuparuk River Oil Pool feel 11. Present well condition summary Total depth: measured 7675 'MD feet true vertical 6406 'TVD feet 7550 'MD Effective depth: measured feet true vertical 6289 'TVD feet Plugs (measured) None Junk (measured) Vann gun @ 7420' Casing Length Size Cemented Measured depth ~ue Vertical depth Conductor 112' 16" 248 sx AS. II 112'MD 112'TVD Surface 3308' 9-5/8" 1250 sx AS III 3308'MD 2860'TVD 250 sx AS I Production 7642' 7" 375 sx Class G 7642'MD 6371'TVD 350 sx AS I Perforation depth: measured 6942' - 6992' true vertical 5746' - 5791 ' Tubing (size, grade and measured depth) 3-1/2", J-55 ~ 6870' Packers and SSSV (type and measured depth) HRP @ 6851' & TRDP @ 1943' 12.Attachments RECEIYEO OCT 1 1986 AI~ 0Ii & Gas Gens, Commission Anchorage Description summary of proposal ,~,~.Detailed operations program ~ BOP sketch ~ 13. Estimated date for commencing operation December 21, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~ Title Associ ate Engineer ~/ Commission Use Only (JWR) SA/139 Date Conditions of approval Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance Approved b~ 4~. L .~~ Form 10-403 R~v-'-~--1-8,~ --- / // / Returned Commissioner by order of /[.,~/-- /,.-~,. I the commission Date" 7~/.//~:~[.,,. I Submit i~ triplicate Kuparuk Well 2X-6 Conversion to Selective Single Preliminary Procedure 1. Move in and rig up workover rig. Kill well. 2. Nipple down tree. Nipple up and test BOPE. 3. Shear out of SBR. POOH and stand tubing in derrick. 4. Pick up 3-1/2" drill pipe and retrieve packer. POOH. 5. Run CET. Perform cement squeeze between "A" and "C" sands, if required. 6. Run in hole and set retrievable bridge plug. Remove 3M tubing head and install 5M head. Test casing to 3500 psi. Retrieve BP. 7. RIH with casing scrapers and 6-1/8" bit to PBTD. Circulate and condition brine. POOH. 8. Reperforate "C" sand if well is squeezed. Run GR/JB to PBTD. RIH and set permanent packer between "A" and "C" sands. 9. Run 3-1/2" single selective completion assembly. 10. ND BOPE. NU tree and test. 11. Displace well to diesel by reverse circulation. 12. Test annul us and tubing. 13. Secure and release rig. 14. The well will be acidized and/or fracture stimulated after rig release. (Workover Fluid: NaCl/NaBr) BHP = 3040 psi @ 5746' TVD (6942' MD) SA/140:db 10-29-86 ANNULAR PREVENTER § BLIND' RAHS PIPE RAt'IS 4 TUBINO HEAD 1. 16" CONDUCTOR SWAGED TO 2, 11"-3000 PSi .STARTING HEAD 3, 11"-:3000 PSI X 7-1/16"-5000 TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE DAMS 5. 7-I/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAP ACCUMULATOR CAPACITY TEST WITH HYDRAULIC FLUID. 2. ASSURF' mAT ACCU~LAT~ P~SS~ IS ~0~ PSi WITH ,soo ps, ,s .s s~cm~s c~os,.~ ~,.~ ~ ,2oo.s, ~.~,.,~ ,,EssuRE. R E C E ! V E D OCT ~ 1 ]986 BOP STACK TES ,,,AlasleT Oil & Gas Cons.-~oC°mmiss'-n 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. Anchorage 2. CHECK THAT ALL HOLD-DOWN SCREWS Ai:~ FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUO WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. ~. CLOSE ANNULAR PREVENTE~ AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PS! AND HOLD FORt 10 MINUTES. 5. INCP, EASE Pl:~SSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSi. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PPESSURE TO ZERO PS1 TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, tF ANY, WITH 3000 PS! UPSTREAM OF VALVE AND WITH ZERO PS1 DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PiPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOP, 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND ~ECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES A~E FULL OF A~CTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. I 1. TEST STANDPIPE VALVES TO :3000 PSi. 1'2. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 1.3. P,F. COP, D TEST INFORMATION ON BLOWOUT PP, EVENTEP, TEST FORM. SIGN AND SEND TO DRILLING SUPEP, VISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. dG ,JUNE 16, 1986 (NORDIC RIG 9-5/8") Mr. C. V. Chat+orton May 27, 1986 Page 3 Well Number 1L-5 1R-3 Date of Initial ~e]~~_~ ].~~ Injection prOfile 11/19/85 3/21/86 lQ- 13 11/16/85 3/18/86 Well Number Date of Initial Injection Date of Injection Profile 1Y-2 1Y-8 1Y-12 1Y-15 3/30/85 3/30/85 3/30/85 10/28/85 8/7/85 8/8/85 8/10/85 3/23/86 Well Number Date of Initial Injection Date of Injection Profile 2W-2 11/15/85 3/26/86 2W-8 11/15/85 3/27/86 2W-9 1/13/86 3/28/86 2W- 10 11/15/85 3/29/86 2W- 14 11/15/85 3/31/86 Well Number Date of Initial Injection Date of Injection Profile 2X-1 11/4/85 3/22/86 2X-2 11/19/85 3/14/86 2X-3 11/4/85 3/23/86 2X-6 11/4/85 3/21/86 2X-7 11/4/85 3/23/86 Well Number Date of Initial Injection Date of Injection Profile 11/4/85 4/3/86 12/2/85 4/2/86 12/1/85 4/6/86 VLF-pg-O051 RECEIVED 0 Oil & Gas Cans. Comm!-'s. Anct~r~ ARCO Alaska, Inc Post Office-,._.-,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 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 1F-4 Conversion 1F-5 Conversion 1F-8 Conversion 1G-3 Conversion 1G-4 Conversion 1L-3 Conversion 1L-5 Conversion 1Q-8 Conversion 1Q-12 Conversion 1Q-14 Conversion 1R-3 Conversion 1R-10 Conversion 1Y-7 Conversion 1Y-10 Conversion 1Y-15 Conversion 1Y-13 Conversion 2~-6 Conversion 2B-8 Conversion 2B-11 Conversion 2B-12 Conversion 2C-2 Conversion 2C-4 Conversion 2C-5 Conversion 2C-7 Conversion 2D-4 Conversion 2D-5 Conversion 2F-3 Conversion 2F-4 Conversion 2F-15 Conversion 2F-16 Conversion 2D-10 Conversion 2D-16 Conversion 10/24185 10/24/85 10/24/85 10/25/85 10/25/85 10/24/85 10/24/85 10/25/85 10/25/85 10125185 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 10/26/85 11/5/85 1115185 11/5/85 11/5/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/6/85 11/2/85 11/2/85 11/2/85 11/2/85 11/6/85 1116185 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Mr. C. V. Chatterton, Ch a irma n Page Well Action 2X-1 Conversion 2X-3 Conversion 2X-6 Conversion 2X-7 Conversion ~.~ _7~ Conversion 2Z-3 Conversion 2Z-6 Conversion 2Z-8 Conversion Date Per formed 10/31/85 10/24/85 10/24/85 10/31/85 11/1/85 11/1/85 11/1/85 11/1/85 If you have any questions, please call T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. RECEIVED DE(] 0 6 !985 Alask:..,~ ~, .......... ,~. ~ .... misslol~ A, tuhurage STATE OF ALASKA ALASKA'OiL AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] r~e~(~)p ~/~,tl~ 7. Permit No. 2. Na e SKA, INC. 83-11 0 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20988 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION- 390' FSL, 602 FEL, SEC. 4 T11N, R9E, UM BOTTOM HOLE LOCATION- 1449' FNL, 1320' FWL, SEC. 9, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (RKB) I ADL 25645, ALK 12. 2576 10. Well Number 2X-6 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 24, 1985 Kuparuk well 2X-6 water injector well as part of the effort. Water is being injected into was converted from a producer to a full field waterflood conversion both the "A" and "C" sands. RECEIVED Alaska OJJ & Gas Cons. Oon,,,.m:issJori Anchorarj3 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space below for Commission use Title KUPARUK OPERAT iONS COORD Conditions of Approval, if any: Date 11 / 1 5 / 85 Approved by. By Order of COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Post Office'~-e.