Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
199-079
Originated: Delivered to:12-Sep-24 Alaska Oil & Gas Conservation Commiss 12Sep24-NR ATTN: MeredithGuhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24 CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24 CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24 2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39555 T39556 T39557 T39558 T39559 T39560 T39561 T39562 T39564 T39565 T39566 T39567 T39668 T39563 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.13 08:31:59 -08'00' 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 T39562 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-20 KUPARUK RIV UNIT 3F-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3F-20 50-029-22947-00-00 199-079-0 W SPT 5781 1990790 1500 1468 1468 1468 1468 225 270 270 270 4YRTST P Brian Bixby 6/4/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-20 Inspection Date: Tubing OA Packer Depth 520 2220 2180 2180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607081220 BBL Pumped:0.7 BBL Returned:0.5 Wednesday, July 26, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 12, 2019 TO: Jim Regg r / �4 / 3�t SUBJECT: Mechanical Integrity Tests P.I. Supervisor �dl CONOCOPHRLLIPS ALASKA, INC. 3F-20 FROM: Guy Cook KUPARUK RIV UNIT 3F-20 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry'I�IF__ NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-20 IInsp Num: mitGDC190608160719 Rel Insp Num: API Well Number 50-029-22947-00-00 Inspector Name: Guy Cook Permit Number: 199-079-0 Inspection Date: 6/6/2019 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F20 Typelnj w TVD 781 Tubing io4s 1649 1648 1641 - -- 1990790 —_ Type Test SPT PTD � � y � Test pst lsoo IA soo 2510 z46o � 2455 BBL Pumped 08 BBL Returned �o.e OA 265 L 310 310 310 Interval-- - - - -- 4YRTST PIF P J Notes: Job was completed with a Little Red Services pump truck and calibrated gauges. Wednesday, June 12, 2019 Page 1 of I • 0 oN to 1F- T ro 3 io Y o G) CO v Y: CV fU6 +N.+ O v1 > i C a c C C — T O 411 0 W l9 w C �° a Q v E o a m hW 0oa 0 Q 0 N z w CO CO CO CO CO CO CO CO CO CO , 10 L O Q oa.m E -, C -O o 7-C it v) a Q) a a a aT a 0, O �' Y O > > > > 3 c c <00 _ -' Q a Q Q Q Q Q a Q Q u) u) 0 m L c H M a 1n t0 r CO Orn Orn o ,_ N U '6 - 0 C to N N N N N N N N M M U 4 v E � a, VI Q ° Y ° roo 0 cc u u 0 0 0 0 0 0 0 0 0 0 0 0 tip L 4= 0 L_ w J J J J J J J J J J J J C 7 N a W W W W W W W W W W W W a > y N F- LL LL LL LL LL LL LL LL LL LL LL LL _ O Q J J J J J J J J J J J J I-- N C w - Q Q Q Q Q Q Q Q Q Q Q Q 0 co U 0 C Z Z Z Z Z Z Z Z Z Z Z Z C s O > 0w M -, LL LL LL LL LL LL LL LL LL LL LL LL -r6 . r .c s O N E u cu .ets O ' a U ' U o C u 0 O ~ - G a H > U Q1 +-' C ao o Q cu a 1n C a 0 f.") R) rt.: w LI- 0 �) J J 0 J O LL 0- Cr) O ° O 3 ° O NI ..4 W � oao � -Iaa � aa d V tO .•.1 ; m a a v 0. 0 d U 3 > a; 00 04 U p 1 ►. V 6 v o 0 ro x � - 14 t mi ro x o -A., z x70.ig Ad WF tz v a J J J J J J J J J J J J g W dityPir)."111P ° >W > > > > > > > > > > 111 21X IX Ce W MIX MCC X Ce r‘ Ce z Y Y Y Y Y Y Y Y Y Y Y Y > > > > > > D0000 = l'-''0 w Q Q Q Q Q Q Q Q Q Q Q Q O ,r. a a a a a a a a a a a LL ro C '- > > > > > 0 > > 0 > > > i Y Y Y Y Y Y Y Y Y Y Y Y tin C ® x n 1L ! 1O CON- O O N r N O •) E ' ` N N co 1� N co co co co 11'1 1n 1n Lill (V7 o O M O O O M O O O O O Q0 O O O O O O O O 0 O O O co N o a a a 0 a a a a a a a .02 Uw a U (. U U U Y U u LL LL LL > mom O > ( (9 LL 0 0 0 CO 00 LL ( (CO CO 0 0 0 Q uc I6�i r-+ W oo � ° oo � o ° oo ° a ro N 0 E .x w ® A o �, o f4 V Q U) O O O O O O O O O O O O O ill {D O O O O O O O O O O O O « • of CC ; r V N O M M N O N U) M W �= - a '. M CO O O) N N 0 40 Tr 1n O) 'I — N M 0 C") M M a 0 0 N N 0 O N n• N N N N N N N N N N N N C O d Q O) M O) o T O) m O) 0 0) O) C) c 0 .. 8 N O N N N N N N N N N N O O e- O O O O O O O O O O C O O O O O O O O O O O O a 4! OU O 10 11) 1f) 10 1f') In 10 1() N 11) I!) 1n •a CU Q� " E • z V E E C. -o co a,o a) Y Fas u" d Q6J' . a' 1n co O T •v v O 1n O cO v .+�' E N v y Z O O O o O r' O N O o a, b t� Z ti LL m W z O O E 1n ; N J m N m m N co M C wm E E .66 �� O' Q a W N Nco c r.42 1 O >i a a H I-C MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,July 01,2015 TO: Jim Regg 6 P.1.Supervisor < 7 I i C SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-20 FROM: Johnnie Hill KUPARUK RIV UNIT 3F-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-20 API Well Number 50-029-22947-00-00 Inspector Name: Johnnie Hill Permit Number: 199-079-0 Inspection Date: 6/27/2015 Insp Num: mitJWH150630144126 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well[ 3F-20 - Type Inj G' TVD 5781 Tubingl 3225 3229 3230 3230 • PTD 1990790 Type Test SPTest psi1 1500 IA I 1360 2010 • 1985 • 1 1980 - Interval 4vRTST P/F P ✓ OA 420 - 420 420 420 Notes: 0 3 bbls diesel SCANNED (;U;. 0 '1i' Wednesday,July 01,2015 Page 1 of 1 Kak 3c--Ze Regg, James B (DOA) ' 9a From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday,June 22, 2015 2:12 PM ) c9f („(z.���S To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA);Wallace, Chris D (DOA) Subject: Kuparuk 3F pad SW MIT-IA's Attachments: MIT KRU 3F-PAD WAIVED SI 06-21-15.xls Jim, Attached are recently performed SW MIT-IA's on 3F pad (waived by Chuck Scheve). All wells were shut in at the time of testing. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor SCANNED JU ConocoPhillips Alaska, Inc. 2 2O) Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 AWELLS TEAM Conc+cciPlamps 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to pm regq(Htalaska,gov AOGCC.Inspectorsaalaska,gov phoebe.brooksOalaska goy chns wallaceCrD_alaska oov OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT/PAD: Kuparuk/KRU/3F Pad 1-ell /_6174 c DATE: 06/21/15 OPERATOR REP: Hight/Riley AOGCC REP: (Chuck Scheve waived) Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-03 Type In] N TVD • 5,701' Tubing- 975 1,025• 1,050 1,050• Interval 4 P T.D. 1852270 Type test P Test psi 1500 Casing 750 1,710, 1,680 1,670, P/F P Notes: OA 40 40 40 40 Well•3F-15 Type In) N TVD • 5,673' Tubing 1,950 1,950 1,950 1,950 Interval 4 P T D 1852930 Type test P Test psi 1500 Casing 650 2,650 2,550 2,540 P/F P Notes: OA 280 320 320 320 Well•3F-16A Type Int N TVD • 4,990' Tubing 1,700 1,700 1,700 1,700 Interval 4 P T,D 1961510 Type test P Test psi 1500 Casing 210, 2,420 2,360 2,340P/F P Notes: OA 80 80 80 80 Well 3F-20 Type In) N " TVD , 5,781' Tubing. -1,825 1,825 -1,825 1,825. Interval 4 ✓ P T.D. 1990790 Type test P - Test psi 1500 Casing 510 • 2,550 -2,500 -2,490 P/F P Notes: OA 200 - 220 - 220- 220 - Well•3F-21 Type In) N TVD • 5,848' Tubing 1,450 1,450 1,450, 1,450, Interval 4 P T D. 2002030 Type test P Test psi 1500 Casing 100 2,210 2,140 2,130, P/F P Notes: OA 10 20 20 20 Well Type Int TVD - Tubing Interval P T D. Type lest Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Forth 10-426(Revised 11/2012) MIT KRU 3F-PAD WAIVED SI 06-21-15 66 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /,.,'¢- ~ 7~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: n Other- Pages: DIGITAL DATA n Diskettes, No. [] Other, No/Type OVERSIZED .!'3 Logs-of various kinds . Other COMMENTS: Scanned by: Beverly Dianna Vincent (~n Lowell Date: Is/ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell . Date: STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate J Other r Alter Casing r FUII Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 199 - 079 3. Address: 6. API Number: Stratigraphic r" Service 17 P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22947 - 00 °' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25632 ' 3F - 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 7542 feet Plugs (measured) None true vertical 6302 feet Junk (measured) None Effective Depth measured 7473 feet Packer (measured) none true vertical 6253 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 86 16 121 121 SURFACE 3469 7.625 3503 3239 PRODUCTION 7504 5.5 x 4.5 6830 x 7537 6299 RECEIVED Perforation depth: Measured depth: 7026- 7045', 7236'- 7264', 7284' -7318' MAY 3 0 2012 True Vertical Depth: 5927'- 5942', 6083'- 6103', 6118' -6142' AOGCC Tubing (size, grade, MD, and TVD) 3.5, L -80, 6841 MD, 5790 TVD a 1 ,MNED JUL C , 3 2012 Packers & SSSV (type, MD, and TV)) no packer eR Y�9 no SSSV 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 287 Subsequent to operation 2294 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service I' Stratigraphic r 16. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations _XXX GSTOR fl WINJ r WAG Iv GINJ r SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265 -6471 Printed Name John Peirce Title Wells Engineer c� Signature l/� Phone: 265 /2 ! �� €.7.Z ------ ,,s l '': Lo 7 ft, Date 7 /_, FIBM$ MAY 3 0 2017 Form 10 -404 Revised 11/2011 Wy Submit Original Only 3F -20 Well Work Summary DATE SUMMARY 4/28/12 GAUGED TBG TO 2.77' TO D LE @ 6781' RKB. DRIFTED TBG WITH410 x 2.68" DUMMY PERF GUN TO 7313' RKB, NO PROBLEMS ENCOUNTERED. READY FOR ELINE. 5/5/12 PERFORATE INTERVAL 7025' -7045' USING 2.5" HSC LOADED 6 SPF, 60 DEG PHASED, USING DP MILLENIUM HMX CHARGES. LOG CORRELATED TO SLB PERFORATION RECORD DATED 14 FEB 2000. WELL TURNED OVER TO DSO TO BE BROUGHT ONLINE. a KUP 3F -20 • ConocoPhillips if Well Attributes • Max Angle & MD TD AI 7SA <t, Ir>t;; Wel!bore API/UWI Field Name Well Status Inc! (°) MD (ftKB) Act Min (ftKB) p Ngps 500292294700 KUPARUK RIVER UNIT INJ 44.39 7,475.62 7,542.0 '° Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date — SSSV: NIPPLE Last WO: 1/25/2000 Well ConBp' - 3F -20, 549/201212'39'49 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,288.0 4/28/2012 Rev Reason: ADD PERFS ninam 5/19/2012 Casing Strings HANGER, 28 Casing Description String 0... String ID ... Top (ftKB) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15062 35.0 121.0 121.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 34.4 3,503.4 3,239.3 29.70 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 33.9 7,537.4 6,298.8 15.50 L -80 LTC 5.5 "x4.5" @ 6844' 1 1141 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd 5 TUBING 3 112 2.992 27.5 6,840.6 5,789.6 9.30 L -80 EUE8r4MOD Completion Details Top Depth (TVD) Top Incl Nomi... Top (ftKB) (RKB) ( °) Item Description Comment ID (in) 27.5 27.5 2.52 HANGER FMC GEN IV HANGER 3.500 CONDUCTOR, r 496.7 496.5 4.09 NIPPLE CAMCO DS NIPPLE NO GO 2.813 35 - 121 } _ 6,781.1 5,745.5 42.77 NIPPLE CAMCO D NIPPLE W/ NO GO PROFILE 2.750 6,827.8 5,780.2 42.16 LOCATOR BAKER LOCATOR 4.250 6,828.7 5,780.8 42.15 SEAL ASSY BAKER SEAL ASSEMBLY 3.000 NIPPLE, 497 Perforations & Slots Shot I Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (Ph— Type Comment i 7,025 7,045 5,927.3 5,942.2 C-4, 3F -20 5/5/2012 6.0 IPERF 2.5" HSC Loaded, 60 Deg Phased, • (� DP Millenium HMX Charges II 7236 7,264 6,083.4 6,103.4 A -3, 3F -20 2/13/2000 4.0 IPERF 2 7/8" DP, EJ III, 0 deg phasing, +/- 90 deg orient 7,284 7,318 6,117.7 6,142.0 A -2, 3F -20 2/13/2000 4.0 IPERF 2 7/8" DP, EJ III, 0 deg phasing, +/- 90 deg orient Notes: General & Safety • End Date Annotation 1/25/2000 NOTE: Pups are BTC - MX EUE 8rd special clearance. 34 - 3,503 SURFACE, 7/21/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1 GAS LIFT, _- 6,721 NIPPLE, 6,781 LOCATOR, 6,828 SEAL A 6,829 6,829 I' - -- PERF, III Mandrel Details To Depth Top Port ( TVD) Incl OD Valve Latch 0166 TRO Run IPERF, Stn Top (ftKB) (ftKB) ( °) Make Model (!N Sery Type Type ON (psi) Run Date Com... 7,236-7,264 1 6,720.8 5,701.9 43.56 CAMCO KBG2 - 9 1 GAS LIFT DMY BTM 0.000 0.0 2/7/2000 IPERF, 7,2847,318 PRODUCTION 5 5'54.5" e 6644, 34-7,537 • TD, 7,542 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 07, 2011 TO: Jim Regg P.I. Supervisor ( (4'11( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F -20 FROM: John Crisp KUPARUK RIV UNIT 3F -20 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv:_1_18 NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3F -20 API Well Number: 50- 029 - 22947 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110605220131 Permit Number: 199 -079 -0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3F -20 • Type Inj -1 W TVD 5781 ' IA 800 2100 ' T 2070 2070 - P.T.D' 1990790 'TypeTest SPT Test psi 1500 OA 400 480 480 480 Interval 4YRTST P/F P ' Tubing 2600 2650 2650 2650 Notes: .4 bbl pumped for test. No problems witnessed. ` 4' a)JUN 1 '7 2011 Tuesday, June 07, 2011 Page 1 of 1 JVIEMORANDUM . State of Alaska . \Iaska Oil and Gas Conscrvation Commission 10: Jim Regg -;:>. P.r. Snpervisor I\Û5'ti . i DATE: lucsda\ Junc 12 21)0' q -, S¡ BJECT: 'vkchJnlc:d Intcg:!l\ Tests CO~OCOPfi:T. LiPS .