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Home My WebLink About185-147Originated: Delivered to:8-Jul-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-04 50-029-20595-00 910151309 Kuparuk River Plug Setting Record Field- Final 30-Jun-25 0 12 1B-05 50-029-20237-00 910106098 Kuparuk River Multi Finger Caliper Field & Processed 19-Jun-25 0 13 1B-05 50-029-20237-00 910106098 Kuparuk River Plug Setting Record Field- Final 21-Jun-25 0 14 1B-11 50-029-20657-00 910151309 Kuparuk River Multi Finger Caliper Field & Processed 1-Jul-25 0 15 1B-11 50-029-20657-00 910149873 Kuparuk River Plug Setting Record Field- Final 1-Jul-25 0 16 1B-15A 50-029-22465-01 910106169 Kuparuk River Plug Setting Record Field- Final 20-Jun-25 0 17 1D-101 50-029-22988-00 910151308 Kuparuk River Packer Setting Record Field- Final 6-Jul-25 0 18 1H-103 50-029-23593-00 910082841 Kuparuk River Multi Finger Caliper Field & Processed 21-Jun-25 0 19 1L-24 50-029-22170-00 910151023 Kuparuk River Packer Setting Record Field- Final 28-Jun-25 0 110 2A-16 50-103-20042-00 910150862 Kuparuk River Plug Setting Record Field- Final 27-Jun-25 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:181-065177-001181-136204-256200-183218-003191-066185-147T40642T40643T40643T40644T40644T40645T40646T40647T40648T406497/9/2025102A-1650-103-20042-00910150862Kuparuk RiverPlug Setting RecordField- Final27-Jun-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:29:07 -08'00' Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1E-07A 50-029-20495-01 909619502 Kuparuk River Packer Setting Record Field- Final 20-Oct-24 0 12 1E-28A 50-029-20832-01 n/a Kuparuk River Packer Setting Record Field- Final 16-Jan-25 0 13 1F-08 50-029-20836-00 909737879 Kuparuk River Plug Setting Record Field- Final 3-Dec-24 0 14 1H-101 50-029-23585-00 909606936 Kuparuk River Multi Finger Caliper Field & Processed 28-Oct-24 0 15 1R-20 50-029-22207-00 909678505 Kuparuk River Packer Setting Record Field- Final 11-Nov-24 0 16 2A-16 50-103-20042-00 909780661 Kuparuk River Multi Finger Caliper Field & Processed 1-Jan-25 0 17 2C-03 50-029-20968-00 909740014 Kuparuk River Plug Setting Record Field- Final 14-Jan-25 0 18 2M-07 50-103-20178-00 909618938 Kuparuk River Plug Setting Record Field- Final 25-Oct-24 0 19 2W-01 50-029-21273-00 909740411 Kuparuk River Radial Bond Record Field- Final 7-Jan-25 0 110 3B-04 50-029-21323-00 909740412 Kuparuk River Multi Finger Caliper Field & Processed 3-Jan-25 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:T39999T40000T40001T40002T40003T40004T40005T40006T40007211-062213-095182-162217-138191-108185-147183-089192-080185-010185-061T400081/23/2025191 108185-147183 0892A-1650-103-20042-00909780661Kuparuk RiverMulti Finger CaliperField & Processed1-Jan-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:13:51 -09'00' Ir Project Well History File' Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier RESCAN DIGITAL DATA Color items: B Grayscale items: [] Poor Quality Originals: [] Other: [] Diskettes, No. [] Other, No/Type NOTES: OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanning Preparation BY: BEVERLY BREN VINCENT SHERYL O LOWELL Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: ¢~' y PAGE COUNT MATCHES NUMBER IN SCANNING PI~ARATION: V YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: Stage 2 BY; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (individual page [special attention] scanning completed) RESCANNEDBY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked {done) 10125/02Rev3NOTScan ned.wpd ! • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2A-16 Run Date: 6/26/2010 July 16, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-16 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-103-20042-00 Production Profile Log 50-103-20042-00 A ,~l~~m~~ ~:~.tj~: x .~~3~~ . 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com ~! ~' ~~~ f Date: __,a /9939 Signed: t~ ~ . ~or~+ra~ ~o'~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 2 3 2010 1. Operations Performed: Abandon Re air w ell ~"" p Plug Perforations Stimulate ~~~~ Cp(pt(11SSI Alter Casing ~" Pull Tubing Perforate New Pool """ Waiver ~`-' Time ExtensionA Change Approved Program (erat. Shutdown ~"""" Perforate ~°' Re-enter Suspended Well "` 2. Operator Name: 4. Current Welt Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory 185-147 3. Address: .API Number: P. O. Box 100360, Anchora e, Alaska 99510 Stratigraphic ~ Service ~ 50-103-20042-00 7. Property Designation` 8. Well Name and Nu ber: ~ ADL 25570 2A-16 9. Field/Pool(s): \ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9888 feet Plugs (measured) None true vertical 6368 feet Junk (measured) None Effective Depth measured 9738 feet Packer (measured) 5758, 8543, 8592, 9373 true vertical 6260 feet (true vertucal) 4066, 5540, 5565, 6017 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 104 104' SURFACE 3581 9.625 3609 2856' PRODUCTION 8989 7 9017 5790' LINER 1160 5 9888 6368' Perforation depth: Measured depth: 9284'-9348', 9482'-9506', 9530'-9558' `~-~.~~. i~'s r ~~~' ~~ ~.~ ? ~ (~t True Vertical Depth: 5956'-6000', 6089'-6105', 6121'-6140' Tubing (size, grade, MD, and ND) 3.5 / 2.375, N-80, 5739 / 9395 MD, 6031 ND Packers & SSSV (type, MD, and ND) PACKER -BAKER "FHL PACKER @ 5758 MD and 4066 TVD PACKER -BAKER "FHL PACKER @ 8543 MD and 5540 TVD PACKER - CAMCO HRP-1-SP PACKER @ 8592 MD and 5565 TVD PACKER -BAKER DB PACKER @ 9373 MD and 6017 ND NIPPLE - 3.5" x 2.875" Camco "DS" Nipple @ 533 MD and 533 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 549 2034 2567 - 223 Subsequent to operation 1101 1358 1794 -- 203 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E) lorato ' Developm ent Service . Well Status after work: OII Gas WDSPL Daily Report of Well Operations XXXX SPLUG °" GSTOR WAG GASINJ WINJ "'-" 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or rlia, if C.o. Exempt: 310-006 contact Howard Gober l~ 263-4220 Printed Name Howard Gober Title Wells Engineer Signature Phone: 263-4220 Date ,~ I L-( Form 10-404 Revised /2009 2 3 ~ %` Y ,~ ~o Subm~it~Original Only .-° Cono~c~Phiilips ... W3p C fig7q&tn6, 3f2 _ _, Stlt__epc-Ar HANGER. 22 - CONDUCTOR, _ 26-106 NIPPLE. 533- PRODUCTION W/0,30-1,929 GAS LIFT. 3,06] E SURFACE. 313,609 GAS LIFT. _ a.]s GAS LIFT, 5,664 LOCATOR, 5.719 Seeing Sleeve, --- 5,]20 \ SEAL ASSY, 5,]20 '~ SBE, 5.727 PACKER,S,]58- PACKER. 8.543 NIPPLE, 8.561-- -- - SBR Overshot, a 571 \ seR.as]s- PACK=R. 8.592 PRODUCTION. 6.631 SLEEVE-O, 8.668 NIPPLE, 6.668 - PRODUCTION,- 1 9259,01] IPERF. s.zea-s,36e SEAL ASSV. 5,371 PACKER. 9.373 SBE, 9.3]6 NIPPLE.9,389 WLEG, 9,395 KU P 2A-16 ll Attrib J t ,~r{- , , - jMax Angle $ MD TD 'I e u es ellbore APVUWI Field Name Well Status Inc! (°) MD (HKB) Act Btm (HKB) 501 03 20 04 200 ~KUPARUK F:IVEI=: UNIT PRO D ~ 60.15 ~ 7,900.00 9,888 0 merit ~H25 {ppml (Date (Annotatio n (End Date KB-Grd (ft) Rig Release Date 3SV~ NIPPLE 425 I 1/10/2009 Last WOE 3/22/2010 34.50 8/20/1985 notation Depth (ftKB) EndL 1 Annotation (Last MOd ...'End Dafe fst lag JLM 9.806.0 I 1/;:' t 1 Rev Reason Warkover_Pull ball/Rod RHC. GLV C/O Imosbor 3/25/2010 asing Strings - _ s rig Descr priori String 0... ~ 51 ing ID Top (ftK6) Set Depth (f. __ Set DepN (ND) Sir rig Wt. S1r rig ... String Top Thrd UCIO UN h 6 40 100 1(74.0 6250 H-00 ~ ~ rsin Descri tion ~Btn~n Strin O. g ID g p( To HK6) ) ( Sef De th f... Set Depth ND ' String Wt... ( String ... (String Top Thrd JRFACL / 95/8 d.:65 30.6 3,609.3 2,857.5 36.00 J-55 BTC rsing Description String 0... String ID . _ Top (HKB) Set Depth (f. .. Set Depth (ND) ... String Wt... String ... String Top Thrd TODUCTION 7 (5.151 24.3 9,017.4 5,790.4 26.00 J-55 BTC (sing Description String 0... Btring ID .. . Top (kK8) Set Depth (f. .. Set Depth (NO) ... String Wt... String ... String Top Thrtl TODUCfION WIO 7 6.7;6 30.1 1,929.0 1,809.4 26.00 L-80 TC2 __ rsing Description ~ String 0... String ID .. . Top (HKB) Set Depth (f. .. Sat Depth (ND) ... String Wt... String ... String Top Thrd NER 5 4.1'11 8,727.7 9,888.0 15.00 K-55 FL45 finer Details -_ T p Depth (NDI T p I cl 1 Nomi... >p (HK6) (ftK6) () ', Item D iption Comment ID (in) 8,127.7 5,635.7 58.54' HANi LR BAKER'DAG' LINER HANGER & TIEBACK RECEPTACLE 5.000 ubin Strin s ibing Description String 0... 51 g ID . _ Top (HKB) Set Depth (f. - ___- .. Set Depth (ND) Str rig Wt_. Str g .. Stri g Top Thrtl JBING Uocer 31/2 _. :92 22.0 5,739.0 4,055.0 9.30 I LAO EUE 8rd Too Inc! 1 Nomi... Top (HKB) In^ol (') Item Description __- Comment iv t"4 22.0 22.0 0.18 HANGER FMC, TCta Hanger, ENS 7 7/1fi" x 3 1!2 2.992 ' 533.1 533.1 0.79 NIPPLE 3.5" x 2.875" Camco "DS" Nipple -- ___.__ 2.875' 5,718.7 4,043.6 56.06 LOC.41 OR LOCATOR 3.0001 5,719.9 4,044.3 56.06 SEAL ASSY Baker 80-0O BONDED SEAL ASSEMBLY w/7.84'space out 3.000 Tubing Description String 0... String ID ~__. Top (HKB) Set Depth (i... Set Depth (ND) .. . String WI... String ... String Top Thrd I UBING Lower 3 t/2 -' 992 5,719.9 8,587.5 5,562.9 9.30 L-80 EUE 8rd Completion Details - _ -- - - - - -. - Top Depth (ND) Top Inc! Nomi... Top (ftKB) (HKB) (°) Item Desn'i priori Comment - _ ID (in) 5,719.9 4,0444 56.06 Semnq Sleeve LINER SETTING SLEEVE 5.250 5,727.5 4,048.6 56.04 SBE Baker "80-00" Seal Bore EMension 4.000 5,746.3 4,059.1 55.98 XO - Rerlucmg 5" BTC Box x 3.5" EUE 8rd Pin X-O Sub 2.970 5,758.0 4,065.7 55.95 PACF;EI? (Baker"FHL Packer 2930 8,543.1 5,540.1 5905 PACKEI? Baker "FHL Packer 2.9301 8,560.6 5,549.1 59.01 NIPPLE 3.5" x 2.812" Camco "DS" Nipple 2.812 8,568.0 5,552.9 58.991X0 - Reducing 3.5" EUE Srtl Boz x 2.875" EUE Srtl Pin X-O Sub 2.441 8,571.0 5,554.41 58.98~SBF: Overshot OEJ w! 3' Space out 2313 Tubing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) .. .:'String W[... ',String ....String Top Thrd I UBING Original 2 3/8 1 1.595 8 SSS 0 9 396.1 6,031.8 4J0 N-80 ~ EUEBrd ~ . Completion Details _ "' ''iTop Depih (ND) lop Inc! Nomi... Top (ftK6) (HKB) (°) Item Description Comment ID (in) 8,572.0 5,554.9 58.98 XO 3 Sx3.E/5 2.875 8,575.0 5,556.5 58.97 SBF. CAMCO OEJ SBR 2.297 8,592.5 5,565.5 58.92 PACN:EF: CAMCO HRP-I-SP PACKER 2.344 8,668.1 5,604.7 58.74 NIPPLE -- AVA BPL PORTED NIPPLE 2.250 8,702.2 5.622.4 58.62 XO ~~-~--- - 2.375 2.875"x23!`_" 9,371.4 6,015.3 47.93 SEAL A.SS'Y BAKER LOCATOR SEAL ASSEMBLY 1.995 9,373.2 6,016.5 47.94 PACN;EF: BAKER DB PACKER 3.250 9,376.2 6,018.6 47.97 SBE SEAL BORE EXTENSION 2.375 9,389.4 6.0274 48.07 NIPPI_F. CAMCO'D' NIPPLE 1.812 9.395.3 C;.03 L31 48.11'1 WLEG OIIS SHEAR OUI SUB w/WIRELINE RE-ENTRY GUIDE 1.9951 pumps fish et I Other In Hole (Wireline retrievable plugs valves c.) i , , , , Top Depth , (TVDI Top Inc! Top (HKB) (HKB( (°) Descuop[iun~ Comment _ Run Date ID (in) _ . _. 8,668 5.604. / l SLEEVE ! 2.25" AVA BPC SET IN PORTED NIPPLE S8 /4 (OPEN 5/20/2006 1.875 5/20/2006) Perforations & Slots _. _- snot _. - - Top (TVD) etm (NDj Dens Top (ftKB) Bim (ftK6) (ftKB) IfIKBi Zone Date (sh-~ Type Comment 9,284 9,348 5,956.4 `.~,:J99.5 C-0, 2A-16 9!9/1985 12.0 IPERF 3 3l8" Csg Gun; 60 deg ph 9,482 9,506 6 089.2 i?.705.3 A-0, 2A-16 9/9/1985 12 0 IPERF 3 3/8"Csg Gun; 60 deg ph 9,530''. 9.558 6.121.4 5.14(1.1 A-3, 2A-16 9/9/1985 i 12.0 IPERF 3 3/8" Csg Gun; 60 deq ph Mandrel Details ~_ ', Top Depih Top ' Port (TVDI Inc! OD Valve Latc h S¢e TRO Run Stn Top (HKB)( (ftKB) (°) Make 1 Model (in) Serv Type Typ e (in) (psi) Run Date Com... 1 304691 2,522.4 53.70 CANICU KBMG 1,GAS LIFT iGLV BK 0.156 1.260.0 3/23/2010 I 2 4,750.71 3,506.6 55.73 CAMCO KBMG 1 GAS LIFT ~GLV BK '0.188 1,298 0 3/23!2010 I 3 5 663.7 4,013.0 56.23.CA^eICO KBMG 1 GAS LIFT OV BK 0.250 0.0 3/23/2010 4 8,631.3 5,585) 5886~jCAl'oICCi k:BMG 1 PROD DMY BK 0.000 0.0 5/27/2003 LINER, 8,][8-9,888 TD. 9.888 ~©r-exciPh~{lips ... W eM Conf g ~ 2q-t6, 325f2i Schematic-Ac HANGER. 22 KUP 2A-16 KB-Grtl (H) it Rig Release Date L 34.50 8/2011985 Annotation ___ SCI-IEIvl:li lC w/Alaska Schematic9.0 ~mER, 8,]28-5,888 \ TD. 5.888 2A-16 Pre Rig Events DATE SUMMARY 1/19/10 PULLED 3" ER TEST TOOL @ 5848' RKB, JOB SUSPENDED DUE TO DIMINISHING WEATHER. IN PROGRESS. 1/20/10 TAG @ 9806' RKB, MEASURED BHP @ 9421' RKB(2883 psi).GRADIENT@ 9271' RKB (2841#). REPLACED GLV'S @ 2815' RKB & 4721' RKB W/ 1" DVBK'S. IN PROGRESS. 1/21/10 ATTEMPT TO LOCK OUT SSSV (UNABLE TO OBTAIN CLOSURE TEST AND UNABLE TO SEE FLOW TUBE MOVEMENT PRIOR TO LOCKING OUT ). IN PROGRESS. 1/22/10 LOCKED OUT TRDP-1A-SSA @ 1899' RKB. PULLED ER PACKER PATCH ASSEMBLY @ 5848' RKB. PULLED ER PACKER @ 5875' RKB. DRIFTED TBG.DOWN TO 8630' SLM. WELL READY FOR E-LINE 1/23/10 (PRE RWO) T POT -PASSED. T PPPOT -PASSED. IC POT -PASSED. IC PPPOT -PASSED. FUNCTION TEST LDS's 1/24/10 RIH WITH WEATHERFORD WRP (2.25 OD) AND SET THE WRP @ 8626'. 1/25/10 SET JUNK CATCHER ASS'Y (1.875" G-FN, OAL=53") ON TOP OF WRP @ 8626' MD. "**NOTE: CATCHER ASS'Y BELONGS TO HES UNIT #765*"". PULLED DV @ 8529' RKB *"*OPEN POCKET***. JOB COMPLETE. 1/26/10 PERFORMED MIT: PASSED. (2525-PSI INITIAL MIT PRESSURE, 2440-PSI 15-MIN PRESSURE, 2420-PSI 30-MIN PRESSURE.) BLED TUBING TO 0-PSI AFTER MIT. 1/27/10 PUNCH HOLES IN TUBING AT 8559.9' - 8565.0' WITH 5.1-FT HES 2-IN TUBING PUNCH. PERFORMED TUBING CUT USING RADIAL CUTTING TORCH (RCT); CUT TUBING AT 8557.0', MIDDLE OF FIRST FULL JOINT ABOVE SBR. APPEARED TO OBTAIN SUCCESSFUL CUT, ,{L~~ HOWEVER, RCT BECAME STUCK AT CUT. HAD TO PULL OUT OF WEAK POINT AT CABLE- ~"~' HEAD TO RIG OFF WELL. 1/31/10 RECOVERED E-LINE TOOLSTRING @ 8525' SLM. COMPLETE. 3/23/10 PULLED BALL & ROD @ 8561' RKB. REPLACED DVs @ 3046' & 4751' RKB WITH GLVs. REPLACED SOV WITH OV @ 5664' RKB. ATTEMPTED PULL RHC. IN PROGRESS. 3/24/10 PULLED RHC f/ 8561' RKB. BAILED FRAC SAND & METAL PIECES f/ 8588' - 8597' SLM. IN ~oS.E r~ PROGRESS. 3/25/10 BAILED FRAC SAND & METAL DEBRIS f/ 8597 - 8604' SLM. IN PROGRESS. 3/26/10 UNABLE TO WORK LIB PAST OEJ @ 8575' RKB. BAILED FRAC SAND & METAL DEBRIS f/ 8604' - 8607. IN PROGRESS. 3/27/10 BAILED FRAC SAND & SCALE f/ 8610' - 8617' SLM. ATTEMPTED LATCH JUNK BASKET. IN PROGRESS. 3/28/10 BAILED FILL & PULLED JUNK BASKET f/ 8617' SLM. PULLED WRP f/ 8626' ELM (1/3 OF ELEMENT MISSING). COMPLETE. ConocoPhiilips Time Log & Summary Welfview Web Reporting Report Well Name: 2A-16 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/1/2010 1:00:00 AM Rig Release: 3/21/2010 8:30:00 PM Time Lo s Date .From. Ta Dur S. De th E. De th Phase Code Subcode T Comment 2/27/2010 24 hr summary RDMO of 1J-158. Break down and load 13 5/8 BOP on skid. PU and Rack back 11" 5M stack. Prep rig. Rig released at 1630 HRS. Move ri to 1 D ad. Held u until midni ht as tem eratures were - 44 de . 16:30 17:30 1.00 MIRU MOVE MOB P Move rig from 1J-158 to 1J Pad entrance. 17:30 20:30 3.00 MIRU MOVE MOB P Move rig from 1J pad to 1D pad. 20:30 00:00 3.50 MIRU MOVE MOB T Wait on weather as temperature had dro ed to -44 DEG. 2/28/2010 Continue move rig from 1 D to Oliktok Y. Wait on crew change. Continue rig move to CPF-s. Wait on CPF-2 Crew chan e. Continue move to 2B. 00:00 05:00 5.00 MIRU MOVE MOB P Continue move rig from 1 D to Oliktok Y. Tem erature from -38 to -41 De . 05:00 06:30 1.50 MIRU MOVE MOB T Rig held up at the Oliktok Y for CPF-2 Crew chan e. 06:30 14:00 7.50 MIRU MOVE MOB T Standby with crews waiting for temperature to rise above -40 de rees. 14:00 17:00 3.00 MIRU MOVE MOB P Road rig from Oliktok "Y" to 2 X Pad access road. 17:00 19:00 2.00 MIRU MOVE MOB T Standby with crews for CPF 2 Crew change -temperature -36 degrees as of 16:30 hrs 19:00 00:00 5.00 MIRU MOVE MOB P Move rig from 2 X Pad access to 4- corners. 3/01/2010 Continue move rig form 4 corners to 2A. Lay mats. Set berms. Set tanks, berm same. Spot rig over 2A-16. Rig accepted @ 0100 HRS 3-1-2010. RU to kill well. Load pits with 9.6 PPG Brine. Pull BPV. Load hole with 324 BBLS of 9.6 PPG brine. Monitor well -static. Install BPV. Function LDS. Nipple down Tree. Nipple up 11" BOP's. 00:00 00:30 0.50 MIRU MOVE MOB P Continue move rig form 4 corners to 2A Pad. 00:30 01:30 1.00 MIRU MOVE MOB P Set up well liner and Hang tree in cellar. Prep to spot rig. Acce t Nordic Ri 3 1:00 hrs on 3-1-10. 01:30 02:00 0.50 COMPZ MOVE MOB P Spot rig over well 2A-16 and berm u. 02:00 06:30 4.50 COMPZ MOVE KLWL P Load pits with 9.6 ppg brine. RU to kill well. Rig up auxiliary equipment. Warm u well head. 06:30 07:00 0.50 COMPZ WELCTI SFTY P Held PJSM with crew. Reviewed overview of the workover procedure and killin of the well. Page 1 of 25 Time Lo s ' Date From To Dur S. De the E. De th Phase Code Subcode T Comment 07:00 10:00 3.00 COMPZ WELCTL MPSP T RU Lubricator and attempt to pull H BPV -was able to tap into BPV and see 750 psig TBG pressure. Not able to release BPV -tore up prong. Place steam blanket around tree and heat up tree for 2.5 hrs. Release BPV and Lubricate out BPV. 10:00 13:00 3.00 COMPZ WELCTL CIRC P O en up well - SITP = 750 psig, SIIAP = 750 psig and SIOAP = 1,050 psig. Strap on kill tank was 119" _ empty. Notify Security and DSO for the venting of gas. Bled off gas head of the TBG and IA to kill tank. Begin pumping down TBG @ 3 bpm @ 230 ICP and pump 3,871 stks / 226 bbls - SWI w/ choke and gauge tank 59" = 248 bbls in Kill tank -Change out crews -Strap tank 66" = 280 bbls - kill fluid siphoning thru pump. Begin pumping @ 3 bpm @ 410 psig till KWF at surface @ 5,000 stks / 292 bbls pumped w/ 420 FCP + 32 bbls si honed = 324 of 9.6 KWF. 13:00 13:30 0.50 COMPZ WELCTL OWFF P Monitor well for flow 13:30 14:00 0.50 COMPZ WELCTL MPSP P Dry rod and Set HBPV. Lay down d rod. 14:00 15:30 1.50 COMPZ WELCTL NUND P ND Adapter and Tree 15:30 16:00 0.50 COMPZ WELCTL MPSP P Clean and inspect TBG Threads - MU Blanking plug. Function all lock down screws. 16:00 00:00 8.00 COMPZ WELCTL NUND P NU 11" BOPE, including choke & kill lines. 3/02/2010 Continue NU 11" BOP stack. perform BOP test. Witness of test waived by AOGCC rep -John Crisp. Pull hanger to rig floor with 150K upweight. CBU. No gas. POOH to SSSV with no overpull issues. Observed string dragging 95-100K initially. Recovered 29 SS bands and 100% of control line. Observed proper dis lacement. 00:00 01:00 1.00 0 0 COMPZ WELCTL NUND P Contiue nipple up 11" BOP stack, choke & kill lines. 01:00 07:30 6.50 0 0 COMPZ WELCTL BOPE T Ri up and attem t to test 11" BOP . stack. Troubleshoot leaks. Install test joint with blanking plug. Continue chasing leaks. Witness of test waived by AOGCC rep -John Cris . 07:30 08:30 1.00 0 0 COMPZ WELCTL BOPE T Begin bleeding OA to kill tank. Cleaned lifting threads again and Chan ed out blankin lu . 08:30 11:30 3.00 0 0 COMPZ WELCTL BOPE P Test BOPE 250/3500 psi. Test choke manifold and all valves. Test HC's and manuals including floor safety valves. Perform Koomey test. Initial 200 PSI in 20 secs, with full 2900 PSI attained in 85 secs. 6 Nitrogen bottles with avg PSI of 2500 PSI. Page 2 of 25 Time Lo s Date .From To Dur S. De th E De th Phase Code Subcode T Comment 11:30 13:00 1.50 0 0 COMPZ RPEQPI MPSP P Pulled blanking plug. Checked IA for pressure - 0. Pulled BPV. MU landing jt in hanger. MU top drive to landing jt. and set down 2K wt. BOLDS. No movement of tubing t in to ush u on han er. 13:00 13:30 0.50 0 0 COMPZ RPEQPI PULL P Pulled tubing hanger loose and out of _ bowl. Pulled max.(114K + TP wt 35K) 150K, 80% of yield, tubing not loose. Worked up and down to max with no luck. Pulled approximately 6' of stretch. Pulled max. 150K and set brake. Call E-line for new cut. 13:30 14:00 0.50 0 0 COMPZ RPEQPI PULL P Wait on E-line. While waiting with 114K + TP wt on tubing, weight dro ed off to 65K + TP wt. Pulled hanger to rig floor dragging w/ 22K over. 14:00 17:00 3.00 0 0 COMPZ RPEQPI CIRC P Established circulation w/ 9.6 ppg brine to ensure well is loaded wih 9.6 brine.Circulate @ 3 - BPM , 290 PSI. Observed no as on bottoms u . 17:00 17:30 0.50 0 0 COMPZ RPEQPI PULL P POOH, laid down landing jt, hanger. RU Schlumberger spooling unit. Blow down to drive & lines. 17:30 22:00 4.50 0 0 COMPZ RPEQPI PULL P POOH laying down 3 1/2" tubing._ Spool control line. Pull to SSSV recovering 29 SS bands (Note: 33 run originally) and 100% of control line. Observed no overpull issues when SSSV pulled to surface. Observed string initially dragging with 95-100K. When we reached joint number 50, drag smoothed some, and steady at 80K. Tubing condition looked good. UP WT = 80K, SO WT 60K. Observed ro er dis lacement. 22:00 23:00 1.00 0 0 COMPZ RPEQPI PULL P Breakout & lay down SSSV. Unload tubing form DS pipe shed. SIMOPS: Crew loading 3 1/2" DP on ODS pipe shed while la in down tubin . 23:00 00:00 1.00 0 0 COMPZ RPEQPI PULL P Continue POOH laying down 3 1/2" tubing. Observed proper dis lacement. 3/03/2010 Continue POOH lay down 3 1/2" tubing & 10 GLM's. recovered OEJ-SBR. Observed tbg was not cut. Observed external corrosion on tubing string. TBG punch holes were good. Observed proper displacement. Load Pipe shed with DP & DC's. Install wear bushing. PJSM. MU BHA #1, 6 1/8" bit & scraper assembly. TIH, ickin u sin les from shed to 4500' DPM with no issues. Page 3 of 25 Time Lo s -Date From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 13:00 13.00 0 0 COMPZ RPEOPI PULL P Continue POOH laying down 3 1/2" tubing. Observed proper displacement. Observed 3 1/2" tubing "slightly" corkscrewed when laying in pipe shed starting on joint number 89. Obtain SLM tubing when POOH. Bad corroded 3 1/2" tubing started @ approx. 5769', corroded bad until 6365' (600') remainder of couplings corroded moderately. Good hole fill. Recovered 272 jts. 3 1!2" tubing, 10 GLM, 1-CAMCO 2 7/8" OEJ SBR. 13:00 16:00 3.00 0 0 COMPZ RPEOPI PULL P Break out SBR, and last jt with Radial Cutting Torch attempt, while laying down this jt it bent at spot of attempted RCTcut. Marked and sent to DTH for samples to be cut out for analyzing. Kick out remainder of 3 1/2' tubing. Load 4 3/4"drill collars in i e shed. 16:00 16:30 0.50 0 0 COMPZ WELLPF OTHR P Install wear bushing. RILDS 16:30 17:00 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM with Crew & BOT rep. Discuss safety & hazard recogniiton issues. Discuss procedure to make up BHA and TIH picking up drill pipe sin les. 17:00 00:00 7.00 0 4,495 COMPZ WELLPF PULD P PU & RIH w/ 6 1/8" bit (open jets), 7' all weight casing scraper, bumper and 6-4 3/4" drill collars. RIH on 3 1/2"drill pipe (picking up) to 4495 DPM. UP WT - 85K, SO WT = 82K. . Observed proper displacement. While RIH, notice scraper turning to the left from 250' to 350'. MU top drive to run thru this spot so scraper would not back off. 3/04/2010 Continue TIH with BHA #1, picking up DP singles from shed to 8542'. Circulate a sweep. POOH rack back drill string. RU HES wireline crew with PJSM. Attempt to run caliper log twice, with line failures. Change out s ool on truck, test, make u tools and RIH. 00:00 07:00 7.00 4,495 8,551 COMPZ WELLPF PULD P Continue trip in hole with BHA #1, from 4495' DPM picking up singles from shed. Load pipe shed as needed. Obtain SLM. Observed proper displacement. On bottom @ 8551'. U wt = 133K dwn wt. = 83K 07:00 09:00 2.00 8,551 8,551 COMPZ WELLPF CIRC P Reverse circulate hole clean w/ 30 bbls 3#/bbl Flo Visc Plus sweep. No solids in returns, small trace of sand/scale. Pumped @ 5 BPM w/900 si. 09:00 14:00 5.00 8,551 0 COMPZ WELLPF TRIP P Blow down top drive. Up wt 133K dwn wt 83K. POOH standing back 3 1/2" drill i e. Page 4 of 25 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:00 16:00 2.00 0 0 COMPZ EVALWE ELOG P Clean rig floor. Set 7" shooting nipple and closed bag. PJSM w/ HES E-line crew. RU E--ine packoff, and PDS to in tools. 16:00 16:30 0.50 0 0 COMPZ EVALWE ELOG P RIH with PDS caliper for 7" casin . Ran in just below surface and had tool failure. 16:30 17:00 0.50 0 0 COMPZ EVALWE ELOG T POOH with caliper tools. 17:00 20:00 3.00 0 0 COMPZ EVALWE ELOG T Troubleshoot, and re-head line. 20:00 21:30 1.50 0 0 COMPZ EVALWE ELOG T RIH to 5000'. Observed short in line. 21:30 22:00 0.50 0 0 COMPZ EVALWE ELOG T POOH with caliper tools, same roblem. 22:00 23:30 1.50 0 0 COMPZ EVALWE ELOG T Change out spool on unit. 23:30 00:00 0.50 0 0 COMPZ EVALWE ELOG T RIH with caliper logging tools. 3/05/2010 Continue RIH with caliper logging assembly. Log out of hole at 50 ft /min. Lay down tools. RU GYRO assembly. RIH complete GYRO run. Change out wireline spools, and rehead. MU CBL Fast Cast logging assembly. Trouble shoot communication issue when line powered up. Change out bad tools. RIH with Fast Cast assembl with Midni ht de th at 1400' WLM. Observed hole -static. 00:00 00:30 0.50 0 0 COMPZ EVALWE ELOG T Continue RIH with caliper logging tools back to 5000' WLM. 00:30 05:30 5.00 0 0 COMPZ EVALWE ELOG P Continue RIH with caliper logging tools to 8550' WLM. Log out of hole to surface @ 50 ft/minute. Lay down tools. 05:30 14:30 9.00 0 0 COMPZ EVALWE ELOG P Make up GYRO assemb_y, and RIH. Stop at 900', questionable data coming back on vertical section (less than 15°). Trouble shooting for diagnosis. No problems (human error). Continue in hole, run Gyro from 8550' to surface. 