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186-136
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-13 KUPARUK RIV UNIT 3K-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-13 50-029-21630-00-00 186-136-0 W SPT 6376 1861360 1594 2850 2850 2800 2825 180 200 200 200 4YRTST P Josh Hunt 5/9/2025 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 3K-13 Inspection Date: Tubing OA Packer Depth 410 2010 1900 1880IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510092947 BBL Pumped:3.7 BBL Returned:2 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 13:58:51 -08'00' MEMORANDUM To: Jim Regg % Ito P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, May 11, 2021 SUBJECT: Mechanical Integrity Tests ConowPhillips Alaska, Inc. 3K-13 KUPARUK RN UNIT 3K-13 Src: Inspector Reviewed By: P.I.Supry J6 Comm Well Name KUPARUK RIV UNIT 3K-13 API Well Number 50-029-21630-00-00 Inspector Name: Lou Laubensteln Permit Number: 186-136-0 Inspection Date: 5/42021 , Insp Num: mitLOL210505081846 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-13 - Type Inj I w - TVD 6376 Tubing 2925 - 2925 , 2925. 2925 PTD 1 1861360 -Type Test I SPT Test psi 1594 IA 570 2000- 1990 - 1880 - BBL Pumped: 2.2 BBL Returned: 2.2 OA so 50 - so 50 - Interval 4YRTST P/F P Notes: Tuesday, May 11, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,January 22,2018 TO: Jim Regg P.I.Supervisor 1 -.4-fel 1(z'(i c SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3K-13 FROM: Guy Cook KUPARUK RIV UNIT 3K-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ46— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-13 API Well Number 50-029-21630-00-00 Inspector Name: Guy Cook Permit Number: 186-136-0 Inspection Date: 1/21/2018 Insp Num: mitGDC180121163809 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-13 Type Inj 7 W'TVD 6376 ' Tubing 2860 ' 2860 " 2860 1 2860 , PTD 1861360 Type Testi SPT Test psi 1594 - IA 970 2000 - 1930 1930 BBL Pumped: 1.5 -- BBL Returned: ; 1.4 - OA 400 450 I 450 450 Interval aYRTSTP/F I P ✓ Notes: Little Red Services pump truck used for testing SCAN1 ' ,1 0 a. ;`1 . Monday,January 22,2018 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg t7 l DATE: Wednesday,May 15,2013 P.I.Supervisor k - 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-13 FROM: Bob Noble KUPARUK RIV UNIT 3K-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J�� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-13 API Well Number 50-029-21630-00-00 Inspector Name: Bob Noble Permit Number: 186-136-0 Inspection Date: 5/12/2013 Insp Num: mitRCN130513072142 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ]861360 'Type SPT psi OA Well 3K-13 Type Inj TVD 1s9a �s1s 2000 !F 1910 1900 6376 IA PTD " 'T a Testi 'Test st Interval '4YRTST P ' Tubing 2925 29205 j 29205 2925= 1 z7 P/F Tubin 1 Notes: SCANNED FEB 2 0 2014 Wednesday,May 15,2013 Page 1 of 1 f STATE OF ALASKA A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Forforations r Stimulate r Other r PROD to INJ Alter Casing r Rill Tubing r Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -136 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service ■ 50 - 029 - 21630 - 7. Property Designation: 8. Well Name and Number: ADL 25629 ". • 3K -13 9. Field /Pool(s): .. Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 8588 feet Plugs (measured) none true vertical 6856 feet Junk (measured) 8457 Effective Depth measured 8476 feet Packer (measured) 7964, 8154 true vertical 6771 feet (true vertucal) 6375, 6523 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 115 115 0 0 SURFACE 4415 10 4452 3760 0 0 PRODUCTION 8488 7 8562 6 0 0 0 f t 0 0 0 Perforation depth: Measured depth: 8058 -8128, 8244 -8260, 8280 -8328 RECEIVED True Vertical Depth: 6449 -6503, 6593 -6606, 6621 -6658 MAR 08 ?Oi Tubing (size, grade, MD, and TVD) 2.875, J -55, 8181 MD, 6543 TVD Alaska 00 & Gas Cons. Commission Packers & SSSV (type, MD, and TVD) PACKER - CAMCO 7 X 2 7/8" HRP HYD SET PACKER, OD 5.937 ", ID 2.343 6375 TVD PACKER - BAKER 7" DB 84 -32 W/L SET PACKER @ 8154 MD and 6523 TVD SAFETY VLV - 2 7/8" CAMCO TRDP -IA -SSA SSSV, OD 5.125 ", ID 2.312" @ 1803 MD and 1784 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure • Prior to well operation ee.i - .- 3 2 600 950 160 Subsequent to operation a . - * 0 0 1445 600 2850 13. Attachments J 14. Well Class after proposed work: or Copies of Logs and Surveys run Exploratory r Development r Service 7 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WAG r GASINJ r WINJ r ' SPLUG r 16. 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: 311 -002 Contact Bob Christensen /Darrell Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659 -7535 Date z t( BDI�AS MAR 08 200 3 S•,��'� t� Form 10-404 Revised 7/2009 il'� j rigin Only • 3K -13 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/07/11 1WeII Broughton line • • 1S A[Lazu SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Darrell R. Humphre Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 %O WED IAN 1 S 1011 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K -13 Sundry Number: 311 -002 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday . ■ eekend. Sin e ly 1 1 1 Jr . or ail Com iss'.ner 1 DATED this 7 day of January, 2011. Encl. Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhillips Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 December 30, 2010 Dan Seamount'''" iVED AOGCC Commissioner 4 2011 State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 0,448 g, Go% Corr, Co iS$ion Ancnofage Dear Mr. Seamount, My sincere apologies regarding this request for approval. The request for 3K -13 sundry approval was apparently not sent in the holiday mail and was returned to my desk. It would be greatly appreciated if this approval could be expedited as quickly as possible and I apologize if for any confusion created. If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, Darrell R. Humphrey • STATE OF ALASKA 0 v o,,( 1 h, ` ALASKA OIL AND GAS CONSERVATION COMMISSION • 1 � APPLICATION FOR SUNDRY APPROVALS 1' 20 AAC 25.280 1. Type of Request Abandon ❑ Rug for Redril ❑ Ferforate New R oI ❑ Repair well ❑ Change Approved A ❑ Suspend ❑ Rug Perforations ❑ Perforate ❑ Pull Tubing ❑ rune 13denslon ❑ Operational Shutdown ❑ Re -enter Susp. Well ❑ plate ❑ Alter casing ❑ OtherPROD to INJ 1 . 