\L\Sf.:A !\;C FRO\I: John Crisp Petrolcum Inspcctor f.:UPARUK R1V UNIT 3F-20 1QQ-071 Src: Inspector Rcviewcd Bv: P.I. Suprv :fßI2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3F-20 Insp Num: mitJCr070612123409 ReI Insp Num: API Well Number: 50-029-22947-00-00 Permit Number: 199-079-0 Inspector Name: John Crisp Inspection Date: 6/8/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. -~"_UT- ----- "--"-i--'-~---------:-T----¡---'~-------I -~--------'---T-~-'- --- -' ----------'-- Well I 3F-20 :Type InJ. I W ! TVD 5781: IA ,625 2000 1880 1870 ----------t---------:------r--~----1----r-~----¡_----- ---------:-------·---'-----·--~--¡----------l- '-' --- P.T-!>~¡~0/90_c!xpeTe~~P~c Testy.s.ï .-:.. 150~__O--,>\ 60 220' 220 220 60 Min. ----.--- --'-',' -'------- Interval _4ì'R~S2..___ RŒ____r...._ Notes: 4 bbl pumped [or test 2700 2700 SCANNED JUN· 2 1 2007 Tuesday, June 12, 2007 Page 1 of 1 . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 SCANNED SEP 082006 <\,o1Q \G\:, Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 top-fill operation was completed on August 14,2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-704},i(you have any questions. // f/ Sincerely, 4' 17 // 4,7'/7 ,l / f//f' ßj ,I,t~,/~~ j" f M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date . . " 3f-O~1 " c",... 1&p'Í"~~5. '> , , . '. I NA' . . " , "" .. ·8f~1ltI1Q~ ' 3F-02 1 85-226 24' 7.0 8/14/2006 7.5 8/21/2006 '3~~,fJ,ff" ' "'. 't.afit~2t .,' ,'... ... ' t3"4" . , .: . .' :",'c" , '811:4/2¡¡~ . [." '. ~:',8~~1!@t1~ . 3F-04 1 85-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 ~ ," ,.' 5.1 .' . . ,'c" ',: .' :"ØJ;1i412Q'(;f6f . ¡... , 1~5t '. . , ig~1'Þ2â06:' 3F-06 1 85-244 Did not modify 3~:()7 "','1~~2~: " '.' ".... 6~6 . 8/14'I2:QÐ6: .,. ..' 1~5 ' . ,J}/21ì2Q()6.,· . . .' 3F-08 1 85-246 1 1 14" 2.6 8/14/2006 6.6 8/21/2006 3F~ØQ:," .' .' '1å~~'l,() Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 3f:;-1:1: . "18,5"2'12 ' " ,·$F, '. .....NA. . ' .r5 ~;." ,'. ' . ,1,.1: . I. ðI4~Æ~4O:~' . 3F-1 2 1 85-273 7'4" 1 .8 8/14/2006 6.2 8/23/2006 ~ '1'~~~1!1~¡': '< . ,',"1. '.' NÀ . :.'-., l~ _, £1.:- ".;: :~ß/29þtê10(!t '-:_. 185-292 Did not IOUUIIY -''1;},{«~ I,a· 2A. " " '-' '" . , -, 'B'fj~12P'Ø'~":, ;<) " ":Ø¡2':tl2Ó1i)$: ,- 3F-16 196-151 6" NA NA 2.7 8/23/2006 ~F;':11 ' ." ~ - "ft" - ."" 3.1 , 8lt:A4~20Ø6-' '. ;, 8 , af2-8'kaÖ:Øfi>;,:, . '. , 3F-1 8 196-112 4' NA NA 28 8/23/2006 :3F~J9: - - , -¡ ··.Ztt4~a:1EF :f,~;,8" . . . NÄ '. '.8". .,f\1A. - . ..... .. 2' ;.':8/~S'120Ø6. ' 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-2:1 200¡2ß3 I .45" . . NA NA '- 31 8121ìzOb6 MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg "V", Ii (öù' t:;; P.I. Supervisor f-.....Cf( DA TE: Monday, October 24, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-20 KUPARUK RIV UNIT 3F-20 Src: Inspector /0·' fA',. /, 0 ' ,Cn Reviewed By: P.I. Suprv _-J15e- Comm FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 3F-20 Insp Num: mitCS051018074724 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-22947-00-00 Permit Number: 199-079-0 Inspector Name: Chuck Scheve Inspection Date: 10/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3F-20 Type Inj. w I Tv~-1___ 5781 IA 1370 I 2210 2200 2200 I I t·- P.T. 1990790 TypeTest SPT I Test psi I 1445.25 OA 360 ---1-- 460 460 460 Interval 4YRTST P/F P Tubing 2250 ~~50 2250 2250 Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity, 5i;ìANNE( NO\! 1 7 2005 Monday, October 24, 2005 Page 1 of 1 10/13/2005 4:05 PM 1 of 1 Jim Regg AOGCC Please schedule MITs and provide at least 24 hrs advance notice for inspector witness. I'd appreciate confirmation of your scheduling by next Monday, 10/10/2005. ~KRU 3F-20 (PTD 1990790) - last MIT 1/14/2001 KRU 3F-21 (PTD 2002030) - last MIT 7/21/2001 The Commission's records show MITs are due on the following wells: -----Original Message----- From: J a me s Regg [~.9.:.~.~..t...?..:...J.~.~~_~.~.9,9,~?..9.:ª~~J..~...:"..ê..~:..9.:.!::"s:".:...~.~...:...:g:.§.] Sent: Wednesday, October 05, 2005 4:24 PM To: NSK Problem Well Supv Cc: Tom Maunder Subject: MITs Due titANNE[,) NO\! 1 (I 2005 Thank s , Marie McConnell Problem Well Supervisor 659-7224 I'm not sure when we'll be able to schedule these last few tests, it should only be 1 or 2 days of testing. It has been our understanding that the tests can be completed anytime within the calendar year in which they come due. While we have until Dec 31 to complete these tests, we prefer to complete them in the summer as winter testing is less efficient. I will attempt to schedule them before I leave on 10/19. We are currently in the middle of repairing the near surface, surface casing leaks on 3F-18 and 3F-17, so I'm unable to commit to a date for MITIAs at this time. We actually have 12 more MITIAs on our 2005 MITIA list. 3F-20 and 3F-21 are among those 12 wells. We've been scheduling this year's MITIAs between our diagnostic testing, waiver compliance testing, pre-rig testing, and repair work this summer and are about 90% complete so far. These last few tests might have been completed already, but the inspectors have been very busy this summer with meter proving and other high priority work, so we've also been working with their busy schedule per their request. Thanks for the reminder. I appreciate your help in working together on compliance, much preferred over the alternative. Jim, q ) ) RE: MITs Due . ~ ~ Conoc~iIIi ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED S~P 3 0 2004 September 27, 2004 Alaska Oil & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 report notice for ConocoPhillips Alaska, Inc. well 3F-20. A cement OA squeeze was performed on this well 9/19/04 as a preemptive measure to prevent problems should the well develop a surface casing leak. Please call MJ Loveland or me at 659-7224 if you have any questions. Sincerely, Br~P Brad Gathman Problem Well Supervisor Attachments OR\G\NAL ~ ~ RECEIVED SEP 3 02004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATlqf\J_~- n:1 0 rtu "'-"" Abandon 0 RepairWell 0 Plug Perforations 0 Stimulate 0 n,....n.. ..~... ...' ~ 1. Operations Performed: OthEJ{nchor .¡ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension Change Approved Program 0 Ope rat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 199-079 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-029-22947-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 88' 3F-20 8. Property Designation: 10. Field/Pool(s): Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7542' feet true vertical 6302' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical 6276' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' SURFACE 3415' 7-5/8" 3503' PRODUCTION 6742' 5-1/2" 6830' LINER 707' 4-1/2" 7537' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3-1/2' , ,6839' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 497' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMSBFL SEP~ij 2004 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure Tubino Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG0 GINJO WINJO WDSPLO 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: Contact Brad Gathman/MJ Loveland 659-7224 Printed Name Brad Gathman Title Problem Wells Supervisor Ý. } Signature ~~ Phone 907-659-7224 Date' ¿ r- (') 1 PrRosrprl ¡"""har^n All - -4RI? .. Form 10-404 Revised 04/2004 nn'G\NAL Submit Original Only ~ ~ 3F-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 9/19/2004 Pump 30 bbls of tail cement down OA to cement shoe. Estimated top of cement at 3003' MD. 9/24/2003 MITOA - Failed at 1800 psi. No substantial leak-off. Initial T/I/O = 2500/0/500, pressure up OA with diesel to 1800 psi, start MITOA T/I/O = 2500/0/1450, re-pressure to 1800 psi, start MITOA T/I/O = 2500/0/1800,15 minute reading T/I/O = 2500/0/1500,30 minute reading T/I/O = 2500/0/1300 bleed down. ~ ~ MECHkl"ICAL INTEGRITY TEST (MIi, FORM WELL NO,: 3F-20 DATE: 19-24-04 WELL TYPE: MI I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITOA i.e., Tbg, IA /9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 1 psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: IDiesel d IIW IIh dP f dd' T Recor a e ea ressures be ore an Urine est. STARTTIME: 09:10 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING 2500 2500 2500 T IA/9-S/S" 0 0 0 FAIL OA/13-3IS" 500 1800 1450 1 COMMENTS: 1st test START TIME: 09:25 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING 2500 2500 2500 2500 T IA/9-S/S" 0 0 0 0 FAIL OA /13-3IS" 1450 1800 1500 1300 2 COMMENTS: 2nd test PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME: I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) FAIL S TUBING T IA/9-S/S" OAf 13-3IS" 3 COMMENTS: rSC COMMENTS: * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFFill D - FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D - FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. D - NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: ¡Brake & Arend - AES cc: PWS 6/3/00 . . . , .~ ~ .~I!'II~ .~!. .1nC. KRU 3F-20 3F-20 - API: 500292294700 Well Type: INJ Anale (â) TS: 41 dea (â) 6967 TUBING SSSV TvDe: NiDDle Oria Completion: 1/25/2000 Anale (â) TD: 44 dea (â) 7542 ¡o.æ39, Annular Fluid: Last W/O: Rev Reason: Tao TO OD:3.5OO, Reference Loq: Ref Loa Date: Last Update: 1/3/2004 ID:2.992) Last Tao: 7453 TO: 7542 ftKB Last Tao Date: 1/1/2004 Max Hole Anole: 44 dea (â) 7542 SURFACE CasinG StrinG . ALL STRINGS (0-3503, DescriDtion Size ToD Bottom TVD Wt Grade Thread OD:7.625, SURFACE 7.625 0 3503 3239 29.70 L-80 BTC-MOD Wt29.70) PRODUCTION 5.500 0 6830 5782 15.50 L-80 LTC-MOD CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED LINER 4.500 6830 7537 6298 12.60 L-80 IBT-MOD TubfnaStrina - TUBING .. Size I ToD I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 6839 I 5788 I 9.30 I I EUE-MOD Perforations Summarv Interval TVD Zone Status Ft SPF Date TVDe Comment 7236 - 7264 6081 - 6101 A-3 28 4 2/13/2000 IPERF 27/8" DP, EJ 111,0 deg ODUCTION ' - ..- Dhasino. +1- 90 deo orient (O-ææ, I; 7284 - 7318 6116 - 6140 A-2 34 4 2/13/2000 IPERF 27/8" DP, EJ 111,0 deg OD:5.5OO, Dhasino. +1- 90 dea orient Wt15.50) Gas Lift Mandrels/Valves St I MD I TVD I :~ Man Type I V Mfr I V Type I V OD I Latch I Port I TRO I Date I Vlv Run Cmnt , 1 I 6720 I 57011 CAMCO I KBG2-9 I CAMCO I DMY I 1.0 I BTM I 0.000 I 0 I 2/7/2000 I Other II luGS e UiD. etc.'. JEWELRY DeDth TVD TvDe Description ID 497 497 NIP CAMCO NO GO 2.813 6781 5745 NIP CAMCO D NIPPLE WINO GO PROFILE 2.750 6829 5781 SEAL BAKER SEAL ASSEMBLY 3.000 NIP I~NðtAs ,.. .....'..'" '."....'.'....>'...' ,..................................... ,».