~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on september 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted 'to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED o ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKJ. ,IL AND GAS CONSERVATION Cr~__~MISSION SUNDRY'i OTICE$ AND REI:IORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. see attached 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 so- see attached OTHER [] 4. Location of Well N/^ 6. Lease Designation and Serial No. see attached 5. Elevation in feet (indicate KB, DF, etc.) N/A 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11, Field and Pool · Kuparuk River' Field Kuparuk River 0il P0ol 12, Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list o~A/~roducing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion_ to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SEP 2 o 19B5 Gas Cons. Com.m~'ssi°n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /¢~-/~ ~,~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 COMMISSIONER ^pprove~l C_op~... -~ ~ the Commission Date Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate 223 237 239 83- 84 103 109 118 107 110 113 114 83- 80 85 77 38 85-138 107 109 21239 21253 21255 029-20963 20982 20987 20995 20985 20988 029-20991 20992 029-20960 20964 20957 20924 21377 21379 21361 21363 25645 25645 25653 25646 25653 25646 2576 2576 2579 2577 2579 2577 10 10 12 10 12 10 12 12 10 12 10 /1 /1 /1 5/~5 5/85 5/85 /15/85 /15/85 /15/85 /15/85 /15/85 /15/85 /15/85 /15/85 10/15/85 10/15/85 10/15/86 lO/15/85 12/15/85 12/15/85 12/15/85 12/15/85 MARK:0093 RECEIVED S EP2 0 C;O~, Alaska Oil & 6as Cons. ' ":'" Anchorage ARCO Alaska, Inc. Post Offic ox 360 AnchorJg'~,~laska 99510 Telephone 907 277 5637 RETURN TO: Date: 2/05/85 Transmittal No: 4824 ARCO ALASKA, INC. ATTN: Records clerk ATO-1115B P~O. Box 100360 . ~Anchorage, AK 99510 _T_ra~n_s_m~itted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 Gearhart ----2Z-6/ 9/03/84 Otis 2X-6/ 8/16/84 Gearhart '-- 2X-4/ 8/16/84 Camco --2X-lw 8/16,19/84 Camco --2V-5~'" 8/16,19/84 Dresser -~-2V-2~" 9/07/84 Otis ~2F-9/ 8/28/84 Otis / --2F-8~'].. 10/08/84 Camco --2F-7/ 10/07/84 Otis ---2B-l~.?' 9/03/84 Otis · ~-2C-5 / 8/17/84 Otis --1Y-13/ 8/16/84 Dresser flY-9/ 9/07/84 Camco ~lY-5/ 9/14/84 Camco 1Y-5~ 9/06/84 Otis ~lG-6.' '8/25/84 Otis ~lH-4v 9/04/84 Otis --1F-12 ¥ 9/09/84 Otis ~-lF-9~' 8/17,18/84 Camco <-lF-8z 8/16,17/84 Camco / --1E-8~ 10/12/84 Otis ~-lD-5/ 10/07/84 Camco '-lA-4/ 9/02/84 Otis ~--1A--3/ 9/02/84 Otis Receipt Acknowledged: "HP 232" "F3 233" 9/06/84 "SB ' 9/05/84 8/17/84 8/16/84 10/13/84 10/0'7/84 "Static BHP" "PBU"" "PBU" "SBHP" "E Line" "Pressure Falloff" DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmetl Well Files LUP,;RU,, Ei.IGI,,EERII'IG ': 3,00'7 TRANSMITTAL =. .~. ~ ..... FROM' TO' D. Fay Allison / DATE' ~~ Zd, ./~/ WELL NAME' see below Transmitted herewith are the following' . . PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Wel~l De s c r i pt i on Date Ru_~n. : . PET ACKNOWLEDGED' RETURN RECEIPT TO' ARCO ALASKA, IHC. ATTii' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 · .-,-. L-' z - -: ; DATE' -' ARCO Alaska, Inc. Post Office BOw-360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 17, 1984 Chat Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat: Commission Attached in duplicate following wells at the Well Action are subsequent notices on the Kuparuk River Field: Date Performed 1F-9 1Y-11 1Y-14 SWPT SWPT 2X-1 2X-2 2X-3 2X-5 2X-6 2X-7 Perforation 11/30/83 Stimulation 11/14/83 Production/Injectivity Test 5/24/83 Mud acid wash 11/22/83 Water Injection see attached Perforation 12/9/83 Perforation 12/10/83 Perforation 12/11/83 Perforation 12/12/83 Perforation 12/13/83 Perforation 12/14/83 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (Duplicate) JAN i 8 ]984 0il & Gas Cons. Cornmiscien A,~cho;ago AllCO Alaskn. inc. is a subsidiary of AtlanticRichfieldCempany STATE OF ALASKA ALASKAhDIL AND GAS CONSERVATION COr~fMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL CA 2. Name of Operator ARCO ALASKA, ]:NC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 390' FSL, 602 FEL, SEC. T11N, R9E, UM OTHER [] BOTTOM HOLE LOCATION' 1449' FNL, 1320' FWL, SEC. 9, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (RKB) I ADL 25645, ALK 12. 4, 7. Permit No. 83-110 8. APl Number 50- 029-20988 9. Unit or Lease Name KUPARUK RIVER UN]:T 10. Well Number 2X-6 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL 2576 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~,07 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 12-13-83 perforated "A" sand with 4 jet shots per foot. Intervals' 7135 - 7164'; 7108 - 7122'. 14. I hereby certify that the fo,~egoing is true and correct to the best of my knowledge. Signed ~~ ~~ Title KUPA"UK OPERATIONS The space below for Commission use COORDINATOR Conditions of Approval, if any: 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 KUPARUK ENGINEERING TO: DATE' /, d TRANSMITTAL FROM' NELL NAME' D. Fay Allison Transmitted herewith are the following: PLEASE NCFI-E: BL - BLUELi NE, ..-. Z.×'- ~' S - SEPIA, F - FI UA, RECEIPT ACKNOWLEDGED' ~EASE RETURN RECEIPT TO ARCO ALASKA, INC. ATTN: D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 995].0 KUPARUK ENGINEERING TRA.NSHiTTAI '-' - ,= D. Fay Allison Transmitted herewith are the following' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TA~ R~C'~I PT ACKNOWLEDGED' LEASE RETURN RECEIPT TO' ARCO ALASKA, IHC. ATTIi: D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 Ix'lJPz'-~qJK ENGINEERI ix;C; TRANSM ~ ~TAL '-' TO: DATE: , lVi I I iam \/anAl en Transmitted herewith are the followincj- FF~-4: D.W. Bose/Shelby J. ~,~tthews WELL ICA~/~:: - . P-LEASE kOTE-B~- BLUE'LINE,(~- sEPIA, F- F! IA4, T - TAPE, PC - PHOTODDPY' - ~~~~: P-LEASE RETUPdXl RECEI F~F TO: ARCO A~I~, ! !',~. ATrN: SHELBY J. ~,~TTI-IB~,G - ATOI 1115-B P. O. BOX 100360 At, EI-DP,~GE, AK. 99510 ARCO Alaska, Inc. Post Office B~"'~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton: Attached are notices of intention to perforate we] !s in the Kuparuk "A" sand: 2X-1 2X-2 2X-3 2X-6 2X-7 If you have any questions, please call me at Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) the following 263-4527. ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA'O'iL AND GAS CONSERVATION C~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-110 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20988 4. Location of Well SURFACE LOCATION' 390' FSL, 602 FEL, SEC. 4, T11N, R9E, UM BOTTOM HOLE LOCATION' 1449' FNL, 1320' FWL, SEC. 9, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (RKB) I ADL 25645. ALK 2576 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2X-6 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforat.e the fol lowing Kuparuk "A" Sand intervals using 4 SPF through-tubing guns. Interval (MD) 7108-71221 7135-71641 A 3000 psi lubricator will be used be pressure tested prior to doing fluids will be diverted to tankage Expected Start Date' on all wireline work, lubricator will the work. All circulated and flowed on location. S~seO, ue~t Work ~eportecl 14. I hereby cer~fy~that the forego',mg ~ true and correct to the best of my knowledge. The soace below for Commission use OPERAT IONS COORD I NATOR Date Conditions of Approval, if any: Approved by ORIG;H~,L SIGNED BY LONNIE C, SMITll ' Approved Cop)' Returned 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, Inc. Post Office B~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 18, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2X-6 Dear Mr. Chatterton: Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:tw GRU4/LI08 Enclosure RECE VE J Gas Cons. Commission Anchorag~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '- '~ ~""' STATE OF ALASKA '--'" ALASKA-_.,t' AND GAS CONSERVATION C( MISSION /I ELL COMPLETION OR RECOMPLETION REPORT AND LOG ' 1. Status of Well Classification of Service Well OI LX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-110 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20988 · 4. Location of well at surface ,TT~~ 9. Unit or Lease Name 390' FSL, 602' FEL, Sec.4, T11N, RgE, UM~AI~ONS~ Kuparuk River Unit At Top Producing Interval , 10. Well Number 1398' FNL, 1648' FWL, Sec. 9, T11N, RgE, UM j Surf.__l~__~ 2X-6 ~ B. FI, __~__ j At Total Depth 11. Field and Pool 1449' FNL, 1320' FWL, Sec.9, T11N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKBIADL 25645, ALK 2576 , 1~. Date Spudded07/27/83 08/02/8313' Date T.D. Reached 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re I i6' N°' °f C°mpleti°ns09/25/83 N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7675'HD,6400'TVD 7550'MD,6289'TVD YES'il NO []I 1943 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/CNL/GR/SP/Cal/FDC, CBL/VDL/CCL/GR, Gyro. 