The URL can be used to link to this page

Home My WebLink About185-091MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2U-07A KUPARUK RIV UNIT 2U-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2U-07A 50-029-21283-01-00 185-091-0 W SPT 5772 1850910 1500 2550 2550 2535 2550 345 346 446 442 4YRTST P Austin McLeod 8/7/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2U-07A Inspection Date: Tubing OA Packer Depth 560 1810 1720 1700IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220808194825 BBL Pumped:2.3 BBL Returned:1.6 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:46:12 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e o 4I 2 5 DATE: Friday,April 03,2015 P.I.Supervisor ( ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2U-07A FROM: Chuck Scheve KUPARUK RIV UNIT 2U-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry-ST— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2U-07A API Well Number 50-029-21283-01-00 Inspector Name: Chuck Scheve Permit Number: 185-091-0 Inspection Date: 3/27/2015 Insp Num: mitCS150327165006 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well li 2U-07A Type Inj I 1TVD 5772 Tubing 1825 -1 1825 --1825 _T- 1825 - r-_ PTD1 1850910 ' !Type TeL SPT(Test psi 1500 IA 520 2580 - , 2490 - 2470 H Interval 4' TST P/F P OA j 320 560 560 550 . 1 Notes: SUNNED , tr . , ; . Friday,April 03,2015 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 02,2013 TO: Jim Regg P.I.Supervisor ell /0/711 t 3 SUBJECT: Mechanical Integrity Tests 11 CONOCOPHILLIPS ALASKA INC 2U-07A FROM: Chuck Scheve KUPARUK RIV UNIT 2U-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv-J 6,--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2U-07A API Well Number 50-029-21283-01-00 Inspector Name: Chuck Scheve Permit Number: 185-091-0 Inspection Date: 9/27/2013 Insp Num: mitCS130929071040 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2U 07A IType Inj 1 W ,TVD 5772 ' ; IA 840 T 2630 -L 2580 - 2560 . 1 PTD —1 r OA = PT YP p 990 990 _ T e Test Test st 785 990 i, 1850910 I, ISPT, i 1500 INITAL P/r P ✓ Tubing 2000 - 2000 - 2000 2000 - r Interval g'' L Notes: Initial test post workover ✓ SCANNED DE L 2 ti 20i::; Wednesday,October 02,2013 Page 1 of 1 • • Brooks, Phoebe L (DOA) P17). /050,/0 From: NSK Problem Well Supv[n1617 @conocophillips.com] Sent: Wednesday, October 02, 2013 9:37 AM To: Brooks, Phoebe L (DOA) Subject: RE: KRU state witnessed MITIA's: 1Q-11 (PTD#1841990); 2C-05 (PTD#1830990); 2T-28 (PTD#1950920); 2U-07A(PTD#1850910); 30-17 (PTD#1880290); 3Q-05 (PTD#1861960) Attachments: 1Q-11 Well Schematic.pdf; 2U-07A Well Schematic.pdf Hi Phoebe - Not a problem. Current well schematics are attached. Regards, Jolin Oksness Original Message From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooksOalaska.gov] Sent: Wednesday, October 02, 2013 9:30 AM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: KRU state witnessed MITIA's: 1Q-11 (PTD #1841990); 2C-05 (PTD #1830990); 2T-28 (PTD #1950920); 2U-07A (PTD #1850910); 30-17 (PTD #1880290); 3Q-05 (PTD #1861960) Would you please send me the well schematics for the post RWO wells (2U-07A and 1Q-11) so I can verify the packer tvds? Thank you, Phoebe Phoebe Brooks Statistical Technician II „ H � .-, � is Alaska Oil and Gas Conservation Commission ,- Phone: 907-793-1242 Fax: 907-276-7542 Original Message From: NSK Problem Well Supv [mailto:n1617Pconocophillips.com] Sent: Tuesday, October 01, 2013 8:51 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Dethlefs, Jerry C; NSK Problem Well Supv Subject: KRU state witnessed MITIA's: 1Q-11 (PTD #1841990); 2C-05 (PTD #1830990); 2T-28 (PTD #1950920); 2U-07A (PTD #1850910); 30-17 (PTD #1880290); 3Q-05 (PTD #1861960) Please find attached forms for recently performed MIT's at KRU. The initial test pressures for well 3Q-05 (PTD #1861960) were not recorded before rigging down the pump truck and sending it to the next location, in an attempt to efficiently progress the work. Unfortunately, due to that the test pressure dropped below the lower threshold, despite passing parameters. This well was called a fail and will be scheduled for a re-test at first opportunity, and an inspector will be invited to witness. Please let me know if you have any questions. 1 • • Thanks, Ron Wilson / Roger Mouser CPAI Field Supervisor, DHD Office: 659-7022 Cell: 943-0167 Pager: 659-7000; #121 2 ' KUP INJ 2U-07A ConocoPh flips .',4 T= Weflat�ibutes ,�-_ `loti, ID - .,!'', Wellborn API/UWI Field Name Wellborn Status Intl(°) MD(ftKB) Act Btm(ftKB) 1A(c'tdS.2') 500292128301 KUPARUK RIVER UNIT INJ 53.97 8,000.00 8,250.0 coracoPMfrps ___-- - "'"` Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date wau conr9 -2u-07A,Sr2712013t1c)213AM SSSV:NIPPLE Last WO: 8/9/2013 41.70 3/20/1985 Schemata:-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,874.0 8/25/2013 Rev Reason:TAG,GLV C/O,PULL hipshkf 8/27/2013 PLUG/CATCHER,PULL BALUROD HANGER.33 Casing Strings 1 ll.'I"1 - 2 Iii N'etk Casing Description String 0... String ID...Top(ftKB) Set Depth(5...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 38.0 101.0 101.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 36.6 3,627.0 2,975.6 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35 2 I 8,235 0 6,047.3 26 00 J-55 BTC ni Strin•s - a 7. ' y Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt...String..String Top Thrd , - - TUBING WO 3 1/2 2.992 33.0 7,703.4 5,727.7 9.30 L-80 EUE-8rd Mod r Ieon Details :� ,r , ,i ' Top Depth 41 r til (ND) Top Intl CONDUCTOR, Top(ftKB) (ftKB) (1 Item Description Comment ID(In) 38-101 33.0 33.0 0.34 HANGER McEVOY GEN IV TUBING HANGER 2.992 508.9 508.9 0.34 NIPPLE CAMCO DS NIPPLE2.875"Profile(EUE 8rd)("500') 2.875 -- -- 7,684.6 5,715.9 51.19 LOCATOR BAKER LOCATOR 2.990 NIPPLE,509 7,685.6 5,716.5 51.20 SEAL ASSY BAKER PBR SEAL ASSY 2.990 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd STACKER PACKER 5.01 2.970 7,688.5 7,750.5 5 756 9 9.30 L-80 Top Depth (ND) Top Intl Top(ftKB) MKS) (°) Item Description Comment ID(in) SURFACE. 7,688.5 5,718.3 51.22 PBR BAKER 8040 PBR 2.970 37-3.cn 7,708.3 5,730.7 51.36 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 aim 7,728.5 5,7432 51.50 NIPPLE CAMCO DS NIPPLE 2.812(EUE 8RD) 2.812 GAS LIFT, ; 7,746.0 5,754.1 51.63 OVERSHOT BAKER POOR BOY OVERSHOT 2.950 7.628 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f.,.Set Depth(1VD)...String Wt...String...String Top Thrd f TUBING ORIGINAL 3 1/2 2.922 7,746.6 7,802.9 5,789.1 9.30 J-55 EUE8rd °,: s* : t-'IS .''. ; :_ '`2' tt Top Depth _ (ND) Top not LOCATOR, Top(ftKB) (MKS) r) Item Description Comment ID(In) it , ,7' 7,762.8 5,764.5 51,75 SBR OTIS SBR 3.000 SEAL ASSY, 7,773.9 5,771.5 51.83 PACKER OTIS RRH PACKER 2.970 7,686 PBR.7.689 7,790.1 5,781.4 51.95 NIPPLE CAMCO D NIPPLE NO GO 2.750 LE-___, . ,__, 7,801.6 5,788.3 52.40 SOS OTIS SHEAR OUT SUB 3.000 x0-7h7,,�0, 7,802.4 5,788.8 52.41.WLEG OTIS WIRELINE RE-ENTRY GUIDE 3.000 PACKER,7,708 Perforations&Slots _ __, s- - .. VaI,..,- . 'XI xO-Th read.. Shot 7.717 Top(ND) BM(TVD) Dens It Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment NIPPLE.7.72!7 7,880.0 7,952.0 5,836.3 5,879.6 A-4,A-3,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing 7,982.0 7,988.0 5,897.1 5,900.6 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing 1. 7,992.0 7,996.0 5,903.0 5,905.3 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing 8,008.0 8,014.0 5,912.1 5,915.6 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing 8,021.0 8,026.0 5,919.8 5,922.8 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing OVERSHOT, 7.746 IC c- 8,050.0 8,056.0 5,937.1 5,940.7 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun,120 deg.phasing at Notes:General&Safety :' [ 7_,,, ° SSR,7763 �^ End Date Annotation 12/2/2002 NOTE:WAIVERED WELL:T x IA COMMUNICATION PACKER,7774 mJ NIPPLE.7,790 ■ 1. SOS.7,802 WLEG.7.802 ;� IPERF, 7.880-7,952 IRF, :*z:,-: 7,952 PE-7.988 ,., IPERF. _ ,Detail S. _� k ^Z" # _ _Lt:{3 7,992-7,596 _ - Top Depth Top Port �� S-,. (ND) Ind OD Valve Latch Sloe TRO Run N...Top(ftKB) (SKB) ("1 Make Model (in) Sery Type Type lie) (Psi) Run Date Cent... PERF, 600;7,1074 '` 1 7,628.1 5,680.0 50.78 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 8/22/2013 IPERF, Z:'""- 8.021-8,026 IPERF. 8.050-8.056 V ,, PRODUCTION. TD(2221.7A�). \ Alt 11. 8.250 f • STATE OF ALASKA RECEIVED ALA.OIL AND GAS CONSERVATION COMMON AUG 3 0 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell 17 Rug Perforations r® Perforate aherAOGCC Alter Casing IT Pull Tubing ri Stimulate-Frac fl Waiver n Time Extension Change Approved Program rOperat. Shutdow n r Stimulate-Other n Re-enter Suspended Well I 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 185-091 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21283-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 266£23- 25(pyl-1 2U-07A - 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 8250 feet Plugs(measured) 7790 true vertical 6056 feet Junk(measured) none Effective Depth measured 8147 feet Packer(measured) 7708, 7774 true vertical 5994 feet (true vertical) 5731,5771 Casing Length Size MD TVD Burst Collapse CONDUCTOR 63 16 101 101 SURFACE 3590 9.625 3627 2976 PRODUCTION 8200 7 8235 6047 SCANNED 2 ; f "• Perforation depth: Measured depth: 7880-7952,7982-7988,7992-7996,8008-8014, 8021-8026,8050-8056 True Vertical Depth: 5836-5800,5897-5901,5903-5905, 5912-5916,5920-5923, 5937-5941 Tubing(size,grade,MD,and ND) 3.5, L-80,7703 MD,5728 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PRODUCTION PACKER @ 7708 MD and 5731 TVD PACKER-OTIS RRH PACKER @ 7774 MD and 5771 TVD NIPPLE-CAMCO DS NIPPLE @ 509 MD and 509 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory ll Development IT Service Stratigraphic 16.Well Status after work: Oil r Gas IT WDSPL IT Daily Report of Well Operations_ XXX GSTOR SUSP I WINJ WAG GINJ SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-381 Contact Erik Nelson a,263-4693 Email Erik.Nelson(a)conocophillips.com Printed Name E.gik Nels Title Sr. Wells Engineer Signature r Phone:263-4693 Date ,/ 7( 'Afi 1 L P `�)f/9 RBDMS SEP 12 2.'3. Form 10-404 Revised 10/2012 /0/15-11, Submit Original Only d KUP INJ 2U-07A ConocoPhillips Oa Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Narne Wellbore Status Inc!(°) MD(ftKB) Act Btm(ftKB) 500292128301 KUPARUK RIVER UNIT INJ 53.97 8,000.00 8,250.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' SSSV:NIPPLE Last WO: 8/9/2013 41.70 3/20/1985 Well Confg..2U-07A,8/14/2013628:54AM - Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,882.0 4/22/2013 Rev Reason:WORKOVER haggea 8/14/2013 HANGER.3312.... Casing.Strings'. !„ Casing Description String 0String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 38.0 101.0 101.0 62.50 H-40 WELDED Casing Description String 0String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 36.6 3,627.0 2,975.6 36.00 J-55 BTC I Casing Description String 0String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.2 8,235.0 6,047.3 26.00 J-55 BTC Tubing Strings Tubing Description String 0String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING WO 3 1/2 2.992 33.0 7,703.4 5,727.7 9.30 L-80 EUE-8rd Mod lit Completion Details Top Depth (ND) Top Intl Neon... CONDUCTOR, 38-107 Top(ftKB) MB) (°) item Description Comment ID(in) 33.0 33.0 0.34 HANGER McEVOY GEN IV TUBING HANGER 2.992 R. 508.9 508.9 0.34 NIPPLE CAMCO DS NIPPLE2.875"Profile(EUE 8rd)('500') 2.875 NIPPLE.509 7,684.6 5,715.9 51.19 LOCATOR BAKER LOCATOR 2.990 ' 7,685.6 5,716.5 51.20 SEAL ASSY BAKER PBR SEAL ASSY 2.990 Tubing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(ND)...String Wt...String...String Top Thrd STACKER PACKER 5.01 2.970 7,688.5 7,750.5 5,756.9 9.30 L-80 Completion Details Top Depth (ND) lop Intl Noml...J Top(RKB) (RKB) (°) nem Description Comment ID(in) S 373,627 7,688.5 5,718.3 51.22 PBR BAKER 80-40 PBR 2.970 IIII 7,708.3 5,730.7 51.36 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 GAS LIFT, - 7,728.5 5,743.2 51.50 NIPPLE CAMCO DS NIPPLE 2.812(EUE 8RD)W/RHC-M PLUG 2.812 7.628 1- 7,746.0 5,754.1 51.63IOVERSHOT BAKER POOR BOY OVERSHOT 2.950 Tubing Description String 0... String ID...Top OMB) Set Depth(f...Set Depth(TVD).. String Wt..String... String Top Thrd TUBING ORIGINAL 3 1/2 I 2.922 I 7,746.6 I 7,802.9 5,789 1 9 30 J-55 EUE8rd Completion Details ,„, < u,,.. .,\w, .....,1,„1 LOCATOR, Top Depth 7,685 INDI Top Item Nomi... Top(ftKB) (ftKB) I°) Itom Description Comment ID)ie) SEAL ASSY, 7,762.8 5,764.5 51.75 SBR OTIS SBR 3.000 PER,7,689 7,773.9 5,771.5 51.83 PACKER OTIS RRH PACKER 2.970 7,790.1 5,781.4 51.95 NIPPLE CAMCO D NIPPLE NO GO 2.750 xo-Tnreads. 7,707 7,801.6 5,788.3 52.40 SOS OTIS SHEAR OUT SUB 3.000 PACKER.7,708 -- 7,802.4 5,788.8 52.41 WLEG OTIS WIRELINE RE-ENTRY GUIDE 3.000 xo-Threads, a Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 7,717 R Top Depth (TVD) Top Intl NIPPLE.7,726 ilin Top(ftKB) (ftKB) 1°) Description Comment Run Date ID(in) 7,783.1 5,777.1 51.90 CATCHER CATCHER SUB(2.72x94") 7/21/2013 0.000 7,790.1 5,781.5 51.95 PLUG 2.75"CA-2 7/21/2013 0.000 Perforations&Slots Shot OVERSHOT, -.. �� Top(ND) Btm(TVD) Dens Comment 7,746 7---J Top 7,880.)Btm952.0 (ftKB) (ftKB) Zone Date ( Type 7,880.0 7,952.0 5,836.3 5,879.6 A-4,A-3,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing SBR,7,763 7,982.0 7,988.0 5,897.1 5,900.6 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing 7,992.0 7,996.0 5,903.0 5,905.3 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing r PACKER,7,774 119301202 r_ 8,008.0 8,014.0 5,912.1 5,915.6 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing 8,021.0 8,026.0 5,919.8 5,922.8 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing CATCHER, I I 8,050.0 8,056.0 5,937.1 5,940.7 A-2,2U-07A 4/19/1985 4.0 IPERF SOS 4"Csg Gun;120 deg.phasing 7,783 ti, 'Y - NIPPLE,7,79' PLUG.7,790 fr Notes:General&Safety � End Date Annotation _ 12/2/2002 NOTE:WAIVERED WELL:T x IA COMMUNICATION SOS,7,802--- - 4 --!-, ' I WLEG,7,802 /I IPERF, - 7,880-7,952 - i- IPERF, 7,982-7.988 Mandrel Details IPERF, 1 - Top Depth Top Port 7,992-7,996 (ND) Intl OD Valve Latch Size TRO Run N...Top(ftKB) MB) (°) Make Model (in) Sery Type Type P^) (psi) Run Date Com... IPERF, 1 7,628.1 5,680.0 50.78 Camco MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 8/8/2013 DCR-1 8,008$014 She... Open 8,0 RF, 21 PEPERF, IPERF, 8.0508,056 PRODUCTION, 35$235 TO(2U-07A1, 8,250 • 2U-07A Pre and Post Rig Well Work Pre Rig Well Work DATE SUMMARY 4/21/2013 RECOVERED 1-7/8" CUTTER BAR @ 7713' SLM. RAN 2.75" LIB TO FISH @ 7717' SLM; LIB SHOWS NO WIRE, CLEAN ROPE SOCKET. PULLED TOOLSTRING FISH @ SAME. ATTEMPTED PULL CA-2 PLUG. RAN PUMP BAILER TO CA-2 PLUG @ 7741' SLM, RECOVERED 1 GAL SCALE. IN 4/22/2013 PULLED 2.75 CA-2 PLUG @ 7790' RKB. BRUSHED& FLUSHED TBG. TAGGED @ 7882' SLM/7931' RKB; EST. 125' FILL. READY FOR E-LINE. 4/26/2013 BRUSHED & FLUSHED TBG TO D NIPPLE @ 7790' RKB. SET 2.75" CA-2 @ 7790' RKB. MIT TBG 3000 PSI, PASSED. COMPLETE. 4/30/2013 (AC EVAL) IA DDT; IN PROGRESS FOR EXTENDED MONITOR 5/1/2013 (AC EVAL) IA DD TEST- PASSED 7/20/2013 PULLED CA-2 PLUG FROM 7790' RKB. MEASURED BHP @ 7880' RKB: 3189 PSI. IN PROGRESS. 