2. Operator Name: 4. Current Weil Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 186 -138 3. Address: El ® 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 • 50-029 - 21630-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number. where ownership or Landownership changes: Spacing Exception Required? Yes ❑ No © 3K-13 • 9. Property Designation: 110. Field / Pool(s): . ADL 25629 Kuparuk River Field / Kuparuk 011 Pool r ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth 1VD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6856 7S 8476' 6771' none 8457' . - Casing h " , - Length ) (I') Size MD TVD Burst Collapse CONDUCTOR' ' 76 ' `i 16 115' 115' SURFACE 4415 10 4452' 3760' PRODUCTION 8488 - 7 8562' 6836' . Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8058 -8128, 8244 -8260, 8280 - 8328 6449- 6503, 6593 -6606, 6621 -6658 2.875 J-55 8181 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO 7 X 2 7/8" HRP HYD SET PACKER, OD 5.937 ", MD= 7964 TVD= 6375 PACKER - BAKER 7" DB 84-32 W/L SET PACKER MD= 8154 TVD= 6523 SAFETY VLV - 2 7/8" CAMCO TRDP - IA-SSA SSSV, OD 5.125 ", ID MD= 1803 PM= 1784 12. Attachments: Description Summary of Proposal ❑v 13. Well Class after proposed work: Detailed Operations Program in BOP Sketch ❑ Exploratory ❑ Development CI Service ©. 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/15/2010 Oil ❑ Gas ❑ WDSPL in Suspended fl 18. Verbal Approval: Date: WINJ p ' GINJ ❑ WAG in Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Printed Name Darrell R. Humphrey Title: Production Engineering Spedalist Signature Phone: 659 -7535 Date t Z- 7 / 0 Commission Use Only Sundry Number :31 —OC7. Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test II Location Clearance ❑ k►./I M Other: JAN 0 4 2011 Subsequent Form Required: /0 0 %81i$" lissiort i nOfage Ane ��� APPROVED BY /- - /1 _ A. 7 E � M ISSIONER THE COMMISSION Date: ! Form 10 -403 Revised 1/2010 V.' G NA 0 /. / / Sub mit in CSu et ��`�` 0 3K -13 DESCRIPTION SUMMARY OF PROPOSAL 3K -13 ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3K -13 from Oil Production service to Water Injection service. Well 3K -13 was produced to reduce formation pressure prior to CTD drilling for 3J -15. CTD was completed in the Kuparuk formation for 3J -15 on November 1st, 2010. Conversion to Injection service is required due to potential reservoir depletion. Well 3K -13 injection will provide pressure support to offset producer 3J -15. The 16" Conductor was cemented with 1540# Poleset (115' and / 115' tvd). The 9 -5/8" Surface casing (4452' and / 3760' tvd) was cemented with 1230sx AS III and 300sx Class G. The 7" Production casing (8562' and / 6839' tvd) was cemented with 325sx Class G and 175sx AS I. The top of the Kuparuk C was found at 7993' and / 6398' tvd. The top of the Kuparuk C1 was found at 8055' and / 6445' tvd. The top of the Kuparuk B was found at 8074' and / 6460' tvd. The top of the Kuparuk A was found at 8385' and / ' 6700 tvd. The USIT CBL has been filed with AOGCC The injection tubing /casing annulus is isolated via Camco 5.937" OD x 2.347" ID located @ 7964 and / 6376' tvd. An MIT -IA was last performed on 5/15/09; 4 year State Witnessed ( Chuck Scheve) MITIA - passed. Initial T /I /O= 2700/900/300, Pressured up IA with 2.0 bbls diesel. T /I /O= 2700/2280/300, 15 min T /I /O= • 2700/2200/300, 30 min T /I /O= 2700/2190/300. Bled IA. FinalfT /I /O= 2700/150/290 , I .1\ KUP 3K -13 ConocoPhillips tillik ell Attributes ax Angle & MD TO Inc. Wellbore API /UWI Field Name Well Status Intl1 ") MD (111(5) Act Btm ((MB) Alaska, ,,.,,,_,,,, , 500292163000 KUPARUK RIVER UNIT INJ 47.52 2,700.00 8,588.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date "' _ SSSV: TRDP Last WO: 39.01 7/29/1986 Well Confi9. - 3K -13, 3/3/2010 935 25 AM imir Schematk - Actual Annotation (Depth (ftKB)'End Date !Annotation Last Mod ... End Date Last Tag: slm 8,350.0 2/25/2010 Rev Reason: Pull Plug/Gauges, Tag, GLV C/O I lmosbor 3/3/2010 HANGER, 35 Casing Strings _ g tng . trn ID . Top .. a Set DepLpth (TVD) . string g .. String ... String Top Th rd I . I CONCaainDUCTODescripR ion string 16 0. 1 5,062 39.0 (f 115.0 th ( 115.0 62.50 WI. H-40 1 , Casing Dascripbon String 0 ... . S String ID ... Top (18(8) Set Depth (1 .... . Set De Set Depth !TVD) ... String Wt... St r i ng . Stri T op Thrd SURFACE 9 5/8 8.921 37.0 4,451.7 3,760.1 36.00 J BTC III Casing Description String 0... String ID ... Top (MB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 74.2 8,562.0 6,837.9 26.00 J -55 BTC Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... ftKBl Sat Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 39-115 TUBING I 27/8 2.441 I Top l 35.0 J 8,182.4 I 6,545.8 EUE8rdABMOD SAFETY VLV, _ ) Completion Details 1,803 1.. .1 Top Depth GAS LIFT, (TK8) Top Inc! ND ( In) 2782 Top 118(5) ( ) ( °) Item Description Comment 35.0 35.0 0.48 HANGER CIW 3 1/2" Tubing Hanger 3 1/2 8rd 2.441 Q Q 1,802.8 1,784.2 23.33 SAFETY VLV 2 7/8" CAMCO TRDP-1A-SSA SSSV, OD 5.125 ", ID 2.312" 2.312 7,946.0 6,362.1 39.04 SBR CAMCO '0E4 OD 4.750", ID 2.312° (SBR) 2.312 SURFACE, ,445 l 7,963.6 6,375.7 39.02 PACKER CAMCO 7 x 2 7/8" HRP Hyd Set Packer, OD 5.937", ID 2.347" 2.347 OAS LIFT, 8,151.5 6,521.8 39.08 SEAL ASSY Baker 5' Seal assembly w/ Locator+ 1.63 Spare out 2.406 5.117 6 111c 8,154.2 6,523.9 39.09 PACKER Baker 7" DB 84-32 w4 set Packer 3.250 GAS LIFT, 8,517 8,157.8 6,526.7 39.09 SEAL ASSY Baker 80-32 Seal Bore Extension 5' 3.250 GAS LIFT, 8,170.8 6,536.7 39.13 NIPPLE CAMCO 2 7/8" D- Nipple ID 2.250" 2.250 ]' 8,180.8 6,544.5 39.15 X0 XO 2 7/8" to 3 1/2" 3.500 GAS LIFT, _ 7,629 8,181.6 6,545.2 39.15 SOS CAMCO 31/2" Shear out Sub 2.441 GAS LIFT, r Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 7,8% 3 ". Top Depth _ (TVD) Top Incl Top (18(8) 1 111(8 1 ( ") Description Comment Run Date ID (in) SBR, 7,946 i I 8,457 6,757.7 40.23 FISH 1 1/2 DMY w/ RK Latch Empty Pocket; Fell to Rathole 12/14/1986 PACKER, 7,964 !_ -! Perforations & Slots INJECTION, Shot 8, 001 Top (TVD) Btm (TVD) Dens - Top (ftKB) Btm (111(8) (ftKB) (11118) Zone Date Hit,.. Type Comment 8,058 8,078 6,449.1 6,464.7 C-1, UNIT B, 12/5/1986 12.0 IPERF 120 deg. ph; 5" Csg Gun IPERF, 3K -13 B, D5 IPERF, 8,118 8,128 6,495.8 6,503.6 C-1, UNIT B, 12/5/1986 12.0 IPERF 120 deg. ph; 5" Csg Gun 3K -13 IPERF , . 8,244 8,264 6,593.2 6,608.9 A -3, 3K -13 8/28/1992 4.0 RPERF 0 deg ph; 2 1/8" Silver Jet 125-8,120 8. 