The URL can be used to link to this page

Home My WebLink About182-154Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11AͲ08 50Ͳ029Ͳ20313Ͳ00 909572342 Kuparuk River Leak Detect Log with ACXField & Processed 13ͲSepͲ24 0 121BͲ20 50Ͳ029Ͳ23164Ͳ00 909462416 Kuparuk River Multi Finger CaliperField & Processed 15ͲAugͲ24 0 131CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 25ͲAugͲ24 0 141CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 25ͲAugͲ24 0 151CͲ24 50Ͳ029Ͳ23063Ͳ00 ALSL764Ͳ002 Kuparuk River Packer Setting Record FieldͲFinal 15ͲSepͲ24 0 161DͲ32 50Ͳ029Ͳ22982Ͳ00 909582494 Kuparuk River Multi Finger CaliperField & Processed 6ͲSepͲ24 0 171EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Leak Detect Log FieldͲFinal 8ͲSepͲ24 0 181EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Packer Setting Record FieldͲFinal 7ͲSepͲ24 0 191HͲ01 50Ͳ029Ͳ22330Ͳ00 909524903 Kuparuk River Multi Finger CaliperField & Processed 29ͲAugͲ24 0 110 1HͲ01 50Ͳ029Ͳ22330Ͳ00 909593144 Kuparuk River Plug Setting Record FieldͲFinal 23ͲSepͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39678T39679T39680T39680T39680T39681T39682T39682T39683T39683178-040203-115201-248200-173182-154193-00610/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:33:37 -08'00'1EͲ2950Ͳ029Ͳ20828Ͳ00 909524908KuparukRiverLeakDetectLogFieldͲFinal8ͲSepͲ240181EͲ2950Ͳ029Ͳ20828Ͳ00 909524908KuparukRiverPackerSettingRecordFieldͲFinal7ͲSepͲ2401T39682T39682200 173182-154193 006 Image~l~'roject Well History File Cover ~e 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 Histo~ntifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No, [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: ~OBIN VINCENT SHERYL MARIA WINDY Project Proofing .. BY: BEVERLY ROBIN VINC~ MARIA WINDY Scanning Preparation ~ x30 = ~.O~--~ + j~'~, = TOTALPAGES BY: BEVER~NCENT SHERYL MARIA WINDY Production Scanning Stage, PAGE COUNT FROM SCANNED FILE: "'~ PAGE.COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~ YES BY: ~OBIN VINCENT SHERYL MARIA~ WINDY DATE:I,~,03 /SI ~ Stage 2 IF NO IN STAGE '!, PAGE(S) DISCREPANCIES WERE FOUND: __ YES I/ ROBIN VINCE~ MARIA WINDY DATE:/ /?/~' '- / BY: BEVERLY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A'i"CENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) ReScanned (lndividuai page [special at~ei~tiot~] ~ca;~ning complet, ed) NO NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked {done) 12110102Rev3NOTScanned.wpd • • Page 1 of 1 Regg, James B (DOA) ~ IBZ-~~~ From: NSK Problem Well Supv [n1617@conocophilli'ps.com] ~~~ 43~co ~ce Sent: Friday, July 30, 2010 9:59 AM \\ 1, To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1 E-29 (PTD 182-154) Report of failed TIFL Attachments: 1E-29 schematic.pdf Tom, Jim, Guy Gas lifted producer 1 E-29 (PTD 182-154) failed a diagnostic TIFL on 07/29/10. The TIO prior to the test was 215/1274/482. A leaking GLV is suspec a is line wi roubleshoot and repair if possible. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 '1 `` K55 ~ 2~~ Sc_~ = I Z74~s~ ~--~ ~~ ~~ = z~. ~~~ ~~ ce ~ ~" ~rR4 8/10/2010 KRU 1E-29 PTD 1821540 7/30/2010 TIO Pressures TRN_ANNL TRN_ HNN~ I N 7 T ,on. 3000. SC 3000 200. 3000. 3000. 2700 3000. •n nn 2400 I1 . o. o. 0. 0. 0. D. 2100 1800 15D0 1200 900 600 300 0, PLOT START 'TIME MINOR TIME ~,.ri'i' `ttlF~,t~€~pi??4 PLOT F.Ni; ~i'SMG O1-MAY-10 07:30 MAJOR TIME WEER +02160.00:00 HRSI-JUL-10_D7c30 PICK TIHF 28-J t7N-10 14:24:23 r;r~ TAG N~IiE DESCRIPTION ,, ., _. I.1'TT.rT WL1E-29-CHORE FLOW TUBING CHORE ???~~?' SCRATCH 31 FLOW TUBING PRESSURE ??????? SCRATCH_31 FLOW TUBING TEMP ??????? PI-1E5D07-29 GL CASING PRESSURE ??????? ~ ??????? SCRATCH_31 1NNF;R t1NNUI,U;; PRES ? ~ ~ % SCRATCH_31 OUTER ANNULUS PRES ??????? m~+~a~~am m~~eaw~ ra~~ DRILLSITE WELL PREV WELL le 29 NEXT WELL EN"1-r~', OPERATOR OPERATOR VERIFIED ~ SYSTEM AUTO ENTRY ~ BOTH • u WELL NAME: WLRRUlE-29 _ ,fi_- __, ~ KUP 1E-29 ~• ~ _ _ _ CQt1QCb~~11~ ~l [?5 (~ ~, Well Attributes ax An Ig e & MD TD ., ~, I Wellbore ARl/UWI Fleltl Name wen status mcl l-1 m~lrrnol ..~. o..,, t,.,. o, }" ' ~ ~ ; I 500292082800 KUPARUK RIVER UNIT PROD 23.37 3,400.00 6,835.0 C ment H2S (ppm) Date Annotation End Date KBGrd (R) Rlg Release Date SSSV: Nipple 55 8/62009 Last WO: 9/23/2007 39.00 9/25/1982 wbu c rg ~ - / s , ,~- ~rrJ1o icors Actusi ^ nrd ~ t hon Depth (RKB) End Date Annotation Laat Motl... End Date Last Tag: SLM 6,622.0 322010 Rev Reason: Pull Plug w/Gauges Imoshor 327201D ' Casit~Strings -. -- 12 ~--. HANGER ~,:. . Cas ng Dascnpgon String 0 ... Stnng W .. . Top (RKB) set Depth (1... Set Depth (ND)... Stnng Wt... at~ing ... String Top Thrd . - i CONDUCTOR 16 15.060 0.0 79.0 79.0 65.00 H-40 ' T Casing Description String 0... String ID ... lap (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd --~; ~ , SURFACE 103/4 9.794 0.0 2,206.0 2,177.6 45.50 K-55 ~' T' i Casing Descrlptlon String 0... String ID ... Top (RKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd - PRODUCTION 7 6.151 0.0 6,811.0 6,624.6 26.00 K-55 CONDUCTOR, Casing DeacripROn String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd o-7s CASING PATCH 5.651 3,337.2 6.276 3.404.0 32.915 . _ _ r-_i _ Tubing Strin s _' NIPPLE 469 • ~' , _ Tubing Descr ption St g 0... SU-ng ID . iTop (kKa) 'Set D pth (r.. Set D pth (TVD) . St g Wt... St ng ... String Top Thrd ~ , ~ ~ _ , L-80 _ IBT-Motl _~ TUBING WO 3 112 2.992 11.8 5 963.0 5 778.8 9.30 Com letion Details -- -- SURFACE, 0-22W Top Depth ITVDI Top Intl - - Nomi... ~__ .l Top (RKB) (RKB) (°) Item Descrlptlon Comment ID (in) _ , { 11.8 11.8 0.42 HANGER Hanger 2.992 GAS LIFT, z.373 '--7 469.1 469.0 0.78 NIPPLE 31/2x2.875"IDCamco"DS"Nipple 2.875 _~ 5,904.7 5,721.0 6.73 NIPPLE 312x2.812"IDCamco"DS"Nipple 2.812 _ ( ~ ~ 5,948.7 5,764.6 6.29 LOCATOR Locatorw/2'spaceout 2.970 . ~,. ~ 5,951.0 5,766.9 6.27 SEAL ASSY SEAL ASSEMBLY 2.970 ' Tubing Descrlptlon String 0... String 10 ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CASING ` TUBING Original 4.54 2.992 5.948.9 6,325.9 6,140.4 FL_4S ~ 3.2aiiaod I _ Completion Details ~~ - -- - - -- ~= --- Top Depth ---'-~ Omi... (ND) Top Intl N GAS LIFT, 3,598 t ~ D Top (RKB) (RKB) (°) Kem Descrlptlon Comment (iN ~~ i ' ~ 5,948.9 5,764.8 6.29 PBR 3.913 _- 5,962.6 5,778.4 6.15 PACKER Baker FHL Packer 2.930 ,~ 6,005.2 5,820.8 5.73 NIPPLE CAMCO X NIPPLE 2.812 Gns urr, 4,fi33 - i , -.g 6,013.0 5.828.6 5.65 SBR Seal Bore Receptacle 4.375 6,025.7 5,841.2 5.52 PACKER Baker FHL Packer 3.000 6,186.2 6,001.1 4.67 BLAST JT Blast Ring Joint eroded - 22' Patch set 4/16/1994 2.992 _ r --`~ 6,305.4 6,119.9 4.72 SEAL ASSY Seal Assembly 2.965 GAS LIFT, s,447 }__ ~ 6,305.9 6,120.4 4.72 PACKER Baker FB-1 Packer w/Seal Bore EMension 4.000 j 6,3202 6,134.7 4.62 NIPPLE CAMCO'D' NO GO NIPPLE -HAS NIPPLE REDUCER 2.25" ID 2.750 6,325.1 6,139.6 4.59 WLEG WirelineGuide 3.000 Other I n Hole Wirelin e retrievable fish, etc.) pumps valves plugs GAS LIFT, 5,851 ~ ~ , lop Gepth __ _ , , , _ (ND) Top Intl ---"} Top (RKB) (RKB) (°) Descripdon Comment Run Date ID (in) ' it 6,236 6,050.8 4.78 TBG PATCH 22' Meda Tubing Patch Set on 4/16/94; Patch across eroded 4/16/1994 2.375 Blast Joint; Flowing 'C' Sand may erode Tbg Patch. (See WSR) NIPPLE, 5,905 6,320 6,134.7 4.62 Nipple Reducer NIPPLE REDUCER SET IN NIPPLE WHEN PATCH SET 4/4/1994 2.250 ~~ Siots Perforations & _ _ _ LOCATOR, _ .~ ~ _ _ _ Shot Top (ND) Btm (NO) Dana PBR, 5,949 SEAL ASSY - - - Top (RKB) Btm (RKB) (RKB) (ftK6) Zone Date (sh... Type Comment . s,951 6,229 6,295 6,043.8 6,109.6 C-4, C-3, C-2, 925/1982 4.0 IPERF ~~ C-1, 1E-29 PACKER, 5,963 ~1 6,422 6,431 6,236.2 6,245.2 A-5, 1E-29 9/25/1982 4.0 IPERF I 6,442 6,462 6,256.2 6,276.1 A-4, tE-29 9/25/1982 4.0 IPERF NIPPLE. 6.005 ~ - _. __ ~.. -_._ ..--___: Notes: General & Safety_ _ _ _ ~ ~' - Eno fiats Annotation SBR, 6,013 ~~--_ "~ 1/102009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 PACKER, 6,026 ~~ -_ - PRODUCTION, ' ~-~-- J ~ - 6,070 r PRODUCTION, I } 6,147 a LAST JT, Q186 ' TBG PATCH, B,236L- ~~ IPERF, j 6.2296,295 PRODUCTION. i '-- _.. - - 6.287 f - - - _. - _ Mandrel Details - -- Top uepth Top Port (NO) Intl OD Valve Latch Size TRO Run SEAL ASSV, "' Stn Top (RKB) (RKB) (°) Make Model (In) Serv TYPe Type (in) (psi) Run Date Com... s,3os - -- - 1 2 373 0 2 334 5 17 20 CAMCO K BG-2-9 1 Gas Lift GLV BTM 0.156 1,265.0 9282007 PACKER, 6,30fi ~ , . , . . T°cing Pup - 2 2 3 598 469 3 9 23 34 CAMCO K BG-2-9 1 Gas Lift DMY BTM 0.000 0.0 9/282007 Joint, 6,314 , . , . . NIPPLE, 6,320 3 4 633 3 4 466 9 11 58 CAMCO K BG-2-9 1 Gas Lift GLV BTM 0.156 1,270.0 9282007 Nipple Reducer, y , . , . . 6,320 ~7 4 5,447.1 5,2672 8.86 CAMCO K BG-2-9 1 Gas Lift DMY BTM 0.000 0.0 9282007 wLEG x 325 ~ _~ 5 5,851.1 5,667.6 6.51 CAMCO K BG-2-9 1 Gas Lift OV BTM 0.250 0.0 9/282007 , , 6 6,070.1 5,885.5 5.08 OTIS 3 .5x1.5 1 1/2 PROD CV RM 0.000 0.0 1/10/2009 IPERF, 431 6 422~ 7 6,146.8 5,961.8 4.73 OTIS 3 .5x1.5 1 1/2 PROD CV RM 0.000 0.0 1/10/2009 , i, 8 6,286.6 6,101.2 4.56 OTIS 3 .5x1.5 1 12 PROD DMY ROS 0.000 0.0 4/4/1994 IPERF, 6,442-6,462 L PRODUCTION, - 46.811 TD, 6,835 C~ CcmocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: C~ '~~~~CE4V~D ~I~sk~ ~ ~ ~a Cep. Gtlmrnission llncfr~r~ge l`~ E~ 9 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)7. Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25th 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6th, 7th, 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor s s ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16110 7A_ 1C_ 1E PAD C Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" Na 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" n/a 2" n/a 1.7 7/8/2010 1A-13 50029207000000 1811950 11" Na 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" Na 2.1 7/8/2010 1G01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" Na 24" n/a 8.5 7/6/2010 1 G03A 50029205350100 2070630 SF Na 16" Na 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6!2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1 E-02 50029204720000 1800500 21 " n/a 21 " n/a 1.7 7/7/2010 1E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 717/2010 1E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" Na 5" n/a 2.6 7/7/2010 1E-08 50029204960000 1800810 5" n/a 5" n/a 2.6 7/7/2010 1E-10 50029207250000 1820360 2" n/a 2" n/a 1.7 7/7/2010 1E-13 50029207500000 1820780 5" n/a 5" n/a 2.6 7/7/2010 1 E-19 50029209050000 1830170 1 " n/a 1 " Na 1.7 7/7/2010 1 E-21 50029208920000 1830020 3" n/a 3" Na 2.6 7/7/2010 1 E-24A 50029208570100 1971870 2" n/a 2" Na 1.7 7/7/2010 1 E-25 50029208440000 1821700 3" Na 3" Na 1.7 7/7/2010 1 E-28 50029208320000 1821580 4" Na 4" n/a 2.5 7/8/2010 9 E-29 50029208280000 1821540 7" Na 7" Na 2.5 7/8/2010 "-~ ~~~~ NO. 5203 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth r,-r'~y ~~»~~ ~~~~ ;: F"t ~~~~5 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3F-03 ANHY-00070 INJECTION P ' 2D-03 1 E-29 ANHY-00075 B04C-00030 ROFILE - ( ~ PRODUCTION PROFILE - ~ PRODUCTION PROFILE l 04/04/09 04/10/09 04/14/09 1 1 1 3G-13 3F-18 iD-117 ANHY-00079 B04C-00031 B14B-00027 INJECTION PROFILE ~ </ PRODUCTION PROFILE / - INJECTION P 04/15/09 04/15/09 1 1 1 D-128 AYS4-00057 ROFILE '3.- . ~-- INJECTION PRO 04/16/09 1 iH-21 1 D-120 B14B-00028 AYS4-00058 FILE PRODUCTION PROFILE G INJECTION P 04/16/09 04/17/09 1 1 2K-22 1E-15 AYS4-00059 AYS4-00061 ROFILE IBP/SBHP - INJECTION PRO ' 04/17/09 04/18/09 1 1 1Y-04 3F-02 AYS4-00071 AYS4-00063 FILE ~. INJECTION PROFILE PRODUCTION PROFILE ~'- 04/20!09 04/28/09 04/22/09 1 1 1 1 G-04 iR-03A 8146-00036 AYS4-00063 SBHP SURVEY Z e L~ SBHP SURVE 04/23/09 1 iG-O6 B1 Y i } -I_ (` ~O(~ _(~~r ~ 9y~ 04/23/09 1 4B-00035 SBHP SURVEY ~~ l ~a -. ~ (°~-s~s ~ 04/23/09 1R-10 6146 00031 ~~ .