> (6781-6782, Date I Note OD:4.540) 1/25/2000 I Pups are BTC-MX EUE 8rd special clearance. SEAL (68mB30, OD:4.500) Perf - - (7236-7264) - - - - - - - - LINER - - - - (6lID7537, - - 00:4.500, - - Wt12.60) - I-- - I-- - I-- - I-- Perf - I-- (7284-7318) - I-- - I-- - f-- - f-- - f-- - f-- - f-- - f-- - I-- - I-- - I-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P, O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory __ Stratigraphic __ Service._X 4. Location of well at surface 5185' FNL, 252' FEL, Sec. 19, T12N, R9E, UM ,At top of productive interval 2121' FNL, 993' FEL, Sec. 19, T12N, RgE, UM `At effective depth (asp's 508246, 5985917) ,At total depth 1740' FNL, 1106' FEL, Sec. 19, T12N, R9E, UM (asp 's 507376, 5989361) 12. Present well condition summary Total depth: measured true vertical 7542 feet 6302 feet Plugs (measured) 6. Datum eleVation (DF or KB feet) RKB 88 feet 7. unit or Property name Kuparuk Unit 8. Well number 3F-20 9, Permit number / approval number 199-079 / 10. APl number 50-029-22947 11. Field / Pool Kuparuk Oil Pool Effective depth: measured true vertical feet Junk (measured) feet Casing Length CONDUCTOR 121' SURFACE 3415' PRODUCTION 6742' PRODUCTION 707' Size Cemented Measured Depth True vertical Depth 16' 9 cu yds Portland Type III 121' 121 ' 7-5/8' 343 sx AS III LW & 564 sx Class C- 3~03' 3239' 5-1/2' 195 Sx C~ass G 6830' 5782' 4-1/2" 195 sx Class G 7537' 6299' PRODUCTION Perforation depth: 'Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) i:~ ...... 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure .................. . 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data, OikBbl Gas-Md Water-Bbl' C asi n.g___.._.p..r_~_s...u...r...e.. .......... Tubing. 15. Attachments Copies of Logs and Surveys run __ Dally Report of Well Operations ._X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge~ ............. SignedjeffA. Spencer ~%~'-'~~'~'~/-~-'~/ Title Production Engineering Supervisor Questions? Call Jeff Spencer 659-7226 Prepared by Robert Christensen 6~9-7E35 SUBMIT IN DUPLICATE 3F-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to DrilINo. 1990790 WelIName/No. KUPARUK RIV UNIT 3F-20 Operator PHILLIPS ALASKA INC. APINo. 50-029-22947-00-00 MD 7542 TVD 6302 Completion Date 2/14/2000 Completion Status 1WINJ Current Status IW1NJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -- __ DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH / Dataset Type Media F_0[mat' .Nam.~._ ~i-'i_ ........ Sca!e .... Media _Nj ...... _St_a_rt- .... s!0p CH ....... _R~c~ei~ved Nu_mber Comments ............... q:( SRVY RPT 0 7542 OH 2/10/2000 ' ~-I~-~YC ........................... y DGR/EWR4-TVD 25 FINAL 227 6302 OH 6/21/2000 O 6/21/2000 09568C,/' 176-7488 L-'~$TAT BHP-TEM 5 FINAL 7177 7400 CH 2/25/2000 Lc//SCMT 5 FINAL 6650 7454 CH 3/14/2000 BL(C) 9 .... --c~~''DGR/EWR4-MD 25 FINAL 227 7542 OH 6/21/2000 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/N~ Ghips-Rec~iverl2-. ........ Aiial-ysis-Reeeivc .al'?'---Y-/N Daily History Received? (~)/N Formation Tops Receuived? (~)/N Comments: Compliance Reviewed By: ...................../,~ Dte;a ~[._., .,../~/~¢~. _ .i)~.(3..~g~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 3, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-20 (Permit No. 199-79) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 3F-20. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil E~ Gas r"~ suspended E~ Abandoned [~ Service [~] Injector 2. Name of Operator .:- ...... ~.',~-~,~;.~.~ 7. Permit Number t *,.f~-:'~'.~,; :,.; .... .f 199-79 ARCO Alaska, Inc.~ ,., ~_:,_, 3. Address I ' i( 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~:?.:~r~..~%,~.~ 50-029-22947 4. Location of well at surface ~ ;;'. "-::'~"~',,--.~ ~k? 9. Unit or Lease Name 94' FSL, 254' FEL, Sec. 19, T12N, R9E, UM (ASP: 508246, 5985917) ; .?~L-..': ":~ "~ ; Kuparuk River Unit 2121' F~L, 993' F~I_, Sec. 19, T12N, R9~, UM (ASP:507490, 5988982.9). ~ 3F-20 At Total Depth ~'. ! 11. Field and Pool 1743' FNL, 1105' FEL, Sec. 19, T12N, R9E, UM (ASP:507375.6, 5989361) "~ . _. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 84 feetI ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. __ ~?.,~15. Water Depth, if offshore 16. No. of Completions January 7, 2000 January 20, 2000 ~ ~_~~~-l,,-¢-.i- N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey '120. Depth where SSSV set 21. Thickness of Permafrost 7542' MD/6302'TVD 7473' MD/6253'TVD YES [~] No r-~ ! N/A feetMD 1584' 22. Type Electric or Other Logs Run GR/PWD/DDS, GR/Res/DDS/PWD, SCMT, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP Be'I-I-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 24" 9 cu yds Portland Type III 7.625" 29.7# L-80 Surface 3503' 9.875" 343 sx AS III LW, 231 sx Class G 5.5" 15.5# L-80 Surface 6830' 6.75" 195 sx Class G 4.5" 12.6# L-80 6830' 7537' 6.75" same as above 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) ~ ~/~' ~!.~" ;; ':~: ~ i"i~" 3.5" 6829' N/A , j: 7298'-7318' MD 6126'-6140' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7236'-7264' MD 6081'-6101' TVD 4 spf . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7284'-7298' MD 6116'-6126' TVD 4 spf ~ N/A · ORi S, ,AL,,, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 6967' 7073' 7215' 7398' TRUE VERT. DEPTH 5884' 5963' 6067' 6199' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF A-FI-ACHMENTS Summary of Daily Operations, Directional Survey .... -. ,; .. -' ~. r', ' 32. I hereby certify that the following is true and correct to the best of my knowledge. ~' ' ; ¢ ' Graham Alvord Title Drilling Engineerinq Supervisor Date . Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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: tf 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fo rm 10-407 Date: 02/16/00 ARCO ALASKA INC. WELL SI/MPLARY REPORT Page: 1 WELL:3F-20 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/07/00 START COMP: RIG:NABORS 19E WI: 0% SECURITY:0 API NUMBER: 50-029-22947-00 BLOCK: FINAL: 01/03/00 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 114/114 114) RIG UP OVER WELL 3F-20 SUPV:R. L. MORRISON JR. Move rig modules from 2G pad to 3F pad. Rig up to spud. 01/04/00 (D2) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 114/114 0) RIGGING UP, NIPPLE UP DIVERTER SYSTEM SUPV:R. L. MORRISON JR. Continue to rig up. Rig up derrick. Set shop, camp, dewater house. Raise mast. Held pre-spud meeting. 01/05/00 (D3) MW: 8.6 VISC: 110 PV/YP: 18/34 APIWL: 11.6 TD/TVD: 114/114 0) FUNCTION TEST DIVERTER FOR AOGCC SUPV:R. L. MORRISON JR. Complete derrick board pin-up and windwall closure. PJSM. Continue to rig up. 01/06/00 (D4) MW: 8.6 VISC: 155 PV/YP: 21/50 APIWL: 10.0 TD/TVD: 114/114 ( 0) DRILLING AT 138' SUPV:R. L. MORRISON JR. Complete diverter nipple up. PJSM. Function test diverter. Held diverting shallow gas drill. PJSM. Rig accepted at 12:00 pm 1/6/2000. 01/07/00 (D5) MW: 9.2 VISC: 125 PV/YP: 31/50 APIWL: 8.4 TD/TVD: 1067/1067 ( 953) DRILLING AT 1400' SUPV:R. L. MORRISON JR. Tag ice at 104' Clean out conductor from 104' to 114' Drill 9-7/8" hole from 114' to 285' Circulate clean. Take gyro survey at 285' Drill 9-7/8" hole from 285' to 712' Rig generator went down. Repair. Drill from 712' to 916' Put on larger shaker screens. Drill from 916' to 1067'. Rig ran out of water. 01/08/00 (D6) MW: 9.4 VISC: 115 PV/YP: 35/40 APIWL: 6.8 TD/TVD: 2347/2316 (1280) DRILLING AT 2600' SUPV:R. L. MORRISON JR. Drill 9-7/8" hole from 1076' to 1506'. Reroute tugger cables and stand back kelly. Wipe hole from 1506' to drill collars. Hole free. Trip to bottom, hole free. Wash 30' to bottom. Drill 9-7/8" hole from 1506' to 1570'. Rig generator went down. Drill 9-7/8" hole from 1570' to 1790' Safety meeting and fire drill. Drill 9-7/8" hole from 1790' to 2347' Date: 02/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 01/09/00 (D7) MW: 9.6 VISC: 119 PV/YP: 38/32 APIWL: 5.8 TD/TVD: 3515/3248 (1168) CIRCULATE A_ND COND. MUD AND HOLE FOR CASING SUPV:R. L. MORRISON JR. Drill from 2347' to 2896' Circulate hole clean. Held safety meeting and H2S drill. Wipe hole from 2896' to 1966'. Work pipe through tight spots 2486' to 2382' and 2130' to 2098'. RIH to 2856' wash to 2896' precautionary. Circulate hole clean. Drill from 2896' to 3515'. Circulate bottoms up. Held divert shallow gas drill. Pump hi-density hi vis sweep. Good cuttings recovery from sweep. 01/10/00 (D8) MW: 9.9 VISC: 102 PV/YP: 34/21 APIWL: 5.8 TD/TVD: 3515/3248 ( 0) CIRCULATE AND CONDITION MUD AND HOLE FOR CEMENT JOB. SUPV:R. L. MORRISON JR. Wiper trip to hwdp. Tight and swabbing from 1845' to 1625' work pipe as required. Circulated hole clean at 1719' Continue wiper from 1625' to 1235' hole free. Not swabbing. RIH. Wash 30' to bottom, no fill. Pump hi-vis hi-density sweep. Good cuttings recovery from sweep. POOH. Hole started swabbing. Pump and work out of hole using head pin from 1972' to 1235' - to prevent swabbing. POOH with hwdp, no swabbing. Rig up to run casing. PJSM. Run 7-5/8" casing. 01/11/00 (D9) MW: 9.7 VISC: 42 PV/YP: 16/ 8 APIWL: 0.0 TD/TVD: 3515/3248 ( 0) NIPPLE UP 11" BOPE SUPV:R. L. MORRISON JR. Run 7-5/8" casing. Circulate mud. PJSM. Pump cement. Did not bump plug. WOC. Break out and laydown landing joint. Set out and break down hydrill. Clean out remaining cement in hydril. 01/12/00 (D10) MW: 9.0 VISC: 42 PV/YP: 8/ 8 APIWL: 15.0 TD/TVD: 3515/3248 ( 0) MAKE UP BHA SUPV:R. L. MORRISON JR. PJSM. NU BOPE. Safety meeting. Test all BOPE to 250/3000 psi. 01/13/00 (Dll) MW: 8.8 VISC: 42 PV/YP: 11/ 7 APIWL: 14.0 TD/TVD: 3515/3248 ( 0) POOH SUPV:R. L. MORRISON JR. PJSM. Lay down 6.5" drill collars. Rabbit 2 - 4 3/4" drill collars to remove scale and pick up same. PJSM. Rabbit drill collar. Drift stuck in drill collar. Drive drift through drill collar. RIH w/HWDP. Safety meeting. Test upper and lower kelly valves to 250/3000 psi and test methane and H2S alarms to complete BOPE test. Safety meeting. RIH to 3311', bit taking weight. Break circulation. Union on stand pipe started leaking. Repair. Date: 02/16/00 ARCO ALASKA INC. WELL SUMPLARY REPORT Page: 3 01/14/00 (D12) MW: 8.8 VISC: 42 PV/YP: 11/ 7 APIWL: 14.0 TD/TVD: 3515/3248 ( 0) MAKE UP BHA SUPV:R. L. MORRISON JR. Ream and wash soft cement from 3311' to 3376'. Drill cementing plugs and firm cement from 3376' to float collar at 3414'. Attempted to test casing to 3000 psi. Test bled off at 50 psi per minute. Circulate bottoms up. PJSM. Had problems standing back kelly. Thaw out trip tank pump. POOH. RIH with retrieve-a-matic packer. Mud and water freezing to floor hands. Plug holes in wind walls. Steam ice off rig floor. Rig boilers still not operating efficiently. PJSM. RIH with packer and HWDP. Circulate out thick mud. Set packer at 1074' Test casing about packer to 3000 psi. No pressure loss. Test casing below packer. Had 300 psi loss. Release packer. Run in hole with Baker retrieve-a-matic packer. 01/15/00 (D13) MW: 8.9 VISC: 44 PV/YP: 15/16 APIWL: 7.0 TD/TVD: 4217/3787 ( 702) DRILLING AT 4696' SUPV:R. L. MORRISON JR. Continue RIH with Baker retrieve-a-matic to 3380' Circulate bottoms up. Test casing to 3000 psi above packer at 3380' No pressure loss. Test below packer to 3000 psi, pressure loss through cement channel in shoe joints. POOH with packer. RIH w/HWDP. Circulate bottoms up. Drill out float collar at 3414'. Drill hard cement and float shoe at 3503' Clean out rat hole to 3515' Drill new hole to 3535'. Circulate bottoms up. Pump hi-vis spacer and displace well with new LSND mud. Perform LOT to 14.38 ppg EMW. Drill 6.75" hole from 3535' to 4217' 01/16/00 (D14) MW: 9.3 VISC: 45 PV/YP: 15/17 APIWL: 5.0 TD/TVD: 5024/4421 (807) DRILLING AT 5282', NOW WORKING ON SCR'S AGAIN. NOTE: SUPV:R. L. MORRISON JR. Drill 6.75" hole from 4217' to 4730' Trouble with SCR rotary table function. Drill 6.75" hole from 4730' to 4772'. Circulate hole clean for wiper trip. Wipe hole to shoe. Hole free. Work on SCR rotary table function. RIH to bottom. Washed last 30' no fill. Drill 6.75" hole from 4772' to 4896'. Auger locked up. Pull 5 stands. Work on cuttings auger. Pick up kelly and wash 40" to bottom, no fill. Drill 6.75" hole from 4896' to 5024' Date: 02/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 01/17/00 (D15) MW: 9.3 VISC: 47 PV/YP: 15/18 APIWL: 4.8 TD/TVD: 5276/4626 ( 252) FINISH HOOK UP NEW TRACTION MOTOR. SHOULD BE RUNNING I SUPV:R. L. MORRISON JR. SCR went down on rotary table. Work pipe and circulate at slow rate. Drill 6.75" hole from 5024' to 5276' SCR went down on rotary table. Circulate with slow pump while trouble shooting. Rotary traction motor burned up. Pump slug and pull to shoe. Hole free. PJSM. Pull wind wall on rig floor. Pull traction motor. Reinstall wind wall. Pull hub off motor and install on new motor. 