8,250 8,251 ' 6,597.9 6,598.7 A -3, 3K -13 12/5/1986 1.0 IPERF 120 deg. phasing; 4" Csg Gun •; 8,253 8,254 6,600.3 6,601.1 A3, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun INJECT81[37 ION, 8,256 8,257 6,602.7 6,603.4 A-3, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun " I 8,258 8,260 6,604.2 6,605.8 A-3, 3K -13 3/31/1987 2.0 RPERF 60 deg ph; 2 1/8" Silver Jet SEAL ASSY,� 8,151 _ 8,259 8,260 6,605.0 6,605.8 A 3K - 13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun PACKER, 8,154 SEAL ASSY, " 8,280 8,310 6,621.4 6,644.7 A - 2, 3K - 13 8/28/1992 4.0 RPERF 0 deg ph; 2 1/8" Silver Jet 8,158 8,287 8,292 6,626.9 6,630.8 A -2, 3K -13 3/31/1987 2.0 APERF 60 deg ph; 2 1 /8" Silver Jet NIPPLE, 8,171 )rit 8,292 8,293 6,630.8 6,631.5 A -2, 3K -13 12/5/1986 1.0 IPERF 120 deg. phasing; 4" Csg Gun 8,299 8,300 6,636.2 6,637.0 A -2, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun x, 8,182 SOS, 8,182 iT 8,307 8,308 6,642.4 6,643.2 A -2, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8,311 8,312 6,645.5 6,646.3 A -2, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8,313 8,314 6,647.0 6,647.8 42, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8,320 8,321 6,652.5 6,653.2 A -2, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun IPERF, C 8,323 8,324 6,654.8 6,655.5 A -2, 3K -13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8250 - 8 ' 252 IPERF, 8,327 8,328 6,657.9 6,658.6 A - 2, 3K - 13 12/5/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8,2538,254 RPERF, Notes: General & Safety 9.2448.264 End Date Annotation IPERF, 0 11/6/2009 NOTE: VIEW SCHEMATIC w/Alaska Schemtic9.0 8256-8,257 = RPERF, = s 8,258-8,260 a IPERF , \ N CC 8,259 - 8,260 as APERF, 8,287 -9,292 IPERF, 8,292 -8,293 RPERF, 8,280 -8,310 IPERF, 8,299-8,300 PERF, 8,307 -8, IPERF, - Mandrel Details 8,311 -8,312 Top Depth Top Port (TVD) TIT OD Valve Latch Sire TRO RUn IPERF, Stn Top (ftl(B) (11081 P) Make Model (in) Sera Type Type (in) Iqi) Run Date Core... 9,3138,314 - 1 2,781,3 2,552.0 47.00 Mona TMPD 1 GAS LIFT DMY BK 0.000 0.0 10/28/1987 IPERF, 2 5,116.7 4,255.5 43.93 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/6/1986 8, 320.8 ,321 _ 3 6,516.7 5,272.8 42.95 Mena TMPD 1 GAS LIFT DMY BK 0.000 0.0 10/28/1987 8,3238324 .. 4 7,233.8 5,816.6 40.43 Mena TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/6/1986 IPERF, 5 7,629.0 6.117.8 40.11 Mer/a TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/6/1986 9,327 -8,328 6 7,895.9 6,323.1 39.11 Mena TGPD 1 1/2 GAS LIFT DMY TG 0.000 0.0 10/29/1987 FISH, 8.457 • 7 8,003.9 6,406.8 38.71 Merla TMPD 1 INJ DPHFCV BEK 0.000 0.0 3/2/2010 8 8,136.6 6,510.2 39.04 Merla TMPD 1 INJ DPHFCV BEK 0.000 0.0 3/2/2010 PRODUCTION, 74 -8,562 - + - TD, 5,588 • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhillips Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 December 7, 2010 r Dan Seamount IAN () 2011 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission ,', P C ors& Carris 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 '$ncnorhge Dear Mr. Seamount, ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3K -13 from Oil Production service to Water Injection service. Well 3K -13 was produced to reduce formation pressure prior to CTD drilling for 3J -15. CTD was completed in the Kuparuk formation for 3J -15 on November 1st, 2010. Conversion to Injection service is required due to potential reservoir depletion. Well 3K -13 injection will provide pressure support to offset producer 3J -15. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3K -13 (PTD 186 -136). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, Darrell R. Humphrey Attachments Sundry application Well schematic WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 3K-13 Run Date: 8/31/2010 -__I September 2, 2010 _; ;•~ ~ ~ ~= ~~ . The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21630-00 Bottom Hole Pressure Survey Log 1 Color Log 50-029-21630-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3535 klinton.wood ";~~ ~~, ~,:.~.%' Date: vsa ~~~ ~-r3~ °. . ~o~~~ ~~ ~~ ~ Signed: ~ ~ I ~1~ ~ ~ ~ .~3 Colombie, Jody J (DOA) "3~ From: Foerster, Catherine P (DOA) Sent: Thursday, July 29, 2010 3:19 PM To: NSK Prod Engr & Optimization Supv Cc: Seamount, Dan T (DOA); Norman, John K (DOA); Colombie, Jody J (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: Allocation Metering Request Gary, Your request is granted. Cathy From: INSK Prod~Engr & Optimization Supv [mailto:n2046@conocophillips.com] Sent: Thursday, July 29, 2010 2:46 PM To: Foerster, Catherine P (DOA) Subject: FW: Allocation Metering Request Cathy, answers to your questions below. Call or email if you have any further questions. r ~~ Thanks Gary Gary, I shared your request with a couple of folks here and they asked a few questions: 1. What other options do you have? The other option is to install a test divert valve to the test header resulting in a pad shutdown and loss of production. This option is not preferred and one we likely would not pursue, due to the production impacts and associated exposure risk. 2. Why couldn't/wouldn't you add 3K-13 to an existing test header and subtract to get 3K-13's volume? Twinning 3K-13 is not an option because of the associated back-out of production with the existing producer. In addition, design cost and fabrication for temporarily twinning 3K-13 to an existing producer is not justified. 3K-13i is not expected to make much if any oil production. The goal for this flowback is depressuring. This well has been on injection continuously since 11/1987 and has injected a cum volume of water of 5.2 MMBW. Also, comparing this well to another flowback {3K-12), since we started flowback 1/2010, cum prod is 1,156 BO with a peak of 17 bopd. Its cum injection over its life was 4.3 MMBW. The oil from these injector flowbacks does not justify twinning impacts with an active producer nor an entire header shutdown. Thanks. Cathy From: NSK Prod Engr & Optimization Supv [mailto:n2046@conocophillips.com] Sent: Wednesday, July 28, 2010 11:45 AM To: Foerster, Catherine P (DOA) Subject: Allocation Metering Request Cathy, per our discussion, ConocoPhillips woul'~like to convert Well 3K-13 from a water in~on well to a production well in an effort to reduce the reservoir pressure in the fault block before the coiled tubing drilling rig drills Well 3J-15. Approval for the conversion would be via normal Sundry process. One issue on Drillsite 3K is that all of the matched production/test header slots are full. There is a production header slot available, but not a test header slot. Therefore, one of the most promising options is to convert 3K-13 to production through the available production valve without a connection to the test header. The idea is to "roll" the injection turbine meter to the opposite direction and use it as a two phase production meter. Watercut measurement would be handled by samples and shakeouts. This well has never been on gas injection, so we do not expect gas to be a significant metering issue. Therefore, we are requesting the State allow us to utilize this metering method for allocation purposes on a temporary basis until Well 3J-15 is drilled, currently planned for November, 2010. Please call me at the number below if you have any questions Thanks in advance for your time on this matter. Gary Gary TargacJDenise Titus NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK-47 • • ~~a~~ 0~ Q1~a~~{Q /~..