~ - 1 2F-02 1R-15 - AYS4-00060 B14B-00032 SBHP SURVEY - (~ ~ INJECTION PROFILE ~ L+ - /~ ` U SBHP SU '"' ~ 04/20/09 04/19/09 1 1 RVEYS - ~ } ~ 04/20/09 1 04/30/09 u u Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ConocoPhillips January 29, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: J. Eggemeyer Engineering Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~~5~ - l~~ ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 3 ''" "^ '`°" 1E-29, u requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. (^rw A~'f~' 1 ~U ~ ~ ~VVti Sincerely, ~~~`r`- . Eggemeyer Engineering Team Leader CPAI Drilling JE/skad Page 1 of 1 Maunder, Thomas E (D4A) Fram: Maunder, Thomas E (DOA} Sent: Wednesday, December 12, 2007 10:54 AM Ta: 'Eggemeyer, Jerome C.' Subject: 1E-29 (182-154} Detailed Report Request Jerome, Further to our discussions, woukt you please provide the detailed operations reports for the following well (s}/operations. 1 E-29 (182-154) warkover begun 9/1/f07, non-rig work summary provided is sufficient Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 12J12/2007 • J~~C~'IV~'D STATE OF ALASKA (~(~ V ~ Q ALASKA OIL AND GAS CONSERVATION COMMISSION ~~D7 REPORT OF SUNDRY WELL OPERATI~`~~ A'~& ~~~ ~~~~ ~b,n,,,,1Qe 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ ~ Ot ~ Ofaj~g Alter Casing ~ Pull Tubing Q Perforate New Poot ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnoCOPhillips Alaska, InC. Development ~ Exploratory ^ 182-154 / ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20828-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 1 E-29 - 8. Property Designation: 10. Field/Pool(s): ADL 25651, ALK 469 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6835' - feet true vertical 6648'- feet Plugs (measured) Effective Depth measured 6619' feet Junk (measured) patch @ 3238' (csg>, 6236' (tbg) true vertical 6433' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 79' 16" 79' 79' SUR. CASING 2100' 10-3/4" 2206' 2178' PROD. CASING 6705' 7" 6811' 6625' Baker Ex Patch 3237'-3304' across csg leaks @ 3263'-3270' Perforation depth: Measured depth: 6229'-6295', 6422'-6431', 6442'-6462' true vertical depth: 6044'-6110', 6236'-6245', 6256'-6276' Tubing (size, grade, and measured depth) 3-1/2" , L-80 / J-55, 5963' / 6325' MD. Packers & SSSV (type & measured depth) pkr- BAKER FHL ; BAKER FHL, BAKER FB-1 pkr= 5963", 6026', 6307' Camco DS nipple @ 468' 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 Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 161 1428 2243 -- 220 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-232 Contact Jim @ 265-1544 Printed Name ,..~~~-% Title Wells Group Engineer Signature , %i'` Phone ~~ )~ c? Date Pre red b haron I u Drake 263-4612 `~±' ~+?~'~ ~# ~ :, r iii ry~~% /''"~ ~ ~ Submit Ori Form 10-404 evi ed 04/2006 ~~~ ginal Only • • Conocct~i!lips Time Log Summary '~ tYe/Wfew web Reporting Well Name: 1 E-29 Job Type: RECOMPLETION Time Lo s Date From To Dur S. De th E De th Phase Code Subcode T COM 09/10/2007 22:00 00:00 2.00 MIRU MOVE DMOB P Prepare rig to move to 1 E pad 09/11/2007 00:00 12:00 12.00 MIRU MOVE MOB P Move thru the field w/ various stops due to Ka uruk field chan a out da 12:00 21:00 9.00 MIRU MOVE RURD P Begin R/U and setting equip 21:00 00:00 3.00 PROD1 RPCOti RURD P Accepted Rig @ 21:00 hrs. R/U to circ and kill welt rior to tree removal. 09/12/2007 00:00 01:00 1.00 PROD1 RPCOh RURD P Continue to RU to circ and kill well. 01:00 03:00 2.00 PROD1 WELCT SFTY P PJSM on pulling BPV and RU to pull BPV. Unable to latch into valve. Continue to attem t w/ no success. 03:00 07:00 4.00 PROD1 WELCT CIRC P IA 590 psi OA 120 psi. Vent gas and circ @ 43 spm or 1 bpm @ 740 si. 07:00 12:00 5.00 PROD1 WELCT CIRC P Circulated 310 BBLS 9.6 PPG long way. 9.6 away 9.6 return. Shut down pump monitor well. IA & OA on vac. ???? Visual on BPV. Pre to ull. 12:00 18:00 6.00 PROD1 WELCT NUND T Inspection of hanger threads prove to be undesirable. After utilizing wire brush and several other methods decision was made to move into wireline options to set plug in SSSV profile to prepare for BOP test. Discussed option with Anchorage and AOGCC on variance for BOP test. Best option is plan forward. Call for HES & SWS for support. Notified BAker fishin for o lions. 18:00 20:30 2.50 PROD1 WELCT NUND T N/U tree and 20:30 00:00 3.50 PROD1 RPCOII SLKL T RU Slickline and test lubricator to 2500 psi. Rih w/ CA2 Blanking Plug and set 1854' SLM. Pooh. 09/13/2007 00:00 03:30 3.50 PROD1 WELCT NUND T Pressure test to 250„~si and chart against CA2 Blanking Plug @ 1854' SLM. RD Slickline. 03:30 08:30 5.00 PROD1 WELCT NUND T Set BPV and ND Tree. Set Surface Blankin Plu and NU BOPS. 08:30 10:00 1.50 PROD1 WELCT NUND P Func test BOP's. Verify size and condition of variable rams. Flood stack, choke manifold and check for leaks. 10:00 13:30 3.50 PROD1 WELCT BOPE P Test BOPE 250/2500 psi. • • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/13/2007 13:30 14:00 0.50 PROD1 WELCT BOPE P Conduct draw down test 14:00 18:00 4.00 PROD1 RPCOh SLKL P RU Slick line and recover prong and CA2 Blanking Valve. Make a 2.80" ua a run to 6034'. RD slick line. 18:00 21:00 3.00 PROD1 FISH ELNE P Spot Equipment and held PJSM. R/U Schlumberger. Fill lubricator to for ressure test. 21:00 00:00 3.00 PROD1 FISH ELNE T Crew change for both Nabors and Schlumberger. Lubricator design didn't meet service company's sop. Re -desi n lubricator. PROD1 FISH 09/14/2007 00:00 03:00 3.00 PROD1 FISH ELNE T Continue to re-build lubricator. 03:00 06:00 3.00 PROD1 FISH ELNE P Fill lubricator and pressure test to 500 psi. Rih w/ 80 Gr. String shot to 6050'. Set CCL @ 6007' and Fire strip shot f/ 6011' t/ 6023' and Pooh. 06:00 12:30 6.50 PROD1 FISH ELNE P Load and RIH with 2 5/8" Chemical cutter. Log /tie in to tubing jewelry. Fire chemical cutter at 6,022' ELMD. POOH stopping at 4,000' / 2,000' respectively for anchors to equalize. Inspection of severing head show positive indication of fire. All tool accounted for!!! 12:30 13:30 1.00 PROD1 FISH PULD P Pick up Baker spear for engaging tubing hanger. Engage fish, and attempt to pull. Exercise pipe from 100-120K in 5K increments 7 each. No movement. Decide to reconfigure for eline. 13:30 18:00 4.50 PROD1 FISH ELNE T Prepare E-line to RIH with jet cutter. Plan is to cut tubing @ ~ 5,981'. Rih and 'et cut tb 5978'. Pooh. 18:00 19:30 1.50 PROD1 FISH PULD P Pick up and make up spear, uQ II han er to floor, laydown spear and han er. 19:30 21:30 2.00 PROD1 RPCOh CIRC P RU and circulate 1.5 hole volumes 320 bbis.) @ 3 bpm @ 170 psi. Blow down and ri down circ a ui . 21:30 00:00 2.50 PROD1 RPCOA PULD P Pooh spooling up control line and laying down 35 joints of 3 1/2 9.2# J-55 BTC as of midnight. Recovered 34 stainless steel bands. 09/15/2007 00:00 06:00 6.00 PROD1 RPCOh PULD P Continue to Pooh laying down 3 1/2 Production string. Corrosion started 't 116 on cou lip s. 06:00 09:00 3.00 PROD1 RPCOA ~ PULD P LD all 3.5" production tubing. & 12.5' of cut off joint. Clean rig floor and pick u 3.5" drill i e handelin a ui ment. 09:00 10:30 1.50 PROD1 RPCO h NUND P While changing out pipe equipment and clearing shed change out Flow line riser sub and re lace. gaga 2 of 3 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/15/2007 10:30 13:30 3.00 PROD1 FISH PULD P Begin picking up fishing BHA as listed in tubin tall . 13:30 15:00 1.50 PROD1 FISH OTHR P Slip drill line. 15:00 23:00 8.00 PROD1 FISH PULD P PU and Rih w/ 3 1/2 DP 1x1 from pipe shed w/ 174 'ts to 5660' 23:00 00:00 1.00 PROD1 FISH RURD P Pick up and Make up kelly. 09/16/2007 00:00 01:30 1.50 PROD1 FISH RURD P Continue to PU and MU kelly 01:30 04:30 3.00 PROD1 RPCOh PULD P RU Test equip and test @ 250/2500 si. lower kelly valve had to be replaced. Test both upper and lower - good. RD test equip and RU bales and elevators. 04:30 06:00 1.50 PROD1 FISH TRIP P Continue to Rih f/ 5660 t/ 5960'. UP wt 90k DN wt 85k. Tag TOF @ 5960'. S ace out and MU Kell . 06:00 07:00 1.00 PROD1 FISH MILL P Begin wash over 17' in on joint 184 Aprox 5960' RKB. Wash over with min torque. Latch up fish and begin jarring. First pull straight @ 120K Fish on. Second jar at 135K jarred fish free. No significant weight increase. Appears that we sheared the SBR. No fluid losses or ain. 07:00 08:30 1.50 PROD1 FISH RURD P Set back Kelly and prepare to puN to surface standin back usin sinners. 08:30 12:00 3.50 PROD1 FISH TRIP P POOH with drill pipe. 12:00 14:00 2.00 PROD1 FISH PULL P Break out and laydown BHA# 2 and la down 43.53' offish. Came into chem cut. 14:00 16:30 2.50 PROD1 FISH PULD P MU and Rih w/ OS BHA # 3 to 287' 16:30 18:00 1.50 PROD1 FISH TRIP P Rih f/ 287' to 3542' w/ 3 1/2 DP. 18:00 18:30 0.50 PROD1 RIGMN SVRG P Service rig 18:30 20:00 1.50 PROD1 FISH TRIP P Continue to Rih f/ 3542' to 5975' and s ace out MU Kell . 20:00 23:00 3.00 PROD1 FISH JAR P En a e fish 6007' and slide over 7' and engage grapple. Jar on pkr from 40k to 100k osw of"95k. SBR came free and was able to move. Pull off of stick and RU to circ BU. 23:00 00:00.. .1.00.. PROD1 FISH CIRC P Circ bottoms up @ 3 bpm @ 370 psi. Monitor well. 09/17/2007 00:00 00:30 0.50 PROD1 FISH CIRC P had small amount of gas break out. Circulate 3 b m 370 si 00:30 06:00 5.50 PROD1 FISH TRIP P Pooh f/ 5990' t/ 287' 06:00 08:00 2.00 PROD1 FISH PULL P Pooh and lay down un-needed fishing tools from BHA #2 and recovered fish. ~'~ 2 3 ~f ~ • • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09!17/2007 08:00 10:00 2.00 PROD1 FISH PULD P Lay down SBR overshot. All pieces acounted for. Clean rig floor. Change out BHA to clean out run as per procedure. E-line unit availability is still ossible at this time. 10:00 14:00 4.00 PROD1 FISH TRIP P RIH with clean out BHA. 14:00 16:30 2.50 PROD1 FISH CIRC P Begin circulating at 6,010' reversing. Launch viscus pill for effect. reverse 1.5 Bottoms up. 4 BPM @ 350 PSI. C cle over SBR olish rod. 16:30 22:30 6.00 PROD1 FISH TRIP P POOH standing back. Up WT = 79K DWN WT = 69K. Prepare to lay down FCO BHA to pick up FHL ass m as er roceedure. 22:30 00:00 1.50 PROD1 FISH PULD P Lay down clean out assy. 09/18/2007 00:00 01:00 1.00 PROD1 FISH PULD P Continue to Lay down and load fishing tools. 01:00 02:30 1.50 PROD1 RIGMN RURD P Clear rig floor of un necessary equip. and RU casing toms and elevators for 3 1/2 x 7" scab liner. 02:30 03:30 1.00 PROD1 RPCOA TRIP P Held PJSM and begin PU FHL assy. 03:30 04:30 1.00 PROD1 RIGMN RURD P RD Casing tongs and elevators 04:30 11:00 6.50 PROD1 RPCOh TRIP P MU and RIH wlBaker SBR skirt, 2.81" 'X' nipple, one jt. 1-80 tubing, FHL packer (pinned 60M# shear) PBR (pinned 40M# shear) and retrievamatic test packer on 3.5" workstring. Located existin SBR stick. 11:00 12:00 1.00 PROD1 RPCOh CIRC P Spotted corrosion inhibited brine (1% b vol CRW-132 between ackers. 12:00 12:30 0.50 PROD1 RPCOh OTHR T After spotting CI brine, Kicked on charge pump and lowered to engage skirt (overshot) over existing SBR stick, pressure was 70 psi, while going over stick pressure came up to 125 psi. Shut off charge pump. Attempted to lower on down but no movement. Attempted to pick back up and stab again, would not come up. Pulled 20K over, still would not come up. Worked up and down several times and decided FHL packer had set rematurall . 12:30 13:00 0.50 PROD1 RPCO0. DHEO P Discussed problem with Engineering. Decided to go ahead and set FHL. Pressured up to 1250 psi held for 5 min. No visible signs of setting. Bled pressure down to 750 psi. Sheared PBR @ 117K. 27K overpull. PU 25' set Retrievamatic Packer. Pressure tested packers below to 2500&i held~_. ood for 5 min. Page 4 of 8 • Tirne Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/18/2007 13:00 22:00 9.00 PROD1 RPCOA TRIP P Bled off pressure. Removed head pin and hoses. Pulled 35 stands. Set test acker 3769' ress u below to 2500 si OK. Attempted to press backside above. Pumped into holes 2 BPM @ 750 psi. Continued testing coming up the hole. Found lower hole above @ 3268'+/- and upper hole below 3250'+/-. Could pump away @ 2 b m S20 si. 22:00 00:00 2.00 PROD1 RPCOh TRIP P Give SWS 3hr notice and Pooh f/ 3250' t/2350' 09/19/2007 00:00 01:30 1.50 PROD1 RPCOA TRIP P Continue to Pooh to DC's 01:30 03:00 1.50 PROD1 RPCOh TRIP P Stand back DC's and laydown Retrievamatic test packer and seal ass from FHL acker. 