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 112' 24" 248 sx AS II 9-5/8" 40.0# J-55 Surf 3308' 12-1/4" 1250 sx AS Ill & 250 sx iS I 7" 26.0# J-55 Surf 7642' 8-1/2" 375 sx Class "G" & 350 s; AS I 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) 6942' - 6992' w/12 spf 3-1/2" 6866' 6842' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ,\ 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'r) Press. 24-HOUR RATE ~ ~8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Anchorage Form 10-407 GRU4/WC13 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand. Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 6941' 6984' 7087' 7230' TRUE VERT. DEPTH 5746' 5784' 5876' 6004' 30. FORMATION TESTS "' Inclu de interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History~ Completion Summary_, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Dri 11 ing Engr. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 2X-6 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1300 hrs, 07/27/83. Drld 12-1/4" hole to 3349'. Circ and cond hole. Ran 85 jts 9-5/8" 40# J-55 HFERW BTC csg w/shoe @ 3308'. Cmtd 9-5/8" csg w/1250 sx AS III & 250 sx AS I. Bumped plug w/1500 psi - floats held - ok. ND Hydril. NU FMC wellhead & BOPE, tstd BOPE to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt, tstd csg to 1500 psi. Drld FS & 10' new hole and ran leak-off tst 11.7 ppg EMW. Cont drlg 8-1/2" hole to 7484'. Ran triple combo log. DIL/SFL/CNL/GR/SP/Cal/FDC f/7454' to 3307'. Cont drlg 8-1/2" hole to 7675' TD on 08/02/83. Ream hole f/7611' to 7675'. Circ & cond hole. Ran 194 jts of 7" 26# J-55 SMLS BTC csg w/shoe @ 7642'. Cmtd 7" csg w/375 sx Class "G". Bump plug w/2000 psi - floats held - ok. ND BOPE. NU FMC wellhead & tstd packoff to 3000 psi. Arctic pack 9-5/8" x 7" csg w/350 sx Arctic Set I & 67 bbls Arctic pack. Secured well & released rig @ 2200 hrs on 08/03/83. HILL/DH36 09/14/83 2X-6 COMPLETION SUMMARY RU Dresser-Atlas. Ran CBL/VDL/CCL/GR f/7495'-5750'. Ran Gyro f/7450'- surface. RD Dresser-Atlas. Secured well. Accepted rig @ 1200 hrs, 09/20/83. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran 3-1/2" completion assy. ND BOPE. NU tree & tstd to 3000 psi - ok. Opened SSSV. Disp well w/30 bbls diesel followed by 211 bbls Kuparuk crude oil. Set packer. Ran Temp. Survey/CCL/Spinner/GR. Found that primary shear pins had been sheared. ND tree. NU BOPE & tstd - ok. POOH w/tbg hanger & tbg. Disp well w/brine. Latched onto pkr & sheared out. POOH & LD pkr and Geo-Vann assembly. Reran 3-1/2" completion assembly w/tail @ 6866', pkr @ 6842' & SSSV @ 1943'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/Kuparuk crude. Set packer. Closed SSSV. Dropped bar & perforated the following interval: 6942'-6992' w/12 spf Flowed well to clean up. Installed BPV. Secured well & released rig @ 2400 hrs, 09/25/83. GRU4/CS12 F~F'ERRY-SLIN WELL ._,LIRVEYING COMPANY /~,.~.z,.,~,": ~ ..... ~"- 0i~ ~ Gas Cons.. CoL~ts:.~ ANCHORAGE ALA.z,k.A'- .... ARCO ~LA'.3K~ INL. URFUR~TE~ ...... 2X-6 (.=,E_. 4 TllN ROgE) COMF"UTATION DATE '"'1 '-' ' 9/- q,,~ c, KLIPARUK ALIuJ.=,]..__., 1 ........ ~LASKA VERT'IF:AL :BERTInN CALCULATED ALONGL. Lu.:,L'-' IRE DATE OF SURVEY AUGUST 24, BOSS GYROSCOF'IC SLIRVEY dOB NLIMBER AK-B0-300'.;'5 I<ELLY BUSHING ELEV.= OPERATOR- E. ' SELLERS TRUE ::~L IB-::-;EA L. uLIR._ E L. JLIR.:.E DOG-LEO ~EEA:31_IRED VERT I CAL VERT I CAL I NCL I NAT I ON D I RECT I ON ._ EVER I TY )iEPTH DEPTH DEPTH DEG M I N DEGREE.'E; DEG/100 TOTAL. REC'¥ANGUI_AR COORD I NATES NORTH/SOLITH EAST/WES]' C) 0.00 -106.00 0 () N O. C) E 0.00 .1. (") 0 1 (") 0 0 0 -6.0 0 0 '-"" . .:,,:, N 19.60 E 0.64 200 1 '-} 9 9'-.-, '--~ ::: '.~ 9 0 '~= N I '-' 8'~ ,- E 0 ~ 09 · . . # . . ..., ~ . . ~ ._1 . :300 2'~'..T,'. '.'-.','? 19:]:. '79 0 :31 N 1.5..1. 9 E 0.07 4 00 :::'...-~'.'.'> ':.>:--:2'.~ ::-: '..'-~::: 0 4:3 N ':":' ::: 9 E 0:2---' o -- . . # .... . . -- ._.._1, _ . , -. 500 49'?. 97 393.97 0 52 N 21 ~ 19. E C) ~ ,=...'---":~ 600 59'F,. 96 49:3.96 0 15 N 21,5C) W 0.70 .... 4. 0 W '" 7(:) 700 699. '? 3 593.9 ::: 2 37 S M :s:00 799, 73 693.73 4 24 ,.z; 55.89 W 1.79 ':~0() 899.15 793. 15 7 47 S 63.5(:) W :3.47 1000 997.66 891.66 11 51 :-': 6,4. 0 W 4.06 11. 00 1094 · 72 '-~,-~o'-"-'. 72 15 ~ = ~- AO. M' _ ._t) W 4 16 1200 11._,.°:'"-7, 99 ...... 1 ¢')A3.99 1 '? 25 S 55.60 W 3.79 13(:)(:) .1. 2:::3. qP, 1177.3::: '-."-' :~A S ~ .. 5c) W ,~.. M/- ':' 21 'R 42 '-' ':' 42 ':'/- '-~, 48 14. C) 0 1._74 I 4 S 57 1(] W .~._1 · . . ._ . .1. 5c)c).. 1463 . ..'.:.'"'-' 1 .:.._'-'?]7.2:.-.: 2:.-.: 36 S 56 .19 W .."-'. 55 1 ~:,C)0 1550.56 1444.56 29 41 S 55.80 W 1.11 .... ~ . 0 _1. 7C)0 .1. 636 72 1~3(] 72 31 1:3 S ._ 7 I W 1.75 1 :--:00 1721.21 1615.21 :]:'2 1 '.-.-/ S 57.1 '.-.-/ W 2.02 1 '~0C) 18C)3, 51 1697.._~ 1 ._,~':'~ 51 .'--'~ ~-~ :,. 60 W 2 .5~ 2000 188:3.08 1777. (:)8 :38 41 :z: 56. 0 W 2.85 2.1. 00 _1. 'F."5'?. 75 1853.75 41 '? .S 55.69 W 2.48 '-'C '-' 91 9'28. '? 1 220C) -.' .).:,4. I 41 22 :--; 5.5.60 W 0.2:.-.: :2.300 2109.84 2003.84 41 3:3 S 57.50 W 1.27 2400 .2184.73 2078.7:3 41 26 S 55.89 W 1.07 25C)(':) '--'."25'?. 66 2153.66 41 28 S 56. 0 W 0. (:)7 2600 2 :_:: 34.57 .- ....._.'-"':"-"':'. 57 41 :]: 0 :_:: ~_ A_. 19 W 0 . 1 ._.':' 2700 2409.40 230:3.40 41 36 '.--: 56.19 W ' 0.11 :2800 2484.20 2:378.20 41 .34 '.3 5/".. 19 W 0.04 · .' 4._,-.'. 7:.-.: 42 2 'F..' 00 .."'" ~, ~ ._~ o'-'. 7:3 '-' = '-' :3 S ._~ ._~. :3 '? W 0 . ?,.- ~';' F'AGE I 198:]: 1 (':)6.0 C) F T. V E R'T I C A I_ S E C T I 0 N 0.00 0.00 0.00 0.53 N 0.19 E -0.42 1.55 N 0.49 E -1.18 :2.49 N 0.'72 E -1.::33 3.46 N 1.19 E -.:::.". 7(:) 4,69 N ' 1.81 E -'.:::.84 5.61 N 2.00 E -4.45 4.48 'N 0.(:)7 E -2. :21 0..'::'8 N 4.97 W :3.8'.-.-' 4.2(:) '.L:; 14.22 W 14.49 11.7:_'-: S 29.52 W :31.52 23.00 S 50,70 W 55.51 39.15 S 76.37 W 85.7'.-.-' 59.16 S 106.12 W 121.50 81,72 S 140.62 W 162.59 106.97 S 178.96 W 208. :i::5 134.20 S 219. :.-.:4 W 256.84 162.24 S 261.64 W 307.41 191.2:'-: '._--; 306.54 W 360.72 222.24 S 354.09 W 417.32 255.85 S 404.4'7 W 477· 65 291.87 S 457.56 W 541.52 329.09 S 512.(:)2 W 607.16 365.59 S 567,27 W 67:3.15 401.96 '.--; 622.65 W 739.20 439.04 S 677.51 W :,,,:(i)5.13 475.99 S '732.50 W 871.11 51 '2. :-'-:9 :_-'; 7:--:7.62 W 9:::7.18 549. :32 :::; :342.7::: W 100:3. ::::0 587.05 S 898.08 W 106'?.68 · _FERRY-oL.N WELL "' ' oLIRVEYING F:OMPANY ANCHnRAGE ALARk'.'A VERTICAL 'SECTION CALCULATED - P ALuN., CLOSLIRE C'OMF'UTATION DATE AUGUST 26, 1 '-?'-'"'.-. ,=.._-, F'ALgE '2 DATE OF SLIRVEY ALIGUST 24, 1'F~83 BOSS GYROSCOPIC SURVEY ,..lOB NUMBER AK-BO-300'?5 KELLY BUSHING ELEV. = :1.06,00 FT. OPERATOR- E, SELLERS ] R _IE .,. UB-.=,EA UU _IR.=,E ~EAA';I_IR ED VERT I CAL VERT I CAL I NCL I NAT I ON ~IEPTH DEPTH DEF'TH DEG M I N COLIRL=;E .. 'ri I RECT I ON DEGREES DOG-LEG '.SEVER I TY DE A / 100 TOTAL RECI'ANGLILAR cr'/ORD I NATEF.; NORTH/'-'- ~ ' .=,l_l _Il' H lEAST/WEST VERT'I CAi_ S E C T I 0 N 3000 2632.92 2526.92 42 :3100 2707· 00 2601.00 42 14 3200 2780.66 2674.66 42 52 :'.:.: 30 (') 2853 '-? 2 :;-2747. '-? '--' 42 5 ::, 4..) (.) ';' '-.? ';'/-, '- ~' ~.,_, ..'--"="~' 0.. 9543 16 3500 2'.;'.99. 86 2893.86 43 6 3/_-,00 3072.95 2766· 95 42 58 :L::700 :3146 16 '-' ' ' . o04O 16 42 3800 321 '~ · 57 3113 · 57 42 37 3'.-.?00 3293.33 318'7.33 42 1 4000 33/=,7 · 32 32/=, 1.32 42 14 4100 3441.59' 3335.59 41 50 4200 351/=,. 41 3410.41 41 18 4300 35? 1.73 3485 · 7:2: 40 57 4400 36/_-,7.40 3561.40 40 40 4.5('~0 3743 27 ""/-'-' · .... z, :,.:,7 27 40 37 4600 381 '.-}. 35 3713 · 35 40 17 4700 3895.87 3789 · 87 39 52 4800 3972 · "?'6 386/=,. 96 39 15 4'~00 4050 · 66 3944.66 38 45 5000 4128 · 93 4022 · 93 38 13 51. O0 4207.75 4101.75 37 44 5200 4287.03 4181 · 03 37 22 · -! ! 