14:30 18:30 4.00 0 0 COMPZ EVALWE ELOG P Break down Gyro tools. Re-head 3/8"- 7 conductor line. 18:30 23:00 4.50 0 0 COMPZ EVALWE QEVL T Make up CBL Fast Cast assembly. Trouble shoot issues of communication with tools when assembly powered up. Change out bad tools. Retest. All ood. 23:00 00:00 1.00 0 0 COMPZ EVALWE QEVL P RIH with Fast Cast assembly. Midnight depth = 1400' WLM. Observed hole -static. Bled off OA- minimal ressure 20 PSI. 3/06/2010 Continue wireline logging with CBL Fast Cast assembly from 1400' - 4700'. Observed failure in caliper readings. POOH. Trouble shoot assembly. MU and run new FAST CAST tool. Log 4700' to surface. MU strin shot. RIH and shoot at 1938'. PU Retreivable bride lu . 00:00 02:30 2.50 0 0 COMPZ EVALWE QEVL P Continue logging with CBL Fast Cast assembly from 1400' WLM - to 4700'. Obtained artial to . 02:30 05:30 3.00 0 0 COMPZ EVALWE QEVL T WLOH with tools to surface. Trouble shoot assembly. Found another short in the 3/8" -7 conductor cable. Re air and Retest. Pages of 25 Time`Lo s Date From To Dur S. De th E. De th Phase 'Code Subcode T Comment 05:30 07:00 1.50 0 0 COMPZ EVALWE QEVL T WLIH with new CBL Fast-Cast assembl to 4200". 07:00 15:00 8.00 0 0 COMPZ EVALWE QEVL P Logged w/Hi-Resolution from 4200 to 4700'. Ran to bottom 8550'. Logged Hi-Resolution zone from 8550' to 5600'. Kept logging w/standard resolution from 5600' to surface. Bad readings from the Fast-Cast caliper tools from 3600' to surface. Determined TOC @ 2050 w/gradual cutoff streamers to 1982'. 15:00 17:00 2.00 0 0 COMPZ EVALWE QEVL T MU new Fast-Cast tools and RIH to 4700'. 17:00 19:00 2.00 0 0 COMPZ EVALWE QEVL T Log back up from 4700' to surface in standard resolution. 19:00 20:30 1.50 0 0 COMPZ EVALWE QEVL P Breakout & Lay down Tools. Change out wires ools. 20:30 21:00 0.50 0 0 COMPZ WELLPF ELOG P Make up 240 Grain String Shot. 21:00 21:30 0.50 0 0 COMPZ WELLPF ELOG P RIH with string shot assembly. 21:30 22:00 0.50 0 0 COMPZ WELLPF ELOG P Tie in and locate collar. Fire string 22:00 22:30 0.50 0 0 COMPZ WELLPF ELOG P POOH from 1938'. Breakout & lay down assembl RD HES. 22:30 23:00 0.50 0 0 COMPZ WELLPF SVRG P Inspect & Service top drive. Pull RBP to ri floor. 23:00 23:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make & run Retievable Bride lu . 23:15 00:00 0.75 0 22 COMPZ WELLPF PULD P Make up Baker G Lock set bridge plug assembly and setting tools on drill i e. 3/07/2010 TIH with Baker G Lockset Bridge plug & set @ 2615' DPM. Pressure test casing & plug to 2500 PSI - 10 MIN. Dump 8 - 601b sacks of sand and flush to bottom. Tag sand at 2600'. POOH, lay down setting tool. Confirm OA bled off. Nipple down BOP stack. Nipple down tubing head. Observed 7" casing "grow" 18". Pull 7" packoff. Engage 7" with spear and pull tension to 124K on weight indicator, with casing movement of 9 1/2". Beat emergency slips back into place. Obtain Hot Work permit. Tack weld slips in place to 7" casing. Hold PJSM. Ni le u BOP stack. 00:00 02:00 2.00 22 2,615 COMPZ WELLPF TRIP P TIH with Baker G Lockset Bridge lu to 2615' DPM. 02:00 02:30 0.50 2,615 2,615 COMPZ WELLPF TRIP P Locate & work string to set BP @ 2615' DPM. UP WT = 66K, SO WT = 62K. 02:30 03:00 0.50 2,615 2,615 COMPZ WELLPF PRTS P Rig up lines. Fill drill string. Pressure test plug and casing to 2500 PSI - 10 minutes. Record on chart. Gaod test. Release pressure. Rig down lines. 03:00 05:00 2.00 2,615 2,615 COMPZ WELLPF OTHR P Break drill pipe connection. Slowly dump 8 - 60 LB sacks of S&G sand down drill pipe to cover approx - 30 ft. above BP. Allow sand to fall. 2,615 2,615 COMPZ WELLPF OTHR P POOH 1 stands. Wait 30 minutes for sand to fall. Retag sand top @ 2600', 19' of sand over RBP. - Page 6 of 25 Time Lo s `Date From To Dur S. De th' E De th Phase Code Subcode T "Comment 05:00 07:30 2.50 2,615 0 COMPZ WELLPF TRIP P POOH racking back 27 stands Ins ect & break down retrievin tool. 07:30 15:30 8.00 0 0 COMPZ WELLPF NUND P ND BOP. Install tong all-thread bolts on tubing head x casing head flange. ND bolts on tubing head, with weight down, backed off long bolts raduall as 7" casin rew 18". 15:30 17:00 1.50 0 0 COMPZ WELLPF NUND P Set BOP stack back on stump out of the way. Remove tubing head and set out. 17:00 19:00 2.00 0 0 COMPZ WELLPF FISH P Pick up 7" casing spear with packoff. RIH engage 7" casing. Back out lockdown screws. Attempt to pull packoff with pull on casing - no go. Make up bolts and puller on packoff and pull same. Pull 7" casing into tension with 124K observed on weight indicator and 9 1/2" of pipe movement. Hammer down emergency slips into place to hold tension. Release spear, POOH.. Lay down same. 19:00 21:00 2.00 0 0 COMPZ WELLPF OTHR P Held PJSM with crew. Discuss saftey & hazard recognition issues. Perform gas check in cellar for tacking slips to casing. Observed 100 PPM LEL. Load OA with 4 BBLS of 9.6 Brine. Recheck LEL levels to o PPM. All clear -safe. Issue Hot Work permit. Utilize rig welder to weld tack the emergency sli s to 7" casin . 21:00 21:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with crew. Discuss saftey & hazard recognition issues. Discuss procedure to nipple up BOP stack with s ool. 21:15 00:00 2.75 0 0 COMPZ WELLPF NUND P NU spool to casing head. NU BOP stack. 3/08/2010 Continue NU BOP Stack, choke & kill lines. Perform 1500 PSI Body test. Witness of test waived by AOGCC Rep -Chuck Sheve. RU shooting nipple &HES Slickline crew. MU PDS Memory Caliper log assembly. RIH. Log from 2602 WLM. RD HES Slickline crew & tools. MU BOT 5 3/4" Cutter assembly. RIH to locate collars, and cut 7" casing at 1909' DPM with pumps at 3 BPM - 350 PSI. Observed 350 PSI drop in pressure with good indication of cut, and fluid U tube to OA. Observed gas, shut in and circulate through choke full volume. Monitor well -static. POOH lay down cutter assembly. Rig up HES E-line crew with GYRO assembly. WLIH with tools to log from 2600' to surface. RD HES E-line. MU 7" Spear &packoff assembly. RIH engage casing fish. Pull 4'. Be in circulate 160 De ,seawater down 7" to clean u OA 4 BPM - 325 PSI. 00:00 03:30 3.50 0 0 COMPZ WELLPF NUND P Continue Nipple up BOP stack, choke & kill lines. NU flow ni le. 03:30 04:00 0.50 0 0 COMPZ WELLPF BOPE P Load hole with 9.6 Brine. Perform 1500 PSI body test on BOP's, 7" x 9 5/8" OA. Good test. No leaks. 04:00 07:30 3.50 0 0 COMPZ EVALWE SLKL P Rig up HES Slicline crew with sheave. Make up PDS Claiper memo to in assembl . 07:30 08:30 1.00 0 2,600 COMPZ EVALWE SLKL P RIH and logged from 2600' WLM to surface. Observed tight spot with log 275'. Ri down PDS. Page 7 of 25 `Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:30 09:00 0.50 COMPZ EVALWE SLKL P Break down PDS tools and download info. 09:00 09:30 0.50 COMPZ WELLPF SLKL P Rig down Hallliburton Slickline. Pull shootin ni le. 09:30 11:30 2.00 0 1,929 COMP2 WELLPF TRIP P MU 5 1/2" inside cutter for 7" casing w/stabilizer and 6 - 43/4" drillcollars on 3 1/2" drill i e, RIH 11:30 12:30 1.00 1,929 1,909 COMPZ WELLPF CUTP P Up wt. 60K Dwn wt 60. Correlate w/logs and locate casing collars at 1843' ,1886', & 1929' DPM. Picked up 20', cut casing @ 1909' DPM. Pump pressure dropped off when cut from 600 si to 240 si. 12:30 13:30 1.00 1,909 1,919 COMPZ WELCTI CIRC P Circulated gas out @ 36PM250 si.takin returns to Kill Tank. 13:30 15:00 1.50 1,909 0 COMPZ WELLPF TRIP P POOH with inside cutter standing back drill i e, la in down cutter. 15:00 15:15 0.25 0 0 COMPZ EVALWE SFTY P Held PJSM with crew & HES wireline crew. Discuss safety & hazard recognition issues Discuss procedure to rig up nad run Gyro Assembl . 15:15 18:00 2.75 0 0 COMPZ EVALWE ELOG T RU HES wireline crew, and GYRO assembly. Observed tool failure. Troubleshoot and re air. MU Tools. 18:00 22:30 4.50 0 0 COMPZ EVALWE ELOG P RIH, log from 2600 ft to srface. Rig down HES wireliners. 22:30 22:45 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with crew & BOT fishing rep. Discuss safety & hazard recognition issues Discuss procedure to make up 7" spear assembly. Discuss new crew -first ni ht back. 22:45 23:15 0.50 0 0 COMPZ WELLPF FISH P Make up 7" Spear assembly with packoff. RIH to tag & engage fish. Pull to verify catch. UP WT = 85K. Pull 4'. 23:15 00:00 0.75 0 0 COMPZ WELLPF CIRC P Circulate 160 deg, 8.5 seawater down 7" casing staging pump rate from 2 - 4 BBLS /Min.- 325 PSI initially and when full circulation achieved pump pressure came down 200 PSI. Taking returns to open top tank. Observed no as. 3/09/2010 Continue Circulate down 7" casing taking returns through OA to clean up OA @ 4 BPM - 325 PSI. Pump a total of 200 BBLS. Shut down. Monitor well -static. Pull casing stub to surface. Observed emergency slips ~/i knocked off from tack weld and slid down to bowl. Stop pulling. Discuss forward ops. With casing in place, 7~ nipple down BOP's to retrieve emergency slips. NU BOP. Body test to 1500 psi. POOH laying down casing. Be in Weekl BOPE test. 00:00 01:00 1.00 0 0 COMPZ WELLPF CIRC P Continue Circulate 160 deg, 8.5 seawater down 7" casing staging pump rate from 2 - 4 BBLS / Min.- 325 PSI initially and when full circulation achieved pump pressure came down 200 PSI. Taking returns to open top tank. Observed no gas. Blow down lines. Page 8 of 25 'Time. Lo s Date From To Dur S: De th E. De th Phase Code Subcode T Comment 01:00 01:15 0.25 0 0 COMPZ WELLPF OWFF P Monitor well -static. Drain BOP Stack. 01:15 02:00 0.75 0 0 COMPZ WELLPF FISH P Pull 7" casin to floor with s ear. Observed that the tack welded emergency slips and fallen off and slid down the 7" casing to the bowl. Sto ullin . 02:00 03:00 1.00 0 0 COMPZ WELLPF FISH P Discuss plan forward with FMC reps. Decision to nipple down BOP's. Set rotary slips. Release spear and lay down full joint of 3 1/2" DP. Install 6' pup, and re-engage 7" casing with spear and packoff assembly. Pull rotat sli s. UP WT = 85K. 03:00 03:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with Crew & BOT reps. Discuss safety & hazard recogniiton issues. Discuss procedure to nipple down BOP's and recover emergency sli s. Monitor well -static. 03:15 08:15 5.00 0 0 COMPZ WELLPF NUND P Nipple down BOP stack, riser, choke & kill lines. Lift stack. Fish out 4 slip segments and two slip bodies. All arts accounted for. 08:15 11:00 2.75 0 COMPZ WELLPF NUND P U BOP stack riser, choke & kill lines. Pressure test break to 1500 si visual) check for leaks. Good. 11:00 13:30 2.50 COMPZ WELLPF PULL P PJSM w/casing crew. RU casing tongs & elevators. Start pulling & LD 7" casing. Starting up wt = 75K Dwn wt. = 65K. Jt. #6-8-20 corkscrewed. With 12 jts out up wt = 70K dwn wt = 57K. 13:30 15:00 1.50 COMPZ WELLPF CIRC P With 20 jts out (860') shut down to unload from pipe shed. Well out of balance, hole fill 1/2 bbl off. RU head pin, MU top drive and circulated 50 bbls 2 BPM @ 60 psi around to clean up and balance. SD and 0 ress. No flow. 15:00 15:30 0.50 COMPZ WELLPF PULL P Pulled 10 more jts. 57 up wt 45 dwn wt. jts 27,28,29 & 30 corkscrewed. Hole fill still not ri ht 2 bbls short. 15:30 16:00 0.50 COMPZ WELLPF CIRC P RU head pin again, screw in top drive and circualte hot SW @ 4 BPM @ 50 psi. Break out top drive. Blow down same. Well static. Page 9 of 25 Time Lo s Date `From To Dur S. De th E. De th Phase Code 8ubc~e T Comment 16:00 17:00 1.00 COMPZ WELLPF PULL P Continue to POOH jt 32 & 35 cork screwed. At jt 33, started getting vibration while pulling but no extra wt or drag. Up wt 45K. On jt # 37 we had 10K over pull and dropped off immediately to35K and pull smoother w/ no vibration. Out of hole w/43 jts of 7" 26# casing and one 23.79' piece from cut,and 19 centralizers. Break out torque on 7" became less and less as we came out of hole, 1st jt was very tight, last connection was not ti ht at all. 17:00 19:30 2.50 COMPZ WELLPF CIRC P .RIH with 3 stands of 3 1/2" Drill Pipe from the Derrick to 291-ft. Circulate Arctic Pack from top of hole. Clean u BOP Stack. 19:30 21:00 1.50 COMPZ WELLPF PULL P Stand back 3 Stands of 3 1/2" Drill Pipe in Derrick. Blow down Top Drive. Break out and lay down 7" Casing Spear. Clear and clean Floor. 21:00 23:00 2.00 COMPZ WELLPF OTHR P Set Test Plug. Install 2 ea 3 1!8" Valves on Drillin S ool. 23:00 00:00 1.00 COMPZ WELLPF BOPE P Begin Weekly BOPE test per ConocoPhillips/AOGCC re uirements at 250/3,000 si. 3/10/2010 Complete weekly BOPE test. Pull Test Plug. RIH with 8 112" Shoe/Casing Scraper. Unable to pass by _ casing problem at 260-ft. POOH. RIH with 8" casing scraper and went past 260-ft with no problems. T~_._.._~_._-_-_____ _.__ Continue down to 1,900-ft. Circulate out remaining Arctic Pack and swap wellbore over to 9.6 Ib/gal Brine. RU HES E-Line Unit and run Cali er and G ro Lo s. 00:00 07:30 7.50 COMPZ WELLPF BOPE P Continue with weekly BOPE test at 250/3,000 psi. Had two valve failures on choke Manifold. Re-build same and re-test. Perform Koomey draw down test. Pull Test Plug. The State's right to witness test was waived b C. Scheve. 07:30 10:00 2.50 0 252 COMPZ FISH PULD P Mobilize Baker tools to rig floor. PJSM. MU BHA # (shoe & casing scra er . 10:00 10:30 0.50 252 260 COMPZ FISH TRIP P RIH with 8.5" & casing scraper, stacked out @~60' solid. Worked 2-3 times but could not o ast 260'. 10:30 11:30 1.00 260 0 COMPZ FISH TRIP P Pulled BHA back out of hole. Removed 8.5" shoe and WP. 11:30 14:00 2.50 0 1,900 COMPZ FISH TRIP P Run back in hole w/9 5/8" wo/washpipe and shoe. Dropped past spot @ 260' without notice. Staged in hole pumping every 600' to clean up Artic Pac. Stopped with scra er 1900', 9' off of 7" stub. F'age 10 of 25 Time. Lo s Date Fram To Dur S. De th E. De th Phase Code Subcode T Comment 14:00 16:00 2.00 1,900 1,900 COMPZ FISH CIRC P Circulate hole volume with Seawater to clean up Artic Pac. Switched to 9.6 ppg brine and changed hole over. Still getting Arctic Pac back. Switch from open top tank back over shackers. Pumped 35 bbls 9.6 still ettin Arctic Pac back. 16:00 18:00 2.00 1,900 0 COMPZ FISH TRIP P Blow down TD. POOH standing back DP & DC. 18:00 19:00 1.00 0 0 COMPZ FISH PULD P Lay down Tools. Clear and clean Rig Floor. 19:00 19:30 0.50 0 0 COMPZ EVALWE SFTY P PJSM with E-Line Crew, Rig Crew, Tool Pusher, and Co Man. Discussed E-Line rig up and securing area while running tools in and out of hole. 19:30 19:45 0.25 0 0 COMPZ EVALWE ELOG P Rig up E-Line. Make up Tools for Caliper log run as follows: GR, CCL, TTTC-U,NKL, Press, Cent, 2.125" Cali er, Cent. 19:45 21:45 2.00 0 1,885 COMPZ EVALWE ELOG P Zero Tools at Rig Floor. RIH to 1,885-ft. Open Caliper Tool. Log back to surface at 50 ft/min. Caliper survev confirms „eag-shaped" spot in _. th /8" Casin at -260-ft. 21:45 00:00 2.25 1,885 0 COMPZ EVALWE ELOG P Pick-up Gyro Tool. Allow Gyro Tool to warm-u .Start RIH with same. 3/11 /2010 Complete Gyro Log. RIH with Back-Off Tool and back off 7" casing connection at 1,929-ft. RIH with Spear and complete back-off and retrieve backed off piece. Make up 8 3/8" Drift Run BHA and attempt to pass by damaged casing at 255-ft. No success. Made a second attempt with a 8 3/16".Drift. Still unsuccessful. Wait on an 8 1/4" Strin Mill. 00:00 02:30 2.50 0 1,885 COMPZ EVALWE ELOG P Continue RIH with Gyro, taking survey while RIH to 1,885-ft. Log back to surface. Gyro once again confirms problem at the 260-ft area in the 9 5/8" Casing (255' _ .84 Begs, 263' = 3.05 degs, 271' _ .60 degs). Lay down logging tool string. Rig down a-Line Unit. Clear floor. 02:30 03:00 0.50 0 0 COMPZ FISH SFTY P PJSM to Make up Baker Back-off Assembl .Read floor. 03:00 05:00 2.00 0 0 COMPZ FISH PULD P Make-up Back-Off BHA as follows: 5" Bull Nose, 5 ea 4 3/4" Drill Collars, Ported Sub, Blanking Sub, Lower Anchor Section, Back-Off Tool Power Section, Upper Anchor Section, Pump-Out Sub, 3 ea 4 3/4" Drill Collars. 05:00 09:00 4.00 0 1,909 COMPZ FISH TRIP P Trip in with BHA and 3 1/2" Drill Pipe from Derrick filling with water from to eve stand. Page 11 of 25= Time Lo s Date From To Dur S. De th E'>be th Phase Code` Subcode T Comment 09:00 10:30 1.50 1,909 1,909 COMPZ FISH CUTP P Up wt = 65K Dwn wt = 63K.With upper anchors On Back-off tool @1918' and the lower anchors @ 1943'. Pressured up to 800 psi and set lower slips. Set down 5K, pressured up to 3100 psi to set upper slips. Bled of pressure. Pressured to 1600 psi for initial break and made 1/2 turn. Bled pressure wait for tool to ratchet. Pressure to 760 psi and made another 1/2 turn. Continued these steps until total of 4 1/2 turns with back-off tool. Last two attempts gained no turns, tool not ratchetin . 10:30 12:00 1.50 1,909 0 COMPZ FISH CIRC P Broke out DP pups. MU single and screw in top drive. Drop ball & rod for pump out sub. Screwed in single. Pressured up to 2050 psi to shear Pump out sub. Closed annular and reverse circulated fresh water out of drill pipe until good 9.6 ppg all around and balanced. Monitor well, static. 12:00 15:00 3.00 0 0 COMPZ FISH TRIP P Break out top drive. Blow down. POOH standing back drill pipe and laying down back-off tools. LD two 4 3/4" drill collars. 15:00 16:00 1.00 0 1,909 COMPZ FISH TRIP P MU 7" Spear and packoff assy. and RIH on 3 1/2" drillpipe. Up wt 55K dwn 60K. Engaged fish at 1909', pulled 4K overpull. Backed off 11 rounds to the left. PU and ulled free. 16:00 17:30 1.50 1,909 0 COMPZ FISH TRIP P POOH standing back drillpipe, laying down spear and fish. Twenty ft. stub came out with pin end, leaving 7" 17:30 19:30 2.00 0 0 COMPZ FISH PULD P Lay down Back-Off BHA and all other excess Baker Tools. Clear and clean floor. 19:30 21:00 1.50 0 255 COMPZ FISH TRIP P Make up Drift Run BHA as follows: 8 3/8" Triple Connect Screw-In-Sub, Pup Joint, Pup Joint, XO, Float Sub. RIH with 3 1/2" Drill Pipe. Tagged solid at 255-ft. No over pull. Tried several times. Stacked out 15K Top Drive wei ht. No further ro ress. 21:00 21:30 0.50 255 0 COMPZ FISH TRIP P Trip out with Drift Run BHA. Inspect Triple Connect Sub. Observed a 4" flare on the lip of the tool. Flare indicates that the drift quite likely is setting down on a ledge in the damaged 9 5/8" Casing section. Lay down BHA. Page 12 of 25 Time Lo s Date From =To Dur S. De fh E. De th Phase ''Code Subcode T Comment ' 21:30 22:30 1.00 0 258 COMPZ FISH TRIP P Make up a second drift run attempt. Leave out the Triple Connect Sub. Installed a 8 3/16" Centralizer between two 7" Pup Joints. RIH and tagged at 258-ft. Once again tried several times. No further progress. TOOH. Discuss plan forward with Anchora a En ineer. 22:30 00:00 1.50 258 0 COMPZ FISH MILL T Plan forward is to run an 8 1/4" String Mill. Wait on Mill from Baker Fishin Tools. 3/12/2010 RIH w/8 1!4" String Mill to open up tight section from 251' - 268'. Continue down to 1,920-ft with no further tight spots. Rana 8 3/16 Gauge to drift tight section. However stopped at 272-ft. No further progress. Ran an 8 3/8" string mill to continue to open up tight section from 255-ft - 277-ft. Ran the same 8 3/16" Gauge to drift again. Gauge when through tight section however had to stack 5 - 8K to get through. RIH w/8 1/4" x 8 3/8" Tandem String Mill BHA. Reamed from 255-ft - 290-ft. RIH w/8 3/16" gauge to drift tight section. Saw one bobble at 267-ft. Call-out service com an to run 7" Casin . 00:00 04:00 4.00 0 0 COMPZ FISH MILL T Continue to wait on Baker Machine Sho to build an 8 1/4" Strin Mill. 04:00 05:00 1.00 0 256 COMPZ FISH MILL T Bring String Mill BHA to Rig Floor. Make up BHA. RIH and tag tight spot 251'. 05:00 09:00 4.00 256 280 COMPZ FISH MILL T Up wt 45K Dwn wt 45K ROT wt 45K. Pumping @ 4 BPM w/60 psi. Start milling 251', down to 257' cleaned up w/1000 ft/Ibs torque. Run down start milling again 265' thru 269' was tight 2-3K torque. Reamed back thru three times, 266' to 268' still tight w/2K torque. Ran back thru tight spots without rotating to 275', took 5K dwn wt to et thru. 09:00 10:30 1.50 280 1,920 COMPZ FISH MILL T Shut down pumps blow down TD. RIH free to 1920'. 10:30 11:30 1.00 1,920 0 COMPZ FISH TRIP T POOH. Slowed down thru tight spot 269' thru 251' free. 11:30 12:00 0.50 0 0 COMPZ FISH PULD T Break out and LD 8 1/4" mill BHA. 12:00 13:30 1.50 0 272 COMPZ FISH TRIP T MU BHA for gauge run largest OD 8 1/4". Stopped @ 272'. Worked but could not et thru. 13:30 15:00 1.50 0 0 COMPZ FISH PULD T POOH break out BHA. MU BHA w/8 3/8" strip mill. 15:00 18:30 3.50 0 266 COMPZ FISH MILL T RIH to 256'. Begin milling through tight section in the 9 5/8" Casing down to 266' with 3 - 5K torque. Continue to work Mill up and down through tight section several more time. Final pass from 255' - 277' torque was 1 - 2K. Make one pass from 255' - 277' with no rotation. Mill takes 3 - 5K down weight to pass throu h. 18:30 19:00 0.50 266 0 COMPZ FISH TRIP T POOH with 8 3/8" String Mill BHA and la down same. Page 13 of 25- Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T .Comment 19:00 21:00 2.00 0 271 COMPZ FISH TRIP T Pick up 8 3/16" Centralizer between two 7" Pup Joints BHA for gauge run. RIH. Set down at 258-ft. Took 3 - 5K to enter top of tight section and 5 - 8K to drop out the bottom at 266-ft. POOH. Discuss plan forward with Anchorage Engineer. Lay down BHA. 21:00 22:00 1.00 0 0 COMPZ FISH TRIP T Make up Tandem String Mill BHA as follows: 4 1/2" Bull Nose, XO, 8 1/4" String MITI, 4 1/2" x 10-ft Pup Joint, 8 3/8" String MIII, 6 1/4" Bumper sub, XO, 6 ea 4 3/4" Drill Collars. 22:00 00:00 2.00 0 290 COMPZ FISH MILL T RIH. Parameters as follows: Up weight = 45K, Down weight = 45K. RPMs = 60, Pump = 4.0 bpm/60 psi, Torque 1 K. Tagged at 255-ft. 8 1/4" Mill entered tight section with 2 - 3K torque and 3 - 5K down weight. 8 3/8" Mill entered tight section with 3 - 4Ktorque and 5 - 8K down weight. 8 3/8" Mill stalled out at 267-ft. Pulled 20K over to free. Reamed back down. 8 3/8" Mill stalled again at 267-ft. Pulled 10K over to free. Small amount of fine mill dust recovered on Ditch Magnets. No cement or formation fines seen on Shaker. 3/13/2010 Continue reaming tight section in the 9 5/8" Casing. Made drift run through tight section with very little effort. Make up Shoe Track and start RIH w/7" Casing. ES Cementer set down at 262-ft. POOH. RIH w/8 1/2" string mill. Ream once again through tight section. Continue down to the next possible tight spot at 322-ft. Ream through and continue down to 1,918-ft with no problems. Circulate bottoms up. Mix and circulated Wellbore with MI Safe Lube. POOH. 00:00 01:00 1.00 255 290 COMPZ FISH MILL T Continue to ream tight section from 255-ft - 266-ft with the Tandem String Mill BHA: The 8 1/4" Mill goes through the tight section w/2 - 3K torque and normal string weight. The 8 3/8" Mill goes through the tight section w/3 - 4 torque and 3 - 5K down weight. After several more passes, parameters remain the same. 01:00 02:00 1.00 290 0 COMPZ FISH TRIP T POOH. Lay down Tandem String Mill BHA. 02:00 03:00 1.00 0 300 COMPZ FISH TRIP T Pick up 8 3/16" Gauge run BHA. RIH and drift through tight section. Saw one 2 - 4K down weight bobble at 267-ft. Continue down to 300-ft. POOH. La down BHA. 03:00 06:00 3.00 0 0 COMPZ WELLPF PUTB T Call out Halliburton ES-Cementer Serviceman. RU Casing Crew. MU 7"x5' casing pup jt , 7" x 10' pup jt and HES cementer w/six shear ins Page 44 of 25 Time Lo s Date From To Dur S. De th E. De th Phase' Code ` Subcode T Comment 06:00 09:00 3.00 0 262 COMPZ WELLPF PUTB T PJSM. T xo jt BTC x TCII and new 7" TCII casing w/ one centrilizer per jt. RIH slowly and started taking wt Cad 252' (5K dwn wt) stopped solid 262'. 09:00 10:00 1.00 0 0 COMPZ WELLPF PULD T POOH laying down 7" casing and HES cementer. Threads on bottom u ~t dama ed. 10:00 12:00 2.00 0 0 COMPZ FISH PULD T MU 8 1/2" mill assembly. 12:00 14:30 2.50 0 265 COMPZ FISH MILL T Tagged tight spot @ 260'. Parameters = 45K up wt, 45K dwn wt, 45K ROT. Milled thru tight spot in 9 5/8" casing with 8 1/2" mill from 260' thru 270'. Milled hard from 263' thru 265' w/3K for ue. 14:30 19:30 5.00 0 1,918 COMPZ FISH MILL T Blow down Top Drive. Continue in hole and tagged again @ 322'. Milling thru with same parameters. Continue down to next possible tight section at 1,666-ft. However, saw nothing and passed through this area with no problems. Continue to 1,918-ft. Up weight = 66K. Down wei ht = 65K. 19:30 20:45 1.25 1,918 1,918 COMPZ FISH CIRC T Circulate bottoms up at 9.0 bpm/660 psi. Observe occasional metal shaving across Shaker. Recovered some more Arctic Pack. Mix up MI Safe Lube and circulate wellbore at 5.0 b m/270 si. 20:45 00:00 3.25 1,918 0 COMPZ FISH TRIP T Trip out with 8 1/2" BHA. Back-ream through the 322-ft area with no problems. Back reamed at 266-ft. However, when attempting to slide back through with no rotation, Mill stack out with 8K. Re-ream this area twice. Now can pull back through and slide back down with 2 - 3Kdrag. Finish POOH and lay down BHA. 3/14/2010 Made drift run to 1 918-ft with ES Cementer Drift BHA. Attempt to drift with 8 3/8" Triple Connection Sub. However it stacked out at 270-ft. Resume milling and re-work both tight sections at 255-ft - 270-ft and 315-ft - 328-ft with a 8 1/2" x 8 3/8" tandem string mill BHA. Drift tight sections with the 8 3/8" Triple Connection Sub and the 8 1/4" ES Cementer Drift BHA. Successful) ass throu h both sections. Continue RIH. 00:00 01:30 1.50 0 0 COMPZ FISH PULD T Make up Drift Run BHA as follows: 7" x 5' Pup Jt, 7" x 10' Pup Jt, ES Cementer, 7" XO Jt, XO, XO, Bumper Sub, XO, 2 std 4 3/4" Drill Collars. Page 15 of 25 Time,Lo s `:Date From To Dur S. De th E. De th Phase' Code Subcode T Comment 01:30 05:00 3:50 0 1,918 COMPZ FISH TRIP T RIH with Drift BHA. Started taking weight at 255-ft. down to 267-ft. Took 5 - 8K to get through tight section. Continue down to 323-ft. Took 3K to get through. Continue down to 1,918-ft with no problems. POOH. (Note: time frame includes gaining one hour for Daylight Savings Time . 