03:00 03:30 0.50 PROD1 EVALVI~ SFTY P Held Prejob safety meeting w/ rig crew and SWS Eline crew. 03:30 15:00 11.50 PROD1 EVALVI~ ELOG P RU and Rih w/ UCI Casin ins ep ction. g f/5920' to 50' with standard resolution. Reran special interest section in high resolution @ 4100' to 3950; _3700' to 3100' and 400' to 50'. RD SWS E-line. 15:00 17:00 2.00 PROD1 FISH TRIP T MU and RIH w/Spear Assembly t/ 292' 17:00. 22:00 5.00 PROD1 FISH TRIP T Rih f/ 292' t/ 5949' filling pipe every 30 stands. Obtain parameters 89k up wt and 79k do wt. engage @ 5986' and pull 40 k osw and let jars bleed, then strai ht ull - acker was free. 22:00 00:00 2.00 PROD1 FISH TRIP T Pooh to 5620' bottom of SBR and drop ball rod and pressure up to 1800 psi and shear circ sub. Continue to Pooh. 09/20/2007 00:00 03:00 3.00 PROD1 FISH TRIP T Continue to Pooh t/ 279'. 03:00 06:00 3.00 PROD1 FISH PULD T Pooh laying down Jars,LBS. RU 3 1/2 Tbg equip and lay down FHL assy w/ spear. Lay down 1 it 3 1 /2 Tbu and X ni le. La down SBR and ins ect. 06:00 14:00 8.00 PROD1 WELCT BOPE P Pull wear ring and install test plug. BOP rams to 250/2500 si, annular to 250/2500 psi. Kelly to 250/2500 psi. Testing witness by John Krisp AOGCC. 14:00 15:30 1.50 PROD1 RPCOh PACK T MU BHA for 2nd FHL packer run consisting of Baker SBR skirt (overshot), 2.81" 'X' Nipple, one jt 3.5 tubing, FHL packer, (pinned 60M# shear) PBR (pinned 40# shear} and retrievamatic test acker. 15:30 20:30 5.00 PROD1 RPCOR PACK T RIH on 3.5" workstring f/ 356' t 5982', obtain parameters 91k up wt; 85k do wt. Page ~ of S Time Lo s Date From To Dur S. De th E De th Phase Code Subcade T COM 09/20/2007 20:30 22:30 2.00 PROD1 RPCOh PACK T Rih t/ 6013' and MU head pin in jt #184. Rih circulating w/ charge pump @ 48 psi. seen pressure increase to 100 psi @ 25' in @ 6027' bled off and no-go @ 35' in @ 6049'. PU 1' for space out and pressure to 2390 psi and set FHL @ 5985' w/ top of PBR @ 5971' Bottom of SBR @ 6048'. Shear out of PBR w/ 2475 psi and 4k over pull. Pull 12' seal assy from PBR and Pooh t/ 5907'. Set retrievamatic pkr @ 5891'. Pressure test to 2500 psi and hold for 10 min. & Bleed off. 22:30 00:00 1.50 PROD1 RPCOA TRIP T Pooh w/ DP 09/21/2007 00:00 01:30 1.50 PROD1 RPCOh DHEQ T set Test pkr @ 3270' and pressure test f/ 3270' t/ wrp @ 6092' @ 2500 psi. Good. Move up hole and set pkr @ 3263' and test down drill string - pumping away @ 2 bpm @ 820 psi. Pressure IA tt 2500 psi and test good. Bleed off and RD testin a ui . 01:30 06:00 4.50 PROD1 RPCOA TRIP T Pooh to 266' 06:00 08:00 2.00 PROD1 RPCOh PULD T Pooh laying down Test Pkr Bha. 08:00 09:30 1.50 PROD1 CASIN( RPTH P Load X Patch tools in pipe shed and Begin making up 7" 23-26# Internal atch ass . -when set will have an ID of 5.651". Rlh t/ 118' 09:30 11:00 1.50 PROD1 CASIN( RPTH P Rih w/ drill pipe f/118' t/2874' stacked out with atch, would not o. 11:00 17:00 6.00 PROD1 CASIN( RPTH T Pulled Casing Patch back out and layed down. Some damage to patch but not enough to keep from re-running. Sent back to Baker shop for dressu . 17:00 19:30 2.50 PROD1 FISH PULD T PU BHA for clean out run with 3 - 6.151" OD Window mills w/Drill Collars between for stabili ._ Drilled and set mouse hole. 19:30 20:30 1.00 PROD1 FISH TRIP T Rih f/ 190' t/ 437' and laydown 7 jts. PU Kell . 20:30 00:00 3.50 PROD1 FISH OTHR T Ream f/ 221' t/ 466' @ 50 rpms @ 400 ft/Ibs torque. Rot wt 17k. Circulate @ 3 b m 40 si. 09/22/2007 00:00 02:30 2.50 PROD1 FISH OTHR T Continue to Rih f/ 437' t/ 2968' Lay down sin les t/ 2844' PU Kell . 02:30 04:00 1.50 PROD1 FISH OTHR T Ream f/ 2844` t/ 2996' @ 50 rpms @ 1029 ft/Ibs to 1517 ft/Ibs torque, Circ @ 3 bpm @ 150 psi w/ 50 t/ 53k Rot wt. Torque was seen in the depth of 2860' +/-. w/ each mill spaced out @ 30' apart. re reamed when high torque values were seen in attempt to clean up, had approx. a 300 ft/Ib loss after re reamin . Pace 5 of 8 • n Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/22/2007 04:00 07:00 3.00 PROD1 FISH OTHR T Set back kelly and Rih t/ 3338' and lay down 4 jts. Kelly up and ream f/ 3214' t/ 3366'. 07:00 08:00 1.00 PROD1 FISH CIRC T Pumped 30 HI-Visc sweep around and returns show only small shavings on screen and ditch ma net. 08:00 11:30 3.50 PROD1 FISH PULD T Stand back Kelly and POOH standing back workstring. Laydown milling BHA. 11:30 14;00 2.50 PROD1 CASIN( RPTH T Load Ex Patch tools in pipe shed and MU 7"23-26# Internal patch assembly -when set will have an ID of 5.651". 14:00 17:00 3.00 PROD1 CASIN( RPTH T RIH with patch on 3-1/2" workstring t/ 3304' _ 17:00 19:30 2.50 PROD1 CASIN( RPTH _ P RU and Pump 20 bbl corrosion Inhibited Brine Pill followed by 85 bbl 9.6 ppg brine and spot f/ 3237' t/ 3304' behind Baker 7" 23-26# Internal X atch. 19:30 22:00 2.50 PROD1 CASIN( RPTH P Swed a and set casingpatch f/ 3237' t/ 3304' w! max pressure of 2680 psi @ slip and seal area w/ low of 650 psi. When pulling swedge back thru 35k over ull of 50k strn was max seen. 22:00 23:00 1.00 PROD1 CASIN( DHEO P Pressure test casin @ 2500 psi for 30 minutes and chart. 23:00 00:00 1.00 PROD1 RPCOIt TRIP P Pooh laying down Drill pipe. 09/23/2007 00:00 03:00 3.00 PROD1 RPCO6 TRIP P Continue to lay down drill pipe and csg atch settin tools. 03:00 06:00 3.00 0 2,600 PROD1 RPCOh TRIP P Rih w/ 42 stds dp. Kelly up and breakdown kell . 06:00 09:30 3.50 2,600 0 PROD1 RPCOh TRIP P Lay down kelly and 84 jts dp. 09:30 11:30 2.00 0 PROD1 RPCOh TRIP P Pull wear ring. Lay down all tools not needed from ri floor. 11:30 12:00 0.50 PROD1 RPCO11 SFTY P PJSM covering running completion. 12:00 22:00 10.00 0 5,983 PROD1 RPCOf~ PULD P RIH with completion as per procedure. and locate w/ 't # 185. _Seen seals enter PBR. Pooh and Laydown jt #185, use jt #184 to land and place s ace out u below to 't. 22:00 23:00 1.00 PROD1 RPCOR CIRC P Pump 20 bbls of 1% corrosion inhibited 9.6 ppg brine and chase w/ 51 bbls 9.6 ppg brine. Spot corrosion inhibited fluid behind production sting and drain stack. 23:00 00:00 1.00 PROD1 RPCOh HOSO P Land production string w/ 2' space out. 54k u wt and 50k do wt. ~~ye 7 0~ 3 C7 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcade T CAM 09/24/2007 00:00 02:00 2.00 PROD1 RPCOh DHEQ P Held PJSM on pressure testing csg and tbg. Pressure test & chart tbg t/ 2500 psi for 15 min. -good test. Bled tbg down t/1750 psi. Csg t/ 2500 psi for 30 min. -good. Shear out DCK -3 Shear Valve @ 5469' @ 1600 psi. Circ @ 2 bpm @ 780 psi and reverse Circ @ 2 bpm @ 800 psi. thru DCK-3 Valve. 02:00 09:00 7.00 PROD1 WELCT NUND P Set BPV and ND BOPE and NU Tree. Pull BPV and install Test Plug, test tree & pack offs to 5000 psi. Remove test plug & install BPV. Clean cellar and Release rig @ 09:00 hrs 9/24/2007. Pale 8 e~ 8 1 E-29 Well Events Summary DATE 9/12/07 9113/07 9/14/07 9/15107 9/16/07 9/17/07 9!18/07 9/18/07 9/19/07 9/20/07 9121/07 9122/07 Sum ry Accept rig Nabors #3S @ 21:00 hrs on 9-11-07 Test BO 250!2500 ps'r. Good Test. Ghem cut t @6022', no tbg movement. Power cut tbg ~ 8'. POOH and begin laying wn production tbg. Continue to la own 3112 production string. MU a rih w/fishing tools. Engage Fish an ooh w/ 43.53' of tbg to chem Recover frsh down pkr Rih w/ FHL assy an LOGGED CASING C I FPH, MADE HI-RES P SURFACE. NO CORRO Continue to Run UCt L Lay down FHL ass Test csg whi ooh.. Leaks ~ 3250'-3268' narrow clown h in csg to Ream Pate rea and arc d 2500 p ", K. ON L FROM 5922` TO SURFACE AT <3000 F M 4400'-3950', 3700'-3100', 400'- ANOMALIES DETECTER. Fish FHL packer PE Test, and Rih w/ 2nd FHL Assy. t/ 3270'. Rih wt Baker 7" X-patch. PBR, Set X Patch 3237'-3304'. PT csg 9/23/07 I..a n drill pipe and Rih w/ ion and land hanger. 9/24!07 chart recorder to tbg Z~ IA. PT tbg 00 psi i 5 minutes, OK. Bled tbg to 1750 psi. PT IA 2500 psi 30 minutes, O Set BPV. NDBOP. NUWH. P7 9/27/07 ATTEMPT TO DRIFT DOWN TO WRP AT 92' RKB, OBSTRUCTIONS AT 6005` SLM AND 6024' SLM. WONT FALL P T 6040' SLM, APPEARS TO BE SCALE fN BAILER. PULL 1" DGLV FROM 71' RKB AND 1" SOV FROM 5467` RKB. SET 1" DGLV/BTM LATCH AT 546 KB. CIRC OUT T x IA WITH 100 BBLS DIESEL, 98 BBLS OF INHtBtTE EAWATER FOLLOWED BY 25 BBLS OF DIESEL. 9/28/07 INSTALL OV AT 5871' RKB, INSTALL LGLV'S AT 46! DRAW DOWN BACKSIDE TO 0#, TtlBtNG MAtNTAII AND SLUDGE OFF TOP OF WRP AT 6092' RKB. Sl 6060' SLM, POSSIBLE PACKED IN METAL DEBRIS. RKB AND 2393' RKB. BAIL SAND ING HOLE AT tN 9/29/07 MAKE MULTIPLE HYDROSTATIC BAILER RUNS.. RECOVER LRG PIEGES OF METAL IDENTIFIED AS PART OF AN ELINE PO -CUTTER. OBTAIN IMPRESSION OF TOP OF WRP. fN PROGRESS. 9/30!07 BAIL ON WRP AT 6050' SLM, GETTING MINIMAL RETURNS. SEVERAL ATTEMPTS TO EQUALIZE WRP W/ NO LUCK. 10/2/07 BAILED ON WRP ~ 6Q51' SLM, GETTING MINIMAL RETURNS. RECOVERED SOME RUBBER DEBRIS ~ MADE SEVERAL ATTEMPTS EQUILIZE WRP. IN PROGRESS. 10/3107 BAILED ON WRP ~ 6053' SLM, OBTAINED 112 CUP flF MUCKY FILL DEBRIS, MADE SEVERAL ATTEMPTS TO EQUILIZE WRP, TATTLE TAILS INDICATE WRP EQUILIZED BUT TUBING STILL PRESSURES UP, 1N PROGRESS. 10/4107 AATTEMPT TO PULL WRP ~ 6053' SLM, APPEARS TO BE FILL {SCALE) LAY DOWN FOR WIND, IN PROGRESS. 10/5/07 t3AILED ABOUT 'S12 GALLON OF FINE GRITTY SCALE FROM 6049` SLM TO 6Q52' SLM, LiB OF FILL STILL, LAYDOWN FOR WIND, IN PROGRESS. 10/6107 BAILED ON WRP @6054' SLM, OBTAINED SAMPLE OF SCALE /METAL DEBRIS, RAN LIB, PICTURE OF WRP. IN PROGRESS. 10/7/07 PULLED 3112" WRP ~ 6092' RKB, 1/4 OF UPPER 2 ELEMENTS FROM WRP LOST IN HOLE, TAGGED FILL @6619' SLM, MEASURED BHP 625Q' RKB (2687 PSI} GRADIENT ~ 6150' RKB (2647 PSI} GOMPLETE. • ~--. ~~ G~~a~~l~~~I~~ps A1~t~k~, 1r~~. 1L E..2g-- TUBING (~~~ OD:3.500, ID:2.992) TUBING (5963-&325, OD:3.500, ID:2.992) Perf (6229-6295) sos (6325.6326, OD:3.500) Perf (6422431) f I ~ i F KRU 1 E-29 Casing String -ALL STRINGS PROD. CASING 7.000 ~ 6811 I 6625 I 26.00 I K-55 I I _ ~`ubing String -TUBING Srze To Bottom TVD Wt Grade Thread 3.500 0 5963 5779 9.20 L-80 IBT-MOD 3.500 5963 6325 6139 9.20 J-55 BTC AB-MODS Perforations Summary Interval TVD Zone Status Ft SPF Date T e Comment 6229 - 6295 6044 - 6110 4,C-3,C-2, 66 4 9/25/1 982 6422 - 6431 6236 - 6245 A-5 9 4 9/25/1 982 6442 - 6462 6256 - 6276 A-4 20 4 9/25!1 962 has Lift M - -_ andr e_IsNalves S< MD _ TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VN Cmnt 1 2372 2334 CAMCO KSG-29 GLV 1.0 BTM 0.156 1265 9/2812007 2 3597 3469 CAMCO KBG-29 DMY 1.0 BTM 0.000 0 9/28/2007 3 4632 4466 CAMCO KBG-29 GLV 1.0 BTM 0.156 1270 9/28/2007 4 5446 5266 CAMCO KBG-29 DMY 1.0 BTM 0.000 0 9/23/2007 5 5850 5667 CAMCO KBG-29 OV 1.0 BTM 0250 0 9/28/2007 Producti0 rt Man dreisNa lves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 6 6071 5886 Otis 3.5x1.5 MMH-HF CV 1.5 RM 0.000 0 5/1/2004 7 6148 5963 Otis 3.5x1.5 MMH-HF CV 1.5 RM 0.000 0 5/1/2004 8 6287 6102 Otis 3.5x1.5 MMH-HF DMY 1 5 R05 0.000 0 4/4/1931 Closed ©ther (plug_s, equip., etc.) -COMPLETION _ De th TVD T e Desch tion ID 32 32 HANGER TUBING HANGER 3.500 468 468 NIP CAMCO DS NIPPLE 2.875 3238 3139 CSG 7" CASING PATCH 5.651 PATCH 5903 5719 NIP CAMCO DS NIPPLE 2.750 5950 5766 PBR BAKER 80-40 PBR 2.990 2.810 4.390 L- _ 6236 6051 TBG 22' Merla Tubing Patch Set on 4/16194; Patch across eroded Blast Joint; 2.375 PATCH Flowin 'C' Sand ma erode Tb Patch. See WSR 6307 6122 PACKER Baker FB-1 4.000 6321 6135 NIP Camco'D' Ni le NO GO 2.750 6325 6139 SOS Baker 2.992 6326 6140 TTL 2.992 Pert (6442462) Page 1 of 1 Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophiilips.com] Sent: Thursday, November 29, 2007 9:56 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: 1 E-29 (182-154) workover Attachments: 1e-29 workover summary.pdf ~,,.,~,.., .,~.,,.,,~ .y ,.~.,.~,,.,,~,. Jim Ennis j.ennis@conocophillips.com (907)265-1544 (UV~ (907)632-7281 (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, November 29, 2007 9:14 AM To: Ennis, J J Subject: 1E-29 (182-154) workover Jim, 1 am reviewing the 404 and have a couple of questions. 1. What rig was used? 2. There is no pressure test of the IA documented. The casing was tested when the patch was run, however i don't see any test after the tubing was in place. Look forward to your reply. Tam Maunder, PE AOGCC 11/30f2007 1 E-29 Well Events Summary • DAT Summary 9 /07 Accepted rig @ 21:00 hrs on 9-11-07 9/1 7 Test BOPS 250/2500 psi. Good Test. 9/14/ Chem cut tbg @ 6022', no tbg movement. Power cut tbg 5978'. POOH and gin laying down production tbg. 9/15/07 C tinue to lay down 3 1/2 production string. MU and rih w/ fishing tools. 