5:Z-:('~0 4._-,,=,6 · 55 4260.55 :'::7 16 5400 4446.51 4340· 51 3/=, 31 5500 4527 · 24 4421 · 24 35 47 56F~0 4608.59 4502~ 59 35 20 5700 4690 · 57 4584 · 57 34 30 5800 4773.22 4667.22 34 1 59'00 4856 · 48 4750 · 4.8 33 15 S P?= A'.-.'¢W S c:.~ /-,9 W · '=; 55,/..-,i~ W .... -' .-'-) W S 55. OW S ~'~ .'_::'F/ W '-' 55 20 W S 55.50 W S 55.50 W S ~";.'~ '-'"? · - ,- · ,.2, .'. W S 55.6'~ W S 55.8C) W S 56.39 W S ~/' o =,. 1 '.-.? W S W 56.5(.] ~--; 56.69 W S 57.1(.') W S 57.6'~ W · _,,=,. 19 W S ~'=' A0 W S 58,89 W ,.~ ~,- , - ._.-~.19 W S 59, 60 W S 59, 8°.~ W ~--; 60,50 W S 61,1'2 W S 62,30 W '.--; 62, 0 W .=,'-' 6:_'-:, (]. W '--; 64,.1'2 W (').. 11 62: 4.. 64 ._, '=' '::'~. Pi_._.":,' 61 W 11 :'-': 6, 4. 4 0 16 6A2.4(] S 100'? 16 W 1""-'-' '-") ,, _ . · ...:~ (..)..:,...:, (. 0.64 700.51 S 1065.04 W 1:270.61 0.14 ~/.:,'-',=, '':' . '.;¢ A ...... S 11:21.19 W 1 :'4 :--: :=:. :}.': 4 0.51 777.?C) S 1177.32 W 14.06.27 0 3 ~: b: 16. '.~6 S .-,.-,.-, 75 c, · ' ' 1~._-~....= W 1474. q°._._, C). 14 '='.=,~ 77 ~R 1 =,_, .~ 67 W 1 ._ 4~. 21 ,_,0. ~. · _ "?.'~" · ~ '-, 0.16 894.4.5 ._.q 1345 .74 W 1/=, 0 '.~ . '-?.. ,_ 0, 27 '~..._'7_';,..91 S 1401.70 W 1677. ~._,..-.,'-' 0.._, '~'._,':' '.-.? 71 .20 ._,R 1457 . :'_41 W 1744. .70 0 21 1009 .-.'-'._, ~- S 1.-q . o 18 ._ .... 12 7 .... W 1 :L 6:..]: 0.41 104/,, 94 S 1~- '-" 1~ W · 3 60 '· '-' -' '-' _ ' 1 ,=,/,=,. 28 0.67 1 (')'-"" - ' . ,=,...~. 'Y 5 :~ 162 :]':. ~'" 1 W 1 ? 44 .36 0.36 1120 45 '-' . · .=, 1677.9::: W 2C)09 89 R . S 732 34 ';'(')7~. ('):.7 0.34 11._6 67 I . W ...... 0.14 11 '-?? R'-' _. . y._, ....... _- S 178/-, 73 W 2139 0.4 :'-: 1227. '..? 7 S 1841.0'.'l) W 2204.65 (]). 57 1262.66 S 1875.33 W 2268.8'.~ 0.6 ? 1296.46 S 194'..~. 3'2 W 2 :--: :_--: 2.47 0./-_,._, '=' 1 '~'--"'-? . :_'-: 5 S 2 C) 02. "~ '-? W 2 :--: 9 R 34 0.54 1:}61.54 S 2056. ';25 W :2457.52 C) F, 1 1393.1 '-? S 210'?. 0 ::: W '-' ~ '-' 1 ...... -" ._, 1 .'.', 0 0 44 1424 22 S :2161 49 W '-'.~; . . . . ...._ 79 9:'_:: .. . s 2/.4o 54 (') 2(') 14._4.77 S 2213.87 W _ .. 0.83 1484.61 '._--; .... _,._'~- ';'/- .~. ';-* 7 W 270 C). R_ :=:_ 0 '=' R 1 ~ 13. '7.~ :--; 2317 F, F) W 27 .~, ii t_,._ .. ,_ ,_ · -- . ._ .. · - - 0,78 1= (' - · _,4 _), 88 :_--; 2368.73 W 'ZA 17.74 0. :q.~ 1 .q 241 '.-7, :35 W 2874 _ _ 567.63 .... 0.75 157:_--:. 63 S '.;:469.2';? W 29 }:1.27 1.02 1618.26 ~q_ ..._":'~ 18 . :q_ 9. W 2'? :--:6.61 ....... E;PERRY-'SUN NELL SLIRVEYINA ~_.UMPANY ,:..,,~=.,..,~.. .. ANL. H_]RAE~E ALASKA AR_.O ALAol-...A INCC~RF'nRATED ...... : 2X-6 (SEC 4 T11N ROSE) COMPUTA"I'ION DATE KUPARUK AUGUST 2/:,, 1983 ALASKA VER]"ICAL SECTION CALCULATED ALONG CLOSURE TRUE SUB-SEA COURSE -.~EA.SURED VERT I C:AL VERT I F': .AL I NF:L I NAT I ON ,I~EF'TH DEPTH DEPTH DEG M I N DATE OF SURVEY AUGUST 24, B J :'-,.:, G Y R ri S C: 0 P I C S U R V E Y ,_lOB NUMBER AK-BO-:30095 KELLY BU'.-':;H I NG ELEV, = OPERATOR- E, SELLERS; COURSE DOG-LEG TOTAL D I RECT I ON SEVER I TY RECTANGULAR COORD I NATES BEGREE~:; BEG/100 I',IORTH/SOUTH EAE;T/WEST PAGE :3 198:':: 1(')6.00 FT. VERT I C:AI_ SECT I ON 6000 4940.33 4834.33 32 46 S 65.50 W 0.85 1641.42 S 256,8,21 W 6100 5024.42 4918.42 32 44 S 66.10 W 0.3::: 1663.60 S 26.17.56 W 6200 5108.49 5002.49 32 49 S 67.39 W 0,71 1684.97 S 2667.31 W 6300 5192.6.5 5086.6.5 32 3:3 S 68.6_-.0 W 0.71 1705.20 S 2717.39 W 6400 5277.00 5171.00 32 26 S 70.80 W 1.19 1723.84 S 2767.76 W ,' ~;' .. =;:-, ,.].-,~=; - ,'-'.._ L)L) ....-.61 64 5:_-: 73. W 1, . ~ · _ -'... 64 :-": 1 S 80 69 1740 ~ ' '-' _ - - L)._~ S ,:'""'-'18,_~ 4A W 6600 5446.87 5340.87 3~. 9 S 76. 0 W 1.37 1753.66 S 2868.94 W 6700 5533.07 5427.07 29' 45 '._:; 77.30 W 1.56 176.5.37 S 2918.25 W 6800, 5620.43 5514.43 28 29 S 78.39 W 1,3'7 1775,62 S 2965.81 W 6';.~00 5708.95 5602.95 26 55 S 78.89 W 1.59 1784.78 S 3:011. :3'? W 7000 5798.16 5692.16 26 48 S 80. :39 W O. 69 1792. '.-'..~0 S :3055. :-::4 W 7100 5887.46 5781.46 26 40 S 80.69 W 0.19 1800,29 S 3100.22 W 7200 5'.776.92 5870.92 26 25 S 80.60 W 0.24 1807.55 S 3144.33 W 7300 6066.45 5960.45 26 27 S 80.39 W 0.09 1814.90 S 3188.25 W 7400 6155.76 6049.76 27 I S 81.30 W 0.69 1822,05 S 3232.67 W 745£) 6200.22 60'.-74. :22 27 25 S 82.19 W 1.16 1825.33 S :3255. :31 W 7500 6244.60 6138.60 27 25 S 82.19 W 0.04 1828.46 E; :3278.1:3 W 7600 6:3:33.36 -,'-'"'-' 25 .... 6..--.-,,.2:6 27 S 82 19 W (') 02 1834 71 S 3:323 77 W 7675 6399.92 6293.92 27 25 S 82.19 W 0.03 1839.40 8 3358.00 W 3040.98 3C)94.93 314:3.83 :3:2('.')2.46 :32!55.6£) :':: :30'7, 84 :3358.6.6 3407.53 3454. 18 :34'78.55 :3541.4:3 :35:_::3.91 3626.08 3668.13 3710.52 3731. '75 3753.47 37'~6,. 50 382:-::. 78 HORIZONTAL DISPLACEMENT = 3828.78 FEET AT SOUTH 61 DEG. 17 MIN. WEST AT MD = 7675 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF E:URVATURE METHOD. ARCO ALASKA INCORPORATED 2X-6 (SEE: 4 T11N ROgE) I<L~F'ARUK ALASKA ..FERRY-L=;UN WELL .'::URVEYING C'OMPANY ANL. HuRAe E ALASKA COMPLITAT ION. DATE A U G U S T 2:6, 19'8:2: DATE 'OF SLIIi;:VEY ALIGLIST 24, ,_10 B N LI I'1B E R A K - B 0-- 30095 KELLY BUL-.;HING EL. EV. = 8--° · . . ~.,~ OPERATOR- E, .:,ELI_ER~ 1 (')6.0() F T. INTERPOLATED VALUES FL R EVEN 1000 FEET OF MEASIJRED DEPTH .)'IEA?=;LIRED DEF'TH TRUE SLIB-SEA TOTAL VERT I F:AL VER]" I F':AL RECTANGLILAR C:OORD I NA'FES M[I-TVD VERT I E:AI_ DEF'TH DEF'TH NORTH/SOLITH EAST/WEST DIFFERENCE C:FmlRF(EC:T I ON () 0. (')0 -106.00 0.0(:) ("). 00 0. ¢)0 ,-,9 2~,. ~'F.' W '-' 34 100() 997.66 ,:..~ I 66 11 '7:2: q '=' :34 20 C) C) 1. '-"-"-' (")::: 1777 ¢) 8 '-"-q '= '-' ,. ..... ,..:,._, ::; 4¢)4.4'7 W 116 92 1:L4 ~9 ,:,,:)."8 ,, . - , · . , .- . :300(:) 26:32. '-.':;"=' '='~':'/-, '-'.:.'2 624 64 S '~;"53.61 W .:, :, 7. ("):=: 25() 16 -" ,z./=,.:., &C) 4C)0¢) :2:367. ':":' :2:2/, 1 ::::z 100'F/. '-'":" '" 1512 7,'_.=.' W /_-,32.68 · '"" '- # ~ .,.I ..?.. · 5000 41..- ,_,':":'. 9 .... 2 4 ('~ 22.93 1 ~, ~. 1 .54- ._'=; ,.' ¢~,., 6 .25 W :371 .07 2:2~ 8 · 40 8'~, (" ,':8.":8 ~1:~ Y .%"8 600¢} 4 y4 .) 48:=:4, 33 1641 42 S 188.60 .._,._, . ,.._,o,:, .21 W 105?. 67 7('1()0 ._.~ 7':'~:::.. ..... 16 ~A'.-}2.16 1792. '.~0 S .=,'-'¢J" ,-.'=;~._,, 84 W 12~:~ 1 , ,_,':'4 142 · 17 7,/-, 7.:; ........ ,/-,:'::9':F~ .92. 62'.-7,'3 . '~2.. :i.':' ':' c~,_, ._. .. · 40 S .:,""-' ~'-'._- ._ c,. 0() W 1~7~'-' ~ .08 7:2: .24 THE C:ALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADILIS OF 'CLiRVATLIRE METHOD. ' ARCO ALASKA INCORPORATED '-' ~ ":' I-' .::X-6 ( .... E_. 4. Tl lN R09E) KLIF'ARLIK ALASI<A · =,FERRY-c, UN WELL :-.] I-', -'- , · .. L RVEY I NG L. uMF ANY ANE:HORAGE ALASI<A COMPUTATION DATE ALIGUST 26, 198::: F'AGE 5 DATE OF ._-,LRVEY AUGLIST 24 1'F~8:'_.:: ,J 0 B N I_1M B E R A K- B fl- :':: 0095 KEI_LY F._-~USHII'46 ELEV. = .1.06. ()0 FI'. OPERATOR- E. SELLER'S IN)ERFLLA~EDVALLE.:, FOR EVEN 100 FEET OF oLB-.:,EA DEPTH )tEASURED DEPTH 'I'RUE VERTICAL. DEPTH 0 0. O0 106 106. O0 206 206. O0 3()6 306.00 406 406.00 506 506. O0 606 606.00 706 706.00 806 806. O0 906 906.00 1008 1006.00 1111 1106.00 1217 1206.00 ~u6 00 13:24 1 '"" . 14:35 1406.00 · _:, 4 ,:. 1 .~ (]/-.. 00 1664 160/_-,. 00 17,'_--: 1 1706.00 1903 1806.00 SUB-F;EA TOTAL VE:R'f' I CAL RECI'ANGULAR ROORD I NATES MD-TVD DEPTH NARTH/SOUTH EAST/WEST D I FFEREN~E:E -106. O0 O. O0 O. 00 O. O0 0.00 0.59 N 0.21 E 0.00 100.00 1.61 N 0.50 E 0.01 200.00 2.55 Iq 0.74 E 0.01 300.00 3.52 N 1.2:3 E 0.02 400.0'0 4.77 Iq 1.84 E 0.03 500.00 5.A1 N 1.97 E 0.04 600, 00 4.31 N 0,16 W 0-08 700.00 O. 6'....v N 5.40 W 0.29 800.00 4.64 S 15.10 W 0.92 900.00 . 12.54 S :31.14 W 2.53 1000.00 24.65 S 53.55 W 5.75 1100.00 42.39 S 81.11 W 11.01 1200.00 64.48 S 114.19 W 18.65 1300.00 90.11 S 153.60 W 2'?.16 140().00 120.01 S 198.41 W 42.76 1500.00 152.'09 S 245.95 W 58.05 160 0.00 · '-'.=,, ..... 1.=.._ :32 S '.-.'9:=:. 14 W 75 79 1700.00 223.24 S 355.61 W 97.08 VERT I CAL CORRECT I ON / O. O0 0.01 0.00 0. O1 0.01 0.01 O. 04 0.22 0.63 1~61 3.22 5.26 7.64 10.51 1 :z:. 