01/18/00 (D16) MW: 9.3 VISC: 50 PV/YP: 17/24 APIWL: 4.2 TD/TVD: 5468/4626 (192) DRLG @5990' SUPV:R.W. SPRINGER/TOM BROCKWAY Pull wind walls back off w/crane, set traction motor on floor, reinstall windwalls. Bolt and wire traction motor. Pick up single, go into open hole and circ mud around, blow down mud lines, lay down single. Alarm coming on rotary, troubleshoot electrical problems w/rotary. RIH. Ream to bottom, no problems. Drilling from 5276'-5468' 01/19/00 (D17) MW: 10.3 VISC: 53 PV/YP: 20/24 APIWL: 4.0 TD/TVD: 6574/5594 (1106) DRILLING @6880' SUPV:R.W. SPRINGER/TOM BROCKWAY Drill from 5468'-6574' Held spill drill. Circulate and condition mud. Blow down lines, set back kelley. PJSM. Perform fit to 12.1 ppg, 10.3 ppg mud. RIH to 6574', no problems. 01/20/00 (D18) MW: 10.3 VISC: 48 PV/YP: 23/22 APIWL: 4.0 TD/TVD: 7542/6302 (968) WIPER TRIP TO BTM SUPV:R.W. SPRINGER/TOM BROCKWAY Drill from 6574' to 7111' SCR # problems. Drill from 7111' to 7174' Problems #3 SCR. Drill from 7174' to 7542' 01/21/00 (D19) TD/TVD: 7542/6302 SUPV:R.W. SPRINGER MW: 10.3 VISC: 53 PV/YP: 23/22 0) RUNNING PRODUCTION CASING APIWL: 4.0 Circ hole clean & set back kelly. Short trip to shoe, hole clean. PJSM. RIH, no problems. Circ sweep & clean hole. Monitor well, pump dry job, blow down & set back kelly. POH. 01/22/00 (D20) TD/TVD: 7542/6302 ( SUPV:R.W. SPRINGER MW: 10.3 VISC: 44 PV/YP: 18/20 0) FINAL CUT OF CASING F/SLIPS APIWL: 4.0 PJSM. Run 4.5" & 5.5" casing. Break circ, mud returns not correct. Break circ slowly, lost 9 bbl, circ bttms up. Continue RIH. Gained 7 bbls back. Circ, hole taking fluid. Continue RIH w/5.5" casing to bottom. PJSM. Pump cement. Bump plugs. Floats held. Date: 02/16/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 01/23/00 (D21) TD/TVD: 7542/6302 SUPV:R.W. SPRINGER 01/24/00 (D22) TD/TVD: 7542/6302 SUPV:R.W. SPRINGER 01/25/00 (D23) TD/TVD: 7542/6302 SUPV:R.W. SPRINGER MW: 10.3 VISC: 0) RUNNING COMPLETION 0 PV/YP: 0/ 0 APIWL: 0.0 ND BOPs. Install packoff and test. PSJM. MW: 0.0 VISC: 0 PV/YP: 0/ 0 0) NIPPLING DOWN STACK, NIPPLE UP TREE APIWL: 0.0 PJSM. RIH w/3.5" completion assy. Displace well to seawater. Pressure tubing to 3500#, OK. Pressure annulus to 3500#, OK. Rig down high pressure lines. Install back pressure valve. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) RIG RELEASED ND choke, kill line and valves, ND stack. Install tree and test tree. PJSM. Pump diesel to freeze protect. Release rig ~ 1330 hrs. 1/25/2000. PJSM. Prepare rig to move. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~' K1(3F-20(W4-6)) WELL JOB SCOPE JOB NUMI~ER ' " 3F-20 DRILLING SUPPORT-CAPITAL 0131000653.1 DATE DAILY WORK UNIT NUMBER 02/14/00 PERF A2, A3. INITIAL A2&A3 BHP. 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 YESI YES SWS-ELMORE HUNT FIELD AFC# CC# Signed ESTIMATE AK0038 230DS36FG , , Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 200 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED 7236'-7264' (A2) AND 7284'-7298' (A3). 200 PSI RISE IN WHP AFTER A3 PERF. BHP = 2675@7277'; 2645@7177' MD.[Perf, Pressure Data] TIME LOG ENTRY 07:00 MIRU SWS 2128 ELMORE, TGSM, PT 3000#. 08:30 RIH W/SWIVEL,WTBAR, CCL, 14' GUN. OAL=31'. ORIENTED RIGHT 90 DEG FLSH. 08:50 TI GUN 3. RIH TO 7380. 09:00 LU TO SHOOT 7284'-7298', ORIENTED RIGHT 90 FLSH. POOH. 09:50 RIH W/GUN 4. 14' ENERJET ORIENTED LEFT. 10:15 CHECKTI, RIH TO 7380'. WHP=0 PSlG. 10:20 LU SHOOT GUN 4 7284'-7298', ORIENTED LEFT 90 FLSH. POOH. WHP=0 PSIG. 11:00 RIH W/GUN 5.28' EJ ORIENTED LEFT 90 FLSH. 11:28 TI GUN 5. WHP=0 PSIG. 11:36 LU SHOOT GUN 5. POOH. WHP=200 PSlG. 12:25 RIH W/GUN 6, ORIENTED RIGHT 90 FLSH. 12:55 TI GUN 6. 13:00 SHOOT GUN 6 ORIENTED RIGHT 90 FLSH. POOH. WHP=250 PSlG. 13:40 RIH W/SWIVEL, WTBAR,CCL/GR,PRESS,TEMP. 14:15 TI TO SCMT LOG. 14:28 LOG 30 MIN PRESSURE AT 7277' MD (SENSOR DEPTH), AND 10 MIN PRESSURE AT 7177' MD. POOH. 15:40 AT SURFACE, RD. 16:40 RDMO TO HOUSE. ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, K1(3F-20(W4-6)) WELL JOB SCOPE JOB NUMBER 3F-20 DRILLING SUPPORT-CAPITAL 0131000653.1 DATE DAILY WORK UNIT NUMBER 02/13/00 SCMT-CEMENT BOND LOG, PERF 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 NOI YES SWS-ELMORE HUNT FIELD AFC# CC# Signed ESTIMATE AK0038 230DS36FG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSI 0 PSI DAILY SUMMARY SCMT SHOWS GOOD CEMENT JOB. PERFORATED ~298'-9318' (20' OF A2 SAND), 4 SPF, ORIENTED +/- 90 DEG FLSH.[Perf] TIME LOG ENTRY 07:45 ON LOC, WAIT FOR SLICKLINE TO FINISH D & T. 10:30 MIRU, SWS 2128 ELMORE, PT 3000# 11:10 RIH W/SWIVEL,WTBAR,SCMT. OAL-40.5' 12:10 TI TO MWD LOG. RIH TO TD. 12:15 LU MAIN & REPEAT PASSES AT 2000 FPH. POOH. 13:40 AT SURFACE, BD. PROD ENGR REVIEW LOG, OK TO PERF. RU GUN 1. 14:40 PT 3000#, RIH W/GUN 1. WHP=0 PSI. SWIVEL,WTBAR,CCL MPD, 20' X 2.125 EJ GUN. OAL=36.7'. ORIENTED 90 DEG LEFT. 15:25 TI TO SCMT AT JEWELRY. CORRECT -7'. RIH TO 7415'. 15:30 LU JEWELRY LOG 7415'-6650'. 16:05 PUH TO SHOOT 7298'-7318', WHP=1100 PSI. BLED TO 600 PSI TO BALANCE BHP WITH ESTIMATED RESVR PRESSURE. ORIENTED 90 DEG L FLSH. POOH. WHP=0 PSI. 16:40 AT SURFACE, RU GUN 2. SAME AS GUN 1, EXCEPT ORIENTED RIGHT 90 DEG FLSH. 17:00 RIH W/GUN 2. 17:35 TI GUN 2. PERF FROM GUN 1 VISIBLE ON CCL. 17:40 LU TO SHOOT 7298'-7318', ORIENTED RIGHT 90 DEG FLSH. POOH. 18:30 AT SURFACE, RD. 19:30 RDMO TO HOUSE. LV EQUIP SPOTTED TO FINISH PERFING TOMORROW. North Slope Alaska Alaska State Plane 4 Kuparuk 3F 3F-20 Surveyed: 20 January, 2000 SURVEY REPORT 4 February, 2000 RECEIVED FEB 10 ~000 Naska Oil & Gas Co,qs. Commissior~ Anchorage Your Ref: API-500292294700 Surface Coordinates: 5985917.14 N, 508245.89 E (70° 22' 21.8822" N, 149° 55' 58.7285" W) Kelly Bushing: 88.30ft above Mean Sea Level O RIL. L. INI~ SERVICES Survey Ref: svy9010 All. ALLIBuR'rQN CO~tPANY North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 3F-20 Your Ref: API-500292294700 Surveyed: 20 January, 2000R E ¢ E IV E D FEB 1 0 2000 Vertical Depth (ft) AJask.~ 0il & Gas Co,qs. CommissiOn A~ch0rage Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Dogleg Rate (°/lOOff) Alaska State Plane 4 Kuparuk 3F Vertical Section (ft) Comment 3F-20 PHOTO GYRO 0.00 0.000 190.0O 0.750 3F-20 0.000 225.000 -88.30 101.69 210.20 0.530 231.500 121.89 270.44 0.610 258.990 182.13 306.25 0,790 271.390 217.94 337.61 0.840 264.290 249.29 368.17 1.050 280.230 279.85 399.85 1.900 286.370 311.52 428.98 1.920 290.780 340.63 457.87 2.720 295,440 369.50 487.91 3.560 299.920 399.49 520.01 5,180 304.200 431.50 550,33 6.600 306.520 461.66 580,72 7.820 306.010 491.81 611.39 8.290 306.060 522.18 642.00 8.380 304.110 552.46 672,90 8,590 306.070 583.02 701.98 8.740 305.800 611.77 731.20 8.590 306.020 640.66 762.21 8.160 307.090 671.34 793.10 7.340 308.660 701.95 824.15 6,980 311,180 732.75 0.00 189.99 210.19 270.43 306.24 337.59 368.15 399.82 428.93 457.80 487.79 519.80 549.96 580.11 610.48 640.76 671.32 700.07 728.96 759.64 790.25 821.05 0.00 N 0.00 E 5985917.14 N 508245.89 E 0.88 S 0.88W 5985916.26 N 508245.01 E 1.03 S 1.05W 5985916.11 N 508244.85 E 1.27 S 1.58W 5985915.87 N 508244.31 E 1.30 S 2.01W 5985915.84 N 508243.88 E 1.31 S 2.46W 5985915.82 N 508243.43 E 1.29 S 2.96W 5985915.85 N 508242.94 E 1.09 S 3.75W 5985916.05 N 508242.15 E 0.78 S 4.67W 5985916.36 N 508241.23 E 0.31 S 5.74W 5985916.82 N 508240,15 E 0.46 N 7.19W 5985917.59 N 508238,70 E 1.77 N 9.25W 5985918.90 N 508236,64 E 3.58 N 11.78W 5985920.71N 508234.10 E 5.83 N 14.86W 5985922.96 N 508231.02 E 8.36 N 18.33W 5985925,48 N 508227.55 E 10.91 N 21.97W 5985928.03 N 508223.91 E 13.53 N 25.70W 5985930.64 N 508220.18 E 16.10 N 29.24W 5985933.21 N 508216.63 E 18.69 N 32.81W 5985935.79 N 508213.06 E 21.37 N 36.44W 5985938.47 N 508209.43 E 23.93 N 39.73W 5985941.03 N 508206.14 E 26.41 N 42.70W 5985943.50 N 508203.17 E 0,395 1.145 O.468 0.654 0.359 1,095 2.725 0.509 2.843 2,911 5.144 4,748 4.020 1.533 0,969 1.157 0.534 0.526 1.475 2.741 1.538 0.00 -0.63 -0.74 -0.83 -0.75 -0.66 -0.51 -0.12 0.41 1.13 2.24 4.03 6,41 9.36 12.68 16.06 19.53 22.90 26.30 29.81 33.10 36.25 MWD Magnetic Continued... 4 February, 2000 - 10:50 - 2 - DrillQuest 1.05,04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for 3F-20 Your Ref: API-500292294700 Surveyed: 20 January, 2000 R E C E IV E D 854.86 6.650 313.120 763.25 851.55 885,03 6.300 315.660 793.22 881.52 915,86 5.470 319.420 823.89 912.19 947.71 4.940 323.240 855.61 943.91 973.87 2.530 340.120 881.71 970.01 1005.18 1.200 355.030 913.01 1001.31 1093.56 0.880 148.160 1001.38 1089.68 1185.89 0.940 149.240 1093.70 1182.00 1280,33 0.990 156.270 1188.13 1276.43 1343,26 1.160 148.900 1251.04 1339.34 1409.35 1.010 149.230 1317.12 1405.42 1448.40 0.330 158.000 1356.17 1444.47 1467.27 0.210 287.650 1375.04 1463.34 1499.26 0.370 319.810 1407.03 1495.33 1532.22 1.030 317.800 1439.99 1528.29 1563.87 1.900 321.100 1471.63 1559.93 1595.49 3.100 318.640 1503.22 1591.52 1627.33 4.440 319.050 1534.99 1623.29 1658.82 5.480 319.980 1566.36 1654.66 1689.60 6.900 326.770 1596.96 1685.26 1721.70 7.290 332.210 1628.81 1717.11 1753.39 7.580 338.040 1660.24 1748.54 1784.76 9.000 347.310 1691.28 1779.58 1816.51 10.590 347.250 1722,56 1810.86 1848.42 11.460 346.790 1753.89 1842.19 .FEB 10 2000 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (fi) (fi) (ft) Dogleg Rate (°llOOft) 28.85 N 45.40 W 5985945.94 N 508200,46 E 31.23 N 47.83 W 5985948.32 N 508198,03 E 33.56 N 49.97 W 5985950.64 N 508195.89 E 35.81 N 51.78 W 5985952.89 N 508194.07 E 37.26 N 52.65 W 5985954.34 N 508193.20 E 38.23 N 52.91 W 5985955.31 N 508192.94 E 38.58 N 52.63 W 5985955,66 N 508193.22 E 37.32 N 51.87 W 5985954.41 N 508193.98 E 35.91 N 51.15 W 5985953,00 N 508194.70 E 34.87 N 50.60 W 5985951.95 N 508195.25 E 33.80 N 49.95 W 5985950.88 N 508195.90 E 33.40 N 49.74 W 5985950.48 N 508196.12 E 33.36 N 49.75 W 5985950.44 N 508196.10 E 33.45 N 49.87 W 5985950.54 N 508195.98 E 33.75 N 50.14 W 5985950.84 N 508195.71 E 34.37 N 50.66 W 5985951.46 N 508195.19 E 35.42 N 51.55 W 5985952.51 N 508194.30 E 37.00 N 52.93 W 5985954.08 N 508192.92 E 39.07 N 54.70 W 5985956.15 N 508191.15 E 41.74 N 56.65 W 5985958.82 N 508189.19 E 45.16 N 58.66 W 5985962.23 N 508187.18 E 48.88 N 60.38 W 5985965.95 N 508185.46 E 53.19 N 61.69 W 5985970.26 N 508184.14 E 58.46 N 62.88 W 5985975.53 N 508182.94 E 64.40 N 64.25 W 5985981.47 N 508181.56 E 1.310 1,499 2.967 1.987 10.029 4.487 2.291 0.068 0.136 0.348 0.227 1,756 2.604 0.695 2.004 2.761 3.809 4.209 3.312 5.183 2.419 2.549 6.203 5.008 2.740 Alaska State Plane 4 Kuparuk 3F Vertical Section (ft) Comment 39.29 42.20 44.99 47.62 49.24 50.25 50.51 49.11 47.56 46.41 45.21 44.77 44.74 44.86 45.22 45.95 47.19 49.06 51.51 54.58 58.39 62.42 66.92 72.32 78.42 Continued.,. 4 February, 2000- 10:50 -3- DrillQuest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 3F-20 Your Ref: API-500292294700 Surveyed: 20 January, 2000 R E [ E iV E D Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) FEB 1880.03 13.000 347.250 1784.78 1873.08 1914.60 13.240 347.400 1818.44 1906.74 1945.87 14.230 348,380 1848.82 1937.12 1975.56 15.590 349.460 1877.51 1965.81 2007.64 16.540 348.930 1908.34 1996.64 2039.04 17,900 347,800 1938.33 2026.63 2070.65 18.740 347.890 1968.34 2056.64 2102.81 20.020 348.710 1998.67 2086.97 2132.98 20.250 348.500 2027.00 2115.30 2164.26 21.020 348.950 2056.27 2144.57 2196.84 22.580 348,720 2086.52 2174.82 2228.33 23.650 348,280 2115.48 2203.78 2261.46 25,070 347,340 2145.66 2233.96 2291,41 25.290 348,330 2172.77 2261.07 2323,40 26.260 348,110 2201.57 2289.87 2353.52 27,620 347.410 2228.43 2316,73 2382.91 28,410 347.510 2254.37 2342,67 2415.59 29,970 347.450 2282.90 2371,20 2447.83 29.900 347.980 2310.84 2399.14 2478.96 30.740 347.790 2337.71 2426.01 2511.02 32.460 346.910 2365.02 2453.32 2540.92 32.650 346.690 2390.22 2478.52 2574.66 33.400 346,540 2418,51 2506.81 2604.52 35.320 345.910 2443,16 2531.46 2636.73 35.420 346.460 2469,42 2557.72 Alaska Oil & Gas Co~s. Com.