7/21/2013 SET 2.75"CA-2 PLUG IN D NIPPLE @ 7790' RKB. PT 2000 PSI, GOOD. BLED TO 0 PSI, GOOD. SET 2.72" OD CATCHER ON CA-2 PLUG. PULLED DV FROM 7723' RKB. READY FOR E/L TBG 7/24/2013 RIH W/5' 160GR/FT STRING SHOT, SET AND FIRED MIDDLE OF STRING SHOT @ 7747', CCL TO MIDDLE OF STRING SHOT: 5', CCL STOP DEPTH @ 7742', STRING SHOT FIRED SUCCESSFULLY, POOH, WILL RETURN TOMORROW TO CUT TUBING 7/25/2013 PERFORMED TUBING CUT. CUT TUBING WITH 2.5" RCT @—7747'. TOOLSTRING STUCK AFTER CUT AND LEFT IN THE WELL. FISH STATS AREAS FOLLOWS: 50', 2.75" O.D.,AND 325# ***FISH LEFT IN WELLBORE*** 7/26/2013 (PRE RWO) : T-POT PASSED, T-PPPOT PASSED, IC-POT(UNABLE TO PERFORM DUE TO SEALTITE IN TEST VOID) IC-PPPOT FAILED (WOULD NOT PRESSURE UP ABOVE 1100 PSI), FUNCTION TESTED LDS"S (COMPLETE). MIT-OA PASSED TO 1800 PSI. 7/27/2013 Pulled 50' E-Line Fish @ 7747' RKB. (Called in for BPV to be installed)Job Complete. Post Rig Well Work 8/18/2013 UNABLE TO LATCH BALL& ROD DUE TO FILL, BAIL FILL F/7606' SLM TO 7662' SLM, GAUGE TBG 2.84"TO 7662' SLM, IN PROGRESS 8/19/2013 BAILED FILL OFF RHC PLUG FROM 7661' SLM TO 7672' SLM, JOB IN PROGRESS 8/20/2013 BAIL FILL OFF TOP OF BALL & ROD @ 7728' RKB (TTL PIN INDICATES @ TOP OF BALL& ROD). JOB IN PROGRESS 8/21/2013 BAIL FILL; PULL BALL & ROD @ 7728' RKB; BAIL FILL ON TOP OF RHC PLUG @ 7728 RKB. IN PROGRESS 8/22/2013 PULL SOV& REPLACE WITH DV @ 7628' RKB; MIT- IA(PASSED); PULL RHC PLUG BODY @ 7728' RKB & BAIL FILL OFF TOP OF CATCHER. IN PROGRESS 8/23/2013 BAIL MUD ON TOP OF CATCHER FROM 7712-7729' SLM. IN PROGRESS 8/24/2013 BAIL MUD & PULLED CATCHER @ 7783' RKB; ENCOUNTERED MORE MUD TRYING TO LATCH 8/25/2013 BAIL FILL& PULL 2.75"CA-2 PLUG @ 7790' RKB; TAG W/ FILL 2.5 BAILER @ 7874' SLM (EST. 120' FILL ABOVE BTM. PERF); MEASURE BHP @ 7925' RKB. JOB COMPLETE. • • Conoco fillips Time Log & Summary We wFew Web Reporting Report xy., _ 14, { Well Name: 2U-07 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 8/4/2013 12:00:00 AM Rig Release: 8/9/2013 6:00:00 PM Time t ogs O,' Date .. From 46. Dur' S.Death E.Death"Phase Code Subcode T Comment(i 07/29/2013 24 hr summary Moved Pits, Motors and Boilers to 2U-07A.Work on repairing and matting the roads for Sub and Pipe sheds. 00:00 12:00 12.00 MIRU MOVE MOB P R/D and move pit,motor, boilers and pump complexes to 2U pad. Roads are extremely soft, road blew out between 2U and 2G.Wait for roads to be repaired and graded. 12:00 00:00 12.00 MIRU MOVE MOB P Cont to wait on roads to be repaired. Matt roads and lay plywood from 2G pad to CPF2. 07/30/2013 Laid rig mats and plywood from 2G to CPF2. Moved pipe sheds and sub to CPF2.Work on moving mats and plywood from CPF2 to 2V pad. 00:00 00:00 24.00 MIRU MOVE MOB P Laid rig mats and plywood from 2G to CPF2. Moved pipe sheds and sub to CPF2.Work on moving mats and plywood from CPF2 to 2V pad. 07/31/2013 Laid rig mats/wood from CPF 2 to 2V pad. Moved sub and pipe shed to 2V pad. Moving mats/wood to 2U access road. 00:00 05:00 5.00 MIRU MOVE MOB P PJSM, Lay matting boards and plywood f/CPF 2 t/2V pad. 05:00 07:30 2.50 MIRU MOVE SFTY P Shut down laying mats and pull support crews away for ASRC weekly safety meeting 07:30 15:00 7.50 MIRU MOVE MOB P Cont to lay matting boards and plywood f/CPF 2 t/2V pad. 15:00 16:15 1.25 MIRU MOVE MOB P Move pipe shed to 2V pad. 16:15 17:30 1.25 MIRU MOVE MOB P Lay more plywood on roads. 17:30 18:45 1.25 MIRU MOVE MOB P Move sub base from CPF-2 to 2V pad 18:45 00:00 5.25 MIRU MOVE MOB P Move matting boards from CPF2 road to 2V pad road. 08/01/2013 Laid plywood f/2V to 2U cutoff. Shut down and wait for support crews to clean— 100 gal diesel spill. Return to laying plywood from 2V to 2U. 00:00 16:00 16.00 MIRU MOVE MOB P Lay matting boards and plywood from @V pad to 2U pad. 16:00 00:00 8.00 MIRU MOVE MOB P While loading plywood into ASRC lowboy a ASRC loader damaged the fuel tank on the lowboy. Shut down rig move to clean up spill,-, 100 gal. Clean inside rig while waiting on plywood. 08/02/2013 Move sub base and pipe sheds to 2U access road. Move pipe sheds onto 2U pad,mat access road for sub base. Page 1 of 7 X1117@ Logs t r i a � "� C�,� �I��' 411144 1%,M Date :'vry}From'yr To Our S.Depth t.Denth'Plhase Code Subcode 'T Comment 00:00 00:00 24.00 MIRU MOVE MOB P Lay plywood and mats from 2V pad to 2U cutoff. Move pipe sheds and sub base to 2U cutoff. Lay plywood of 2U access road and move pipe sheds onto 2U pad. Pick up plywood and mat 2U access road for sub base. 08/03/2013 Move sub base to 2U pad,spot over 2U-07A. Spot modules and R/U.Accept rig @ 24:00 hrs. 00:00 12:00 12.00 MIRU MOVE MOB P Cont to lay plywood and matting boards on access road. 12:00 12:30 0.50 MIRU MOVE MOB P Move sub base onto 2U pad. 12:30 16:15 3.75 MIRU MOVE MOB P Move rig mats from access road and mat well to spot rig. 16:15 17:45 1.50 MIRU MOVE MOB P Spot sub over well 2U-07A. 17:45 21:15 3.50 MIRU MOVE MOB P Lay mats for modules. Spot pits, pumps, motors and boilers. Spot rock washer and burm rock washer and boilers. 21:15 23:00 1.75 MIRU MOVE RURD P PJSM, connect inner connects and electrical lines. Rig up pipe skate and cattle chute. 23:00 00:00 1.00 MIRU MOVE RURD P Work on rig acceptance check list. Rig accepted @ 24:00 hrs. 38/04/2013 Circulate out freeze protect with 10.9 ppg mud. OWFF and set BPV. N/D tree and N/U BOPE.Test BOPE to 250/4000 PSI, annular to 250/3500 PSI.Witness waived by AOGCC rep Lou Grimaldi. 00:00 02:00 2.00 MIRU MOVE RURD P Rig up scaffolding in cellar and R/U tiger tank. Take on 11.4 ppg mud into pits. 02:00 03:00 1.00 MIRU WHDBO RURD P Rig up lubricator and test to 2500 PSI. Pull BPV,400 PSI on tubing and 30 PSI on IA. 03:00 04:00 1.00 MIRU WHDBO RURD P Cont to R/U tiger tank,dilute 11.4 ppg mud to 10.9 ppg mud with water. 04:00 04:15 0.25 MIRU WHDBO PRTS P Test cement line and hard line to tiger tank to 2000 PSI. 04:15 05:15 1.00 MIRU WHDBO COND P Cont to dilute mud to 10.9 ppg and run over shakers. 05:15 07:30 2.25 MIRU WHDBO KLWL P PJSM, bleed pressure off well to tiger tank. Kill well, pump 10.9 ppg KWF down tubing taking returns out IA, pump @ 3 BPM holding 500 PSI back pressure with choke. Pumped a total of 316 bbls with 270 bbls returned to tiger tank. FCP=550 PSI tubing, 150 PSI on IA. 07:30 08:15 0.75 MIRU WHDBO OWFF P OWFF and R/D circulating lines, line up to circ into pits. 08:15 09:15 1.00 MIRU WHDBO CIRC P Circulate down tubing taking returns out IA into mud pits, pump @ 5 BPM= 1150 PSI. 09:15 09:45 0.50 MIRU WHDBO OWFF P OWFF,static. 09:45 10:15 0.50 MIRU WHDBO RURD P Blow down and R/D circulating lines. Page 2 of 7 Time Logs �u h gg to Date from* o Dur '°S.°Depth E.Death Phase Code ,Subcode ...T Comment ' "RI'li 10:15 10:45 0.50 MIRU WHDBO SEQP P Set BPV and test to 1000 PSI from below. 10:45 11:00 0.25 MIRU WHDBO RURD P PJSM, R/D scaffolding in cellar. 11:00 12:00 1.00 MIRU WHDBO NUND P PJSM, N/D tree and adaptor flange. 12:00 15:15 3.25 MIRU WHDBO NUND P PJSM, N/U BOP stack and install adapter flange. Install turnbuckles and choke line, measure riser hight. 15:15 17:00 1.75 MIRU WHDBO RURD P PJSM, R/U to test BOPE,cut small hole in a joint of 3-1/2"tubing to be used as test joint. 17:00 18:00 1.00 MIRU WHDBO NUND P Add 8"to riser,clean and clear rig floor. 18:00 18:30 0.50 MIRU WHDBO SVRG P Service rig. 18:30 00:00 5.50 MIRU WHDBO BOPE P PJSM,Test BOPE to 250/4000 PSI w/3-1/2"test joint,annular to 250/3500 PSI. Test#1:Top pipe rams,CV 1,12,13&14.Test#2: Upper IBOP, CV 9&11. Test#3: Lower IBOP, CV 5,8&10. Test#4: Dart valve,CV 4,6,&7. Test#5: Floor valve&CV 2. Test#6: HCR choke&4"kill line demco. Test#7: Manual choke&HCR kill(HCR kill did not pass,will be rebuilt and re-test) Test#8:Annular preventer. Test#9: Lower pipe rams. AOGCC rep Lou Grimaldi waived witness of the test. 38/05/2013 Completed testing BOPE to 250/4000 PSI. C/O HCR valve and test. Pull hanger to floor and CBU. UD 3-1/2" tubing. 00:00 01:15 1.25 MIRU WHDBO BOPE P Cont to test BOPE.Accumulator test:system pressure=3000 PSI, pressure after closing= 1600 PSI, 200 PSI attained after 45 sec.,full pressure attained after 236 sec. Five bottle nitrogen avg.= 1950 PSI. Lou Grimaldi of AOGCC waived witness of test. 01:15 02:45 1.50 MIRU RIGMNT SLPC P PJSM, slip and cut 78'of drilling line. Service rig, SIMOPS work on HCR kill valve. 02:45 04:00 1.25 MIRU RIGMNT SVRG P Rig up power tongs and tubing equipment and tally 3-1/2"tubing in shed.SIMOPS,wait on HCR kill parts. 04:00 08:45 4.75 MIRU RIGMNT RGRP T Remove HCR kill valve and install new valve. Make up kill line to valve. 08:45 09:45 1.00 MIRU WHDBO BOPE P Test HCR kill valve and kill line flange to 250/4000 psi. 09:45 11:00 1.25 MIRU WHDBO SEQP P Rig up and pull BPV. 11:00 12:00 1.00 0 7,747 COMPZ RPCOM THGR P Make up landing joint, BOLDS and pull hanger to floor. Broke over @ 130K. Rage3of7 Time Lege 1N4" k' 6 Hi ' '- "; Date ._..< : From,..To Dur : S. Depth E.Depth,Phase Code "'Subcode Th„,Comment 12:00 13:30 1.50 7,747 7,722 COMPZ RPCOM CIRC P PJSM, UD hanger and R/U to circulate. CBU X 1-1/2”@ 4 BPM=1050 PSI. 13:30 14:00 0.50 7,722 7,722 COMPZ RPCOM OWFF P OWFF, R/D circ lines. 14:00 16:30 2.50 7,722 5,827 COMPZ RPCOM PULL P L/D 3-1/2"tubing to SSSV @ 5827'. 16:30 17:00 0.50 5,827 5,827 COMPZ RPCOM SSSV P L/D SSSV and control line, R/D spooler unit. Recovered 32 SS bands, 1 missing. 17:00 19:00 2.00 5,827 4,200 COMPZ RPCOM PULL P Cont.to L/D 3-1/2"tubing. 19:00 19:45 0.75 4,200 4,200 COMPZ RPCOM CIRC P R/U to pump dry job, pump 20 bbls 12.2 ppg @ 4 BPM. R/D circ lines. 19:45 21:45 2.00 4,200 220 COMPZ RPCOM PULL P Cont to L/D tubing to joint 240. 21:45 22:15 0.50 220 220 COMPZ RPCOM OTHR P Heavy scale and paraffin on tubing, shut down,take pictures and discuss with town. 22:15 22:30 0.25 220 0 COMPZ RPCOM PULL P Cont to UD 3-1/2". UD 243 joints of 3-1/2"tubing, SSSV, GLM and cut joint.Actual displacement=31.97 bbls, Calculated displacement= 26.03 bbls. 22:30 00:00 1.50 0 0 COMPZ RPCOM OTHR P Clean and clear rig floor. Load pipe shed with drill pipe to make scraper run. 38/06/2013 P/U and RIH with casing scraper assy to 7739'MD and clean up.Test casing and POOH, L/D BHA. Rig up to run completion. 00:00 03:00 3.00 0 0 COMPZ RPCOM OTHR P PJSM and continue load pipeshed w/ DP, DC and process. 03:00 05:45 2.75 0 146 COMPZ RPCOM PULD P P/U BHA to rig floor and M/U to 146' MD. 05:45 11:30 5.75 146 4,865 COMPZ RPCOM TRIP P Single in hole w/4"DP t/4865'MD, P/U=97k, S/O=75k. Calc Disp=28 bbl,Actual Disp=29.5 bbl. 11:30 12:00 0.50 4,865 4,865 COMPZ RPCOM CIRC P Break circulation @ 4865'MD 2 bpm,200 psi. Pump dry job. 12:00 14:15 2.25 4,865 7,571 COMPZ RPCOM TRIP P Continue single in hole to 7571'MD. 14:15 18:00 3.75 7,571 7,739 COMPZ RPCOM WASH P Wash and ream f/7571'MD t/7738' MD(tight spots f/7578'-7640') Rotate 80 rpm, pump 300 gpm @ 1000 psi. P/U=126k, S/O=85k. Rotating wt=103k,TQ=5-6k.Tagged up on tubing stump @ 7739'MD,set do 10k several times, pump 30 bbl HV sweep and circulate hole clean. Ample shaker returns of scale/paraffin materials while washing and circulating. 18:00 19:00 1.00 7,739 7,697 COMPZ RPCOM PRTS P PJSM-UD 2 jts in shed for even stands, R/U and test casing t/3500 psi on chart 30 minutes. 19:00 19:30 0.50 7,697 7,697 COMPZ RPCOM OWFF P Rig down casing test equipment, B/D lines,monitor well. 19:30 21:45 2.25 7,697 140 COMPZ RPCOM TRIP P POOH f/7697'MD t/140',monitor well,fill Trip tank. Calc Fill=44.8, Actual Fill=50.8 bbl. Page4of7 Hate From ,To Dur S.Depth''E.Depth„Phase Code Subcode T Comment "" :ter 21:45 22:45 1.00 140 0 COMPZ RPCOM PULD P PJSM and L/D BHA. Baskets clean, marks on overshot extension indicate stump had bottomed out in the 13' overshot, putting stump at 7725.9' D141 RKB. 22:45 00:00 1.25 0 0 COMPZ RPCOM RURD P Clean and clear rig floor, L/D tools. P/U tubing running tools. 38/07/2013 RIH w/3-1/2"completion, locate and set packer, S/O PBR. Set storm packer @ 50'and CIO tubing head. 00:00 08:30 8.50 0 7,708 COMPZ RPCOM RCST P PJSM and run 3-1/2"tubing completion per detail to 7708'MD, Calc Disp=25.8 bbl,Actual Disp= 25.8 bbl. 08:30 09:00 0.50 7,708 7,725 COMPZ RPCOM CIRC P M/U XO t/3-1/2"jt, M/U top drive and RUH t/7725'MD,tag top of tubing stub. Break circulation @ 1 bpm, 350 psi. 09:00 10:15 1.25 7,725 7,725 COMPZ RPCOM CRIH P PJSM, Pump and spot 30 bbl 11.1 ppg NaCI/NaBr corrosion inhibited brine(4%Conqor 303A).Chase with 64 bbl 10.9 mud, leaving 3 bbl in tubing. 10:15 11:15 1.00 7,725 7,732 COMPZ RPCOM PACK P Engage overshot over tubing stub, 3.9'to 7732.02'MD D141 RKB. Drop 1-3/8 rod/ball,set down 10k. Pressure up to 4000 psi-set packer, chart for 10 min. Bleed off pressure, P/U 10k over to verify packer set. 11:15 12:00 0.75 7,732 7,605 COMPZ RPCOM PULD P R/U and lay down 4 jts tubing. 12:00 13:15 1.25 7,605 50 COMPZ RPCOM PULD P PJSM, L/D 3 more jts tubing and P/U storm packer,set storm packer @ 50'MD. 13:15 13:30 0.25 0 0 COMPZ RPCOM PRTS P Test storm packer to 250/1500 psi 5 min each on chart 13:30 13:45 0.25 0 0 COMPZ RPCOM PULD P L/D running tool 13:45 14:30 0.75 0 0 COMPZ RPCOM OWFF P Monitor well for 30 minutes 14:30 15:15 0.75 0 0 COMPZ WHDBO NUND P PJSM, N/D BOP stack 15:15 15:45 0.50 0 0 COMPZ WHDBO SEQP P Loosen bolts on tubing spool, spool started growing. 15:45 17:15 1.50 0 0 COMPZ WHDBO SEQP P Rig up HydraTight tools and grow casing 2.5". 17:15 17:30 0.25 0 0 COMPZ WHDBO SEQP P R/D HydraTight 17:30 18:45 1.25 0 0 COMPZ WHDBO SEQP P Remove old tubing spool 18:45 19:15 0.50 0 0 COMPZ WHDBO RURD P Clean cellar area and drip pan, BOLDS and prep to C/O primary seals and cut 7"casing. 19:15 19:30 0.25 0 0 COMPZ WHDBO PULD P P/U Baker spear tools via Beaver Slide 19:30 19:45 0.25 0 0 COMPZ WHDBO FISH P M/U spear,engage casing and pull 95k, putting 60k tension on casing, release in slips. Casing grew from 7" to 16.5". 19:45 20:15 0.50 0 0 COMPZ WHDBO PULD P Release spear and L/D via Beaver Slide. Page 6of'7 TimeLogS .x - w, o ) elii 1110 io9 w Date From To Dur j,: S. Death E.'Deoth'Phase Code °`Subdode .T Comm o 449" 114 20:15 21:15 1.00 0 0 COMPZ WHDBO SEQP P Pull 7"packoff, install new packoff and torque lock down screws. 21:15 23:15 2.00 0 0 COMPZ WHDBO CPBO P R/U casing cutter,cut and bevel casing 23:15 00:00 0.75 0 0 COMPZ WHDBO SEQP P Install new tubing spool 08/08/2013 N/U and test new tubing head, N/U BOP and test breaks. Pull storm packer,space out upper GL completion and land.Test tubing/IA. N/D BOP and N/U adapter and tree,test. 00:00 02:00 2.00 0 0 COMPZ WHDBO NUND P N/U tubing spool and test packoffs to 250/3000 psi 10 min. 02:00 03:30 1.50 0 0 COMPZ WHDBO NUND P N/U BOPE and choke line, install bell nipple, R/U test equipment. 03:30 04:00 0.50 0 0 COMPZ WHDBO BOPE P Test breaks&choke line on BOP, 250/4000 psi on chart. 04:00 04:30 0.50 0 0 COMPZ WHDBO RURD P R/D test equipment, Blow down choke and kill lines. 04:30 05:30 1.00 50 7,605 COMPZ RPCOM PACK P Retrieve storm packer, P/U=95k. LID retrieving tool&packer. 05:30 06:45 1.25 7,605 7,703 COMPZ RPCOM RCST P Space out, M/U pups, hanger and landing jt. Land tubing, P/U=95k, S/0=65k. Seal assembly @ 7703.4' MD. 06:45 07:15 0.50 7,703 7,703 COMPZ RPCOM THGR P Run in lock downs 07:15 08:45 1.50 7,703 7,703 COMPZ WHDBO PRTS P R/U and test tubing on chart 250 psi 5 min, 3500 psi 30 min, bleed tubing to 2500 psi.Test IA 250 psi 5 min, 3500 psi 30 min. Bleed IA to 0, belld tubing to 0 psi. 08:45 09:15 0.50 7,703 7,703 COMPZ WHDBO RURD P R/D test equipment, blow down lines and clear rig floor. 