~..E.~w..~.,, Darrell R. Humphrey Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Poo] Sundry Number: 310-191 Dear Mr. Humphrey: Y/ i ~~ ~~ 3K-13 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisZ~ day of June, 2010. Sincerely, Daniel T. Seamount, Jr. Chair Encl. r .. e - • r ConocoPhillips June 21, 2010 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk We113K-13 from Water Injection Service to Oil Production service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3K-13 (PTD 186-136). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659-7535. Sincerely, Darrell R. Humphrey Attachments Sundry application Well schematic .. ` ~ STATE OF ALASKA ~ ~1"' , l~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~,.'lh APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~fQ.i- v V_ t 1. Type of Request: Abandon ~ Rug for Redrill r Pbrforate New Fool r Repair w ell ~ Change Approved R~ogram Suspend [` Rug Perforations ~ Perforate [' Pull Tubing r Time Extension Operational Shutdown [' Re-enter Susp. Well r Stimulate r Alter casing (- Other:WINJ to PROD'' r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Devebpment r Exploratory r 186-136 3. Address: Straf ra hic g P r Service r 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-029-21630-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes [j No ~ 3K-13 • 9. Property Designation: 10. Field/Pool(s): ADL 25629 Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft):t Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): X585 ; ~YSc~ ~c~v 8476' 6771' none 8457 Casing - z •~ Length ' ~° Size MD TVD Burst Collapse CONDUCTOR 76 16 115' 145' SURFACE 4415 10 4452' 3760' PRODUCTION 8488 7 8562' 6836' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8058-8128, 8244-8260, 8280-8328 6449-6503, 6593-6606, 6621-6658 2.875 J-55 8181 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO 7 X 2 7/8" HRP HYD SET PACKER, OD 5.937", MD= 7964 TVD= 6375 PACKER -BAKER 7" DB 84-32 W/L SET PACKER MD= 8154 TVD= 6523 SAFETY VLV - 2 7/8" CAMCO TRDP-1A-SSA SSSV, OD 5.125", ID MD= 1803 TVD= 1784 12. Attachments: Description Summary of R-oposal vj 13. Well Class after proposed work: Detailed Operations Program ~`~' BOP Sketch E~loratory r Development ~ • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/24/2010 Oil r Gas (- WDSPL ~ Suspended ['j 16. Verbal Approval: Date: WINJ [- GINJ ~ WAG ~ Abandoned ~f Commission Representative: GSTOR ~ SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob ChristenseNDarrell Humphrey Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature Phone: 659-7535 Date ~o - Zl . a C mi ion Us nl Sundry Number: O.•„~ "1 v 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance ~~~~~~~~ Other: ~uN ~ ~ zoo Subsequent Form Required: ~~ • ~~`~ ~~~=ks ~~ ~ ~~ ~~15~ (~08}(Ois~ 4~t~h®r~~~ APPROVED BY ~ ~ / O Aooroved bv: C~~'~COMMISSIONER THE COMMISSION Date• Form 10-403 Revise ~uH ~ ~ o R ~ ~ i N a ~ Ott + ~~ is ~ , t ~, to ubmit in Duplicate ,~ '~~~, • s 3K-13 DESCRIPTION SUMMARY OF PROPOSAL 3K-13 The upcoming 3J-15 CTD sidetrack will enter the fault block in which 3K-13 injector is located. It is expected that the pressure in this block exceeds the CDR2 CTD pressure drilling limit. The proposal has been made to depressurize the fault block by converting 3K-13 to production. Required time for adequate depressurization is predicted anywhere from 3 to 5 months. By November of 2010 the fault block pressure should be adequate to drill the 3J-15 CTD sidetrack. ,~ 6~g~~ 6~ _ / G •LF•!c }y~. ~~'~~ KUP ~ 3K-13 COf1000~'i1~~IP5 Well Attributes Max An le 8 MD TD ALttiM1,f. 111. Wellbore API/UWI Fieltl Name Well Status Inc! (°) MO (RKB) Act etm (RKB) 500292163000 KUPARUK RIVER UNIT INJ 47.52 2,700.00 8,588.0 Comment R23 (ppm) Date Annotation End Date KB~Grd (R) Rig Release Date "' SSSV: TRDP Last WO: 39.01 7/29/1986 Well Confi - 3K-13 3/32010 9'.35'.25 AM hemat~-I~NaI Annotation Depth (RKB) End Date Annotation Last MOd ... End Date Last Tag: slm 8,350.0 225/2010 Rev Reason: Pull Plug/Gauges, Tag, GLV C/O Imosbor 3/3/2010 HANGER, 35 Casin Strin $ Casing Description String 0... String ID .. Top (RKB) Sel Depth (f... S et Depth (TVD) .. String Wt... String ... Slring Top Tnrd CONDUCTOR 16 15.062 39.0 115.0 115.0 62.50 H-40 Caving Description String 0... String ID _. Top IRKS) Set DepN (r.. S et Deptn (TVO) String Wt... String .. String Top Tn rd SURFACE 95/8 8.921 37.0 4,451.7 3,760.1 36.00 J-55 BTC Casing Description String 0... String ID ... Top (RKB) Set OepN (f... S et Deptn (TVO) ... String Wt... String .. String Top Tn rd PRODUCTION 7 6.151 74.2 8,562.0 6,837.9 26.00 J-55 BTC ' Tubin Strin s CONDUCTOR, 39-115 ' Tubing Description String 0... Slring ID ... Top (RNs) Set Depth I/... Set DepN (TVD) ... String WI... String String Top TnrO TUBING 27/8 2.441 35.0 8,182.4 6,545.8 6.50 J-55 EUE8rdABMOD sAFErv vw. _- Com letion Det ails 1 ~~3 - Top Depth (TVD) lop Inc! Nomi... GAS LIFT, 781 2 Top (RKB) (RKB) (°) it em Descripto n Comment ID (In) , 35.0 35.0 0.48 H ANGER CIW 31/2" Tubing Hanger 31/28rd 2.441 1,802.8 1,784.2 23.33 S AFETY VLV 2 7/8" CAMCO TRDP-tA-SSA SSSV, OD 5.125", ID 2.312" 2.312 7,946.0 6,362.1 39.04 S BR CAMCO'OEJ', OD 4.750", ID 2.312" (SBR) 2.312 s 3RF4Aa z 7,963.6 6,375.7 39.02 P ACKER CAMCO 7 x 2 7/8" HRP Hyd Set Packer, OD 5.937", ID 2.34T' 2.347 GAS LIFT, 151 8 5 521 6 8 39 08 S EAL ASSY Baker 5' Seal assembly w/ Loptor + 1.63 Spare out 2.406 s,t1] . , . , . GAS LIFT 8,154.2 6,523.9 39.09 P ACKER Baker T' DB 84-32 wA set Packer 3.250 s,s1i 8,157.8 6,526.7 39.09 S EAL ASSY Baker 80-32 Seal Bore Extension 5' 3.250 Gns uFr, ~ ~4 8,170.8 6,536.7 39.13 N IPPLE CAMCO 2 7/8" D-Nipple ID 2.250" 2.250 8,180.8 6,544.5 39.15 X O X0 2 7/8" to 31/2" 3.500 GAS uFr, 7 629 8,181.6 6,545.2 39.15 S OS CAMCO 3 1/2" Shear out Sub 2.441 GAS uFr, Other in Hole Wiretine retrievable lu s valves um s, fish etc. ~e9s rop Deptn (TVD) Top Inc! Top (RKB) (RKB) (°) Description Comment Run Data ID (In) SBR, 794fi 8,457 6,757.7 40.23 F ISH 1 1/2 DMY w/ RK Latch Empty Pocket; Fell to Rathde 1214/1986 PACKER. 