~issior~ Anchorage Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°ll00ft) 70.93 N 65.76 W 78.58 N 67.48 W 85.84 N 69,03 W 93.34 N 70.50 W 102.06 N 72.16 W 111.16 N 74.04 W 120.88 N 76.13 W 131.33 N 78.30 W 141.51 N 80.35 W 152.32 N 82.50 W 164.19 N 84.85 W 176.30 N 87.31 W 189.66 N 90.20 W 202.11 N 92.88 W 215.73 N 95.72 W 229.07 N 98.62 W 242.54 N 101.62 W 258.10 N 105.07 W 273.82 N 108,49 W 289.18 N 111.79 W 305.57 N 115.47 W 321.24 N 119.15 W 339.13 N 123.41 W 355.49 N 127.42 W 373.60 N 131.87 W Alaska State Plane 4 Kuparuk 3F Vertical Section (ft) 5985988.00 N 508180.06 E 4.882 85.12 5985995.65 N 508178.33 E 0.701 92.96 5986002.91 N 508176.76 E 3.252 100.38 5986010.40 N 508175.29 E 4.675 108.00 5986019.12 N 508173.61 E 2.996 116.86 5986028.22 N 508171.73 I:: 4.460 126.15 5986037.93 N 508169.62 E 2.659 136.07 5986048.38 N 508167.45 E 4.069 146.73 5986058.56 N 508165.39 E 0.799 157.10 5986069.37 N 508163.22 E 2.513 168.11 5986081.23 N 508160.86 E 4.795 180.19 5986093.35 N 508158.38 E 3.442 192.53 5986106.70 N 508155.48 E 4.443 206.19 5986119.15 N 508152.78 E 1.587 218.92 5986132.76 N 508149.93 E 3.047 232.81 5986146.10 N 508147.02 E 4.636 246.45 5986159.57 N 508144.01 E 2.693 260.24 5986175.12 N 508140.53 E 4.774 276.17 5986190.84 N 508137.09 E 0.849 292.25 5986206.20 N 508133.78 E 2.716 307.95 5986222.59 N 508130.08 E 5.554 324.74 5986238.25 N 508126.39 E 0.749 340.83 5986256.13 N 508122.11 E 2.236 359.21 5986272.49 N 508118.08 E 6.539 376.06 5986290.59 N 508113.61 E 1.036 394.70 Comment Continued... 4 February, 2000 - 10:50 -4 - DrillQuest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) 2668.61 36.030 346.270 2495,30 2583.60 2731.90 37.910 346.630 2545,87 2634.17 2831.79 37.700 346.960 2624.79 2713.09 2859.62 37.750 347.780 2646.80 2735.10 2951.49 37.850 349.140 2719.39 2807.69 3047.89 37.640 347.170 2795.62 2883.92 3142.66 37.280 348.910 2870.85 2959.15 3236.61 39.540 347.580 2944.47 3032.77 3332.14 39.340 348,250 3018.24 3106.54 3427.07 39.040 348.570 3091.82 3180.12 3453.94 38.920 348.250 3112.71 3201.01 3545.02 38.650 347.980 3183.70 3272.00 3655.94 40.210 346.670 3269.38 3357.68 3750.59 40.730 342.920 3341.39 3429.69 3845.47 40.940 343.660 3413.18 3501.48 3940.27 41.120 344.360 3484.69 3572.99 4033.45 39.650 342.480 3555.67 3643.97 4127.77 38.670 341,110 3628.81 3717.11 4222.56 38,810 340.580 3702.74 3791.04 4318.66 38,650 340,280 3777.71 3866.01 4413.19 37.260 343.020 3852.25 3940.55 4507.81 37.090 345.540 3927.65 4015.95 4601.64 38.400 347.640 4001.84 4090.14 4699.71 38.480 345,940 4078.66 4166.96 4793.65 38.630 345.590 4152.12 4240.42 Survey Report for 3F-20 Your Ref: API-500292294700 Surveyed: 20 January, 2000 Local Coordinates Northings Eastings (ft) (ft) RECEIVED FEB 1 0 2000 Nask~ 0il & Gas Co,~s. Ccmm~sst0r~ Anchora[te Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/100ft) 391.69 N 136.26W 428.69 N 145.18W 488.30 N 159.16W 504,92 N 162.89W 560.08 N 174.15W 617.83 N 186.26W 674.22 N 198.21W 731.35 N 210.11W 790.69 N 222.82W 849.45 N 234.87W 866.01 N 238.27W 921.84 N 250.02W 990.57 N 265.49W 1049.82 N 281.60W 1109.24 N 299.44W 1169.07 N 316.58W 1226.93 N 333.79W 1283.50 N 352.39W 1339.54 N 371.86W 1396.19 N 392.00W 1451.35 N 410.32W 1506.38 N 425.81W 1562.25 N 439.11W 1621.60 N 453.04W' 1678.35 N 467.44W Alaska State Plane 4 Kuparuk 3F Vertical Section (ft) 5986308.68 N 508109.20 E 1.945 413.32 5986345.67 N 508100.24 E 2,990 451.37 5986405.27 N 508086.19 E 0.292 512.59 5986421.88 N 508082.45 E 1.812 529.61 5986477.03 N 508071.12 E 0.914 585.84 5986534.77 N 508058.95 E 1.270 644.78 5986591.14 N 508046.94 E 1.179 702.36 5986648.26 N 508034.97 E 2.561 760.66 5986707.59 N 508022.20 E 0.492 821.29 5986766.34 N 508010.08 E 0.381 881.20 5986782.89 N 508006.67 E 0.872 898.08 5986838.71 N 507994.86 E 0.350 955.07 5986907.41N 507979.31E 1.594 1025.48 5986966,65 N 507963.13 E 2.629 1086.89 5987026.05 N 507945.23 E 0.556 1148.88 5987085.86 N 507928.02 E 0.521 1211.09 5987143.70 N 507910.75 E 2.049 1271.41 5987200.26 N 507892.08 E 1.386 1330.85 5987256.27 N 507872.56 E 0.380 1389.97 5987312.90 N 507852.36 E 0.257 1449.86 5987368.04 N 507833.98 E 2,311 1507.85 5987423.05 N 507818.42 E 1.619 1565,00 5987478.90 N 507805.06 E 1.956 1622.42 5987538.24 N 507791.06 E 1.081 1683.37 5987594.97 N 507776.60 E 0.282 1741.92 Comment Continued... 4 February, 2000 - 10:50 - 5 - DrillQuest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Survey Report for 3F-20 Your Ref: API-500292294700 Surveyed: 20 January, 2000 Sperry-Sun Drilling Services R£C£1V D 10 2000 Alaska Oil & G~s Co~;s, Oom~issio~ Anch0~age Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 4885.73 38.240 344.850 4224.25 4312.55 4981.46 38,230 346,760 4299.45 4387.75 5075.21 39.480 350.330 4372.46 4460.76 5169.72 39.180 350,290 4445.56 4533.86 5222.92 38.760 349,230 4486.93 4575.23 5359.39 37,520 348.310 4594.26 4682.56 5455.02 38,440 350,140 4669.64 4757.94 5549.91 40,490 351.980 4742.89 4831.19 5644.74 40.850 352.050 4814.82 4903.12 5740.61 40.850 352.200 4887.34 4975.64 5834.33 40,790 351.550 4958.26 5046.56 5930.21 40.970 351.910 5030.76 5119.06 6026.19 41,160 352.330 5103.12 5191.42 6122.70 41.790 352,950 5175.43 5263.73 6217.33 42.500 350.040 5245.60 5333.90 6311.71 42.900 348.890 5314.96 5403.26 6407.29 43,360 349.440 5384.72 5473.02 6500.92 44.040 346,520 5452.42 5540.72 6593.38 43,210 343.360 5519.35 5607.65 6687.50 42.480 342.370 5588.36 5676.66 6783.23 42.740 342.110 5658.82 5747.12 6881.19 41,460 341.390 5731.50 5819.80 6975.50 41.350 342.500 5802.24 5890.54 7064.75 42.710 343.080 5868.53 5956.83 7475.61 44.390 343.610 6166.30 6254.60 1733.69 N 482.04W 1791.12 N 496.57W 1848.75 N 508.22W 1907.80 N 518.30W 1940.72 N 524.25W 2023.39 N 540.65W 2081.19 N 551.64W 2140.77 N 560.99W 2201.97 N 569.58W 2264.08 N 578.17W 2324.73 N 586.83W 2386.83 N 595.85W 2449.29 N 604.50W 2512.68 N 612.68W 2575.46 N 622.08W 2638.38 N 633.79W 2702.56 N 646.07W 2765.81 N 659.55W 2827.40 N 676.10W 2888.56 N 694.96W 2950.28 N 714.73W 3012.65 N 735.29W 3071.96 N 754.62W 3129.03 N 772.30W 3400.23 N 853.40W Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/100fi) Alaska State Plane 4 Kuparuk 3F Vertical Section (ft) 5987650.30 N 507761.94 E 0.655 1799.15 5987707.72 N 507747.35 E 1.235 1858.39 5987765.33 N 507735.63 E 2.735 1917.10 5987824.36 N 507725.49 E 0,319 1976.79 5987857.28 N 507719.51 E 1,481 2010.16 5987939.93 N 507703.01 E 0.999 2094.30 5987997.72 N 507691.96 E 1,521 2153.02 5988057.29 N 507682.54 E 2.487 2213.04 5988118.48 N 507673.89 E 0,383 2274.44 5988180.59 N 507665.23 E ,0.102 2336.73 5988241.22 N 507656.50 E 0.458 2397.62 5988303.31 N 507647.41 E 0.309 2460.00 5988365.76 N 507638.70 E 0.349 2522.63 5988429.14 N 507630.44 E 0.779 2586.06 5988491,91 N 507620.97 E 2.195 2649.20 5988554.82 N 507609.20 E 0.929 2713.05 5988618.99 N 507596.84 E 0.622 2778.26 5988682.23 N 507583.30 E 2.274 2842.87 5988743.79 N 507566.67 E 2.523 2906.64 5988804.94 N 507547,75 E 1.055 2970.58 5988866.63 N 507527.91 E 0.328 3035.28 5988928.98 N 507507.28 E 1.396 3100.81 5988988.26 N 507487.89 E 0.787 3163.06 5989045.32 N 507470.15 E 1.585 3222.75 5989316.43 N 507388.74 E 0.418 3505.61 Comment Continued... DrillQuest 1,05.04e 4 February, 2000 - 10:50 - 6 - North Slope Alaska Survey Report for 3F-20 Your Ref: API-500292294700 Surveyed: 20 January, 2000 Sperry-Sun Drilling Services RECEIVED FEB I 0 Alas](-~ 0[I & G.~.s C0?,s. Commission Anchorage Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 7542.00 44.390 343.610 6213.74 6302.04 3444.78 N 866.51 W 5989360.97 N All data is in feet unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/100ft) 507375.59 E 0.000 Magnetic Declination at Surface is 26.544° (28-Dec-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 345.520° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7542.00ft., The Bottom Hole Displacement is 3552.1 Oft., in the Direction of 345.881° (True). Alaska State Plane 4 Kuparuk 3F Vertical Section (ft) Comment 3552.02 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 7542.00 6302.04 3444.78 N 866.51 W Projected Survey Continued... DrillQuest 1.05.04e 4 February, 2000 - 10:50 - 7- Sperry-Sun Drilling Services Survey Report for 3F-20 Your Ref: API-500292294700 Surveyed: 20 January, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 3F Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 210.20 210.19 To Measured Depth (ft) 210.20 7542.00 Vertical Depth (ft) 210.19 6302.04 Survey Tool Description Good Gyro MWD Magnetic RECEIVED FEB 1 0 200~ AJask~ Oil & G~,'~ Co~s. Commissio~ 4 February, 2000 - 10:50 - 8 - DrillQuest 1.05.04e iqq. o~4C~ Schlumberger NO. 121231 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1 R-01A 20076 SCMT 2/6/00 1 1 R-22A 20075 SCMT 2/5/00 1 3F-20 20086 SCMT 2/13/00 1 R C'E!V n 2/29/00 SIGNED: DATE: th Alaska 0il & (~as ~0,~. Anchorage Please sign and return one c is transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Schimberger NO. 121212 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2Z-23 ~.L,L~(--- WATER INJECTION PROFILE 000211 I 1 3F-20 STATIC BHP W/TEMP 000214 I 1 1G-17.1~ 20012 SCMT 991203 I nrrrl\lEr~ FEB 25 2000 SIGNED: DATE: Alaska, Oil & Gas ~orl~. ~,~ll~.~ssion ~ch0.ra9~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. i nanK you. 2/23/00 04-Feb-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3F-20 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 7,542.00' MD (if applicable) RECEIVED FEB 1 0 ~000 Alaska Oil & Gas Cons. Corn,mission Anchorage Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) CPF3 H2S Follow Up Subject: CPF3 H2S Follow Up Date: Thu, 16 Dec 1999 13:55:40-1000 From: "Thomas A Brockway" <TBROCKW~mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us CC: "Paul Mazzolini" <PMAZZOL~mail.aai.arco.com>, "Chip Alvord" <CALVORD~mail.aai.arco.com>, "Mike Zanghi" <MZANGHI~mail.aai.arco.com>, "Randy L. Thomas" <RLTHOMAS~mail.aai.arco.com>, "Nabors 19E Company Man" <NABORSCM~mail.aai.arco.com> Dear Blair, Thanks again for the quick response on the H2S issues and the clarification on what is expected by the AOGCC. Recapping the conversation this morning between you, Paul Mazzolini, and myself, this is what I understand to be the expected requirements when the "Hydrogen Sulfide measures" box has been checked on the approved Permit to Drill: AAI Drilling will continue to comply with current AOGCC regulations and AAI Drilling Standard Operating Procedures as follows: 1) The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2) The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors will also be maintained on location. 