05:00 06:00 1.00 0 265 COMPZ FISH PULD T MU Drift BHA consisting of 8 3/8" Tripple Connect too1,10'x7" pup jt, 8 1/4" HES cementer, 1-xoverjt TCII x BTC, bumper sub, 6- 4 3/4" DC, xover to 3 1/2" Drill Pi e. 06:00 08:00 2.00 265 270 COMPZ FISH PULD T RIH and started taking wt.@ 255' down to 270' stacked out. Attempt to rotate thru but could not get thru. POOH la in down drift BHA. 08:00 10:00 2.00 0 215 COMPZ FISH PULD T MU new BHA consisting of tandom mills. 8 1/2" above 8 3/8". 10:00 16:00 6.00 215 285 COMPZ FISH MILL T RIH and tagged up at 260'. Obtained parameters of up wt 45K dwn wt 45K ROT 45K Pump @ 4 BPM w/60 psi. Mill on section between 260' and 284'. Reamed thru this section with max torque @ 4K ft/Ibs. Small amount of cement returns, less than one cu . 16:00 21:00 5.00 285 340 COMPZ FISH MILL T Continue down hole and tagged tight spot @ 316'. Continue milling from 315-ft - 328-ft. 5 - 6K torque. Torque smoothed out at 2 - 3K torque. However, now have observed fluid loss. 21:00 22:00 1.00 255 275 COMPZ FISH MILL T Pull up hole to the upper tight section from 255-ft - 270-ft. Ream through one time. Then tried to slide through with no rotation. However, 8 1/2" Mill stacked out at 267-ft. Continue to re-ream section. (fluid loss = 20 bph). Now able to work throu h with little roblem. 22:00 23:00 1.00 275 0 COMPZ FISH TRIP T POOH with Tandem Mill BHA. Lay down same. 23:00 00:00 1.00 0 328 COMPZ FISH TRIP T Make-up Triple Connection (modified) Drift Run BHA as follows: 8 3/8" x 3-ft Triple Connection Sub, 7" Pup Jt, 7" Pup Jt, ES Cementer, XO Jt, XO, XO, XO, 6 1/4" Bumper Sub, XO, 2 Stands 4 3/4" Drill Collars. RIH to tight section at 255-ft - 270-ft. Passed through with only a few slight bobbles. Continue down to next thight section at 315-ft - 328-ft. Passed through with no problems. Continue RIH. ' Page 16 of 25 Time Lo s Date From To Dur S. De th E. De th Phase .Code Subcode T 'Comment 3/15/2010 za hr summary Continue Triple Connection Sub and ES Cementer drift to 1,918-ft with no problems. RU S-Line and record Caliper and Gamma Ray logs. Make up Triple Connect Sub assembly, 7" Pup Jt, Halco ES Cementer, XO Jt. Run 7" 26 ft/Ib L-80 TCII Casing per program. Screw into 7" Casing at 1,929-ft. Pull test connection and pressure test casing. Install Cement Head. Verify Closing Plug is installed. Rig up Cementers. PJSM with all. PT line. Circulate Well. Mlx and pump cement. Displace cement. No cement returns to surface., Bum lu Veri lu is holdin . 00:00 01:00 1.00 328 1,918 COMPZ FISH TRIP T Continue to RIH with the 8 3/8" Triple Connection Sub and the 8 1/4" ES Cementer Drift Run BHA down to 1,918-ft with no roblems. 01:00 02:00 1.00 1,918 1,918 COMPZ FISH CIRC T Circulate bottoms up at 3.0 bpm/70 psi. Returns observed contained some mill fillings, very small amount of cement, and some Arctic Pack. Lost -50 bbls Burin circulatin . 02:00 04:00 2.00 1,918 0 COMPZ FISH TRIP T POOH to just below 328-ft. Eased back through tight sections with no problems. Drop back down through both tight sections once again with only a few small "bobbles. Finish POOH. (Call out S-line and PDS for Cali er Lo La down BHA. 04:00 06:00 2.00 0 COMPZ EVALWE RURD T Wait on S-Line Unit to arrrive on location and begin to rig up. (Maintain Rig. service Top Drive. Prep equipment to pick-up 7" Casin 06:00 12:00 6.00 COMPZ EVALWE SLKL T PJSM w/HES Slickline Crew ,PDS Logging Eng. and Baker Fishing Rep. RU Slickline equipment and Caliper logging tools. RIH and run Caliper log from 1918' to surface. After getting Gamma Ray tools from Deadhorse. MU and ran Gamma log from 1918' to surface. RD HES slickline. 12:00 14:00 2.00 0 62 COMPZ WELLPF RNCS P PU & MU Tripple Connection Screw-in sub, 3'x7" pup, 10'x7" pup, HES cementer (all Bakerlok below cementer Xover 't to TCII. 14:00 16:00 2.00 62 1,723 COMPZ WELLPF RNCS P RIH with 7",26# L-80 TC-II casing past tight spots between 250' and 350' without any trouble. Stopped @ 471', rotate pipe w/2k free torque. Continue in hole with casin . 16:00 16:30 0.50 1,723 1,723 COMPZ WELLPF RNCS T With 40 jts in hole, bearing went out on low gear shaft on casing tongs. Swithched out tongs with backup set. 16:30 17:00 0.50 1,723 1,929 COMPZ WELLPF RNCS P Continue in hole with 7" casing. Up wt 80K Dwn wt 75K. Tag top of pin looking up @ 1929'. PU 1', MU xover to To Drive. Page 1T of 25 Time Lo s Date From To Dur S. De tli E. De th Phase Code Subcode T Comment 17:00 18:00 1.00 1,929 1,929 COMPZ WELLPF CIRC P Established circulation with 9.6 ppg brine, 4 BPM @ 80 psi. Pump 35 bbls Hi Visc sweep, chased sweep with 130 bbls hot seawater at 4.0 b m/50 si. 18:00 19:00 1.00 1,929 1,929 COMPZ WELLPF PRTS P Pick up weight 76K. Ease down and screw into 7" Casing collar at 1,929-ft. with no problems. Pull test at 25K over. Good. Slack back down. Pull test to 50K over for a final pull test to 126K. Good. Pressure test Casing at 1,500 psi. Bring pressure up to a final test of 2,470 psi. Good test. Blow down Top Drive. 19:00 21:00 2.00 1,929 1,918 COMPZ WELLPF RURD P Rig down Casing Crew. Install Cement Head. Install Closing Plug. Spot and rig up Cement Equipment. Sta a Vac Trucks. 21:00 21:30 0.50 1,929 1,929 COMPZ CEMEN' SFTY P Safety and operations meetings with Rig Crew, Schlumberger, Halliburton, Vac Truck Drivers, Tool Pusher, and Rig Rep. Discussed high pressure, spill prevention, weather, communications. Review scope of job, cementing procedures, and ressure limits. Page 18 of 25 Time Lo s_ Date From To' Dur S. De ttr E. De th Phase Code Subcode T `Comment 21:30 00:00 2.50 1,929 1,929 COMPZ CEMEN' CMNT P Final equipment check and walk through. Prime up with hot (90 deg F.) Sea Water. Pressure test cement line at 4,000 psi. Good. Open ES Cementer at 3,520 psi. Establish circulation at 5.3 bpm/325 psi. 80 total bbls pumped. End circulation. Mix ARCTICSET I Cement w/ D110 Retarder and start downhole at 1.3 bpm/46 psi/15.4 ppg. Increase rate to 4.9 bpm. At 25 bbls pumped/5.0 bpm/470 psi/15.8 ppg. At 40 bbls pumped 5.0 bpm/510 psi/15.8 ppg. At 75 bbls pumped 4.9 bbls/500 psi/ 15.7 ppg. End Cement with 75 bbls pumped. Start Sea Water displacement. Plug is launched. Rate 5.5 bpm/200 psi. Catch up to cement column with 35 bbls into displacement. Rate 5.0 bpm/545 psi. At 60 bbls pumped 5.0 bpm/1020 psi. No cement returns to surface (calculated annu vol = 57 bbls). Reduce rate, open sample valve and check for returns at wellhead. No returns. 70 bbls pumped 1.0 bpm/620 psi. No returns. 72 bbls pumped 1.0 bpm/632 psi. No returns. Start looking for plug to bump. No returns. Bumped Plug with 76.0 bbls pumped/2495 psi. (calculated volume to bump plug was 74.1 bbls). Plug down at 23:46 hrs. Hold closing pressure. Release pressure slowly. Verify plug holding, no returns. Total cement = 75 bbls (57 bbls annu vol + 18 bbls excess). Total Sea Water displacement to bump plug = 76 bbls. No cement returns to surface. 3/16/2010 Rig down cement equipment. Wait on cement. Discuss possible top job to the 9 5/8" x 7" annulus. Attempt to perform injection test. Pressure test at 2,000 psi. Run 1" CS Hydril Tbg and tagged hard cement or centralizer at 35' below surface. Pump Methanol to freeze protect. Cut 7" Casing w/WACHs Cutter. ND BOP Stack. 00:00 08:00 8.00 1,929 1,929 COMPZ CEMEN" CMNT P Rig down Cement Equipment. Wait on cement. Prep to nipple down BOP Stack. Begin to load Pipe Shed with Completion Tubing. Drift and tally same. Other miscellaneous Rig projects. Notify Anchorage Engineer that there was no cement returns to surface. Plan forward endin . Page 19 of 25 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:00 12:00 4.00 COMPZ CEMEN" CMNT T Flange BOP bolts back up. Receive Plan Forward from Anchorage. RU to circulate 7" x 9 5/8" OA. Pump 27 strokes @ .0473 bbl /stroke = 1 bbl to pressure up to 2,000 psig. - Bled off ressure. Noti Town En r. .12:00 16:00 4.00 COMPZ WELLPF OTHR T Call out 1"TBG, continue to load, rack and tally 3 1/2" completion string while waiting on offsite equipment. Load 1"TBG and strap and tally. PU and RIH to 64' from rig floor (35' below surface) and tagged hard. Could be cement or a centralizer 16:00 16:30 0.50 COMPZ WELLPF SFTY P Held PJSM with Little Red Services and rig crew on RU and Pumping of methanol. 16:30 18:00 1.50 COMPZ WELLPF FRZP P RU LRS and Pump 2 bbls of Methanol @ 1 bpm and displace sea water from 35' from surface until si ns at surface. RD LRS. 18:00 22:30 4.50 COMPZ WELLPF NUND P Break BOP Stack apart and lift.. Set 9 5/8" Emergency Slips. Install WACHs casingcutter and cut the 7" , Casing. Lay down the 33.17-ft 7" cut-off stub. 22:30 00:00 1.50 COMPZ WELCTL NUND P Set BOP Stack down on Wellhead. Ni le down BOP Stack. 3/17/2010 Install 9-5/8"x7" Pack-off. Nipple up Tubing Spool. Test pack-off, Install 2 7/8" x 5" VB Pipe Rams in BOP. Perform weekl BOPE test. Pull Test Plu .Install Wear Bushin . 00:00 02:00 2.00 COMPZ WELCTL NUND P Finish nipple down BOPE. 02:00 08:30 6.50 COMPZ WELLPF NUND P Install 9 5/8"x7" Pack-off. Nipple up 11" 3K x 7 1/16" x 5K Tubin Head. 08:30 09:00 0.50 COMPZ WELLPF PRTS P Test pack off to 3,000 psi for 15 minutes - ood test. 09:00 14:00 5.00 COMPZ WELCTL OTHR P NU riser and wash stack to clean and inspect cavities. Install 2 7/8" x 5" VB Pipe Rams in preparation for test BOPE. 14:00 18:00 4.00 COMPZ WELCTL BOPE P Fill Stack and shell test -door seal failed, drain stack and replace door seal. Fill stack and shell test - graylock failed, replace same. Test kill line -gray lock failure -replace same. Wait for AOGCC Inspector to arrive to witness BOPE test. 18:00 22:30 4.50 COMPZ WELCTL BOPE P Test Alarms. Perform weekly BOPS test per conocoPhillips/AOGCC requirements at 250/3,500 psi. Good tests. Perform Koomey draw down test. Good test. All tests was witnessed by AOGCC Field Ins ector - J. Cris . 22:30 23:00 0.50 COMPZ WELCTL BOPE P Rig down test equipment. Pull Test Plu .Install Wear Bushin . Page 20 of 25 Time Lo s Date From To Dur S. De th E. De th `Phase -Code Subcode T Comment ':' 23:00 23:30 0.50 COMPZ WELLPF SFTY P PJSM Picking up BHA. Discussed Overhead loads and line of fire. Hand lacement and communications. 23:30 00:00 0.50 COMPZ WELLPF PULD P Make up 6 1/8" Bit BHA as follows: 6 1/8" Bit, Boot Basket, Boot Basket, Bit Sub, String Magnet, Bumper Sub, Pump-Out Sub, 9 ea 4 3/4" Orill Collars. 3/18/2010 Slip and cut Drilling Line. RIH with 6 1/8" Cone Bit. Drill out cement stringers and the ES Cementer at 1,912-ft. Tagged top of sand at 2,600-ft. Test Casing at 2,500 psi x 30 minutes. Good. RIH with Globe Basket BHA and clean debris off of sand to . 00:00 00:30 0.50 0 314 COMPZ WELLPF PULD P Complete making up 6 1/8" BHA. 00:30 01:00 0.50 314 314 COMPZ WELLPF SFTY P Held PJSM with crew on Slip and cut of drill line and inspection of draw works 01:00 02:30 1.50 314 314 COMPZ WELLPF SLPC P Slip and cut Drilling Line. (84-ft). Ins ect Drawworks. 02:30 03:30 1.00 314 1,823 COMPZ WELLPF TRIP P Trip in hole with 6 1/8" Cone Bit. Tagged Cement stringer at 1,823-ft. Up weight = 67K. Down weight = 60K. 03:30 06:00 2.50 1,823 1,912 COMPZ WELLPF DRLG P RPMs = 60. Pump rate = 6.0 bpm/480 psi. Drill through cement stringers here and there from 1,823-ft down to ES Cementer at 1,912-ft. 06:00 08:00 2.00 1,912 1,953 COMPZ WELLPF DRLG P Control drill on Wiper plug and ES Cementer f/ 1,912' to 1,914' fell thru and chase stringers to 1,953' w/ 5 to 7k WOB 70 r m's. 08:00 08:30 0.50 1,953 1,953 COMPZ WELLPF CIRC P CBU @ 8 bpm and saw rubber @ shakers, 08:30 09:30 1.00 1,953 2,056 COMPZ WELLPF DRLG P Drill out stringers from 1,953' to 2,056' and fell thru -Blow down Top drive. 09:30 10:00 0.50 2,056 2,570 COMPZ WELLPF TRIP P RIH f/ 2,056' to 2,600' and tag upon sand plug POOH to 2,570' and RU Circ lines. 10:00 11:00 1.00 2,570 2,570 COMPZ WELLPF CIRC P Circ hole clean taking Arctic Pack returns too en to kill tank. 11:00 12:00 1.00 2,570 2,570 COMPZ WELLPF PRTS P Pressure test 7" 26# csg to 2,500 si for 30 minutes and chart. 12:00 13:00 1.00 2,570 2,570 COMPZ WELLPF DRLG P Laydown working jt and MU TD, RIH f/ 2,570' to 2,600'. Dry dri-I on junk and sand @ 70 rpms w/ 3 to 4k WOB to 2,603'. PU and CBU 13:00 14:30 1.50 2,570 314 COMPZ WELLPF TRIP P Blow down top drive, and Trip out of the hole 14:30 15:30 1.00 314 0 COMPZ WELLPF PULD P POOH laying down BHA #19 -clean Boot baskets -recovered cmt particles, milled csg, brass shear ins 15:30 16:00 0.50 0 0 COMPZ WELLPF SFTY P Held PJSM, PU and MU BHA #20 Globe Basket run 16:00 16:30 0.50 0 306 COMPZ WELLPF PULD P PU and MU BHA #20 and RIH to 306' Page 21 of 25 Time Lo s -' Date .From To Dur S. De th E. De th Phase -Code - Subcode T Comment 16:30 21:00 4.50 306 2,608 COMPZ WELLPF TRIP P Trip in hole w/ BHA #20 f/ 306' to 2,603-ft. Tag top of sand. PU 10 feet and establish parameters as follows: Up weight = 70K. Down weight = 65K. Pump rate = 10.0 bpm/480 psi. Reverse circulate into top of sand down to 2,608-ft to pick up any debris into the Globe Basket. Shut down um Tri out. 21:00 00:00 3.00 0 2,611 COMPZ WELLPF TRIP P Pull BHA out of hole. Dump Globe Basket. Recovered 6 chunks of aluminum ring from the Wiper Plug. Re-load Globe Basket and RIH to 2,608-ft. Up weight =72K. Down weight = 65K. Pump Rate = 10.0 bpm/1,000 psi. Reverse down to 2,611-ft. 3/19/2010 RIH with Baker Retrieving Tool. Release and pull Baker Retrievable Bridge Plug from 2,615-ft. Run in with 5 3/4" Cut-Lip Guide/V1/ashpipe BHA and washover the Camco OEJ at 8,575-ft. Circulate bottoms up. Single out la in down 81 'ts of 3 1/2" Drill Pi e. Stand remainin 3 1/2" Drill Pi a in Derrick. La down BHA. 00:00 03:30 3.50 2,611 0 COMPZ WELLPF TRIP P Continue to reverse circulate from 2,611-ft - 2,621-ft, top of Retrievable Bridge Plug body. Shut down Pump. Trip out of hole. No debris recovery. La down Globe Basket BHA. 03:30 05:30 2.00 0 2,605 COMPZ WELLPF TRIP P Make up Baker Retrieving Tool. Trip in with same to 2,605' 05:30 06:30 1.00 2,605 2,605 COMPZ WELLPF CIRC P Displace SW with 9.6 ppg brine circulatin at 4 b m 260 si. 06:30 10:00 3.50 2,605 2,631 COMPZ WELLPF MPSP P Workover fishing neck and attempt to latch up with no luck. Circulate @ 10 bpm @ 900 psi and wash off top of RBP. Attempt to latch up with no success. Reverse Circulate @ 8 bpm @ 800 psi. Attempt to latch up -was able! Release plug, Let elements relax and POOH for 50' locating csg collar -RIH and was able to go past original setting depth of 2,621' to 2,631'. 10:00 10:30 0.50 2,631 2,631 COMPZ WELLPF OTHR P Blow down Top Drive and Bring next BHA to ri floor. 10:30 13:30 3.00 2,631 0 COMPZ WELLPF TRIP P POOH w/ RBP slowly,_seeing signs of CSG collars till inside TC-II csg. BOLDS on wear ring @ 60' and continue to POOH engaging wear ring and pulling to rig floor. Recovered RBP, Gauge rings were bent. Unable to release from plug at surface. 13:30 14:00 0.50 0 0 COMPZ WELLPF OTHR P Set wear ring 14:00 15:00 1.00 0 307 COMPZ WELLPF PULD P PU and MU BHA # 21 5 3/5" Cut lip uide w/ CSG scra er to 307'. Page;22 of 25 Time Lo 's `Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:00 19:00 4.00 307 8,592 COMPZ WELLPF TRIP P Continue trip in with 3 1/2" Drill Pipe and BHA to 8,570-ft. Make up Top Drive. Up weight = 132k. Down weight =90k. Tagged top of OEJ Slick Stick at 8,577-ft md. Bring pump on line at 8.0 bpm/1,720 psi. Washed over down to 8,592-ft and bottomed out on HRP-1-SP Packer. Worked on/off OEJ three times with no roblems. 19:00 20:00 1.00 8,592 8,590 COMPZ WELLPF CIRC P Parked Cut-Lip Guide at 8,590-ft (2-ft off of Packer body). Circulated bottoms up until clean at 8.0 b m/1,825 si. 20:00 22:30 2.50 8,590 5,714 COMPZ WELLPF PULD P Blow down Top Drive. Single down 81 joints of 3 1/2" Drill Pipe in Plpe shed. 22:30 00:00 1.50 5,714 3,600 COMPZ WELLPF TRIP P Drop a 2.130" Drift w/100-ft of wire to drift remaining 3 1!2" Drill Pipe to be used to run Completion (Min ID in BHA, Casing Scraper = 1.375"). Continue trip out standing back 3 1/2" Drill Pi a in Derrick. 3/20/2010 TOOH and lay down 5 3/4"Cut-Lip BHA. Begin running 3 1/2" completion as designed. Spot Corrosion Inhibited Sea Water. Set Baker FHL Packers. Test Tubing. Test Casing. POOH and lay down Setting Tool. Start runnin the to section of the 3 1/2" Com letion as desi ned. 00:00 03:00 3.00 3,600 0 COMPZ WELLPF TRIP P Finish trip out from 3,600-ft with 3 1/2" Drill Pipe, standing back in Derrick. Lay down Drill Collars. Recover Drift. Lay down BHA. Clear and clean floor. 03:00 03:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discussed picking up Completion. Line of fire, overhead toads, hand lacement. 03:30 10:30 7.00 0 2,874 COMPZ RPCOM PULD P Rig up floorto handle Completion. Pick-up Completion Jewelry as follows: OEJ. Camco 2.813" DS Nipple w/RHC Plug in place, Lower Baker FHL Packer. Single in with 87 Jts of 3 1/2" 9.3 Ib/ft L-80 AB Mod Tubing. PU and MU Upper Baker FHL Packer, SBE and Setting Sleeve w/ Baker C-2 Running Tool. 55k u wt, 55k do wt. 10:30 15:00 4.50 2,874 8,590 COMPZ RPCOM TRIP P RIH w/ Lower 3 1/2 Completion on 3 1/2 DP from 2,874' to 8,592' located Slick stick @ 8,575' and seen pressure increase. bleed off pressure, Nogo'd @ 8,590'. PU to 8,573' and Rig up to spot CI Sea Water. 15:00 17:30 2.50 8,573 8,573 COMPZ RPCOM CIRC P Reverse circulating 50 bbls Sea Water @ 3 bpm @ 400 psi ICP, followed by 110 bbls of CI Sea water, followed by 150 bbls of Sea water to spot CI fluid around packers. FCP = 330 si . Page 23 of 25 Time Lo s Date From To Dur S: De th E> De th Phase -Code Subcode T Comment 17:30 19:30 2.00 8,573 8,587 COMPZ RPCOM PACK P Drop Packer setting Ball/Rod. Blow down Top Drive. Wait for 30 minutes for ball to go on seat (Crew change). Bring Pump on line and pressure up to 3,100 psi to shear and set both Packers. Test Tubing x 5 minutes. Good. Release Setting Tool. Pressure test Casing x 10 minutes at 2,500 psi. Good. Record both tests on chart. 19:30 23:00 3.50 8,587 0 COMPZ RPCOM TRIP P Trip out with 3 1/2" Drill Pipe, standing back in Derrick (59 stands, jt 1 - 177 in tally order). Break out and lay down Setting Tool. Recovered com lete. 23:00 23:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discussed running order and safe handling of the remaining 3 1/2" Com letion. 23:30 00:00 0.50 0 100 COMPZ RPCOM RCST P Begin running the top section of the 3 1/2" Com letion as desi ned. 3/21 /2010 Complete running 3 1/2" Completion. Space out. Circulate Inhibited Sea Water. Land Hanger. Pressure test both the Tubing and Casing. Nipple Down BOP Stack. Nipple up Production Tree. Test Tree at 5,000 si. Freeze rotect well. Install BPV. Release Ri at 2030. 00:00 06:30 6.50 100 5,745 COMPZ RPCOM RCST P Continue picking up the top section of the 3 1/2" Completion as designed and RIH to 5,745' - 7' in on jt 266. Nogo'd out @ 5,726' w/ locator and mule shoe @ 5,745'. 70k up wt, 65k do wt 06:30 08:00 1.50 5,745 5,715 COMPZ RPCOM HOSO P Mark pipe @ PU 7' for space out.. POOH and lay down jts 266 and 265. MU hanger on landing jt and RU to circulate CI Sea water. 08:00 09:00 1.00 5,715 5,715 COMPZ RPCOM CIRC P Pump 150 bbls CI Sea water (CRW 132 1% by Volume) and follow with 20 bbl sea water @ 5 bpm @ 300 si . 09:00 09:30 0.50 5,715 5,738 COMPZ RPCOM THGR P Drain stack, RIH, seen mule shoe locate setting sleeve. Land hanger and RILDS. 09:30 11:30 2.00 5,738 5,738 COMPZ RPCOM PRTS P RU to PT TBG and IA. PT TBG @ 2,500 psig for 15 minutes, bleed back to 1,500 psig and Pressure up on IA to 2,500 psig for 30 minutes. Bleed IA to 0 psig and TBG to 0 psig. Pressure up on IA to 1,500 psig and Shear out SOV. RD test e ui ment. 11:30 12:00 0.50 5,738 5,738 COMPZ RPCOM MPSP P Back out Landing jt. Set BPV. 12:00 12:30 0.50 5,738 5,738 COMPZ RPCOM SFTY P PJSM with rig crew on ND BOPE and NU Tree 12:30 15:30 3.00 5,738 5,738 COMPZ RPCOM NUND P ND ROPE and NU Tree. Orientation was witnessed b J. Kuzma DSO. 15:30 16:00 0.50 5,738 5,738 COMPZ RPCOM SEQP P Set test plug, Test Adapter and Tree @ 5,000 psig for 10 minutes each. - ood tests. Pull test lu . `Page 24 of 25 .:;Time Lo s Date From To Dur S. De th E. De th Phase . Code Subc~de T Comment 16:00 16:30 0.50 5,738 5,738 COMPZ RPCOM SFTY P Held PJSM with Little Red Services and Rig crew on RU and Freeze rotect of well. 16:30 17:30 1.00 5,738 5,738 COMPZ RPCOM FRZP P RU and PT lines to 2,500 psig. Pump 110 bbls of diesel @ 2 bpm @ 850 ICP 1,500 psig FCP SI w/ 300 si RD LRS. 17:30 20:30 3.00 5,738 5,738 COMPZ RPCOM OTHR P Allow well to U-tube IA x TBG. Set BPV. Secure Production Tree and Cellar. Prep to move-off Well. Release Rig at 20:30 hrs. 03-21-2010. Page 25 of 25` Schwartz, Guy L (DOA) Page 1 of 3 From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Tuesday, March 16, 2010 5:05 PM To: Schwartz, Guy L (DOA} Subject: RE: 2A-16 (PTD~ 185147) Sundry 310-006 7"x9-5/8" Top Job Guy, We tagged up at 35' below the wellhead. This is approximately 30' down on the first full joint of casing. We put centralizers on each joint that the 1" pipe will not pass, so we could be hitting a centralizer or cement. They pulled the pipe out after the first tag to make sure there was not cement in the bottom of the pipe. Nothing was there. There is 33' to a bbl in the 7"x9-5/8" annulus. It is feasible we tagged the cement top since the numbers match up fairly we(I. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 OfFce 907-240-5515 Cell Howard. Gober@conocoph fillips. com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, March 16, 2010 1:16 PM To: Gober, Howard Subject: RE: 2A-16 (PTD 185-147) Sundry 310-006 7"x9-5/8" Top Job Howard, Just let me know if you tag up or not. Thanks. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Tuesday, March 16, 2010 12:18 PM To: Schwartz, Guy L (DOA) Subject: RE: 2A-16 (PTD 185-147) Sundry 310-006 7"x9-5/8" Top Job Guy, Update.......We attempted to pump into the leak. After about 1-1/2 bbi of 9.6 ppg brine, we pressured up. We went up to 2000 psi and it was holding. It appears cement was near surface -maybe 1 bbl down. We are going to run a 1" pipe in as deep as we can get and pump methanol into the annulus. Looks like we probably got ~19 4/29!2010 Page 2 of 3 bbls of cement away into the leak. With this new information, I do not think a temp log or bond log would be of any value. After pumping the menthanol we are going to proceed with the program: ND BOP and lift. Land casing on slips with 50M# tension. Rough cut and set back BOP stack. Make final cut with Wachs cutter. Fill any void below packoff with diesel. Install casing packoff. NU tubing head. Test Packoff. NU and test BOP. Please call with any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, March 16, 2010 11:24 AM To: Gober, Howard Subject: RE: 2A-16 (PTD 185-147) Sundry 310-006 7"x9-5/8" Top Job Howard, This summarizes what we discussed this morning adequately. It would be interesting to see what is really behind the surface casing up in the dogleg area.... I would assume a very large void filled with lots of melted ice water and mud. I wonder where this fluid is getting displaced to by the cement? (out / up /down???) Not sure if that would be data worth trying to get ... like a temperature log after you finish this top job. Just a thought. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Tuesday, March 16, 2010 10:32 AM To: Schwartz, Guy L (DOA) Subject: 2A-16 (PTD 185-147) Sundry 310-006 7"x9-5/8" Top Job Guy, Just wanted to document our conversation this morning regarding 2A-16. During the milling operations in the 9- 5/8"' casing, we milled a hole in the casing. We were loosing approximately 20 bbl/hr while circulating. Yesterday we successfully ran the 7" casing and screwed back into the casing stub. A pressure test of 2460 psi was obtained on the 7" casing after we screwed in. We opened the Halliburton ES cementer and cemented the 7" inside the 9-5/8" casing with 75 bbls ArcticSet1 cement (24% excess). Unfortunately we did not get any returns to the surface. While waiting on orders, the crew began to ND the BOP stack. We are nippling back up the stack. Since we have casing leaks now, the stack is no more than a diverter stack, and we cannot pressure test it, therefore, we will not pressure test. 4/29/2010 Page 3 of 3 Our plan is to: • NU BOP stack • Have Schlumberger deliver a full bulk truck of ArcticSet1 cement in case a 2nd job is needed • Establish injection rate down 7"x9-5/8" annulus with 9.6 ppg brine at 0.5 and 1 bpm. Pump 10 bbis fluid after catching up with fluid level. • Ensure mix water is 60-70 deg F if possible. Cooler mix water will make the cement blend thicker • Mix and pump 25 bbis cement as follows: • 5 bbis AS1 neat at 1 bpm max • 10 bbis AS1 with 2 lb/bbl CemNet at 1 bpm max. CemNet is fibrous and will help the cement to bridge off. • 10 bbis AS1 with 2 Ib/bbl CemNet at 0.5 bpm max. Trying not to push the cement, but just keep up with it falling • Do not displace the cement past the Wellhead valve. Close in wellhead valve and clean up lines. • If necessary due to the cement falling all the way to the 9-5/8" casing hole, we wilt do a second job. • Clean out OA valves with diesel • WOC until 500psi compressive strength. • ND BOP and lift. Land casing on slips with 50M# tension. Rough cut and set back BOP stack. Make final cut with Wachs cutter. Fill any void below packoff with diesel. Install casing packoff. ise confirm that this note adequately documents our conversation. Please call with any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, tnc. 907-263-4220 Office 907-240-5515 Cell Howard. Gober@conocoplyl G ps. co m 4/29/2010 Re: 2A-16 (PTD 185-147 Sundry 310-006) Completion- Enterprise Vault Archived Item Page 1 of 2 From Gober, Howard Date Thursday, March 11, 2010 3:24:44 PM To Schwartz, Guy L (DOA) Cc Subject Re: 2A-16 (PTD 185-147 Sundry 310-006) Completion Guy, 5650' MD is an approximate depth, but the packer will be in that vicinity.. Howard Gober Wells Engineer ConocoPhillips Alaska Inc 907-263-4220 office 907-240-5515 cell From: Schwartz, Guy L (DOA) <guy.schwart:z@alaska.gov> To: Gober, Woward Sent: Thu Mar 11 15:17:03 2010 Subject: RE: 2A-16 (PTD 185-247 Sundry 310-006) Completion Howard, Your proposal is acceptable in order to isolate potential casing leaks in the 7~€I i. The proposed straddle section will be from 5650a€TM and to 8592~€TM and (existing top packer). Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Thursday, March 11, 2010 2:53 PM To: Schwartz, Guy L (DOA) Subject: 2A-16 (PTD 185-147 Sundry 310-006) Completion Guy, I just wanted to document our discussion on the completion of 2A-16. Our original plan was to stack a packer above the existing top packer and run gas lift tubing to the surface. Caliper logging during the workover has revealed some pitting up to 5785' RKB. Our plan will be as follows: ~t• Set bottom packer as planned ~t• Run straddle packer with 3-1/2" tubing below. Stab into bottom PBR and set straddle packer at 5650' RKB (above pitting damage). ~t• Run 3-1/2" gas lift completion above the packer at 5650'. This completion will isolate the pitted casing from production fluids. We will ensure corrosion inhibited brine is pumped into the annular space of the straddle. Please let me know if you have any questions or if you need more information. I would appreciate a note back with you concurrence that this adequately documents our conversation. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc, https://ancev02.soa.alaska.gov/EnterpriseV ault/ViewMessage.asp?VaultId=17A3EF6017F... 4/29/2010 Re: 2A-16 (PTD 185-147 Sundry 310-006) Completion- Enterprise Vault Archived Item Page 2 of 2 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com https://ancev02.soa.alaska.gov/EnterpriseVault/V iewMessage.asp?VaultId=17A3EF6017F... 4/29/2010 • • f~L~ ~£ 9~~ PROACTIVE DAAGNNOSTIC SERVICES INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C '~. ~ ~j~ Anchorage, AK 99518 Fax: (907) 245-8952 1 ] Depth Determinatiom 2] 15-Mar-10 2A-16 v ~~~`1 Signed Print Name: ~4i~/99 EDE 50-103-20042-00 ,. ~ ~' Date . i Yt~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (807245-88952 E-mall : ~adser-ehorsae(a~rroemorvEog.com WEBSITE : wnnr~v.rnemorvlog.com C:\Documents and Settings\Diane Williams\Desktop\Transmit Conoco.docx I/~/ELL LQG TI~.~N~MITTAL ,,. PrtoAcri-~ DirgNOSric Services, Iwc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hole/Open Ho{e/Mechanical Logs and/or Tubing lnspection(Caliper/ MTn The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 2) 10-Mar-10 2A 16 1 Report / EDE 50-103-20042-00 l `~ ~~ ~ 3 Signed Print Name: ~_~ .~ '= MAR 2 3 201D Date r~,r'; ~. ~rt+ PROACTWE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraae(a~memorvlog.com WEBSITE : www.memorvloa.com C:~Documen~ end Seltings~Diette Williame~DesktoplTrenemit Corroco.docx • Memory Multi-Finger Caliper .Log Results Summary Company: ConocoPhitlips Alaska, inc. Well: 2A-16 Log Date: March 10, 2010 Field: Kuparuk Log No.: 7391 State: Alaska Run No.: 4 API No.: 50-103-20042-00 Pipet Desc.: 9.625" 36 Ib. J-55 Top Log Intv11.: Surface Pipet Use: Surface Casing Bot. Log Intvl1.: 1,880 Ft. (MD) Inspection Type : Buckling 8 Restriction lnspection COMMENTS This caliper data is correlated to a cement bond log dated March 5, 2010, This log was run to assess the condition of the 9.625" surtace casing. The caliper recordings indicate bends in the surface casing at -258' to -270' and -314' to 324', with a minimum I.D. of 7.67" at 267'. A log plot of the caliper recordings across the logged interval is included in this report. Ring-like deposits are recorded throughout the log interval, restricting the I.D. to 7.28" in joint 41 (1,667'). Although the caliper fingers were restricted to 7.28",adrift of a larger diameter may not be impaired by these deposits due to the differences in force of a drift run and a caliper arm during normal logging speeds. This is the fourth time a PDS caliper has been run in this well and the first time the 9.625" surface casing has been togged. Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: R. Overstreet ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: {281) or (8$8) 565-9085 Fax: {281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ' • • PDS Multifinger Caliper 3D Log Plot ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-16 Date : March 10, 2010 ' Description : Detail of Caliper Recordings Across Bends in Surface Casing and Rings of Deposits • deformation """~"~"`"'" Joint 10 400 +~ ,. i _ _ l Joint 11 450 - i --- t- ~ . E .,~ _.__, __ _ A ~~~~ 1 ~ I , ~, - -- . ,~ ---, L ._ _ ~ Joint 12 500 • ~ .~. _~ ,~~ - - ""'.' - .o. - ~ _ .~.. ~ - .~ ~~ --- oint 13 i. ,._ _ _ i ~' ` ~ _._ k ..: 550 _ ~ Joint 14 Joint l5 600 _ __ t ~ ; _ Joint 16 650 _ --- Joint 17 i 700 -r - Joint 18 - ~~ t9t 750 _ Joint 19 Joint 20 800 ` ~ i I . Slight oval deformation ! ~ ~ I ~ ` ~ - . _.+.:. - - _-- Joint 21 Slight oval deformation 850 . . -- -~ ~ - ' +-- I -._ . ~. ~. -- - --- -- • Joint 22 - - ? j 900 I ~ -~ Joint 23 Slight oval deformation 50 -f-- - _ ' Joint 24 .. Slight oval ~ ! ~_ deformation __ _ 1000 ' Joint 25 :,~ Slight oval deformation ~ I !; i_ i ~ E x 1050 W a Joint 2s Slight oval ` r x: deformation j - ~ Joint 27 Slight oval deformation 100 - _i-. ~ ~ ~ ? j_ _ , - ~ ~ ._~ a ~; - ___~ _ _ ! ~; Joint 28 1150 - ~ ;~, ~ ~ ~ Joint 29 1 _. . _ - -~"" 200 Joint 30 ~ ,T - ~ t - ~ ,,, ,. ~~ Joint 31 1250 ~ + ~" m---- - _, . ~-~- ~.~ .._ __- .~. _., -- -- Joint 32 1300 ~ L ~ - ~ _ - --_.. Joint 33 1350 I _. ~ .~_ • Joint 34 1400 Joint 35 1450 Joint 36 1500 Joint 37 Joint 3s 1550 Joint 39 Deposits 1600 Joint 40 Deposits 1650 Joint 41 Min. LD. = 7.28" --- 1700 Joint 42 Joint 43 1750 Deposits Joint 44 1800 ~ Joint 45 - Deposita 1850 Joint 46 • ~~~ -- - Minimum Diameter Profile Well: 2A-16 Survey Date: March 10, 2010 Field: Kuparuk Tool: XR UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches CounUy: USA Tubing I.D.: 8.765 inches Minimum Measured Diameters (la) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 7.25 7.75 8.25 8.75 0.1 2 4 6 8 ,o 12 14 16 18 20 22 Z = 24 .s 26 28 30 32 34 36 38 40 42 44 46 r r 1 1 --- -- -._ • PDS Report Overview ti._ ~,. Body Region Analysis Well: 2A-16 Survey Date: March 10, 2010 Field: Kuparuk Tool Type: XR UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 36 f -55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ----- metal loss body 50 40 30 20 10 0 0 to 1 to 10 to 20 to 40 ro over 1% 10% 20°I° 40% 85% 85% Number of ~oints anal sed total = 47 pene. 1 46 0 0 0 0 loss 34 13 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body ;.~;;~ rnetal loss body 0 50 100 0 10 20 30 40 Bottom of Survey = 46 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2A-16 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.765 in Country: USA Survey Date: March 10, 2010 Joint No. Jt. Depth (Ft.) I'c~n. Ut~sc~t (Ins.) Pen. Body (Ins.) I'c~n. ~~ 'vlc~tal I cuss °4, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 36 11 0.01 3 i_~ 8.73 PUP 1 41 t) 0.0 i 8.69 2 78 a 0.02 4 U 8.68 3 113 t. 0.01 ; ' 8.70 4 151 ~' 0.02 4 U 8.70 5 195 a 0.01 i I 8.6 6 238 t) 0.01 2 I 7.67 Bend. 7 280 t) 0.00 1 I 8.19 Ben . 321 U 0.03 7 1 end. 9 358 U 0.04 9 i) 8.70 Sli ht oval defo m do 10 399 O 0.02 (i ~ 8.63 Lt. De osits. 11 4 9 U 0.02 i _' 8.35 Lt De osits. 12 479 tJ 0.03 6 _' 7.64 De sits. 13 522 U 0.03 (i I 833 t De osits. 14 562 U 0.02 5 U 8.47 Lt De osits. 15 604 U 0 02 6 1 .33 De s'ts. 16 640 U 0.03 7 1 8.67 17 682 U 0.02 6 2 8.67 18 716 t) 0.02 5 I 8.66 19 759 i) 0.02 5 U 8.58 Lt. De osi 0 802 U 0.0 5 _' 8. 0 Sli ht oval defor ation Lt. e osits. 21 837 t) 0.02 (~ I 8.51 Sli ht oval deformation.Lt. De osits. 22 874 t) 0.0. 7 8.64 23 917 t) 0.02 5 I 8.59 Sli ht oval eformati n. Lt. osits. 24 954 O 0.02 '? 8.47 Sli ht ova deformation. Lt. e osits. 25 997 t) 0.03 6 U 8 63 Sli ht oval deforma i 26 1040 U 0.03 6 U 8.66 Sli ht oval eformati n. 27 1083 t1 0.02 5 1 8.63 Sli ht oval deformation. 28 1123 t? 0.02 5 t) 8.29 osi . 29 1166 U 0.03 0 1 8.61 30 1209 U 0. 3 L 8.67 31 1245 tl 0.02 5 t) 8.07 De its. 32 12 5 !) 0.03 ~ t) 8.53 t. sits. 33 1324 a 0.03 ~ 1 7.84 De sits. 34 1366 a 0.02 5 t) 7.89 De sits. 5 1404 t~ 0.04 8 I 8.59 Lt. De osits. 36 1447 t) 0.03 £~ O 8.52 Lt. De osits. 37 148 U 0.03 (> 0 8.31 De sits. 38 5 6 i) 0.03 b t) 8.42 t. De osits. 39 156 t) 0.0 (> I 7.76 De sits. 40 1608 l1 0,0 7 ! 7.56 e sits. 41 1652 U 0.03 (, ? 7.2 De osits. 42 1695 tt 0.02 5 I 8.56 t. e osits. 43 1731 t) 0.02 6 _' 7.83 De sits. 44 1767 l) 0.03 7 u 8.56 45 1808 U .02 `; t) 8.33 De o 46 1846 U 0.02 6 1 7.85 De osits. _ Penetration Body Metal Loss Body Page 1 r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ r rw ~~ ~ PDS Report Cross Sections Well: 2A-16 Survey Date: March 10, 2010 Field: Kuparuk Tool Type: XR UW MFC 40 No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf I-55 Analyst: M. Eawrence Cross Section for Joint 6 at depth 267.317 ft Tool speed = 44 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 100 Tool deviation = 2 ° Finger 1 Radius = 4.18 ins Bend Minimum I.D. = 7.67" HIGH SIDE = UP • Cross Sections page 1 ~ ! ~ ~ ~ ~ ~ i ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ - PDS Report Cross Sections Well: 2A-16 Survey Date: March 10, ZOtO Field: Kuparuk Tool Type: XR UW MFC 40 No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 9.625 ins 36 ppf I-55 Analyst: M. Lawrence Cross Section for Joint 7 at depth 315.55 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 100 Tool deviation = 3 ° -~ Finger 1 Projection = -0.491 ins Bend Minimum I.D. = 8.19" HIGH SIDE = UP Cross Sections page 2 s PDS Report Cross Sections Well: 2A-16 Survey Date: March 10, 2010 Field: Kuparuk Tool Type: XR UW MFC 40 No. 218451 Company: Conoco Phillips Alaska, lnc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: M. Lawrence Cross Section for Joint 41 at depth 1666.77 ft Tool speed = 43 Nominal ID = 8.765 ~' Nominal OD = 9.625 Remaining wall area = 100 °~ Tool deviation = 31 ° Finger 18 Projection =-1.026 ins Ring of Deposits Minimum I.D. = 7.28" HIGH SIDE = UP ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ Cross Sections page 3 ~`~ _ KUP 2A-16 ConoeoPhillips 1 ttrlbutes n le & MD TD all' 1 rt Apl;UWl =0103_004200 Field Name WNI Status MD IttK81 KUPARUK RIVER UNIT PROD EC 'E 7.900.OD AM Btm IhKBi 9.868.0 ' __ ent H2S IPpm) Dnte - - SSSV: LOCKED OCIT 3^_5 1/101009 Annotaton E Last WO: nd Date KB-Grd lft) 34.50 R~q Rtkast Datt 8i26r1965 -AC:_r~ Annotation Dtpth IRKBI Bntl Dale Annotaton Last Mod y End DAtt Last Tay: ;LM 9 606 0 1;26^010 Rev Roeson-Tay. GLV C,'O. Cut 7by. Pull Imosbor 11291^_O1D Casing Strin s Casmq OCStripnon ctnnq O D string ID finl Top lhKBl Set Depth !ftKB~i SE[ Depih 'TYD7 IhKB) Str in{ Wt nb~i.'R] shlnq G~adt String TOp Thrtl cova.~cTOR. I~ CGNDUCTOR i 6 15.OOD 24.0 1D4.0 104.0 62.50 -H-4D r ~ t U AC 5 J 8. 5 0.0 - - - 7.0 28 .i 3 . 0 J- 5 SAFE r v LV. o t Deg t pRODIiCTION 7 6 151 ~ - C 0 9 017 0 5790 1 ^6 DD J-55 LINER S 4 15' ~ 7.'Z C 9 888 n 15 OG 1-5c. oAS Le ~ Tubin Strings - SVRFACE. - ~ ~ Tubmg DesclapROn snir,q o ~nl D so-inq lD 1m1 7eP IhKEI set Depm tt'KBl set rtpm rrvnl IRKBj st. iPq wt Ilbs•m sbinq rmde ~ Strang TOp Thrtl aem TUBING 3 T G 992 C G 0.570.0 5 554 9 9.3G J 55 EUEBrd,ABMOFI oAS uFr 72 t 4 TUBING 2 T 8 2441 8.572.0 8.7D2.D 5.822.3 6.5D J-55 E„E . UBING _ 3i 1 995 702 0 0 6 31 B 3.70 N-80 EUE 8R Other In Hole All Jswsl :Tubin Run & Rstrie vable. Fish ete. Gc" L'~ 53tA o ttKB Top Deput TYDI 1 (~B! Top Incl t'I esori tion _ Comment un Date D Ifni oas L FT. S~Na 1.899 1.785.7 36.80 S AFETY VLV Cemco'TRDP•lA-SSA' LOCKED OUT 1;:212D10 8,'15;1991 2.813 2815 2.386.3 54.19 G AS LIFT CAMCOIKBUGl1!DMY!BK/!10omment STA 1 11221=010 2922 GAj LIFT Y ommaM ~ r4,~ /t~05 ~ - Y omment - 5 794 4.085.8 5 .84 G AS LI CAMCO(KBU /1/DMY(BKlll Comment: xt kg STA 4 12Y'2!~009 2922 Gas LIFT. eet2 6 ^05 4 314 4 56 44 Ci AS LIFT CAMCOjKBUG/IiDMY;BKJf(Commeni STA 5 5;2(1999 ^_ 5, ~' . 1_ 4. 5.1 .66 G LI CA / U I1rD Yi KIi( ommenr.. A 6 Sp i1 1 _.52. oas LIFT. _ _ ~ Y DmmenT . . _ __ - I - 2525 5.022.1 50-55 G AS LIFT CAMCO.rKBUGJi(DMY173KgIComment..STA 6 8:15(1991 292^_' FT aAS L 8.023 5.275.0 59.70 G AS LIFT CAMCO/KBUGII(DMYIBK(IlComment: STA 9 51211999 2522 - . 5. _ 5 .09 AS LI CA ;M -^_(1. PEN K,~II omment ~ A 10 1 1=0 2.3 1 8.557 5537.° 59.02T BGCUT PRE-SIDETRACKCUTTUBING 112712070 3.994 Gas L Pt s c,~ 8.560 5. 8 8 59.01 T P BG UNCHES TUBI PUNCHES 4 spf. 5. t'x2D" 117f2D7o 2 000 ` F 8.575 5.556.5 58.97 S BR Cemco'OEJ' 8115;1991 2:97 ''4s ` ' q ..2y 5._ tanco H - Sri 1I1 1 I _ 5 3 58.87 C CH P - 1 T A K CA H 1 7 G- 1 _5J~ 1 67 Tao cuT. A.551 8.631 5.585.5 58.86 P ODUC ION CAMCO(KBMG-1J11DMY(BKJjf Comment . TA 11 5l27i2003 2.347 8.6 8 5.604-6 58. 4 N I PLE AVA B L ORTED NIPPLE 811 511 99 1 ^_.250 76G ~ PVhCHES 8.668 .604. 8. 4 EVE-O 2 AVA PC. set 51 6 /012 fi 1.6 5 . s eye - 8.690 5.616.0 58.66 F ISH IECES UPP R WRP ELEMENT 211 011 99 5 .ODO ~ 9.373 6.0164 47.94 P ACKER 8eker'DB' 8!15J7991 3250 4.389 6.0227 48.07 N IPPLE Ct3mco'D' Nipple. NO GO SJ15;7991 1.813 SBP 5'i`- - - 7 77 Il 7 . 9.396 6.031.8 48.12 T TL NO TTL ELMD LOG AVAILABLE 8715;1991 7.955 PACKER 9 •.~2 -. -. 9.752 6.272.2 44.28 ISH 1 1,2" OV Empry Pocket Fell otATlhole 2;10;`1995 D.D00 Perfora tions & Slots cATCNER A62e Top (ftKB1 Btm (Ttl(81 Top ITYD7 IttKB) BRn ITVDI tltK81 Zone Date Shot Otro (sh°- T pe Comment 9.284 9.348 5.956.4 5.999 5 C-4. 2A-16 9Nl798 12.0 IPERF 3 318' Csg Gun: 60 deg ph PR°D'°':T'ir Ae_ 9A8. 9.506 6.089.2 6 105 3 A-4.2A-i6 9811905 12.0 IPERF 3 3/$" Csg Gun: 60 day ph PP 9.536 9.55E 6.12Li 6.140.1 A-3.2A-16 9'9;1985 12.0 IPERF 3 3''8" Csy Gun. 6D dey ph NI EE. A,55A -- sLEE~'Ea Notes: General 8 Sei 8 058 End Date Annotation 5/7(1999 NOTE Tby x Annulus comm~ suspect G! M 6?~ 0529' mey ba 9ow rut FsL y cNC. ~ 6/22(^_D05 NOTE VJAIVERED WELL IA x OA ANNULAR COMMUNICATION 5)151°-0 9 N ELL OUN UBING L AK R' 5863 ELMD PRODUCTIa: B.C r- IPERF. F,2E4-N.;4A PACKER. 0.373 NIPPLE B?AN 505.0 3 a. ~ 7rL N~BP IPERF. 448?-8;39 IPERF. 6.53Cr-0.552 FIST 8~5i UNTD.0 BB8 ~`+i~ F--,ober ge 17 of 27 February 11, 2010 • WALL LC?~ TRANSIVI/TTAL la• PIaoA~crive D'IAgnlasrit SERVrc~s, Iwc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A Richey 13D West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 08-Mar•10 2A-16 1 Report/ EDE 50-103-20042-00 2) ~ 5- ~ ~/~ PROACTIVE DIAGNOSTIC SERVES, INC., 13Q W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98518 PHONE: (907)245-8851 FAx: (907)245438952 E-MAIL : pdsanchoraaeCaamemorvloa.com WEBSITE : www.memorvloa.com C:~Doaiments and settings~Diane VIrilliems~Desktop\1Yanamit Co,wco.docx • • Memory Multi-Finger Caliper Log Results Summary ;~. Company: ConocoPhillips Alaska, Inc. Well: ZA•16 Log Date: March 8, 2010 Field: Kuparuk Log No.: 7389 State: Alaska Run No.: 3 API No.: 50-103-20042-00 Pipet Desc.: 7" 26 Ib. J-55 Tap Log Intvl1.: Surface Pipet Use: Production Casing Bot. Log Intvl1.: 2,610 Ft, (MD) ~ inspection Type : Buckling & Restriction lns~ction COMMENTS This caliper data is tied into the surface (~ 43' (Orilier's Depth). This log was run to assess the impact of suspending the 7" casing on areas of previously reported buckling. ' The caliper recordings indicate buckling from -260' to 290' and 330', with a minimum I.D. of 6.26" at 280'. A tog plot comparison of the current and previous caliper recordings highlighting this buckling is included in this report. This is the third time a PDS caliper has been run in this well and the second time the 7" production casing has been logged. Field Engineer. Wm. McCrossan Analyst: C. Waldrop Vlfrtness: C_ Fitz atnck 8 R. Overstreet ProActive Diagnostic Services, Inc. / P.D. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 • • PDS Multifinger Caliper 3D Log Plot ~, S. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-16 Date : March 8, 2010 Description : Comparison of Caliper Recordings Across Buckling Pre and Post Casing Suspension • • • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf )-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Dake: • ILATION SHEET 2 A-16 Kuparuk ConocoPhillips Alaska, Inc. USA March 8, 2010 Joint No. )t. Depth (Ft.) Peen. t 11>s~~t (Ins.) Pen. Body (Ins.) Pen. %~ Metal I oss °i<, Min. LD. (Ins.) Damage Profile Comments (% wall) 0 50 100 1 43 t).U7 0.06 16 7 6. 8 Shallow ar nt Wear. 2 8 t) 0.04 12 6.28 Shallow A arent Wear. _- 3 28 t~ OA5 13 7 6.28 Shallow A arent Wear. 4 171 U 0.04 1 Z 7 6.28 ha low A arent Wear ;K 5 215 t~ 0.05 13 ti 6.28 Shallow A arent Wear. 25 U 0.06 18 ~> 6.2 Shallow A ar nt Wear. Bucklin . 7 302 t) 0.04 t;' 7 6.26 Shallow A arent We r. Bucklin . 8 346 U 0.04 11 7 6.28 Shal A a e t Wear. 9 88 i) 0.05 15 9 9 Shallow A rent Wear. 10 432 li .04 12 7 6.27 Shallow A arent ar. 11 475 U 0.06 17 7 6.28 Shallow A arent Wear. 12 518 U 0.10 ~ 7 ~; 6.2 A arent Wear. 13 562 U.U7 0.10 29 ~~ 6.28 A arent Wear. 14 605 U.1 U 0.13 a5 9 6.27 rent Wear. 15 648 l).UfS 0.10 28 ~) 6.28 A arent Wear. 16 69 lL~)t1 0.09 2Ei f3 6.2 `" A ar ntWear. 17 735 t1.U7 0.10 2(~ (t 6.28 A arent Wear. 18 779 U.U7 0.08 2.S 7 A arent Wear. - 1 82 t).Ob 0.10 27 6.24 A ar nt Wear. 20 866 0.t)7 0.10 ~9 ~) 6.27 A rental ar. 1 909 t).05 10 27 7 6. 7 A arent We r. 953 U.U7 0. 9 Z4 7 6 8 A rent We r. _ 2 993 U.l~!i 0.08 22 b 6 7 A a ent W a. 24 1035 t).U(~ 0.10 27 (, 6.27 A ar ntW ar. 25 1079 11.07 .08 ~ 1 t, 6.25 rent ear. 26 11 2 t ~ .07 1 ~) a 6.26 ShaAo A a ent Wear. 7 1165 U 0.08 ~' t, 6.27 A ent Wear. 28 1208 O.(16 0.07 19 t, 6.26 Shallow A arent Wear. 9 1252 U.i) 5 0.06 17 ~ 6 Shallow A ren W ar. 30 1295 U 0.04 10 S 6.28 Shallow A arent Wear. 3 13 9 U 0 03 9 .26 ha I w A rent Wea . 32 1382 t1 0.03 t3 .~ 6.26 33 142 U 0. 6 16 4 .27 S allow A arent W r. 34 1467 (1 0.05 14 ~1 6.24 Shallow A arent Wear. 35 1511 t? 0.0 I a -1 6.27 Shallow A arent Wear. 36 155 + 1 0.04 1 U ~' 6. 6 Shallow A arent Wear. 37 1598 ~. ~ 0.03 8 ' 6. 5 38 1641 U 0.02 6.23 1684 ti 0.04 11 ~ 6.25 Shallow A r nt Wear. 1728 U.U i 0.04 12 - 6.27 Shall w A are t Wear. 41 1772 +? 0.04 I ~ -~ 6. 5 hallo A ar nt Wear. 4 1815 t' 0.05 1 5 ~1 6.27 S allow A arent W ar. 43 1859 U .03 t1 3 6. 6 44 190 U 0.04 12 3 6.26 Sal ow A ar nt Wear. 45 1946 U 0.03 9 ~ 6.25 Shallow A arent Wear. 4 1 89 U 0.0 ~) 2 6.26 hallow A are Wear. 47 2033 1+ 0.04 11 _' 6.24 Shallow A arent Wear. 48 076 t 1 0.04 12 ~' 6.24 Shallow A arent Wear. 49 2120 U 0.03 9 ~' 6.25 Shallow A arent Wear. 50 16 a 0.0 8 6. 6 - Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf J-55 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: iLATION SHEET 2 A-16 Kuparuk ConocoPhillips Alaska, inc. USA March 8, 2010 Joint No. )t. Depth (Ft.) Porn. Ui~set {Ins.) Pen. Body (Ins.) Pen. % Metal I r~ss °~~> Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 51 06 a 0.03 t3 z 6. 5 52 50 u 0 03 9 ~ 6.22 Shallow A arent We r. 53 2 94 U 0.0 8 2 6.26 54 2337 !? 0. 4 11 3 .2 S allow A are t Wear. 55 381 a 0.03 t3 6.2 6 2424 (~ 0.03 8 6.23 57 2467 O 0.02 7 2 6. 8 2511 U 0.02 ~ ~ 6. 5 59 2554 U .03 Y I 3 60 2598 U 0.02 (~ 1 6.23 _ Penetration Body Metal Loss Body Page 2 ~, ~~~ ~ KUP 2A-16 ConoeoPhillips ~ ttributes n le 8 MD TD ~ I"'` 1 e API:I!WI 50143_004'_00 Fteltl Name Well Status KUPARUK RIVER UNIT PROD MD !fr KEr _ 7.9DG GO Act Btm IttKBi 9.88b.0 wen eon -:A-tE vz~°ato tua +ePxt ~ - ent H2S Ippml Dnt! AnnoWfan E - m' LUCKED OUT ~'S 1/1012009 Lest WO: nn Dale K6-Grtl IT, 3450 Rrq Release Dete 8i20n9S5 , . magic- Mnctatron Depth IRKB; Entl Date Annotatbn Last Motl By Entl Date ! ast Tay SLA1 9.806.0 ~~r~201G Rev Reasoe Tag. GLV C; O. Ctri Tby. Puil Imosba 1;^9;2010 Casing Strings smg Descrrpnon String Cr r D Suing ID Im! lap IRKEI Set Depm lhK81 Set Depm (7VDI (ftKBI So-lnp Wt Ilbs:kl Sn~nq Grxte Stnnp Tnp 7hrd covtwcroR. CONDUCTOR 1 6 15.1060 24.0 104.0 104.0 6250 .H-40 nFET SU A E 1 . 6 .0 3.6 ~.85 .1 3 . J- , r vLV. o t s9P PRODUCTION 7 6 151 0 0 9.017 0 5.790 1 ^6 OG J-55 LINEP. 5 4 151 S i__^8 0 9 888 C 15 OG J-55 C4SLiFT z.etE Tubin Strin s g SURFACE. Tubrng Descrllwon Suing O -.n! D Slr ing ID flnl Top lkKEl Set Depth f11KBl Set Depth RVDI (ttKB; Str inq Wt IIh9~R1 Snnq erode Stnng TUp Tnrtl sem TUBING -S''. :_' °_992 C.G 0.572.0 5.554.9 3.30 J-55 EVE8rjA8MOU oASUFr. ~ TZ[ TUBING 7 .8 2A41 8.5720 8JG20 5.5:2.3 6.50 J-55 EUE . TUBING ; 8 1 995 8. D° D 9396 6 031 B 4 7G N-80 EUE 8RU Other In Hole All Jewel :Tubin Run 8 Ratrievabls, Flsh, etc.- Gti `1FT' 0,31E hNB Top DepN I7VD) (~B1 op Inc! 1`I esc " 'on omment __ un Date D 'ml oASUFr. 9+ 0 ' 1.899 1.785.7 36.80 S AFETYVLV Cameo'TRDP-IA-SSA'LUCKEDOUT1/22j2D1D 8!1511991 2.813 . . 2.815 2386.3 54.19 G AS LIFT CAMCO/KBUGII;DMYIBKIiI CommenC STA 1 112"2010 2922 cAS uFT. 4' I Y Il! anmem~ . _ /_.. . eras __ Y ommeM:., 5.794 4.085.8 .84 G AS LIFT CA ( UG111D YIB /7 Commem: Eat Pkg 5 A 4 12/22/2009 292_ SAS ^FT. B.E t2 6_°05 4.314 4 56 44 G AS LIFT CAMCO(KBVGI1fDMYJBKJ,;1 Commem STA 5 5j2(1999 ~ 9=° . 1~ .53 . ' LI CA / U 1! Y/BKp, Comment. S A 115/1991 _.9__ oASUFT. - _ Y ommem. ;-r - i 7.525 5.02:.1 58.55 G AS LIFT CAMCOIi®UGhiDMY(BK11f Comment: 5TA 8 8115f1991 2922 GAS ` Fr 8.02 5.275. 59.70 G AS LIFT CAMCOIKBU I11DMY/BKp(Corranerlt: A 9 5f~1999 2.922 - . _ _ LI A _/1. N ! omment: S _ J~ i 8.557 5.5422 59.02T BGCUT PRE-SIDETRACKCUTTUBING 1;271201D 3.992 'SAS ~R. e aza 8.560 5.548 8 59.01 T P BG UNCHES TUBING DUNC ES 4 spf. 5 1k2 0" 1/27J2 10 2.000 JAS !'FT 6.575 5.556.5 58.97 S BR Camco'OEJ' 8)1511991 2297 . B_:c ` 3` 811100' Jl ;1 1 86_ 5 58.87 C AC E R -SI A K A HE 1 N lj~ i~ 1D 1 67_ Teu CUT, g sc~ 8.631 5.585.5 86 P RODUC ION CAMCOfKBMG-1(i/DMY/BK((/ComnTrnt: STA 11 5127(2003 ^_.34 8.668 5.604.6 58. 4 N IP L AVA PL PO TED NI LE 8)t 5;1991 2.50 reo Pukc -- ~~ .6 8 .6 . 4 S EV - .~ " AV B C, set /. /06 ` ?~ J_ 1.875 e ao 8.690 .616.0 58. FI SH I C SO V PERWRPELEMENT 211 ;1995 0. 0 _ 1 9.373 6.016 4 47 94 P ACKER Baker DB' 8115/1991 3 °50 9.389 6.027.1 48.07 N IPPLE Cameo' 'Nipple. NO GO 8;1511991 1.813 9.396 6.031.8 48.1: T TL NO TTL ELMD LOG AVAILABLE 8J1511991 1.995 PACKER. B'Ji----- - -- - 9. 52 6.27.2 44.28 FI SH 1 112" OV EmpTy Pocket Fell DDwnhDle .110!1 5 .000 Perforations & Slots cATCHER_ e eze op (RKB) tm (RKB) Top INDI IRKBI Bun 1ND1 IRKBI one ate Shot Dero (sn.° T omment 4284 9.348 5.956.4 5.999.5 C-4. 2A.-16 91911985 120 IPERF 3 3/8" Csg Gun: 60 da'9 ph °ROOU=T'om` se~• 9.40^_ 9.50E 6.089.° 61053 A-4. 2A-', 99;1985 1_.O IPERF 33,8"Csg Gun: 60 dey ph NIPPL'c B BeE - 9. '~ • 9 55E f.1~1.4 6 '4G.1 a-9 =A-'6 93;1985 ',..G IPERF 3 3rS" Csy Guk. 60 cMy ph , . , SLEEVE. ~ e eEB Notes: General 3 Safe . End Cat< Anno[ation 51'7.'1333 NOTE: Tby x Annuh:5 can n,- s~<o?c• !?v1 ~ uS23' may be flow cut Fur, seEC ~ " 6J22J2D06 NOTE WAIVEREU WELL 10. x UA ANNULAR COMMUNICATION 5/ (20 9 N : LDL O ND U NG L AK 2 _ 3' EL PRODUCTICIN 9.01] IPERF. 9.w-a ve PACKER r3`b NIPPLc' 8.399 I' 505. B.