09:15 09:30 0.25 7,703 7,703 COMPZ WHDBO MPSP P Set Cameron two way check 09:30 10:00 0.50 7,703 7,703 COMPZ WHDBO OWFF P Monitor well for 30 minutes 10:00 12:00 2.00 0 0 COMPZ WHDBO NUND P PJSM,open doors on BOP and remove rams, clean out ram cavities. 12:00 14:45 2.75 0 0 COMPZ WHDBO NUND P PJSM, HRW and continue taking apart and cleaning BOP Ram components. 14:45 20:30 5.75 0 0 COMPZ WHDBO NUND P Remove bolts from adapter flange, pick up stack and break apart spacer spool, lower rams, mud cross,blind rams, upper pipe rams and annular preventer, removing from cellar. 20:30 21:00 0.50 0 0 COMPZ WHDBO RURD P Clean up cellar area and prep for N/U tree adapter and tree. SIMOPS- Laying rig mats on road from 2U to CPF-2. 21:00 23:00 2.00 COMPZ WHDBO NUND P PJSM, nipple up adapter flange and test t/250/5000 psi, 10 minute. 23:00 00:00 1.00 0 COMPZ WHDBO NUND P Nipple up tree,oriented per Cameron rep.Called CPF-2 Lead Operator at 20:00 for orientation, no call back. 08/09/2013 N/U and test tree, S/O and displace to diesel. Sercure well and LID DP. Separate mods, pull off well and spot sub on 2U,moving rig mats, pad very soft. Page 6 of I * , Time Logs 4_ Date y Fromh To Dur ! S.Death E.'Depth Phase Code Subcode :T Comment ''I'1o1,, .' 00:00 01:00 1.00 0 0 COMPZ WHDBO PRTS P PJSM-R/U and test tree and packoffs to 250/5000 5 minute on chart. 01:00 01:30 0.50 0 0 COMPZ WHDBO MPSP P Pull 2 way check 01:30 02:00 0.50 0 0 COMPZ RPCOM RURD P R/U circ lines, spot up Little Red Services 02:00 05:00 3.00 0 0 COMPZ RPCOM FRZP P PJSM-TEst circ lines t/3500 psi, line up down IA and shear out SOV @ 2550 psi,freeze protect well w/ 270 bbl LEPD @ 1.9 bpm taking returns out tubing. ICP 400 psi 1.9 bpm, FCP 950 psi 1.9 bpm. 05:00 06:00 1.00 0 0 COMPZ RPCOM RURD P Rig down LRS, blow down circ lines. U-tube well,set mouse hole and prep for lay down DP. 06:00 07:00 1.00 0 0 DEMOB MOVE MPSP P Set'H'BPV and secure well. Remove Kelly hose 07:00 13:45 6.75 0 0 DEMOB MOVE PULD P PJSM-UD DP via mousehole 13:45 15:00 1.25 0 0 DEMOB MOVE DMOB P Clean pits&rock washer, remove pipe from shed. PJSM-remove bails from topdrive. Latdown bails and elevators. Remove all lift subs,XO's, slips,elevators,tongs, air slips from rig floor. 15:00 17:00 2.00 0 0 DEMOB MOVE DMOB P Blow down water,disconnect and interconnects and electrical. Load pipe shed and prep for rig move. 17:00 18:00 1.00 0 0 DEMOB MOVE DMOB P Move pipe sheds, rockwasher, powerpack and sub off 2U-07A. Release rig @ 18:00 hrs. Page 7 of 7 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission j DATE: Tuesday, December 27. 2011 TO: Jim Reg cc 114 I ! v PI Superv ( t SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 2U -07A FROM: Matt Herrera KUPARUK RIV UNIT 2U-07A Petroleum Inspector Src: Inspector Reviewed By: F.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNTf 2U -07A API Well Number: 50-029-21283-01-00 Inspector Name: Matt Herrera Insp Num: mitMFH111219084157 Permit Number: 185 -091 -0 Inspection Date: 12/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2U -07A 'Type Inj. N , TVD 5772 , IA 960 1720 , 1670 1670 P.T. 1850910 • TypeTest SPT Test psi 1500 - OA 0 100 100 100 Interval RE Q V ` P/F P . Tubing 910 913 909 909 Notes: MITIA performed to 1700 psi , zg 0 10 Tuesday. December 27, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 22, 2011 TO: Jim Regg \mil 4 P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2U -07A FROM: Matt Herrera KUPARUK RIV UNIT 2U -07A Petroleum Inspector Src: Inspector Reviewed By: _ P.I. Supry NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2U - 07A API Well Number: 50 029 21283 - 01 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111219084607 Permit Number: 185 - 091 - Inspection Date: 12/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 20 -07A Type Inj. N TVD 5772 IA 1000 1020 1020 1020 - P.T.D 1850910 (TypeTest SPT Test psi 1800 OA 275 1800 . 1720 1690 - Interval REQVAR P/F P - Tubing 950 950 - 950 - 950 Notes: MITOA performed after MITIA Ajo zg,Ol Thursday, December 22, 2011 Page 1 of 1 • MEMORANDUM To: Jim Regg ~ 1~~~~t ~' P.I. Supervisor ~~~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 23, 2009 SLiBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2U-07A KUPARUK RIV UNIT 2U-07A Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv ~~-- Comm Well Name: KUPARUK RIV UNIT 2U-07A API Well Number: 50-029-21283-01-00 Inspector Name: Bob Noble Insp Num: mitRCN091223071137 Permit Number: 185-091-0 Inspection Date: 12/20/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __ r I 2L1 07A r-- --~ ~ - 1 __- ~_ - i -- , I 220_ _' - --?---- Well :.Type Inj. N , TVD 5771 ~i IA 70o I 1700 ]660 1660 ---- ---- -- ~ - - --- ~ -- - --- -~ -- --{ - - ---- 1. . I - P.T Dt ia5o91o.irypeTest SPT I Test psi ~ 1700 "~pA lob zoo 200 ~ _..___--~ ~ ---1__ --- -- ---- -j--- -~---- . _ --_ - 1250 1260 I 1260 -- REQVAR P ~ TUb-n~1250__ LL~ r Interval__ T~ P/F _ g I_ ~ __l I I Notes. MIT-IA / M;~ , rt~8e1 ~~-~P~~s~~~ = r~~~~, ~-~~~~,~~ J~~~ ~ 4zF Z~ r;~a Wednesday, December 23, 2009 Page 1 of 1 MEMORANDUM TO: Jim Regg ~~~ (I~j ~~ P.I. Supervisor II FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 23, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2U-07A KUPARUK RIV UNIT 2U-07A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 2U-07A API Well Number: 50-029-21283-01-00 Inspector Name: Bob Noble Insp Num: mitRCN091223072312 Permit Number: 185-091-0 Inspection Date: 12/20/2009 Rel Insp Num: ~, Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Y J- ~-- - . ' 5771 ~y IA - 650 - i~ ...660 ~- - 728 ~ r Well ~u o7A '~`-Type In.. N '~TVD ~' f -- - 760 _ _ -~---- 1850910 ; SPT ~ I 1815 I QA ~ 200 1815 ~ 1768 ~ 1753 '~~ _TypeTest I Test psi _ -r- --- P.T D REQV --- --~ ---~------ -- L _------_- --}- --r --_ _ - -- ~-- Interval ~ P/F P "~ Tubin lzso l~so lzso ~ lzso g - ---~--- ~- ----~ '-------- Notes: MIT-OA Wednesday, December 23, 2009 Page 1 of 1 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ ~, _> March 5, 2009 ;~_.~ a ~~ ~~,~ ~:~ Mr. Tom Maunder Alaska Oil & Gas Commission ~ ~(~ 333 West 7th Avenue, Suite 100 ~~~ Anchorage, AK 99501 ~~ -~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23rd , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ ~~~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 ~, 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 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3,5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2!23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21" 1/24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 MEMORANDUM To: Jim Regg ~ ,, ~~;rI ' . ~~, ~","' P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Couservation Commission DATE: Thursday, January 10, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2U-07A KUPARUK RIV CiNIT 2Ci-07A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.LSuprv ~.~~~~ Comm Well Name: KUPARUK RN UNIT 2U-07A Insp Num: mitLG07122914125s Rel Insp Num: API Well Number: so-o2~-2t2s3-ol-0o Permit Number: 185-09I-0 Inspector Name: Lou Grimaldi Inspection Date: 12/29/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 ~1in. 60 Min. Well ~ zU-o7A Type Inj. ~ ~ TVD i s77t "f IA ! 70o Tao Tao j Tao p T ~ tsso9lo ~,TypeTest ~ SPT ~~ Test psi ~r tsoo ~~. OA ' o isso ~ ta9o I t46o InteCVal OTHER P~F P ~ TUhing ~! 13s0 1350 ~ _ _ 1350 I 1350 i j NOteS: 2.4 bbl's pumped. OA tested for sundry compliance. Good test, IA tested before this test, took excessive fluid (7.2 bbl's), needs retest of IA when well goes on line. _ _. _ _~ __ Thursday, January 10, 2008 Pase 1 of 1 MEMORANDUM To: Jim Regg -~ , P.LSupervisor ~'`~ 1~, k,ROtvt: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 10, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2li-07A KUPARUK RIV UNIT 2U-07A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv r ;''~- Comm Well Name: KUPARUK RN UNIT 2L'-07A Insp Num: mitLG071229135627 Rel Insp N'um: API Well Number: 5 0-02 9-2 1 2 8 3-0 1-00 Permit Number: 185-091-0 Inspector Name: Lou G~imaldi Inspection Date: 12,~29~2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I zt;-o7A TypeInj.~ `~ '~I TVD s77I `'~ IA 300 ~ 20?0 ~, ~9os ', i89o ~ P T ! Iaso9io ITypeTest I SPT'~ Test psi ~ _ ~isoo ~~ pA ~ o ~ o j , ~ o ~ o _ Interval oTI1ER p/F _ P ~ TubingL I3so I I37o ~ Is7o i37s _ _- _I NOteS• 7.2 bbl's pumped. Two year compliance testing, well shut in due to flowline deration. Numbers good but should be retested when well goes on injection due to large amount of fluid pumped. OA tested after this test. ~« ~ ~%' ~a~ ~ ~ 2t14 ~~~ Thursday. January 10, 2008 Page I of 1 • FRAtVK hl. IVPURKOINSKl, G04/ERI~lOR 333 W. T" AVENUE. SUITc t00 ANCHORAGE, ALASKA 99501-3539 PHONE (907! 279-1433 FAX (907) 276-7542 AD~VII1~iI5TRATIVE APPI20VAi, i~iC1. AI® 2B.010 ~Ir..Ierry Dethlefs Problem Fell Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99~ 10-0360 RE: KRU 2U-07A (PTD 18~-091) `~~~''~~ ~~~ ~ ~~~ Request for Administrative Approval Dear vtr. Dethlefs: On May 28, 2006 ConocoPhillips Alaska, Inc ("CPAI") requested an administrative approval under Rule 9 of Area Injection Order ("AIO") ZB to allow continued water injection in service well Kuparuk River Unit ("KRU") 2U-01A. The Alaska Oil and Gas Conservation Commission ("Commission") GRANTS CPAI's request for WATER ONLY service, as detailed below. 2U-Q7A w-as originally reported to have tubing x inner annulus ("T x IA"} pressure communication in December 2001 and a sundry was obtained for continued operation. Diagnostic testing determined that the IA pressure communication is due to a leaking sealing unit at the top packer and that a rig workover is necessary to repair the well. CPAI has elected not to perform corrective action on 2U-07A to restore full integrity. The Commission finds that, based upon reported results of CPAI's diagnostic procedures, 2U-07A exhibits two competent barriers to the release of w-eI1 pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity and will not result in an increased risk of movement of fluids outside the injection zone. Vdhere freshwater is not affected, 20 AAC 2~.4~0 gives the Commission authority to approve less stringent well integrity and operation requirements. Per Rule 9 of AIO 2B, the Commission hereby grants CPAI's request for administrative approval to continue water injection in KRU 1H-07 on the following conditions: 1. Injection is limited to WATER ONLY: 2. CPAI shall monitor and record tubing, inner annulus and outer annulus (T~IIO) pressures and injection rate daily; ADMINISTRATIVE .~PPEtOV~L At0 NO. ZS.OLO Iune Z l , 2006 Page 2 of 2 3. CPAI shall submit to the Commission a monthly report of well pressures and in}ection rates including any pressure bleed events; 4. CPAI shall perform an Combined tilechanical Integrity Test (C~IITj of the tubing and inner annulus {T x IA) every two years; ~. CPAI shall perform an MIT-OA every two years; 6. CPAI shall immediately shut in the well and notify the Commission upon any measurable change in the wells mechanical condition; and 7_ After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 8. The NIIT anniversary date is January 3, 2006. As provided in AS 31.0.080, 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. ~ 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. DONE at :~Chc~orage, Alaska and dated June 21, 2006. The Alaska Oil and Gas Conservation Commission ~ ',i / ~ r !~/ i f Orman Daniel T. Seamount, Jr. Cathy,~~. Fo-erster Commissioner Commissioner MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supcrvisor 'Re11 fr/O{, DATE: Wednesday, January 04, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 2U-07 A KUPARUK RIV UNIT 2U-07A ·S-V oÜ\ , \fJ6 ' FROM: J efT Jones Petrolcum Inspector Src: Inspector Revicwcd By: P.I. Suprv ~2-.. Comm NON-CONFIDENTIAL Permit Number: 185-091-0 Inspector Name: Jeff Jones Inspection Date: 1/3/2006 Well Name: KUPARUK RIV UNIT 2U-07A Insp Num: mitJJ060104084450 ReI Insp Num API Well Number 50-029-21283-01-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 M.in. w·~ii········2U~07A .. "'Typ'~ I~j:···· ···w·-r···Tvnu··'--"'·-·"·"s'7·:;ï-·-'··-T--IA-··· ··-······ï·230·--···-·····-··!950··..'..'···T·-···-·Ï9·3o·····..-·"··'··'·ï·93Ö..·······--·n __,.,.."_~,,,.._~._ ."...~.._ _'.....__,._".._~.'_.,"_.,._"",. '_"_~""'.'._.""" ~__.._..~.,__ ...___. ,..,. "" .,.,." ",.~ .",""."___R'__._~_'_· _.______,_,.....~'._._'..._..._.__..._,__"._..._____._ ___.___~_." .." .... .........._,'......__,_".. ."~,,.___,___.,,__.___,_.,~...__. . . ,"'_.."_"'_"'.".""_' ._"__.'''''"..'' ,..,,_,_ _..,_.....,." ,. "'. P.T. 1850910 TypeTest 1442.75 OA 60 60 60 60 REQV AR Tubing 2650 2650 2650 2650 Notes 1.2 BBLS diesel pumped. Sundry #302-055. 1 well house inspected; no exceptions noted. :SÇANNIE[~' Jbr~N 11 2005 Wednesday, January 04, 2006 Page I of I ') . C()nocoPtUIUpsAJa$k:a~ Jnc~ 2U-07 A SSSV (1895-1896, OD:3.500) TUBING (0-7803, OD:3.500, ID:2.992) Gas Lift andrei/Dum my Valve 1 (7723-7724, OD:5.750) SBR (7763-7764, 00:3.500) PKR (7774-7775, OD:6.151) NIP (7790-7791, 00:3.500) SOS (7802-7803, OD:3.500) TIL (7803-7804, OD:3.500) Perf (7880-7952) Perf (7982-7988) Perf (7992-7996) Perf (8008-8014) Perf (8021-8026) Perf (8050-8056) i Gas Lift MandrelsNalves 1 St MD TVD Man Man Type I Mfr 1 7723 5740 Cameo MMG-2 Other (plugs. equip., etc.) - JEWELRY Depth TVD Type 1895 1796 SSSV 7763 5765 SBR 7774 5771 PKR 7790 5781 NIP 7802 5789 SOS 5789 ~ API: 500292128301 SSSV Type: LOCKED OUT ¡ '::: Reference Log: Last Tag: 8131 Last Tag Date: 7/18/2004 1 Casing String - ALL STRINGS :: . .:::).. . Description 'j:::::: CONDUCTOR ).::~:;~:.:.:.::::,..::::::.:.:.:.:, I SUR. CASING lmry :.',.,'......... PROD. CASING {j¡¡j(}:.:,:,:.:.:.:. I Tubing String - TUBING .' ......'..'...:.:: ."...., . L :~~ I T gP '.' I Perforations Summary Interval TVD 7880 - 7952 5836 - 5879 Annular Fluid: II 7982 - 7988 5897 - 5901 7992 - 7996 5903 . 5905 8008·8014 5912-5916 8021 - 8026 5920 . 5923 8050 - 8056 5937 - 5941 '" I.T~ ......."" . . . . , . .. .. " " .. ':::::::::?:::::::::~ :!:~: !:~:~:~:~: ~:¡: ~:~{: WELL: T x IA x OA COMMUNICATION - =1= ~ --r- ~ ~ -~ j l= __1~ Well Type: INJ Orig 3/24/1985 Completion: Last w/o: Ref Log Date: TD: 8250 ftKB Max Hole Angle: 54 deg @ 8000 Size Top Bottom 16.000 0 101 9.625 0 3627 7.000 0 8235 Bottom TVD Wt 7803 5789 9.30 Zone Status Ft SPF A-4,A-3 72 ~ A-2 6 4 A-2 4 4 A-2 6 4 A-2 5 4 A-2 6 4 V Mfr V Type DMY Description Cameo 'TRDP-1A' (Locked Out 7/18/2004) Otis Otis'RRH' Cameo 'D' Ni~ple NO GO Otis ) KRU 2U-07A Angle @ TS: 52 deg (ji) 7762 Angle @ TD: 53 deg @ 8250 Rev Reason: TA.G FILL, lock out SSSV Last Update: 7/22/2004 TVD 101 2976 6047 Wt 62.50 36.00 26.00 Grade H-40 J-S5 J-~;5 Thread I Grade I J-55 Thread EUE 8RD Date ~yp~ Comment 4/19/1985 IPERF SOS 4" Csg Gun, 120 deg. phasing 4/19/1985 IPERF SOS 4" Csg Gun; 120 deg. phasing 4/19/1985 IPERF SOS 4" Csg Gun; 120 deg. phasing 4/19/1985 IPERF SOS 4" Csg Gun; 120 deg. phasing 4/19/1985 IPERF SOS 4" Cs'g Gun; 120 deg. phasing 4/19/1985 IPERF SOS 4" Csg Gun; 120 deg. . phasinº-- VOD Port--fRëf""-' Date Run 0.000 0 5/3/1985 Vlv Cmnt Latch 1.5 RK ------- ID 2.810 2.810 2.970 2.750 2.992 -----..