3) Self Contained Breathing Apparatus for all rig personnel will be maintained on location 4) Ail personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of personal protective equipment 5) A standard H2S contingency plan will be posted at the rig. 6) H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered It is expected that for standard KRU drilling operations, the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H2S encounter, drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures, full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49, and approval of the AOGCC. If you have any additional comments or would like to discuss this issue further, please contact myself or Paul Mazzolini (263-2603). Sincerely, Tom Brockway Operations Drilling Engineer 263-4135 1 of 1 12/16/99 3:43 PM ,_ Kuparuk'CPF3 H2S ..... Subject: Kuparuk CPF3 H2S Date: Wed, 15 Dec 1999 10:30:53 -1000 From: "Thomas A Brockway" <TBROCKW~mail.aai.arco.com> To: blair wondzell@admin.state.ak.us CC: "Paul Mazzolini" <PMAZZOL~mail.aai.arco.com>, "Chip Alvord" <CALVORD~mail.aai.arco.com>, "Mike Zanghi" <MZANGHI@mail.aai.arco.com>, "Randy L. Thomas" <RLTHOMAS~mail.aai.arco.com> Hello Blair, After our conversation yesterday I was able to track down the most recent H2S sampling data from the Kuparuk CPF3 area and wanted to pass it along to you for your records. One thing I noticed when reviewing this data was that the produced H2S average at 3F Pad has dropped from 265 ppm in 1994 to 154 ppm in 1997. In light of this and the fact that we have not encountered H2S during previous drilling operations from 3F Pad, I was wondering if you would be willing to take another look at the H2S classification on the permit to drill for the upcoming 3F-20 injector well (APD# 99-079). In the event that you may , , ~ be willing to change this classification, the rig will still be required to follow AAI Drilling SOP in regards to H2S and will have fully functioning H2S monitoring equipment, self contained breathing apparatus for rig personnel, and rig crews which have been trained in H2S emergency procedures and the use of personal protective equipment. In addition, I can also have H2S treating material for the drilling mud system available on location in the event that any H2S is encountered. Also, for future reference, I was wondering if you could give me some insight on the criteria that you use to determine when to specify H2S measures on the drilling permit (i.e. is there a pad average cutoff you use, etc.). I have read through the regulations (20 AAC 25.065) but would still appreciate some further clarification. I would welcome th~;chance to discuss this issue with you further and can be reached at 263-%135. If I am unavailable, you may also contact Paul Mazzolini, Drilling Team Leader, at 263-4603. Thanks again for any help or insight that you can give. Tom Brockway Operations Drilling Engineer 263-4135 (See attached file: 1997 H2S SAMPLING.xls) ~i' Name: 1997 H2S SAMPLING.xls 1997 H2S SAMPLING.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel)I Encoding: base64 Microsoft Excel 5.0 Description: 1 of 1 12/15/99 3:20 PM 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 _ Perforate _ Other _X Change of rig 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 94' FSL, 254' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 2040' FNL, 1055' FEL, Sec. 19, T12N, R9E, UM At effective depth At total depth 1823' FNL, 1108' FEL, Sec. 19, T12N, R9E, UM 5. Type of Well: Development __ Exploratory __ Stratig rap h ic __ Service __X 6. Datum elevation (DF or KB feet) RKB 84' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-20 9. Permit number / approval number 99-79 10. APl number 50-029-22947 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measu red 7529 true vertical 6352 Effective depth: measu red true vertical Casing Length Conductor 26' Surface 3397' Size 16" 7.625" Production 6760' 5.5" Liner 685' 4.5" Proposed as per Permi' feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds. Portland Type II1 368 sx Class G,308 sx AS III, 60 sx AS I 199 sx Class G see above to Drill #99-79 Measured Depth True vertical Depth 110' 110' 3481' 3226' 6844' 5824' 7529' 6352' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth N/A I Packers & SSSV (type & measured depth) N/A 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation December 7, 1999 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _//~/~,4,4/~,, ~ i~').~,.~, Title: Drilling EngineeringSupervisor OralSarn Alvord FOR COMMISSION USE ONLY Questions? Call Tom Brockway 263-4135 Date t' { ~ I.,-a ~ Prepared b~' Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness I I ¢..~ OO~¥ Plug integrity BOP Test Location clearance J n°'-~//--(~/""~ "~ ~"~ Approval fO'q':-' -- -- -- I~)~ ~V~(~8~o,,,d% Mechanical Integrity Test ~ , . Subsequent for~ required 10- [~y order of the Commi~ion O~[GI~L~,I_~D~Z Commissioner Date 1/--/ ~~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. AAI Drilling Post Office Box 100360 Anchorage, Alaska 99510 November 4, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Revision of Application for Permit to Drill Permit # 99-79 KRU 3F-20 Kuparuk Injector, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby requests a revision of permit #99-79 referencing KRU well 3F-20 located in the Kuparuk River Unit. Due to rig scheduling issues, ARCO proposes to drill and complete this well using Pool Rig 9 rather than Nordic Rig 3 as stated in the original permit application. No changes from the oriqinal permit application are planned in the drill and complete procedure, fluid program, casing program, or directional profile. Please find attached a listing of the Pool Rig 9 Drilling Fluids System and schematics detailing the diverter and BOP systems which Pool 9 will use on this well. Please note that the revised anticipated spud date for this well is December 7, 1999. If you have any questions or require further information, please contact Tom Brockway at (907) 263- 4135 or Chip Alvord at (907) 265-6120. Sincer ~ Thomas A. Brockway Operations Drilling Engin.~,~ Attachments: CC: KRU 3F-20 Well File Chip Alvord Randy Thomas Randy Kanady Mark Chambers ATO- 1030 ATO- 1038 ATO-1290 ATO- 1 O32 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Drilling Fluids System - Pool Riq 9 3 - Derrick FIo-Line Cleaners Demco Desander Derrick Desilter Derrick DE 1000 Centrifuge Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor 9 - Gallagher pit agitators Cuttings Dryer RECEIVED.. 2T-210 (E) 1 TAB, 11/03/99, vl ,1" 5000 psi BOP Stat.. Pool Arctic Alaska Rig 9 ~ .5 L Kill Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. Choke Line BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 10 minutes. 12. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. 13. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. 14. Perform BOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 30 day intervals. Functionally operate BOPE daily. 15. Pit drills are to be conductled weekly for each drilling crew. 1. 16" Starting Head 2. 11" 5000 psi Through Bore System Wellhead 3. 11" 5000 psi Hydril SGL Gate (pipe rams), 4-1/16" 5000 psi Side Outlets wi Manual Locks 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate 2 Kill valves - one 2" 5000 psi Hydraulic gate and one 2" 5000 psi Manual gate 1 Check valve in Kill Line - 5000 psi 5. 11" 5000 psi Hydril Double Ram (pipe rams on top, blind on bottom), 4-1116" 5000 psi Side Outlets w/ Manual Locks 6. 11" 5000 psi Hydril Annular Preventer, Flange Connection RECEIVED · ~ ~t~ Oil & Gas Cons. commission Anchorage jt Rev 10/21/99 21-1/4" DIVERTER SCHEMATIC Pool Arctic Alaska Rig 9 k Open I ~ To Accumulator I I Closed ~' '~" I ! I I I From ~ .... Accumulator Closed Open Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 3 FI 2. Close annular preventer/open the valve in the event that an influx of wellbore fluids or gas is detected. DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 21-1/4" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" x 13-5/8" 5000 psi, Double Studded Adapter Flange (Optional) 6. 21-1/4" Hydril MSP 2000 psi Annular Preventer 7. 8. RECEIVED 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 16" Diverter Line jt, Rev. 10/21/99 ARCO Alaska, Inc. To,' Blair Wondzell From: Tom Brockway PaBes: $ (including this page) Phone: 793-1226 Date; 08/10/99 Re: KRU 3F-20 Permit CC: [] Urgent X For Review [] Please Comment [] Please Reply [] Please Dear I~lair, Attached are a revised completion schematic and form 401 for well KRU 3F.20. As we discussed this afternoon, the position of the crossover seal bore on the 5-112" x 4-1/2" tapered production casing string was listed incorrectly on the original submitted permit. ARCO Alaska, Inc. proposes to place this crossover +/- 70' above the top ot the Kuparuk C4 sand at +/- 6844' MD (5824' TVD) providing a testable annulus down to this point, No other revisions to the original permit are planned at this time, Thanks again for your help in approving this permit, I apologize for any confusion or inconvenienoe resulting from this correction. If can be of any assistance or answer any questions please feel free to contact me a[ (907) 263-4135. Since'" ,,- ,.-, J Thomas A. Brockway Operations Drilling Engineer AAI Drilling STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeefwo~k: Drill [] Reddll [] lb. Type of well. Exploratory [] ._RtreligraphicTest[~ Develeprner,t Oil [--] Re-an~ ~ Deepen ~ Se,vi~ B DevebpmenlG~ ~ Single Zone ~ Multiple Zone ~ ARCO Alaska, lac, RKB 84 3. Addle-~, 8. ~oper~ D¢~ignation Kupar~ River Field . 256~ ...................... ._ p.o=~? lO.~86~..~phoruoo, ~ 995.~00a~ ..~Q.L 2~32 AkK ....... Kuj~ar~ River 4. Lo,aden of we~ at suda~ 7. UnR or proper~ Name 11. Ty~ Rand (,~ ~o 94' FSL, 264' FEL, Sec. 19, T 12N, R9E, UM .... ~aruk ~ver' Unit $tatewide Al lop of pr~e interval 8. W~I number Ntimber 204~' ¢NL, 1055' eEL, $~, 19, T12N, RgE, UM 3F-20 ¢U-630610 Al total dep~ 9. Approxima~ spud dale Amount 1823' FN~ 1108' FEL, S~. 19, TI2N, R9E, UM August 24, 1~9 12, Di~t&nce le nearest prepe~ I~e ~ 13. D~bnce ~ nearest w~l ~4. Nu~er of scr~ in properly 15. Prepuued depB (MD end TVD) 1~6 8 T~e leer~ .... 3F"17 !.5:8' ¢ 100' MD ~t 2560 7529' MD/635Z 'TVD ....................... _ ...................... 18. I ~ be c~mpletod I~ fl~vlal~d WeI}~ 17. Antici~ted press~e (o~ 2D ~ 2&o3b Kickoff dapO~: 1500 MD ~x~um hole angle 39.4~ Maximum surf~ 1~3 pMg At total d~pth oVD) 2258 18, C~i~lg pro~r~)~ Settin~ Depth ~ize . ~p~cificatio~ Top B~om Qus~tt~ of Cemenl .. Ilole C~l~ Weight- ~rade coupling Length MD TVD MD ~D (include ~f~e ~) ~0" 16' 82,5¢ R-3 Weld 26' 84' 84' 110' 118' 230 ~x , ............... 9.626'; 7.625' 29.7f~ L-80 BTC-~d 3397' 84' 84' 3481' 3226' 308 sx Cl~s G. ~8 sx AS III, 60 sx AS I 6.75' 5.5' 15.5¢ L-S0 LTCM ¢60' 84' 84' 6844' 5824' 199 ~ Cla~ G ..................... 6,75' 4,5" 12,6¢ L-SO BTOM 789' 6740' 5743' 7529' 635~ see above ................. 19. To be oomOat,d for R,~fill','~e'~' ;'%~;~;n nper~ion~. ' ..... P~nl well cotldlflon sum~v To~ Depth: ~lie~ured teel Plug~ Effec~[ve Depth; m~urad ~et Jr*Ilk (me.urn) C~ing Leith Size ~m~l~ M~sur~ depth True Ve~lcal depth Conductor Production Linor P~r~r~on (~ptir. ~uo vordc~ .. ~ ,~ .......... ~0. At~c~n~n~ Piling ~e ~ f'mpe~ PJ~t ~ HOP Skelch ~ bive~i Sket~ ~ Driling piog~am~ Dri~g ~uid program ~ Time vs dep~ plot ~ Reff~tion nn~s ~ ~bed report ~ 20 ~C 25.050 requbef~nls D 21. I hereby ~[~h~]~r~oing is ~ue ~nd correm to the b~t of my ~o~edge Qu~t/ons~'O~-II' T~' Br~kway 263.413~ · ~ Commission Use Onl~ P~m~ N~mr APl n~ [ Approv~ da~ ---~' ~¢~r ia~i ' 50-J ~for oiher requiremen~ c~ndiflm~s of approval ~1~ re~uked ~ Ye~ ~ No Mud Icg required ~ Yes ~ No Hydrogen s~fi~ me.urea ~ Yea ~ No Di[eciion~au~vey required ~ Y~ ~ Nu ~rBOPE ~ 2M; ~ ~ ~ SM; ~ 10U;~ Required working pressure O[hal: by ord~ of A~roved by Col~u~i~j~?% .......... j~_~.~ommi~,inn Dale .KRU 3F-20 Proposed_. Completio, n TAM 7-$/0" Port Collar Smd. Grade BTC Thread~ (+/- 1000' MD i 998' TVD) Surface cs9. 5/8" 29,7,~l L-80 BTCM I/- 3qSZ' MD / 3226' TVD) All Depths Reference NOr(lie 3 RKB Production c~g, 5-1/2" 15.5# L,~0 LTCM run XO/St3E to sudace (+/- 6844' MD / 5824' TVD) Production csg. 4-1/2' 12.6# L-80 BTCM run TD to ×O/SRE (+/- 7529' MD / 6352' TVD) I, 3-1/2" Gert IV tubin9 hanger with 3-1/2" I_-,':I,0 FIJE 8RD-Mod pin down H. 3-112' L-8~) 9.3# EUE 8RD-Mod tubing to surface G. 3-1/2" Camco 'DS' nipple w/2.812" No-Go Profile. 3-t/2" x 6' L-BO pup installed above. 3-1/2" x G' L-80 Iluw coupling installed below, EUE 8RD-Mod sot at +/- 5o0' MD F, 3-1/2" L-80 9,311 EUE 8RD-Mod tubing to nipple E. 3-1/'" x 1" Camco 'KBG-2~9' Mandrel w/DV and lalci~ (Max. OD 4.725", ID 2.90"). 15' L-80 crossover handling pups (BTC x Gpocial Clearence EUE BRD) installed on GLM, D. Ijt 3,1/2" L-BO 9,3~ EUE §RD-Mod tubing C. 3-1/2" Camco 'D' landing nipple wltll 2.75" ID and No-Ge profile (Max OD 4.50"} B. I Jt 3,1/2" L.80 9.3# EUE §RD.Mo0 lubh~g A. Baker 4-1/2' 'GBH-22' Locater Seal Assembly w/15' of seals & Iocalor S-1/2" ~ 6' handling p,,p installed mn top. ELJE I~RD-M~xl box up rBaker XO Coupling - J Baker 5" OD x 4" ID Seal Bore Extension J Baker XO, SBE x 4-1/2' BTCM L set at d- 6844' MD / 5824' TVD Future Thru-Tubing Perforations 4-I/2" BTCM landing coll~r/FS/FC TAB, BJ3/99, v3 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION August 20. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Graham Alvord, Drlg Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99501-0360 Re~ Kuparuk River Unit 3F-20 ARCO Alaska. Inc. Permit No: 99-79 Sur. Loc. 94'FSL. 254'FEL, Sec. 19, T12N. R9E, UM Btmhole Loc. 1823'FNL. 1108'FEL. Sec. 19, T12N. R9E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integnts.' Test (FIT). Cementing records, FIT data, m~d any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 3F must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the m]nular space of a single well or to use that xx-ell for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrits.' (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission mav witness the tests. Notice max' be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607,.,----~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC; Deparunent of Fish & Geane. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 August 4, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: KRU 3F-20 94' FSL, 254' FEL, Sec 19, T12N, R9E, UM 2040' FNL, 1055' FEL, Sec. 19, T12N, R9E, UM 1823' FNL, 1108' FEL, Sec. 19, T12N, R9E, UM Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 3F pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 3F pad. The well is designated as a monobore injector and is planned to penetrate the Kuparuk C and A sands using a 7-5/8" Surface casing string and a 5-1/2" x 4-1/2" tapered production casing string with a crossover seal bore. The well will be drilled and completed using Nordic Rig 3. Completion plans call for running 3-1/2" production tubing as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 9) 10) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs William Raatz, Geologist (20 AAC 25.071 ) 263-4952 Please note that the anticipated spud date for this well is August 24, 1999 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Chip Alvord at (907) 265-6120. Thomas A. Brockway ~ Operations Drilling Engineer Attachments: CC: KRU 3F-20 Well File Chip AIvord Mark Chambers Randy Kanady ATO-1030 ATO-1 O32 ATO-129O STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [] Redrill [] I lb. Type of well. Exploratory [] Stratigraphic Test E] DevelopmentOilE] Re-entry [] Deepen []I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 84 feet ,3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-036~ ADL 25632 ALK 2565 Kuparuk River Pool 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.0251) 94' FSL, 254' FEL, Sec. 19, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2040' FNL, 1055' FEL, Sec. 19, T12N, R9E, UM 3F-20 #U-630610 At total depth 9. Approximate spud date Amount 1823' FNL, 1108' FEL, Sec. 19, T12N, R9E, UM August 24, 1999 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1055 @ Targe feetI 3F-17 15.3' @ 100' MD feet 2560 7529 ' MD/6352 'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25,035 (e)(2)) Kickoff depth: 1500 MD Maximum hole angle 39.4° Maximum surface 1903 psig At total depth (TVD) 2258 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# R-3 Weld 26' 84' 84' 110' 110' 230 sx ASI 9.625" 7.625" 29.7# L-80 BTC-Mod 3397' 84' 84' 3481' 3226' 368 sx Class G, 308 sx AS III, 60 sx AS I 6.75" 5.5" 15.5# L-80 LTCM 6656' 84' 84' 6740' 5743' 208 sx Class G 6.75" 4.5" 12.6# L-80 BTCM 789' 6740' 5743' 7529' 6352' !see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEIVED Liner ~.~(.ii,'~ ORIGINAL Perforation depth: measured ,~aska 0il & Gas Cons. C0mrnisslor~ true vertical Anchorage 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling programr¢] Drilling fluid program [] Timers depth plot [] Refraction analysis [] Seabed report [] 2O AAC 25,050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Ca//Tom Brockway263-413~ Signed ~ Title: Date Graham Alvord ~ ~ D/filing Enginee/fng Supervisor Prp. n~rp.c] hv ,qh~rnn AIl.~Hn-F)r~l(~ / Commission Use Onl~ PermitNumber?¢... 77 I APInumber50_ o ¢- I Approvaldate ~O~)._.¢¢jforotherrequirementslSee coverletter Conditions of approval Samples required [] Yes ~ No Mud Icg required [] Yes .~ No Hydrogen sulfide measures J~ Yes [] No Directional survey required ,J~ Yes [] No Required working pressure for BOPE.Z [] 2M; [] (~;~ [] 5M; [] IOM;• [] Other: 'v" ORIGINAL SIGNED-BYRobert N. Chdstenson byorder of Approved by Commissioner the commission Date ~'. Form 10-401 Rev. 12/1/85 · Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER UNIT- INJECTOR KRU 3F-20 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/3481') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering 4. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with mud. Note: TAM Port Collar will be placed in the 7-5/8" casing 1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alteCnative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Nipple down diverter and install wellhead. NiPple up B©PE and test to 3000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 14.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Drill 6-3/4" hole to well total depth (+/- 7529') according to directional plan, running LWD logging equipment as needed. 9. Run and cement 5-1/2" 15.5# L-80 LTCM x 4-1/2" 12.6# L-80 BTCM tapered casing string with polished seal bore as part of XO. Adequate cement will be pumped to place cement top +\- 500' above the Kuparuk sands. Displace cement with mud. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 10. Pressure test casing to 3,500 psi for 30 minutes per AC)GCC regulations. Record results. 11. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 12. Freeze protect well. Pull landing joint. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. 13. Secure well. Release rig. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. 3F-20 TAB, 8/3/99, v2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 3F-20 Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casing 8.5-10.0 16-26 25-50 150-250' 10-20 10-30 8-15 8-10 4-6% Drill out to TD 9.0-10.0 5-15 5-12 30-40 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillinq Fluid System: Nordic Riq 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1903 psi. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3226 ft)(0.70 - 0.11) = 1903 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of the 3F-20 target location are expected to be -2900 psi (0.49 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.0 ppg would be predicted as the maximum mud weight needed to safely drill in this formation using conventional drilling methods, assuming a TVD of 5878'. Well Proximity Risks: The nearest existing well to 3F-20 is 3F-17. As designed, the minimum distance between the two wells would be 15.3' at 100' MD. 3F-20 TAB, 8/3/99, v2 Drillinq Area Risks: Risks in the 3F-20 drilling area include lost circulation and possible differential pressure between the "A" and "C" sands in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. If lost circulation cannot be controlled with LCM and a reduction of circulating pressure, 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #3 or a coiled tubing unit will drill out 4-3/4" hole and run a 3-1/2" liner to TD. Careful analysis of pressure data from offset wells shows that a mud weight of 10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 14.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on 3F pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3F-20 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 3F-20 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure Max Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3226') + 1,500 psi = 3513 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTCM 4,790 psi NA 6,890 psi 5,856 psi 5-1/2" 15.5 L-80 3 LTCM 4,990 psi 4,242 psi 7,000 psi 5,950 psi 4-1/2"* 12.6 L-80 2 BTCM 7,500 psi 6,375 psi 8,440 psi 7,174 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 3F-20 TAB, 8/3/99, v2 KRb 3F-20 Proposed Comply,ion TAM 7-5/8" Port Collar Stnd. Grade BTC Threads (+/- 1000' MD / 998' TVD) Surface csg. 7 5/8" 29.7# L-80 BTCM (+/- 3482' MD / 3226' TVD) All Depths Reference Nordic 3 RKB Production csg. 5-1/2" 15.5# L-80 LTCM run XO/SBE to surface (+/- 6740' MD / 5743' TVD) Production csg. 4-1/2" 12.6# L-80 BTCM run TD to XO/SBE (+/- 7529' MD / 6352' TVD) I. 3-1/2" Gen IV tubing hanger with 3-1/2" L-80 EUE 8RD-Mod pin down H. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to sudace G. 3-1/2" Camco 'DS' nipple w/2.812" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE 8RD-Mod set at +/- 500' MD F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to nipple E. 3-1/2" x 1" Camco 'KBG-2-9' Mandrel w/DV and latch (Max. OD 4.725", ID 2.90"). 15' L-80 crossover handling pups (gTC x Special Clearence EUE 8RD) installed on GLM. D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'D' landing nipple with 2.75" ID and No-Go profile (Max OD 4.50") B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 4-1/2" 'GBH-22' Locator Seal Assembly w/15' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up I!aker XO Coupling aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 4-1/2" BTCM et at +/- 6740' MD / 5743' TVD Future Thru-Tubing Perforations 4-1/2" BTCM landing collar/FS/FC TAB, 8/3/99, v2 I V 300 300 600 900 1200 1500 1800 2100 2400 2700 50OO 5300 3600 3go0 4200 4.500 4~00 5100 5400 57OO 6000 6300 6600 300 A' CO Alaska, Inc. Structure: Pod 5F Well : 20 Field : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 84' Begin Dnl Nudge 3.00 End Angle Build Begin Angle Drop 3.00 End Angle Drop Created by jones For: T BrockwayI Dote plotted : 2-Aug-1999 [ Plot: Reference Ts 20 Verslon j~8. I 1000 Coord~no{[es ore ~n fee[ reference slot 220. I I True Vertical Dep[hsm~ence Est. RKB. Top TD LOCATION: 1823' FNL, 1 108' FEL SEC. 19, T12N, RgE KOP 3.00 Bose Permafrost 6.00 9.00 12.00 ~ 15.00 DLS: 3.00 de9 per 100 ft ~[ 18.00 ~ 21.00 ~ 24.00 ~ 2Y.00 '~ 50.00 ~ 33~06.000 Top West Sok Sands 39.00 EOC Bose West Sok 7 5/8 Casing Pt MAXIMUM ANGLE 39.42 DEG Camp. SS C80 TGT #2 LOCATION: BASE A2 SANDS 1965' FNL, 1073' FEL SEC. 19, T12N, R9E TGT #1 LOCATION: TOP A3 SANDS 2040' FNL, 1055' FEL SEC. 19, T12N, RgE 800 I C20 TD 345.52 AZIMUTH 3473' (TO TD) ***PLANE OF PROPOSAL*** C40 C50 <- West (feet) 600 400 200 I I I I I I Top Kup D / C4 Top B Shale TA~OET - T/ A3 TAR~ Top C50 Miluveoch - B/ A2 TARGET - T/ A~ Top A6 Top B Shale Fop Kup D / C4 K-1 Marker Bose HRZ C50 0 C40 C50 C80 Comp. SS 7 5/8 Casing Bose West Sak C20 Base HRZ K- 1 Marker Top C3 Top C2 Top A6 yOC Top West Sok Sands ~ ~, KOP TD 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 12OO 1000 800 6O0 400 200 SURFACE LOCATION: J 94' FSL, 254' FEL SEC. 19, T12N, R9E 500 600 900 1200 1500 1800 2100 2400 2700 5000 Vertical Section (feet) -> A~,imut'h ~45.52 wifh rof~r~n¢~ 0.00 N, 0.00 Ir from $1o~ #20 3300 3600 Creoted by jones For: T Brockway Dote plottsd: 2-Aug-199g PIo~ Reference Is 20 Ve~ion ~8. ARuO Alaska, Inc. Structure: Pad 3F Well : 20 Field : Kuparuk River Unit Location : North Slope, Alaska I 520 3O0 280 260 240 22O 200 180 160 140 120 100 80 6O 4O 2O 200 180 160 140 120 I I I I I I I I I / <- West [feet] 1 O0 80 60 40 20 0 I 1~ 2500 1700 \\ 1600 \\ X~O0 2200~ ~ \\ 1400 ¥°° 190~ 2200 ~800~ ~ 700~ O0 ~ BO0~ ~ ~00 ~00~ 1900 1800 1700 2000 200 180 160 140 120 100 80 60 40 <- Wesf (feet) 20 40 60 80 I I I I I I I I I 13C0'~1500 390 12001 lO0 ~ 800 \%700 % 600 1 7O 5OO 6OO 3800 3700 320 300 280 260 240 220 200 180 160 140 120 1 O0 80 60 40 1200 20 0 3600 20 8OO 20 110C 40 0 20 40 60 80 Z 0 Creoted by jones FOl': T Rl.owekwa.,v Dote plotted: 2-Au9-1999 Plot Reference ~s 20 Version ~8. J 2300 220O 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 Alaska, In _ Structure : Pod 5F Well : 20 Field : Kup~ruk Eiver Unif Lo¢~fion : North Slope, Al~sk~ <- West (feet) 900 800 700 600 500 400 500 200 1 O0 0 1 O0 200 500 400 4800 ~, 4600 540~ ~ 4-400 4200 32oc \ ~, 4000 3000 ~ 3800 I I I I I I I I I I I I I I I I I 3400 3200 3000 280O 260O 3800 280t 5600 2400 3600 340C 