~d- TTL e_e. rPERF 9Ib'-9'~E IPERF F.53L' PT•'_b F!SN P:s~ LINER PPbb ~. TD. D.P9d -~-}{. E7t)beF e 11 of 27 February 11, 2010 WELL LQG TRAN~~/TTAL I'. PrtoA,crivE DiAgNOSric Sertvices, INC. 2A-16 1 Report / EDE To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 15-Mar-1O 2j Signed ; Print Name: ~~~~ 50-103-20042-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-r+1~41L : adsanchoraaeCaamemorvlog.com WEBSITE : www.memorVloa.com C:\Documents and Settings\Diane Willisms\Desktop\Transnut_Conoco.docx • • Memory Multi-Finger Caliper Log Results Summary ~. Company: ConocoPhillips Alaska, Inc. Well: 2A-16 Log Date: March 15, 2010 Field: Kuparuk Log No.: 7395 State: Alaska Run No.: 5 API No.: 50-103-20042-00 Pipet Desc.: 9.625" 36 Ib. J-55 Top Log Intvl1.: Surtace Pipet Use: Surtace Casing Bot. Log Intvl1.: 1,919 Ft. (MD) ~ Inspection Type : Buckling & Restriction Inspection COMMENTS This caliper data is tied Into the top of the 9.625" Surtace casing at 36'. ' This log was run to assess the condition of the 9.625" Surtace casing following milling operations to alleviate I.D. restrictions due to bends in the surtace casing. A log plot of the caliper recordings across the logged interval and a plot of the top 500' is included in this report. ' Apparent mill debris /deposits are recorded from 1,830' to 1,900, restricting the I.D. to 6.17" in joint 45 (1,838'). Although the caliper fingers were restricted to 6.17",adrift of a larger diameter may not be impaired by these deposits due to the differences in force of a drift run and a caliper arm during normal logging speeds. This is the fifth time a PDS caliper has been run in this well and the second time the 9.625" surface casing has been logged. A comparison of the current and previous log (March 10, 2010) indicates a decrease in deposits and new indications of mill wear, which have increased the diameters recorded in the vicinity of the ^ bends. ,: Field En ineer: Wm. McCrossan Analyst: M. Lawrence & G. Waldrop Witness: R. Overstreet ProACtive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone; (281) or (888} 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 v~' I G/ • PDS Multifinger Caliper 3D Log Plot ~~ _ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-16 Date : March 15, 2010 Description : Detail of Caliper Recordings Across Bends in Surface Casing Pre- &Post-Milling. Comments Depth Max. I.D. (03-10-10) Image Map (03-10-10) Max. I.D. (03-15-10) Image Map (03-15-10) 1ft:800ft 7.7 9.7 0° 90° 180° 270° 0° 7.7 9.7 0° 90° 180° 270° 0° Min. I.D. (03-10-10} Min. I.D. (03-15-10) 7.7 9.7 7.7 9.7 Nominal I.D. ! O.D. Nominal I.D. / O.D 7.7 9.7 7.7 9.7 . _ Tree ~ .~ • >, Pup Joint _ __. 50 Joint 1 .. _. Joint 2 1100 Joint 3 150 Joint 4 200 Joint 5 Joint 6 Mill Wear on 250 Bend Min. LD. = 8.25" Joint 7 Mill Wear on 300 Bend Min. I.D. = 8.65" Joint 8 350 Joint 9 ~~- ~ ~ ' 400 Ili ~ ' _ ~ ~ - ' - ,; ,__ ~ -- . Joint 10 1_ -4~ _ -_~~- 450 _ _ --_ _ _ - - ~ -'-' - Joint12 ! -~! ' • PDS Mu(tifinger Caliper 3D Log Plot ' \~ ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-16 Date : March 15, 2010 ' Description : Detail of Caliper Recordings Across Bends in Surface Casing and Deposits. Image Map (Centered) 0° 90° 180° 270° 0° ' • • • • • • • PDS Report Overview ~~.-- ~,,. Body Region Analysis Well: 2A-16 Survey Date: March 15, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 9.625 ins 36 ppf 1-55 8.765 ins 9.625 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~,.;,, metal loss body 40 30 20 10 0 0 to 1 to 10~~to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 48 pene. 2 40 2 Z 0 2 loss 16 28 2 1 1 0 Damage Configuration (body ) 20 10 0 isolated general line ring hole/puss pitting corrosion corrosion corrosion ible hole Number of'oints dams ed total = 17 3 0 12 0 2 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 0 10 __ _ 20 30 40 Bottom of Survey = 47 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 9.625 in 36.0 ppf J-55 Well: 2A-16 Body Wall: 0.430 in Field: Kuparuk Upset Wall: 0.430 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 8.765 in Country: USA Survey Date: March 15, 2010 Joint Jt. Depth Pen. Pen. Pen. lvlcial Min. Damage Profile No. (Ft.} Upset Body °i<> loss LD• Comments (%wall) (Ins.l (Ins.) "~, (Ins.) 0 50 100 i ~a i ~ Sin i +~ i n m i , i ~ i R ~~ i ~ 40 1614 i) 0.01 2 I 8.67 41 1657 lr 0.03 i> 8.65 42 1701 U 0.02 5 8.61 Lt. De osits. f _ Penetration Body Metal Loss Body Page 1 PDS Report Cross Sections Well: 2A-16 Survey Date: March 15, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: Conoco Phillips Alaska, Inc. Tool Size: 2.75 Country: US,A No. of Fingers: 40 Tubin 9.625 ins 3b f )-55 Anal st: M. Lawrence Cross Section for Joint 6 at depth 264.817 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 52 Tool deviation = 2 ° Finger 2 Penetration = 0.724 ins Mill wear on Bent Pipe 0.72 ins = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ PDS Report Cross Sections Well: 2A-16 Survey Date: March 15, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Taol Size: 2.75 Country: USA No. of Fingers: 40 Tubin 9.625 ins 36 ppf J-55 Analyst: M. Lawrence Cross Section for Joint 7 at depth 317.527 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 66 Tool deviation = 1 ° Finger 26 Penetration = 0.539 ins Mill Wear on Bent Pipe 0.54 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 2 PDS Report Cross Sections Well: 2A-16 Survey Date: March 15, 2010 Field: Kuparuk Tool Type: UW MFC 40 No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: U5A No. of Fingers: 40 Tubin 9.625 ins 36 f J-55 Anal st: M. Lawrence Cross Section for Joint 45 at depth 1837.677 ft Tool speed = 43 Nominal ID = 8.765 Nominal OD = 9.625 Remaining wall area = 100 Tool deviation = 39 ° Finger 35 Projection = -1.548 ins Apparent Mill Debris /Deposits Minimum I.D. = 6.17" HIGH SIDE = UP Cross Sections page 3 ~~~ ~ KUP ~ 2A-16 ConocoPllillips Attributes le & MD TD .11.7-:"t ~1~ Wellborn APWWI 501032004200 Fieltl Name KUPARUK RIVER UNIT Well Stahts PROD Inc!(°7 MD IftKB) 60.15 7,900.00 Aft Btm lftKB) 9,888.0 was arm -za-1s irz 1o r o3 es PM Commern M2S (ppm) SSSV: LOCKED OUT 425 Date 1/10/2009 Annotation Last WO: Entl Data KB-C.rtl (ft) 34.50 Rig Release Data 8/20/1985 . c- Atlual Annobtran Depth Iroce7 Entl Dam Annot~on Last Motl By Entl Dale Last Tag: SLM 9,806.0 1/20/2010 Rev Reason: Tag, GLV C/O, Cut Tbg, Pull Imosbor 1/2972010 Casin Stria s _ _ Caning Daseription Stang O linl D String ID lin) ToD IRKS) Set Depth (roCe) Set Depth (TVD) (Ttl(B) String Wt (IbsHt) String Gratle String Top Thrtl cor7DUCroR, 1oa CONDUCTOR i fi 15.060 24.0 704.0 104.0 62.50 .H-00 FE SURFACE 95 18 8.765 0.0 3,607.0 2,856.1 36.00 J-55 sA TV VLV' 1,ass PRODUCTION 7 6.151 0.0 9,017.0 5,790.1 26.00 J-55 LINER 5 4.151 8.728.0 9,888.0 15.00 J-55 casuPT, z e1s Tubin Stria s . SURFACE run Daacri can Stang O linl D Stang 10 Gn) ro rote! Sat DepN Iroce7 Set DepM (TVD) (rote) String Wt Iwsm) String crane so-in ro Thrtl , 3,ao/ TUBING 3 1/ 2 2.992 0.0 8,572.0 5,554.9 9.30 J-55 EUESrdABMOD OAS LIFT. 4 ~1 TUBING 27/ 8 2.441 8,572.0 8,702.0 5,622.3 6.50 J-55 EUE ' TUBING 231 8 7.995 8.702.0 9,396.0 6,031.8 4.70 N-80 EUE SRD Other I n Hole A ll Jewe l :Tubin Run Bt Retrievable Fish etc. cAS uFT. 5,318 o I1NCB) Tap Daptn (T`/DI (ftKB) Top Inel (°) escri 'an ommaM un Data D in OAS LIFT, s ~ 7,899 1,785.7 36.80 S AFETY VLV Camcn TRDP-tASSA'LOCKED OlJT 1/2?12010 8/15/7991 2.813 ' 2,815 2,386.3 54.19 G AS LIFT CAMCOfK6UGl1/DMYBK/!! Comment- STA 1 1!22/2010 2.922 casuFr. 4.721 3,489.8 55.70 G AS LIFT CAMCO/KBUGl1/DMYBK///Comment:STA2 1/22/2070 2.922 s,zos 5,318 3,822.4 56.71 G AS LIFT CAMCOlKBl1G/1/DMY/BK/O Comment: STA3 8/15/1991 2.922 5,794 4,085.8 55.84 G AS LIFT CAMCO/KBUG111DMY/BKI!! Comment: Ext Pkg STA 4 12/22/2009 2.922 cas uFr. sslz 6,205 4,374.4 56.44 G AS LIFT CAMCO/KBUG/1/DMY/6K/// Comment STA 5 5/211999 2.922 6,612 4,535.7 57.66 G AS LIFT CAMCO/KBUG/1/DMY/B W//Comment: STAG 8/15/1991 2.922 cAS UFT 7,112 4.802.9 57.62 G AS LIFT CAMCO/KBUG/1/DMY/B W!/Comment STA7 51211999 2.922 ~~12 7,525 5,022.1 58.55 G AS LIFT CAMCO/KBLIGl1/DMYBKI//Comment: STAB 8/15/1991 2.922 cas uFr 8,023 5,275.0 59.70 G AS LIFT CAMCO/KBtJG/1/DMY/BK///CommenC 5TA9 5/2/1999 2.922 , 1,~g 8,529 5,532.9 59.09 G AS LIFT CAMCOIMMG2/1.5/OPEWRKI/l Comment STA 10 7/25/2070 2.371 8,557 5,547.2 59.02 T BG CUT PRESIDETRACK CUT TUBING 7/27/2010 3.992 OAS uFr, a,oz3 8.560 5,548.8 59.07 T P BG UNCHES TUBING PUNCHES, 4 spf, 5.1'x2.0" 1/27/2010 2.000 8,575 5,556.5 58.97 S BR Carlxo'OEJ' 8/75/7991 2.297 cas uFT. 6,529 8.592 5,565.2 58.92 P A KER Camcn'HRP-I-SP' 8!15/1991 2.344 8,626 5,583.0 58.87 C ATCHER PRESIDETRACK CATCHER 1.875" G-FN 1!25/2010 1.875 Tec cur, asst 8,637 5,585.5 58.86 P RODUCTION CAMCOIKBMG-1/1/DMY/BK/I/Comment STAii 5127/2003 2.347 8,668 5,604.fi 58.74 N IPPLE AVA BPL PORTED NIPPLE 8/15!1991 2.250 reO PUNCHES 8,668 5,604.6 58.74 S LEEVE-0 2.25" AVA BPC, set 5/20/06 5/20/2006 1.875 . also 8.690 5,616.0 58.66 F ISH PIECES OF UPPER WRP ELEMENT 2/10/1995 O.ODO 9,373 6,016.4 47.94 P ACKER Baker'DB' 8/15/1997 3.250 9,389 6,027.1 48.07 N IPPLE Camco'D' Npple, NO GO 8/15/1991 1.813 seR,eals 9,395 6,0.31.1 48.11 S OS Otis 8!15!1997 1.995 9,396 6 031.8 48.72 T TL NO TTL ELMD LOG AVAILABLE 8/15/1991 1.995 PACKER 8 592 9,752 6,272.2 44.28 F ISH 1 1/2" OV Empty Pocket; Fell Downhole 2/10/1995 0.000 , , Perforations 8 Sots cnrcr+eR, To TVD Btrn (ND7 sna Dens 852fi Top Iro(B) etm Irocel ) p ( IftKBI t~Bl Zane Date Ish_. TYPe CommerR 9,284 9,348 5.956 4 5,999.5 C d, 2A-16 9/9/1985 12.0 IPERF 3 3/8" Csg Gun; 60 deg ph PROOUCrION, 8,831 9,482 9,506 6,089.2 6.105.3 A ~4, 2A-16 9/9/1985 12.0 IPERF 33!8" Csg Gun; 60 deg ph 9,53D 9,558 6,121.4 6.140.1 A -3, 2A-16 9/9!7985 12.0 IPERF 33/8" Csg Gun; 60 deg ph NIPPLE 8668 sLFEVE ~~ Notes: General & Safe 6'~ Entl Dato Annotation 5/7/1999 NOTE: Tbg x Annulus Comm; suspect GLM @ 8529' may be tbw cut FISH, 8,690 6/22/2005 NOTE: WAIVERED WELL: IAx OA ANNULAR COMMUNICATION 5!15/2009 NOTE: LDL FOUND TUBING LEAK ~ 5863' ELMD PRODUDTIDN, 9,01 IPERF, 9.2849.318 PACKER. 9.313 NIPPLE, 9,389 SOS. 9,395 Tn. s.~a IPERF. 9.4829,506 IPERF, 9.530-9.558 FISH, 9,152 LINeo; 9',eeas ge 11 of 27 February 11, 2010 Schwartz, Guy L (DOA) Page 1 of 2 From: Schwartz, Guy L (DOA) Sent: Tuesday, March 16, 2010 11:24 AM To: 'Gober, Howard' Subject: RE: 2A-16 (PTD 185-147) Sundry 310-006 7"x9-5/8" Top Job Howard, This summarizes what we discussed this morning adequately. It would be interesting to see what is really behind the surface casing up in the dogleg area.... I would assume a very large void filled with lots of melted ice water and mud. I wonder where this fluid is getting displaced to by the cement? (out / up /down???} Not sure if that would be data worth trying to get ... like a temperature log after you finish this top job. Just a thought. Regards, Guy Schwartz .._ ~ ~~~~;~i,_ ~ ~ ~ ~ ~~_,~, Senior Petroleum Engineer ~"~~•~~y` ~~ '~ `~ ~~ ~~ AOGCC _ 793-1226 (office) 444-3433 (cell) From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Tuesday, March 16, 2010 10:32 AM To: Schwartz, Guy L (DOA) Subject: 2A-16 (PTD 185-147) Sundry 310-006 7"x9-5/8" Top Job Guy, Just wanted to document our conversation this morning regarding 2A-16. During the milling operations in the 9- 5/8" casing, we milled a hole in the casing. We were loosing approximately 20 bbl/hr while circulating. Yesterday we successfully ran the 7" casing and screwed back into the casing stub. A pressure test of 2460 psi was obtained on the 7" casing after we screwed in. We opened the Halliburton ES cementer and cemented the 7" inside the 9-5/8" casing with 75 bbls ArcticSet1 cement (24% excess). Unfortunately we did not get any returns to the surface. While waiting on orders, the crew began to ND the BOP stack. We are nippling back up the stack. Since we have casing leaks now, the stack is no more than a diverter stack, and we cannot pressure test it, therefore, we will not pressure test. Our plan is to: • NU BOP stack • Have Schlumberger deliver a full bulk truck of ArcticSet1 cement in case a 2nd job is needed • Establish injection rate down 7"x9-5/8" annulus with 9.6 ppg brine at 0.5 and 1 bpm. Pump 10 bbls fluid after catching up with fluid level. • Ensure mix water is 60-70 deg F if possible. Cooler mix water will make the cement blend thicker • Mix and pump 25 bbls cement as follows: • 5 bbls AS1 neat at 1 bpm max • 10 bbls AS1 with 2 Ib/bbl CemNet at 1 bpm max. CemNet is fibrous and will help the cement to bridge off. • 10 bbls AS1 with 2 Ib/bbl CemNet at 0.5 bpm max. Trying not to push the cement, but just keep up with it falling • Do not displace the cement past the Wellhead valve. Close in wellhead valve and clean up lines. • tf necessary due to the cement falling all the way to the 9-5/8" casing hole, we will do a second job. • Clean out OA valves with diesel • WOC until 500psi compressive strength. • ND BOP and lift. Land casing on slips with 50M# tension. Rough cut and set back BOP stack. Make final cut with Wachs cutter. Fill any void below packoff with diesel. Install casing packoff. 3/16/2010 Page 2 of 2 ise confirm that this note adequately documents our conversation. Please call with any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophitlips.com 3/16/2010 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Casing Evaluation (CASE) /Advanced Cement Evaluation (ACE) Run Date: 3/6/2010 March 15, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-16 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20042-00 5" CASE Log (1:240) 1 Color Log 50-103-20042-00 ZO" CASE High Resolution Log (1:60) ,., r -, h°; 1 Color Log 50-103-20042-00 ~,, 9~~.~'~~~'' ~iAr? ~v° ~ ~ Vi'i' 5" ACE Log (1:240) 1 Color Log 50-103-20042-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 l '`~ 5~. ~ ~~ Office: 907-273-3527 Fax:907-273-3535 l~~/~ ~( rafael.barreto@halliburton. com Date: ~~ Signed: Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 11, 2010 3:17 PM To: 'Gober, Howard' Subject: RE: 2A-16 (PTD 185-147.:,~dry 310-006) Completion Howard, Your proposal is acceptable in order to isolate potential casing leaks in the 7". The proposed straddle section will be from 5650' and to 8592' and (existing top packer). Guy Schwartz Senior Petroleum Engineer ;~~ ~~~ ~~~ .~ ~~ ~~~, AOGCC ~''` 793-1226 (office) 444-3433 (cell) From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Thursday, March 11, 2010 2:53 PM To: Schwartz, Guy L (DOA) Subject: 2A-16 (PTD 185-147 Sundry 310-006) Completion Guy, I just wanted to document our discussion on the completion of 2A-16. Our original plan was to stack a packer above the existing top packer and run gas lift tubing to the surface. Caliper logging during the workover has revealed some pitting up to 5785' RKB. Our plan will be as follows: • Set bottom packer as planned • Run straddle packer with 3-1/2" tubing below. Stab into bottom PBR and set straddle packer at 5650' RKB (above pitting damage). • Run 3-1/2" gas lift completion above the packer at 5650'. This completion will isolate the pitted casing from production fluids. We will ensure corrosion inhibited brine is pumped into the annular space of the straddle. Please let me know if you have any questions or if you need more information. I would appreciate a note back with you concurrence that this adequately documents our conversation. Thanks, Moward Gober Wel-s Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com 3/11/2010 • ` Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Sunday, March 07, 2010 8:52 AM To: Gober, Howard Cc: Nordic 3 Company Man; CPA Wells Supt; Cawvey, Von; Ennis, J J Subject: RE: 2A-16 (PTD 185-147) Sundry 310-006 Program Change Howard, I agree with your assessment and plan forward. There are adequate barriers to the reservoir in place already... You mentioned a bridge plug in the 7" and KWF. Getting a "rolling" test of the flange break and 7" rams to 1500 psi (against the OA and bridge plug) should be OK until the until the 7" is pulled and a plug set in the casing head. We can meet to discuss future subsidence workovers any time next week. If you could please bring some Gen III wellhead diagrams and we can go from there. thanks, Guy Schwartz Staff Petroluem Eng. AOGCC ;;r..-. ~,.'~ -----Original Message----- From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Sat 3/6/2010 11:14 PM To: Schwartz, Guy L (DOA) Cc: Nordic 3 Company Man; CPA Wells Supt; Cawvey, Von; Ennis, J J Subject: 2A-16 (PTD 185-147) Sundry 310-006 Program Change Guy, I wanted to document our phone conversation this evening regarding a program change on 2A-16. We are repairing subsidence related issues on this well during the workover along with replacing corroded tubing. We have completed the logging inside the 7" casing and are preparing to run in hole with the retrievable bridge plug as per the plan. The next step in the plan is to cut the 7" casing followed by ND of the BOP stack and tubing head. I want to reverse these steps since I need to have the 7" casing in tension prior to cutting it. When the stack is nippled back up to the tubing head, I said in the program that we would set a test plug and pressure test the BOP flange 3000 psi. We cannot do this. With the 7" casing still in the well, there is no place to set a test plug. Therefore, I proposed that we NU the stack to the casing head and pressure up to 1500 psi. We will be pressuring up against the surface casing and against the bridge plug in the 7" casing. We can verify there are no visible leaks on the wellhead and stack, but we will most likely not get a straight line on the test chart. We will install 7" rams in the stack for the casing pull. The AOGCC Inspector will be given notice of this test. Next we can cut and pull the 7" casing. At that time we will be ready for a weekly BOP test. With the 7" casing pulled we can set a test plug in the casing head and pressure test the BOP stack to 250/3000 psi. The top flange of the casing head is rated to 3000 psi. The AOGCC inspector will be given notice of this test. After all this work, we will be back on the original plan. I would like to sit down with you to discuss future subsidence related workovers and how to handle the steps above in the future. I will call next week to set up an appointment. Thank you for your help in this matter. Please send a reply to this note saying that it reflects the discussion that we had and that you approve going forward with the revised plan. Please call me on my cell phone if you would like to discuss this matter further. 1 Thanks, • Howard Gober Well Engineer ConocoPhillips Alaska, Inc 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 29, 2010 Attn.: Christine Mahnken . ~~•.- _ . 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 <~~~~ ~~ ~ ~_ RE: Perforating Record: 2A-16 Run Date: 1/27/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20042-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~,rG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99~ 18 Office: 907-273-3527 Fax: 907-273-353 rafael.barreto@halliburton.com Date: ~~~ ~~~~ ~~ a~ ~,j ; i Signed: ~ ~ ;'~ • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 28, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 ° ~" ~~ Anchorage, Alaska 99501 s' ~ ~ ~~ 4 {~ ~,~~~~~ ~C~ RE: Plug Setting Record: 2A-16 Run Date: 1/24/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20042-00 ~ .~5--- Ic` ~- ~ 9 ~G~ PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNIIvTG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-353 rafael.barreto@halliburton.com - Date: _ _ 1 ~ ~ /~ ~ ~ ~ Signed: +~ ,~ %~ ~~ • A1LA5S-A OII, ~1~TD Gr~S CO1~T5ERQATI011T COMl-II551O1~T Mr. Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~~~~ ~Ai~ ~ ~- ~~~~ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-16 ~ 1 L Sundry Number: 310 006 ~ '' '~1 Dear Mr. Gober: • SEAN PARNELL, GOVERNOR 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 file 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, Daniel T. Seamount, Jr. Chair DATED this day of January, 2010 Encl. • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 13, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: • ~~ ~. ~ gg:;~ Z~~u ES .., .rn ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2A-16 (PTD 185-147). 2A-16 was originally completed in September of 1985, and a rig workover was performed in August of 1991. The well is a gas lifted producer that developed a tubing leak in April of 2009. Additionally, the well is in an area with surface subsidence due to permafrost thawing. Although the well does not exhibit any problems with the OA or the IA (both pass MIT pressure tests), ConocoPhillips plans to take proactive measures to mitigate future potential subsidence related problems. The purpose of this workover is to repair the tubing leak, cut & pull a portion of the 7" casing, re- run new 7" casing, and circulate cement into the 9-5/8"x7" annulus. The 7" casing work is not . required to fix an existing problem, but it will be done while the rig is on the well as a proactive measure. New 3-1/2" L-80 tubing along with a stack packer will be run into the well to repair the tubing leak. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. G er Wells Engineer CPAI Drilling and Wells ~ ~~ • STATE OF ALASKA • ~ ~ ~ ~ a ~/ ALASKA OIL AND GAS CONSERVATION COMMISSION `~~'~ ~~ APPLICATION FOR SUNDRY APPROVAL~~a t~~z ~~ ; ~~,~~,~:~-w ~~r~l~°~~~~° 20 AAC 25.280 ^ ` 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well 0 Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^~ Time F~ctension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^~ Other: n 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q , Exploratory ^ 185-147 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20042-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO Q 2A-16 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25570 ~ Kuparuk River Field /Kuparu k River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9888' 6368' 9738' 6260' 8690', 9752' Casing Length Size MD TVD Burst Collapse Conductor g0' 46" 104' 104` Surface 3581' 9-5/8" 3609' 2856' Intermediate ggg9' 7" 9017 5790' Liner 1160' S" ggg8' 6368' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9284'-9348', 9482'-9506', 9530'-9558' 5956'-5999', 6089'-6105', 6121'-6140' 3.5", 2-7/8", 2-3/8" J-55, N-80 8572', 8702', 9396' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Camco HRP-I-SP pkr, Baker'DB' pkr 8592' MD/5565' TVD, 9373' MD/6016' TVD Camco TRDP-1A-SSA 1899' MD / 1786' TVD 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ - Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 28, 2010 Oil ~ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Engineer Signature Phone 263-4220 Date ~ J Commission Use Onl Sund r Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~ ~ QoP f- ~ 350o P Other: A r,-S'~ ~~"~~''~! 'q n,. -~w-~ I ~ ~ SCb , -~ Z P ? Subsequent Form Required: /O .7 ' APPROVED BY ~0 A d by O MISSIONER THE COMMISSION Date: ~71fM~40~v'FSelb 'l~l~0 ' Submit in Duplicate l/`~ 6v - . • 2A-16 General Workover Procedure 1/13/10 1. Pull ER test tool in patch at 5848' RKB. Pull Patch at 5848' RKB. Tag fill. After a minimum of 3 days shut-in time, obtain 30 min SBHP at 9421' RKB (mid A & C sand perfs). Pull up to 9271' RKB for 15 min gradient stop. Lock out SSSV at 1899' RKB. Pull GLV's at 2815' RKB and 4721' RKB. Replace with DV's. Pull DV at 8529' RKB and leave pocket open. Set WRP at 8626' RKB. CMIT to 2500 psi. Drawdown test to 0 psi. Set catcher sub on WRP. Cut tubing at 8557' (middle of first full joint above OEJ). Set BPV. 2. MIRU Nordic 3. 3. Pull BPV. Verify well is dead. Load hole with 9.6 ppg brine. Set BPV. ND tree. NU 11" 5M BOP. Pressure test BOP including annular to 250/3000 psi. Maximum potential surface pressure is estimated at 1675 psi based on maximum observed SI tubing pressure on 10/23/09. Anew MPSP will be calculated after obtaining the SBHP during pre-rig work. The 3000 psi BOP test should be more than adequate. 4. Pull blanking plug and BPV. Circulate hole clean. POOH laying down tubing. 5. RU E-Line. Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. RD E-Line. 6. Set retrievable bridge plug below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi. Dump sand on top of RBP. 7. Cut 7" casing with mechanical cutter above TOC. Circ 9-5/8" x 7" annulus clean. ND BOP - and tubing head. NU 11" 5M BOP on casing head. Pressure test break to 3000 psi. 8. Spear and POOH laying down 7" casing. 9. Run 9-5/8" casing scraper to top of 7" stub. Circ clean. 10. RU E-Line. Run caliper log and gyro survey in 9-5/8" casing. RD E-Line. 11. Run back off tool and back off casing stub. 12. Spear and recover casing stub. 13. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. 14. Open ES cementer and pump cement into 9-5/8" x 7" annulus. Close cementer. 15. WOC. ND BOP and land 7" on slips. Cut 7" casing and install packoff. NU tubing head. 16. NU 11" 5M BOP and test break to 3000 psi. 17. Drill out cement and plug. Pressure test casing to 2500 psi. 18. RIH with wash shoe and circulate out sand on top of RBP. POOH. RIH w/ retrieving tool on work string. Release RBP and POOH. 19. RIH with poorboy overshot, packer, and PBR on 3-1/2" drill pipe. Go over tubing stub. Circ in corrosion inhibited fluid. Set packer. POOH laying down drill pipe. 20. RIH with new 3-1/2" tubing and seal assembly. Load tubing and IA with corrosion inhibited seawater. Stab into PBR and space out. Pressure test tubing and IA to 2500 psi. Shear SOV. 21. Set 2-way check. ND BOP. NU tree and pressure test. 22. Pull 2-way check. Freeze protect well. Set BPV. 23. RDMO Nordic 3. 