60 15. '~'-':' 17.75 21. c..,9 ARCG ALASKA INCORPORATED 2X-6 (SEC 4 T11N RO'PE) KUF'ARUK ALASI<A 5FERRY-.:,JI',I WELL SURVEYING COMPANY ANCHORAGE ALASKA COMF'UTATION DATE (4 LIG U S T 26, 1 '.98 ::: PAGE 6 DATE OF: SURVEY AUGUST 24, 1'.::,8::: .JOB NUMBER AK-BO-:30095 KELLY BLISHINO ELEV. "= .1.06.0() FT. OPERATOR- E, SELLERS I NTERF'OLATED VALUES FOR EVEN 100 FEET OF :3LIB-SEA DEF'TFI ~)EASI. IRED DEPTH TRUE VERT I CAL DEPTH ~:.';UB-SEA TOTAl_ VERT I CAL RECI'ANGLILAR CCIORD I NATES MD-TVD DEPI'H N L~R1 H/SOLITI~ EAST/WEST D I FFERENCE VERI' I CAI_ CGRRECT I GINI 2029 :2161 22':':?4 2428 2561 26:,~5 2829 2'?~63 30'.-7~8 3234 3371 3508 3645 3781 3'.-.-~ 17 4052 4186 4318 4450 1 '.-.?06.00 2006. O0 2106. O0 2206.00 2306.00 2406.00 2506.00 2606.00 2706.00 :;:_"806. O0 2906. O0 3006.00 3106.00 3206.00 :3306.0¢) :3406. O0 :3506. O0 3/_-,06.00 3706.00 1800.00 266.11 S 41'~. 6'.-.-~ W 12:3. :::7 1 '.~(')('~ .... .00 ._,"-' 14.7¢]. ...,':' 49 .1. .0.1. W 1 ._~.... 47 2000. (3 ...... 0 ._,':' 1-_,._,':' 76 S ~/-, 4 40 W 1 '-':,o '=' . :--:'7 -- " .-i I'! '-- -' '-- ,~f 21 (')0. (")0 4,12.5£) S 6..:,,-,. 21 W ~:Z.Z.._,,_i 220(').00 461 '~3 c. 711 ._,.~ W ,_! · 2300.00 ._.~, 11 .21 :'-'; 7,--,~.,. 1 l'-"= W ~.":":"~',_, ... 4.5 2400.00 ~./-,_ (')..._H,~,:--' :--; :::_ _ _. ~...,~ :~ ':~ ~' W ~., ...-,':'":' ':' . 1 ,_, ~' '-~',""')¢').00 610.77 -~ '.,'~3:3 42 W ';=-' 68 ,i.. ..... · ._ ..#1/ii 2600 (')0 661. :-]'-" ' . :37~2./- F] · ,_ ~:, '.--; 1 ()(')::: 41 W .... 27¢)0. (')0 713.77 S 1084.48 W 42:3.._F,':,,_, 2:--,'(]('). 00 766.5:3 S 1161.16 W 465.22 .......'29 (") ('). 00 820 ',~';' E; 1 .' ~,_-,'-"-"-'.."-'~._ W 502.41 i'"1 .-! , . .. -,- .. ii 3000.00 .:. 7._~. 29 S 1:314.9'--, W .~':~"~ 17 3100. (') ¢) ~'-' ~' 1:3'? . .. ~:._,. 83 '.--; I 41 W 575.56 :2:200.00 977.75 :--; 1466.80 W 611.1 :--,: 3:300.00 102'.-.-~. 00 S 1541.75 W 646.2(:) :_::4(](') 00 1078.89 S 161 ~ ~':~ W 68(:). 1 ~ # . · --- w -- ,. :3500.00 1127. :34:3 1688.23 W 712. '.-?(:! :3600.00 1174.96 S 1760.01 W 744. :_--."~ 26.2'~ 32.10 33.40 33.51 33.47 33.60 :_'-::3.7 () :_--:4.54 34. '~6 35. '.-.? 4 36.64 37. 19 36.77 36. :38 35.57 35.07 33. '95 32.75 31. '.~".-.-, ARCO ALASKA INCORPORATED 2X-6 (SEC 4. T11N ROgE) I<UPARUK ALASKA SPERRY-SUN WELL ~'E:URVEYING COMPANY ANRHORAGE ALASKA DATE OF SURVEY ALIGUS'I' 24, COMF'UTATION DATE ALIGUST 26, 1':.-~83 ._lOB NUMBER AK-BF~-30(]97-; KELLY BL.:,HING ELEV = OF'ERATFIR- E. SELLER~E; INTERPOLATED VALUER FOR EVEN 100 FEET OF SLIB-SEA DEF'TH 106.00 FT. TRUE '~IEASURED VERT I CAL 'DEF'TH [ EF YH SLIB-g;EA TOTAL. VERT I CAL RECTANGULAR L. UL RD INA rE.:. MD-'I"VD VERT I CAI_ - ,. ::;- ~:; ,-. DEF'TH NUR] H/._ UUTH EA.- T/WEoT D I FFERENCE CORRECT I ON 4582 3806. O0 4713 3'.-.'~06. O0 4842 4006.00 4'.~70. 4106.00 5097 4206. O0 5223 4306.00 5349 4406.00 !547:3 4506.00 5596 4606.00 5718 4706. O0 583'~ 4806.00 5'F,'59 4906. O0 6078 5006. O0 6197 5106.00 6315 5206.00 64:::4 5306. O0 6552 ._,4C~ ~-. 00 6668 5506.00 6783 5606.00 3700. O0 1221.82 S 1831.59 W 776.4'F7 31.60 3800.00 1267.18 S 1902,49 W 6:07.20 30.71 3900.00 1310.68 S 1972.26 W 836..66 29.46 4000.00 1352.22 S 2040.7'.-.? W 864.81 28.15 4100.00 1392.50 S . 2107.86 W 891.79 26.97 4200.00 1431.55 S 2173.99 W 917.87 26.09 4300.00 1469.76 S 2239.80 W 943.54 25.66 4400.00 1505.98 S 2304,08 W 967,81 24.28 4500.00 1540.03 S 2:367.11 W 9'.-.70.83 23.02 4600.00 1572.61 S 2428.71 W 1012.72 21.89 4700.00 1603.67 S 2489.00' W 1033.55 20.83 4800.00 1632.24 S 2548.09 W 1053.17 19.62 4':.?00. O0 1658.80 S 2606.73 W 1072.10 18.93 5000.00 1684.35 S 2665.83 W 1091.04 18.94 5100.00 1708.31 S 2725.32 W 1109.84 18.80 52(:)0.00 1729.90 S 2785.17 W 1128.37 18.5:.3 5300.00 1747.59 S 2844...02 W 1146.20 17.84 5400.00 1761.97 S 2903.15 W 1162.82 16.62 5500.00 1774.05 S 2958.14 W 1177.59 14.77 ARCO ALASKA INCORPORATED 2X-6 (SEC: 4 T11N ROgE) I<L~PARUK ALASI<A · _FERRY-._-,UN WELL SLIRVEYINC.~ F:OMF'AI',IY -. - , ~ C;..' ANL. HuRAI: E ALA._ I.,.A COMPLITATION DATE Al II]11~:;l '..':':6, 1 '-'",":"--' PAGE 8 DATE OF-' SURVEY AUGUST 24, 1'.~'8:':: ,_lOB NUMBER AK-BO-3()O?~5 KELLY BLISHING ELEV. = 106.00 F'T. OPERATOR- E, SELLERS; INTERF'C~I ATED VALLE.=, FOR EVEN 100 FEET OF .-,LB-oEA DEF"I"H TRUE SLIB-SEA I"OTAL .~IEASURED VERT I CAL REC:TANGULAR C:00RD I NATES; MD-TVD VERT I C:AL DEF'TH DEF'TH DEPTH NORTH/:-';OUTH EAST/WES'I' D I FFERENCE VERT I C:AL CORRECT I ON 6 ::: 9/. .=; 7 ('~/-, 00 = ' ' :::(')~'~ 9 92 W 11 ';'~ 0, A':~ · .,/:,00.00 17:E:4. 49 '" 7C.)()8 .=;'-'P' 00 .=;-,7r,] 00 1. 7'.;':3 5,, ._, .... :, .,,_-, ....... . _ _ ,:' ._"::¢l.~l':~.._ .. , 7.5 W ,,* .....-.,¢-r-.,..,:.. 7,F~ 712~:) .=;,'- ' . ........ ._ .:~ ¢) 6 00 .=;:::~')~'~ 00 18 (:~ 1 7 ? :_=; 31 ~:~ 9 41 W 1214 74 7'2:::2 /:,006. ()0 5':.-/00. Or~ 180'.:.'~. '.-.-~ 1 S :315:s:. 5'.-.-~ W 1226.48 7 :--: 44 /:, 10/:,. 00 6000.00 1818 .17 ':'._, :::_ 2 ~]_ 7 . A_ :~_ W 12:38.18 745/-, 620/:, 00 6100.00 l'~"-'s ~- . o-".- 74 (:; '"'-'='-"' ""'" . ~ ._', ..._,o..:,:, W 1'''='-,' .., U · ._.~'-".. 75/-,'.'.-; Z',:~('~6 00 6200-00 1'~':".-" 78 ~' '-"~'"~ '-'" .......,- ._,.- :=, -',o~.~ .. . 70 W . 1 ,:6o. 1 ,_,o 7675 A::.~,--~ '72 A'~"?'-' 92 '-"""'- - ....... ,:.:.._- 1 40:5 ¢]0 W 1~ ... 08 · . o..:, Y :~AS:~: '::'. 7.=;-, THE CALC:LILATION F'ROC:Ei]LIRE:3 LISE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 I--OOT MD (FROM RADIUS OF CURVATURE) F J INT.=, 1:3. 10 12.10 11. ?6 11.73 11.71 12.33 1:2.66 11. ?0 ARE. J ALASKA INRF~RPnRATED 2X-6 (SEC 4 T11N ROgE) I-:::I_IF'ARLIK ALAL--:;K~ SPERRY-SUN WELL E;LIRVEYING Cr~MF'ANY' ANCHORAGE ALASKA ROMF'UTATION DATE ALIOLIST 26, 1 '-.~,=,'-"-' PAGE 'P DATE OF SURVEY AUGUST 24, 1983 ,_IDB NUMBER AI<-BO-300'P5 KELLY BUSHING ELEV. = 106.00 FT. OPERATOR- E. SELLERS INTERPOLATED VALUEE; FOR ,:,FE_.IAL c,L RVEY. F'OI NTB 'rJEF. TH ]'RUE VERT I C:AL DEPTH SUB-SEA VERT I CAL DEF'TH TOTAL RECTANGLILAR I.-.:00RD I NAI"ES NORTH/SOUTH EASl'/WEST MARKER 6941 6'.-.-~84 7087 '72:30 7450 7550 7675 5745.51 5783.88 5875.85 6003.78 6200.22 6288.98 6399.92 5639.51 5677.88 5769.85 5897.78 6094.22 6182.98 6293.92 1788.35 S 1791.67 S 1799.34 S 1809.73 S 1825.33 S 1831.58 S 1839.40 S 3029.60 W :3048.72 W 3094.46 W 3157.50 W 3255.31W 3300.95 W 3358.00 W TOP UF'PER SAND BASE UPPER SAND TOP LOWER SAND BASE LOWER SAND SURVEY DEPTH PLUOBACK TD TOTAL DEPTH ARCO ALASKA INCORPORATED 2X-6 (SEC 4 T11N R09E) 8TRATIGRAPHIC SUMMARY DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA MARKER TOP UF'PER SAND BASE UPPER SAND TOP LOWER SAND BASE I_OWER SAND PLUGBACK TD TOTAL DEPTH MEASLIRED DEF'TH ]"VD THI _.KNE.:,.:, BKB BKB SLIB-SEA VERT I CAL 6941 5745.51 5639.51 6984 5783.88 5677.88 7087 5875.85 5769.85~ 7230 6003.78 5897.78 7550 6288.98 6182.98 7675 6399. S~2 6293.92 COORDINATES WITH REF. TO WELL. HEAD (ORIGIN- 390NS1_ 602WEL) SEC 04 T11N ROgE 1788. 358 :'::02 ?). 1791.6'.:.~S 3048.72W 179'.-.-~. 348 3094.46W 1809. 738 3157.50W 1831. 588 3300.95W 183?. 408 3358.00W 1) FROM LINEAR EXTRAF'OLATION BELOW DEEPEST STATION. 2) COMF'UTER PROGRAM - ~E:PERRY SLIN THREE DIMENSIONAL RADILIS OF L-:LIRVATLIRE. DATA CALCULATION AND INTERF'OLATION BY RADIUS OF CURVATURE COMF'I_ITATION DATE A U G U ::; T 26 · 19 :::3 DATE OF-SURVEY AUGLIST 24, 1';'8:3 .JOB NUMBER AK-BO-:--:O0'F~5 KELLY BU'..--JHING ELEV. = .1.06.00 FT. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ' '- operator, We~l Name and Number Reports' and Materials to be received by: / ~ -- ~ .~-., ' -Date ReqUired Date Received Remarks Cc~pletion Report Yes. /~ '~c~.--~ 0 ~-~ _ . ? _-.- . , .Core Chips Core Description · Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports l.x~s Run · Ye~ Digitized Data ye3 g~ ~R 2--~3 ? ~{'~' ARCO Alaska, Inc. Post Office E~3'~"100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 12, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-6 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/GRU4L99-tw Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC~_.,VllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLX[] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc, 83-110 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20988 4. Location of Well Surface: 390' FSL, 602' FEL, Sec.4, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 12. 