7.964 -- Perforations 8 Slots INJECTION, snoe 8,001 Top (TVD) Btm ITVD) Oena Top (RKB) Btm (RKB) (ftNB) (RKB) Zone Date (sh--- Type Comment 8,058 8,078 6,449.1 6,464.7 C -1, UNIT B, 125/1986 12.0 IPERF 120 deg. ph; 5" Csg Gun IPERF, 3 K-13 B.DSea,D]e 8,118 8,128 6,495.8 6,503.6 G 1, UNIT B, 125/1986 12.0 IPERF 120 deg. ph; 5" Csg Gun 3 K-13 IPERF, 8,244 8,264 6,593.2 6,608.9 A -3, 3K-13 8/28/1992 4.0 RPERF 0 deg ph; 2 1/8"Silver Jet B,1 tea,lze 8,250 8,251 6,597.9 6,598.7 A -3, 3K-13 125/1986 1.0 IPERF 120 deg. phasing; 4" Csg Gun 8,253 8,254 6,600.3 6,601.1 A -3, 3K-13 125!1986 1.0 IPERF 120 deg ph; 4" Csg Gun INJECnoN, 8 256 8 257 6 602 7 4 A 6 603 -3 3K-13 125/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8.13] , , , . , . , SEAL ASSV, 8,258 8,260 6,604.2 6,605.8 A -3, 3K-13 3/31/1987 2.0 RPERF 60 deg ph; 2 1/8"Silver Jet B,1s1 PACKER 8.15/ 8,259 8,260 6,605.0 6,605.8 A -3, 3K-13 125/1986 1.0 IPERF 120 deg ph; 4" Csg Gun . SEAL ASSV, - 8 158 8,280 8,310 6,621.4 6,644.7 A -2, 3K-13 8/28/1992 4.0 RPERF 0 deg ph; 2 1/8" Silver Jet , 8,287 8,292 6,626.9 6,630.8 A -2, 3K-13 3/31/1987 2.0 APERF 60 deg ph; 2 1/8" SilverJet NIPPLE. 8,171 8,292 8,293 6,630.8 6,631.5 A -2, 3K-13 125/1986 1.0 IPERF 120 deg. phasing; 4" Csg Gun xo s 1et 8,299 8,300 6,636.2 6,637.0 A -2, 3K-13 1Z5J1986 1.0 IPERF 120 deg ph; 4" Csg Gun , . sos, B,1Bz 8,307 8,308 6,642.4 6,643.2 A -2, 3K-13 125/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8,311 8,312 6,645.5 6,646.3 A -2, 3K-13 125/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8,313 8,314 6,647.0 6,647.8 A -2, 3K-13 125/1986 1.0 IPERF 120 deg ph; 4" Csg Gun 8,320 8,321 6,652.5 6,653.2 A -2, 3K-13 125f1986 1.0 IPERF 120 deg ph; 4" Csg Gun IPERF, zsl e zso 8,323 8,324 6,654.8 6,655.5 A -2, 3K-13 125/1986 1.0 IPERF 120 deg ph: 4" Csg Gun . a IPERF, 8,327 8,328 6,657.9 6,658.6 A -2, 3K-13 125/1986 1.0 IPERF 120 deg ph; 4" Csg Gun a 2538,254 RPERF. Mots: tieneral ~ $af@ 8,244-8.261 End Data Annotation IPERF, 11!6/2009 NOTE: VIEW SCHEMATIC w/Alaska Schemtic9.0 a 2568,257 RPERF. 8,2588,260 IPERF, e,2ss-e,2w APERF, 8,28]-6,292 IPERF , 8,292-8,293 RPERF, 8.280-8.310 IPERF, 8.299-8,300 IPERF, 8,3078.308 ERF Mandrel Details IP 312 8 317-6 Top Deplh Top Port , , (TVD) Inc! OD Valve Latcn Slxe TRO Run IPERF, Stn Top (RKB) (RKB) (°) Make Model (in) Serv Type Type (in) (psi) Run Date Com... e,313-8,31a 1 2,781.3 2,552.0 47.00 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 10/28/1987 IPERF, 8 320-8 321 2 5,116.7 4,255.5 43.93 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 126/1986 , , IPERF. 3 6,516.7 5,272.8 42.95 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 10/2&1987 8.3238.324 4 7,233.8 5,816.6 40.43 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 126/1986 IPERF, 8 3278 328 5 7,629.0 6,117.8 40.11 Meda TMPD 1 GAS LIFT DMY BK 0.000 0.0 126/1986 , , 6 7,895.9 6,323.1 39.11 Meda TGPD 1 1/2 GAS LIFT DMY TG 0.000 0.0 10/29/1987 FISR, e.4s] 7 8,003.9 6,406.8 38.71 Meda TMPD 1 INJ DPHFCV BEK 0.000 0.0 3/2/2010 8 8,136.6 6,510.2 39.04 Meda TMPD 1 INJ DPHFCV BEK 0.000 0.0 3/22010 PRODUCTION, ]4-8,562 TD. B,SBB • MEMORANDUM To: Jim Regg // P.I. Supervisor ~ ~/~j b ~~ (~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-13 KIJPARUK RIV UNIT 3K-13 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~'~`- Comm Well Name: KUPARUK RIV UNIT 3K-13 Insp Num: mitCS090515161843 Rel Insp Num: API Well Number: 50-029-21630-00-00 Permit Number: 186-136-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P.T.D 3K-13 1861360 ~ Type Inj. W TTY i 6376~I,~ TypeTest SPT Test psi 1594 / QA 900 300 2220 / 300 2180 300 2180' 300 Interval aYRTST p~F P ~ Tubing 2700 270o z7oo z7oo Notes' Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ~Rflt' i, '. 5_ a. _4~..~ Wednesday, May 20, 2009 Page 1 of 1 ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth C k~- - ~~~~~ ~U~ ~ 2dQ~ • Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/30/08 iF-04 11964615 INJECTION PROFILE ~ +L- / ~ ~ _ 05/26/08 1 1 3F-10 11964609 PRODUCTION PROFILE I 8 05/23/08 1 1 1J-101 11970685 GLS = C C 05/23/08 1 1 iJ-166 11970681 GLS / ""' 05/20/08 1 1 2N-306 11964608 INJECTION PROFILE / ~s/U (-~- 05!22/08 1 1 3K-13 11970688 INJECTION PROFILE ~ 05/26/08 1 1 iB-08A 11970686 INJECTION PROFILE e i ~ ~~ / 05/24/08 1 1 1Y-11 11964613 INJECTION PROFILE f$ - /(e~~ 05/25/08 1 1 3K-19 11964616 INJECTION PROFILE U"' .~. f5 ~' 05/27/08 1 1 1 LJ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Conoc~illips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 :;¡ July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 1 ·)","'7 S'Cp.,~Ne.D AUG Q, ;. ;;ij b~ \òlP \~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ') ! -\- 7 h.. ii/OJ Perry Kl . ConocoPhillips Well Integrity Supervisor . . JUL3 1 2007 () Ci ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-S 186-123 66' 9.0 26" 7/7/2,007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K-11 186-164 43··.. 605 21" - 7/10/2007 ... 7.8 7/16/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 Jim Regg P.I. Supervisor ) ''Ke11 lot 14( 06 Alaska Oil and Gas Conservation Comm. ')n .;,t.al~ Uf AlaSKa H .....L:../H'..I. '-' .I.'-1""11.,.u U 1 T.I. TO: DATE: Wednesday, May 25,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-13 KUPARUK RlV UNIT 3K-13 \~-' 13ft, FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Cîß¡e.. Comm Well Name: KUPARUK RIV UNIT 3K-13 Insp Num: mitCS050521154118 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21630-00-00 Permit Number: 186-136-0 Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-13 Type Inj. I w TVD 6376 IA 550 2110 2050 2050 P.T. 1861360 TypeTest I SPT Test psi 1594 OA 400 600 600 600 Interval 4YRTST P/F P Tubing 2850 2850 2850 2850 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNED JUL 0 7 2005 Wednesday, May 25, 2005 Page 1 of 1 ) ) V ?ft; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test \lb Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhi/lips Alaska Inc. FIELD 1 UNIT 1 PAD: Kuparuk 1 KRU/3K DATE: 05121 105 SCAI\h\\E.D MAY 2 6 2.005 OPERATOR REP: Arend I Sauvageau - AES AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well\3K-02 I Type Inj I S I TV.D. 6421 I Tub~ng I 27501 27501 27501 2750 lnterval 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 I 550 I 550 I 550 well 3K-04 I Type Inj I S I Tv.D·1 6431 I Tub~ng I 30001 30001 30001 3000 Interval 4 P.T.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 I 350 I 350 I 350 well 3K-05 I Type Inj I S I TV.D. I 6341 I Tub~ng I 27501 27501 27501 27501 Interval \ 4 P.T.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 I 940 I 940 I 940 we1l13K-07 I Type Inj I S I T.V.D. 6565 I Tubing I 29501 29501 29501 2950 \ Interval I 4 P.T.D. 1861250 Type Test P T est psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 I 340 I 340 I 340 well 3K-12 I Type Inj I S I T.v.D. I 6644 I Tubing I 28501 28501 28501 285Ollnterval 0 P.T.D. 1861650 Type Test P Test psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 I 480 I 480 I 480 well 3K-13 I Type Inj I S I T.V.D. 6376 I Tub~ng I 28501 28501 28501 2850\lnterval 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 I 600 I 600 I 600 well 3K-15 I Type Inj I S I T.V.D. 6448 I Tubing I 28501 28501 28501 2850 Interval I 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 I 450 I 450 I 450 well 3K-18 I Type Inj I S I T.V.D.