24. Pull ball and rod. Pull SOV and run new gas lift design. Pull RHC body. Pull catcher sub. Pull WRP. 25. Return well to production. T M WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 4, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2A -16 Run Date: 10/19/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20042 -00 t, t' tnklatii``. O ,i 200S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto /Ll 6900 Arctic Blvd. C Anchorage, Alaska 99518 l 15 9 3 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto@ ibnrtofl coxh Date: NOV o 6 L 00 Signed: s f ntkAPrv)I ~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ha ~~aKI~~PB " ~ ~ ~+ ~~~~;a~. Log Description NO. 5261 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th-Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/03/09 2U-15 AZCM-00012 GLS - 03/28/09 1 1 3G-12 B04C-00047 INJECTION PROFILE ~- `-~- j J j 05/10/09 1 1 iC-172A 604C-00049 GLS 05/11/09 1 1 3G-11 B04C-00050 PRODUCTION PROFILE 05/12/09 1 1 2A-06 8146-00048 DDL - 05/15/09 1 1 2A-16 B14B-00047 LDL - 05/15/09 1 1 3G-16 6148-00049 INJECTION PROFILE O ,- ~ 05/16/09 1 1 3G-18 B14B-00050 PRODUCTION PROFILE 05/17/09 1 1 2D-05 AYS4-00072 INJECTION PROFILE - 05/21/09 1 1 1 E-15 B14B-00058 LDL 05/24/09 1 1 3H-33 B04C-00006 CH EDIT (PEX,SONIC SCANNER,CHFR) 02/09/09 4 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. f 2A-16 (PTD 185-147) Report ailed TIFL • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, April 14, 2009 1:53 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); NSK Problem Well Supv Subject: 2A-16 (PTD 185-147) Report of failed TIFL Attachments: 2A-16 schematic.pdf; 2A-16 90 day TIO plot.jpg Tom, ~~~(~(l~l~~ Kuparuk gas lifted producer 2A-16 (PTD 185-147) failed a diaonostic TIFL on 04/13/09 and will be added to the weekly SCP report. The TIO prior to the test was 200/1300/1230. A leaking GLV is suspected. Slickline will troubleshoot the tubing leak and repair if possible. Attached is a schematic and a 90 day TIO plot. «2A-16 schematic.pdf» «2A-16 90 day TIO plot.jpg» / 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 ~'VY b !'t! dG..W ~~ C-~,f~c~~~ c~~ u~~,il ~P~-- 4/ 15/2009 Not of Ku ar k W iv r ~ 11 ~ _ p u a e ed e ,~ ~~ ~ ~~ WELL: 2A-~ s WELL TYPE: Producer Gaslift DATE: 06-09-05 Production Data: OIL= 720 bopd GOR = 7700 WATER CUT = 81 Pressures: Tubing IA OA Producing: 252 psi 700 psi 700 psi Shut-In: 1900 psi 1500 psi 1400 psi REASON FOR NOTICE: Production casing by surface casing communication (IA x OA) TUBING x IA COMMUNICATION? YES NO XX •TIFL passed on 04/25/05 indicating tubing has integrity. IA x OA COMMUNICATION? YES XX NO • Slow IA x OA Comm has existed prior to 1994. Bleed rate has increased to ~2 bleeds per week to keep IA from Tracking OA. • The packoffs have integrity as POT & PPPOT-IC passed on 04/30/03. • Well passed an MITOA on 04/25/05; IMPORTANT CONSIDERATIONS/COMMENTS: • Well does not need gas lift to produce at this time, but may in the future; • Production casing packoffs appear to have integrity but still may the leak point • Surface casing has integrity based on passing MITOA @ 1800 psi on 04/25/05; • The surface casing has a cement shoe and Arctic Pack pumped in 1982; • IA x OA communication exists and can be in the packoffs or downhole. PLAN OF ACTION: XX Grant waiver to continue operations .......................................... • Allow operation with gaslift as needed; • Allow OA to equalize with IA pressure up to 1400 psi; • Monitor well head pressures daily and log as per surveillance requirements into Setcim; • Perform the following waiver compliance testing: • 2-year TIFL / MITOA @ 1800 psi alternating with a 2-year OA fluid level; • A failing MITOA will void the waiver and require SI the well and securing; • T x IA communication (failed TIFL) will void the waiver and require SI the well and securing. Problem Well Supervisor CPF Production Engineer Problem Well Su ervisor Date: Date: ENDORSEMENT: CPF Su ervisor Date: Wells Team Leader Date: Distribution: Send Original to: Problem Well Supervisor, NSK-69 DS Operator CPF PE Wells File and schematic Central Files ATO Central Files Kuparuk KRU 2A-16 PTD 185-147 4/ 14/2009 TIO Pressures • • ConocoPhillips Alaska, Inc. 2A-16 - ~ -~ -~ -~ ~ ~ API -- sssv (1899-1900, OD:5.938) SBR (8575-8576. OD:2.875) PKR (8592-8593, OD:6.156) SLEEVE-0 (8668-8669. OD:2.250) PKR (9373-9374. OD:4.156) NIP (9389-9390. OD:2.375) TUBING (8702-9396. OD:2.375. ID:1.995) Perf (9482-9506) Perf (9530-9558) 1 1/2" OV (9752-9753, OD:1.500) KRU 2A-16 (a~ TD: 144 deD an 9888 Com letion: Annular Fluid: Last W/O: Rev Reason: TTL ELMD NOTE Refe rence Lo Ref L Date: Last Update: 9/7/2007 _ Last Ta :9644' RKB TD: 9888 ftKB _ _ _ Last Ta Date: 5/1 812 00 6 _ _ _ __ Max Hole An le: 60 de 7900 - -- - _ --- Casing String -ALL CAS Description __ INGS Size j Top_ B__ottom __ TVD Wt j Grade Thread I CONDUCTOR _ ~ 16.000 0 10_4 _ 104 62.50 l H-40 SURFACE 9.625 _ ___ 0 _ _ __ _ _ _ 3607 2_85_6 36.00 _ r J-55 ~ _ PRODUCTION i 7.000 _ _ 0 9017 5790 26.00 J-55 _ _ LINER T S 5.000 8728 9888 I 9888 ~ 15.00 J-55 ubin~c tring -TUBING Size _ _Top _ ____ _ _ Bottom ___i _TVD ___ Wt -' Grade Thread ~ 3.500 0 ~___ 8572 __ _ ' 5555 9.30 J-55 _ _ E__U E_8RD AB MOD 2.875 8572 _ 8702 _ 5622 6.50 i J-55 - EUE 2.375 8702_ ' __ 9396 ' 6032 4.70 N-80 _EUE 8RD ~ Perforations Summa Interval TVD Zone Status Ft SPF ~ Date Tye Comment 9284 - 9348 _5957 - 6000 i C-4 __ 64 12 9/9/1985 _I_PERF 3 318" C s Gun; 60 d e h 9482 - 9506 6089 - 6105 A-4 24 12 9/9/1985 IPERF 3 3/8" C s Gun; 60 d h _ 9530 - 9558 6121 - 6140 A-3 '~ 28 12 9/9/1985 j_IPERF j 3. 3/8" Cs Gun; 60 d e h Stimulations & Treatme Interval ~_ _Date nts Type _ Comment 0 - 0 1/24/1991 ,Scale Inhibitor Pum 26 Bbl Diesel w/ 1 Drum SA-8603, Pum_ 70 BBI 0 - 0 3/16/1992 'Scale Inhibitor Pumped 27 Bbl Diesel/SS8603 wash, Pump _ 0 - 0 11/13/1993 -_ G Scale Inhibitor Pumped A/C Sand S 289 Scale-Inhibitor Squeeze, Wel - _ -- - as Lift Mandrels/Valve . St MD TVD Man Mfr s - -- - Man Type V Mfr V Type V OD Latch Port TRO - Date Run Vlv ___ Cmnt 1 2815 2386, Camco KBUG GLV 1.0 BK 10.156 J 1289 5/24/20031 2 4721 3490 Camco KBUG GLV 1.0 BK 1 0.188 1329 5/24/2003' 3 5318 3822 Camco KBUG DMY 1.0 BK ~ 0.000 0 8/15/1991 4 5794 4086 Camco KBUG OV 1.0 BK 0.250 _ 0 5/24/2003 5 6205 4315! Camco KBUG DMY 1.0 BK 0.000 0 5/2/1999 6 6612. 4535 ~ Camco KBUG DMY 1.0 BK 0.000 0 8/15/1991 7 7112 4803 Camco KBUG DMY 1.0 BK 0.000 0 5/2/1999 8 7525 5022 Camco KBUG DMY 1.0 BK 0.000 0 8/15/1991 _ 9 8023 5275 Camco KBUG ' DMY 1.0 BK 0.000 0 --- 5/2/1999 - 10 8529 5.533 Camco i MMG-2 ~ DMY 1.5 RK_10.000 0 5/7/1999 Production Man_drels/Va ~- -- St MD TVD 'Man Mfr lves - Man Type ~ V Mfr V Type V OD Latch Port TRO Date Run Vlv i - - - Cmnt 11 8631 5585f Camco KBMG-1 DV 1.0 BK 0.000 0 _ ._ 5/27/2003 __-_ ~ De th lu s, equip., etc they ' TVD _ Type .) -COMPLETION -- _ - _ Descrptfon - _ , ID 1899 11786 SSSV__ Camco'TRDP_-1A-SSA' _ _ _ 2.813 8575 5557 SBR ~ Camco'OEJ' 2.297 8592 5565 _ PKR Camco'HRP-I-SP' 2.344 8668 5605 ' NIP AVA BPL PORTED NIPPLE 2.250 8668 5605 (SLEEVE-O , 2.25" AVA BPC set 5/20/06 1.875 9373 6016 PKR Baker'DB' 3.250 9389 6027 ___ NIP ____ C~amco'D' Nipple NO GO _ 1.813 9395 6031 SOS Otis _ I 1.995 9396 6032 TTL Fish -FISH NO TTL ELMD LOG AVAILABLE 1.995 Depth __ Descri ption T Comment_ 9752 1 1/2" OV ~m~ty Pocket; Fell Downhole __ - General Notes Date Note - -- - --- -- _ _ _- -- -- - 5/7/1999 NOTE: Tbg x Annulus comm_suspect GLM ~a 8529' may be flow cut 6/22/2005 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION ,., ~~ ~ Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • ~~fM~ NGU ~ 3 20Q7 ~~.~T Dear Mr. Maunder: Enclosed please find a spreadsheet with alist of we1ls..from the Kuparuk field (KRi~. Each_of these wells was found to have a void in the conductor.- 'T'hese voids were filled with a 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 tfie treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on November 10, 2007. The attached spreadsheet presents the well name, top ofcement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerel , ~, ~~/ ~ _y Perry Klei t ', ~" , ,,, : r . ConocoPhillips Well Integrity Projects Supervisor • nC® i~li s I~Sa ~C. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 11/10/2007 Well Name PTD # Initial top of .cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-15 185-146 5" NA 5" NA 3.5 11/10/2007 2A-18 ~ 185-147 39" NA 39" NA 21 11!10/2007 2A-19A 201-083 12" NA 12" NA 6 11/10/2007 2A-20 193-151 9" NA 9" NA 7.5 11/10/2007 2A-24 193-144 5" NA 5" NA 2 11/10/2007 2A-25 196-062 10" NA 10" NA 2 11/10/2007 RECE\VED Sc~lumbepgep /_ /' tt-('1- \i'J 06/13/06 lJUN 1 4: 2006 NO. 3850 p¡laska Oil & Gas Cons, Commil~sion Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,../1"-" ;..~~ ~'j _.."",1l....1<,:~.~_f:_:\;~.;,. Jl·"5!.~-"''' ~~t ~) Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Date BL Color CD Job# Log Description b'- 3J-16 11249908 INJECTION PROFILE 06/03/06 1 1 R-08 11249909 INJECTION PROFILE 06/04/06 1 3H-11 - 11213760 PRODUCTION PROFILE WIDEFT 05/31/06 1 1 R-07 11249912 PRODUCTION PROFILE 06/07/06 1 1F-12 11320981 PRODUCTION PROFILE WIDEFT 06/06/06 1 3G-20 11249911 INJECTION PROFILE 06/06/06 1 2A-16 11213754 PRODUCTION PROFILE W/DEFT OS/25/06 1 2A-22 11213756 LDL OS/27/06 1 1Y-04 11320980 LDL 06/03/06 1 2Z-02 (REDO) 11235362 INJECTION PROFILE OS/28/06 1 1 H-19 (REDO) 11320975 INJECTION PROFILE OS/29/06 1 2A-13 (REDO) 11320976 LDL 05/30/06 1 3J-09 11320977 INJECTION PROFILE 05/31/06 1 1F-17 11249913 PRODUCTION PROFILE W/DEFT 06/08/06 1 1J-170 11320983 USIT 06/11/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r / -(J?~~~,--,- ~) / 1'1 ((p e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: THRU: FROM: SUBJECT: Julia Heusser, Commissioner Tom Maunder, ~ P. I. Supervisor t(~c~-c~ Chuck Scheve; Petroleum Inspector January 4, 2001 Safety Valve Tests Kuparuk River Unit -2A Pad Thursday, January 4, 2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2A Pad, As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2A-12 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. Earnie Barndt conducted the testing tOday he demonstrated good test procedure and was a pleasUre to work with . All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: River Field. I witnessed the semi annual SVS testing at 2^ Pad in the Kuparuk KRU 2A Pad, 12 wellS, 24 components, 21 wellhouse inspections Attachment: SVS KRU 2A Pad 1-4-01 CS 1. failure 4.1% failure rate X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Submitted By: Chuck Scheve Date: 1/4/01 Operator Rep: Eamie Barndt Field/Unit/Pad: Kupamk/KRU / 2A Pad AOGCC Rep: Chuck ScheVe Separator psi: LPS 96 HPS Well Permit Separ Set ' L/P Test Test Test Date Oil, WAG, G~J, Number Number PSI PSI TAp Code Code Code Passed oas or CYCLE 2A-01A 1840570~ 2A-02 1840500 · 2A-03 1840510! . 2A'04 1840530 · 2A-05 1840670 2A-06 1840640 2A-07 1840650 2A-08 '1852480 2A-09 1860010 96 - 70 50 P P OIL 2A-10 1860020 96 70 55 :P P OIL 2A-11 1860030 96 70 50 P P OIL 2A-12 1860040 96 70 70 P 4 OIL 2A-13 1851440 96 70 50 P P OIL 2A-14 1851450 96 70 70 P P OIL 2A-15 1851460 ~ 96 70 70 P P OIL · 2A-16 1851470 96 70 '70 P P OIL 2A-17 1931400 ~ 96 70 50 P P OIL 2A-18 1950590 96 70 60 P ' P OIL 2A-19 1931520 2A-20: 1931510 2A-21 1931330 2A-22 1950680 96 70 70 P P OIL 2A-24 1931440 96 70 60 P P OIL 2A-25 1960620 · Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1% E]9o var Remarks: Surface Safety on 2A-12 had slow leak, valve to be serviced and retested ...... p~o~ ~ n¢~ SVS KRU 2A Pad 1-4-01 CS.xls ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION ~ 2A- 1 6 Stimulate 2V-09 Stimulate 2 V- 1 2 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: W. H. Carter ATe 1120 KeEl .4-9 w/o attachments RECEIVED OCT - 4 1991 DJl & Gas Cons. C0mmissien '" LAr~h0.rage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.. Operation Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate ~( Plugging Repair well Perforate m Other X Re.place tbg ** 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _.X_ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1266' FSL, 227' FWL, Sec. 13, T11N, R8E, UM At top of productive interval 1256' FSL, 1179' FEL, Sec. 24, T11N, R8E, UM At effective depth 1238' FSL, 659' FEL, Sec. 25, T11N, R8E, UM At total depth 840' FSL, 1037' FEL~ Sec. 24, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 9 88 8' true vertical 6368' feet feet Plugs (measured) 6. Datum elevation (DF or KB) 722' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-16 9. Permit number/approval number 10. APl number 50-103-20042 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9 73 8' feet true vertical 6262' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 104' 16" 3609' 9 5/8" 9017' 7" 1160 5" measured 9558'-9530', true vertical 6140'-6121', Cemented Measured depth True vertical depth 234 Sx AS II 1 0 4' 1 04' 1100 Sx AS III & 3609' 2858' 400 Sx Class G 500SxG&180SxPFC 9017' 5790' 150 Sx Class G 9506'-9482', 9348'-9284' 6105'-6089', 6000'-5956' RECEIVED OCT - 4 199! Tubing (size, grade, and measured depth) ** 3 1/2" 9.3#1Pc EUE @ 8571, 2 7/8" 6.5~, EUE, @ 8691', 2 3/8" 4.7#, EUE @ 93~la$.~a 0il & Gas Cons, C0mmissiE Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA, 1899', Packer: Camco HRP-1-SP, 8591', Packer Baker DB, 9362'. 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 9558'-9482' Treatment description including volumes used and final pressure Refraced w/ 422 bbl XL ~el and 31,649# 12/18 Carbolite ~ 25-23 BPM w/ Final Press. of 6918psi. RePresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 81 8 565 - 0 - 1 725 273 Subsequent to operation 2334 21 43 23 1 1 00 291 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys runm Water Injector __ Daily Report of Well Operations X Oil X, Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 09/12/90 Title Senior Engineer Date 9/26/91 SUBMIT IN DUPLICATE WELL ARCO Alaska, Inc, ,' Subsidlery of Atlantic Richfield Company ~'qNTRACTOR DOWELL // V. YOAKU~ FIELD- DISTRICT- STATE OPERATION AT REPORT TIME JOE, COM, PLE TE WELL SERVICE REPORT IDAYS/ I DATEoeoZ~ i MEMARKS · RE-FRAC'A* .SAND - 0;30 ,,14/l~f,t DOWEI. J. F£AC E~P'T. I 0 O0 SAFETY M 105~ 01~N w~.; 165o PSi o, Te~. 1054. JSECa/N PU~PtN& ~E. PAD 1104 ~DP~-~D. ~ZP 1661 /11~ ~1~ ~MPI~ PAD 1400 CC.: K 8~-740 SCREENED ouT' (~ G918 PSI; No FLUS, II IN WELL. RI~ DOWN 5uMMAgY ' ?uJ4PET) 3164c) ~b. ~?./~8 CARBOLtTE ~ EST. 15661 lb. iN FM~ 17988 lb, AY& PE£$$u~£ 5500 ~1 .; 6915 Ps~ {~ 6CREEN O~T. ~,~N~T~INE'Z~ 31oo P~ o~J ~'" C,,~. Pt~E.PAD .TSIP= 1667m) LO^~ WAT~. 4O9 01~.% -w ,,,"' 1-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knoll AUG-13-'91 ~36:01 ):hORDIC RiG 1 TEL riO:': :_334? :4:3;. POi ARCO Alaalm, Inc. '~f' Dally Complatlon/WorKover Report AKa22 13/91 DB/SW W~I~ Il.; II~/ I QI3 Gl mil 2A-16 ge~'J 9738 ~82' MIX~G THIKBAL SYSTEM 7" ~ ~ ~' '~' AND 'A' ~AND~ ~' I; n'~ ~ 1~I 3~ 7.5 ,, , , :0~1~ 12 ~VE ~G ~ 1D PAD TO 2A PAD , , 1~1~ 1,~ PREPARE RI~ ~VE RIG OVER WE~, RIG AGGE~D 1~ Hfl8 8/1WgI .... , 1~1~ ,I ~U C~KE & ~LL UNES~ PULL 1~~ ~0 WU 0~9 WL. RIH WI i ..... ~~ 7.8 MIX ~ BBL 8~T SPACER TO 10 PPG & ~ICK 9AL 8YOTM TO 12,9 PPG ..... , ,, ~ ........... i , RIO ACCEDED ., , , , , , ~ , ,, ARCO Alaaka, Inc. .~' Dally Completlon/Workover Report ,-- . . O0 ... ~ Grm~. Co~ Ca#~ I.erql~ .... ulw ~ m~ "' . . I~ O~ ~u~ ~ W~ , ,. 0 CPF.1 . . . ,,. ,, 1~ CPF. 1 1~ CPF. I i i i i i , ~ ' 'T~ ~ ~ ~ ~m ~ ~ u~ 2 ~ ~/~1~1 . . , 14 4 R~/I~I w~ ~ ..... ~e ~' ~ [T~ v~ {ga~) ........... ~,1~ ~11~ N ~ ....... ~ , ARCO AJMkl, lnG. ~i~ Dilly Completlon/Workover Report . i i i ! il i - .l i ................... ~ ~~lY~ !~ ...... ~.. , , ,~,_..~ , ~'~:~'~ ~'-' ."1;~' ~ " '-~"' ' ' ~, ~* ~ ~ ~ ' m~~ ~ m~ ' " :1~. ~ ?.8 tl/1~ tB · , , r i' _ m m m m '- {- - "'- !-' 27: ~' . 'l~ ~ , _ ~ , ~ ~ - - . , . { : { . . ~,, , ~ ~ ..... ~~~ . , ~ 1., ~ ~ ~L tY~M,~ 1)e ~ ....... _ 1~11~ ~ ~ AT 3 Bffi. 1~ ~ ~~ WE~ ~ FL~. , . ~~. a '~ ~ WAy ~.V~V~ ~ ~ ~ ~ 7-~a,~ m~ ~ . . - 1~1~ '~.0 a~ ~~ ~ 3 B~ 1~ ~ .... ~!~m ~.m m ~ ~ ~ ~ ...... .... mm m m m m' m I mm mm - , ~~ eeL ~ ~ ~A~~ , i i · i . i i i i i i i i i m i i B i i i i J i i ii B i i i i ii Il I m ~ m Il I I I I I I I I II m mi . ~ I .. . I I II II I I - ~ J I mmm I ' , m m · ~ II , , m m , m m mm m m m - " .~. -' m m m m m, m m m m ,mmmmm .mmmmm m m AUG-14-"91 06,:19, ,!,~:~ORDIC RIG 1 TEL NO:956~B347 ~4~ PO1 ARCO Almska, Ino. ~ Delly Oompletlon/Workover Report ARCO AIBt~, Inc. <~ DBIly Completlon/WorRover Report AK~I'~ Oe/tS/gl DB/DS ,2A.16 ~C~II out ~11~ I1~ ~ pull CV f/ 7" ~ ~ I~"~ ~'-~' . ['C' ~D 'A' SANDS ., pu~ ~a 1 ~I/Z" X , --' I; I 12.9 ,,T~ .... ~ ~ .. , ~f~~ ~0-~0 3.0 R~ ~ ~ly 3-1/~ m~l~ ~ul~ RU ~ rm 3.1/~ ~e~ a,em~y. ~0-~0 13.5 PU SSSV to ~0 p~ f~ 15 mln (O~. ~nue RIH w/.re~r ~ ~]/2' tu~. ~0-2~0 1.5 L~ mbl~ ~ RILDS. Press ~e~ ~ ~ ~J s~ ~ 2~ p~ ~ 15 rain (OK~, . Test 858V w/~ psi di~~ f~ 15 rain (~. Test ~nulus ~ 2~pN ~r 15 mtn . . (~a ~o ~i, ~}. . .... ~0-0130 1.5 LD ~1~, S~ BPV, NDfl~,~ ~E. NU 3-1/8' x ~ p~ FMC tree. 1~-02~ 1.0 Pull BPV. S~ te~ ~ug ~d ~ g~ ~ ~ ~i f~ lS ~n (~. ~1t te~ ~ug. 0~0-~0 2.5 RU to d~l~ w~119 ~el. A~pt to ~ well ~ dles~ F~ by vi~s sweep. U~ to ...... ~ ~5~ pa. Giro v~ve ~ ~. R~urge w~l. E~llsh ~~ rate at 20-~ spin ~ 2700 pN. cim v~ve ~ ~. ~urge w~l b~ ~n ~ eft, ~0-~ 1.0 C~I ~ NI~ fine un~ to ~11 ~rcul~bn ~e, RU ~mp in v~v. In Fep~a~n for sll~ line unit. , ..= i i i i .... .. , ,. ARCO Alaaka,/nc. '~' Dally Complatlon/Workover Report CASING / TUBING / LINER DETAIL WEM.: 2A.1 6 ARCO Alaska, Inc. DATE: 8 / 1 s / 9 ~ ~ub~ldi-ry of Atlantlo Rlohflel<:l Company 1 OF 2 PAGE~ # ITEMS '" COMPLi;:i.E DE,~RIPTION OF EQUIPMENT RU'N LENGTH DEI~TH TOPS · 3-1/2'~ ProdUction StHna ' . ..RKB To Tubing Head Flan~le - Parker 141 " 22.00 " FMC 3-1/2" T~bing Hanger, Gert III 5Ksi w/ Double Pin Pup 3.10 22.00 ..... 1 JT 3-1/2", 9,38, J-55, EUE 8rd 'AJ3-Uod, IPC.. T. ubing 31.46 25.10' Space Out Pups 6.10 56.56 59 JTS 3-1/2", 9.38, J-55, EUE 8rd AB-Mo~d, IPC Tubing 1825.82 62:66 Pup Joint, 3-1/2" T[Jbing 10.05 1888,48 SSSV, Ca~cO TRDP-1A-SSA, 8.937" OD, 2.812" ID. 11.05 1891~.53 Pup .J. 0int, 3-1/2" Tubing 10.05 1909.58 29 JTS 3-1/2", 9.38, J-55, EUE 8rd AB-Mod, IPC Tubing' 895.65 1919.63 GLM #11 Camco 3-1/2"X1" KBUG wi DV, BK, 5.359"OD, 2.920"1D 6.54 2815,28 62 JTS 3-1/2", 9.38, J-55, EUE 8rd AB-MOd, IPC Tubing 1'898.83 2821.82 GLM #10 Camco 3-1/2"X1" KBUG w/DV, Bi<:, 5.359"OD, 2.920"1D 6.53 4720.65 19 J'I:'.S 3-1/2', 9.38, J-55, EUE 8rd AB-Mod, IPC Tubin~. -' 591,10 4727.18 GLM #9 Camco 3-1/2"X1" KBUG w/DV, aK, $.$59"OD, 2.920"1D 6.4:8 5318,28 15 JTS 3-1/2", 9'.3#, J-SS, 8rd AB-Mod, IPC Tubing '469.22 5324.76 ' GLM #8 Camco 3-1/2"X1' KBUG w/DY, BK, 5.359"OD, 2.920"iD 6.62 5793.98 13 JTS 3-1./2", 9.38, J-55, EUE 8rd AB-Moa, IPC Tubing 404,8~ 5800.60 GLM #7 Cameo 3-1/2"X1" KBUG w/DV, BK, 5.359"OD, 2.920"1D 6.55 6205.49 13 JTS 3-1/2"; 9.38, J-55, ELJ~ 8rd AB-M(~d, IPC Tubing' 399.72 6212.04 ' GLM #6 Camco 3.1/2'X1' KBUG wi DY, BK, 5.359"OD, 2.920"1D 6.52 6611.76 16 JTS 3-1/2", 9'.38; J-55, EUE 8rd AB-Mod, IPC Tubing 493.36 6618.28 GLM #5 Camco 3-1/2"X1" KBU~ w/DV,'BK, 5.359"OD, 2.920"1D 6.52 71 11.64 13 JTS, 3-1/2", 9.38, J-55', EUE 8rd AB-M(~d, IPC Tubin~ 40'6.47 7118,16 GEM #4 Camco 3-1/2"X1' KBUG w/DY, BK, 5.359"OD, 2.920"1D 6.65 7524.63 , 16 JTS 3-1/2", 9.38, J-55, EUE 8rd AB-Mod, IPC Tubing 491.67 7531.28 ....... GLM #3 Camco 3-1/2"X1" KBUG w/DV, BK, 5~359"OD, 2.920"iD 6.50 8022.95 16 JT$ 3-1/2", 9.38, J-55, EUE 8~'d AB-MOd, IPC Tubing 493.68' 8029.45 .... . Pup Joint, 3-1/2' Tubing 6,08 " 8'523.13 GLM #2, Camco 3-1/2' X 1-1/2", MMG-21 48/64' Check, 8.25 852'9,21 RK Latch, 5.750" OD, 2.,867" ID' . Pup Joint, 3-1/2" Tubing 4.09 8537,46 .1 JT 3-1/~_", cj.3#, J-S6., IEUE 8rd Ag-Mod, IPC Tu..bin~ ...30.42 $~>41,$$ XO 3-1/2" EUE 8rd AB-Mod X 2-7/8" 0.82 .- 8571.97 Remarks: String Weights with Blocks: 49K8 Up, 26K# Do';vn, 6K# Bloc :s. Ran 33 SS bands on 1/4", 0.049" wall SSSV control line. Ran 273 joints of 3-1/2' tubing.. "Uie'd Arctic Grade APl Modified thread compound on all connectiohs. Dri.fted tUbing, ~anger, & Gl'Ms'with 2.860" p. lasti(~ rabbit; 2-7/8" pup & OEJ barrel with 2.330' plastic rabbit. 3-1/2' equipment was new. OEJ barrel was redressed. Stabbed over slick stick on Camco HRP-ISP packer i..a De,owl left tn well ~rom onglna~ completion run on 9/8/85. Nordic Rij~ JJl' Ddlling Superv. isor: CASING / TUBING /LINER DETAIL WELL: ARCO Alaska, Inc. DATE: Subaidlary of Atlantlo Richfield Company 2 OF 2 PAGF..~ # ITEMS COMPLETE DE,~d~RIPTION OF EQUIPMENT RUN LENGTH DEPTH'" TOPS , Pup J'~ir~'t, 2-7/8" Tubing 2.18 8572.79 Camco 2-7/8" O.EJ SBR, .2.297" ID 16.50 8574.97' SBR Space Out 1.00 8591.47 * * * · * * · *Packer and Tail Ur~moved From 9/8/85 Completion ' ' * ' * · · * '' ~" * * * * * Packer, C.~'mco HRP-1SP'PKR, 53K# Shear 7.78 8592.47 1 Jt 2-7)8",6.5#, J-55, EUE, IPC Tubing.. 31.07 8600.25 GLM #1 Camco KBMG-I", DV, BK latch, 5.359"OD, 2.920"1D 6.52 '8631.32 1 Jt 2-7/8",6.5#, J-$5, EUE, IPC Tubing 30.24 8637.84 · AVA Ported Sleeve w/BPI (1.87" ID) .... 2.85 865'~.08 1 Jt .. 2-7/8",6.5#, J-55, EUE, IPC Tubing 31.26 8670.93 XO 2-7/8" X 2-3/8" 1,81 "8702.19 17 JTS 2-3/8", 4.7#, N-80, EUE 8rd, IPC, Tubing 564.54 8704.00 3 Blast Jts, 8R T&"'~,~74S B~tween, 74' Rings f)' §279'-9353 98.84 9268.54 ~Pup Joint, 2-3/8" 4,06 9367.38 Baker LOC w/ 1 Seal & 6.2~' s~al Ass¥ w/6 Seals 0,80 9371.44 Pick Up 1 ff F~r'$~'ace Out ......_ 1,00 9372.2-4 ! Baker Model DB PKR, W/L set AT 9362' on 9/8/85 3.00 9373.24 Seal Bore Extension 4.39 ~'6.24 , XO to 2-3/8" 0.62 9380.63 · Pup Joint, 2-3/8" 8.18 938i.25 camco "D" Nipple w/ 1.812" Profile 1,44 9389.43 PUp .J. oint, 2-3/8" 4.45 9~'90.87 lOfts Shear Out Sub w/.W._I, Reentry Guid~'" 0.76 9395.32 Tubing Tail ~396.08 , Il III I I IIII I I -- I III I I- Remarks: #I ARCO Alaska, Inc. ~O~ Dally Completlon/Workover Report 2A.1~ SM' ~38 ~a~ ' . , w~~ ' ~,~ -. RIO RELEAgED ~378;0~ , ~ ~ ~1~ ]~" ~ I~.'-~ .. '~ ~D ,A' ~ _. 1~0~ WI~M JW0, ~lO -- '~1~ Pure ~ 1 &l~ X I" ~ ~ESEL IN TUBING & ~NULU8 A~VE G~ ~ ~', 12.g P~ ~ ~lS11~7~ THIKgAL BRINE BELOW GLM TO A2 BLAN~NG PLUO ~8t' I '-- / / . , .' · -- , , ....... , ~ * ~ffi 2.0 RU p~p ~ ~' & ~. ~ ~o e~inl u~L ~-1100 ., 3.0 RU ~ls Stl~ llnl. Tlst Iu~t~ ~ 25~ ~i. RIH w~ O~-6 v~ve ~rc v~ve from b~ GLO. U~le to get ~wn bebw 470r b~u. of ~ix~. POH w/M~ ~e. RD sl~ linB u~. i , , _ .. r~e. l~d r~e .m~hed ~1~ bpm ~ 25~ p~. . C~~ r~e in~d ~ 3 b~ ~ 3~ p~. ~~ ~x~ O.9p~ ~8 ~e~ f~M b~ ~4 b~l of 10.5 p~ ~. F~w bd~ ~h Al ~,5 ~S ~f ~ di~~ drc ~ve ~g~ ~ a~. -- _, ~0-0~0 2.0 ., RD 2" ~sa. vanes, ~ ~~ ~. B~w ~ ~if~d ~ ,~e~. BI,~ off ~es~re. ~- . , . .--. , . , . . . ., .. ~ . . . , . . .. ~ . .. L , .., . . . . . . ...... . ,., -- . , ,.. . . . ,i .. . ' ' " , .' ' , . .. ,~_ L_ i L · I , I --,. .... -- , A~ ~a,~, Inc. ~ DiI~ Completlon/Workover Report 'r~--'~ STATE OF ALASKA ~- ' ALASK/~ r~lL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISED OIL~[~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-147 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20042 4. Location of well at surface 9. Unit or Lease Name 1266' FSL, 227' FWL, Sec.13, T11N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1256' FSL, 1179' FEL, Sec.24, T11N, RSE, UM 2A-16 At Total Depth 11. Field and Pool 840' FSL, 1037' FEL, Sec.24, TllN, RSE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 122'I ADL 25570 ALK 2668 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116'No'ofC°mpIeti°ns 08/09/85 08/17/85 08/20/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9888'MD, 6368'TVD 9738'MD, 6260'TVD YES ~ NO []I 1822' feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/LDT/CNL/Cal/Micro, CET/GR/CCL, GR/CCL, GCT 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 104" 24" 234 sx AS II 9-5/8" 36.0# J-55 Surf 3609' 12-1/4" 1100 sx AS Ill & 400 ~;~ Class G 7" 26.0# J-55 Surf 9017' 8-1/2" 500 sx Class G & 1~0 s:~ PFC 5" 15.0# K-55 8728' 9888' 6-1/8" 150 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) 2-7/8" 9401 ' 8,597' & 9378' 9558 ' -9530 ' 9506'-9482 ' w/1 2 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 9348'-9284' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addeldum for fracture data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None SL ,: ,.., *Note: Tubing was run and well perforated 9/9/85. WC3/58:DANI Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. k-. · GEOLOGIC MARKERS NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 9282' 9348' 9447' 9640' TRUE VERT. DEPTH 5953' 5997' 6064' 6193' 31. LISTOF ATTACHMENTS Addendum 30. 'F(~RMATION TESTS .. Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 10/16/85 2A-16 Frac well in 5 stages w/total of 165 bbls diesel. Drilling S~perintendent Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2A-16 Dear Mr. Chatterton- Enclosed is a copy of the 2A-16 Well History to include with the Well Completion Report, dated 09/23/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L104 Enclosure cc- 2A-16 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany ARCO Oil and Gas Company Well History - Initial Report - Daily instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty, parish or borough North Slope Borough ILease or Unit ADL 25570 ITitle Drill Kuparuk River State Alaska jWoII no. 2A-16 Auth. or W.O. no. AFE 904350 Parker 141 API 50-103-20042 Operator ARCO W.I. ARCO Alaska, Inc. -', Spudded or W.O. begUnspudded IDate 8/9/85 IH°ur 1330 hrs. lPr°rs'atu'"aw'°' Date and depth as of 8:00 a.m. 8/lO/85 thru 8112185 8/13/85 8/14/85 Complete record for each day reported 56.24% 9-5/8" @ 3609' 4150' (4046'), Turbo Drl'g Wt. 8.4· PV 6, YP 8, PH 11.0, WL 19.3· Sol 1 Skid. rig to 2A-16, Accept Rig @ 0730 hfs, 8-9-85. Spud @ 1330 hrs, 8-9-85 16" @ 104'. Drl f/104'-496, pmp pill, TOH, chg BRA, LD DP. TIH, drl w/bldg assy to 2004'. Drl & surv to 9-5/8" csg. C&C hole to rn 9-5/8" csg. Rn 88 its 9-5/8" csg, FC @ 3525'. FS @ 3609'. Cmt w/ll00 sx AS III & 400 sx Class G. CIP @ 1107 hrs, 8/11/85. ND Div, NU BOPE & tst. Drl & LO. Tst to 12.5 ppg, round trip. Turbo Drl'g. 710', 6.7°, S31.6E, 709.5 TVD, 11.43 VS, S10.01, W5.61 1540', 28.2°, S35.SE, 1481TVD, 302 VS, S252, E167 2200', 46.3°, S36.1E, 2007 TVD, 695 VD, S581, E382 2607', 54.2°, S30.5E, 2262 TVD, 1012 VS, S850, E550 3382', 53.3°, S34.5E, 2721TVD, 1636 VS, S1376, 886E 9-5/8" @ 3609' 6923' (2773'), Turbo Drl'g & Surv Wt. 9.5, PV Turbo drl & 3755', 52.2° 4411', 58.8° 4882', 55.4° 5254', 56.0° 6095', 55.7° 6346', 56.5° 14, YP 11, PH 9.0, WL 7.4, Sol 9.2 surv & correction runs. , S35.7E, 2947 TVD, 1933 VS, S1620, E1054 , S39E, 3322 TVD, 2470 VS, S2049, E1379 , S34.9E, 3588 TVD, 2857 VS, S2359, E1612 · S34.7E, 3797 TVD, 3164 VS, S2611, E1787 , S31.7E, 4269 TVD, 3860 VS, S3179, E2190 , S32.5E, 4409 TVD, 4068 VS, S3355, E2300 · 9-5/8" @ 3609' 9030' (2107'), Pmp Hi-Vis Pill WT. 9.7, PV 9, YP 6, PH 8.5, WL 7.2, Sol 10.6 Turbo drl, corr drl to 7" csg PT. CBU 40 std wiper trip. HI-Vis sweep. 