6. Lease Designation and Serial No. ADL 25645 ALK 2576 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2X-6 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). RU Dresser - Atlas. Ran CBL/VDL/CCL/GR f/7495' - 5750', Ran Gyro f/7450' - surface, RD Dresser - Atlas, Secured well, Accepted rig ~ 1200 hfs, 09/20/83. ND tree. NU BOPE & tstd to 3000 psi - ok. Ran 3-1/2" completion assembly. ND BOPE. NU tree & tstd to 3000 psi - ok. Opened SSSV. Disp well w/30 bbls diesel followed by 211 bbls Kuparuk crude oil. Set packer. Ran Temp. Survey/CCL/Spinner/GR. Found that primary shear pins had been sheared. ND tree. NU BOPE & tstd - ok. POOH w/tbg hanger & tbg. Disp well w/brine. Latched onto pkr & sheared out. POOH & LD pkr and Geo-Vann assembly. Reran 3-1/2" completion assembly w/tail ~ 6866', pkr ~ 6842' & SSSV ~ 1943'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/Kuparuk crude. Set packer. Closed SSSV. Dropped bar & perforated the following interval: 6942' - 6992' w/12 spf. Flowed well to clean up. Installed BPV. Secured well & released rig @ 2400 hfs, 09/25/83. 14. I hereby//,///~,r~cAy that the forego~pg is tru and correct to the best of my knowledge. //// /~¢¢¢~ t,/,~.,~ Title Area Signed ----~ ~ *"~¢ .- ~~mission use ConditionTof App., By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 6RU4/SN#9 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPAR~K EF~ ! NEER I h~ TO: William VanAlen FFO~{: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following- . ,/~1 PT AGKNO~/I_EEGED: P-LEASE P, ElqJP~i RECEIPT'TO: ~ A~, I N~. P O. ~X 100360 Alaska. Oil & Gas ~~~E, ~(. 99510 ARC(~ Alaska, ' Post Oft,.,..~E~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Commi ssi on Enclosed are the Monthly State Reports for the 2X-3 2X-8 2X-4 2C-5 2X-6 1G-9 2X-7 1G-10 Thank you. Sincerely, P. A. VanDusen District Drilling Engineer PAV/SH9'sm Enclosures following wells' ARCO Alaska. Inc. Is a Subsidiary of AllanllcRichfleldCompany " - STATE OF ALASKA ' '- 'ALASK-~-'~ILAND GAS CONSERVATION ( VIMISSION MONTHLy REPOR1 OF DRILLING AND WORKOVER · Drilling well [] Workover operation [] XX 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-110 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20988 4. Location of Well at surface 390' FSL, 602' FEL, Sec. 4, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. p^~ ~, ~nc, ov~ ADL ?,;~b.~ AI K 2576 For the Month of August ,19 83 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2X-6 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 @ 1300 hrs, 07/27/83. Drld 12-1/4" hole to 3349'. Ran, cmtd, & tstd 9-5/8" csg. Cont drlg 8-1/2" hole to 7474'. Ran triple combo logs. Cont drlg 8-1/2" hole to 7675' TD. Ran, cmtd, & tstd 7" csg. Arctic Packed 9-5/8" x 7" ann. Secured well & released rig ~ 2200 hrs on 08/03/83. SEE DRII IINC HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40# J-55 HFERW BTC csg w/shoe ~ 3308'. Cmtd w/1250 sx AS II I & 250 sx AS 7" 26# J-55 5MLS BTC csg w/shoe ~ 7642'. Cmtd w/375 sx Class "G". I · 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/CNL/GR/SP/Cal/FDC f/7454' to 3307'. 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE__ ~)¢~/ Area r~,-; i i i,,~ Er, g.~ neetDATE ~iOi aTnEc] ~;sP~grotn ~m~m~Lri~sqiu~Inre~dvft~hr~e1a.~hc~a~e~a~u72~ihi~nremganrnd~ss~n[~t"~tr~i"~f~r~ns~ and must be flied in duplicate with the Alaska Form 10~404 Submit in duplicate Rev. 7-1-R¢~ 2X-6 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1300 hrs, 07/27/83. Drld 12-1/4" hole to 3349'. Circ and cond hole. Ran 85 jts 9-5/8" 40# J-55 HFERW BTC csg w/shoe @ 3308'. Cmtd 9-5/8" csg w/1250 sx AS III & 250 sx AS I. Bumped plug w/1500 psi - floats held - ok. ND Hydril. NU FMC wellhead & BOPE, tstd BOPE to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt, tstd csg to 1500 psi. Drld FS & 10' new hole and ran leak-off tst 11.7 ppg EMW. Cont drlg 8-1/2" hole to 7484'. Ran triple combo log. DIL/SFL/CNL/GR/SP/Cal/FDC f/7454' to 3307'. Cont drlg 8-1/2" hole to 7675' TD on 08/02/83. Ream hole f/7611' to 7675'. Circ & cond hole. Ran 194 jts of 7" 26# J-55 SMLS BTC csg w/shoe @ 7642'. Cmtd 7" csg w/375 sx Class "G". Bump plug w/2000 psi - floats held - ok. ND BOPE. NU FMC wellhead & tstd packoff to 3000 psi. Arctic pack 9-5/8" x 7" csg w/350 sx Arctic Set I & 67 bbls Arctic pack. Secured well & released rig @ 2200 hrs on 08/03/83. HILL/DH36 09/14/83 KUPARUK ~ I NEERI hE; TO: William VanAlen FR~,.4: D.W. Bose/Shelby J. [~tthews Transmitted herewith are the following- PLEASE NO]%. BL - BLUEL I NE, S - SEP IA, F - F I LM,~ PC - FgDT(X~PY ,, / /~IPT AP_J~,OW1 .EF)S : ~,/PLEASE RETURN RECEIPT TO: /¢tCD ALASKA, I h~. Alq-N: SHELBY J. /VATTHEWS - ATO/1115-B P. O. BOX 100360 AhE]-DP~E, AK. 99510 _ ARCO, Alaska, I~, Post Offi¥~..~3ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells- 2X-2 2C-3 2X-3 2C-4 2X-5 2C-5 ~2X-6 2C-6 2C-7 Thank you. Sincerely, P. A. VanDusen District Drilling Engineer PAV/SH8'sm Attachments Aiaska 0il & (~as Cons, Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of Allanl,icRichfieldCompany , - ,~-. STATE OF ALASKA .... O~S ~LASK, ~ILAND GAS CONSERVATION C ,VIMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI 1. Drilling well ~0X Workover operation [] 12. Name of op~erator 7. Permit No. ARCO Alaska, Inc. 83-110 3. Address 8. APl N~l~er 20988 P. 0. Box 100360, Anchorage, AK 99510 50- 9. Unit or Lease Name 390' FSL, 602' FEL, Sec. 4, T11N, R9E, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 77', 106' RKB 6. Lease Designation and Serial No. ADL 25645 ALK 2576 10. Well No. 2X-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool July 83 For the Month of. , 19 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1300 hfs, 07/27/83. Drld 12-1/4" hole to 9-5/8" csg. Cont drlg 8-1/2" hole to 6985' as of 07/31/83. 3349'. Ran, cmtd, & tstd SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40# HFERW BTC csg w/shoe ~ 3308'. Cmtd w/1250 sx AS II I & 250 sx AS I. 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~--~t/ t~-~~ v--- TITLE Area Drilling Engineer DATE NOTE--Repo/ oll~t~l/s~/m is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas~onserv~n Commission by the 15th of the succeeding month, unless otherwise directed. Form 113-404 Submit in duplicate 2X-6 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1300 hrs, 07/27/83. Drld 12-1/4" hole to 3349'. Circ and cond hole. Ran 85 jts 9-5/8" 40# HFERW BTC csg w/shoe @ 3308'. Cmtd 9-5/8" csg w/1250 sx AS III & 25'0 sx AS I. Bumped plug w/1500 psi - floats held - ok. ND Hydril. NU FMC wellhead & BOPE, tstd BOPE to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt, tstd csg to 1500 psi. Drld FS & 10' new hole and ran leak-off tst # 11.~7 ppg EMW. Cont drlg 8-1/2" hole to 6985' as of 07/31/83. HILL/DH36 08/16/83 MEMORANDUM statve of Alaska T~RU: Lonnie C. Smith TELEPHONE NO: Commi s s ioner FROM: Edgar W. siPple, Jr~-~/ SUBJECT: Petroleum Ins pector~-~--'~ August 1, 19 83 108A:~2 Witness BOPE Test on ARCO Kuparuk 2X-6 Sec 4,TIlN,R9E, 5~4 Permit No. 83-110 Parker Drilling Rig 141 Friday J.u.ly 29, 1983: I witnessed the BOPE test on ARCO Kuparuk 2X-6, Parker Drilling Rig 141. The drilling rig ~s in the process on running casing. The BOPE Test commenced at 8:00 p.m. and was concluded at 3:00 a.m. on July 30, 1983. There were five failures. The lo%a~r pipe rams, and four three way valves on the accumulator were leaking. The lower pipe rams %~re changed out and tested to 3,000 PSI. The four three way valves were repaired and c~hanged out. The valves %~re al. ripping but would stop in 15 minutes. There was no pressure loss on the full charge pressure. We contributed the dripping of the oil due to the lines being higher than the accu- mulator. See diagram attached to this report. I fill. ed out the A.O.G.C.C. BOPE Test RePOrt which is attached, to this report. In summa, fy, I witnessed the BOPE test on ARCO Kuparuk 2X-6, Parker 141. I talked to Stan Barrett, August I, 1983, 10:30 a.m., after monitoring the system for three days, it is dripping for a~ut 15 minutes and stop. Att achme nt s 02-001AfRev. 