-.'- i~ ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission . \1.t\ù4/ TO: Jim Regg /lt1î \ DATE: January 14, 2004 P.I. Supervisor \ ~ ~ SUBJECT: Mechanical Integrity Tests From: John Spaulding CPAI Petroleum Inspector 2U 07A KRU Kuparuk River Field NON- CONFIDENTIAL P Type Test Interval M= Annulus Monitoring 1= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to CP AI's Kuparuk River Field well 2U-07 A to witness a MITT. As noted above the tubing has displayed integrity. M.I.T.'s performed: 1 Number of Failures: Q Total Time during tests: 1 hr Attachments: none cc: ~ @(;t~l~~g~El, JJ~N i~ ~ 200,~, M IT report form 5/12/00 L. G. mit kru 2u-07 a 1-14-04 jhs.xls 1/2012004 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 3, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please t-md a 10-403 Sundry Notice variance request for Phillips Alaska, Inc., well 2U-07. The variance request is for approval to continue injection with a failed MIT. Also attached are a discussion and action plan and a well schematic. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, ~ethle/'~fs~--~ ~~ Phillips Problem Well Supervisor Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 Location of well at surface 4673' FNL, 4547' FEL, Sec. 32, T12N, R9E, UM At top of productive interval 1444' FNL, 1692' FWL, Sec. 6, T11N, R9E, UM At effective depth 1565' FNL, 1349' FWL, Sec. 6, T11N, R9E, UM At total depth 1422' FNL, 3826' FEL, Sec. 6, T11N, R9E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (asp's 509279, 5975870) (asp's 504730, 5973838) 6. Datum elevation (DF or KB feet) RKB 106 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2U-07A 9. Permit number / approval number 185-091 10. APl number 50-029-21283 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3606' Production 8214' 8210 feet Plugs (measured) 6157 feet 8147 feet Junk (measured) 5994 feet Size Cemented Measured Depth 16 230 sx CS II 80' 9 5/8 730 sx PF 'E' & 880 sx PF 'C' 3627' 7 295 sx Class G & 250 sx PF 'C' 8235' True vertical Depth 80' 2975' 6047' Perforation depth: measured 7880-7952', 7982-7998', 7992-7996', 8008-8014', 8021-8026', 8050-8056' true vertical 5836-5879', 5897-5901', 5903-5905', 5912-5916', 5920-5923', 5937-5941' Tubing (size, grade, and measured depth 3.5" 9.30# J-55. EUE, 0-7803' MD Packers & SSSV (type & measured depth) Camco TRDP-1A SSSV @ 1895' md (1796' tvd) Otis RRH Packer @ 7774' md (5771' tvd) RECEIVED FEB 0 6 ZOO2 Alasl(a 0il & Gas Col~.~ 13. Attachments Description summary of proposal .__X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended __ Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title: Problem Well Supervisor Je fs Questions? Call Jerry Dethlefs 659-7224 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~ ~.-~--~-.~--, ¢..,~,..%~,....,,3 I Approval no. Plug ,ntegd~ __ BOP Test __ Location cleave __ ' I = o.~C ~Mechanical Integ,~ Test ~ ~ Subseq,ent ,o~ req,lred 10-~ ~~~, ~S O~~ Approved by order of the Commission 0riflJnal ~;~..J m Commissioner ~ Date~~_~ Form 10-403 Rev 06/15/88 · Please return to PWS @ NSK-69 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 2U-07A (PTD 1850910) SUNDRY NOTICE 10-403 VARIANCE REQUEST 02/03/02 The purpose of this Sundry Notice variance request is for approval to continue water-only injection with a failed MIT. A failed MIT was reported to the AOGCC 12/10/01, the packer being suspected of leaking. Subsequent diagnostics indicate the packer is leaking and the tubing is in good condition. The following events support this conclusion: · 12/10/01: MIT-IA failed @ 3000 psi with leak rate of 0.25 bpm (reported to AOGCC); · 01/13/02: Tubing tail plug set in D nipple @ 7790' MD; · 01/17/02: A Combination-MIT T x IA passed @ 3000 psi, then an MIT-T passed @ 3000 psi, then the IA would not bleed back down below 1000 psi; · 01/29/02: Wellhead pressures T/IA/OA: 2000/1000/150 psi (tubing plug still in well). Attempt to bleed IA again failed, would not bleed below 600 psi. Tubing pressure is solid at 2000 psi. Final pressures 2000/600/150 psi. · 01/30/02: Post bleed pressures 2000/720/240 psi show stable tubing and slowly increasing IA pressures. · Note: A small leak appears evident in the tubing plug. At no time did the tubing or IA pressures appear to track or communicate. MIT test form attached. The diagnostics show that the packer can, at times, support a passing MIT yet not hold a dp as the annulus is bled down (one-way type leak). Diagnostics indicate the tubing is competent and so all injection fluids must be entering the approved zones. The following Action Plan is proposed to support the variance request for continued injection: ACTION PLAN 1. Well 2U-07A will be used for water injection only (no gas or MI allowed); 2. Perform a passing MIT-IA every 2-years; or if MIT-IA fails, set a tubing plug and perform a MIT-T as per AOGCC MIT criteria; 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut-in the well should MIT's or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor OPERATOR: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_Maunder@admin,stde.ak.us and Bob_Fleckenstein@admin.state.ak,us Phillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk / GKA / 2U-O 7A DATE: 1/17/02 Diesel 5, 771 1,443 2,150 3,240 SW 7,774 7"/26#/J-55 1,500 1,200 3,000 COMMENTS: _...,~ Test#l: CMITTxlA with TTPinDnipple @ 7790'MD. NOTE: Smallleaksuspectedin tubingplug. Well#:2.P'e'7A I N I P I SW I 7,774 I 7/26#/J-55 3.500 1,500 3,000 2,960 F,,N~ Well#:~ L.N I P I SW I 7,774 I 7"/26#/J-55 3.500 1,500 1,000 1,000 COMM ENTS~o,~b'"ht'T'est #3: MITT only (after bleeding IA to 1000 psi, would not bleed lower) %,/ PTD: COMMENTS: 3,140 3, 040 3,000 3,000 2,125 2,125 2,950 2,940 2,975 I 2,900 1,000 1,000 I I I PTD: Well #: COMMENTS: Ir. ID ID ID TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: orig - Well File c - Operator c- Database c- Trip Rpt File c- Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 0.00 0.00 0.00 WELL TEST: Initial 4 - Year Workover Other X OPERATOR REP SIGNATURE: Pete Nezaticky , AOGCC REP SIGNATURE: Chuck Scheve MIT KRU 2U-07A 01-17-02.xls (Rev 9/23/99) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY SSSV -- (1895-1896, 0D:3.500) Gas Lift landrel/Dummy Valve 1 (7723-7724, OD:5.750) SBR (7763-7764, OD:3.500) PKR (77744775, OD:6.151) NIP (7790-7791, OD:3.500) TUBING (0-7803, OD:3.500, ID:2.992) SO$ (78O2-7803, OD:3.500) KRU 2U-07A ZU~07A::, : : :::: SSSV Type: Annular Fluid: Well Type: INJ Odg Completion: J 3~24~85 Last W/O: Ref Log Date: J TD: 8250 ftKB Max Hole Ang e: 54 deg @ 8000 APl: 500292128301 Reference Log: LOCKED OUT Last Tag: 7929 Last Tag Date: 4/20/01 casihg StHhg L :STRINGS :)escri@tion Size CONDUCTOR I 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Top 0 T~bing String. TUBING : : Size Top Bottom 3.500 0 7803 Perforationssummary Interval 'FVD 7880-7952 5836-5879 7982- 7988 5897- 5901 7992- 7996 5903- 5905 8008-8014 5912-5916 8021-8026 5920-5923 8050- 8056 5937- 5941 Boffom TVD 101 101 3627 2976 8235 6047 Angle ~ TS: J52 deg (~ 7762 Angle @ TD: J 53 deg @ 8250 Rev Reason: Tag fill, pull Inj Valve by ImO Last Update: 4/24/01 Wt Grade Thread 62,50 H-40 36,00 J-55 26.OO J-55 I TVD Wt Grade Thread 5789 9.30 J-55 EUE 8RD Zone Status Ft SPF Date I Type Comment J A-4,A-3 J J 72 J 4 J 4/19/85 J IPERF JSOS 4" Csg Gun;120 deg. phamng A-2 6 4 4/19/85 IPERF SOS 4" COg Gun; 120 deg. phasing A-2 4 4 4/19/85 IPERF SOS 4" Csg Gun; 120 deg. phasing A-2 6 4 4/19/85 IPERF SOS 4" Csg Gun; 120 deg. phasing A-2 5 4 4/19/85 IPERF SOS 4" Csg Gun; 120 deg. phasing A-2 6 4 4/19/85 IPERF SOS 4" Csg Gun; 120 deg. phasing IVlv Cmnt Gas: Lift Mandrels/Valves St I MD I TVD I Man I Man I V Mfr I VType I V OD I Latchl Po, I TRO: Date Mfr Type Run 1 7723 5740 Camco MMG-2 DMY 1.5 RK 0.000 0 5/3/85 ;Other (Pibgs; equiPs, etc,), JEWELRY Depth I TVDI Type Description 1895 1796 SSSV Camco %RDP-1A' (Locked Out 11/19/94) Pulled Injection Valve 4/26/01 7763 5765 SBR Otis 7774 5771 PKR Otis 'RRH' 7790 5781 NIP Camco 'D' Nipple NO GO 7802 5789 SOS Otis 78O3 5789 TTL ID 2.810 2.810 2.970 2.750 2.992 2.992 Per[ (7880-7952) Per~ (7982-7988) Perf (7992-7996) Perf (8008-8014) Pad (8021-8026) Perf (8o~) MITfail-011210-KRU 2U-07A.txt Subject: Re: Kuparuk well 2U-07A failed MIT Date: Mon, 10 Dec 2001 15:16:22 -0900 From: Tom Maunder <tom maunder@admin.state.ak.us> To: NSK Problem Well Supv <nl617@ppco.com> CC: Bob Fleckenstein <bob fleckenstein@admin.state.ak.us>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Jerry, Thanks for the notice. Your plan is appropriate, please keep us infor med regarding the diagnostics. Also for future notices of MIT failures, w ould you please copy Bob Fleckenstein and the NS Inspectors as well. Tom Maunder NSK Problem Well Supv wrote: > Tom: On 12/10/01 Phillips Kuparuk well 2U-07A WAG injector (PTD 1850 910) > failed an MITIA. The MIT was performed to diagnose suspected T x IA > communication. The leak rate into the IA was 0.25 bpm @ 3000 psi pum P > pressure; the packer is suspected as being the source of communicati on. The > well is currently on water injection. > Our plan going forward is: > 1. Set a TTP and MIT-tubing to verify integrity of the tubing string ; > 2. Run a leak detect log to verify leak is past the packer; > 3. Review results with AOGCC and file Sundry Notices as required. > > I would like to keep the well on water injection as needed while we perform > diagnostics. Let me know if you approve of our plan. Thanks! > > Jerry Dethlefs > Phillips Problem Well Supervisor Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder Page 1 MEMORANDUM State of Ala ..a Alaska Oil and Gas Conservation Commission TO: Cammy O Taylorc,?~ DATE: January 17, 2002 Chairman ii_SUBJECT: Mechanical Integrity Tests THRU: ,, Phillips Tom Maunder P.I. S u pervis° r/~_,--~,"~O-~'~ ~,,--r,,- - ~ ~,~~_ KRU 2U-07A FROM: Chuck Scheve Kuparuk Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ' WellI 2U-07A I Typelnj. I N J T.V.D. 15771i ~00 i~00 i~00 i~00 J lntervalJ O P.T.D.I 185-091 ITYpetestl P ITestpsiI 1443 I CasingI 1200I 2980I 2960I 2960I PIE I P Notes: Well was pre-produced and converted to injection Vvell[ P.T.D.I Notes: WellI P.T.D.I Notes: P.T.D.I Notes: WellI , P.T.D-I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips Kuparuk River Field to witness an MIT on well 2U-07A. This well has a history of failed IA MITs with one reportedly having a leak rate of .25 bbls per minute. Prior to my arrival a plug had been set in the tubing at 7790 with the packer at 7774 MD. The initial pressure test was on the tubing and revealed a 500 psi pressure loss in 30 minutes (possible leak by tubing plug) and no change in IA pressure. The tubing and casing were then pressured up together with the bleed rate on the tubing slowing to 200 psi in 30 minutes and the casing holding solid at 3000 psi. The tubing was then bleed back to 2100 psi and the casing pressure stabilizing at 2960 psi. In summary, at the time of today's testing well 2U-07A demonstrated acceptable mechanical integrity of the tubing casing and packer. I recommend that another MIT be performed after the well has been placed back on water injection and the temperatures have stabilized. M.I.T.'s performed: 1_ Number of Failures: _0 Total Time during tests: 5_ Attachments: cc: MIT report form 5/12/00 L.G. MIT KRU 2U-07A 1-17-02 CS.xls 1/29/02 Re: Kuparuk well 2U~07A failed MIT Subject: Re: Kuparuk well 2U-07A failed MIT Date: Mon, 10 Dec 2001 15:16:22 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: NSK Problem Well Supv <n1617@ppco.com> CC: Bob Fleckenstein <bob_fleckenstein@admin.state.ak. us>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Jerry, Thanks for the notice. Your plan is appropriate, please keep us informed regarding the diagnostics. Also for future notices of MIT failures, would you please copy Bob Fleckenstein and the NS Inspectors as well. Tom Maunder NSK Problem Well Supv wrote: Tom: On 12/10/01 Phillips Kuparuk well 2U-O7A WAG injector (PTD 1850910) failed an MITIA. The MIT was performed to diagnose suspected T x IA communication. The leak rate into the IA was 0.25 bpm @ 3000 psi pump pressure; the packer is suspected as being the source of communication. The well is currently on water injection. Our plan going forward is: 1. Set a TTP and MIT-tubing to verify integrity of the tubing string; 2. Run a leak detect log to verify leak is past the packer; 3. Review results with AOGCC and file Sundry Notices as required. I would like to keep the well on water injection as needed while we perform diagnostics. Let me know if you approve of our plan. Thanks/. Jerry Dethlefs Phillips Problem Well Supervisor i Tom Maunder<tom maunder~,.admin.state.ak, us> st' Petr°leum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 12/10/01 3:18 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate ~ Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. AddreSs P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 604' FSL, 732' FWL, Sec. 32, T12N, R9E, UM At top of productive interval 1444' FNL, 1692' FWL, Sec. 6, T11N, R9E, UM At effective depth 1565' FNL, 1349' FWL, Sec. 6, T11N, R9E, UM At total depth 1607' FNL, 1421' FWL, Sec. 6, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 825O 6056 feet feet 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name Kuparuk River Unit 8. Well number 2U-07 /-~ 9. Permit number/approval number 85-91/94-324 10. APl number 50-029-21283-01 1 1. Field/Pool Kuparuk River Oil Pool Plugs (measured) None ~feet Effective depth: measured 8 1 4 7 true vertical 5 9 9 4 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7880'-7952', Length Size 8O' 16" 3606' 9 5/8" 8214' 7" measured 7982'-7988' true vertical Cemented 230 SX CS II 730 SX PF 'E' & 880 SX PF 'C' 295 CLASS G & 250 SX PF 'C' 7992'-7996', 5903'-5905', 8008'-8014', Measured depth 101' 3627' 8235' 8021'-8026', 5920'-5923', True vertical depth 101' 2975' 6047' 8050'-8056' 5937'-5940' 5836'-5879', 5897'-5901', 5912'-5916', Tubing (size, grade, and measured depth) 3 1/2", 9.'3 LB/FT, J-55 EUE 7803' Packers and SSSV (type and measured depth) SSSV: CAMCO TRDP-1A-SSA @ 1895' W/CAMCO A-1 ,NJ VALVE, PKR: OTIS RR1-~7~77~ ~ V 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure Install Camco A-1 Injection Valve DEC 2 ? 1994 0il & Gas Cons. Commission Anchor~ - 14. Prior to well operation Subsequent to operation ReDresentative Daily Average Production or Iniection Dat~, OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 5 3 0 0 2500 Tubing Pressure 3900 600O 25OO 395O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil _ Gas __ Suspended __ Service X {WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 ~.~_.~ Title Wells Superintendent Date { ~-/~Z~r/~z~[ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT __ WELL DESCRIPTION OF WORK 2-U-07 LOCK OUT TRDP & RUN IN~I. VALVE DATE CONTRACTOR I KEY PERSON IAFC/CC# - SCA# 11/19/94 HALLIBURTON / MOORE ( UN1T 70356 ) & LRS RANKIN ! 