9/16/07 En a Fish and Pooh w/ 43.53' of tb to chem cut. 9/17/07 Reco~r fish down to pkr 9/18/07 Rih w/ L assy and set. Test csg while Pooh. Leaks @ 3250'-3268' 9/18/07 LOGGED SING CORROSION LOG FROM 5922' TO SURFACE AT <3000 FPH, MAD I-RES PASSES FROM 4100'-3950', 3700'-3100', 400'- SURFACE. CORROSION ANOMALIES DETECTED. 9/19/07 Continue to Run CI Log and Fish FHL packer 9/20/07 Lay down FHL as Weeklv BOPE Test, and Rih w/ 2nd FHL Assy. 9/21/07 narrow down holes i sq to 3263' t/ 3270'. Rih w/ Baker 7" X-patch. 9/22/07 Ream Patch Area and 'rc debris from PBR, Set X Patch 3237'-3304'. PT csg X00 psi OK. 9/23/07 Lay down drill pipe and Ri /completion and land hanger. 9/24/07 NDBOP. NUWH. Released 0900 hrs. 9/27/07 ATTEMPT TO DRIFT DOWN WRP AT 6092' RKB, OBSTRUCTIONS AT 6005' SLM AND 6024' SLM. W 'T FALL PAST 6040' SLM, APPEARS TO BE SCALE IN BAILER. PULL 1" LV FROM 5871' RKB AND 1" SOV FROM 5467' RKB. SET 1" DGLV/BTM LA AT 5467' RKB. CIRC OUT T x IA WITH 100 BBLS DIESEL, 98 BBLS O HIBITED SEAWATER FOLLOWED BY 25 BBLS OF DIESEL. 9/28/07 INSTALL OV AT 5871' RKB, INSTALL LG 'SAT 4653' RKB AND 2393' RKB. DRAW DOWN BACKSIDE TO 0#, TUBING INTAINS 600#. BAIL SANQ D SLUDGE OFF TOP OF WRP AT 6092' R .STOP MAKING HOLE AT 6060' SLM, POSSIBLE PACKED IN METAL DE IS. IN PROGRESS. 9/29/07 MAKE MULTIPLE HYDROSTATIC BAILER RUNS. COVER TWO LRG PIECES OF METAL IDENTIFIED AS PART OF AN EL EPOWER-CUTTER. OBTAIN IMPRESSION OF TOP OF WRP. IN PROGRE 9/30/07 BAIL ON WRP AT 6050' SLM, GETTING MINIMAL RETU S. MAKE SEVERAL ATTEMPTS TO EQUALIZE WRP W/ NO LUCK. 10/2/07 BAILED ON WRP @ 6051' SLM, GETTING MINIMAL RETUR RECOVERED SOME RUBBER DEBRIS & MADE SEVERAL A MPTS TO EQUILIZE WRP. IN PROGRESS. 10/3/07 BAILED ON WRP @ 6053' SLM, OBTAINED 1/2 CUP OF MUCKY F DEBRIS, MADE SEVERAL ATTEMPTS TO EQUILIZE WRP, TATTLE ILS INDICATE WRP EQUILIZED BUT TUBING STILL PRESSURES UP, IN PROGRESS. 10/4/07 (ATTEMPT TO PULL WRP @ 6053' SLM, APPEARS TO BE FILL (SCALE) LAY DOWN FOR WIND, IN PROGRESS. 10/5/07 BAILED ABOUT 1/2 GALLON OF FINE GRITTY SCALE FROM 6049' SLM TO 6052' SLM, LlB OF FILL STILL, LAYDOWN FOR WIND, IN PROGRESS. ~~ ~~' h o ~ ~ ~~ ~~ 10/6/07 BAILED ON WRP @ 6054' SLM, OBTAINED SAMPLE OF SCALE /METAL DEBRIS, RAN LIB, PICTURE OF WRP. IN PROGRESS. • 1 E-29 Well Events Summary 10/7/0_7 PULLED 3 1/2" WRP @ 6092' RKB, 1/4 OF UPPER 2 ELEMENTS FROM RP LOST IN HOLE, TAGGED FILL @ 6619' SLM, MEASURED BHP @ 6250' RKB (2687 PSI) GRADIENT @ 6150' RKB (2647 PSI) COMPLETE. l7Ci~IQ111~~~~~' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 AT7N: Beth N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # ~ ~~ NOV ~ ~ 2007 Log Description Date BL Color CD 10/15/07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE .S G - 08108/07 1 1B-14 11837493 PRODUCTION PROFILE - ~ - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE - 08/30/07 1 1Y-18 11837499 PRODUCTION PROFILE G~ 08/30107 1 1G-14 11839652 INJECTION PROFILE i~~~ ~- 08131107 1 1A-01 NIA USIT - 08131/07 1 1Y-04 11839653 INJECTION PROFILE ~'~ ~ 09101107 1 1Y-32 11839655 PRODUCTION PROFILE '`6'~f- 09/02107 1 2T-TAB-01 11839656 INJECTION PROFILE C - - 09/03/07 1 2K-25 11846439 INJECTION PROFILE ~ = j 09/06/07 1 2K-18 11846440 INJECTION PROFILE / - 09/07/07 1 18-18 11846441 PRODUCTION PROFILE ~ - (p 09/08107 1 2T-20 11846442 PRODUCTION PROFILE ~' .J - 09-09107 1 2N-310 11850433 SONIC SCANNER 76'~ -(~ ~ 09/16/07 1 2N-310 11850433 SONIC SCANNER-FMI '~ - ~`~, () 09/16107 1 1J-176 11846443 USIT "3'p 09/17107 1 1 E-29 NIA UCI ~ - ~ 09/19/07 1 3F-21 11837503 RSTI WFL - 09/20107 1 2B-10 11839661 INJECTION PROFILE ~ - 09!22/07 1 1G-05 11837506 INJECTION PROFILE vZC 09/23/07 1 2H-13 11839662 INJECTION PROFIL ~ - 09/23/07 1 1B-05 11837508 INJECTION PROFILE ~.,~,.. 09/24/07 1 3H-OS 11839663 PRODUCTION PROFILE - (j 09124107 1 1Y-31 11839664 PRODUCTION PROFILE j ~' - 09/25107 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - (( 09!27!07 1 2V-08A 11837511 ISOLATION SCANNER ~~ j - ~ 09/28/07 1 1G-11 11837513 PRODUCTION PROFILE - 09129107 1 1Y-22 11837515 PRODUCTION PROFILE (~ 09/30/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • C J · . ~V~VŒ (ill~ ~~~~æ~ / AI,ASIiA. OIL AlO) GAS / CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J. Ennis Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1E-29 Sundry Number: 307-232 SCANNED JUL 2 7 2007 Dear Mr. Ennis: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 me with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~day of July, 2007 Ene!. ~~'d - t5<"( 1. Type of Request: Abandon ~. RECEIVED STATE OF ALASKA µ-~tðOjUL 1 2 Z007 ALASKA OIL AND GAS eONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV AlPlaska Oil & Gas Cons. Cl}mmìssion 20 MC 25.280 Anchorage Suspend 0 Operational Shutdown 0 Repair well ~/ Plug Perforations 00 Pull Tubing ~ Perforate New Pool . CPr -1;~""b1 Stimulate Perforate 0 o Waiver Other 0 Alter casing o 0/ o Time Extension o o o Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Re-enter Suspended Well "'t~ Development Stratigraphic o ' Exploratory 0 o Service 0 5. Permit to Drill Number: 182-154 ~ 6. API Number: 4. Current Well Class: P. O. Box 100360. Anchorage. Alaska 99510 50-029-20828-00 - 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 Requires? Yes 0 No 0 1E-29 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25651 ,/ ALK 469 RKB 106' Kuparuk River Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6835' I 6648' , .' 6647' 6092' Casing Length Size MD TVD Burst Collapse 7" 79' 2206' 6811' 79' CONDUCTOR SUR. CASING PROD. CASING 79' 2100' 6705' 16" 10-3/4" 2178' 6625' 13. Attachments: Description Summary of Proposal [2] Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operat 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is Printed Name J. Ennis Perforation Depth TVD (ft): 6044'-6110',6236'-6245',6256'-6276' Packers and SSSV MD (ft) pkr= 6067'; 6347' SSSV= 1884' 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 .. Gas 0 WAG 0 GINJ 0 Tubing Size: 3-1/2" Tubing Grade: J-55 Tubing MD (ft): 6367' Perforation Depth MD (ft): 6229'-6295',6422'-6431',6442'-6462' Packers and SSSV Type: pkr= BAKER FHL; BAKER FB-1 Camco TRDP-1AENC Service 0 September 1. 2007 Date: Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Signature to the best of my knowledge. Contact: Title: Phone 265-1544 Jim Ennis @ 265-1544 Wells Group Engin r Date Commission Use Onl Sundry Number: Conditions of approval: Notify Commission 0 that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ;)500 X> S \ ~O \2 -\-<è?\- RBDMS 8Ft ,JUL 2 6 1007 Subsequent Form Required: '-\ t> Approved by: Form 10-403 Revised 06/2006 APPROVED BY THE COMMISSION . . 1 E-29 Casing leak Repair Workover Procedure for Sundry Pre-riQ Work 1. Lockout SSSV (Camco TRDP-1AENC) 2. Pull DGL V @ 5998' and leave open. 3. Circulate KWF into well. 4. Ensure well will bleed to Opsi on both sides. (Note: Casing leak in IA) 5. Set FMC 3" ISA BPV within 24 hrs of MIRU. 6. Prepare location for Workover Rig. RiQ Work .¡ 1. Verify sundry appmval to repair casing leak. 2. MIRU N3S. Verify well is dead. ND tree. NUBOP. 13-3/8" wI 3"-6" VB pipe rams. Function test BOP. Pull BPV. Install blanking plug. PT BOP rams 250/2500, annular 250/2500 psi. (Note: MASP using 4/19/05 BHP & 0.1 psi/ft gradient is 1958 psi) Pull blanking plug & BPV. 3. Unland tbg hanger. Attempt to pull tbg from SBR. If unsucces$ful @ 80% yield (88M#), rig up E-line and shoot string shot followed by chemical-cut of tbg in middle of first full joint above packer. POOH wI tbg sideways, spooling SSSV control line as necessary. Survey all equipment pulled for NORM. 4. If SSR pulled OK, go to step 5. If tbg was chemical cut, single in wI Baker washpipe, overshot wI grapple, DC's and jars on 3.5" workstring. Reverse drc down to top of 5.75" OD SBR and engage fish. Pull andlor jar as necessary to remove SBR skirt. POOH, lay down fishing tools. 5. Roundtrip 7", 26# csg scraper to top of SBR stick on 3.5" workstring. RU SLB eline. Run UCI casing inspection log from SBR to surface. RD SLB. 6. RIH wI Baker SBR skirt, 2.81" X nipple, one joint 3.5" L-80 tbg, FHL pkr, PBR and retrievamatic test pkr on 3.5" workstring. Locate existing SBR stick and spot corrosion-inhibited (CI) brine between packers. Pressure tbg to 2500 psi and set FHL. Shear PBR. Using test pkr, verify location of csg leaks and PT csg above and below to 2500 psi. POOH wI test pkr. 7. RIH wI Baker T'x5.5" 3D liner hanger packer, +1-800' 5.5", 15.5#, L-80 Hydril 511 csg and 7"x5.5" CPH liner hanger packer on 3.5" workstring to straddle csg leaks. Circ CI brine into 7"x5.5" annulus. Rotate and set 3D hanger. Stack weight to verify set. Drop ball and release running tool. Stroke up -10' to engage dogs. Stroke down and stack weight to set CPH. POOH wI one stand of tbg. Close BOP and PT csg to 2500 psi. Open BOP & POOH, laying down workstring. 8. RIH wI 3 Y2", 9.3#, L-80, IBT Mod tbg wI special clearance collars as follows: a. Baker seal assembly wI 4.5" locator b. 2.813" Camco 'DS' nipple. c. 3-1/2" tubing and five KBG-2-9 1" GLMs per design wI shear valve in GLM #4 . GLM design MD's 2396',3626',4667',5480',5998' . . d. 2.875" Camco 'OS' nipple @ 500' 9. Spot corrosion inhibited brine in IA below GLM #4 prior to stabbing into PBR. Space-out, land tbg hanger. RILOS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed off tubing pressure to 1750 psi. Holding the tubing pressure at 1750 psi, PT IA to 2500 psi for 15 minutes. Bleed off tubing pressure to shear the dump kill valve. Install TWC. NOBOP. NUWH. Test tree and packoffs to 5000 psi. Pull TWC & install BPV. ROMO. Post-rig Work 1. Circ out KWF wI seawater for re-use and freeze protect well with diesel. 2. RU slickline. 3. Replace shear valve wI dummy. PT tbg 2500 psi. 4. Fish WRP. 5. Install GL design. . . 1 E-29 Proposed Workover Current Comcletion J Original SBR with X Profile Original Baker FHL Packer Original Perm Tbg Patch over eroded Blast Jt Original Baker FB-1 Packer Original 2.75" Cameo D-Nipple 7" Prod Csg Procosed 2007 Comcletion ~ L 2.875" Cameo DS Nipple New 3.5" L-80 Tbg w/ SCC KBG-2-9 GLM 5.5" Casing Leak Straddle 4 KBG-2-9 GLM's 2.813" Cameo 'DS' Nipple PBR 3.5 x 7" Baker FHL Packer 2.813" Otis X Nipple 3.5" L-80 Tbg 10' Baker SBR Skirt 3 H- 01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-17-89 Casing 1 E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M- 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-10 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: D&M . State of Alaska SAPC Unocal Mobil Chevron ... ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F--15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 Kupaurk Fluid Level Report 1 2 Kupaurk Fluid Level Report I 2 Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level. Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 1 2 Kupaurk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report -03-87 -18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 -O4-87 2-02-89 8-27-87 8-27-87 8-25-87 2-2O-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing Casing Casing Tubing Tubin Casint Casin~ Attachment. I ! Page Z Drill Site 1H Well No. ~'1H-3 "1H-4 ~1H-7 ~1H-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. LOg Date IE 1E-IA xi)/19/81 1E-2 ~'8/17/81'"-7 _'~1/17/84/ 1E-3 ~"10/18/8I',.., "-11/7/81/ ~8/4/80'~ ~-~ ~/~7/~ 1E-6 %10/21/81~ ~11/12/82/ ~lE-7 ~/28/81~ ~o/~s/sl/~ .~11/1/81/~ 1E-12 ~11/28/84 1E-IS ~/26/82 1~-16 ~/~9/S~ 1E-26 ~1/13/83 1E-~7 ~O/31/S~ ~6/13/83 1~-~ ~lO/lS/S~ ~ ~7/lS/S3 / / 1E-30 ~0/16/82 Drill Site 1G Well No. "~'IG-1 '~1G-2 '~lG-3 ~1G-4 '~ 1G-8 Log Date 9/7/82 ' 9/25/82~ 9/28/82/ 12/8/84/ .10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. LOg Date 1F .'~1F-1 2/19/83 ~1F-2 2/3/83 '~F-3 1/31/83 ~ ~ "1F-4 5/29/83 '~1F-5 . 10/25/82 '~1F-6 10/28/82' '~ 1F-7 11/19/82~ ,-- ,~ 5/7/83,/ '"/~ ~ RECEIVi ,,/, FEB E 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc.' Post Office box 100360 Anch.orage~ Alaska 9951~-C360 '[eiephone 907 276 1215 .June 24, 1985 ~4r. 