10179) O&G -~4 4/.s0 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION CObiblISSION B.O.P.E. Inspection Report Inspector Operator ~.ocatio-:. sec Drilling Contractor Representative ~,~/ ,,~',R~ ,~ f~ ?~?~ Permit #_ .~.',.~//O ~ , Casing Set @ ;~_~D-~ ft. Rig # /%// Representative. ~-~//~ ../~.g .'~ ~// . Location, General Well Sign General Housekeeping Reserve pit Rig ~ ' BO,PE Stack A?~ula r~ ~~e r Pipe Rams Blind Rams Choke Line Valves H.C,R. Valve Kill Li~Valves Check Valve Test Pres .sure ACCUMULATOR S'YSTEH Full Charge Pressure ~©~ psig Pressure After Closure /~/~:O psi% ~ ~ 200 psig Above Precharge Attained: / mit ~)~_ sec Ful,1 Charge Pressure Attained: ~--mln~ ~ secO~ - , / ! Cqntrols: Master ~.,~ ~V~t' ~.~' Remote ~ Blinds switch cover O~ -_ Kelly and Floor Safety. Valves ,/- Upper Kelly Lower Kelly~' Bal 1 Type~ Inside BOP ~. Test Pressure. Choke Manifold No. Valves No. 'flanges ~ -' Adjustable Chokes ~]ydrauically operated choke .... ] %.~ ~%Test Pressure ~Tes t Pressure ~fTest Pressure Test Pressure Test Results: Failures.~ ---_~ Test Time ~ hrs. Ins~ctor/Com~ssion office notified. ~'f~'U~:~'d ~"~-~]',~:~I ! Distribution orig.' - AO&GCC cc - Operator cc - SupervisOr. / ARCO Alaska, In¢ Post Office~-.~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 20, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-6 Dear Mr. Chatterton. Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on August 18, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/GRU3L84:sm Enclosures Er E VEB Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK*, ,.)IL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-110 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-20988 4. Location of Well Surface: 390' FSL, 602' FEL, Sec. 4, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 1OR' RKB 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2X-6 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool ADL 25645 ALK 257F, Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate I~X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other I~(X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: August 18, 1983 ou yo~ ~°'~ 14. I hereby certif~,~that the foregoing is true and correct to the best of my knowledge. - Signed Title Area Drilling Engineer The space J~ ~or Io~/n use Conditions~f Approval, f~fny: ,..;.:roved Copy Returned Approved by. COMMISSIONER the Commission Date ? '",.2.,?-~-~ Form 10~03 Rev. 7-1-80 GRU3/SN45 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate July 20, 1983 Mr. JeffreY B. ~e~in Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Kuparuk River Unit 2X-6 ARCO Alaska, Inc. Permit No. 83-110 Sur. Loc. 390'FSL, 602'FEL, Sec. 4, TllM, RgE, Btmhole Loc. 1551'FNL, 866'F%~, Sec. 9, TilN, RgE, 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 io~ information shall be mab~itted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish, Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the l~bltat -Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State ia prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated tl~ereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Uater Pollution Control Act, as amended. Prior to commencing operations you may be-contacted by a-representative of the Department of Envirom~ental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout Mr. Jeffrey B. K~in Kuparuk River Unit 2X-6 -2- July 20, 1983 prevention~equipment so that a representative of the C~m~ission 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 p~ior 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 abandor~ment, please give this office adequate advance notification so that we may have a witness present. Ver~t~,ru ly y~u~-s~ C. V. Cha~'terton' Chairman of ~.~ O~.~7~ ~ ~7~ go~~o~ Alaska Oil and Gas Conservation Commission be: 6,H/A Enclosure cc: Department of Fish & Game, M~bitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office E~._..~I00360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 13, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 'Kuparuk 2X-6 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2X-6, along with $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. o A diagram and description of the surface hole diverter system. o Diagrams and description of the BOP equipment. Since we estimate spudding this well o~-JUt'.Y 22' t983, your earliest approval would be appreciated. If you have any questions, please-call me at 263-4970. Si nc~..~ly, A/eX'D;illing Engineer JBK/JG3L68: sm Enclosures A,~h~ran~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CCh~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ]~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 ~, -~*f~. 4. Location of well at surface '~'4~ -~' 390' FSL, 602' FEL, Sec. 4, TI'IN, RgE, UN "~':'i~ '~'?~t: . . ,.~ .~ ~ At top of proposed produmng ~nterval ~ ~' ~ Target: 1320' FNL, 1320' F~L, Sec. 9, T11N, RgE, UN ~¢ "~ At,o. , 1551' FNL, 866' FWL, Sec. 9, TllN, RgE, UM ~¢~'¢m 5. Elevation in feet (indicate KB, DF etc.) ~ 6. Lease designation a~d serial no. RKB 106', PAD 77' ~ ADL 256~5 ALK 2576 Federal Insurance 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 32 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 8018' MD~ 6555' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 600 feet. 21 14. Distance to nearest property or lease line miles 4678' FWL @ Surface feet 17. Number of acres in lease feP. t 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 39 o (see 20AAC25.035(c) (2) 9. Unit or lease name Kuparuk River Unit 10. Well number 2X-6 Proposed Casing SIZE !Hole Casing 24" 16" i2-1/4" 9-5/8" 8-1/2" 7" ARCO Alaska, lnc 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 2~(-5 well 60 ~ surface feet 18. Approximate spud date J 07/22/83 2611 psig@ 60°F . Surface 3088 psig@ 6066 ft. TD (TVD) Liner and Cementing Program CASING AND LINER SETTING DEPTH Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD 65.5# H-40 PEB 80' 29' I 29' 109'! 109' 40.0# HF-ERW BTC I 3241' 29' I 29' 3270'Ii2866' J-55 I 26# HF-ERW BTC J 7990' 28' I I 28' 8018' 16555' J-55 ~_~ I I , proposes to drill a Kuparuk River Field development well to approximately QUANTITY OF CEMENT (include stage data) ± 200 cf 1300 sx AS III & 250 sx AS I 481 sx Class G neat 8018' MD (6555' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2611 psig. Pressure calculations are based on latest reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon comple- tion of the job. 2X-5 will be 60' away from 2X-6 ~ surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ 6028' MD, approx. 1000' MD above the Kuparuk sands. Reserve pit fluid will be disposed down the 9-5/8" x 7" annulus of this well. The 9-5/8" x 7" annulus will be i~eft with a non-freez3ng fluid dur3ng any ~nterrup~on in the disposal process. SIGNED TITLE Area Drilling Engineer DATE . _~ The space by~r~on~m~ use-- ' CONDITIONS OF APPROVAL Samples required []YES ~[~'N O Permit number Mud log required I-lYES ~NO IR~v 7-1-RO Approval date Directional Survey required I APl number ¥ES []NO I 50- ¢Z¢' SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 20, ]983 by order of the Commission Submit in triplicate ARCO "' ALASKA.-- ]~NC-.- ' ' ~ ~:- : PAD ' .... KUPARUK-~ F'! , . 400 500 _ ...400 .... 3OO I · . 1702 ................. N U.IX_/ H.. "-'200 ~oo o ~ ~ oo I 1623 2O0 ARCO ALASKA. !NC. PAD 2X. ~/ELL NO, 5-6-7-8 PROPOSED KUPARUK FIELD, NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. NOTE,· WELL PATHS EXTEND'BEYOND 154.1 .................... THIS VIEWIN8 WINDOW - - . _ . _ . 14S$ .. . :300. ' - _ _. 300 I .._:.,-oo... 4, .... ..:.-:::.,.::: :._:._.:.:.,,_.: --. _,--,, _..: --": "r":: -'/''"'."' - ....... ~- -- .' ' ''$': .............. / ....... :-'/'" '"'"-"-----' .... :"--:-'-'- -':::-/':": T:-:':--:: ......................... ' ...... -'--/ x%,,,'''r- ';'== -- -': ..... / - ;'-'-- ..... 