230DS28UL-40115 DAY OPERATON AT REPORT TIME IFIELD EST: IACCUMULATED COST I I I [~ COMPLETE r-'] INCOMPLETE $4,325 $4,325 TIME LOG ENTRY WHP- 3900 lAP- 2600 OAP- 400 l 100 MIRU HES & LRS PR,ESS TEST LUB & BOP'S & LRS TO 4000 PSI TS, ( 1.7/8 ) RS, QC, 5'WB, ICI, 5' WB, ICI, LSS, QC 1125 RIYI W 3.0" SB & F - COLLAR STOP DID NOT SET AT 1967'WLM 1215 CHANGE TOOL STRING TO 12' OF 2 1/8 WB, LSS, QC 1245 RIH W/3.0" SB & F - COLLAR SToP SET AT 1967' WLM 1330 RIH W/Z-5 LOCK-OUT TOOL SET AT 1863' WLM WRONG SPOT 1410 RIH W/3.0" RB TO 1863' WLM PULL Z-5 1450 RIH W/Z-5 SPACED OUT FOR TRDP-1A-SSA SET AT 1867' WLM (1895' RKB ) 1525 KIH W/2.45" BLIND BOX BEAT DOWN FOR 45 MINLrrES AT 1867' WLM 1630. RIH W/3.0" KB AND.PRONG PULL Z-5 AT 1867' WLM & F-COLLAR STOP AT 1967' WLM _ 1710 TRY A CLOSURE TEST TO SEE IF FLAPPER IS LOCKED OUT (TESTED GOOD DID NOT CLosE ) 1715 RIH W/CAN1~CO A-1 ]NJ. VALVE ON B-7 LOCK SET AT 1865' WLM 1745 PERFORM CLOSURE TEST ON VALVE 2500 D/P HELD GOOD FOR 15 M]N 1850 RD HES & LRS SUMMARY LOCKED OUT TRDP AT1895' RKB SET CAMCO A-1 ]NJ. VALVE AT 1895' RKB ON B-7 LOCK 1" BEAN * NOTE TAKES 3/4" PRONG BY 50" TO PULL TOTAL LENGTH 45" PERFORM CLOSURE TEST 2600 PSI DOWN TO 100 PSI FWHP - 100 IAI)- 2600 OAP- 400 Page I of 2 r CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather t Temp'' I Chill Fact°r I VlslbilitYReport °F °F miles Iwincl vel' I slgneaknots, AR3B-7031 l...--,~ ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 November 29, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Application for Sundry Approval (Form 10-403) on the following Kuparuk well. Well Action 2U-07 Variance(Inj 0 R l. If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (attach only) File: FTR112996 (w/o attach) RECEIVED DEC - 5 1994 Alaska Oil & Gas Cons. ComrolssiO~t Anchorage ARCO Alaska. Inc, is a Subsidiary of Atlantic Richtield Company STATE OF ALASKA ~----~. , SKA OIL AND GAS CONSERVATION COb. .~SION APPLICATION FOR SUNDRY APPROVALS REEEIVI:U DEC - 5 1994 1. Type of Request: Abandon __ Suspend__ Alter. casing __ Repair well Change approved program _ Operation Shutdown __ Re-enter su~§l~W~lGas Cons. COmllrlLssl0_l _ Plugging ~ Time extension _ Stimulate ,_.: ~UlShoi'a~?a ' Pull tubing __ Variance X Perforate __ Other __ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 604' FSL, 732' FWL, Sec. 32, T12N, R9E, UM At top of productive interval 1444' FNL, 1692' FWL, Sec. 6, T11N, R9E, UM At effective depth 1565' FNL, 1349' FWL, Sec. 6, T11N, RgE, UM At total depth 1607' FNL~ 1421' FWL~ Sec. 6~ T11N~ R9E, UM 12. Present well condition summary Total Depth: RKB 106 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2U-07 9. Permit number 65-91 10. APl number so-02 9-21283-01 11. Field/Pool Kuparuk River Oil Field/Pool measured 8 2 5 0 feet true vertical 6056 feet Plugs (measured) None Effective depth: measured 81 4 7 feet true vertical 5994 feet Junk (measured) None 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7880'-7952', 5836'-5879', Length Size Cemented -8 0' 1 6" 230 SX CS II 3606' 9 5/8" 730 SX PF'E' & 880 SX PF 'C' 8214' 7" 295 CLASSG& 250 SX PF 'C' Measured depth True vertical depth 101' 101' 3627' 2975' 8 2 3 5' 6047' Tubing (size, grade, and measured depth) 3 1/2", 9.3 LB/FT, J-55 RUE 7803' Packers and SSSV (type and measured depth) SSSV: CAMCO TRDP-1A-SSA @ 1895'~ PKR: OTIS RRH @ 7774' Attachments measured 7982'-7988', 7992'-7996', 8008'-8014', 8021 '-8026', 8050'-8056' true vertical °' Description summary of proposal X Detailed operation program _ BOP sketch 14. Estimated date for commencing operation 11/19/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Gas Service X (WAG) Suspended 17' Ih~fy.~t~re~i_ '2rue Si~ned.~ - ,...~..~/ C..~ and correct to the best of my knowledge. Title Wells Superintendent Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance ~ Mechanical Integrity Test Subsequent form require 10- -- ~pprovea Copy .Original Signed By Returned David W. Johnston /'~' Commissioner Approved by order of the Commission Form 10-403 Rev 06/15/88 IApp. rov. al Ne., SUBMIT IN TRIPLICATE Attachment I ,-.~, Request for Variance .',..? Kuparuk Well 2U,07 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the failed surface controlled, subsurface safety valve in Injection Well 2U-07 with a downhole, spring controlled, injection valve. This injection valve will act as a one-way check valve allowing downward injection of water and gas while preventing upward flow of these fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. STATE OF ALASKA :' ALASKA O~L AND GAS CONSERVATION CO~h~llSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OI1 I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-91 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21283-01 4. Location of well at surface 9. Unit or Lease Name 604' FSL, 732' FWL, Sec.32, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1444' FNL, 1692' FWL, Sec.6, T11N, R9E, UM 2U-7A At Total Depth 11. Field and Pool 1607' FNL, 1421' FWL, Sec.6, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 106' RKBI ADL 25644 ALK 2575 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8250'MD,6056'TVD 8147 'MD ,5994 'TVD YES [~X NO []I 1907 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, CNL/FDC, Cal, Gyro, GR/CBL/VDL, CCL 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 101' 24" 230 sx CS II 9-5/8" B6.0# J-55 Surf :3627' 12-1/4" 730 sx PF "E" & 880 sx PF "C" 7" 26.0# J-55 Surf 8235' 8-1/2" 295 sx Class G & 250 si PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7880' - 7952' 3-1/2" 7803' 7774' 7982' - 7988' 7992' - 7996' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 8008' - 8014' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8021' - 8026' See attached Addendum for frac data. 8050' - 8056' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I OIL-BBL GAS-MCF WATERiBBL iOIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APR 2 3 !98~ Alaska 0ii & Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run and the well perforated 4/21/85. DAM2/WC27 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. (~ i 30. i ', .. 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 Kuparuk B 7761' 5763' N/A Top Lower Sand 7856' 5822' Base Lower Sand 8096' 5964' 31. LIST OF ATTACHMENTS Addendum (dated 7/26/8'5) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge / ~ Associate Engineer Signed t//~~ ~ 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 ARCO Alaska, Inc. Post Otfice Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 20, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: ~lell Completion Reports Dear Mr. Chatterton' Enclosed are [.:Jell Completion Reports for the following wells' 2H-2 2U-7 ~ 2U-9 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L90 Enclosures RECEIVED Alaska Oil & Gas Cons. Commissi.~n a~r-~ ~tl~l~n Inr i~ :~ _q~h~i~Jiarv nf AtlanlicRichlieldComl3an¥ · '~'-' STATE OF ALASKA ALASKA L,,L AND GAS CONSERVATION CG,¥~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS I--I SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-,~;/.__ 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21283 4. Location of well at surface ' ' 9. Unit or Lease Name 60/+' FSL~ 732' FWL, Sec.32, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1/~/+' FNL~ 1692' FWL, Sec.6, T11N, RgE, UH 2U-7/~ At Total Depth 11. Field and Pool 1607' FNL~ 1/+21' F~/L~ Sec.6~ T11N~ RgE~ UR Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKB ADL 256/+/+ ALK 2575 12. Date Spudded . 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore [ 16. No. of Completions · ~ '~/,,~,~"[/~'~- 03/23/85 03/2/+/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8250'ND,6056'TVD 81/+7'ND,599/+'TVD YES r~x NO [] 1907 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SPs CNL/FDCs Ca1, Gyro, GR/CBL/VDLs CCL 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-/+0 Surf 101' 2~" 230 sx CS II 9-5/8" 36.0# J-55 Surf 3627' 12-1//+" 730 sx PF "E" & 880 sx PF 'C" 7" 26.0# J-55 Surf 8235' 8-1/2" 295 sx Class G & 250 s~ PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7880' - 7952' 3-1/2" 7803' 777/+' 7982' - 7988' 7992' - 7996' w//+ spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8008' - 801/~' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8021' - 8026' 7730' - 7580' 200 sx Class G 8050' - 8056' 6308' - 6008' 135 sx Ciass G See attached Addm dum for fr~. d~_ 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 I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressur® 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. kECEiVED Alaska 0il & Gas Cons. Commissior; Form 10-407 * NOTE: Tubing was run and the wel I perforated /+/21/85. GRU11/WC19 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' ' ' ' GEOLOGIC MARKERS ' I' FoRMATIONTES~S'.' '' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk B 7761~ 5763' N/A Top Lower Sand 7856~ 5822~ Base Lower Sand 8096' 596~~ .. . . 31. LIST OF ATTACHMENTS :'. Addendum {dated 7/26/85) 32~ I hereby certify that the foregoing is true and correct to the best of my knowledge (~ ~ ~~/.~ Title Ass°c'ate Engineer Date Signed - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) Or other elevation (DF, KB, etc.). Item 23' AttaClqed supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 5/08/85 ra~c well w/335 bbls gelled diesel in 8 stages w/700# 100 mesh & 14,500# of 20/40 mesh. RU Otis "E" line. RIH w/temp tl & CCL. Tag fill @ 8020' (127' of fill covering lower 11' of perfs). Temp tl failed, POOH. Drilling S~perintendent RECEIVED '1 '" SEP 2 / ~98b Oil & Gas Cons. Commission Anchora~e ~ ~ate ' ARCO Alaska, Inc. Post Office Bo~, i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 30, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2U-7~ 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 GRU10/L99 Enclosures RECEIVED '~."?~:~,ka Oil & Gas Cons. Cornm~,ssion Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .--- ALASKa..~IL AND GAS CONSERVATION C~_ AMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-~ ~/ 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21283-- 4. Location of well at surface - 604' FSL, 732' FWL, Sec,32, T12N, RgE, UN LOCATI~)N~ 9. Unit or Lease Name Kuparuk River Unit VERIF~..~D At Top Producing Interval 10. Well Number 1444' FNL, 1692' FWL, Sec.6, TllN, RgE, UN $~rfL r/ 2U-7/~ At Total Depth _.~._~1. ~_. · 11. Field and Pool 1607' FNL, 1421' FWL, Sec.6, T11N, RgE, UN - Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Ot 1 Pool 106' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore J 16. No. of Completions ~ ~'~/p~'" 03/23/85 03/24/85* N/A feet MSLJ 1 '17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8250'ND,6056'TVD 8147'ND,5994'TVD YES ~X NO [] 1907 feet MDJ 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, CNL/FDC, Cal, Gyro, CR/CBL/VDL 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 101' 24" 230 sx CS I I 9-5/8" 36;0# J-55 Surf 3627' 12-1/4" 730 sx PF "E" & 880 sx PF "C" 7" 26.0# J-55 Surf 8235' 8-1/2" 295 sx Class G & 250 s~ PF "C" , , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7880' - 7952' 3-1/2" 7803' 7774' 7982' - 7988' 7992' - 7996' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8008' - 8014' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8021' - 8026' 7730' - 7580' 200 sx Class G 8050' - 8056' 6308' - 6008' 135 sx Class G . 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD e .. Flow Tubing Casing Pressure CALCULATED=~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~1~ 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alaska Oil & Gas 6'ohs. Corr~m]s~;ior~ Anchor~,qo Form 10-407 * NOTE: Tubing was run and the well perforated 4/21/85. TEMP/WC56 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' . GEOLOGIC MARKERS - : ' .... FORMATION"FEsTs · NAME Include interval tested, pressure data, all fluids recovered and gravity, ,. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kupar.uk B 7761' 5763' N/A Top Lower. Sand 7856' 5822' Base Lower. Sand 8096' 5964' 31. LIST OF ATTACHMENTS We]l Histor.y., Gvr.oscooic Survey {2 COOies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~.~')/.~ . ~J-/-,~..,4._~ . __Title Assocf a,e Eng, neet Date /1 - 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 (G L) 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 AtlanticRichfieldCompany J' Dally Well History-Initial Report lalll~ltoal: Prlplrl and SuOmit the "lflltlll Rl~orl" on the licit Weclfloldly Ifil/ · well is spudded or workOV~r oPlrltiofll afl Itl;ted. Dilly wor~ prior to $1='ddding should 131 summlrizid on the form giving inclulivl dltll only. District I County or Pmrtlit Alaska Field ilo.., or Unit I Kuparuk River Auth. or W.O. nO. ITitle I ~ 603643 North Slope Borough State ADL i/25644 Drill· Complete & Perforate Alaska 3/19/85 3/16/85 thr~ 3/18/85 3/15/85 21.66% Date a.d dep~ u of B.'OQ I.m. Complete record for each day 16" @ 10l' 1323', (1222'), DD Wt. 9.3, PV 20, YP 18, PH 9.0, WL 15.2, Sol 6 Accept ri~ @ 1145 hfs, 3/14/85. NU diverter sys. 1530 hfs, 3/1~/85. Drl & surv 12¼" hole to 1323'. 597' Assumedvertical 810', 6.2°, S71.5W, 810 TVD, 11VS, 4S, llW 1021', 14.2°, S69W, 1017 TVD, 49 VS, 16S, 46W 1233', 20.8°, S67W, 1220 TVD, 112 VS, 40S, 105W Spud well @ 9-5/8" @ 3627' 7400', (5877'), Drlg ahead Wt. 10, PV 13, YP 7, PH 9.5, WL 5.6· Sol 10 Drl & surv 12¼" hole to 3645', C&C, TOE. Rn & lnd 83 its, 9-5/8", 36#, J-55 BTC cst w/FS @ 3627', FC @ 3537'. Cmt w/730 sx PF "E" & 880 sx PF "C". Displ w/275 bbls mud. Bump plug. CIP @ 1140 hfs, 3/16/85. Press ce8 Co 1500 pet; OK. Good circ thruout job. Circ'd 200 sx cmo co m~rf. ND div~Ce~, NU & tst BOPE. PU BHA, RIH, DO FC, cmt, l~i+ I0' ne~"l~to.~55'. Press tst formation to 11.8 ppg EMW. .Drl & su~v 8½" hole to 7400' 1449' 1930' 3991' 4546' 5083' 5558' 6104' 7051' . 27.2° , , S64W, 1416 TVD, 200 VS, 76S, 185W , 37.9°, S67.TW, 1825 TVD, 453 VS, 178S, 416W · 47.9°, S67W, 3231TVD, 1952 VS, 650S, 1845W · 45.6°, S60.6W, 3611TVD, 2356 VS, 829S, 2208W · 44.1°, S60.3W, 3992 TVD, 2370 VS, 1016S, 2537W · 48.1°, S66.5W, 4321TVD, 3072 VS, 1169S, 2843W · 44.4°, S63.4W, 4699 TVD, 3467 VS, 1336S, 3200W · 47.5°, S62W, 5339 TVD, 4163 VS, 1649S, 3824W 9-5/8" @ 3627' 8150', (750'), POH to log Wt. 10.5, PV 16, YP 10, PH 9.5· WL 5.2· Sol 15.2 Drl & surv 8½" hole f/7400'-8150', CBU, short trip to rn OHL. 7535', 44.5°, S62.6W, 5675 TVD, 4510 VS, 1810S, 4131W RECEIVED Alaska Oil & Gas b'-~s:l~ommtssion AnchorageU~ Title 5101185 [ Drilling Superintendent Doyon #9 AP1 50-029-21283 OD~rmar I A.R.Co'a W.I. .A~CO Alaska, Inc. I ARCO 011 and Gas Company Daily Well History--Interim Inltnicl~lll: Thi! form ~s used during drilling Or workover operations. If testing. COrln(J. Or oertorat~ng, show Iormahon name ,n ,.'lescr~bing work oeffol'msd. Number Ill drill stem teals sequenhally. Attach descril:)hon of all cores. Work oerformed by Producing Seclion will be rePorteo on "lnlerim" sheels unld hnil completion. Report official or represenlaliva lest on "Final" form. 1)' Submit "Intel'lin" sheets when tilled out but not lass Irequsntly II, an eve~ 30 days. or [2) on Wednesday o! the week in which oil string is set. Submit weekly for workovara and following se[ling of oH st,nG until comolehon Dlltrlct Field Dltl Ind dlpt~ es of 8:00 i,m. I County or Penal1 Alaska North Slope Borough I LIISl or Unit Kuparuk River ADL #25644 Complltl record for each day wllill drilling or workover in progress 3/20/85 3/21/85 3/22/85 ISlale Alaska 9-5/8" @ 3627' 6000' PB (Sidetrack), WOC Wt. 10.5, PV 16, YP 10, PH 9.5, WL 5.2, Sol 15 RU Schl, rn DIL/SFL/GR/SP f/8145'-3627', FDC/CNL f/8145'-7450', CAL f/8145'-6500', RD Schl. RIH, C&C f/csg. After log evaluation, decision made to sidetrack hole due to a fault that decreased net pay zone. TOH. TIH w/OEDP_to 7730', C&C mud. Set balanced cmt plug f/7730'-7580' w/~5~dl "G" w/l% CFR-2. CIP @ 0300 hrs, 3/20/85. POH. MU BHA, WOC. Sidetrack procedure verbally approVed by AOGC. ,, 9-5/8" @ 3627' 6292', (292'), Sidetrack 8½" hole Wt. 10.0~.