\ 6605 I Tubing I 22001 22001 22001 2200 I Interval I 4 P.T.D. 1861510 Type Test P Test psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 I 560 I 560 I 560 Well\3K-19 I Type Inj I S I TV.D. I 6331 I Tubing 1 27501 27501 27501 27501 Interval \ 4 P.T.D. 2011080 Type Test P Test psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 I 620 I 620 I 620 well 3Ko25 I Type Inj I N I T.V.D. 6552 I Tub~ng I 27~1 2751 275\ 275\lnterva, 4 P.T.D. 1980810 Type Test P Test psi 1638 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 I 600 We"\3K-26 I Type Inj I S I T.V.D.\ 6656 I Tubing I 27501 27501 27501 27501 Interva' \ 4 P.T.D. 1970770 Type Test P Test psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 720 I 780 I 780 I 780 well 3K-30 I Type Inj I S I T.V.D·I 6580 I Tubing I 28501 28501 2850[ 2850 I Interval I 4 P.T.D. 1971130 Type Test P Test psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 I 460 I 450 I 450 Well\3K-31 I Type Inj I S I T.V.D.\ 6117 1 Tub~ng I 285~1 28501 28501 2850 \ Interval I 4 P.T.D. 1980820 Type Test P Test psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 I 600 Well\3K-34 I Type Inj I S I T.v.D. I 6285 I Tub~ng I 28501 28501 28501 2850 \ Interval I 4 P.T.D. 1980770 Type Test P T est psi 1571 Casing 300 2140 2140 2140 P/F P Notes: OA: 400 I 650 I 650 I 650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey Test during Workover D = Differential Temperature Test o = Other (describe In notes) MIT Report Form MIT KRU 3K 05-21-05.xls 5/24/2005 Revised: 05/19/02 MICROFILMED 9/1 ~/00 DO NO-/- PLACE ANy NEW M/~.TERIAL NDER THIS PAGE STATE OF ALASKA ~,A OIL AND GAS CONSERVATION COMMI~ REPORT OF SUNDRY WELL OPERATIONS,, .. 1. Operations Performed: Pull tubing 2. Name of Operator Operation Shutdown __ Stimulate Plugging Perfoi',~te X Other Alter casing Repair well 5. Type of Well: Development "~. Exploratory I Stratigraphic _ Service ARQQ Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1084' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1196' FNL, 1535' FWL, Sec. 2, T12N, R9E, UM At effective depth 1404' FNL, 1288' FWL, Sec. 2, T12N, R9E, UM At total depth 1447' FNL, 1237' FWL, Sec. 2, T12N, R9E, UM 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) 69' RKB, PAD 35' 7, Unit or Property name Kuparuk River Unit feet 8. Well number 3K-13 ~ 9, Permit number/approval number #86-136 10. APl number 50-Q29-21630 11, Field/Pool Kuparuk River Oil Pool measured 8 5 8 0' fe et true vertical 6850' feet Plugs (measured) None Effective depth: measured 8 4 76' feet true vertical 6771' feet Junk (measured) None Casing Length Size Structural 8 0' 1 6" Conductor Surface 4 41 5' 9 - 5 / 8" Production 85 2 7' Liner Perforation depth: measured # Cemented Measured depth True vertical depth 1540 POLESET 1 1 5' 1 1 5' 1230 SX AS III & 4452' 3760' 300 SX Class G 325 Sx Class G & 8562' 6839' 175 Sx AS I 8058-8078', 8118-8128', 8250', 8253', 8256', 8258-8260',8287-8292', 8299', 8307', 8311', 8313', 8320', 8323', 8327', 8372-8382' true vertical 6448-6463', 6496-6502', 6597', 6599', 6602', 6603-6605', c0625-6630', 6635', 6641', 6644', 6646', 6651', 6654', 6657', 6691-6699' Tubing (size, grade, and measured depth) 2 7/8", J-55, tbg w/tail @ 8185' Packers and SSSV (type and measured depth) ~-~, ~. .~.t? ~ ?'~[ HRP pEr @ 7967', DB pEr @ 8157' & TRDP-1A-SSA SSSV @ 1806' ~. ~! ,~,_. 13. Stimulation or cement squeeze summary Re-perforation of A2 & A3 Sands @ 4 SPF Intervals treated (measured) 14. 8244' - 8264'; and 8280' - 8310' (md) Treatment description including volumes used and final pressure Ai~ska, rJii & ~3 ,~0ns. C0~l~.~_ss~'~[~ Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -0- 0- 800 1300 2800 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X - 0 - - 0 - 1000 1300 16. Status of well classification as: Water Injector ~ Oil ~ Gas Suspended Service 28OO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C ' /'(,/., ~ Title Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Comnanv WELL I PBDT SSSV TYPE/STATUS .kb'C/CC# & T~ I LOG ~Y KUPARUK RIVER UNIT WELL SERVICE REPORT t CONTRACTOR/KEY PERSON IDAYS IOATE FILIdD~TE DESCRIPTION OF WORK isc,~ IFmLO cost EST. t ACCb~iUt, atVCE COSt PAGE 1 OF _ La:.. ~[sos-'c~ ~/,7lsc (3 F'] CHECK TFIIS BLOCK IF SUM3tARY CONTINUI~ ON BACK j ~ COMPLETE /~ INCOMPLETE ReportWeamer j Temp.OF t Chai Fa:mr jvisibiuty°F miles J Wind Vel. /Signed , ~-,o. L_~ oc %d~ ~, ~ '-~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C~JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [~' GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-136 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21630 4. Location of well at surface 9. Unit or Lease Name 1084' FSL, 316' FWL, Sec.35, T13N, RDE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1196' FNL, 1535' FWL, Sec. 2, T12N, RDE, UM 3K-13 At Total Depth 11. Field and Pool 1447' FNL, 1237' FWL, Sec. 2, T12N, RDE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oil Pool RKB 69' ADL 25629, ALK 2562 . 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/22/86 07/27/86 01/28/87' N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back DePth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8580'MD 6850'TVD 8476'MD 6771 'TVD YES ~ NO []I 1803' feet MD 1700' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL/Cal, FDC/CNL, GR, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 115' 24" 1540# Poleset ,_ 9-5/8" 36.0# J-55 ·Surf 4452' 12-1/4" 1230 sx AS Ill & 300 sx Class G 7" 26.0# J-55 Surf 8562' 8-1/2" 325 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See attached. 2-7/8" 8182' 7964' & 8154' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached adden, lum; dated 05/16/87, for fracture dat.. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATERIBBL CHOKE SIZE GAS-OIL RATIO TEST P~ERIOD II~ Flow Tubing Casing Pressure CALCULATED.i~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None .: , · ; · *Note: Drilled RR 07/29/86. Well perforated & tubing ran 12/06/86. :" Form 10-407 WC2: 051: DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. i 30. GEOLOGIC MARKERS ~ FORMATION TES,TS NAME include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7967' 6377' N/A Base Kuparuk C 8074' 6460' Top Kuparuk A 8222' 6575' Base Kuparuk A 8385' 6701' 31. LIST OF ATTACHMENTS Addendum (dated 05/16/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~, )/~ ~ ' , Associate Engineer Signed ;.