3oo ............ :_ ........... ' ......... / ....... : ...... : ..... , ........ ?!_, ............. : .................... . _ _ ' / -- J U L 400 ........... /~ ....................... 'i', . ~'"'""~ " / 17'02 I~d~ -- . · 2. 3. 4. . . 5urfac~ ~iver:er 16" - 2000 psi Tankco starting head. Tankco quick connect assy. I6" x 20" 2000 psi double studded adaoter. 20" 2000 psi drilling spool w/lO" side outlets· ball valves, hydraulically actuated,~/ w/lO" lines to reser,ze pit. Valves to open automat'ically upon closure of annular preventer. 20" 2000 psi annular'preventer. 20" bell nipple. . Maintenance & Operation Upon initial ins%allation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in. well under any circumstances. 16" Conductor ANNULAR PREVENTER BLIND RAMS PIPE RAMS II I t. f PIPE ~/~MS I CSG . ~"~'Tl · x HD o D blGRAM .-.'1 13-5/8" SO00 PSI RSRRA BOP STACK 1o 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11' o 3000 psi x 13-5/8" - 5000 psi spacer spool 4o 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8' - 5000 psi blind rams -9. 13-5/8"- 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL Will4 HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI OOWNSTREAM 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. ge 10. 11. 12. 13-5/8' BOP STACK TEST 13. 14. 15. 16. 1. FILL BOP STACK AND MANIFOLD 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 ANNUL~ PREVENTER AND OtOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. '" 5. INCREASE PRESSURE TO--AND HOLE FOR I0 MINUTES. BLEED TO ZiP O~Sl. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. ~ 7. INCREASE PRESSURE TO AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLO VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI O0~NSTREAM. BLEED SYSTEM TO ZERO PSI, OPEN TOP SET OF PIPE RAHS ANO CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. OPEN BOTTOM SET OF PIPE RA~S. BACK OFF RUNNING JOINT ANO PULL OUT OF HOLE. CLOSE BLINO RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RN4S AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANOPIPE VALVES TO 3000 PSI. TEST KELLY COCKS ANO INSIDE 80P TO 3000 PSI WITH KOOMEY PLIMP. RECORO TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN ANO SENO TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. F ANNULAR PREVENTER 11 BLIND RAMS '-) '[o [, L PIPE ') DRILLING SPOsOL D IAGP. AN ~2 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 7-1/16" - 3000 psi tubing head 4. 7ol/16" - 3000 psi x 11" - 3000 psi double studded adapteK 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool ' 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines g. 13-5/8" - 5000 psi pipe 'rams 10. 13-5/8" - 5000 psi blind rams 11. 13-5/8" - 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./~ 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 15 45 SECONDS CLOSING TIME AND i200 PSI REMAINING PRESSURE. PIPE ~.AMS ) 7 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND I~IFOLD WITH ARCTI.C DIESEL. ~.. CHECI~ THAT' ALL HOLD DOWN SCRD4S ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT Itl WELLHEJkD. RUN' IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND m_CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. z,,o 7. INCREASE PRESSURE TO AND HOLD' FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED ,MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND P, AMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLINO RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANOPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFOI~M COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE 8OPE DAILY. 3 9o '/:.,Z. Z. ,. bdZ ~ ;,ca.z.,. zdz ',,,r.~.z. ZO,,4~_. . /d~ ~d~ '~8. ~ I ' .~ z ~ ',/c. ~ z. ,. z 4z '/:"'z'. z. ~/¢/A..4/. i ARCO Alaska, Kuparuk Project North Slope Drilling CHECK LIST FOR NEW WELL PERMITS ITEM AP PROVE DATE (2 thru 8) (3) Admin .~~ ~-/~-~ (9 thru 11) (4) Casg~~/, ~7-)~BM (12 thru 20) Company /~F'O~) /L~Io~/~,~ ~~'~ Lease & Well No. YES NO 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .............. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... 9. Does operator have a bond in force .................................. ~ 10. Is a conservation order needed ...................................... ~ 11. Is administrative apprOval needed ................................... //~ 12. 13. 14. 15. 16. 17. 18. 19. 20. (5) OPE (21 thru 24) 22. 23. 24. 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 ............ proposed Is adequate well bore separation ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ,~F- -- Does BOPE have sufficient pressure rating - Test to ~ooo psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78). ................. ~~'~'~? ?P ~ 2'5 Additional requirements ~ (6) Add: - -' ................................. ............. REMARKS Additional Remarks: Geology: Eng.in~e er ing: HWK / LCS 5z~'' BEW WVA,~ JKTJ~,~... HJH rev: 12/06/82 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. CODE 68 6~ 68 68 68 68 68 68 68 2,496 ! l 1., D 47. 998t) £iR ~t0 5 .ti. 0,5 [') 0 n C .~ L .i 3.9630 ,0,2070 , 5000 $ P SP GR $P SP D K P T SP D E P :P SP GR R ? {. ) 35.5469 9RHO 67~. C, O00 CAL'I 2.'$517 Ii:D 501.000o CALl 4.0533 3.0996 ILD 37.~582 t)RHC, 678,5000 CAi, I 3.5074 6.9~83 IbD 29.2~80 l)RffO 9!9.5000 C~LI 3,0039 11..2266 977,5000 2.7~0:t i' 6055 Ib[~ 426.0{~0') CAL 1 4., 3~56 483 9453 46 .'7500 2 9590 8,6563 2.3691 0,070~ 9.2344 3,0117 0,0.464 8.9141 b,41.80 0.0205 8,8672 12.0703 0,0400 8,7031 1,5859 0,0303 12,0781 2,.3.711 O,~:~b4 10, 31.3 1,, Ol 37 g 20 3 2,8574 -999,2500 999 ,: 250:0 9.632g 3,539I -999,250C) 9; 9'?66 [3 ~ GR 1 <,4. 4375 !'. RA% D F, P -999.25:.~0 F£i'... l. -999.2500 3. 3359 l'r~a -9g9.250© 99;187~ -999.~500 [:"Cf.: I, -9~9. 2500 k,¥RA 3.4785 ILP, -999. 2500 FCb;L -999.2500 -999,250I~ 3,127 {:', l I,}) -999.2500 Ca[ I -99°. , 2500 -999.2500 DRHO -999.25¢;() CAL'/ -999.2500 3.,4434 II..D -999.2500 [)RrtD -999,2500 CALl' -9q9.2500 2.9609 I!.,D - 999.2500 D R ~,! 0 -999,2500 CALl -999.25o0 :3.1t3t - 999.25 o 0 '999.2300 -999. 2500 2 ,,, 75 7 ,,.1 I L [~ . c~ 99 .. 2 [4 0 ,,) C .a, i, I' 3,0P98 -999.2500 10.5391. 3,0957 '999,2500 10,7578 3,0879 -999,2500 ]0,0781 3,4414 '999,2500 11,0313 2,9766 -999,2500 10,8359 1,B926 -999,2500 9,4141 -999 . 9.9687 1,5430 '999,~500 i, 0,1719 2,8555 ,2~1.3 3.0801 -99~,2500 '671:9 2,6855 '999,2500 10.0547 GR DF, pT SP R H U !: GR DE pT SP RHO Sg R H t..l 5 GR SP SP SP (~ O I..~,: P SP :GR -9q9,, 25f)t) 5 1 F: (). :~'..'() F;SFI~" 2,3965 1?0.6~75 P.~ R A:'P -999.2500 5000, ()(.)0o MFLb 3.0156 tL -75, ~4:),_. G,~ 101,3.t. 25 ,1. ~ ,1..312% x ¢,. ,;.:, '~ -9q9.2500 2 6¢9'5 -999,2500 -999.2500 2.9297 999,2500 :999.'2500 -999.25O0 2,705~ -999,2500 -999.25o0 -999,2500 2.62:t0 -999.2500 -999.2500 -g99.2500 -999..500 -909,2. 500 -'999. 2500 2.4258 9 9 9.2:5 0 ,) -qq9 - 2500 ~', Ci 6:: 3:"1 ~;~ (i: i',! R AT '"999:.: 2500 ::-999,25:00 i 'l L: g t.) R t,-~ 0 CaLl I LD CALI I L [.) C ~ L, I I .i.., D DRHO C A L I I L D D R Fi :~ 1,., D I) R Fi: 0 C' ~ I.,T 2.4:7..o ~,, 3: G,~,, : ~.l.. 1'25t, 91 !2,~C, ~,~'A,: :: :: 999 2.4 O: 43 : I: L D - 99 g., 2,, 5 o <) i.~ F; 14 ~ ,; 2,8437 -g99,2500 9,B906 2.8027 -g99.2500 9.9922 2 9609 -999i2500 9 8203 2,7969 '999,~500 9,9297 2,6953 '999,2500 lO,07B1 2,5430 -999,2500 I0,4688 2.4023 1::0.23J4 . 2,757B 999' 2500 10,3359 2,6934 -999,2500 '99~' 582, , :2 5 0:0 9,1484 9(~9 · SP SP GR D~PT SP GR D E P ~? SP R 'H [".~ ?, SP G~ P SP -~'? 72.9375 -999.25(;0 ORHL) -999,25(~r', CA!.,.T -999. 2500 3.8633 lbo -999,2500 -999.2501~ CALl 6.30~7 II..P -999.2500 DRNO -999,2500 CnLI -999.2500 3.4160 II~O -999,2500 -999.~500 -999.2500 !,8672 Il.I) -999.2500 HRHG -999.2500 CALl -999.25OO 6,8672 :lbo '999.2500 CAB! 5 0 0 b ~ H 0 10.2813 3,3770 -999,2500 9,9531 4.0938 '999,2500 10.9297 6,3438 -999,2500 10.9687 3.6543 '999,2500 li,3B2g 4,1992 -999,2500 ll.O[r~7~ 7,0~20 -99g,2 C 11.7969 -999, 5 781 3 ,99~'1'172 ~,250:0 ,976~ 5.726:6 -999,2500 8.8984