2600 2200 23O0 22O0 2100 2000 1900 1800 1700 1600 1500 14oo I z 0 1500 ~--~ 1200 ~ 110o lOOO 90O 8O0 700 600 3400 i400 240( 3200 5200 3000 5000 500 400 3200~ 2000 \ 2~oo 30007 \ 18oo \ 2200 4800 2800~ 2000 \ 1600 \ 2000 1800 \ 240( 1400 900 BO0 700 BO0 500 400 300 200 100 0 100 200 500 400 <-- West (feet) 900 800 700 6OO 500 4OO 300 Creo[ed by jones For: T Brockwa~ Dete plo~d: 2-Aug-1999 Plot Reference ~s 20 Vem~on 3450 3500 315O 5000 2850 2700 2550 2400 2250 '~- 2100 1950 0 Z 18oo 1650 1500 1350 1200 1050 At , O Alaska, Inc. Structure: Pad 3F Well : 20 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 1500 1350 1200 1050 900 750 600 450 300 150 0 , 4500 4800 630~ 510( 4500 ~0 63oo 6000 ~ 5700 42 5100 4200 5400 5100 ~, 4soo ~ 4500 330( 4200 5900 4200 60( 3900 270~ 57( 5600 2700 5600 3900 5600 150 300 450 I I I 3300 3000 270O 2400 900 750 600 240~ 3300 30~ 5100 3300, 3000~ 2400 2100 1800 1500 1350 1200 1050 gOO 750 600 4-50 500 150 0 <- West (feet) 150 500 450 5450 5500 5150 5000 2850 2700 255O 2400 2250 l I 2100 1950 1800 65O 1500 1550 1200 1050 900 750 60O Arco Alaskal Inc. Pad 3F 2O slot #20 Kuparuk River Unit North Slope Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 20 Version #8 Our ref : prop71 License : Date printed : 3-Aug-99 Date created : 2-Aug-99 Last revised : 2-Aug-99 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 22 20.9561w149 55 51.299 Slot location is nTO 22 21.882,w149 55 58.729 Slot Grid coordinates are N 5985917.123, E 508245.874 Slot local coordinates are 94.16 N 253.96 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PGMS <0-8108'>,,13,Pad 3F PMSS <644 - 7165'>,,17, Pad 3F PGMS <O-8730~>,,1,Pad 3F PGMS <O-7455~>,,15,Pad 3F PGMS <O-6975~>,,14,Pad 3F PGMS <O-7570~>,,12,Pad 3F PGMS <O-8600~>,,11,Pad 3F PGMS <O-6650~>,,lO,Pad 3F PGMS <O-8070~>,,7, Pad 3F PGMS <O-'[717~>,,6,Pad 3F PGMS <O-6913~>,,4,Pad 3F PGMS <O-7966~>,,3,Pad 3F PGMS <O-7864~>,,2,Pad 3F PGMS <O-7785~>,,9,Pad 3F PGMS <O-8600~>,,16,Pad 3F PGMS <O-7050~>,,8,Pad 3F PGMS <O-8875~>,,5,Pad 3F PMSS <7121-8580~>,,16A,Pad 3F PMSS <475 - 6868~>,,18,Pad 3F PMSS <550 - 8132~>,,19,Pad 3F Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. lO-May-99 101.1 1380.0 1380.0 lO-May-99 15.3 100.0 100.0 lO-May-99 453.6 300.0 300.0 lO-May-99 54.7 0.0 1825.0 lO-May-99 79.7 0.0 0.0 lO-May-99 128.4 300.0 1750.0 lO-May-99 155.0 0.0 300.0 lO-May-99 180.3 240.0 240.0 lO-May-99 303.6 0.0 1550.0 lO-May-99 330.0 0.0 0.0 lO-May-99 379.3 0.0 1500.0 lO-May-99 404.3 120.0 300.0 lO-May-99 429.0 0.0 0.0 lO-May-99 204.2 0.0 0.0 lO-May-99 29.6 0.0 1060.0 lO-May-99 278.5 120.0 120.0 lO-May-99 354.0 140.0 140.0 lO-May-99 2132.5 7528.7 7528.7 lO-May-99 292.5 100.0 100.0 lO-May-99 142.0 100.0 300.0 ~ I~/~s/S~l ~.T ja ~ K99069ACS OS-~A.~ "-.~.~ '"',. . _ ~..,~_~ (~I/ EGEND ~ LOUNSBURY SEE SHEET ~ 2 FOR NOTES ~D LO~TION INFORMATION ~/J~ [ & ASSOCIATES, INC. i AREA: ~ ~ODULE: XXXX UNI?: 03 ARCO Alaska, Inc. ~ DSSF ~ CONDUCTOR 2e SubsidiorY of Atlontic Richfield ComponyAS-BUILT LOCA~ON ~ 15/28/991 MRS' JB P,._ K99069ACS DS-3A. ARE DRILLSITE 3-F ~NUMENT$ PER 18 1 ~16 ' .-" LHD a ASSOCIATES. , . , . . , . ,. WCINI~ MAP ~"= I Mi/e i Sec. 19, ~ 12N., ~. ~ E. wd/ A.S.P.s LA T/~DE (N) LONG/~DE No. ,~ ,X, O/S ELE~ F.S,L.~E.'L. ~ 5,985,9~7.~4 5~8,245.89 7~' 22' 2~.882' ~49' 55' ~.~29' 94' 254' 5~.8' 5~.9' ~ ~.: a '"~_~ *a SUR~YOR'S CER~HCA ~ ~ ~gth ~ ~'~ / H~r C~T/~r rHA r / A~ P~OP~Lr ~C/Sr~D AND , ,,~,~,,~,, L/C~N~ rO P~ACr/C~ LAN~ SU~V~WNC /N TH~ STAT~ O~ a ...... ' ............... ' ..... ~ ALASKA AN~ r~Ar ~'~'~~~'~'~ DONE BY ME O~ UNDER ~ DIRECT SUPERVISION AN~ ~%~,_~ LS~0~5 .,,$~ THAT ALL DIMENSIONS AND OTHER DETAIL5 ARE CORRECT ,,~........dd~.../ ~ AS O~ JUN~ Z ~. LOUNSBURY & ASSOCIATES, INC. ~.~ ~.N~ su~o~s ~EA: ~ ~UL6: ARCO Alaska,Inc. DS3F ~ ~LL CONDUCTOR 2e Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ON LK63e612 6/e2/99 , CEA-D3FX-63e6D12 2 oF 2 1 16" DI~, .~RTER SCHEMATIC-..ordic Rig 3 Kuparuk River Unit Operations Open I I Closed Closed _ _ ..~I ~ To Accumulator I From ~ .... Accumulator Open Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" Schaefer 2000 psi Annular Preventer 6. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 7. 16" Diverter Line TAB, 07/19/99, v2 11" 56,.0 psi BOP Stack-- No. Jic Rig 3 Kuparuk River Unit Operations Kill Line Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 Kuparuk River Unit Operat,ons TAM Port Collar Utilization Decision Tree Cement above Port Collar (1000' TVD), Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One Stage Cement Job / No Cement/ to Surface Cement below Port Collar (1000' TVD)/ If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion ARCO Alaska, Inc. ~ Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99.510-2776 PAY TO THE ORDER OF: The First National Bank of Chicago-0710 Chicago; Illinois Payable Through Republic Bank Shelbyville, Kentucky 230098140 73-426 839 0997587 JULY 22, 1999 ALASKA DEPT OF REVENUE ALASKA OIL & 'GAS CONSERVATION COMMI 3001 PORCUPINE "DRIVE'" . :: : :~,, i: void AFTER 90 DAYS **~;':'.,: :,' ; ':', :" EXACTLY **********'100 'DOLLARS AND 00; CENTS ¢*********** 100.00 . TRACE NUMBER: 230098140 WELL PERMIT CHECKLIST COMPANY ~'~~ WELL NAME,~.)~.~_~,,' .-~,,E'-~__O PROGRAM: exp dev redrll serv ?~'_ wellbore seg ann. disposal para req FIELD & POOL ADMINISTRATION INIT CLASS ENGINEERING APPR. DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOL AREA GEOLOGY ANNULAR DISPOSAL 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~O@~') psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... APPR DATE Y N Y N Y. N Y N Y N Y N Y N Y N Y N Y N Y N Y N 29. Is presence of H2S gas probable ................. Y"' j 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ----Y//N _~?~.,/,z~ 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory N on/..~ Y 35. With proper cementing records, this plan ,/~;~ ~,¢_~u- ~ ,~'/;~c~t 1~.'/.~j ~~--~;-~. ~ ~ N (~N (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. UNIT# /"/Z/~,,"5 ON/OFF SHORE GEQLOGY: ENGINEERING: UIC/Annular COMMISSION: ~ ' DWJ :~'-'~----~ JDH ~ CO ~o ~//~/~.~. Comments/Instructions: c:\msoffice\wordian\diana\checklist Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. · ; · .. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Jun 08 15:38:47 2000 Reel Header Service name ............. LISTPE Date ..................... 00/06/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services RECEIVED JUN 2t 2000 Alaska Oil & Gas Cons. Commission Anchorage Tape Header Service name ............. LISTPE Date ..................... 00/06/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-90217 J. PANTER B. MORRISON 3F-20 500292294700 ARCO Alaska, Inc. Sperry Sun 08-J-U-N-00 MWD RUN 3 AK-MM-90217 J. PANTER R. SPRINGER 19 12N 9E 94 254 88.30 86.50 53.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 3503.0 6.750 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING ~EMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA PJIY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 3. MWD RUN 2 DID NOT REACH BOTTOM DUE TO FAILURE OF CASING PRESSURE TEST AND IS NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PFLASE 4 (EWR4) . 5. DUE TO A FAILURE OF THE EXTRA SHALLOW PHASE RESISTIVITY THE DATA IS NOT PRESENTED. 6. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 5/24/00. MWD DATA IS CONSIDERED PDC. 7. MWD RUNS 1 AND 3 REPRESENT WELL 3F-20 WITH API# 50-029-22947-00 . THIS WELL REACHED A TOTAL DEPTH OF 7542' MD, 6302' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 176.0 R0P 227.0 RPS 3493.0 RPM 3493.0 RPD 3493.0 STOP DEPTH 7488.0 7541.5 7495.5 7495.5 7495.5 FET 3493 . 0 7495.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUlq NO MERGE TOP MERGE BASE 1 176.0 3515.0 3 3515.0 7541.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 FET MWD HR 4 1 68 24 7 Name Service Unit Min Max Mean Nsam DEPT FT 176 7541.5 3858.75 14732 ROP MWD FT/H 4.25 16428.9 210.728 14630 GR MWD API 9.43 528.41 101.984 14601 RPS MWD OHMM 0.13 1206.09 4.08845 8006 RPM MWD OHMM 0.18 2000 5.21646 8006 RPD MWD OHMM 0.21 2000 6.36882 8006 FET MWD HR 0.3028 138.262 2.29943 8006 First Reading 176 227 176 3493 3493 3493 3493 Last Reading 7541.5 7541.5 7488 7495.5 7495.5 7495.5 7495.5 First Reading For Entire File .......... 176 Last Reading For Entire File ........... 7541.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 176.0 3463.5 ROP 227.0 3515.0 $ LOG HEADER DATA DATE LOGGED: 10-JAN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 630.91 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 3515.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 39.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PBO1398HGVW6 PBO1398HGVW6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 9.875 3503.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MI/D CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SPUD 9.40 115.0 8.0 1300 6.8 .000 .000 .000 .000 .0 84.2 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 176 3515 1845.5 6679 ROP MWD010 FT/H 16.75 16428.9 255.784 6577 GR MWD010 API 9.43 125.73 69.4047 6552 First Reading 176 227 176 Last Reading 3515 3515 3463.5 First Reading For Entire File .......... 176 Last Reading For Entire File ........... 3515 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3464.0 RPS 3493.0 STOP DEPTH 7488.0 7495.5 RPM 3493.0 RPD 3493.0 FET 3493.0 ROP 3515.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOW1YHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 7495.5 7495.5 7495.5 7541.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAlgDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 20-JAN-00 Insite 0.41 Memory 7542.0 37.1 44.4 TOOL NUMBER P1386GRV4 P1386GRV4 6.750 LSND 10.40 23.0 9.5 400 4.0 1.200 .620 3.000 1.400 72.0 145.2 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ~ ~OP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 4 8 12 16 20 24 Name Service Unit Min Max DEPT FT 3464 7541.5 ROP MWD030 FT/H 4.25 1932.69 GR MWD030 API 36.05 528.41 RPS MWD030 OHMM 0.13 1206.09 RPM MWD030 OHMM 0.18 2000 RPD MWD030 OHMM 0.21 2000 FET MWD030 HR 0.3028 138.262 First Last Mean Nsam Reading Reading 5502.75 8156 3464 7541.5 173.929 8053 3515.5 7541.5 128.504 8049 3464 7488 4.08845 8006 3493 7495.5 5.21646 8006 3493 7495.5 6.36882 8006 3493 7495.5 2.29943 8006 3493 7495.5 First Reading For Entire File .......... 3464 Last Reading For Entire File ........... 7541.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/06/08 Origin ................... STS Tape Name ................ UNKI~OWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/06/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X 4. Location of well at surface 5185' FNL, 252' FEL, Sec. 19, T12N, R9E, UM ,At top of productive interval 2121' FNL, 993' FEL, Sec. 19, T12N, R9E, UM ,At effective depth (asp's 508246, 5985917) At total depth 1740' FNL, 1106' FEL, Sec. 19, T12N, R9E, UM (asp's 507376, 5989361) 6. Datum elevation (DF or KB feet) RKB 88 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3F-20 9. Permit number / approval number 199-079 / 10. APl number 50-029-22947 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary -I'otal depth: measured true vertical 7542 feet 6302 feet Plugs (measured) Effective depth: measured true vertical feet Junk (measured) feet Casing Length CONDUCTOR 121' SURFACE 3415' PRODUCTION 6742' PRODUCTION 707' Size Cemented Measured Depth True vertical Depth 16' 9 cu yds Portland Type I!1 121' 121' 7-5/8= 343 sx AS III LW & 564 sx Class (~ 3503' 3239' 5-1/2" 195 Sx C~ass G 6830' 5782' 4-1/2" ~ 95 sx C~ass G 7537' 6299' PRODUCTION Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Avera.qe Production or Inlection Data, OiI-Bbl Gas-Md Water-Bbl' Casing Pressure Tubin 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,,~'~./f~,~ ~,,~ Title Production Engineering Supervisor JaffA. Spencer Questions? Call Jeff Spencer 659-7226 Prepared by Robert Christensen 659-7535 -% ~ ..... ,~,',~ ~.-,. ~,,~t,,' SUBMIT IN DUPLICATE