( ~')~,~,' ~ j- Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection,-observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ..... STATE OF ALASKA ' ~ ALASKA ~JtL AND GAS CONSERVATION C~,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-1 36 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21630 4. Location of well at surface 9. Unit or Lease Name 1084' FSL, 316' FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1196' FNL, 1535' FWL, Sec. 2, T12N, R9E, UM 3K-13 At Total Depth 11. Field and Pool 1447' FNL, 1237' FWL, Sec. 2, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 69' ADL 25629, ALK 2562 't 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' N°' of Completions 07/22/86 07/27/86 01/28/87'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8580'MD 6850'TVD 8476'MD 6771 'TVD YES ~ NO []I 1803' feetMD 1700' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL/Cal, FDC/CNL, GR, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 1540# Pol eset 9-5/8" 36.0# J-55 Surf 4452' 12-1/4" 1230 sx AS Ill & 300 sx Class G 7" 26.0# J-55 Surf 8562' 8-1/2" 325 sx Class G & 175 sxI AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 8182' 7964' & 8154' See attached. 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 02/17/87, for Fracture data. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATERIBBL CHOKE SIZE I GAS-OI L RATIO TEST PERIOD I~ I FIowTubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . .- *Note: Drilled RR 07/29/86. Well perforated & tubing ran 12/06/86. "3~-;"::" {:'i ~'!; ('::% ""!":::' "~'"':'"'~::" :~ : / Submit in duplica~ Form 10-407 Rev. 7-1-80 WC2:051 :DAN I CONTINUED ON REVERSE SIDE 29. ' .- I' 30!~ / ~ \ GEOLOGIC MARK[E-F~S ' -] ~" FORMATION TESTS NAME I nclu de interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7967' 6377' N/A Base Kuparuk C 8074' 6460' Top Kuparuk A 8222' 6575' Base Kuparuk A 8385' 6701' 31. LIST OF ATTACHMENTS Addendum (dated 02/17/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer ~'~'~ 7 Signed. [//~/~ ,// )(/~J/L~ ~,' Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL COMPLETION OR RECOMPLETION REPORT & LOG 3K-13 (Cont.) Item 24. Peroration Depths: TVD 8058' - 8078'* 8118' - 8128'* 8250' 8253' 8256' 8259' 8292' 8299' 8307' 8311' 8313' 8320' 8323' 8327' 8372' - 8382' 6448' -6463' 64~ - 6502I 6597 6~9 6~2 662 6~1 6644 6646 ~51 6654 6657 6691 - 6699' Perforated w/1 spf, 0° phasing * Perforated w/12 spf, spiral phasing WC2/O51a 03/02/87 ADDENDUM WELL: 1/28/87 2/07/87 3K-13 Frac Kuparuk "A" sand perfs 8250' 8253' 8256' 8259' 8292' 8299' 8307' 8311' 8313' 8320' 8323' 8327' & 8372'-8382' per procedure dated 1/13/87 as follows: Stage 1: 100 bbls gelled diesel @ 20 BPM, 6237-6200 psi Stage 2: 20 bbls gelled diesel pad @ 20 BPM, 6194-6139 psi Stage 3: 25 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 6139-6120 psi Stage 4: 250 bbls gelled diesel Pad @ 20 BPM, 6120-5900 psi Stage 5: 35 bbls gelled diesel w/2 ppg 20/40 mesh @ 20 BPM, 5945-5913 psi Stage 6: 38 bbls gelled diesel w/4 ppg 20/40 mesh @ 20 BPM, 5913-6200 psi Stage 7: 6 bbls gelled diesel w/6 ppg 20/40 mesh @ 20 BPM, 6200-7500 psi Well screened out 6 bbls into Stage 7. Att to repressure & break down w/o success. Fluid to recover: 463 bbls gelled diesel Sand in Csg & Tbg: 7023 lbs Avg Pressure: 6100 psi Sand In Zone: 2231# 20/40 mesh & 1000# 100 mesh CO well, ~ f/8195'-8476', CBU, POOH, displ'g well w/cln diesel. Turn well over to Production. ' D'r~-lling Supervisor / D~te $ UB-$ URFA CE DIRECTIONAl. SURVEY ~] UIDANCE [~ ONTINUOUS r-fl OOL / Company Well Name ARCO ALASKA, INC. 3K-13 (1084' FSL~ · 316' FWL; SEC 35~T13N,RgE,UM) Field/Location KUPARUK? NORTH SLOPE~ ALASKA Job Reference No. 7169O WEST Date · 18-AUG-86 Computed By: HALSTEAD GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA9 INC. 3K-13 KUPARUK NORTH SLOPE~ALASKA SURVEY DATE: 18-AUG-86 ENGINEER: WEST METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL'- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ, DISTo PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 57 DEG 19 MIN WEST COMPUTATION DATE: 6-SEP-86 PAGE 1 ARCO ALASKA~ INC. 3K-13 KUPARUK NORTH SLOPE~ALASKA DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 100.00 100.00 31.00 0 30 S 5 29 E 200°00 199.99 130.99 0 32 S 5 4 W 300.00 299.99 230.99 0 30 S 3 18 W 400.00 399.99 330.99 0 30 S 4 51 E 500.00 499.98 430.98 0 26 S 5 23 E 600.00 599.98 530.98 0 23 S 15 9 W 700.00 699.98 630.98 0 25 S 8 30 W 800.00 799.97 730.97 0 26 S 12 31 W 900.00 899.97 830.97 0 24 S 7 59 W 1000.00 999.97 930.97 0 18 1100.00 1099.97 1030.97 0 18 1200.00 1199.96 1130.96 0 49 1300.00 1299.85 1230.85 4 39 1400.00 1399.12 1330.12 8 56 1500.00 1497.16 1428.16 13 29 1600.00 1593.78 1524.78 16 4 1700.00 1689.14 1620.14 19 16 1800.00 1782.40 1713.40 22 48 1900.00 1873.36 1804.36 26 9 2000.00 1961.98 1892.98 29 3 2100.00 2047.82 1978.82 32 41 2200.00 2130.45 2061.45 35 37 2300.00 2210.35 2141.35 38 36 2400.00 2286.33 2217.33 42 11 2500.00 2358.77 2289.77 44 46 2600'00 2428.40 2359.40 46 52 2700.00 2496.09 2427.09 47 31 2800.00 2563.86 2494.86 46 53 2900.00 2632.85 2563.85 45 57 3000.00 2702.76 2633.76 45 33 3100.00 2772.97 2703.97 45 7 ~200.00 2844.11 2775.11 44 0 3300.00 2916.74 2847.74 43 12 3400.00 2988.94 2919.94 44 19 3500.00 3060.51 2991.51 44 17 3-600.00 3132.20 3063.20 43 51 3700.00 3204.94 3135.94 42 45 3800.00 3278.80 3209.80 42 8 3900.00 3352.72 3283.72 42 53 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.13 0.53 0.39 S 0.09 E 0.63 0.07 1.34 S 0.12 E 1.18 0.09 2.24 S 0.03 E 1.65 0.23 3.15 S 0.05 E 2.00 0.13 3.92 S 0.14 E 2.43 0.05 4.65 $ 0.09 E 2.95 0.07 5.37 S 0.06 W 3.45 0.01 6.11 S 0.18 W 3.99 0.16 6.85 S 0.34 W 0.00 N 0 0 E 0.40 S 12 58 E 1.35 S 4 56 E 2.24 S 0 45 E 3.15 S 0 59 E 3.93 S 2 1 E 4.65 S 1 10 E 5.37 S 0 40 W 6.11 S 1 40 W 6.86 S 2 51 ~ S 28 33 W S 15 36 W S 50 25 W S 71 45 W S 77 1W S 76 24 W S 74 26 W S 73 57 W S 74 0 W 4.43 0.17 7.47 S 0.47 W 4.85 0.20 7.93 S 0.67 W 5.56 1.45 8.56 S 1.11 W 9.77 4.38 10.18 S 5.08 W 21.10 4.47 13.35 S 16.50 W 39.39 4.61 17.46 S 35.59 W 63.96 1.60 24.18 S 60.48 W 92.69 3.99 32.23 S 89.45 N 127.37 3.78 3,85 S 72 24 W 167.08 7.48 S 3 37 W 7.96 S 4 51 W 8.64 S 7 23 W 11.38 S 26 32 W 21.23 S 51 2 W 39.65 S 63 52 W 65.13 S 68 12 W 95.08 S 70 11 W 42.69 S 123.94 W 131.09 S 70 59 W 53,99 S 163,87 W 172.54 S 71 45 W S 67 30 W S 63 59 W S 60 31 W S 61 20 W S 61 19 W S 59 1W S 56 39 W S 56 37 W S 57 16 W S 58 40 W 212.25 3.89 262.98 3.73 319.06 3.13 379.07 3.83 443.87 3.21 512.67 4.23 584.43 1.75 658.03 0.17 731.55 1.61 803.94 1.24 69.96 S 207.29 W 218.78 S 71 20 W 91.23 S 253.92 W 269.81 S 70 14 W 117.50 S 303.70 W 325.64 S 68 50 W 147.01 S 