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 1A-3 Fracture 5/30/85 1A-4 Fracture 6/1/85 1C-5 Perforate 4/27/85 1E-3 Perforate 3 / 28 / 85 1E-3 Fracture 4/3/85 1E-4 Perforate 4/20/85 1E-4 Fracture 5/7/85 1E-16 Fracture 4 / 1 4/85 1E-1 7 Fracture 3 / 26/85 1 E-29 Fracture 4 / 12 / 85 1F-1 6 Perforate 4/11/85 1F-16 Fracture 4/15/85 1G-1 Fracture 4/1/85 1L--15 Fracture 3/31/85 1L-1 6 Fracture 3/31/85 1Q-1 Fracture 5/31/85 1Q-4 Ac idize 5/1 7/85 1Q-4 Fracture 5/31/85 1Q-5 Fracture 5 / 1 / 85 1Q-6 Fracture 4 / 1 9 / 85 1Q-7 Fracture 4/27/85 1Q-7 Acidize 5/26/85 2C-10 Perforate 4/21/85 2D-3 Ac idize 5/11/85 2W-1 3 Ac id i ze 5/20/85 2X-1 2 Acidize 5/12/85 on the if you have any questions, please cai ! T. M. Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (Duplicate) me at 263-421 2. RECEIVED Alaska Oil & ~a8 Cor~$. Cornrnissiort Anchorage ARCO Alaska. Inc, is a Subsidiary of A' ~-~icRichfieldCompany STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 67' TllN, R10E, UM FNL, 639' FEL, SEC. 21, 5. Elevation in feet (indicate KB, DF, etc.) 106 ' (RKB) I6. Lease Designation and Serial No. ADL 25651: ALK 469 12. 7. Permit No. 82-154 8. APl Number 50- 029-20828 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-29 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 April 12, 1985, the "A" sands of Kuparuk well 1E-29 were hydraulically fractured and propped to improve production. The treatment consisted of 279 BBLS of gelled water as pad and carrying fluid and 14,070 LBS of 100 mesh and 20/40 sand as proppant. 66 BBLS of.gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 6000 psi. RECEIVED JUN 2 6 1985 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK 6 / 19 / 85 Signed J, ~ ~-~~---- Title OPERATIONS COORDINATOR Date The space below for Commission use ~-,4~ ~ __ -- ~.~'~ ;i~, Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate RETLJF<N TO- AF'P.O Al_ A;.'7 K A INr AT'FN' F~'Ei,r-~ORD3'CLERI< :.'.,TO-t i t HB ANCHr~F..'A!;E, .... Al-f ?°~1,., ~. DATE' APRIL t9, t98_: TRAN.?MITTAL NO' 5I 4'7. T "' '" ' ""'-',~? N ,.... i-.,,,: ~, .T. T T, ...-r; I. IE'F:r--' hi ]: T H ....... AFt~,... TI"I ~:? ~. F[]I._ 1._ [) I..,.I ]: fJ [;. ]: I'fE H S' . F'!..'-,:- .... ~--,..,""1::. A C I< r'i.. I,,,l [ r.:' L'.,fT, [: .... F:.'ECI:'ZIPT ,":ii~.I.'.' RETLIRN Of'iF SIGNED COF"( OF THIS 'TRANSMII"TAL. ,:;' F: (;! U E i'-..' C: E t !'":'-- 3 · ~ m._. ,.,q, i Y.-i f f Y-i I ~n--. t i ,m ..- ~ .% fG--2 iG-i IL-J6 .~ ...,.., ~',- i~ :._ :.,. ~_ ,_.' -- ~ i ~-_.f ,~ ",'..-,- - 7 i E:=29-.. 2 W ..... ..£....% ~..~ i E'--i 6 2 U .... 2L.'--2 2 J- t '-~ W, .... -J X: ~ E-.i 6 ") %" "~ 1 ~-../,.. ~ I'-' - I ,r. i I'-' .... t 6 2F-7 OF ~VEN'TS: 'A' ~h.'D FRAC-GELLED WATEF~ ,?, TAT ~ C BHP F'BU I"" E; U pT',l I. " F'BU PBU CELLED WATER FRAC HYDRAULIC FRAC POST FRAC TEHP LOGS PBU F'~U ~TATZC r-; 1~, F' F'BU F'BU GELLED k!ATER BATCH FRAC F'OST FRAC TEHF' LOG £TATIC BHF' ~'TATI C Bt-iF' INJECTTVZTY TF__£T TSZP STATIC BHP BI-iF' B H P B H P F'BU PO2. T BHP POST l.i \" I). I-'-'B U F'BU · FRAC TEHP LOG I"-'F:AC TEMP LOG FRACTURE 4/3/85 4/3/8.5 4/2/85 ~/~/o~ 4/t -2/85 3/;3 t ,/8S S/Si 185 4/t/85 4/1185 412185 4/9-t 0/85 4/7-8/85 418/85 4/~ ~-t S/85 4 / t i - i.." ,/85 4/t 2/85 41t2/85 'll i S,/85 41t :5/85 4/I 3/85 4/t t/85 4/i2/85 4/t.-~/85 4/t2/85 · 4/t 0--t i/85 4/t 4--i 41t 4185 4/t 5/85 41t5/8.5 41t 3-1 4185 41t 4-t 5185 F.:E:[:'E Z F'T ACI< NC, WLED.C-, ED · BF'AE B., C!JF:RIER CFIEVRON DISTRI[:UTION. ' DRII_L IN(;. W, F'ASFIER I ..... I [] H N S T 0 N. E X X 0 N HODIL F'HILL IF'S OIL h'~K CLERK J. RATHMELL ARCO Alaska, Inc. is · Subllcllar~ of AtlanticRtchfieldCompany RECEIVED APR 2 5 1985 ~laska Oil ;.:h~,':lOr:. ,~ .... ~. 0 I"1 ]J 0 UNION I< .~l.J[. I N/VALII_ T ARCO Alaska, Inc.. ~acho~'age, Alaska i~9~I0~0360 Telephone 907 276 1215 March 26, 1985 Mr. C. V. Chatterton', Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive ~nchorage, AK 99501 Dear Mr. Chatterton' Attached following are our notices of Kuparuk Field wells' 1E-17 and 1E-29 If you have any questions, please Mike L. Laue Kuparuk Operations MLL/kmc Attachment Coordinator (In Triplicate) Commi ss ion intention to call me fracture the at 263-4253. RECEIVED ,~'~,.",I-~ 2 ,.S 19g5 Alaska O, & (~as Cons. Commissio[~ Anchorage STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. ANCHORAGE, ALASKA 99510 3. Address P. O. BOX 100360, 4. Location of Well SURFACE LOCATION' 67' T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 106' (RKB) 12. FNL, 639' FEL, SEC. 21, 7. Permit No. 82-154 8. APl Number 50- 029-20828 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-29 11. Field and Pool KUPARUK 6. Lease Designation and Serial No. KU P A R U K ADL 25651, ALK 469 POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~]] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1E-29 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 20/40 sand as the proppant. Gelled diesel will be used as a flush. Lines and equipment will be pressure tested to 5000 psi prior to starting the job. Pre-post frac logs are included in the treatment program. Fluid' Gelled water 253 BBLS Gelled diesel 66 LBS Proppant' 20/40 sand 13,230 LBS RECEIVED ANTICIPATED START DATE' March 29, 1985 Su~ueut Work Re~o~ 6 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . , _, Title OPERATIONS The space below for Commission use 3/26/85 COORDINATOR Date Conditions of Approval, if any: Approved by BY LOflltlE 1. Sill{'{ Approved Ce~a¥ Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office b..^-100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 8, 1985 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-29 Dear Mr. Chatterton: Enclosed is a Well Completion Report for the subject you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L139 Enclosure wel 1. If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ?--¥.- STATE OF ALASKA ALASKA. ,- AND GAS CONSERVATION CO.,,~.VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ........ , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 82-154 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20828 4. Location of well at surface 9. unit or LeaSe Name 67' FNL, 639' FEL, Sec.21, TllN, RIOE, UM Kuparuk River Unit At Top Producing Interval .... 10. Well Number 1136' FNL, 1307' FEL, Sec.21, TllN, R10E, UN 1E-29 ,,, At Total Depth i 1. Field and Pool 1166' FNL, 1329' FEL, Sec.21, TllN, RIOE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River Oi 1 Pool 106' RKB! ADL 25651 ALK 469 , , 12. Date Spudded09/14/82 13. Date T.D. Reached09/21/82 14' Date c°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns09/25/82 N/A feet MSL 1 17. Total DePth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set 121. Thickness of Permafrost 6835'MD,6648'TVD 6725'MD,6538'TVD YES [] NO [] 1884 feet MD 1450' (App.rox) 22. Type Electric Or Other Logs Run D I L/SFL/SP/GR/Cal/FDC/CNL, CBL 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 79' 24" 284 sx AS II 10-3/4" 45.5# K-55 Surf 2206' 13-1/2" 1250 sx AS II ~ 2,50 sx AS I 7" 26.0# K-55 Surf 681'1' 8-3/4" 620 sx Class G "24. Perforations Open to ProduCtion (MD+TVD of Top and Bottom and 25. TUBING RECOR[~ interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6442' - 6462' 3-1/2" 6367' 6347' &..6067' 6422' - 6431' 6259' - 6289' w/4 spf, 90° phasing 26. AClD, FRACTURE, CEMENT SQUEEZE, ETC. 6289' - 6295' ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6229' - 6259' 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 I GAs-OIL RATIO TEST PERIOD I~ "Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BB~. OIL GRAVITY-APl (c°rr) Press. 24-HOUR RATE ~ ,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED 1 ]985 ~las~a Oil & ~as Cons. Comml~ion Anchorage Form 10-407 GRU3/WC58 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6228' 6042' N/A Base Upper Sand 6294' 6108' Top Lower Sand 6409' 6223' Base Lower Sand 6513' 6327' :31. LIST OF ATTACHMENTS Wn rl~nv~ r W~.I 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 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 supplement, al records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' FloWino, Gas Lift Rod P,lmn ~ urm 10-407 ARCO Oil and Gas Company Well History -,Initial Report - Dally Instructions: Prepare and submit the "Initial Rel~rt" on the first Wednesday after a well Is spudded or workover ormratlons are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I parish or borough Alaska County, Field I Lease or Unit Kuparuk River Auth. or W,O. no, ~Title AFE Exp 403113 I North Slope Borough ADL #25651 Recompletion IState Alaska JWell no. 1E-29 W/O Pool 102 API 50-029-20828 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 12/05/84 12/06/84 12107/84 thru 12/10/84 12111/84 12/12/84 Date and depth as of 8:00 a.m. RECEIV FEB ! 4 19 Alaska Oil & Gas Cons. Ar~chorage The above is correct 12/5/84 Complete record for each day reported IHour rARCO w.I, Prior status 56.24% if a W,O, 1000 Hrs. 7" @ 6811' 6725' PBTD Moving rig. 7" @ 6811' 6725' PBTD, Kill well Accept rig @ 1000 hrs, 12/5/84. Pmp 75 bbls wtr, followed by 18 bbls diesel. Pull BPV. Pull dummy vlv @ 6024', POOH; unable to get. tls up thru SSSV. Pmp plug salt pill, att to circ thru GLM; GLM appears to be plugged w/salt. RU to rev circ. 7" @ 6811' 6725' PBTD, POOH & LD DP 10.5 NaC1/NaBr Reverse out salt pill. Circ. N/D tree. N/U BOPE. Test BOPS. Circ. POOH, chg out to AB Mod colrs. PU 3½" DP, latch onto pkr, rel, pull pkr. PU BP, RIH, set @ 6200', tst to 2000 psi; OK. CO tbg head to FMC 5000# equip. NU &tst BOPE. RIH to retrv BP, tst 7" to 3500 psi, POOH. RIH w/bit & scrprs, wsh & rm 6691'-6725', POOH, LD DP. 7" @ 6811' 6725' PBTD, Space out 10.5 NaC1/NaBr RIH w/6.125" gage ring/JB; unable to get below 6230', Run 6.0" Gauge Ring to 6711'. POOH, RD DA. Set Bkr FB-1 pkr @ 6332' ELM. RU & rn 197 jts, 3½" compl string. Stab in & space out. SSSV @ 1884' - Bkr FHL Pkr @ 6067' Bkr FB-1Pkr @ 6347' - Tbg Tail @ 6367' 7" @ 6811' 6725' PBTD, Cln Pits D±esl/Crude Rn 3-~/2" tbg, stab in pkr. Space out, drop ball, set pkr. Shear SBR, lnd tbg. Tst ann 2250 psi. Bk out lndg jr, set BPV. ND BOP. NU tree, tst pkoff. Pull BPV, tst tree 5000 psi. Displ well w/crude lead by 40 bbl diesl. Tst SSSV, tst orifice vlv. Press tbg to 4000 psi, shear out, set BPV. Signature For form preparati(~n and distri/3q~ro~, see Procedures Manual, Section Drilling, Pages 86 and 87, IDate 12/27/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River J ADL #25651 Auth. or W.O. no. ~Title AYE Exp 403113 I Recompletion API 50-029-20828 Operator IAccounting cost center code istate Alaska Well no. 1E-29 W/O Pool 102 I A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ~Date Workover I 12/13/84 Date and depth Complete record for each day reported as of 8:00 a.m. 12/13/84 7" @ 6811' 6725' PBTD, Ri{ Clean pits. Iotal number of wells (active or inactive) on this t est center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 0800 Hrs. Released rig @ 0800 hfs 12/13/84. Old TD Released rig INew TD I PB Depth Date Kind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method Official reservoir name(s) Flowing Potential test data Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day ~ump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Ei'fective date corrected The above is correct Signature /'~ IDate ITitle sFe°; 'l~;~ce~uerPe% M'fnua~ln, dsedigtirc~nbU~io°,n' Drilling, Pages 86 and 87. Drilling Superintendent i'eiephone ~0~ 2t6 i2~5 February 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton' Enclosed are Subsequent Sundry Reports for the following wells' If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L121 Enclosures RECEIVED F'£g o 6 o,, ?? Chorage Commission STATE OF ALASKA ~" ALASKA OiL AND GAS CONSERVATION CO,,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 67' FNL, 639' FEL, Sec.21, TllN, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 12. 