6658', 57.3°, S33E, 4580 TVD, 4330 VS, S3577,.2441E 7440', 57.5°, S35E, 5003 TVD, 4987 VS, S4118, 2813E 8094', 58.9°, S33.8E, 5343 TVD, 5546 VS, S4578, 3131E 8408', 58.8°, S36.6E, 5505 TVD, 5815 VS, S4797, 3286E 8955', 56.8°, S37.5E, 5796 TVD, 6278 VS, S5173, 3558E RECEIVED D,:..,, o !985 Ab~ska Oil & Gas Cons. Commission Anchorage The above is correct Signature For form preparation and ~[]istribution, see Procedures Manual, Section 10, Orillin~ Pmo~_~ RR mncl R7 ITitle Drilling Superintendent ARCO Oil and Gas Company,~,'~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show Iorrnation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less trequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Alaska County or Parish IStare North Slope Borough Lease or Unit ADL 25570 Kuparuk River Alaska IWell no. 2A-16 Date and deptl~ as of 8:00 a.m. 8/15/85 8/16/85 8/17/85 thru 8/19/85 Complete record for each day while drilling or workover in progress 7" @ 9017' 9030' (0'), Setting Pack-off WT. 9.7, PV 10, YP 4, PH 9.0, WL 7.2, Sol 10.3 Fin circ Hi-Vis sweep. LD 5" DP. PU & broke kelly. LD 5" DP, 5" HWDP, DC's Gearhart, TML & Turbine. Chg rams to 7",& press tst'd. RU GBR to rn 7" csg. Rn 208 jts 7", 26#, csg w/B&W FS @ 9017' & BW FC @ 8929'. RU cmt head, C&C mud & hole. Pmp 60 bbls Dowell spacer 3000 ahead of cmt. Mix 500 sx CL "G" cmt, bmp plug w/3000 psi. CIP @ 0415 hrs, 8/15/85. PU stack, set slips & chg rams. Tst packoff to 3000 psi. 7" @ 9017' 9100' (70'), TIH w/Bit #6 WT. 11,3, PV 17, YP 15, PH 10.5, WL 8.0, Sol 16 NU BOPE, LD 5" kelly & PU 3½" kelly. Press tst all BOPE. Pulled tst plug & set wear bshn'g. SLM on TIH w/bit, tagtd FC @ 8929'. Press tst'd 7" csg to 3000 psi, drl'd plug, FC, cmt & FS. Made 10' new hole f/9030'- 9840'. Chg'd over to new mud. Rn leak off tst, 880 psi EMW. Drl f/9040'-9100'. Pmp pill, TOH, MU BHA, TIH. 7" @ 9017' 9888' (788'), Circ 30 BBL H-VIS SWEEP WT. 11,0, PV 16, YP 15, PH 9.5, WL 6.5, Sol 15 TIH , drl f/9100'-9687'. Losing mud, cut mud wt. to 11.1 ppg, circ & mix mud, add'd Quick Seal to mud. Drl f/9687'-9888'. CBU. Made 10 std short trip. Circ H-Vis sweep to cln hole. SLM on TOH, not correction. RU SCHL to log. RIH, w/DIL/GR/SFL t/ stopped @ 9530'. POOH, chg hole finder f/wheels. RIH, tool Stopped @ 9530', POOH. TIH to 7" shoe, cut drl in, TIH to 9500', ream'd f/9500'-9608'. Made 10 std short trip. Circ & spot lube 106 pill, TOH to log. Log w/DIL/SFL/SP/GR/LDT/CNL/CAL /MICRO to 9870'. Chg out tools. RIH w/SCHL RFT tool, stuck in csg @ 8960', got loose. POOH, RD SCHL, TIH, broke circ @ shoe, ream to btm. CBU, pmp Kwik Seal, mix mud. Made 10 std short trip. Tight f/9629'-9598' & f/9441'-9379'. C&C hole, pmp 30 bbl H-Vis Sweep. RECEIVED Alaska Oil & 6as Cons. Commissio. Anchorage The above is correct Signature For form preparatiOn'and Jd~str~bu'ti~'n see Procedures Manual S~ction 10, Drilling, Pages 86 and 87 Date / I-1,~ -,~ ~ ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following selting of oil string until completion. District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25570 Date and depth C6mplete record for each day while drilling or workover in progress as of 8:00 a.m. 8/20/85 IStale Alaska JWell no. 2A-16 5" lnr f/8728'-9888' 9738' PBTD, LD 3½" DP WT. 11.0, PV 16, YP 6, PH 9.5, WL 6.9, Sol 14 Made 10 std short trip. Spotted lube 106 pill, TOH. RU to rn 5" lnr. Rn 31 its 15#/ft, K-55 5" lnr, rn 3½" DP w/5" lnr. Set FC @ 9812', TOL @ 8728', FS @ 9888'. CBU @ shoe, C&C mud f/5" lnr, cmt job. Pmp 15 bbls Dowell Spacer 3000' ahead of cmt. Mix 150 sx CL "G" cmt. Disp w/Dowell, pmp & bmp plug w/3500 psi. Bled off press, floats held OK. Rotated off nr, LD 3½" DP, TIH to 2000', chg'd to 10.3 brine wtr, LD DP. RECEIVED Alaska OJj & Gas Cons, Anchorac~e The above is correct Signature For form preparation and distri~ltion see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate Title 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 it space is available. I Accounting District County or Parish I State Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25570 Auth. or W.O. no. Tit e AFE 904350 Drill Parker 141 API 50-10320042 COSt center code Alaska JWell no, 2A-16 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 8/9/85 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W,O. I 1330 hrs. Date and depth as of 8:00 a.m. Old TD Released rig Complete record for each day reported 8/21/85 1500 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowin~ Potential test data 7" @ 9017' 9738' PBTD, RR Information not available. LD 3½" DP & DC's. RIH w/20 its 3½" DP, w/closed TIW vlv on btm to displ fluid. LDDP, chg rams to 5", ND BOPE. NU wellhead, Release Ri~ @ 1500 hrs, 8-20-85. New TD Date 8~2o~85 Kind of rig IType completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Rotary Well no. Date Rese~/oir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and c~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Superintendent ARCO Alaska, Inc. _ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 . RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 11-19-85 TRANSMITTAL NO: 5452 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE REC~:IPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ CET'S/ ONE * OF EACH 1R-4 J 09-22-8.5 2A-16 -- 09-05-85 2Z-12 j 09-24-85 3C-2~'' 09-30-85 3J-2 ~' 09-19-85 RUN #1 6755-8302 RUN #1 8643-9808 hUN #1 7800-9330 KUN ~1 4750-7440 RUN ~1 7647-9338 RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M DRILLING*BL L. JOHNSTON MOBIL NSK CLERK*~L DiSTRIDUTION: +~. PASHER LXXON PHILLIPS OIL J. 'RATHMELL DATE: STATE OF ALASKA*BL SOHIO /SE UNION VAULT/ANO*FILMS ARCO Alas~,a, Inc. is a Subsidiary o! AtlanticRichfiel~lCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 16, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2A-16 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L187 Enclosure RECEIVED G~ ~,ens. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA --- ALASKA(, _ AND GAS CONSERVATION CO, vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-147 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20042 4. Location of well at surface 9. Unit or Lease Name 1266' FSL, 227' FWL, Sec.13, T11N, RSE, UM JLOCA'Ji©;'-'G! Kuparuk River Unit At Top Producing Interval ! VE',;iFI~-Di~, i 10. Well Number 1256' FSL, 1179' FEL, Sec. 24, Tl1,, R8E, UM i Surf._~/__-/ 2A-16 B. H.._j~[ 11 Field and Pool At Total Depth : ........... · 840' FSL, 1037' FEL, See. 24, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi I Pool 122' RKB] ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 08/09/85 08/17/85 08/20/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9888'MD 6368'TVD 9738'MD 6260'TVD YES ~ NO []I 1822 feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/LDT/CNL/Ca]/Micro, CET/GR/CCL, GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 62.5# H-40 Surf 104' 24" 234 sx AS il 9-5/8" 36.0# J-55 Surf 3609' 12-1/4" 1100 sx AS III & 400 s~ Class G 7" 26.0# J-55 Surf 9017' 8-1/2" 500 sx Class G 5" 15.0# K-55 8728' 9888' 6-1/8" 150 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) 9558' - 9530' 2-7/8" 9401' 8597' ~ ~7~1' 9506' - 9482' w/12 spf 9348' - 9284' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OI L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .o.e R-ECEIVED Alasi(a 011 & Ga~ Con~ C~mlssio,'~ A~ehorage Form 10-407 * NOTE: Tubing was run and well perforated 9/9/85. ' TEMP2/WC23 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - ~' "GEoLoGic MARK'ERS' ':' FORMAT-iON TESTS NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase· Top Upper Sand 9282' 5953' N/A Base Upper Sand 9348' 5997' Top Lower Sand 9447' 6064' Base Lower Sand 9640' 6193' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies), Well History (Completion Details) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date // I 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 supplc:~n.~ntal ~cords for this well should show the details of any multiple stage cement- lng and the location ~Of:;.t~e~c~g tool. Item 27: Method of Opera~ion'-Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are starled. Daily work prior to Spudding should be summarized on the form giving inclusive dates on'ly. District Alaska Field' KuparukRiver Auth. or W.O. no. AFg 904350 Nordic 1 ICoun~, parish or borough North Slope Borough Lease or Unit ADL 25570 Title · · Completion State Alaska Well no. 2A-16 AP1 50-103-20042 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth aa of 8:00 a.m. 8/31/85 thru 9/03/85 9/04/85 9/05/85 9/06/85 IDate 8/30/85 IH°ur Complete record for eaGh day reported 2200 hrs. IARCO W.I. Prior status if a W.O. 56.24% 5" @ 8728'-9888' 9825' PBTD, Log'g Wt. 10.7, PV 8, YP 6, PH 9, WL 19.2, Sol 16 Accept ri~ @ 2200 hrs, 8-30-85. ND tree, NO & Cst BOPE; OK. 6-1/8" bit on 3½" DP. Circ out 10.3 brine w/10.9 mud. RIH, tag @ 8733', C&C 'mud, tst liner to 3000 psi; OK, TOE. RIH w/4-1/8" bit, cln out to 9688', drl cmt f/9688'-9825', tst liner to 3000 psi; OK, POOH, RU WL, RIH w/CET/GR/CCL. 5" @ 8728'-9888' 9825' PBTD, MU BHA Wt. 10.7, PV 8, YP 6, PH 9.5, WL 18.4, Sol 16 RIH w/CET log; did not go past 9175'. POOH, add 300# wt bar & RIH; did not go past 8921', POOH. Rn 6-1/8" bit & 7" scrprs to TOL. Revr out, CBU, POOH. , rev circ, 5" @ 8728'-9888' 9825' PBTD, RU SOS Wt. 10.8+, PV 10, YP 5, PH 9, WL 18.4, Sol 16 Rn 4-1/8" bit & scrpr, tag @ 9698', circ to 9828' POOH. 5" @ 8728'-9888' 9825' PBTD, Chg to Brine 11.0 Brine RU WL, rn CET/GR/CCL f/9812'-8715'. Rn GR/CCL f/9812'-8500', rn GCT f/PBTD to surface. RD WL, rn 4-1/8" bit on tapered string to PBTD. Attempt to displ mud to brine, encounter pmp problems, chk pmp. RECEIVED OCT21 Alaska Oil & Gas Cons. CommissiOrO.cc Anchorage The above is correc~;,.~ 'gnu \ For fo}m preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JTitle Drilling Superintendent tRC 3 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. Accounting cost center code District Alaska Field North Slope Borough State Alaska County or Parish Lease or Unit I Well no. Kuparuk River ADL 25570 2A-16 Auth. or W.O. no. T t e AFE 904350 Completion Nordic 1 Operator ARCO Alaska, Inc. API 50-103-20042 A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Complete 8/30/85 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD 2115 hrs. I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our I Prior status if a W.O, 2200 hrs. I 9/07/85 thru 9/09/85 9/lO/85 Released rig 5" @ 8728' TOL 9825' PBTD, Tst Upper Pkr 11.0 Brine Fin disp hole to 11.0 ppg brine, POOH, RIH w/3-3/8" csg guns, & perf 12 SPF f/9530'-9558', f/9482'-9506'. Perf f/9284'-9348' w/2 equiv 6 SPF ms. Rn 4.125" GR & JB. Rn & set perm pkr @ 9362' WI~M. Rn 17 its 2-3/8", 4.7#, N-80, EUE 8rd tbg, & 278 its 2-7/8", 6.5#, J-55 EUE 8rd tbg. Sting in, space out, drop ball, rn 1-3/4" tool to push ball to SOS. Did not go past AVA sleeve. Rn tapered end; did not go past SOS. Attempt to press-up; would not go. Rn ½" stinger thru SOS & sheared pins on SOS. pull Orifice vlv, SL sheared. Fsh K-O tool & Orifice vlv, rn 2-3/8" SV in "D" nipple. Set pkr, shear SBR, rerun 2-3/8" SV. Press to 3500 psi, tst annl & pkr; OK. SSSV @ 1822', retry pkr @ 8597', AVA sleeve @ 8673', perm pkr @ 9378', TT @ 9401'. 5" @ 8728' TOL 9825' PBTD, RR Diesel Tst pkr to 2500 psi; OK, tst SSSV; OK. Set BPV, chg rams to 3½". ND BOPE, NU tree & tst to 5000 psi; OK. Displ to diesel, RR @ 2115 hrs, 9-9-85. New TD Date PB Depth 9825' PBTD K nd of r g Rotary 9/9/85 Classifications (oil, gas, etc.) 0il Producing method Flowing Type completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Etfective date corrected The above is corre~.t...,, For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ITitle Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2A-16 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2A-16. I have not yet received the Well Histories. When I do, I will forward copies to you. Also, the bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is received. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L118 Enclosure / ECEIVED Alaska ~Ab~'as Cons. ¢'°rnmissiot~ uChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany -. -. STATE Of ALASKA ALASKA ~ AND GAS CONSERVATION CC~j?llSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~× GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-1/+7 3. Address 8. APl Number P. O. Box 100360, Anchorage~ AK 99510-0360 50- 103-200/+2 4. Location of well at surface 9. Unit or Lease Name 227' F~/L, 1267' FSL, Sec.13, T11N, R8E, UM (approx) Kuparuk River Uni~: At Top Producing Interval 10. Well Number To be submitted when gyro is received. 2A-16 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0ii Pool 12/+' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 08/09/85 08/17/85 08/20/85* N/A feet MSLI 1 17. Total Depth (M D+TV D) 9888 ' ND 18. Plug Back Depth (MD+'DVD) 9738 ' MD YES19' Directional Surveyi_~X NO [] I20' Depth where SsSv set1822 feet MD I21 ' Thickness °f Permafr°stlS00' (app rex) 22. Type Electric or Other Logs Run DI L/SFL/SP/GR/LDT/CNL/Cal/Ricro~ CET/GR/CCL~ GR/CCL~ GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 62.5# H-/+0 Surf 10b,' 2/+" 23/+ sx AS II 9-5/8" 36.0# J-55 Surf 3609' 12-1//+" 1100 sx AS III & b,00 s: Class G 7" 26.0# J-55 Surf 9017' 8-1/2" 500 sx Class G 5" 15.0# K-55 8728' 9888' 6-1/8" 150 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) 9558' - 9530' 2-7/8" 9/+01' 8597' & 9378' 9506' - 9/+82' W/12 spf 93Z~8' - 928/+' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ECEi /ED Alaska 0Jj & Gas C0ris, C0r,-~rnJssJ0~ Anchorae~ Form 10-407 * NOTE: Tubing was run and we]] perforated 9/9/85. TENP2/WC23 Submit in duplicate Rev. 7-1~80 CONTINUED ON REVERSE SIDE 29. 30. · : . . GEOLOGIC MARKERs : ~ ~ :FO:RMATION TESTS . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/^ N/^ . 31. LIST OF ATTACHMENTS Nope 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed___ (~ ~ ~.~ ..... Title Associate Engi,eer Date ~'*,.~'~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log':on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this Well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Post Office B~ 00360 Anchorage, Ai~"~a 99510 Telephone 907 276 1215 September 13, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the August monthly reports for the following wells: 2A-15 3C-7 1R-14 6-9 (workover) L1-2 L3-5 2A-16 3J-1 1R-15 6-10 (workover) L1-14 WSP-4 3A-1 3J-2 1R-16 9-30 L2-20 WSP-6I 3C-4 1R-1 2Z-9 9-31 L2-24 WSP-20 3C-5 1R-2 2Z-10 11-9 (workover) L2-26 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L62 Encl osures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA G~ AND GAS CONSERVATION CO~,,.~/IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS II. Drilling wel~x~[] Workover operation [] :2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-1z~7 3. Address 8. APl Number P. 0. Box 100360~ Anchorage, AK 99510 50- 103-200~2 4. Location of Well atsurface 227' F~L, 1267' FSL~ $ec.13~ T11N~ R8E~ UN (approx) 5. Elevation in feet (indicate KB, DF, etc.) 12#' RKB 6. Lease Designation and Serial No. ADL 25570 ALK 2668 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2^-16 11. Field and Pool Kuparuk River Field Kuparuk River Oil For the Month of August ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1330 hfs, 8/9/85. Drld 12-1/~" hole to 3630'. Ran, cmtd~ & tstd 9-5/8" csg. Drld 8-1/2" hole to 9030'. Ran, cmtd, & tstd 7" csg. Drld 6-1/8" hole to 9888'TD (8/17/85). Ran logs. Ran~ cmtd, & tstd 5" liner. PBTD = 9738', Secured well & RR ~ 1500 hrs~ 8/20/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-~0, weld conductor set ~ 10~'. Cmtd w/23~ sx AS I1. 9-5/8"~ 36.0#/ft~ J-55~ BTC csg w/shoe ~ 3609'. Cmtd w/1100 sx AS III & ~00 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 9017'. Cmtd w/500 sx Class G, 5", 15.0#/ft, K-55, FL4S csg f/8728' - 9888'. Cnfcd w/150 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR/LDT/CNL/Cal/Micro f/surface - 9870' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repor~on/I this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the AlasAa Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 TEMP2/MR06 Submit in duplicate ARCO Alaska, Inc. Posl Office :~..,,~ 1003G0 Anchorago, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALAbKA, INC. KU PAl(UR OPERATIONS RECORDS CLERK ,~YU- 111SS P.O. SOX 100360 ANCHORAGE, AK 99510 DATE: 08-30-85 TRANSMITTAL NO: 5317 ENGINEERING. TIgtNSMIT'±'ED IIERE%{ITii ARE T}tL FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN ItOLE LIS TAPES AND LISTING/SCHL/ONE COPY' OF EACH 2Z-9 08-11-~5 RUN 91 3487.0-7357.0 REF # 70730 2Z-10 0~-04-85 RUN #1 3790.0-7866.0 REF # 70712 3~-8 07-23-85 i<UN #1 5184.0-10065.5 REF # 70683 1I{-16 08-19-85 RUN #1 4062.5-8463.5 REF # 70754 1R-15 08-12-85 RUN #1 3788.0-7442.5 REF # 70738 1R-14 0~-06-85 t<UN #2 4602.0-'9158.0 REF ~ 70726 2A-16 08-18-85 RUN #1 '8979.0-9789.5 R£F # 70753 2A-14 07-28-85 RUN #1 7170.5-7871.5 R£F # 70705 2A-15 0~-0~-~5 RUN #1 7420.0-8142.0 REF # 70731 PLEASE ACKNOWLEDGE . I<I~CEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE DRILLING W. PASIiER B. CURRIUM L. JOHNSTON EXXON CIIEVt{ON I,~OB 1 L PIIILLIPS OIL D & [,i NSK CLEI<K J. RATilI,IELL SOHIO UNION K. TULIN/VAULT AlriC~ Alaska. Inr ;~- a Rllb$idiar¥ o! AflanlicRir;,I,; ' ' " STATE OF ALASKA ALASKA'I:TfL AND GAS CONSERVATION C~::::~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-147 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20042 4. Location of well at surface 9. Unit or Lease Name 1266' FSL, 227' FWL, Sec.13, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1256' FSI, 1179' FEL, Sec. 24, TllN, R8E, UM 2A-16 At Total Depth 11. Field and Pool 840' FSL, 1037' FEL, Sec. 24~ T11N~ R8E~ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 122' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 08/09/85 08/17/85 08/20/85*I 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 21. Thickness of Permafrost 9888'MD 6368'TVD ;9738'MD 6260'TVD YESx~ NO[]I 1822 feetMD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/LDT/CNL/Cal/Micro, CET/GR/CCL, GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD 'AMOUNT PULLED /~/~ 62.5# H-40 Surf 1u~' 2~" 234' sx AS II . ~-b/u" ,~b.U# J-55 Surf 3609' 12-1/4" 1100 sx AS Ill & 400 sx Class G /" 26.0# J-55 5urf 9017' 8-1/2" 500 sx Class G & 180 sx Permafrost C b" 15.U# K-55 8728' 9888' 6-1/8" 150 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) 9558' - 9530' 2'7/8" 9401' 8597' & 9378' 9506' - 9482' w/12 spf 9348' - 9284' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAs-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Tubing was run and well perforated 9/9/85. JG/W.,..i~.Q~)~C~i,.._:.~,~, 0i! -P~ G~$ P:'i? ....... Form 10-407 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 9282' '5953' N/A Base Upper Sand 9348' 5997' Top Lower Sand 9447' 6064' Base Lower Sand 9640' 6193' ,L,ST, OF) ooenoum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ,~_~ ~,(J~_J~ Associate Engineer- Signed Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 7/29/86 2A-16 Arctic Pak w/30 bbls PF "C", followed by 60 bbls Arctic Pak. '-DriI/ing Supervisor $UB-~URFACE DIRECTIONAL ~URVEY ~-~ UIDANCE F~ONTINUOUS [~OOL Company ~co A.TuASY~ INCORPOP~TED . Well Name 2A-16 (~12,66' FSL; 2,27' ~[,, [}13. TllN. l~lE. IT~3 Field/Location K~.~., .O~T~ sLoP~., A~As~ _ Jol~ Reference No_. Date. ~o~,.~ RECEIVED bo,qaecl 8~. ~T[~, l ~ Computed ~0~ B~BA GCT DZR£CTtONAL SURVEY CU$?O~£R hISSiNG FOR ARCO AbASKA, INC, KUPARUK NORTH SLOPE,ALASKA $URVI~¥ DATI~I 05 SEP ft5 ~NGI:NIC~Ri D., 8ARB,'k METHODS OF CONPU?ATZON ?002 EOCATZONZ ?ANGRNT:I:Ab- averaged devJet~on and azimuth TNTIECRPO[,,AT]:ONi EZNICAR VIF..R?Z~A[, $[CC'T.ZONZ HERTZ, DJ:ST, PROJgCTED ONTO A TARGET' AZ]:IqUTH OIr SOUTH 33 DE:G 48 N:I:N EAST COHPUTA?ZON DA?El 18-8EP-$5 PAGE ~22,00 2no~.oo 1864 2~00 28OO 2900 3000 3100 3200 3300 3400 3500 3600 3900 O0 19t9 O0 201 O0 2071 O0 214 O0 2 I oo ~ O0 2317 00 2376 00 2435 O0 2494 tO 2372 10 53 57 O0 2553 14 2431 14 53 42 O0 2612 O0 2671 O0 2731 O0 2 ~ oo ~ O0 ~ oo ~ O0 303~ 32 32 53 42 ~850.98 36 2910o03 55 2? S 37 16 E 547.56 $ 37 21 E 683.65 8 37 30 E 759.52 S 37 39 E 834 69 8 37 49 E 9t4 85 8 38 2 ~ 995 98 8 37 59 ~ O76 82 55 S 38 4 E 1 26 $ 38 25 E 1479 $ 38 36 ~ 1560 $ 38 40 E1640 8 38 47 E 1719 $ 4O 957 ~ 38 4 £ 2037 lO 6 82 09 ~o~ , 544 68 S 415 603 460 ,, 556 2? 0 40 0 0 0 0 0 14 8 29 $ 42 $ 606 29 $ 89 $ 75 614 916 68 E 997 E 1079 57 1644 56 ~ 724 0 06 14,4.62 i ' ~ ' "'"ii ' oo .~.oo o° ,°, ~ i g; g' .oo ½goooo°° ,og -,~.oo ~ o,oo oo,oooo ,,,.oo 0.76 . o, Igg. O0 798 65 676.65 10 15 90 42 ?74.42 14 19 ~ [ I~'23 1.61 ~ ~ 1.92 ~ ~4 110o llgg gg ,o~,.,o ~, I · .,~,,, o, ,o..,o 5t2,47 ,:16 386, ARCO ALASKA, INC, DATE OF SURVEYS 05 SEP 85 2~-16 Kgbb¥ BUSHING KUP~RUK NORTH SLOPE,ALASKA ENGIN~ERI De BARBA INTERPOLATED VAt, U£$ FOR EVEN 100 rg£? OF NERSURED DEPTH ,,,,.~o v,,,~,, v,.,,c,, o,v,,,,o. ,,,..,. ,,~,~o. ,,v,.,,, .o.,,,,ou,. ~,.,.., ~EDEPTH DEPTH DI£PTH~ DEG MIN DEG MIN FEET DEG/i00 FEET FEET COHPU?A?ION DAT£1 lfl-$EP-85 PAGE ARC~ AbASKA, ?NC. DATE Or SURVEY/ 05 5~P 85 KUPARUK ZN?~RPD~A?£D VA~£$ ~OR EVEN 100 ~T OF ~ASUR~D D~P?H DEPTH D~PTH DE' !# DEG #IN DEG MTN FEE? DEG/IO0 FEE? FEET DEG 4200 0 1191, 1~ 29 t253. ]13i, 56 2370.14 0.15 1873~ i 60 4~oo o oR ~o9.o~ ~87.~6 ~ ~ 1563, 47004600 00~ 3471,28 14 3155 3299,14 55 51 ~ ~ 22 E 2618.20 2,49 2070 1614, 2?8] 0,i4 ~204 l?lO, i 2,0o ~759. 5100 00 1645,50 3921,50 56 10 5200 0 3756. 3634 ~6 ~6 34 8 ~ · 3032.17 0,60 _ i886, 5300 O§ '8'1o 3689'46 56 ~0 ~ I ~ .59 0.26 ~ 1904. E~ 't22,44~0~9'04 · 3205,78 5400.0 3866. 3?44.93 56 39 ] 5900.005800'05700'05600'0055000~0~ 4088.,44032'274~44.4139'6'74''9~1'5~ 40223966'1439~0'~73854'74~799.'4150 55 565549 56 5654~i S ~8~ ]~ 24 ~ ~5851. !. 3697°733780.5636~5'083532'2244'6~°t3'82 00.2,0.290'3!i.7,~.2055 294628?828'!274426'7 '70.2904 i 74 ~56$$$ T245.2~98'2~49'2~00°205~'0! i '622.~0,953,704.713589"$9'456'053372'7265 o§ I 3154 73~407! $870 31 · 4037 6400~0 4420 {0 4298,{0 97 iv § os 11 E 4198 97 {362 36 o 2525, 4205 8 0 2620, 4374 O0 6800 00. 4634 12 42 $7 45 S 34 ~? 6900 oo 4687 ~ 45 22 ~£ 4937,114452 ~5 o° ~572, 2668, 4458 48 7000 O0 4741 77 4619,72 57 27 7tO0 O0 47.95. 32 4673,32 57 36 7200 O0 4848 57 45 300 400 7500 7600 7700 7800 7900 O0 4902 O0 O0 5050 O0 5111 oo 516t O0 S2tl 8 34 ~ ~ 46 4726,?! $ 34 40 E 4790:28 4780,13 57 46 8 34 8 E 4874.82 4833,'37 57 53 S 34 £ 4~59.46 4986,16 58 26 $ 34 i~ E 5 44,18 4938.05 58 57 $ 34 13 ~ 5129.87 4989.~7 59 29 S 34 t3 E 5~$,~5 508~,53 60 . S 34 34 E 5~88,80 ARCO AbASKA, ?NC. KUPARUK NOR?H SLOPB,AbASKA CONPU?ATION DA?El 18-8£P-85 DATE Or SURVEy! 05 KELb¥ BUSHING I:bEVA?IONI 122,,00 ENGINE:ERI D. BARBA N£ASURED VERTICAL VER~I~ DEV,A?~ON A~INUTH . SECTION 8EVERI?¥ NOR?H/SOUTH EAST/,ES? Di~t; ;TNUTH , ~ 8000 O0 8100'00 8200 O0 8300 O0 8400 O0 8500 O0 8600 O0 8700 O0 8800 O0 8900 00 9000 O0 9,00 9200 9300 9400 95O0 9600 9?00 9800 9888 O0 O0 O0 O0 O0 O0 O0 O0 O0 59 ~3 ~ ~44? 5480~S0 · 5566,63, ~363,!~ . ,24 4 8~'14 414 52~ ~ 2' '5 24 5647. . 4~5 .85 ~ 3245.55 5733 45 42 4621'40 ' 5738,?$ ~465 5~ t6 ~ 35 5~ ~ 56 O' 5'647835 ' 7253~'3857..~4 ~!20 8636~~ 5~1940, '!!9' 70'4 .~4,! 5824.~? 31611 .47 lO S 36 19 ~ 5905 21 4 9 ,?0 S 3445, .05 , , , 34950 36 ~! ~ 5990 483 ~ $9t0.~3 ~567 89 54 .89 54 !i 4~6~ · 3546. 59~6'S0 6i9 84 54~ ~8 38 37 , . ,.97 ' 6081.93 ~672 11 ~ 6076. 490 .27 3598. 37 6'61 36 49 ,97 ~650, . .67 57 59 $ '7 46 E '89 5038025 $ '702. 6412 5 70'83 .27 ~ 3753,8 · . · , 3803, 64~8,42 965 1! Se ~ 45 30 ~ 6489 ,57 384S, 6495,92 6564 · 3880, · * 6$69,83 ~03 ~ 48 ~ 24 16 · 9~ e98 3910, 6642,4! . 21 42 ~ 1 ' ' 65,2 6oi 4e ~304'54 6t~ 5444 a? ~ I~41 ~691~6953' ,.8 5~? ~ 3989. ~ 6786.9-26e~6,85 367 53 62 $ 53 44 27 $ lO 41 ~ 6975 ~ .00 5 48 · , 074 4004. . .00 5~06.12 ~ · 4015, 6977.60 ' ARCO ALASKA, TNC. DATE OF SURVEY! 05 SgP es . 2A-t6 KELLY BUSHING EbEVATIONI ~22.00 KUPARUK NOR?H &LDPE,ASASKR ENGtNEERI Dp BARBA IN~£RPOLA?ED VALUES roe EVEN lO00 FEET Or #EASURED DEPT MEASURED VERTICAL VERTI b DEV! a. IMUTH SECTION SEVERITY NOR?H/SOUTh DEPTH DEPTH DEP 1319.00 4000.00 3087 39 2965 40 37 12 2120.