~ 10, YP 9, PH 10.5, WL 9.4, Sol 11 WOC. R~H,~.-dY1 cmt to 6112', circ & POH. PU Navi-Drl, RIH, --~i~d~t~ck original hole south to 6292'~. 9-5/8" @ 3627' 7600', (1408'), Trip f/BHA Wt. 10.2, PV 14, YP i0, PH 10.0, WL 5.2, Sol 12 Drl & surv 8½" hole to 7600'. 6257', 44.1°, S58W, 4808 TVD, 3573 VS, 1388, 3294 6740', 50.4°, S50.2W, 5136 TVD, 3919 VS, 1593, 3582 7535', 50.4°, S50W, 5642 TVD, 4507 VS, 1984, 4055 The aloove is correct 0rilling, Page, 86 and B7 IOate 5/01/85 .-.. ~.. Drilling Supe'ri.ntenden~ ARCO Oil and Gas Company Daily Well History-Final Report Instfucfiolte: Prepare and suOm,t the "Final Rel=ort" on the hrst Wednesday alter ailowaDle nas been ass,ghee or well ~s Plugged. Ai3an(~orled. or Sold "Final Repofl' sl'tould be suomltted also when operations are suspencled for an mclehmte or apOreclaOle length of t;me On word<overs when an offic,al test ,s not required upon completion, report completion and representative test data ~n OloCkS provided. The "Final Ril~ofl" form may 13e used for reporhng the entire operation if space ~s avadal31e. District ICounty or Parish Alaska Field [Lease or Umt Kuparuk River Auth. or W.O. no. I Title I AF~. 603643 Doyon #9 Ope~tor ARCo. W I ARCO Alaska, Inc. 21.66% Spudded or W.O. begun Spudded · Date and depth Data 3/16/85 3/23/85 thru 3/24/85 · as of 8:00 a.m. 4/ol/85 4/02/85 4/03/84 Complete record for each Say reported North Slope Borough ADL #25644 Drill, Complete & Perforate Accounting cost center code Stats Alaska 2U- 7A AP1 50-029-21283 I otal numi~er of wells (active or ~nact~ve) on pst center prior to plugg,ng and [ ban(tonment of this well our I Prior etatus if a W.O. I 1530 Hrs. 7" @ 8235' 8250', (650') ,..,Ri~ lO.l ppg Bri~e ~ Drl 8½" hole to 8/50', C&C, short trip, circ, POH. RU & rn DIL/SFL/GR/SP/CAL f/8143'-3626'. Rn CNL/FDC f/8143'-7600', RD Schl. Drl 8½" hole to 8250', short trip, C&C, POH. RU & rn 198 its, 7", 26#, J-55 BTC csg w/FS @ 8235', FC @ 8147'. Cmt w/295 sx C1 "G" w/l% CFR-2, 5% KC1, .3% Halad-24. Displ w/10.1 ppg brine. Bump plug. CIP @ 0755 hfs, 3/24/85. Tat csg. ND BOPE, set slips & pack-off & tat same. RR @ 1400 hfs, 3/24/85. 8100', 54°, S58-1/4W, 5988 TVD, 4946 VS, 2245S, 4417W Pmp 250 sx PF "C" cmt. Tagged w/9 mc IR-129. Displ w/58 bbls 7.7 ppg Arctic Pak. Press up 9-5/8" x 7" ann to 1000 psi. Lost 50 psi aft 1 hr. Rn GR/CBL/VDL f/8122'-5750'. Rn GR to surf. f/8095'-surf. OIdTO Il"'wTo 8250' (3/22/85) Released rig [ Date 1400 Hrs. [ 3/24/85 Classifications (oil, gas, etc.) Oil Rn gyro Type completion (single, dual, etc.) Single Produqing metho'd Official reservoir name(s) Wait on completion rig- Kuparuk Sands . . ~ote~tial test ~a Well no. Date Reservoir Producing Interval Oil or gas Test time Procluction (~il on test Gas per ,'Jay Pump size. SPM X length Choke s~ze T P. C.P. Water % GOR Grawty Allowable Effective date correcled The spore is Correct For form preparation and ~Jstribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. Drilling Superintendent IoJ~TU~ TO: ARCO Alaska, inc. Post Offic"--'~ox 100360 Anchorage, ,Maska 99510-0363 Telephone 907 276 1215 ARCO ALASKA, INC. KUPARUK OPERATION5 RECORDS CLERK ATO-1115B P.O. BUX 1U0360 ANCHORAGE, AK 99510 DATE: 08-16-85 TRANSMITTAL NO: 5254 ENGINEERING TRANSMITTED hEREWITH ARE THE RECEIPT AND RETU~ PRESSURE FINALS FOLLOWING IT~]S. PLEASE ACKNO~LEDGE ONE SIGNED COPY OF THIS TRANSMITTAL. CAMCO lB-3 04-21/22-85 1D-8 04-29-85 1E-5 04-26-28-85 1H-6 04-29-85 1L-2 04-24/25-85 1L-5 04-28/29/85 lQ-6 lQ-9 2A-5 PBU ' STATIC PBU STATIC PBU PBU PRESSURE FALL OFF PBU PRESSURE FALL OFF STATIC PBU PBU PBU PBU STATIC PBU STATIC STATIC STATIC PBU STATIC . · PBU PBU PBU STATIC STATIC PBU STATIC. STATIC 2A-5 2C-4 2F-7 2F-8 2F-9 2G-1 2G-1 2U-5 2U-6 2U-7 2U-8 2X-'10 OTIS ~. 2A-2 ~- 2U- 14 [ 2V-2 "i 2v-5 j: 2V-13 ~ 2V- 14 '~ 3B-3 : 3B-8 RECEIPT ACKNU~LEDGED: B. CURRIER CHEVRON* D & M· : 05-07-85 05-12/13-85 0 0 0 0 0 04-21/22-85 .' 05-05-85 04-24/25-85 04-14-85 4-19/20-85 4-13/14-85 4-17-85 4-29-85 5-02-85 5-03-85 05-04-85 05-04-85 04-25/26-85 07-04-85 06-30-85 07-27-85 06-25-85 06-22-85 06-22-85 07-26-85 06-28-85 06-28-85 DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ALASKA OIL A#D EA$ ~,O#$EIIIWTIO#.~,OM~I$$10~f ! ./:;,' soot / ::"* ANCHOR&OEoALABKA ! ~ / - ' We wish to bring to your attention ~hae the Co~i~sion has no~ zet received the following required items on the subject well which our record$ indicated was completed _~- ~ ~.-~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 daTs after completion of a drilled.well. Please submit the above missing material. ,. Chairman lc~C.024 ' ARCO Alaska, Inc. Post Office box 100360 Anchorage. Alaska 99510-03G0 Telephone 907 276 1215 DATE: 05-29-85 TRANSMITTAL NO- 5199 RETURN TO: T 1L\N SM ITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-111513 P.O. BOX 100360 A~'~HORAGE, AI'[ 99510 tiEREWITIi ARE TIlE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN O,~E SIGNED COPY OF THIS TRANSMITTAL. KUPARUK I~ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 STATIC- 'C ' SAND 2A-7 04-23-85 STATIC-'A' & 'C' SAND 2F-6 03-21-85 STATIC-PBU- 'A ' SAND 2G-8 03-21-85 PBU-'A' SAND 2G-12 03-23-85 STATIC-PBU-'A' SAND 2H-i3 04-26-85 STATIC-'A' SAND 2][-14 04-28-85 STATIC-'A ' SAND 2H-15 04-29-85 STATIC- 'A' SAND 2U-1 04-11-85 PBU-'A' SAND 2U-2 04-11-85 PBU-'A' SAND 2U-3 04-11-85 STATIC-'A ' SAND 2U-4 04-11-85 STATIC-'A' SAND 2U-5 05-02-85 STATIC-'A' -SAND 2U-6 05-03-85 ~ STATIC-'A' SAND 2U-7 05-04-85~7~ST~.~TC-'A' SAND 2U-8 05-04-85- 'l/ STATIC-'A' SAND 2U-13 03-09-85 STATIC 2U-14 03.21-85 STATIC-'A'&'C' SAND 2U-!5 03-20-85 STATIC-'A' &'C ' SAND 2U-!6 03-15-85 STATIC-'A' &'C' SAND 2V-2 03-23-85 STATiC-'C' SAND 2V-SA 03-17-85 STATIC-'C' SAND 2v-SA 01-24-85 STATIC-'A ' &'C ' SAND ~W-4 04 - 13-85 S'""' ~ IC-.~. ' A ' SAND 2X-! 04-14-85 STATIC-'A' &'C ' SAND 2X-3 04-13-85 STATIC-'A'&'C' SAND 2X-13 03-30-85 PBU-'A ' SAND -',ECEIPT ACKNOWLEDGE D: DISTRIBUTION: ;PAE* DRILLING W. PASHER ~, . C~-::~TER*~.,.,~- L. JOIi~,~STON~, EXZON I1EV~,O,-]* MOBIL~- PI-! iLLIPS OIL* > & M* NSK CLERK J. ,~AT.'h'.~LL* DAT~i~,:? (ii, ~ b~.s Ccr, s. t;ul;;mission STATE OF ALASKA* SO~[iO* UNi Di'~* K. TULiN/VAULT ARCO Alaska, Inc. Post Office Box .d0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. a~ f~ Enclosed is a copy of the 2U-7 Well History to include with the Well Completion Report, dated 04/23/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L116 Enclosure cc' 2U-7 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' AtlanticRichfieldCompany Daily Well History-Initial Report Inltmctiohl: 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 i County or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AF~. 603643 North Slope Borough ADL #25644 Drill, Complete & Perforate JState Alaska IWall no. 2U-7 Doyon #9 API 50-029-21283 Operator J A.R.Co's W.I. ARCO Alaska, Inc. I 21.66% Date and depth as of 8:00 a.m. 3/15/85 3/16/85 thru 3/18/85 3/19/85 !Complete record for each day reported 16" @ 101' 1323', (1222'), DD Wt. 9.3, PV 20, YP 18, PH 9.0, WL 15.2, Sol 6 Accept rig @ 1145 hrs, 3/14/85. NU diverter sys. 1530 hrs, 3/14/85. Drl & surv 12¼" hole to 1323'. 597' Assumed vertical 810', 6.2°, S71.5W, 810 TVD, 11VS, 4S, llW 1021', 14.2°, S69W, 1017 TVD, 49 VS, 16S, 46W 1233', 20.8°, S67W, 1220 TVD, 112 VS, 40S, 105W Spud well @ 9-5/8" @ 3627' 7400', (5877'), Drlg ahead Wt. 10, PV 13, YP 7, PH 9.5, WL 5.6, Sol 10 Drl & surv 12¼" hole to 3645', C&C, TOH. Rn & lnd 83 its, ' 9-5/8", 36#, J-55 BTC csg w/FS @ 3627', FC @ 3537'. Cmt w/730 sx PF "E" & 880 sx PF "C". Displ w/275 bbls mud. Bump plug. CIP @ 1140 hrs, 3/16/85. Press cs~ to 1500:.psi; OK. Good circ thruout job. Circ'd 200 sx cmt to surf. ND-.d.i-verter, NU & tst BOPE. PU BHA, RIH, DO FC, cmt,.E$~.~.1Or' ne~r~e[~ to. 3655'. Press tst formation to 11.8 ppg EMW. Drl & surv 8½" hole to 7400'. 1449', 27.2°, S64W, 1416 TVD, 200 VS, 76S, 185W 1930', 37.9°, S67.7W, 1825 TVD, 453 VS, 178S, 416W 3991', 47.9°, S67W, 3231 TVD, 1952 VS, 650S, 1845W 4546', 45.6°, S60.6W, 3611TVD, 2356 VS, 829S, 2208W 5083', 44.1°, S60.3W, 3992 TVD, 2370 VS, 1016S, 2537W 5558', 48.1°, S66.5W, 4321TVD, 3072 VS, 1169S, 2843W 6104', 44.4°, S63.4W, 4699 TVD, 3467 VS, 1336S, 3200W 7051', 47.5°, S62W, 5339 TVD, 4163 VS, 1649S, 3824W 9-5/8" @ 3627' 8150', (750'), POH to log Wt. 10.5, PV 16, YP 10, PH 9.5, WL 5.2, Sol 15.2 Drl & surv 8½" hole f/7400'-8150', CBU, short trip to rn OHL. 7535', 44.5°, S62.6W, 5675 TVD, 4510 VS, 1810S, 4131W ,., ju N o 6 1 B5 -~.[;t...'. :-. .,<: ~a~ Cons. commission ~C~ ?~ch0r~ge The above is correct For form preparation and distribu/~on, see Procedures Manual, Section *~0, Drilling, Pages 86 and 87. JDate I Title 5/01/85 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 '*lnlerim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently Ihan every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly Ior workovers and following setting of oil string until complefion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL #25644 Complete record for each day while drilling or workover in progress 3/20/85 3/21/85 3/22/85 lSlate Alaska Well no. 2U-7~ 9-5/8" @ 3627' 6000' PB (Sidetrack), WOC Wt. 10.5, PV 16, YP !0, PH 9.5, WL 5.2, Sol 15 RU Schl, rn DIL/SFL/GR/SP f/8145'-3627', FDC/CNL f/8145'-7450', CAL f/8t45'-6500', RD Schl. RtH, C&C f/csg. After log evaluation, decision made to sidetrack hole due to a fault that decreased net pay zone. TOH. TIH w/OEDP_to 7730', C&C mud. Set balanced cmt plug f/7730'-7580' w/~Cl "G" w/l% CFR-2. CIP @ 0300 hrs, 3/20/85. POH. MU BHA, WOC. Sidetrack procedure verbally approved by AOGC. 9-5/8" @ 3627' 6292', (292'), Sidetrack 8½" hole Wt. 10.0, PV 10, YP 9, PH 10.5, WL 9.4, Sol 11 WOC. RIH, drl cmt to 6112', circ & POH. PU Navi-Drl, RIH, sidetrack original hole south to 6292'. The above is correct Signature ~.~ For form preparation ~n~ d~tribution see Procedures Manual Se~ion 10. ' Drilling, Pages 86 and 87 9-5/8" @ 3627' 7600', (1408'), Trip f/BHA Wt. 10.2, PV 14, YP 10, PH 10.0, WL 5.2, Sol 12 Drl & surv 8½" hole to 7600'. 6257', 44.1°, S58W, 4808 TVD, 3573 VS, 1388, 3294 6740', 50.4°, S50.2W, 5136 TVD, 3919 VS, 1593, 3582 7535', 50.4°, S50W, 5642 TVD, 4507 VS, 1984, 4055 JOate ]Title 5/01/85 ..... Cons, Commission Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended lor an indefinite or appreciable length of time. On workovers when an official lest 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. I Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field Lease or Unit ~Well no. Kuparuk River ADL #25644 I 2U-7~ Auth. or W.O. no. I Title AFE 603643 I Drill, Complete & Perforate Doyon #9 Operator ARCO Alaska, Inc. A.R.Co. W.I. 21.66% Spudded or W.O. begun Date Spudded 3/14/85 Date and depth Complete record for each day reported as of 8:00 a,m. 3/23/85 thru 3/24/85 4/01/85 API 50-029-21283 I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 1530 Hrs. 7" @ 8235' 8250', (650'), RR 10.1 ppg Brine oK Drl 8½" hole to 8/50', C&C, short trip, circ, POH. RU & rn DIL/SFL/GR/SP/CAL f/8143'-3626'. Rn CNL/FDC f/8143'-7600', RD Schl. Drl 8½" hole to 8250', short trip, C&C, POH. RU & rn 198 its, 7", 26#, J-55 BTC csg w/FS @ 8235', FC @ 8147'. Cmt w/295 sx C1 "G" w/l% CFR-2, 5% KC1, .3% Halad-24. Displ w/10.1 ppg brine. Bump plug. CIP @ 0755 hrs, 3/24/85. Tst csg. ND BOPE, set slips & pack-off & tst same. RR @ 1400 hrs, 3/24/85. 8100', 54°, S58-1/4W, 5988 TVD, 4946 VS, 2245S, 4417W Pmp 250 sx PF "C" cmt. Tagged w/9 mc IR-129. Displ w/58 bbls 7.7 ppg Arctic Pak. Press up 9-5/8" x 7" ann to 1000 psi. Lost 50 psi aft 1 hr. Rn GR/CBL/VDL f/8122'-5750'. Rn GR to surf. Rn gyro f/8095'-surf. Old TD Released rig INew TD Date PB Depth 8250' (3/22/85) Kind of rig 1400 Hrs. 3/24/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producir~g method Official reservoir name(s) Wait on completion rig Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on lest Gas pe~a~..,, f ~' Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable E[fective,~ Jl~ 0 l corrected ~ Ala, ;ka Oil & Gas C~ Thn nhnv~ i~ cnrrect ' "'~llidJ~ VED Commission For form preparation ~nd distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office ~_.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 25, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-7 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2U-7~. I have not yet received a copy of the Well History, but when I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the' well completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU6/L49 Enclosure MAy 0 1 1985 0ii & ems Cons. Comm~a~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ° STATE OF ALASKA ALASKA .AND GAS CONSERVATION C¢ ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED J~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21283--¢21 4. Location of well at surface 9. Unit or Lease Name 604' FSL, 732' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2U-7~ At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet {indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 106' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 16. No. of Completions ~ 3/~'/~¢'- 03/23/85 03/24/85} N/A feet MSL N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8250'MD 8147'MD YES [] NO I~lXI N/A feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, CNL/FDC, Cal 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 101' 24" 230 sx CS II 9-5/8" 36.0# J-55 Surf 3627' 12-1/4" 730 sx PF "E" & 880 sx PF "C" 7" 26.0# J-55 Surf 8235' 8-1/2" 295 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) None N/A ;~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,. 7730' - 7580' 65 sx Class G 6308' - 6008' 135 sx Class G 27. N/A PRODUCTION TEST Date First Production J 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 iTEST PERIOD I Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl i'corr) Press. 24-HOUR RATE ~1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED MAY o 1 1985 Alaska Oil & Gas Cons. Anchorage Form 10-407 TEMP/wc07 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -:' , -~': '.- GEOLOGIC-MARK'ERS' ':: :: :' -' 7':-' ' ' i~'' '-.-' '- · - 'FORMATION ' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time· of each phase, N/A --- N/A · , . . ,, . . . . : · -. 