7. Permit No. 82-154 8. APl Number 50- 029-20828 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-29 6. Lease Designation and Serial No. ADL 25651 ALK 469 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon ['-] Stimulation [] Abandonment I'-] 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). Accepted rig @ 1000 hrs, 12/05/84. Killed well. ND tree. NU BOPE & tstd - ok. Pulled tubing and recovered pkr. Set bridge plug ~ 6200' & tstd to 2000 psi - ok. Tstd 7" csg to 3500 psi - ok. Retrieved bridge plug. Washed and reamed to 6725'. Ran 3-1/2" completion assy. Dropped ball & set pkr. ND BOPE. NU tree & tstd tc 5000 psi - ok. Disp well w/diesel and crude oil. Set BPV. Secured well & released rig ~ 0800 hrs, 12/12/84. RECEIVED F'E B 0 6 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~4) ~ ~~ Title The space b~,~ow for Commission use Conditions of Approval, if any: Date Approved by By Order of COMMISSIONER the Commission Date Form 10-403 GRU3/SN19 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Post Ofh,.~~ Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 8, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 1E-29 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-29 to a selective single completion. Since we expect to start this work on November 23, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ngineer JBK/JG/tw GRU2/L79 Enclosures RECEIVED NOV 0 9 l S& Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION uOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLx~3 OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface.' 67' FNL, 639' FEL, Sec.21, TllN, R10E, UM 7. Permit No. 82-154 8. APl Number 50- 029-20828 9, Unit or Lease Name 10. Well Number 1E-?q 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 106' ADL 25¢,~1 Al K z~9 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 ~, 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 convert, well 1E-29 to a selective single completion. fo1 1 ows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 4. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost inte-~rval. 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: November 23, 1984 S,abseq~]e'~t ~Vork Reported RECEIVED NOV 0 9 IJ984 Alaska 0il & Gas Cons. Commission Anchorage 14. i hereby certif.~that the foregoing is true and correct to the best of my knowledge. Signed/Z//~~¢~, ~4,~' Title Area Drilling Engineer T h e space b/~w' ~/r ~/¢~/n issi~n use Conditions/of Appr~f any: Date Approved by BY ~,~,~RY W. K6GLER Approved C o ~:' l~eturned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 GRU2/SN37 IR.v 7-1-RO and "Subsequent Reports" in Duplicate STATE OF ALASKA -~'~' ALASKA O~L AND GAS CONSERVATION COIv, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL i~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-154 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20828 OTHER [] 4. Location of Well SURFACE LOCATION' 67' FNL, 639' FEL, SEC. 21 T11N, R10E, UM BOTTOM HOLE LOCATION' 1166' FNL, 1329' FEL, SEC. 21, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' (]KB) ADL 25651 12. 9. unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-29 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 January 2, 1983~ Kuparuk River Unit Well 1E-29 was stimulated with 90 bbls of 14% HCl through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. The maximum coiled tubing pressure observed was 4000 psig and the maximum tubing pressure was 850 psig. 177 MCF of nitrogen were injected via the coiled tubing to aid in cleanup. Following the cleanup period the well was switched to the CPF. The post-acid well test showed this well producing 1000 BOPD as compared to the pre-acid rate of 750 BOPD. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space .below for Commission use Title KUPARUK OPERATIONS 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 TRANSMITTAL TO' William Van Allen FROM: D. W. Bose/Shelby J. Matthews DATE' '--//--~ ~- P~ WELL NAME: Transmitted herewith are the following' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T -'TAPE,~ REC/~I~T ACKNOWLEDGED: ~/~EASE RETURN RECEIPT TO:' · · ARCO ALASKA, INC. ATTN: SHELBY J. MATTHEWS - AFA/311 P:O. BOX 360 ANCHORAGE, AK. ' 99510 KUPARUK ENGINEERING TRANSMITTAL TO: William Van Allen FROM: D.W. Bose/Shelby J. Matthews WELL NAME- _~/~_~_ Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE,.S - SEPIA, F FILM, T - TAPE, RECEI PT ACKNOWLEDGED' ASE RETURN RECEIPT TO: DATE: ARCO ALASKA, INC. ATTN: SHELBY J. MATTHEWS - AFA/311 .... P.O. BOX 360 ANCHORAGE, AK. 99510 TO: William VanAlen , Transmitted herewith-are the following: · pT ,FASE D. W. Bose/Lorie L. Johnson NOTE:. BL - BLUELINE, S - SEPIA, F - FTI~4, T - TAPE RDCEIPT ~~: PT.FASE RETURN RDCEIPT TO: ARCO ALASKA, INC. t,l~k~ 0i% & Gas Cons. ~ommlss~o~l · A~c~orag~ A~: ~~ ~. ~O~~ - ~311 P. O. ~X 360 ~O~, ~. 99510 ARCO Alaska, Inc. Post Offic~'"'%x 360 Anchorage, .,aska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager November 29, 19.82 Mr. Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, A. laska 99504 Dear Chat' Attached are notices of our intent to wells 1E-27, 1E-28, 1E-29 and 1E-30. If you have any questions, please call R. L. Stramp Kuparuk Operations Coord i nator RLS/b Attachments xc' L. M. Sellers - ANO 332 E.. A. Simonsen .- AFA 331 H. C. Vickers AFA 326 acidize Kuparuk Unit me.at 263-4528. RECEIVED NOV 2 0 j.982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA. "~- ALASKA ~L AND GAS CONSERVATION CO~MI~S4(;;)N - - SUNDRY NOTICES AND REPORTSt DRILLING WELL [] 2. Name of Operator ARCO ALASKA, INC. COMPLETED WELL IX] NOV 2 c) J98~ OTHER [] 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20828 4. Location of Well SURFACE LOCATION' 67' FNL, 639' FEL, SEC. 21 T11N, R10E, UM BOTTOM HOLE LOCATION' 1166' FNL, 1329' FEL, SEC. 21, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (KB) I ADL 25651 12. 9. Unit or Lease Name KUPARUK R!VER UNIT 10. Well Number 1E-29 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER 0IL 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 acidize Kuparuk River Unit Well 1E-29 through coiled tubing to improve the well's productivity. The initial production test on this wel 1 indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells with similar characteristics have shown marked improvements following acid treatments. The treatment remover addit to 4000 psig. just below t perforations 4000 psig and the Following the acid coiled tubing and aid will consist of 3780 gals of 12% HCl with mud and silt ives. The coiled tubing unit BOP's will be pressure tested The end of the coiled tubing will be positioned initially he lowermost perforations and then pulled up across the as the acid is pumped. Pump pressure will be limited to tubing pressure will be limited to 1500 psig. treatment, nitrogen will be injected through the the cleanup. During cleanup the well will be produced to tanks on location. the cleanup the well will be produced to CPF1. Following A full production test (pressure buildup and drawdown) will be performed on this well to evaluate the effects of the treatment. Expected start date' December 4; 1982, ,Su~sequent%~or~ , 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. O~ FO~3:]l~ NO. ' ~ '" ?-!' ].)&[¢_~ ed~'~j~j~ ( ~ KUPARUK Sign , Title (~I31::DATTO.IX!S r'nnDr',TklATnD Date - b~4~ -- I -' -'" · ' ~ ~-~"- -'" ' ' ~" The space for Commission use Conditions~t~ Approval, if any: Approved by Form 10-403 Rev. 7-1-80 ORIGIHAL SIGNED BY LOHHIE C. SMITH ~ Approved Copy Returned By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TO: William VanAlen D. W. Bose/Lorie L. Johnson DATE: Transmitted herewith are the follc~ing: PT.WASE NOTE: F - FII24, T - TAPE, PC - PHOTOCOPY / / · /~'/~ A~: ~/PLVASE RETURN POH/EIPT TO: ARCO ALASKA, INC. AFA/3 ~l~sl~ 0il ti !~as t~ons. ~ommission A/TN: LORIE L. JOHNSON- __ Aachofage P. O. BOX 360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. ~"~' Post Office Be,.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 22, 1982 Mr. C. V. Chatterton Commissioner. State of AlaSka Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1E-29 Well Completion Report Dear Mr. Chatterton- Enclosed are the well completion report and gyroscopic survey for the 1E-29. If you haVe any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. Van Dusen District Dril ling Engineer PAV/JG'sm Enclosures GRU2/L24 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany f ,~,~ STATE OF ALASKA ~ ALASL .-.,?gLAND GAS CONSERVATION , :MISSION WELL COMI:I'LETION OR RECOMPLETION REPORT Al,ID LOG 1. Status of Well Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ._ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-154 ,, 3. Address 8. APl NUmber P. 0. Box 360, Anchorage, AK 99510 50- 029-20828 4. Location of well at surface 9. Unit or Lease Name 67' FNL, 639' FEL, Sec. 21, T11N, R10E, UN Kuparuk River Unit A tTopProducing Interval ~ VEP, IFIED ~- lO. Well Number 1136' FNL, 1307' FEL, Sec. 21, T11N, R10E, UM- E i 'iSuR. -__I:---4 1E-29 At Total Depth IB.H.~ 11. Field and Pool 1166' FNL, 1329' FEL, Sec. 21, T11N, R10E, UM'---'-"------- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKBI ADL 25651, ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/14/82 09/21/82 09/25/82I N/A feet MS.LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6835'MD,6648'TVD 6725'MD,6538'TVD YES ~[] NO [] 1963' feet MDJ 1450' (approx) ., 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/Cal/FDC/CNL, CBL 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 79' 24" 284 sx AS II , 10-3/4" 45.5# K-55 Surf 2206' 13-1/2" 1250 sx AS II & 250 sx AS I 7" 26.0# K-55 Surf 6811' 8-3/4" 620 sx Class G ,,, 24. PerforatiOns open to Production (MD+TVD of Top and Bottom and 25. TUBING REcoRD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6442 ' -6462 ' 3-1/2" 6137 ' 6060' 6422 ' -6431" ' 6259'-6289' 4 spf, 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, 6289''6295' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL uSED 6229' -6259' ' N/A ,. 27. N/A PRoDUcTION TEST Date FirSt Production MethOd 0¢ 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~ : Flow TUbing Casing Pressure : CALCULATED OIL,BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) PresS. 24_HODR RATE I~, . . . , , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None REC I¥ D OCT 2 5 ]982 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC6 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 6228' 6294' 6409' 6513' 6042' 6108' 6223' 6327' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~/~'/~~/'~ . Title Sr. Drilling EngineerDate ~/o~//~2-/ / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- DS 1E-29 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1800 hrs, 09/14/82. Drld 13-1/2" hole to 2226'. Ran 56 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2206'. Cmtd 10-3/4" csg w/1250 sx AS II & 250 sx AS I. ND Hydril & diverter. Pumped 750 sx AS I top job. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. (While NU to BOPE, a 4" x 6" x 7/8" shackle was dropped into the hole.) PU Tri-state basket; TIH; rotated on junk; POOH & recovered shackle. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld cmt, FS & 18' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 6835' TD (09/21/82). Ran DIL/SFL/SP/GR/Cal/FDC/CNL f/6838' to 10-3/4" shoe. Ran 147 jts 7", 26.0#/ft K-55, BTC csg w/shoe @ 6811'. Cmtd 7" csg w/620 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 6725' PBTD. Ran Gyro. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 41 bbls AS I, 98 bbls Arctic Pack. Ran CBL f/TD to 2000'. Perf'd 6642'-6462', 6422'-6431', 6259'-6289', 6289-6295' & 6229'-6259' w/4 spf, 90° phasing. Ran 3-1/2" completion assy w/tail @ 6137' & pkr @ 6060'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV @ 1963'. Set BPV. Secured well & released rig @ 1530 hrs, 09/25/82. JG'sm 10/18/82 GRU2/DH12 RECEIVED OCT 2 1982 011 & ~a~ Cons. Con~n~ion Anchorage K U P A R U K A L A S K A :Ri BOSE:- 16114. .Y .BL:SHING ELEV 106. O0 FT. MEASURED I:)EPTH VERT] ] I NATES ': VERT I CAL SEC::T I ON . ~:; : i · :2 :l 0() 2077 : ~ 7:7,~,o7 W ' 27,F)0 2A40" ' ':: '"="" ~ .... 