~9 0:40 ?5.84 99 , 29S6.01 6000.00 ?000.00 o 4627.t2 4521.33 9888.00 COMPUTATION DATEz ~8-$EP~85 PAGE ARCO A~ASKA~ TNC. DATE OF SURVE¥t 05 SEP 85 2A-16 KELbY BUSHTNG ~EVATION{ 122,00 KUPARUK NORTH SLOPE,ALASKA ENGTN~ERI D. RARBA INT£RPOLATED VALUES FOR EVEN 100 FEET or SUB-SEA DEPTH T~UE SUB-SEA COURSE VERTTCAb DOGb£G RECTANGULAR COORDINATES HOR/:Z' e! DEPARTUR! MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST D~I~.~ AZIMUTH DEPTH DEPTH DEPTH DEG MTN DEG ~TN FEET OEO/100 FEET FEET FEE~ OEO ,oOOoooo **°°°'*-, .' OOoo !. ooo oo i'ol i ½1~ ~oo°° ~' ~, o. oo o o,~°° ~ °'~i°'°° [ oD2~ ,o OD ~ , ~ ~ : ·i " O0 20 ,00 u 75 24 ~ 'I.35 99 ~ 0. 0, 4 2 01 42 30 .00 i 67 27 .07 ,O0 7]] 48 72~ O0 O0 60~.00 ~ ~ 29 g .3S 54 ~ ':4494 54 82 74 822 O0 70 5~ S ~3 22 ~ ~ 9, .00 i0 27 ~ 24 61 .55 3 92 2, 33 S l~,42 ,~ 7~.o6,~ [ ~I:°' , 41 [~!6684 '9182~22120000 [ uO0~'O0oO0, oo'O02224~ 24t~!.g7 74 i ! !~26 }! ~~,t.i~iI '9586 ~ ;! .22 95 9280 ,,~, ~o I,~ l'°g'°° ~ ~' ' ~39 212,42 95 52~ O0 ,0 2842 3847 . 267.51 94 i 125608 ~ 267: ~ t O0 l~ 93 ,~o~ ,o I~! oo l'°g'°° '~ ~ 50 30 18 ~ 28 §38 321,44 52 l~ 74 72 O0 ~ 6! ~ ~ ~o~ oo ,~oo.oo ,. ~o ~, ~ OD ~,oo.oo ~, o, ~ ~ ~ OD ~oo.oo ~, O0 3384,~ 2722 355i, 2822 3716.21 2922 3022 3882 42 3122 ~06; 24 4423 4601 4779 4957 5137 5319 01 15 33 ~4 3422 61 3522 83 3622 7513 3382~72 2600 O0 53 21 00 2700 O0 53 4 ~g ~oo OD O0 O0 5452 O0 3000 O0 56 41 O0 3100 O0 56 00 3200 00 56 i O0 3300 O0 55 O0 3400 O0 5548 O0 3500.00 56 3 O0 3600,00 5633 O0 3700,00 5632 37 ~ 23 3.25 475 80 695.19 3,18 553 86 88 362 84 598,36 696,5t 17 19 1222,40 38 ~ 1357, 0,44 t077 65 829 85 1184 51 914 35 1496,36 1492. 0.~1~ SS ~ i360.14 S 38 8 38 54 ~ 1627, 1760.86 ~:~7 1394'2903243 ~ 998 80 i '631.73 1082 ~6 i765,20 ~249, 2 ~ ~896 ' 2028 S 37 217~. ~] ~37 55~ 0.,'t { i717 ~~ 1340. 2179 232],65 0,j~g 1836 ~ 1432, E 39 37 55 2472, i ~4;8 8 36 20 ~ ~ ..0.30 1954 '524. t; ' 2619, 2,'41 20~1 ~ 4g i6i4,94 2626 3557 ~ Oelt ~19082 0e'42 231040 ~1787~~~700'886 35 50 ~ 3214,88 0,24 2554 65 ~ 1874, i962, E {221 ARCO AbASKA, ZNC, 2A-16 KUPARUK NORTH SHOPE,AbASKA COMPUTATION DATEI 1R-SEP-95 DATE OF SURVEY1 05 SEP 85 ENGTNEERI De~ BARBA ZNT~RPOLATED VALUES FOR EVEN ,00 FEET OF 8UR-SEA DEPTH PAGE 6 122,00 r TRU£ SUB-SEA MEASUR£O V~RTXCAH VERTZCAL ~EPTH D~PTH DEPTH' COUR$~ DEVIATZON AZZMUTH DEG MIN D£G MTN V£RT:]:CAL DOGbEG RECTANGULAR cOORDXNA'~E8 $F..CTXON SEVERZT¥ NORTH/SOUTH ER_S_.T/NEAT D~..~;ie(~,.....i~DEPARTURE FEET DE~/IO0 FEET eP~e.:r oo ~ 20519~ . iO 62~9,96 4322 O~ ~ 38t2 6403 15 4422 O0 2479 54 6589,56 4522 O0 6?76 ?1 4622 O0 ~00 O0 42 34 ~ 4274'~ 43 ~ ~ 4 2 O0 O0 45 ~ 34 4432' ~ ~ 2l 3424 99 4217 3O 772, 16 $122 O0 .00 59 34 g 792i 11 $222 O0 ~00 3~ ~ 5067 ~ oo oo 8314 96 5422 O0 ~00 ~ oo.oo ,? 9, · 3303 ~ . 35 4 4637 56 ~ ,402 8510 ?9 5522 O0 00.00 59 36 ~ 5746 I ~ 36 4500 8704 '4 5622 00 ~00 O0 58 3i ~ ~ 59'4 o 37 ~ ~ 4773 5~ 350t 8894 "5 '722 O0 ~00.00 58 37 4~ ~ 6079 ' 5! ~ 3&99 56 3792 9'84 54 6022 00 5900 00 48 ' S ~4 3'' 6625 ~4 1.42 5358.50 ~ ~158'!! 89 O0 636? 53 6245,53 44 17 S 10 41 ~ 6975 5 O. 5662'48 ~t ~ ~ 45 ARCO AbASKA, TNC, 2A'16 KUPARUK NORTH SbOPE,ALASKA MARKER TOP UPP£R SAND BASE UPPER SAND TOP bO~RR SAND BAS; bONER SAND PB?D TD COMPU?ATZON DATEI 18-$EP-85 VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB 9282 O0 9348 O0 9447 O0 9640 O0 9738 O0 9888 O0 ORIG~N. t266' ?VD FROM KB SUB-SEA 2:27' FW[,. SEC.'J3. 'TI1N.: RSE, RP:CTANGU~AR COORDZNATEA NORTH/SOUTH giST/WEST 5952,92 5997,49 6063,59 6192,67 6260,25 6367,53 ARCO AbASKA. TNC. 2A-16 KUPARUK NORTH SLOPE.AbASKA MARKER TOp UPPER SAND BASE UPPER SAND TOP bOWER SAND BASE I, OWER SAND PRTD COHPUTATION DA~E~ 18-SEP-RS MEASURED DEPTH 9282,00 oo 9640 .00 ,00 973~,00 988 ,00 DATE Or SURVEY! 05 SEP 85 KEbbY RUSH~NG £bEVATIONI 122.00 ENGINEERI De BARBA ,,,,,,,,,,,, ?VD R£C?ANGUbAR~..RDzNAT[$ FROM KB SUB-SEA NOR?H/SOUtH 599? 49 58?5 49 5333.8 ]894. 6367 53 6245 53 fINAl, ~gbb bOCATTON AT TDI TRUE SUB-SEA MEASURED V£R?ICA[, VERTTCAb DEPTH DEPTH DEPTH q8~8.00 6367.53 6245,53 HORIZONTAb DEPARTURE DISTANCE AZIMUTH 6977.60 $ 35 8 E SCHLUMBER©ER 0 ~ RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2A- 18 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOGGED OS SEP 85 REFERENCE 000070819 Wt~LL NAME: ZA-IO SURFACE LOCATION: ~' 5' FSL, 2-27' FWL, S13,~TllN, VI~T ICAL PROJECTION 'q26. -4000 -2000 0 0 2000 4000 6000 8000 1 _0000__ '1~>000 "'" .......... ~'"I ........... ~'"; ......... ;--~.....L.~..~. ....... ;_.-: ....... ;..~..~._.I...L.:..~._:._t__:_...~._~_.:...I...:,..~...:..: ............... ~:...~_...i._.:...:_..i_ ....... .I : - .... .~ : ' · '{ ': . 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SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/2000 IN/FT WELL NAME: ZA-lb SURFACE LOCATION: 1 '~' FSL, 227' FWL, S13, TllN~-R~.,..~IIM HORI Z01~AL PROJECTION NORTH 2000 R~I=' 0000708 1000 -]000 -2000 -3000 -4000 -SO00 SOUTH -6000 -2000 NEST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WEL~-Ntil~E A~ND NUMBER' Reports and Materials to be received by: Date. ., Required Date Received Remarks Completion Report Samples Hud Log .A..',~ ,w'e_ "~": : - -- -' Core Description Registered Survey Plat Inclination Survey Directional Su~ .. P/ , :o ~,~ _., ,~-. l., · Drill Stem TeSt RePorts , .n:~ :.,-re.. . '- ~/~. _ Production Test Reports -' ' - -'~ · ' ' -"t.-+.:f_ '. Log Run ~? y~_~ t,.~.~ Digitized Data MEMORANDUM Statb f Alaska ALASKA OIL AI]D GAS CONSERVATION COMMISSION TO: Co V~~ t. er ton Chai'~rn~~ THRU: Lonnie C. Smith · Commissioner FROM: Bobby D. Petroleum Inspector DATE: FILE NO: TELEPHONE NO: SUBJECT: August 19, 1985 D. BDF. 61 Arco-Well 2A-16 BOPE Test Permit ,~85-147 Kup az~k4'~Oi 1 Pool Sunday, Augu. st 11, 1985: The B.O.P.E. test began at 3:00 PM and was concluded at 4:30 Bi. As the attached B.O.P.E. test report shows, there was one failure which was repaired and test. In summary, I witnessed the B.O.P.E. test on Arco's Kuparuk Well 2A-16. Attachment 02-001AfRev. 10/79) o O&G t;4 5/s4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ~a~ Well Represent at ive ~D~~' ~/.~_/_ j/_~ Location: Sec C~ _~z~~¥~M ,/f . O~neraZ ~ouse~e~.~.~~ ~Z~'~ ll~un ~ge ~essu~_f/~ ~ ~e~ve ~t Z'~M" ~e.~u~ A~t~' C~o~u=e' /~-~Z~ ~s~g. Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor G~s Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures ./ Pump incr. clOSe pres. 200 psig ---- min~g~sec. Full Charge Pressure Attained: ~' min~,~, sec. Controls: Master C~~ Remotet-./~_~/Blinds switch cover~~. Kell7 and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold.~ ~ Test Pressure ~~ No. Valves. ~ IINo. flanges ~%2- Imdjustable Chokes__ ~ [Hydrauically opep~ged choke / ~s~ ~ //Z~rs. days and Inspector/ Repair or Replacement of failed equipment to be made within Distribution · orig. - AO&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc. Post Office ~....~. 100360 Anchorage, Aiaska 99510-0360 Telephone 907 276 1215 July 29, 1985 Mr. C. V, Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2A-Pad Wells 13-16 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer . JG/tw GRUlO/L86 Enclosure If RECEIVED Alasks 0il & Gas Cons. Gommiss[on. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ 0 lO0 90 8O 70 60 50 ~ 13 ~15 OI 02 O~ 04 WELL 1 ;~-~,,r: 5,96o,~zs9 X: 498,620.82 O.G. Elev. 86.3' FWL 227' WELL 14 Y: 5,960,807.68 X:498,620.85 O.G. Elev. 86.7' FWL 2_27' WELL 15 Y: 5,960,747. 68 X=498,620.75 O.G.E lev. 87i1' FWL 2_?..7 WELL Y: 5,960,687.66 X~ 498,620.74 O.G. Eiev. 87.5' FWL 227'' Lat 70° 18' 15.5422" Long. 150000'40.220" Po d E lev. 9t.5' FSL 1,446' Lot. 70°18'14,9519'' Long. ! 50°00'40.219" Pod Eiev. 91.8' FSLIc386' Lat. 70°18' 14.3618" L, cng. 150o00'40.2_?_2" Pad Elev. 91.~)' FSL t,;526 Lat. 70o18' 1,3.7714 Long. 150°00'40.2 2~ Pod Elev. 91.8' FSL 1,266' 2 3 23 I 24 LOCATED IN 'SECTIONS 13~14,23, 24, TttN~RSE. UMIAT MERIDIAN. N.T.S Gas Cons. !' , D.S.L~, 14 I 18 D.S. 2-A ~ii HIS SURVEY 25 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS' A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT. ALL DETAILS ARE CORRECT AS OF ARCO Alaska, Inc. KuPoruk Project North Slope Drilling DRILL SITE 2.-A CONDUCTOR AS-BUILT LOCATIONS Dote: JULY 13, 1985 } Drown By' ,~)- /,"J. Scale: AS SHOWN Dwg. No. NSK 85-8 June 27, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~lchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2A- !6 ARCO Alaska, Inc. Permit No. 85-147 Sur. Loc. 227'FWL, 1267'FSL, Sec. 13, TllN, RSE, U~.~. Btmhole Loc. 884'FSL, 1262'FEL, Sec. 24, TllN, R8E, U~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their.drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Polluti6n of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated, thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. K~win Kuparuk River Unit 2A-16 -2- June 27, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandop~nent, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Harry W. Kuglerz Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COM~ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bu..~.~,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2A-16 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2A-16, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot Diagram and description of the surface hole diverter system ° Diagram and description of the BOP equipment We estimate spudding this well on August 5, 1985. questions, please call me at 263-4970. Sincerely, JBK/TEM/tw PD/LI09 Enclosures If you have any JUN" Alaska Oil & Gas Co,vs. Co,~rn,.ission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O1% AND GAS CONSERVATION CO'I~MISSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE [] S~-~ATIC__~. PHIC b~ DEVELOPMENT GAS ~ MULTIPLEZONE~ la. Type of work. DRILL [~X REDRILL [] DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 9. Unit or lease name 4. Location of well at surface 227' FWL, 1267' FSL, Sec.13, T11N, R8E, UN (Approx.) At top of proposed producing interval 1342' FSL, 1568' FEL, Sec.24, T11N, R8E, UN At total depth 884' FSL, 1262' FEL, Sec.24, T11N, R8E, UM Kuparuk River Unit 10. Well number 2A-16 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 124', PAD 94' I ADL 25570 ALK 2668 12. Bond information (see 20 AAC 25.025) Federa] 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 mi. NW of Deadhorse 2A-15Well 60' @ surface feet 16. Proposed depth (MD & TVD) 9691' MD, 6323' TVD 18. Approximate spud date 08/05/85 14. Distance to nearest property or lease line miles 884' @ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 55 o (see 20 AAC 25.035 (c) (2) 19. If deviated (see 20 AAC 25.050) 2932 KICK OFF POINT 500 feet. 3356 21 psig@ 80°F Surface psig@ 5807 ft. TD (TVD) SIZE Hole ! Casing 24" -T6~' i 12-1/4" 9-5/8" 8-1/2" 7" 6-1/8" . 5" Weight 62.5# 36. O# 26. O# 15.0# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW m ·-55/HF-E~W BTC / Length SETTING DEPTH MD TOP TVD 80' 29' 3583' 8891' 29' I 29' I 29' I i 28' I I 28' 8719'1 5760' I 972' MD BOTTOM TVD 109~ 109' 36121 2805' I 8919 ~ 5875' 9691 ! 6323' / QUANTITY OF CEMENT (include stage data) · 200 cf 875 sx AS III & 392 sx Class 6 149 sx Class G blend 100 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field develoPment well to approximately 9691' MD (6323' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3612' MD(2805' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure wi]] be 3000 psig. Due to gas injection at 2A Pad, Kuparuk "C" Sand pressures are presently over 3500 psi (~ 6200'SS TVD) and still increasing. To drill the we]] safely, 7" casing will be set at 8919'MD (5875'TVD) (approximately 100' above the "C" Sand). The 13-5/8", 5000 psi, RSRRA BOPE stack equipped with 3-1/2" rams will be reinstalled and the rams tested to 4000 psi, the annular to 3000 psi. A 6-1/8" hole will be drilled t'o TD. A 5" liner will be set at TD with a 200' overlap. Expected maximum surface pressure is 2932 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, (see attached sheet) 23. I hereby certi~,y.~hat the foregoing is true and correct to the best of my knowledge SIGNED/ } (___~~4,~~- ~~-~ TITLE Area Drilling Engineer Th e space b~ r~o~m/io-~u se V- CONDITIONS OF APPROVAL Samples required Mud log required []YES ~'NO Permit number Approval date ~ 5"'"' / "-('~ 06 / 27 / 85 APPROVED BY Form 10-401 (.TEM) PD/PD109 ~o,, ~_,_,n ,~'<~/) Q r~lJ33 I Directional Survey required J APl number ~Y_ES t-]NO 50-- t ~L3 - -b¢_O~Z SEE COVER LETTER FOR OTHER REQUIREMENTS June 1985 ,COMMISSIONER DATE /-/, by order of the Commission Submit in triplicate PERMIT TO DRILL 2A-16 (cont'd) including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd 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. 2A-16 will be 60' away from 2A-15 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 8016'MD, approximately IO00'MD above the top of the Kuparuk Sands. The 5" liner will be cemented from TD through the liner lap. After WOC, the liner will be cleaned out and the lap tested to 3000 psi. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well may be fracture stimulated. ................................... HORIZONTAL _.~ROJECTI ON_ . ,, .... :ALE '1 IN. = 1000 FEET -_.. . .. . . ........ PAD 2A,'WELL NO, 16 ~PROPOSED-'.~[----:_¢-~' ~'~ 77-/'_ ~' .... KUPARUK' FIELD, NORTH~ SLOPE, ALASKA ............. WEST-EAST 0 1 000 2000 BO00 4000 1000 1000., I ! ..................... 1.000 ;. . . ._ ............. z ....... 200.0 ~ . 'C: L ........ :]: 3000 .... 4000 ................ 5000 I I '' I [ I ..... I ..... _ ~. ..... z ........... ~.' ....... SURFACE LOCATIONs ~ ....................... ; ........... " 1267' FSL, 227' Fl~.'::-:i--:.::--::-'-"-' ' .~ ..... :- -: .......... ; ....... : SEC. 13, TII#, RSE -- ~ ..................... ...... 1 .... ~ ........ J - -- : ...... ] ...... - .......~ ............. ............. ~ - - ~' -- ~-.~ ....... ¢ -- :---4 ........................... ~- ......... ~_. . : · ..... ~ ........... ~ -. ~ ..... .... _ ;. . _ _ ............ .:' .... ~ -- -~ ............. ~ ....... · ............ 4 - _ ~ .i _ _~ ......... : ......... i ...... ' ..... ~---~,. ....... S '33 DEG' 48-MIN E .... -: .... ..... - ................................ $45~' .... i[TO TAROETT'~ ......... :- '- - - · 6000_ .. .................... NOI£03S 9VOIIB3A . ' : - ..... ._ oooz 0009 ooos ooo~ ooo£ oo°~ ooo~ o . . ! ._~ ~ ! i t ' - - ~ i O0~Z ....... q 1,89,-a'=JO [696-01,4.1. ~- -- ~99-a.'=10 1,6'~6-(:F,.I.L ./.0~,9.=0~.i. SONS, a13~t 3S¥B -- ....... t91,9=a30 B~g6-~,41. ~Z09-O~I SONS: ~IM09 dO/ :i_7 ......:'::.-_.' '-- _ - v9zg-a30 9Lo6-aldz ~£6;-o^1 - SONS uaan aoi .................... o~o9' -- : £B tg-a3O 9 [68-0~1 -'-.'--: _ _-77.-_ .-- ........... _._:-:___:_, ..... -__::- .: .... ' __ ['~=~O_8~Z~'~Z_S,e'},OAi SONS ri'NOn ...... .... _ . ........ z_~ .... . . . . . _ -~ .............. ................... : , . ........... ~ ....................... ...... , , .... _ ...... -._._ ~ ........ - .......................................... . : . ~ ............................. ; : . ; : _-_';-, ......... _- .............. ~ ..... : ......................... : ........ ........... ; ................. T ..... : . : .-. ..... ~ .......... . ......... ~ ........... . .................. ; .............. ~.. - ?- .... ~oo. !.-~ ~oOi .... ~-~.~ 4oo ' Soo soo . --?oo . --~. ..... : ~_! '- -, ......... ....... , ....... ~ - . ? .~:, · ;-; - -- - , ~:-:;: :-;- ,. . . ~ } .- : . .... ~ ........... ;:~' '~ ..... : ...... ' .......... ~ ........ ~ 1FO~ -- ~- ~ .... _ _~ ; ............ ~ ........... ~ ................................. : ~ - ~ ...... ~ ~ ~ · .-; ......... ~ -, ...... .~ ...... : . ! .......... : ...... . ........ ~ ....... ~ ...... ~ .... :~ ......... ; ...... '~.Z ....... ~. ...... ~ ..... ~ . .... ~ .... ' -~ ........ ~ -. ............. : ....... ~_~ 223e. F ,2~ 2~S a~ ~ 2~ ._.~ .... ~ .... ............... ~ ....... : ....... ~ .... 2~8~ --- ..~ ......... ~ ........ & .. : . . : ~ ~o~~ . ~ . .-- - : ~ ........ ~- A~O ALASKA, · -. ...... ~ ...... ~ . ................ ~ ................... ~ PAD 2A,~ ~ELL NO~- ~3- '- ........... '~.: .... ~ .......... '-- ~ 2~ e~:'T"KUPARUK¥ F [E~D ~--~ NORTH'FS~OPE~ I ' . ,: ............... ~ ............ .... ; . - _ -~ .... ......... -- ~ -. . . ~ ........ , ........ --: ~ ' ..... ~- '12~: - '--- - ' ..... ............... ; ~- . .................. _-_-: NOTE, 'WELL PATHS'~EXTEND-BEyOND ......... . .... : ....... I ........_ _ . : .... ....... ' .... 1~ ~ - . . - , ......... . .... :. .... ~ -~ .... ......... ~ -~ .- . .~ ,; ~'~, :~-; · -~:~;.~ ..... - - ' ' ; - -~ - - ' 1702 - ............. i ........ ~ - T ~ ~ - ..... ~ ................ ~/~.~ ...... ~ ....... ~ ..............-~ OL~ : '~ .._ ~ ..... .- .... .... :- ' .... ~ ...... ...... .- ,-:-~ - : ' :-:; :-~--,..~,.~ :. 1000 ' ~ ' '" ..... : ........ ..... _ ~: ~ ...... ~ _ ,~- ~. . ~ ' ~ : ._ ~:;_ _~; _ _k.~, r~ ': ': _.:-:' .,. ~'-~"~: ~_~ : ................ ,: ........ ~ ............ ,. ;.. -.-~, _.~t ~-- . :._.. .............. , ........ ~-_ ~ . ~ ..................... ~-: ...... .~ ~-~,-.-; -. ........ ~ ......... ~ ..................... ' " ~1~ ................. . .. ~ .... ~ ........ ~ ......... ~__: .~ ~ .... : - ....... ~ ........... .~ .......... : ~ I ~ .~ .......... .............. ~ : ............. ' ..... :. ..~ ........ ~- ',~~ ............ .... ~ ....... ~ . _ . ..... ........ , . . . ~ . . ~ · ;._ . .... . · . . _ _ ~ . .. - . .... ~ ~ . ~ - .. . .. Alaska OJ~ & Gas Oo~s. 7 Io 6 4 2 -/. S 10084D0 i~¥ I FOR NE~ WELL PERI~TS iT~' .1 APP~OVE~ 4. 5. 6. 7. 8. <3) Admin (~I~-- (10 and 12) (13 thru 21) (22 thru 26) . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. COmpany (6) Add ~~. ~o~ '~ 27. Lease & Well No. NO "'.. -. Is the permit fee attached .......................................... Is well to be located in a defined pool .................... Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage, available in this pool Is well to be deviated and. is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. ~2~ Is a conservation order needed ...................................... Is administrative approval needed .................................... Is the lease number appropriate ...................................... 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 ............. ........ ;;nsion Will all casing give adequate 'safety in collapse" and burst Is this well to be kicked off from an ·existing Wellbore ............. Is old we.llbore abandonment procedure included on ,10-403 ............ Is ad q lib p rati p d e uate we ore se a on ropose ...................... Is a diverter system required ....................................... ~ Are necessary'diagrams ofdiverter and BOP equipment~attached ....... ~/ · ~'o~ ~ ~0 . Does BOPE have sufficment pressure rating - Test ;~$0~:~$~,~?~ pslg ~ Does the choke manifold Comply w/AP1 RP-53 (Feb.78) ......... ~.~. Is the presence of H2S gas probable .... ' .................. ~.'~. ..... AdditiOnal requirements ............................................ ,. ~ R~,L~RKS Additional Remarks v" 0 Geology: Engineering: WVA ~_~ MTM ~ HJH__ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS~ STATUS AREA NO. SHORE 0ad I/t 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 APPENDIXi ., No special 'effort has been made to chronologically organize this category of information. L¥? 010.~02 V~iFIO~TI~ L!STI~S P~G= ...... REEL HEAD-R ...... SERV!Cr- N~ME :EDIT 2ATE :8510Bi25 ORIGIN : REEL NAME :149208__ CSNTTNUATZON ,~ :01 PRF-VZOUS REEL : COMMF-NTS :LIBRARY TAP: .,..,.,. TAp= H:AD$R~ _ .... .,..,. SERVIC: NAME :EJiT DATE :85108/25 ORIGIN :FS1A TAPE NAME : CONTINUATZ2N ~ :01 OREVIOUS TAPE COMMENTS :LIBRARY TAPE FILE NAME :EDIT .001 SERVICE NAME : VERSION ~ : OAT: : M&XIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ......-,-.,- iNFORMATION RECORDS .:;:q~ MNEM CONTENTS CN : ARCO ALASK& INC., WN : KUPARUK 2A-16 FN : KUPARUK R~NG: 8E TOWN: 11N SECT,: 13 COUN: NORTH SLJPE STAT,: ~LASKA MNEM CONTENTS P R 'E S: E -,--,- C O M M E N T S ;I-' UNIT UNIT TYPE 000 000 000 000 000 000 000 000 'TYPE 000 CAT: 000 000 000 00'0 000 000 000 000 CAT5 000 SIZE 016 014 005 002 004 002 0,12 006 SiZE 00t COOE 055 055 O55 05.5 065 O65 O65 0 65 C O,g E 065 LVP 010.H02 VERiFZCATIDN LISTING °AGE 2 JO5 NUMSER &T ACC: 7075.3 ~UN ~1, DATE L'~u _u. . ~-S=''' 1~ &US 1985 LDP: MB CASING TYPE FLUID DENSITY VISCOSITY FLUID L3SS MATRIX SAND = 7.000" ¢ 9017.0' - BIT SIZE : 6 1/8" TD : LIGNOSULFON&T= : 11.1 L~/G RM : 5.950 : ~2.0 S RMF : 5.450 : 10.0 RMC : 3.5'Z0 ~ 68.0 DF : 5.4 CB ~M ~T ~mT : 2.879 ~ 148. 0'~ LVP OIO,HOZ VERIFICATION LISTING PAISE 3 b ::: SCHLUMBERG:R LOGS INCLUD:D WITH 'T~ZS MAGNETIC TAPE: ::: DUAL iNDUCTiON SPHERICALLY FDCUS:D LCG (9ZL) ~;: DATI AVAILABLE: 9863.0' TO 9008.0' ~:: MiCRSLAT~RLOG C~LL) ,-,-" DATA AVAILABLE: 9800.0' TS 9008.0' '~: LiTHO D~NSZTY C~MPENS.~T~D L~G (LOT) -,- COMF=NSAT~D N,~UTRON LOG (LDT) :1: DATA ~VAiLABL;: 9840.0' 13 9008.0' '"'"'-,--,- DATA =ORMAT, R E C ~'R D,., ~;: "'.,- ENTRY BLOCKS TYP5 2 SIZE REPR CODE ENTRY i 66 0 1 66 ~ 73 60 LV? OlO.H02 Vf~IFiCATION LIST!N'S P~SE ~ DATUM $DfCiF!CaTiSN MN=M S~VIC~ S~RV!Cf SEPT SFLU OIL !LD OIL ILM 9iL SP OIL GR DiL GR LOT CALl LOT ~HOB LOT ORHO LOT NR~T LDT RNRA LOT NPHI LOT PEF LOT NCNL LOT FCNL LOT HO MLL MNOR MLL M!NV MLL GR MLL * ;:: O A T A DEPT SP RHOB NPHI HD SEPT RH08 NPH! HO OEPT SP RHOB NPH.I HD OEPT RHOB NPHi 9 1,5 0 66 66 ELgCKS UNIT AP1 .~Pi &PI AP1 FILE LOG 'TY~ CLASS M,.~D NJ, FT O0 O JO O0 C, 0 OHMM O0 220 O! 0 0 0 H M .M 00 120 46 0 0 2HMM O0 120 44 O 0 MV O0 OlO Oi 0 0 GA,PI O0 310 Oi 0 0 GAPI O0 310 O! O 0 IN O0 2~0 O1 0 0 G/C3 O0 350 02 0 0 G/C3 O0 356 O1 0 0 O0 420 01 0 0 O0 000 O0 0 0 PU O0 890 O0 O 0 O0 358 Ol 0 CPS O0 330 31 0 0 CPS O0 330 30 ! N 00 280 01 0 0 OHMM OO 252 O0 O 0 H M M 00 250 00 0 '0 G4PI OO 310 Ol 0 0 9789.5000 SFLU -56.4255 GR 2.2874 DRHO 44.335'9 PEF 4-6140 MNOR 9'700.0000 SFLU -,48.1443 GR 2.3616 DRHO 4,5.2402 PEF 5.9890 MNOR 9600.0000 SFLU -52.1445 GR 2.4573 ORHO 34.3750 PEr 7.5789 MNOR 3 116 0 21 2 2 0 i 4 2 .1370 .0898 .149,4 .7080 .3557 .9612 .2148 .0269 .9941 .¢729 4.1140 99.5898 -0. 0083 9.7051 2 · 8538 il 72 0 3 9 .2676 .7773 .0269 .4553 .1895 ILO GR N,RAT NCNL MINV GR NR AT NCNL M i N V ' ILD GR NRA'T NCNL M!NV ILO NRAT NCNL MINV 9500.0000 SFLU -82.222'7 GR 2.2795 DRHO 30.6641 PEF 7.1882 MNOR · lin SIZE SPt REPR CODE 4 1 68 4 1 62 4 1 68 4 i 68 4 I 68 4 1 68 4 1 68 4 1 63 4 I 68 4 I 68 4 I 58 4 1 68 4 I 58 4 t 68 4 i 6:3 4 1 68 4 1 68 4 ! 68 4 I 68 2.8206 ILM 115.0898 CALl 3.4045 RNRA 1910.6875 FCNL 2.0315 GR 2.3655 ILM lOS.214$ CALl 3.5276 RNR~ 1938.5875 FCNL 2.3850 GR '3.9065 ILM 99.5898 CALl 2.3713 RNRA 2387.5000 FCNL 3.2893 GR 11-533,2, ILM 72.7773 CALl 2.5018 RNR& 3041.5000 FCNL 8.2754 GR O000000 OOOOOO0 0000000 3000000 JO00000 SO00000 0000000 ~OO00OO OOO0000 OOO0000 0000000 0000000 0000000 0000000 0000000 0000000 O000000 0000000 DO00000 3000000 53 1! 10 7'8 9 1 I 09 ? PROCESS COCT~L) 0000300 000030,3 O00OO00 O00000O 0000300 0000000 OOO0000 0000000 0000000 0000000 0000000 O0000OO 0000000 0000000 O000OO0 OOO0000 0000000 0000000 O000OO0 0000000 2.9358 6.1257 3.5725 4.8125 6.0898 2,.4885 6.4392 3.5842 0.81.25 8.2!48 3.8108 6.3015 3.0295 7.8125 9.5898 3.3613 5.7078 2.7815 3.5875 2.7773 LVP OlO.M02 VERiFICATiON LIST!N& ~AGE 5 DEPT 9400.0300 SFLU SP -53.5445 GR RHO8 2.4241 DRH3 NPHi 32.3242 oEF HO 6.8640 MN~R OE~T 9300.0000 S'FLU SP -94.2227 GR RHOB 2.6311 DRHJ NPH! 38.H$48 PEF HO 7.1218 MNOR 3EPT 9200,0000 SFLU SP -48,7070 GR RHOB 2,3499 DRH3 NPHI 50,9765 PEP HD 7. 813~= MNCR DEPT 9100.0000 SFLU SP -70,6502 GE RHOB 2.4104 DRH2 NPHI 45.2637 PEF HO 8.6~26 MNOR DEPT 9000.0000 SFLU SP -109,660.2 GR RHOB 2,5393 D,RHO NPH! 47,8027 PEF HO 7.2~2~ MNOR DEPT 8979,0000 SFLU SP .-113,4727 GR RHOB 2,455.3 DRHD NPHI 55,1758 PEF HD 7.2039 MNOR ~:g FILE TRAILER FILE NAME :EDI'T SERVICE NAME VERSION ~ ,: gATE : MAXIMUM LENGTH FILE TYPE NEXT FIL~ NAME .001 1024 4.9539 '93.0898 GR 0.0254 NRAT 3,4299 NCNL 3.5643 MINV 91.7148 IL3 ,53.AB05 GR 3.0029 NRAT 9.2441 NCNL Z5.~799 MiNV 1,9356 iLD 125,4643 GR 0.0054 NRAT 3,7561 NCNL 1,4922 MZNV 2.3499 iLD 134.4375 GR 0.0747 NRAT 4.0085 NCNL 2.5647 MINV 0.8032 ILO 130.58?5 GR -0.3774 NRAT 55.1367 NCNL 0,0000 MINV 0,79.25 iLO 125.4023 GR -0,3906 NRAT 33,5742 NCNL 0,0000 MINV ~.77~1 ILM 93.0898 CALl 2.7355 RNRA 2849.5000 FCNL 3.8937 GR 52.4190 iLM 63.4805 CALI 3.1057 RNRa 3117.5000 FCNL 32.0430 GR 1,7120 ILM 125,4.548 CALl 3.8069 RNRA 1~76,6875 FCNL 1.9~32 GR 3,0002 ILM 134.4375 CALI 3,5217 RNRA 2003,687.5 FCNL 2.5,311 GR 15,9082 !LM 130,6875 CALi 3.5920 RNRA 1704,6;375 FCNL 0,0000 GR 14.9238 ILM 125.4023 CALl 3.9983 RNRA 1601.687.5 FCNL 0.0000 GR 4.3718 6.1257 2.99~3 949.8125 9~.0893 5,5 199~ m ~ 6.0395 3.4670 893.8125 63.~$05 1.7842 6.7859 4.0476 463.6406 125.454:5 2.7151 7.2312 3.7776 530.3125 134.4375 2000.6875 6.1101 4.2468 401.1406 130.6875 2000.6875 6.1.335 4.1375 386.8906 125.4023 · ::: TApE TRAILER $~: SERVICE NAME :EDIT DA'TE :85/08/25 ORIGIN :FS1A TAPE NflME : LVP O!O.MO2 VER'!~!CATiCN ; IgTiNG P~G~ 5 CGNTiNU~TiON ~ :01 N~XT Ta,P_~ NAM~: : COMMENTS :LIBRARY .......,..,. R[=L TR~rL;R ...... S5~VIC5 NA'ME :EDIT ~..~TE .~5/3~/25 ~RiG!N : R~EL NAME :149208 CONTINU,&TiON ~ :O1-- N~XT R~L N~M~ : CgMI~$NTS :LIBRARY TAP,~