31. LIST OF ATTACHMENTS .. ~O.n. ~ ... ~ - 32. I hereby Certify that the foregoing is true and correct to the best of my knowledge _ . Signed ~ ~ L~~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. : Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: 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". I:;nrm 1 n~n7 Eastman/ Whipstock A PETROLANE CC~PANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY Pad 2U, Well No: 7. WELL NAME (w/sidetrack) KUPARUK FIELD, NORTH SLOPE, ALASKA LOCATION JOB NUMBER A0385-D0193 TYPE OF SURVEY Go Mwd RECEIVED DATE 14-Mar-85 J · SURVEY BY Jennin~s APR 2 3 !986 Alaska 0i! & Ga..~ Cons. CDmmission Ancho:~g,~ OFFICE Anchorage, Alaska Eastman Whip st oc=c k Date: April 12, 1985 (907) 563-3650 P. O. Box 4-1970~Anchorage, A/aska 99509-1970 ARCO Alaska, Inc. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: Pad 2U, Well No: 7 Location: Kuparuk Field, North Slope, Alaska Type of Survey: Go Mwd Date: 14-Mar-85 Method of Computation: Radius of Curvature Surveyor/Driller: J. Jennings Job Number: A0385-D0193 Atten: Mr. BILL CONGDON Dear Mr. Congdon: -~,= . ~ copy,/copi.~.., of the ¥~.. are enclosing the oriqinai and one '~-: . Go Mwd survey run on the above mentioned wel~ To date, the fo_!lowing distribution has been accomplished: A. 1 copv/co~_)ies~_,, : dei i,>'~'red..,_ to dr i"ling, z for'. in-- house distribution. B. 6 copy/copies noted for oil company represen- tatives. C. 3 copies for E/W permanent well files. We wish to take this opportunity to thank 7ou for usJn. g Eastman %,H]ipstock and look forward to being of se,~-v].ce in the future. L.,~ ict Technica.~ Coordinator' cc/file cc: P.A. Dinmock - BP Alaska Exploration Karen Mes'tas - Sohio Alaska Petroleum Co. Steve Lambert - Union Oil Company T.A. Edmondson - Cheveror. r.i~S.A. N.H. Smith, Jr. -Mobil Oil Corp. J~C. Wi!!ner - Phillips Petroleum Co. RECEIVED APR 2 ~' ~0O Alaska Oil & Gas Cons, Comm!-~sion Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ~ RC(] Al.. ASK A., ~ I',IC. I'--'~ D ~].. ,, W EL.I.. N 0: 7 I":~O M ~ d K I...I PA R I...I K F' ].' E I... D, WI') R T U '.~i;I.. O F:' E~ A L A'.!.~; K A f':;CI I'"1~,:1, (') -- 7 !E; :-": 5 MD, DR I LL_I"-'R RIG: IitOYON 9 F::PLID ]IiIATE: 1. 4 .... HAR-'85 (15::2:(') PM) .... Ir] B N O: ¢../,:it :'::: S 5 f'l,::], 1 'T,' '::: VERTICAL F::EE:'l"If"d',l CALF:LILA"I'EI] IN I='LANE OF []'[RE:r":TIOiq: S ;!:../:. OI.":G, 21 MII',I, W R E F r3 R D OF':' S UR V E Y RAI) ILItE; ~'-IF ':::IJF;:VA"FL.IRE ME]"HOD _ Eastman C "f A L. A S K ~ 1: Ix!C, C 0 M P LIT A T T (] N F::' ('/E~F' Nl"'l ,, 1. }rg] 21J, WEI_.L NO: 7 I':iil") Mu~,J ,_I[.)D NF_'I .' g~C):'.~:::::SF'lf') 19:3 '1' I ME DA]"E ~ F'ARIJK F I EI...D., I'qOF;:"FH '.::_:; I... A F:' I::: ., AI..~~SKA 1 :"::: 51: 52 I 1 -~PR-'::::5 '1" R LJli!~. ASI_IRED ]DF(IF:T DRIFT I-;ClLIRSE Vli.::RTICAL. VERTICAL. :!ii;L.IBSEA R E Ii: T A hi G I_1 L.. A R C L Cl S I_1 R E"' DOGL. EG EF"I'I'"I AIqGL. E:' DIRECTIFIN 1_I::]',I(3TH DEPTH :BE"I"-:TIOIq TVD C: 0 0 R D I N A T E ::'; DISTANC[E DIRECTION F:;EVEF"<I"FY F E: E: 'i" D I"1 ]E.I FI F E E T F E E T F E E '1" ' F F' ["_ T F E E T F E E T D M D G'/! ('F('-) F:' T 0, (") 0 (:) () (':), 0, 00 ('). ()0 .... 106,, 00 O, (')0 0.00 O, 0~") 0 0 c), ()c) LI_ A::::SUMEE~ VI.EF;:"I"I(]:AL 1"0 5'.:'.~7'" 597. (-') 0 ~") 0 :'-':10, 6 12 :::': '71:30 W 1021, 14 12 '.:::: /_-,'? (:) W 12 :--::--:. '20 ,.1. 8 S ,_,/'' ~, ('). W 14.4'i.:/,, 27 1::.':' S 64 :.!:4. W 1682. :3('-) !54 S .... L/._, z.k... ''"' W 19:3C), 37:54 '.E; 6'7 36 W ":' '='- 4.2 :24 · . 1 !.'-10, ,t...., S 68 W 24/_-. 4. 4 :;.: 1.'2 ....':' 72 ("). W :ii'. 1. 6. :1, 416. :38 '2:3:3. 16 :.2 c). ():3 :248 ,, 1824. '.5 :=: 220. ]. 908..41 :314 """' C '"~. . ....-'..).. 7.4 :2:00. 1 '.'-.~ 1:310. :38 :31:3. :;ii: 9 15.1. 4. ,, 0:3 45:3.30 1 '71 E',. 5 :=', 59'i..), 76, i :.'=~ 82.4.1 8 2 8 ,, 6 5 2 096, ,, 7 4 :3001. 4. 7 '::', · _~ S '74. !2 W :'::500. 4.7 6 :.:!; 7:':: 4.2 H :'::'F~'F~I, 47 .:;4 S 67 0 W 454.6. 4.5:3/", '.:.i; 60:36 14 50::::3. 4.4 6 S ,'.':,C) 18 W ........ · .:...' ........ ~. ~::..~ ...... :, '72 426, 14. S 11..,(). W ]. 2':..";7. :3 (") 6'--~ :1 W ., · # ..... ._l .. 49'.:.'/ 2 ::::',':} ::: 8 ::ii: ]. :: """') ::'::' ............. ,, :, ::. _ . 2'792.8:7: 5..'2'7 . ,.,....'::' ~ 'E;' 15 (') 4 . P[ ..... 1 W I .'=;':} 4 .42 '.S 7 (").4 ("~. W 491. 32:30.54 :1. 9 E! 0. :'"'!: 1 :::: 124. !54 649.51 '.E; 184..5.2 :':: W 19!56.21 S 7 ('-} :36 W 555. :3,":, 1. 0,79 2:354,42 :35 (1) 4,79 :.'327, :::', 9 '.E; 2:207, '74 W 2:357, :B 6. S 6,'ii) :;27 W 5:37, ..."::', ':).. ':;.. 1 . 4 '-..-/. 27:31 , 1:3 .:,"-',:,,:::,"" ._, ~-- , 4 '::).. :L (") ...... .L 4 /.,.~;S ..'"' '"'; .... '"";, ~'7. :2: c)_ W 27 :-] 2 , '56 ::.'!; ./::, .... ::::12 W I:.%:' ~.. I:."' I"l ......... ,,=,. 48 6 '._; 6,6, :.-,:0 W 6,10 4-. 4 4 '.':': 4 S ,_,~.- ._,":' 24. W 657'.--./. 4::.': 5zl '..:_; /_",4 C-) W 7051. 47 :-'-:0 '._:: 62 0 W 7535. 44 30 S L-.2 36 W 475, 4:':.:':::'0,79 3(')72,70 4.214,7'? ]. 16'7,80 S ]:':'-":4:2:, (')2 W :307:'::. 5';!: :-':; 67 40 W 546,, 46, 98, :29 :':i: 466. ::3 :::: q-5'P 2 ,, :29 i ::: :::: 4., 74 S :'"i: 200, 2:3 W :E-:.467..4- 2 S 67 2':? W 47 ::";. 502.':: 4,2. 7 :'::: :F: 11,82 4918.27 148'7,74 '._:; :':: 5 (:)9.79 W :':: 812, (:)9 '.:i; 67 2 W · 1.'72, .=; :':::'::8. ::37 ,1-16:3, () &, t:::; 2 7'.'.::, 87 1/_-,.47 · 47 '.B :':::::2:3, '2:3 1,4 416:3. :/:7: :_:; .<':.6 41 W 484, .567.5, o5 .... ,-1..~:; 10 ,2:1 .... .,....,,.:,' ":~ . ('):'~. . 1 :_:: C) '-:~. . .,_':":).. '.:: 4.12: ] , .~--; ..... 1_ 14 4.'=; 1 ("} . :31 . '.E: ./:,/-,_ 21 W 1.2/_', (-). 7 0.4..:. 0.6:':: ::_-"; ,<:,6 DEr-~:=; 0 M IN:=: W 4. 982, .~-; 1 F' E E-I' F I I'qAL C L A:::;I_IRE .- D I R ECT I C~N: D I '.:.'; ]- A N C E ,', 0.00 Eastman _l]'"t}]!J NO '- A C) :~.: L:.!: !:.=., [) O '1. _Eastman / A Al_ A::-';I:::A -, T N I'":. 2U, [,,JELL_ NO: '7 (SI DE:]"RAC. K) ~'_:a:l I;h~,J A IR U K F I E'" L ]3., Ni'"l R T H '.=; L El F'E., A L A S K A T R U F_:' ,_10 B N (]: A 0385 D () 1 'ii).3 F'AGE 1 SL.IR[ETt DRIF'T DRIFT r_':Cil_lRSlii:' VE:R"FICAL. VERTICAL SLIB'.=]:E:A R E C T A N G Ij L. A R C I_ 0 '.~.: I..I R E DOGLEG F'TH ANEiI_E.' I."JIREI"}TI('iN LEiq(-;T'H Dlii!:P"I"H ::3EC'I']](]I,,I "I"VD F: 0 rJl R D I N A T E :i": D ISTAIqC["- D II'-'(E:.C]"I ":IN ?:EVER I'I'Y E E"' 'T' D M ]D F! F E E 'r F:: I:.Z E"[' F' I:}] r::' 'T' I=' liE: E 'T' F E I:E T F E E T D M D G'/100 F' T 104. 44. :::::4 S 6:':_:: 24 W 4 MD IS TIE Ihi F:'OINT FOR :__.:IDETRACK () ,, 1 () O, 1 1. :32 ,_IECTED 'l"n I"D :250, 54 0 :=; :::;8 ]..El; W ]..5C). /=,075.52. "=;0/:,5,.q-'!;' ::J':.):::,"=:~.E2 2:=:08, ,pc)F; 4. !=;1:=: . 7 '.:.~ W .5(:)7z1-..~:'';o :'.:; /=,2 5/_", W (':), 00 F I N A L C L 0 S UIR E ..- D I RF..i C'T' I ("*N: El I '.'='; 'r A N C E: :.':.'; 6'2 EiEr':i?; 5./: M II',I;; /=, SECS W 50 7 Zl., 5 C) F E E T - Eastman Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. , WEI~L NAME ~ND-NUMBER Reports and Materials to be received by:~ Required Date Received Remarks ,Completion Report ~.~ ~'-~' 6f/_.' g~ ~~__~~ Well History y~ ~__ ~,~,~ .~.~.~ ~_~~ Samples Core Chips ,,,vd ;~.-.e f,,,,. Core Description Registered Survey Plat Inclination Survey Drill Stem Test Reports .. Production Test Reports ,Log Run ~._~_ .... ' \/~-5 b. ~ ,- f ' Digitized Data , ARCO Alaska, Post Office,...;,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .o i WELL 1 y = 5,975,841.16 LAT. 70020'42.7599'' X = 509,642.25 LONG. 149°55'18.2508'' PAD ELEV. 68.4 · O.G. ELEV. 64.2 FSL 575 FWL 1,096 WELL 2 y = 5,~75,782.54 LAT. 70°20'&2.1835'' i X = 509,627.77 LONG. 1&9°55'18.6762" PAD ELEV. 68.4 O.G. ELEV. 64.1 517 FWL [,081 FSL WELL 3 ¥ = 5,975,724.43 LAT. 70°20'41.6122'' X -- 509,613.34 LONG. 149o55' 19.O999" PAD ELEV. 68.3 O.G. ELEV. 64.0 , FSL 458 FWL [,066 WELL 4 y = 5,975,666.21 LAT. 70°20'41.0397'' X = 509,599.09 LONG. [49°55' /9. 5187" PAD ELEV. 68.4 O.G. ELEV. 63.9 FSL 400 FWL 1,052 WELL 5 Y = 5,975,753.43 LAT. 70°20' 41.902" X = 509,249.86 LONG. 149°55' 29.720" PAD ELEV. 68.6 O.G. ELEV. 64.4 FSL 488 FWL 103 WELL 6 y = 5,975,811.41 LAT. 10°20' 42.472" · I X = 509,264.30 LONG. 149°55' 29.296" · ~ PAD ELEV. 68.6 O.G. ELEV. 64.4 FSL 546 FWL 718 ; WELL 7 Y = 5,975,869.59 LAT. 70°20' 4].044" j X = 509,278.75 LONG. l~9°55' 28.871" PAD ELEV. 68.6 O.G. ELEV. 64. ESL 604 FWL 732 WELL 8 y = 5,975,927.80 LAT. 70020, 43.616" X = 509,293.26 LONG. !~°55' 2~.445 PAD ELEV. 68.5 O.G. ELEV. 64. 3J 32 FSL 662 FWL 747 LOCATED IN PROTRACTED SECTION 32 ~.,k~..' TOWNSHIP 12 N, RANGE 9 E, UMIAT MER. ~,r~,. ~ '~.-'~"~. ~'~ [40th NO SCALE .... ~- , ,. , ,- ..... ~ i~_~i~~-;,.'~i~,~'· NOTE' BASIS OF BEARING IS PAD PILING CONTROL N 13+55, E8+30 AND NI3+55, E 11+70 AND .- ;..,.~: -a a., ...&...-- ,,~__ BASIS OF ELEVATION IS 2U-SAND 2U-4 PER LHD E~ ASSOCIATES. ' j THI$ SUR.VEY-7 I' ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE - ~ / UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS $~ $~% ARE CORRECT AS OF .'-/~'-.-~-~:'~'-' ~~ /~, ./' ( ARCO Alaska, Inc. '~__,~ ,- R ~"/-~~__ Kuporuk Projec! North Slope Drilling 'i ']BIi.,'.' ! DRILL. si'rE ~U ~~e j~~/ 1 jjj~,j, CONDUCTOR AS- BU ' LT LOCATIONS ._.__ oo,,:..,or,.,,,.,,,,, Drawn By' HZ Owg. No, NSK9.05.221d I Mmrch 20, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2U- 7A ARCO Alaska, !nc. Permit No. 85-91 Sur. Loc. 604'FSL, 732'F~L, Sec. 32, T12N, R9E, UM. Btmhole Loc. 1705'FNL, 1097'F~L, Sec. 6, TllN, R9E, UM. 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 (T~.tle 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Po!lutio~ 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 commencimg operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin Kuparuk River Unit 2U-7A -2- March 20, 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 abandonment, please give this office adequate advance notification so that we may have a witness present. Very t~-~aly yours, .-__-~ ~ ~-~-/~---- C. V. ~tte~to~ Chai~an of Alaska Oil and Gas Conse~ation Co~ission BY ORDER OF THE COMMISSION 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 B~_. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2U-7A (Sidetrack) Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2U-7A, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment If you have any questions, please call me at 263-4970. Sincerely, · . KeWin ~.~ Area. Drilling Engineer JBK/HRE/tw PD/L77 Attachments RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany STATE OF ALASKA ~'-. ALASKA OiL AND GAS CONSERVATION CO,,,,vllSSlON PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL [] REDRILL FXlX DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L~ SINGLE ZONE [] MULTIPLE ZONE [~X 2. Name of operator ARCO Alaska, Inc. 3. Address At total depth 1705' FNL, 1097' FWL, Sec. 6, T11N, R9E, UM '/88/0,, 4. Location of well at surface 604' FSL, 732' FWL, Sec.32, T12N, RgE, UN At top of proposed producing interval 1485' FNL, 1416' FWL, Sec. 6, TllN, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 106', PAD 69' ADL 25644 ALK 2575 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 2U-7A 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 604' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8250' MD, 6075' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 600 feet. MAXIMUM HOLE ANGLE 47 oI (see 20 AAC 25.035 (c) (2) t15. Distance to nearest drilling or completed U-6 well 607 ~ surface feet 18. Approximate spud date 3/14/85 reached TD= 3/24/85 2698 psig@ 80°F Surface 3084 psig@ 60!9 ft. TD (TVD) SIZE Hole Casing i2~'~ '+C"' 8-1/2" 7" Weight . ,../'l'r ii '"~ L~ 26.0# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade I Coupling] , ~- L . n'-"l J-55 gTC HF-ERW SETTING DEPTH MD TOP TVD Length 8226' .34' MD BOTTOM TVD 8250' I 6075' I I QUANTITY OF CEMENT (include stage data) 200 ~F GGG o^ P~,~,af~ost ~C" 295 sx Class G neat Please refer to Sundry Notice concerning the plug back of well 2U-7 and the sidetrack of the new wellbore 2U-7A. ARCO Alaska, Inc., proposes to sidetrack from the existing. 2U-7 wellbore at a depth of about 6112'MD and direetionally drill 8-1/2" hole to approximately 8250'MD(6075'TVD). 16" conductor is presently set at llS'MD, 9-5/8", 36.0#, J-55 casing is set at 3630'MD and is cemented to surface. The presently installed 13-5/8" BOP stack will remain unchanged. If necessary, the BOP stack will be tested to 3000 psi per the schedule established by the installation on 2U-7. Expected maximum surface pressure is 2698 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 2-7/8", 6.5#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. (see attached sheet) -- 23. I hereby c~ [~at the foregoing is true and correct to the best of my knowledge -/ '/____ /.~' The spa o ~m n use Samples required []YES [~O Permit number APPROVED BY ~2 k. E'/" Form 10~01 (~ PD/PD77 CONDITIONS OF APPROVAL Mud log required Directional Survey required I APl number []YES ~ J~'~'ES []NO I 5o- 029-21283-01 Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission March 20, 1985 Submit in triplicate PERMIT TO DRILL 2U-7A Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will beinstalled and tested upon completion of the job. 2U-7A will be the eleventh well drilled on the pad. It is ±360' away from 2U-6 at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6740'MD, approximately IO00'MD above the top of the Kuparuk Sands. 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 completion rig has moved off location, the well will be fracture stimulated. Henceforth, all correspondence for this well will reflect the name change to 2U-TA. RECEIVED .i. 9 1985 Alaska Oil & Gas Cons. Oommission Anchorage , i ?o0, I , : i Ii I , ;"' 'l, ' ,' I :ii ' I J : I ' ' : ' ' ' ........, L l. . l j ! ! i ' t ' ' J' ' ! 1 ' ~ ' ' ' ~ I. i ' I . . ~ !LLi 'NO ~": ?~IS I DEl' RAIl;K) KUPAI~UK', FIELD,J ',..HORTH' SI20PE,~/ALASKA i ! ,'-, .... ,'",- "' : ; ~t · ,, ;' : !ti J ~*'J:tii"'t',!l ! '!"~ , , t , .! Su~acm Oiverq:e.r System [. [6" - 2000 psi Tankco starting head. 5. Tankco quick connect assy. 3. 16" x 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling, spool w/lO" side outlets. · S. 10' ball valves, hydraulically actuated, w/lO' lines to rese~/e pit. Valves to open automat'icmlly upon closure of annular preventer. ,, 50' 5000 psi annular'preventer. 20' bel 1 ni ppl e. · Maintenance & Ooeratton mi Upan initial tnsl~llation close annular preventer and verify thaC ball valves have opened properly. Close annular preventer and blow air through dtverter lines 'every [2 houri. Close annular preventer in the event.that gms or fluid flow to surface is detected. If n~assa~, ~nually ove~tde and close ball valve to u~tnd dive,ar line. Do not shut tn ~ll under an~ ct~tanca~. [5' ConductJ3r 7 6 KZt.l., "r. I CEJVED Nasi~ Oil & Gas Cons, "T-~-'P 9~c ~2.-- CHECK LIST FOR NEW WELL PERMITS ço:mpany ~ Lease & Well No. IC IL V( ~ tA - ? A ITEM APPROVE DATE YES NO REMARKS (1) Fee 91J....... t¡-Vt-Jr. 1. Is the permit fee attached... '.' . . . . . . . . . . . . . .\ .. . . . . . . . . . . .. . . . .. .. . 9~ - (2) Loc ',¡/(!..... y- v~'¡J 2. Is well to be located in a defined pool............................ ~", ~- ~ 8) 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells ...........;........~ - 5. Is sufficient undedicated acreage available in this pool............ ,"" --- 6. Is well to be deviated and is wellbore plat included................" " , --- 7. Is operator the only affected party................................. " --- J! ð If ,,/1/ J'J 8. Can permi t b~ approved before ten-day wait.. . . . . . . . . . . . . . . . . . .. . . . .. " , = (8) I' (3) Admin () Þ--.../ V-l.,'i-lJ' 9. Does operator have a 'bond in force..................................~--- " ~ 12) 10. Is a conservation order needed ...................................... --- .QL::= II:!¡!- ..s-J g/3'.5 11. Is administrative approval needed................................... , ~ (. (10 and 12) I 12. Is the lease number appropriat~ .....................................~ --- (4) Casg ¿iT;/- 1¥ß' 1,3. Is conductor string provided ........................................ JlJJJ - ¿II! fJ-II-CE (13 thru 2 ) J 4. Is enough cement used to circulate on conductor and surface'......... Iliff! --- II It g 35. Will cement tie in, surface and intermediate, or production strings ... /li!l:L ~ z i,',6. Wille, ement cov, er, 'all, kn, own product, i,ve horizons, ...... .,....... .'..... .'.1" ','" , , ,; , , H 9 --- 00 r-:I :'",.',7,. W", ill, ",sur "f a c "e c, ,,a.,S,i..n,,,,gp.,r,ot,e, ,C',t".".f r, e',S"h,,', wa,',',t,' er Z,O,n, e ',s '" . .,.'. . .,. .,. '.'..", ., .'.".... . .' ., "~""".,""---, " " UV," "p., ~,',Æ C-1!. 00 ~ } 8. Will all casing give adequate safety in collapse, tensian and burst.. ' , ~ þd --- ÞO""'"H :9. Is this well to be kicked off ,from an existing wellbore .............. --- ~;ã ;:~O. Is old wellbore abandonment procedure included on 10-403 ........... .11 ---. H 21. Is adequate wellbore separation proposed............................ " " - SEE 8£1.1:>£ù z ,,;,' (5)BOPE",~" " sJgIg&,.,."""~,.""",.,gr""",.,,, :,',.,2. ,I,.,s"a' divert,' er s~,s,'. té!'lreC¡U,ir",e,',d ... "',... ~', ~"~"".'~.'.""',,'~',.....,"'~',".""~"",.,.,,,..,., .,'~. ., ..~,.~,. -,'"", ", 1L.'f1/,'.' ,Sf!R,FItC,'£CSP.,' IJJ..R£, 1JDY"", /Itl' PJ..IlCE.. ,t,,,,,, , ",,' , .r~l'~rtfir~:,",',~3,. A,',".,",""",ë,','"n",',',',e,' C. ',e,',"",a,', ,r""Y, ,,' ,d1,' a, g, r,', älnS,' ",' "Of,d"',i",V,'"',,,e,',,',,,r"'t""e",, r,', an"d" ",',1!,','""O, ~'êll,',\Îi"Pliîê,î1,',t"ã,l:,','l:II, '~,", lI,,","a., "',,","."~'~'.~~',;""'.'Jlfl!,"'~"'-',",'Þ"""',',"',:':,',:"::"'::"', " ',"',""',":""",:""""::" 24. Does BOPE have sufficient pressure rating - Test to 3. ð7fl>, psig.. 7lff}j , , ;~5. D,oes, the, :",Ch"ok,e" manifO,ld, com, PlY, w/A!'I R,P-53",fF,e,b. 78)..; .,..,..." .".... .,' - --", )J()T SUBI'1J1TEÐ ,r":~" 26. Is the presence of H2S gas probable, . . .. . . . . . . . . .. . . . . .... . . . . " . . . . .. - fJjj¡ '-"" , (6) Add :lÍiíI14C¡~ 2.7. Additional requirements..................... ... .. . .. . . .. .... . .. . .'. .. --- l/illl I ~ Additional Remarks: TJI£ )./'1-7 úJ£.LJ...13oÆ£ ¡ tU#lc!l JlA-5 BaN 1'1-//ID I )5 rð£ ONlY N£/lJ?BY . tV ¡£l.LBo/(1f - I' I ( , ./ Geolo&¥: EnNring: HWK ~ LCS ','" ,', .BEWL- INITIAL GEO. UNIT ÖN/OFF WVA~, """,',.",,",', MTM 4L. H;JHblL "P,O,OL, CLASS ST",ATU,.,S AR, EA, N,O', SHORE JALr:- C¡90/()Q ~ I~}J t~,) II In ùA) rev: 03/13/85 6.'011 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. , ¡{tt~rul( .r1.M~ 7A @p ~11 . hale) ~ O~'f'l-~ ~-I ~... ""~ ~ ...'. .....<1).>. r¡. ..~..".'¡.."..' '... ....n....'..'.....~...........'.....'."~................'. .'.".'. . ...¡ ~- . ~ ~ ."""""""""""~""".""""'.':;,tii, ~ c;:j ~*******************~* 1* * "'ì'* .;* * * ********~***.********* *--------------------* *,.....~,~.,.sr;HLUMBEí<G'ea;;.....:.;;.+* *---,-~--~'------------* *****.>'i******"'«********* LIS T¡\PE VER !YFI'CÄ'T:IQ;tt\LitS~J'1t4>G ~.,( . LV? D1J.H02 V~RIFI:ATraN LISTING PA~E 1 **Rèf\;,. HEADER ** $~~V¡C¿ NA~E :EDIT OATê. :a5/0~1 2 û~IG¡N : Rt. et. NAME: CONT¡NJATI~~ # :01 eR E V 10 J. S R: E L : CCMt-L:NfS : ~* 'TAPE HEADER;:{;*- Sf:Kv¡CE ;\lA~1E IA..if: ..:85/ Q".I......'..,.2- ORIGIN ;0000 "II,e.......t4AME ,:C),l...l CGNT:NJATICN # :0 :P~RfVIOJS Ts'tPE : CD M M i N ¡ S .. ********** EOF********** ¥{t;.;;"'. f rLE . HEADER.#* FILE NAM~ :2011 .001 , ,;8;£)( VIC ¡: r~A~f: VfRSION;¡. : Q,:A,fE .' .: MAX¡ HU~~ LE NG T H : " i:i:Lf ..,. ~ 11P'{2 : PR¿vIOJS FIL:: : ** rNF:;RHATliJN ,',~it.i'EM C£Ho1TEN!'S '¡IN:IJf 'f;:fX~E C.Atf S'tZE -_._- ----_._-- -_._- -~-- -_._- -~-- ---- -- ''.,.....' CN : ARCOAl 000 015 065 'ijj~';. lU,.,;;l.í\ eOÐOOS' Oti'5 FN . 'UPA~UK 000 OŒl 065 ,J<'J}'NG: ~j..E OGQQ'JJl Ð65 rp~i~:¡~ .~ .09° 0°} 0 '6,5 , S,E,CT; 32 ' 000 O.{)20ti5 t04N; ~.SLJP2 000 001 965 , SIAT.~ ALA$1(A 0:0,0 ~O{16 {t6'.S CT~Y: US, oao OG3 0&5 MNEM TYPE CATf SIZE CQP& ....~. -..:~ .....,.....,..~ ....:~ -:..... _'-'111181.......~ -- .~..... ~~..........~ -~.._........ ~.:-........~ P~RË$'; .i: 000. DO'D O-:ll ,0:65 ** CDM~E~¡." ** -- ( .( .. .. '" l.V? 01~.HC2. VERIFICATION LISTING PA:3E 2 *************.*~*****.**********.******~~*-***********************~***************~* * SCHLUMBER:;ER * * Al ASK A CDMPUTI\JG C.:NTE.R .,;. "'" **** ** ** ** ** ** ** ** *** * * *** **** ********* *** ~* **,**** ******** ************ ************ ** C G ,,", ? ;. N t - ATLANr¡~ R¡CH~I=LD CüMP~NY WEll = 2 J-J A FI ËL D - KUPARUí<. CO,UI~ TV = NORTH SLOPE BOROUGH STATe = ALASKA RM - 2..11D .iiJ Ó9.0 D~ R~f = ;2. Siia ã) 6 9 .;0 ij';F R~C - ,2.010 ~. 69.0 OF Rij[ÄT 8ti1 = ;1. 328i 148. OF '*'***** ***********************'****'*********~**:"(.ì~(**#*~::#:*:t;.************* ******.****i;' LV? QID.rlQZ VERIFICATION LISTING PA;~ 3 * ~ * * * * * * * * * * * * * * ~ * * ~ * * * * * * * * * * h ~ ~ ~ * SCHLJMb¿RGiR LOGS INCLUD¿O WITH THIS MAGNETIC TAPE: * ~ * * JUAL INùUCT~JN LATERlOG (DIL) * * FORMATION DfNSIJ¥ COMPENSATED LDG (FaN) * * COMPENSATED NEUTRON LOG (FON) .~ t: * * * * * * * * * * ~ * * * * * ~ * ** DATA fORMAT RECJRJ;it* fNTRY Ò4..'JC<S rv. P E SilfR€'ÞA~ ú3DEENTRY 2 1 65 0 4 1 66 1 8 4 73 bO 94 6'5' .tIN 16 6S U 6~ 's'j.rtu M '.' SPti€lfIC4T:;IDNdt'i}CK S 14 N t. M S ¿ R V 1: C ESE R V let lJ NIT API . ;~p I A P I~ P f FILE S I l € S P L R t P R P RJ C ,f;: S,S ' 10, O'R'D;E;R:' LOG TYPE CLASS MO:O NO. Cl1DE "amt:~:t:), Di;, P T FI '. :30 000 00 0 D 1 68 0 QOOf.),POQO.OQQ.QQ n:¡:'.fF;LU JILOriMM' 00 22.'0 ,o:i ,{) :016:8' OOGC;Q])~OOÐn:Ð:;t)Ð;;a ¡L¡) JIL J,HMM 0 Ü 120 46 0 0 1 64:1 0 OP QOO,PP QOP.OQ,~ ':Œti.:H -rl!t. an\~fIIt . ,00 12'0'4.4 :0 Ð 1 68t):åO:QO:tlCO'O(¡:O:ÐI?B ¡P OiL MV JO 010 01 0 D 1 68 DOOQOOODOOOOOJ ,,\ji-R filL , iJA.PI aD ,3:1:0 í):1' ,0 1. åSO>O:G:Q'OOQði0'00e'~G;t GR fDN GAPI CO 310 01 0 1 68 OOOQOOÐQQOOOUJ ~{ LV to' OlD.HOZ VERIFICATIGN LISTING P .IL.. E 4 CALI fDN IN OC ¿SO 01 0 0 4 ' 08 0000000000000) 4. RHDB FDN ;/'3 00 350 02 0 0 It 1 68 00000000000003 ùR:iO ?=DN :;/:3 O~ 35ó 01 0 0 4 1 68 0000000000000) NRAT fDN JO 420 01 0 1) 4. 1 68 00000000000080 RN~A fGN '\1"\ DOO 00 0 Q ~ 1 cbS 00000000000(0) vv HPHI fDN ?U 00 390 00 0 0 4 1 6. oooasooooooloa NCNL FCN CP5 JO 331) 31 0 0 '+ 1 68 OOOOCOOCOOOOOJ f{~ Nt. FDN CPS DC 330 30 0 0 4. 1 b8 OOOOOaOOOOQo'Ol) ** D AT A ** ItM 3.13 535 CALI 8.7969 RNRA 3.. -4-629 OE?T 8;)OD.00DO SFLÜ 3.1422 ¡L .) 'd. 4-2 91 lLJIIt 'g;p ~51,.2500 ;;R 93:'31:25 G.rt S3.'a~ilS' CAL.'l RHùa Z.36:91 ORMG a . 104 5 NR~T 2.aS37 ~NRA 'I'¡;:'HI 3118 64Ð'6 riU::Nt 2$ 3S'.1lDDO FCfoi[ 8 4.6,.~fJ:OfH) Q,f:?T 1 j{lÚ~O<Oø6 SFLU. 12.f1'906 11.û rl.~~:32: a 1 It,. I.'Ø~.'J93H SP -55.5313 :.; R 71.5000 GR '71.50DO CALI $,. ;1141 I'''''û& ¿184t02 iJR'ríO 0 '~' 10:6<4 :fiJ~~A T 2 ~":5 0:4 1H\lRÄ Z~157,8 NP ti I 28.'1250 NCNl 2514.0000 FCNt ~) 1 i *' '50 QO' "'''¡'.. OE?T 130;).OC00 .) fi.. U 5.1211 lLJ "..09Jô '$,' '~.5'3,~.í)'ø~Q,n ~<R 99).;'3;'1'2:.$ â:R "9 .YSXt'l,S RHúB 2..5117 JRHD 0.1,1,,$ NR~I 3..JìpifJ4 ~~P!:fi:l 3'4;.1..37'50 NC:'~I. Z'2;S4¡/'!)'.0<&lO iF.CNtt. 598.:8Ø'i')(1 aiR! 1109..,OOQO $:fLU, 1,.8643, :IttJ 1,,'9,:~,~21 ¡lM l';¡'"'i2'S7 S? -53..0.313 uK 131.25DO GR 131.2500 'ALl. 9 .0859 RJ~:OS ;l~13Z 0 O.RHO D..'.J,..'Q'"/;4 NR41 .3~':'~'tii8' 'RN:RA 3¡..$66D NPhI 4b.331S NCNL 1'741..0000 fC"~L 4..1$00 ,JE~T 7;)00.0000 ;)FLU 2.~219 ILJ 2..5664 S:P ...65)...56,2:;S i;T{' 1 ZJ9-.'.lZ$O G:~ 1.2S. .1~:~:Ð, RH~a .2.4453 0RriL 0.1367 NR~T ,4.1562 ,NRHl ,.,1...8'086 'riB'Nt 1'90 6~,L1O;OO F CN1;t lta:3 .'CO!),\}, ' ,aiJ?ir 15Ù'O,.;OC)-UO S;FLU ,):.1.0'94, It;"} "l.)~2'58 lb.M 2:...:'6.0,9' SP -63.3125 ¡";R 140.JOOO GR -;;93.2500 CALI -.i9':1.2500 .R:tt~H3 '"7",,:¡ ,99'..2500 'il,R:H1J ~"j '9:~i:l S~:6. N~R':A;l ....999 .2:'~.oi1, ¡RNRA -399:.<¿:S€Hl. ÑFril -193.2500 NCNL -'399.2500 FC ~JL - '~~::¡.. ¿sop j£PT lC.,,;1fìQOO SF¡".û 4.D313 ILD ~ ~121 ILM .3. 9648 ..S :ß<P ¡( i:'750Q GR 2(r~¡62:5,O :¡:;'R ~\f'(~ 5,00 CALl .;;"99'~...ZSØO LVP Olv.H02 VER¡~ICATION LIST!NG PAQE 5 RHùè -,99.2.500 JRHJ - j 9 '; . 2 5 0 0 NRA.T -993.2500 RNRA -399.2.500 NPtiI -99~.25!JO NCNL ,- 9 9 9. 25 Q 0 FENl -999.25QO ÐEPT 130Q.0000 SFl..U 2.4688 It. J 2.)81'9 ItJ4 2..5352 ~p -66.0000 GR 253.13000 CjR -")99.2500 CALI '-999.2500 íUi ûa -999.25DO DRHO -999.2.500 NRAJ -'}99.2500 RNRA -999.2500 I~PriI -:j93..25ÛO i'>JC NL -99'1.2.500 Fe ~~L -99~.2500 't.1O!~4 -999.259Ð -39:'.2500 :~i-e:; ,.,(, , ,';¡: :~. ,~,t,!'~¡: ': ,'c ' ;~'~.I;I . LV? OlO.HOl VERIFICATION LISTING PA';E 6 SP -102..2.500 ;.;x 14.3..!500 ;R -999.2500 CALI -999.¿5ÛO RHOB -:)9 i. 2500 DRHQ -999.2500 NRAT -999.2500 RNRA - 999 . 25 00 NPhl -~99.2.SJO NCNL -9Ç'9.2500 FCi>1L -:i9 :L. 2500 Jt:?T 62.0J.0000 5FLü ,+.12.50 ILO 3.8086 rLM 3.1518 $p -99.7500 GR 149~1250 GR -999.2500 CALI -999.2580 RHDB -39'9.2.500 JR:-tO -399.2500 NRAT -~9'9. 2500 RNRA -~9ge25aO ,tip HI -999.2500 NC.NL -999.2500 ¡:: C 1-U. -999.2.S00 610Q.ÐOOO -10'J.7500 - 999..2500 -993.25:)0 JEPT 1.3319 ILM '<I'p ,- 399.,2590 CALI RHOB - 99"1e45QO RNRA NPrlI -99~9 iZSOO . i),fPT 2.1152 11..0 .2..Qi96 ILM 2.\1819 5P 134.5000 GR ~.99j..2.~P () ÇA~¡ -...'3.9'3.. .2:..5 0, Q ",¡{lltO B -'9 9'9..~:2.500 NRAT' .....999,."1:;$00 RNR:A, -99'l., 250:;Q, ,NPd¡ '-999. 2:S00 fCNL - 999 ,.2. 500 ,Qf?! 5 .~. oq.,POOp SFL.U (...,0 .<,138 ILJ ,~.,:l..5,O ø '\S'R ""8:8<;' $O'{lO GR 133.8150 GR ;""'::999~.,2:SðO ~H"J,8 -'399.:2500 ORHG .... '193.,25QO ¡'(RAT - 99'9.2 500 ':NPH,I ~99'~~l500 NCN L '~9'39.1O';25Ø~O ."FCNt ,0-'1':9,9 ,.<250'0 ~H:?'T ' 5'1~'ÐiG ,';43013'0 SrL~U 1,,. "':194'1 ¡t.t> ,Z;..';1,'G94 IlM' Z¡U4t~.0 Sf> -f{7...1500 GR 106.1250 GR ...99,~..250 0 CALI ~ 9,i~I~,.2..!?Jto . liHU5 ~"99;9'!j¡Z5i'ðO ',DRHO "';;9'9j~.2S:,O:O , NR,;~iT -999,.:fl'$LlG RN,~t:A' 0-99 9';, ~¿;:5'tlO N.P n I - j, 99,<8.2599 NCN,L - 99'~ .~2500 FCNt.. ....,:i.9 '3 ..?5~O ~.~$, . ?:,..,.:', Oi:?T 5t.OO..{)OOO SF'_U .2~!,:5}P}, !J..~O , ....' .,. " 2..,,;S,.1'54 "1:1;,' '~;$>~'~>j¡;ø'O;O .GR '~t~;s.,4:a,'~. 'G ,1(' ~:9'9g.:'it,S'ØQ, ' ~t10b' '-39'3.2500 iJRI'1Q -.9,9'~..~.500 .f'iR..A,I ...;~99.,~,2PP ,.,..eìiI ~'~9a;.l5Dø î,,¡;úiNL --'39 ',.25/00 . FCN:L --,991J,,,~'2,5,QiØ' 'Q;f;'PT 5500..0000 SFLU 2:",,203.1 ¡,LO i;.:~' 5:51 'ItM Z.IOJ;!.;9Ó;1" ~p -92.75DO GR 97.12'50 GR -999.,25,00 C4LJ '- 99, .2500 1:806 -"1'99~,.;Z>SDO ORA1Ü ~"3St9.,2?ÐO N.f( '~Ä:T '~i199.':1;:5¡1{) > RNRA "':9~"1i.;.,:2'50:a' NP,,¡ - "199 . 2 50.0, NCNL -999.250.0 ¡CCNt -99g.~500 ",,",' ÖEPT ;} ':t 0 J. ;J 000 SFLU 3..0801 IL3 3.12.89 ILM ',"g''fJ ~IiO~';iQDU'~ s;:r< 111.>. g O;O~O GR:;,.^ +1~:t,.:;Z.$tln' £ALI RhÛ6 -3'3'3. 25 iJ 0 JRMU -999.2500 NRAT -~9 3..25':)0 RNRA ,N~H¡ --39't.Z:5':¡¡:O NCNL 2<1'~:3'~,l5f3":¡ f~:}jL ' ::;~'9,9,.jZ;$t).\1 ,ij;ç,~T 53():Q.,~'J}:DeO SFt..U ihr49>~2,' I:Li) , 2. ..;'!1:,Z.:¿1 lLM '¿'.:6>':~:9 SF -105.'5000 GR 122.:5000 GR -999..2500 CALI - ':; '9 1. 2500 Rti'iDS' ~ .':;9'9 ,¡'Z'S,'fl'() ,0 RHO, ;;";'t'~'~~:Z$Q 0 Nt<~l, +3,9,'9.;\a:500 R¡\rR A "'99~~~,2i5Q'Ø ' 'NPri ¡ -.0'19..25:00 NCJ\iL -999.2500 FCNL -99'0 ~500 -..< ¡t .(. LV? OlD.HOl VERIFICATION L:STING PA;e 7 D~PT 5¿OJ.OCOO SFLU 2.S879 ILU 2.7500 I~M Z.bð35 SP -104.0000 GR 109.8125 GR -i99.ZSUO CALI -999.2500 RHJB -39~.2500 JRHO -999.2500 NRAT -993.2500 RNRi -999.l500 NP~I -999.2500 NCNL -999.2500 FCNL -999.2500 if?T 510~.OOOO ¡fLU 2.6797 ILD 2.8437 ILM 2.1559 SF -104.2500 GR 111.3750 GR -993.2500 CALI -g99.2jQO RHGß -399.2500 ORHO -993.2500 NRI' -999.2500 RNRA -999.2500 HPrll -j9~.2500 NCNL -939.2500 FCNL -39i.Z500 2.51j13 -999.2.500 -'399.2.500 ù.ç P T 4300.00? 0 S.FL U , , 3. D35:2 Il jj ", ,,3,. fl93 8 ,U..M " ' Z.. J92¿ :,i,P "'10ó.~500ij GR ¡lO.,O625 GR~9g'~..2S00 CAll -.'999.l500 RHJb -;99.2500 ORHO -9~3.ZS00 NRAT -999.2500 RNRA -99}.lSOO N"PH1. ...::.)99.2500 NCt\tL .i..99'9..ls,DO fC~L ...~99.l5nO DEPT ~'10U.O'QO>O 5FLU 2.83.\11 3.1191 lLM 3. JDTS SP, " -108.7500 GR lCO.O~25 -999.2500 CA~I -399.2S0ß RHOS .i..399.2S0D Q:RHû .i.. ¡;9'9~l50'O -99''j.250;e RNRA -99'3,.2.500 NPHI -99Q ?SOD NCNt -99 - -i99~25QO /<:"f;}~'X"''::>'':/:;~:'', . ..'",,'.,.,' ,~",.''''~'/~''''; ,.,d. ,''''''"'"'''''':'''''''' ;","",', '" '..;.,....: d'.",.." "",...," ,., J"'j "'¡j'EPT SFlU ,2..964.8 ,~.l5.40 IlMl..1348 '\';)ip, GR 111',.'3125 -.39'J;.2500 'CALl ~;J9'9.2'SGa RHJB JR;iD -j~"j.2500 -:139..25QO RNK -39:j.¿500 /'li\PriI ' N'C~l,,: .;.,9":;}~ Z$,DO ..i..~9~99~ :2,5:QO ' JEPT 4\OJ.0000 SFLU 3.5684 IL0 4.0731 3.8319 SrR, ,-113:. DOJ1O GR 102.:3:1,2,5 ilR ~9;'~~:¡;.:~5JJð.i..99?iì,.>25QQ RHJð -399.2500 OR~G -399.2500 NR~T -93J.2500 -3i9.¿SDQ ,,~ef11 '~,'~,,99,i¡¡25,OQ NtNL ~'9:'9;9,.,~2.5¡JO FC~t. -~i9'9i.~l5'OO ,t]::t:?T 43(rü.O~QOO S,FLU , ,J.3J348 'U..jj3~:84,lg ,¡>t3r1f 1~;51~9:6 SP -114.0000 GR lO4.1250 GR -j99.2500 CAll -999.Z5DO 'j{rJ;,P8 ;~'1;99'.2?QO DRHO +9'9i9';¡.;~5'O.ON~AT""799î'\~Z.'5ø'.oR]U<A :~99'7;~45DO N;rl¡ -;99.2500 NC~L -999.2500 FCNl -399.1500 DEfT 4200.DOOO SFLU 3.2324 3.7969 IlM 3.5586 ,'S';S? '~116.50lJQ {;Kl'()O.,DØí:)()~~91~2,5j;f~ CALI '-99'3:¡¡..lSQO ,R"""",H, "u,"",b -~q;~",., 2.,""5",°",,,°, ,D",R",'1,,',D -",:",>,9, ':1,',',,-, ,,',','''', '5",,°,° ,-"", ",7,,~",9'? ~5"',O,,O, RNRA -999.25ÜO ~"""".""""'."""""""'" .'¡4Sì?Hi 1:;2.5'1)0 NCNt ""'j'l9.l500 ;.;..~;9{ 5(lQ. ( -" ..... \¡''- , ; : :~ . , ~ . , ; .". , .. ... ,. ". ,. .. ." >"" " .",..;.;, "" "'}'i LV? D1D.HOl VERIFICATION LISTING PA:;e 8 OI:I>T 4100.0000 SFLU 3.1855 Il:> 3.5313 ILK 3.30iB SP -llc.SOJO GK 1Q1.9375 GR -999.2.500 CALI -999.2.500 RHJò - ¡ 9 '; . 2 SO 0 DRtíG -999.2500 NRAT -999.2500 RNRA -999.2500 I~ P :i ¡ -199.2500 NCNL -39',.2500 FC\jL '-99~.2.S00 lL.~ 3...1191 CAtI -999.Z5tJG RNRA -993.2500 3300.0000 3. 38,28 -122..9375 101<&8750 -3 '91 .2 50 0 -399.2500 -999.2500 ... 999. ,2500 +BEÞT 31"OA1.íoOOOO' Sf'L U 2'4i4082 ItO I:Lå SP -12'4.,DOOO GR 81.'1375 GR CALI fUi:il6 ~l9';.l50i} DRHO ,~l99..;2:5~O () NRìJ RNitA NPMI -393.2.500 NCNL - 99'1. 25 00 FCNl ùfPT 3615,.0000 :)fLU 6.785.2 .rl,. J 16.213"7 IL~ 2.PQO.OQJO 'ASP ,~".t55;'~1' SO'{) GR .591.90'62 J;,R ,~'9'99~~Zi5'&lØ CAttI ,499ii:~;'."ZiS' 'O() RHûS - ':19 9.,,500 DRHO '-99'3.1500 NRAT ':-: ,'~, '9 ') ... ,!.5DQ RNRA -999.2:';'130 >H"~Hl ~i7'9'9.Z5:0!J ' NCN'L '~'ji'~J;li.t£;n() ¡:c:~( ,~999;2:s:a'o ** FILE TRAILER ** '::.,f:'\¡:t.e,;,'~<NAlV\.E . :,EDrE't" ;.tl¡)1' SERVICE: NAME .. .. ':'ii"I\'~:S'lto'~>" ";: " DATi: '. . ":'~~:;~IM'~J#'1",LENGrH FIL;c 'TYP:: . . ;..15t~e.}(J"flli:'," '; ". ~ 'AM,E' -: :*********;r:i'E'OF.,~i******'*** . ' . ." *~ TAPE TR~ILER¥* ,YS,£;R,VICE:'NAM:E" ,:'E'O! JÄTE :a5/J4/ 2 ',£iJ,.R;¡~.G',IN' "':ÒO:1-"0 rAP E r~ .\:.n: :0.241 ";C¡eNT¡NJAJIJN,~iJ ;0:1 ¡"fXT T l\P,:: NAtvlE: .. .. ,e'trMf.t;:N,fS : :C --.( LV? J1O.HOl VERIFI:ATION LISTING PAGE 9 ** R2E~ TR~ILE~ ** SEKV¡Cé NA~E :fOIT DArE :;5/0+1 2. D,R¡G¡N : REEL N~M.: : CONTINJATICN # :01 ì>fêXT R¿fL\lAME : C£.H4Mi: NT 5: ********** EOF ********** ********** EOF ( -...(