60 : "~;J,:,4 ,,, KUF'ARUK ALASKA 1982 dOB ~. NUMBER BOSS-16114 BUSHI'NG ELEV, = 106.00 FT. MEASURED DEPTH DEPTH!!:':!!:!: ;EVERI TY ' C00RD I NATE$ , i:EAST/WEST VERT I CAL SECT t~ ON 3300 31 , 637; 41 s,..?oo 4500 5/_- 0 0 5 7 0 0 ::0 KLIF'ARUK ALASKA 1982 KELLY BL,,HING ELEV. = 106 c)O FT. F'IE~qoL RED DEPTH VERT LAR . ~] VERT I CAL , : oE'L.T I L N 6800 THE: C:ALCULATI' O KUPARUK ~LASKA . 1.g~2 ,'i:. !~:. :i;,i!i-:il !~ .KE!-L" V BUSHING ELEV. = -...' ';' :,~t] : ' ' ' ' ' 106.00 FT. MEARURED :300,0 " 2 'T.~4E C:ALCULAT: KUF'ARUI< ALASKA :':?' ".~:::<>:~>>:~:.Si ?.:;:~' '-.'"':::~'.',':":' '~:: ·' ,,.,. :=:~- ~-:¥::..'-':: .~::-'~ -~:~<" - :'.;-.z~-..' · .'-' ...... <... - ',~ . .~...,~ -.,,. . ,. · . ~ ~. . . . t~..< ....%.....,-,,.<.~.¥,~....~..~.:~i..,,?~ ~ ,~. - ..,=~ '--.,'.. ..:.-:-:?".-..' i; ..,~;:~. '~ ": :- !~i~.!"'~.~ ~...,.,..,., .,.... ,:,.~:,; ..... ~..,.,.; ....... ..~ .~,:-.:~..= ,., :' ..... dOB 'NUMBER. BOS:E;-16114 MEASURED 206 20~ :':;06 · ._-,0, 906 '"' ' i C '~' .::1406 4 .),.':, :. 151C) : 1506 KLIF'ARUK ALASKA · :, ,':i' ': ~4~;. 1~.82 ' ~ :dOB.. NUMBER ~ BU, ~- 1611,4 ':" .: ? '.i: KELLY. BUSHING' ELEV. = 106,00 FT, I'tEASI, JRED VERT'tCa KUPARUK ALAF~KA 'i .,:~ dOB, NUMBER BOSS- 16114 "" Y BUSHING ELEV. = 106.00 FT. MEASLIRED 4162 '.'4 ' 4264 ' 41:06~ 4 77 4:3'77 KUPARUI< ALASKA ' ~ :>92 KELLY ~USHING ELEV. = 106. O0 FT. MEASURED VERT I~ 6091 61 '.-.? 1 67?2 · KL~F'ARUF'. ALASKA i'::~:_~oss- ~ 6114 · Y<.BUSH!N6 ELEV. =. 106.00 FT. MEA'.E:iJRED 0 ,G 0 ..................... ~: ................................................................. ::~ ~:.~::~ ~:~.: %.: ~.: ~ ~:-:~ ~;~ :: :~.r,~ :.: ~ x.~: c ~ ~ ~.:.:.:.: +~ :. ~.:.;.:+:.:,:. :. x ~.:. ~;i~.~.:~ ~. ~. :.? ?:. :? :. :,:. :,:.:.: ~.::; ~.:;~::~$, ~:;:~ :::; ~ ::: ~ R::;: :~; ::~::;; ~ :¥ :::::::: :'::::: , ' AND SF'ERRY SUN 'SURVEY DATA · . : /: ... . . : .. .... :;.': . ,' · ~: f. :. . Ti. F OF UF'PER ,~ 66'7. !;5;_aW "FOTAL DEPTH DRZ ' 1'32;, 43 O~ Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ' Operator, ' W~i 1 N~me an~ Number ! .. Reports and Materials to be received by: Date Required Date Received Remarks · Complotion Re~ort yes ..... Core ~scription . ,, · Registered ~ey Plat 7e~ Inclination Su~ey ~~ Drill Stm Test Re. ms ~~'~~ , ,, , ~s R~. Yes ' Post Office Bo:/-'"'O AnchOrage, Ala~,,a 99510 Telephone 907 277 5637 October 14, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State RePorts Dear Mr. Chatterton' Enclosed are monthlY reports for September on these drill 1-19 18-6 1-20 18-7 6-21~ 1E-28 6-22 1E-29 13-16 1E-30 13-34 1F-6 1G-2 1G-3 WSW-3 WSW-4 sites' Also enclosed are well completion reports for: 2-26 1G-1 6-20 14-15 (completion report & subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:llm Enclosures GRU2/L15 ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany " ' STATE OF ALASKA ALASKA~-'~L AND GAS CONSERVATION C('"~MISSION . · MONTHLY REPORT DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~ ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-15/+ 3. Address 8. APl Number P, 0, Box 360, Anchorage, AK 99510 50- 029-20828 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 67' FNL, 639' FEL, Sec. 21,,, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation'and Serial No. 106' RKBI ADL 25651 ALK /+69 10. Well No. 1E-29 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of September · 1982 12.Depthatend~fm~nth~f~~tagedri~~ed~fishingj~bs~directi~na~dri~~ingpr~b~ems~spuddate~remarks Spudded well ~ 1800 hfs, 09/1/+/82. Drld 13-1/2" hole to 2226'; csg· Recovered shackle that had been dropped downhole. Drld 8-3//+" hole to 6835' TD; ran open hole logs· Ran & cmtd 7" csg. Ran Gyro/CBL. Perf'd well. Ran 3-1/2" compl. assy. Secured well & released rig @ 1530 hfs, 09/25/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 16" 62 5#/ft, H-/+0, weld conductor set @ 79'. Cmtd w/28/+ sx AS II. 10-3//+", /+5.5#/ft, K-55, BTC csg w/shoe ~ 2206'. Cmtd w/1250 sx AS 7" 26 0#/ft, K-55, BTC csg w/shoe @ 6811'. Cmtd w/620 sx Class G. SEE DRILLING HISTORY II & 250 sx AS I. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL CBL f/TD-2000' f/6838'-2206' 1'8. 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. NOTE--Repo~on ~hi; ~m is req~red for each calendar month, regardless of the status of operations, and must be Oil and Gas ~onservati~ Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 ~117/M~I ? filed in duplicate with the Alaska Submit in duplicate DS 1E-29 DRILLING HISTORY NU Hydril & diverter. Spudded well. @ 1800 hrs, 0~/14/82. Drld 13-1/2" hole to 2226'. Ran 56 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2206'. Cmtd 10-3/4" csg w/1250 sx AS II & 250 sx AS I. ND Hydril & diverter. Pumped 750 sx AS I top job. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. (While NU to BOPE, a 4" x 6" x 7/8" shackle was dropped into the hole.) PU Tri-state basket; TIH; rotated on junk; POOH & recovered shackle. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld cmt, FS & 18' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 6835' TD (09/21/82). Ran DIL/SFL/SP/GR/Cal/FDC/CNL f/6838' to 10-3/4" shoe. Ran 147 jts 7", 26.0#/ft K-55, BTC csg w/shoe @ 6811'. Cmtd 7" csg w/620 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 6725' PBTD. Ran Gyro. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 41 bbls AS I, 98 bbls Arctic Pack. Ran CBL f/TD to 2000'. Perf'd 6442'-6462', 6422'-6431', 6259'-6289', 6289'-6295' & 6229'-6259' w/4 spf, 90° phasing. Ran 3-1/2" completion assy w/tail @ 6137' & pkr @ 6060'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV @ 1963'. Set BPV. Secured well & released rig @ 1530 hrs, 09/25/82. JG:llm 10/07/82 GRU/DH12 TO: William VanAlen FRC~: D.W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT.~ASE NOTE: BL- BLUELINE, S - SEPIA, F - FILM, T- TAPE, _~~- PH~P~ ATIN: LORIE L. JOHNSON P. O. ,BOX 360 ANCHORAGE, AK. 99510 ~ka 0~1 & ~a$ Cons, Commis,~ion An~hor~e ® 2.1 I ~ e.2~ 30 o I p IlL - : . 1 J~ ZZ .k.: T ' i i ,lib IJI ARCO Alaska. Inc. Kuooruk Prolect drawn by ' scale' dwg. no. · ,~?K=~.loS.-/& ~. ~ TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PI.VASE NOTE: BL- BLUELINE, S- SEPIA, F- FILM, PC - PHOTEX/)PY o. ATIN: LORIE L. JOHNSON - AFA/311 P. 0.. BOX. 360 ANCHORAGE, AK. 99510 MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COHMISSION CCha~. ' i ~'terton' DATE: TO: FILE NO: THRU: Lonnie C. Smith Commi ssioner TELEPHONE NO: FROM: DOUg AMOS SUBJECT: Petroleum Inspector September 29, 1982 10 8A/N Witness ROPE Test on ARCO's Kuparuk 1E-29 Well, Sec. 21, TllN, R10E, U.~i. Permit No. 82-154 on Rowan Rig No. 34 Friday, September 17w 1982 - After witnessing the ROPE test ~--'"S0~-i0'S ~A'2'~ W~ii~'1%~veled to ARCO' s Kuparuk 1E-29 well to witness the ROPE test there. The ROPE test commenced at 10:30 a.m. and was concluded at 12:15 p.m. There w~re no failures and I filled out an A.O.G.C.C. ROPE test which is attached. In summa~-_f, I witnessed the successful ROPE test on ARCO's Kuparuk 1E-29 well on Rowan Rig No. 34. O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAs CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well /£- Z{ Location: Sec -~/ T///q R/DE M ~/,/~ Drilling Contractor .~D Date ~' / 7- Well /~'' 2q Representative Permit # Casing set Rig ~ O~ Representativ~ Location, General Well Sign General Housekeeping Reserve pit Rig LOPE Stack Annular Preventer Blind Rams ~ Choke Line Valves H.C.R. Valve / Kill:~ Valves /~ o~ Test Pressure It ACCUMULATOR SYSTEM Full Charge Pressure 7-9~.~ psig Pressure After Closure /~ psig 200 psig Above Precharge Attained: min~ sec , Full Charge Pressure Attained: ,~ min~_._sec N2 Z':SrSr° '~'g;~;~' ~ ~O, / ~7 ~s ig Controls: Master '--~ff~ Remote ~ Blinds switch cover~ Kelly and Floor Safety Valves UPper Kelly / ~Test Pressure ~~ Lower Kelly / ~est Pres~re /' Ball Type ~ ~Test Pressure ,/ Ins ide BOP / Choke Manifold No. Valves No. flanges Adjustable Chokes Hydrauically operated choke Test Pressure ! &'/Test Pressure / Test. Results: Failures A!~q~ Test Time ,~ Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: hrs. ~ , days and i//i ,~~Il Distribution orig. - A0&GCC cc - Operator cc - Supervisor September 10, 1982 Mr. 'Jeffrey B. Kewin Senior Drillin§ En&ineer ARCO Alaska, Inc. P. O. ~-ox 360 Anchorage. Alaska 99510 Res Kupar~ Rive'~ Unit !E-29 ARCO Alaska, Inc. Pe~it Ko. 82-154 Sur. Loc. 638'FEL, 65'FNL, Sec. 21, TllN, R10E, ~. Btmhole Loc. !430'FEL, 1523'FKL, Sec. 21, TllN, R10E, UM. Dear Mr. Kewin~ Enclosed is the approved application for permit to drill the above referenced well. Well samples-and a nd log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted ~on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~t~ny rivers in Alas~m and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Opera~ions in these areas are subject to AS 16,05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you ~ay be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to c~ncing installation of the blowout prevention equipment so that a representative of 'the Commission may be present to witness testing of the equipment before the Mr. Jeffrey B. Kewin Kuapruk River Unit -2- September 10, 1982 surface casing shoe ia drilled. Where a diverter system is required, please also nocify this office 24 hours p~ior to commencing equipment tms~allation so that ~he Co~isolon ~y ~tness testing before drtllt~ below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification-so that we may have a witness present. Very_truly yours, ' ' - "-// .... C. V. Chattert~ Chairman ~f Alaska 0tl and Gas C~mse~vati~n Co~iasion Eric 1 o sure cc, Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC, be ARCO Alaska, Inc. Post Office B .~60 Anchorage, Alaska 99510 Telephone 907 277 5637 September 9, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1E-29 Dear Mr. Chatterton- Enclosed are- o An application for Permit to Drill Kuparuk 1E-29, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map indicating the relative location of Kuparuk wells 1E-30 and 1E-1. o A discussion of wellbore crossings. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. o A map showing the location of the well, as staked. If you have any questions, please call me at 263-4970. Sincerely, /1 or~D~t~ ~~l'i~e r JBK/JG-11m Enclosures GRU1/L91 SEP i m 19B Z· Oil & Gas Cons. commission Aflci~ora.9~. ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA (..,, L AND GAS CONSERVATION CO',v, 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. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 638' FEL, 65' FNL, Sec. 21, T11N, R10E, UN (approx) At top of proposed producing interval 1267' FEL, 1222' FNL, Sec. 21, T11N, R10E, UN R CEIVE SEP 1 ,' ~, i982 9. Unit or lease name Kuparuk River Unit 10. Well number 1E-29 At total depth 1430' FEL, 1523' FNL, Sec. 21, T11N, R10E, UN Alaska 0il & Gas Cons. C0mr Anchorage li~iO~.jeld and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. 72' PAD, 106' RKB I ADL 25651 ALK 469 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 Miles NW Deadhorse IE-1Awell 41' ~ 1937' MD feet 16. Proposed depth (MD & TVD) 7138'MD, 6625'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT3800 feet. 21 14. Distance to nearest property or lease line miles At Surface, 65 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 38° o (see 20AAC25.035 (c) (2) 18. Approximate spud date 09/15/82 2597 2993 psig@ 80°F Surface psig@ 6176 ft TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER . Grade I C°uplingl Length H-40 IWelded I K-55 IBTC I 7107' !' Hole Casing Weight ;~z~,, 16" 65# 13-1/2" 10-3/4" 45.5# .8-3/4" 17" 26# 22. Describe proposed program: SETTING DEPTH M D TOP TV D 80' 35' I 35' 2167' I 33' 33' I 31' I 31' M D BOTTOM TVD 115' I 115' 2200' 12200' I 7138' 16625' I QUANTITY OF CEMENT (include stage data) 250 cf · 1100 sx AS III + .+%~,,~e ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 7138' MD, (6625'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2597 psig. Pressure calculations are based on current reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. 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 completion of the job. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~/~/'~.~ /~, ~/~,~~ TITLE Senior Drilling Engineer The space below/r-C~i~ CONDITIONS OF APPROVAL DATE Samples required []YES ~J~LO Permit number APPROVED BY Mud log required I Directional Survey required I APl number [--)YES ~[NO I ~-MES r-]NO J 50- O-L.~j- ~o8~. ~ _ Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS C//'~/C~~-'--,COMMISSlONER DATE Sept:6~l~er 10, 1982 by order of the Commission Form 10-401 GRU1/PD31 Submit in triplicate ANALYSIS OF 1E-29/1E-1A WELL CROSSING NOTE: Refer to the attached Proximity Map The proposed Well 1E-29 will cross the existing Well 1E-lA by a distance of 41' at a measured depth of 1937'. This distance was calculated using the gyro multi-shot survey on 1E-lA and assuming that Well 1E-29 will be drilled verticallY to its kick-off depth of 3800'. Well 1E-lA has an ellipse of uncertainty of 76' across its major axis at the depth at which the crossing occurs. Well 1E-29 will have a cone of uncer- tainty 14' in diameter at the depth of interest. The areas of uncertainty for the two wells will therefore overlap by 4'. Because the areas of uncertainty in the directional measurements overlap by 4', ARCO proposes that the following procedures be used to drill Well 1E-29: 1. As the 13-1/2" surface hole is drilled vertically to 1937', single shot surveys will be taken to ensure that the hole has 'not deviated in the wrong direction. 2. The first dull bit will be pulled between 1000' and 1500'. At this point, a jetting assembly will be run to impart a small angle (3°+) in a westerly direction. This should ensure a safe crossing with Well 1E-lA. 3. Well 1E-lA will be shut-in if calculations show that a crossing of 45' or less is to occur. This distance cor- responds to the intersection of the areas of uncertainty. Upon shutting in 1E-lA, casing and tubing pressures would be monitored until a safe crossing is evident. In addition to the above precautions, the on-site rig personnel and supervi- sors will continuously monitor all parameters as the interval of interest is drilled. JEO:llm 09/09/82 ONI/AWC2 RECEIVED SE'P 1 o 982 Alaska Oil & Gas Cons. Commission Anchorage Surface Diverter S~,stem 1. 16" Bradenhead. -- 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. '20" bell ~ipple. - R£CEIV£o $£P 1 0 1982 Alaska Oil & Gas Cons. Commission Anchorage 16" Conductor Maintenance & Operation ~- 1. Upon initial installation close annular ! preventer and verify that bal 1 valves ! ~ have opened properly. I 2. Close annular preventer and blow air ~._ . through diverter lines every 12 hours. t 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and' close ball valve to upwind diverter line. Do not shut in well ~ under an~/ circumstances. RNNULRR PREVENTOR BLI ND RRHS 8 ~3.-,5/8" 5000 PSI RSRRA BOP STACKf~, 1. 16" Bradenhead 2. 16" 2000 PSI x lO" 3000 PSI casing head 3. lO" 3000 PSI tubing head 4. lO" 3000 PSI x 13-5/8" 5000 PSI adapter, spool 13-5/8" 5000 PSI 13-5/8" 6000 PSI 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 Be pipe rams drilling spool w/choke ACCL~,IULATOR CAPACITY TEST PIPE RRHS 7 1. . CHECK ANO FILL ACCL~RILATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUIO. 2. ASSURE THAT ACCLt-IULATOR PRESSURE IS 3000 PSI WITH 1S00 PSI IXIW/LSTREA/4 OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIHULTAt(E- OUSLY ANO RECORO THE TIME ANO PRESSURE Rb"4AIN- ING AFTER ALL UIIITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IAOC REPORT. THE ACCEPTABLE LO,dER LIMIT IS 45 SECO2DS CLOSII~ TIME AIIO 1200 PSI REMAINING PRESSURE. - SPOOL 6 PIPE RRHS 5 . 6. 7. 8. TOG HD 3 CSG HD z IVED SEP 1 o 1982 Of) & Gas Cons. Commission l.': ~rhnr~Oe 13-5/8' BOPS TACK TEST 1. FILL BOP STACK N{O MANIFOLO WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLMEAO. RUII IN LOCK DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AllO CHOKES Alto BYPASS VALVES ON MANIFOLO. TEST ALL COHPOND{TS TO ZSO PS! ANO Hi)LO FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PS! ANO MOLO FOR 10 M!NUTES. BLEEO TO ZERO PSI. OPEN ANNULAR PREI/E. tITER AND CLOSE TOP SET OF PIPE RAHS. INCREASE PRESSURE TO 3000 PSI ANO HOLO FOR 10 MINUTES. CLOSE VALVES. 0IRECTLY UPSTRE~! OF CI40ICES. BLEEO OOWNSTREA~ PRESSURE TO ZERO PSI TO TEST VALVES° TEST RDLAINING UtITESTED HANIFOLO VALVES, !F ANY, WITH 3000 PSI UPSTREA~ OF VALVE ANO ZERO PSI DOWNSTREAM. BLEEO SYSTEM TO ZERO PSI. - 9. OPEN TOP SET OF PIPE RN4S AlIO CLOSE BOTTON SET OF PIPE RAILS. 10. INCREASE PRESSURE TO 3000 PS[ ANO HOLD FOR 10 MINUTES. BLEEO TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLINO RN, LSANO TEST TO 3000 PSI FOR 10 MINUTES. BLEEO TO ZERO PSI. 12. OPEN BLIND RAHS AND RECOVER TEST PLUG. MAKE SURE MNIIFOLO Alto LINES ARE FULL OF ARCTIC 01ESEL ANO ALL VALVES ARE SET IN DRILLItlG POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS NtO INSIDE BOP TO 3000 PSI WITH KOC~IEY PU~P. 15. RECORO TEST INFO~"MATION 0~1 BLOWOUT PREVE:ITER TEST FORM SIGN Alto SEIID TO DRILLING SUPER- VISOR. 16. PERFORI.I CC]IPLETE BOPE TEST OrlCE A WEEK MID FUNCTIONALLY OPERATE DOPE DAZLY. RESERVE. .PIT' ' · · -. _- . · . · . . . GYRO MARKER 2"x2"x8' BLACK POST N 5,958,638 . E 549, 7 I 0 _200' . -120' -¢- l~O' '1-20' :I2.0' t20' 120' IE-29 -~ 12o' IE-28 -~ . .) REsERvE PIT* RESERVE PIT · llaska Oil i I D~g.'No: 3.17-17C ' DENOTES WELL SITES FUTURE WELL SITES EIV'ED 'p 1 o 1982 Gas Co~s. Co;nm Anchora,qe sion At lant ic Richf ie IdCompony DRILL SITE "E" -.' ~.AS STAKED WELLS "1E-?_7 to "IE-50" PREPARED BY BOMHOFF ~ ~S$OCI~TE$~ INC. ANCHORAGE ALASKA 'DATE t BCALE ~' .8/lO/82 I": 200' ' DRAWN, K H CNECKEO~ FLR. K. -, i :.WELL LAYOUT DRILL SITE 1E As-Staked -ReferenCe: Field Book 82-05, SR Drawing 22988 Wel]l No. 'lE 27' 1E-28 ]-E' 29 1 E 30 ,NOrth ~ng+ Fas.ti ng-+ FNL* FEL.,* 5959281,~ 87'0 54.9'8-90.750 305' 640' 5959401,860 549890.750 185' 639' -'~5959521..850 54.9890~ 750 65' 638' .5959641-.840 549890.750 5225' 637' + Alaska State Pl. ane Coordinates Zone 4 '* 'Distance ~-~from '-'north .and east sec_ti on 1 i nes. ~ Rang'e ~ ]0 '" East, .. Umiat.-..Meri dj'an., '] Al'ask a. Township 11 North, Secti on 21 21 21 16 RECEIVED SEP o A)~,ska Oil & Gas Cons. Commission CHECK LIST FOR NEW WELL PERI, ITS Company Lease & Well No. ITEM APPROVE DATE (2) Loc (? ~i ..... '~ ~/ thru 8)~ 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 ....................... thru 11) 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. (4) Casg (12 thru 20) (5) BOPE ~.~.~.~Z (21 thru 24) YES NO ? · ..~ 7~-~ Does operator have a bond in force . ~~. Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cover all known prOductive horizons . .................... ,~ Will surface casing protect fresh water ~zones ....................... ~ Will all casing give adequate safety in collapse, tension and burst.. ~ Is this well to be kicked off from an existing Wellbore ............. . ~ Is old wellbore abandonment procedure included on 10-403 ............ ,, Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of.diverter and BOP equipment attached ...,..o /~ Does BOPE have sufficient pressure rating - Test to ,~o~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. R~MARKS Additional requirements ~dditional Remarks: ~ Geology: Engineering: WK LCS BEW er:' 08/19/82 INIT IAL GEO. UNIT ON/OF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry 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. .o ** REEb HEADER DATE ~82/09/25 REEL NAME ~ PREVIOUS REEL 5 NAME CONTENTS UNIT TYPE CATE SIZE CODE CN I ARCO ALASKA INC, 000 000 016 065 WN ] 1E-29 000 ()0o 0o6 065 FN ~ KUPARUK 000 o00 008 065 RANG~ ~OE 000 000 ~04 0~5 TOWNI lIN 000 o00 004 065 EC T{ 21 0oo 000 0o2 065 OUNt NORTH SLOPE 000 ooo 012 065 8TAT~ ALASKA 000 000 006 065 CTRY{ U,S,A, 000 000 006 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE P~ES: DILOOIE 000 non 0o7 065 RECORD TYPE 047 ** BoOTTOM DEPTH TYPE F~UID 6833 FT, FT:~, 2205 FT, X .C POLY~E~ 9 4 65 ,lIN 0 OHMP 7 0 0 0 0 OHM~ 7 I2i: ~ 46 0 0 SP DIE NV 7 1 GR DIL G. API7 3I NPH! FDN NRAT:FDN DRHO FDN RHOB FON NCNL FDN F~NL FDN CAL! FDN GR FDN 0 0 0 32 1 0 0 PU 42 42 G/C3 42 44 0 0 0 · G/C3 42 35 I 0 0 42 34 92 0 0 42 34 93 0 0 IN 42 28 3 0 0 GAPI 42 31 32 0 0 4 o 1 68 4 0 1 68 o 1 6~ 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 D~ 0000 ,U M 0420 8730 N 565 ;R DEPT 6400 CALX 10 ,0000 SF:LU ,7344 GR '2i31'gRH:OB ,2031 GR 72 ,: ,6250 3,2480 0.0:00 FCNL DEPT 6~00 8P 23 DRHO 0 CALl 9 .0000 SFLU 8,3672 ILM ,703i GR" 77,3750 NPH! ,0.537 I~HOB 2,3652 NCNL ,~516 GR 77,3750 6,4688 IL, D 30,9570 N~AT 2214,0000 FCNL OEP? 6200 SP -19 DRHO 0 CALX 11 .0000 SFLU 1,6865 ,5000 GR II0,6875 NPHI ,0723 RHOB 2,3672 NCNL ,1328 GR 110,6875 1,6016 ILD 49,6094 NRAT 1654.0000 FCNL DEPT 8P DRHO CALX O0 0000 SFLU 2 61 , ,2441 XLM -209. 09844 GR 12~ .7500 NPH! , 732 RHOB 2,3340 NCNL 10,8828 GE 122,7500 1 9375 I[.D 46:5820 NRAT 1649,0000 FCNL DEPT SP DRHO CAb! 6000,0000 8FLU 2.6230 '1_7,4063 OR 279.0000 hPHI 089,027 RI-IOB ~,4023 NCNL ,6016 GR 27 ,0000 4~,7969 ILD ,6270 r;RAT 1905,0000 FCNL DEPT 5900,0000 SF[.U 4.7617 IbM 3,3398 ILD 510 50(7: 60~' 0918 ; 0000 ,3677 .8750 721.5000 1.6738 4,0313 427,7500 1,9492 3,8555 393,7500 1,6807 3,5430 501,0000 3.3633 DRHO -99 g SP ."20 DRHO: 999 CALl g 5300 "24 DRHO -999 CALl 1:0 DEPT 5200 SP -21 DRHO -999 CALX 9 0000 SF~U ,0000 ,8750 GR ,0000 8rbU ,4219 Ga ,2500 RH00 .8047 GR D£PT 5100 0000 SFLU SP -21,3906 GR DPHO -999,2500 RHOB CALl 10.2656 GR D£PT $O00,O000 SFLU SP -18,6875 GR DRHO -999,2500 RHOB CALl 10.0156 GR DEPT 4900 8P -19 DRHO -999 CALX 10 .000o SFLU ;3594 GR .2500 RHOB '999,2500 NCNL "'999.2500 FCNL --999 2500 177 9gg ~:250 O: :,:.: FCN :' .,,99g ~ 121,,0410 IbM ,5508 ; ? 50:0 :N:~NI: -99.i~ ' 2500 -999.2500 NCNL -999 2500 126"7500 ' IL, D 2,~5645 NRAT "999 ,: 2500 FCNL -99g, 2500 2,0391 IbM 1,7236 ILD 1,6543 g8,6250 NPHI ggg.2500 '"999,2500 NCNb : .... :999.250u 999;2500 FCNb 999.2500 98,6250 g,~723 ILM ~,9551 II, D ~);9316 10 , 500 NPHI -99 ,2500 NRAT -99 2500 0 NCNL, -999.2500 FC~L -999 250C 100, 2,1699 IbM 2.0781 ILD 2,0840 92.9375 NPHI -999.2500 NRAT g99,2500 -999.2500 NCNb -999.2500 FCNL :999.250o g2.9375 2,0137 II, M 2,0137 ILD 2,050~ · 95,0000 NPH! -999,2500 NRAT -999.2500 -999,2500 NCNL -999.2500 FCNL -999.2500 95,0000 0000 ~U t~ D ~4 }B 0000 -:SFLU 1094 2402 N~AT 3,8457 DEPT 410~,0000 SFLO 3 3047 IbM ~,2246 ILD ~,4648 SP 3 ,4375 GR 94 X250 NPHI 3 ;1074 NRAT ,2598 DRHO 0.0620 RHOB 2 3105 NCNL 1902.0000 FCNL 580.000~ CAbX 12,3828 OR 94 1250 DEPT 4~00,0000 8FLU 2,488{ IbM 2.9766 ILD 3,2441 SP 38.6575 GR 100,a750 NPH! ~.~4~4 N~AT 3.5{17 DRHO 0.0986 RHO8 2.37il NCNb 18 0000 FCNb 488,0000 85" CALX 11.7813 GR 100.8750 DEPT 3800,0000 8FLU 6 3398 IbM 5,5625 ILD 5.6680 SP -46,9062 GR 69:5625 NPH! 42.4316 NRAT 3,62@9 DRHO O.OBB9 RHOB 2,2813 NCNb 2060.0000 FCNL 535.5000 CALl 10,9766 GR 69,5625 I ON L P 0000 $ 7 D 7 DRH0 0 0347 !207 ~CN 546 0000 0000 U 0 IbM ILO 9 NL OEPT SP DRHO CALl SP DRHO C~L! DEPT SP DRHO DEPT SP DRHO CALI DEPT 5P DRHO 0000 ~FLU 9062 3100,0000 SFLU :"74.,6250GR 0,0186 RHOB 10.6563 GR 3000 0000 SFLU -67" ,3750 GR 0.0293 RHOB 10.0781 GR 2900,0000 SFLU -47,5938 GR 0,0430 RHOB 9,9141 GR 2800.0000 $FLU -60,3438 GE O.0181 RHOB 10.8047 GR 2700,0000 SFbU -57.5938 GR 0,0322 RHOB 4219 IbM I ILD NL )00 15,2266 IbM 43,53i3 NPMI 0781 NCNb 15,5859 39'~404:3 NRAT 2!64,0000 FCNL 11.3359 IbM 11.3828 ILD 43,0625 NPHI 40,0879 NRAT 2 ,1367 NCNb 2086,0000 FCNL 43,0625 4,4258 IbM 4,7930 65,2500 NPH! 50,9277 NRAT , 1575 NCNL 1884,0000 FC~L 6 .2500 6~,7734 IbM .9687 NPHI 6~'1484 NCNb .9687 9.0703 ILD 45,9473 NRAT 1932.0000 FCNL 9062 NPHI 45:6543 NRAT 2.119! NCNb 2232.0000 F'CNL 12 56 15, 578,5000 11.8906 3,4414 573,0000 5.1562 4.0273 41~,5000 10,7344 3.8203 453.0000 9,4453 3.8047 532,50U0 DEPT 217~!~, DRHO '0,6240 RH08 C:AT~I 10.3'906 ,0000 IbM ,4~?.5:' NP:H:! ** FX~E TRAILER ** FILE NAME ISERVIC.00I VERSION # = DATE { MAXIMUM LENGTH = 1024 FILE TYPE { NEXT FILE NAME = EOF ** TAPE TRAILER SERVICE NAME ISERVIC DATE 182/09/25 ORIGIN 16562 TAPE NA~E CONTINUATION # NEXT TAPE NAME COMMENTS t$CHLUMBERGER WELL SERVICES FIELD TAPE 20 12! 0000 FCNL ,92:t 235. 0000