356.06 W 385.22 S 67 33 W 177.94 S 413.10 W 449.89 S 66 42 W 211.72 S 473.28 W .518.48 S 65 53 W 250.63 S 533.57 W 589.50 S 64 50 W 291.10 S 595.05 W 662.44 S 63 55 W 331.36 S 656.58 W 735.46 S 63 13 W 369.71 S 717.98 W 807.58 S' b2 45 W' S 59 23 W 875.40 S 59 56 W 946.55 S 60 26 W 1016.74 S 60 0 W 1085.36 S 56 26 W 1154.52 S 55 54 W 1224.34 S 56 31 W 1294.04 S 57 55 W 1362.66 S 58 49 W 1430.06 S 58 32 W 1497.38 0.13 0.97 1.49 1.85 1.92 0.43 1.07 1,50 0.40 1.44 406.39 S 779.36 W 878.95 S 62 27 W 442.41 S 840.77 W 950.07 S 62 14 W 477.27 S 901.80 W 1020.31 S 62 6 W 511.14 S 961.61 W 1089.01 S 62 0 W 547.60 S 1020.38 W 1158.03 S 61 46 W 586-76 S 1078.21 W 1227.53 S 61 26 W 625.61 S 1136.10 W 1296.96 S 61 9 W 662.83 S 1193.74 W 1365.42 S 60 57 W 698.05 S 1251.22 W 1432.77 5 60 50 W 732.91 S 1308.84 W 1500.08 $ 60 45 W COMPUTATION DATE: 6-SEP-86 2 ARCO ALASKA! INC. 3K-13 KUPARUK NORTH SLOPE,ALASKA PAGE DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: WEST 69. O0 Fl' INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000.00 3425,62 3356.62 43 2 4100.00 3499.13 3430.13 42 23 4200.00 3572.78 3503.78 42 56 4300.00 3646.08 3577.08 42 30 '400.00 3720.35 3651.35 41 30 ,500.00 3795.82 3726.82 40 46 4600.00 3871.57 3802.57 40 37 4700.00 3947.51 3878.51 40 35 4800.00 4023,37 3954,37 40 48 4900.00 4098.25 4029.25 42 42 5000.00 4170.56 4101.56 44 1 5100.00 4242.50 4173.50 43 59 5200.00 4314.72 4245.72 43 42 5300,00 4386.88 4317.88 43 57 5400.00 4458.83 4389.83 44 0 5500.00 4530.61 4461.61 44 11 5600.00 4602.21 4533.21 44 19 5700.00 4574,00 4605.00 43 17 5800.00 4747.62 4678.62 42 26 5900.00 4821.33. 4752.33 42 37 6000.00 4894.79 4825.79 42 47 6100.00 4968,15 4899.15 42 50 6200-00 5041.36 4972.36 43 5 6300,00 5114.25 5045.25 43 18 %400.00 5186,91 5117,91 43 27 ~500o00 5259.47 5190.47 43 25 6600.00 5333.50 5264.50 40 37 6700.00 5409.69 5340.69 40 25 6800.00 5485.75 5416.75 40 25 6900.00 5561.83 5492.83 40 33 7000.00 5637.74 5568.74 40 40 7100,00 5713,56 5644,56 40 42 7200.00 5789.50 5720.50 40 25 7300.00 5865.65 5796.65 40 28 7400.00 5941.60 5872.60 40 32 7500.00 6017.80 5948.80 40 14 7600.00 6094.18 6025.18 40 8 7700.00 6170.76 6101.76 39 54 7800.00 6247.61 6178.61 39 36 7900.00 6324.94 6255.94 39 6 DEG MIN FEET DEG/iO0 S 58 38 W 1565.82 S 60 9 W 1633.56 S 58 59 W 1701.12 S 58 14 W 1769.14 S 60 23 W 1836.04 S 61 2 W 1901.53 S 60 37 W 1966.68 S 60 16 W 2031.63 S 59 42 W 2096.73 S 58 21 W 2162.95 S 56 46 W 2232.02 S 55 57 W 2301.47 S 55 26 W 2370.61 S 55 18 W 2439.80 S 55 4 W 2509.20 S 54 55 W 2578.77 S 54 ~2 W 2648.51 S 54 35 W 2718.04 S 54 40 W 2785.64 S 54 26 W 2853.15 S 54 7 ~ 2920.90 S 53 42 W 2988.74 S 53 26 W 3056..71 S 53 20 W 3125.02 S 53 14 W 3193.55 S 53 8 W 3262.18 S 53 20 W 3329.22 S 53 21 W 3393.82 S 53 14 W 3458.59 S 53 19 W 3523.32 S 53 19 W 3588.27 S 53 24 W 3653.32 S 53 17 W 3718.22 S 53 21 W 3782.88 S 53 10 W 3847.77 S 52 58 W 3912.36 S 52 23 W 3976.70 S 51 37 W 4040.72 S 50 57 W 4104.36 S 50 38 W 4167.35 1.19 1.17 2.49 1.57 1.50 0.59 0.66 0.28 0.69 3.22 0.85 0.46 0.34 0.34 0.32 0.17 0.28 2.44 0.17 0.31 0.29 0.31 0.35 0.19 0.14 O.TO 1.71 0.22 0.47 0.18 0.18 0.32 0.18 0.33 0.24 0.38 0.61 0.50 0.58 0.56 FEET FEET FEET .. DEG MIN 768.82 S 1367.12 W 1568.47 S 60 38 W 803.38 S 1425.44 W 1636.24 S 60 35 W 837.06 S 1484.10 W 1703.88 S 60 34 W 873.07 S 1541.81 W 1771.84 S 60 28 W 907,23 S 1599.38 W 1838.77 S 60 26 W 939.08 S 1656.75 W 1904.39 S 60 27 W 970.87 S 1713.76 W 1969.66 S 60 28 W 1002.96 S 1770.35 W 2034.71 S 60 28 W 1035.53 $ 1826.79 W 2099.87 S 60 27 W 106'9.47 S 1883.70 W 2166.12 S 60 24 W 1106.64 S 1941.91 W 2235.10 S 60 19 W 1145.18 S 1999.69 W 2304.39 S 60 12 W 1184.20 S 2056.81 W 2373.35 S 60 4 W 1223.57 S 2113.76 W 2442.36 S 59 56 W 1263.19 S 2170.80 W 2511.58 S 59 48 W 1303.13 S 2227.83 W 2580.96 S 59 40 W 1343.35 S 2284.88 W 2650.52. $ 59 32 W 1383.64 S 2341,64 W 2719.88 S 59 25 W 1422.80 S 2396.83 W 2787.32 S 59 18 W 1461.99 S 2451.90 W 2854'69 S 59 11 W 1501.59 S 2506.99 W 2922.29 S 59 4 W 1541.62 S 2561.91 W 2989.98 S 58 57 W 1582,10 S 2616.70 W 3057.80 S 58 50 W 1622,93 S 2671.66 W 3125.96 S 58 43 W 1663.98 S 2726.73 W 3194.36 S 58 36 W 1705.22 S 2761.82 W 3262.87 S 58 29 W 1745.45 S 2835.66 W 3329.80 S 58 23 W 1784.08 S 2887.63 W 3394.31 S 58 17 W 1822.88 S 2939.69 W 3459.00 S 58 11 W 1861.69 S 2991.71 W 3523.66 S 58 6 W 1900.56 S 3043.93 W 3588.54 S 58 I W 1939.47 S 3096.15 W 3653.53 S 57 56 W 1978.33 S 3148.43 W 3718.38 S 57 51 W 2017.00 S 3200.44 W 3783~o01 S 57 46 W 2055.88 S 3252.59 W 3847.86 S 57 42 W 2094.74 S 3304.40 W 3912.42 S 57 37 W 2133.84 S 3355.76 W 3976.73 S 57 32 ~ 2173.43 S 34,06.43 W 4040.74 S 57 27 W 2213.43 S 3456.37 W 4104.36 S 57 21 W 2253.55 S 3505.48 W 4167,36 S 57 15 W COMPUTATION DATE: 6-SEP-86 PAGE 3 ARCO ALASKA, INC. 3K-13 KUPARUK NORTH SLOPE,ALASKA DATE DF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATIDN: ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 69.00 FT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SDUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 6402.69 6333.69 38 58 8100.00 6480.45 6411.45 38 57 8200.00 6558.1! 6489.11 39 12 8300.00 6635.54 6566.54 39 7 ~400.00 6712.81 6643.81 39 58 JSO0.O0 6789.16 6720.16 40 14 8580.00 6850.22 6781.22 40 14 S 50 30 W 4229.80 S 50 7 W 4292.21 S 49 55 W 4354.69 S 49 37 W 4417.44 S 49 33 W 4480.35 S 49 34 W 4544.35 S 49 34 W 4595.56 0.23 0.39 0.51 1.03 2.97 0.00 0.00 2293.49 S 3554.04 W 4229.82 S 57 9 W 2333.62 S 3602.45 W 4292.25 S 57 3 W 2374.12 S 3650.70 W 4354.77 S 56 57 W 2414.93 S 3699.07 W 4417.58 S 56 51 W 2456.03 S 3747.45 W 4480.56 S 56 45 W 2497.91 S 3796.61 W 4544.65 S 56 39 W 2531.43 S 3835.95 W 4595.94 S 56 34 W COMPUTATION DATE: 6-SEP-86 PAGE ARCO ALASKA, INC. DATE OF SURVEY: 18-AUG-86 3K-13 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WEST 69.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTDRE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 0.00 0.00 -69.00 0 0 1000.00 999.9? 930.97 0 18 2000.00 1961,98 1892.98 29 3 3000,00 2702.76 2633.76 45 33 ~000.00 3425.62 3356.62 43 2 5000.00 4170.56 4101.56 44 6000.00 4894.79 4825.79 42 47 7000.00 5637.74 5568.74 40 8000.00 6402.69 6333.69 38 58 8580.00 6850.22 6781.22 40 14 N 0 0 E 0.00 S 28 33 W 4.43 S 67 30 W 212.25 S 59 23 W 875.40 S 58 38 W 1565.82 S 56 46 W 2232.02 S 54 7 W 2920.90 S 53 19 W 3588.27 $ 50 30 N 4229.80 S 49 34 W 4595.56 0.00 0.17 3.89 0.13 1.19 0.85 0.29 0.18 0.23 0.00 0.00 N 0.00 E 0.00 N 0 0 E 7.47 S 0.47 W 7.48 S 3 37 W 69.96 S 207.29 W 218.78 S 71 20 W 406.39 S 779.36 W 878.95 S 52 27 W 768.82 S 1367.12 W 1568.47 S 60 38 W 1106.64 S 1941.91 W 2235.10 S 60 19 W 1501.59 S 2506.99 W 2922.29 S 59 4 W 1900.56 S 3043.93 ~ 3588.54 S 58 1 W 2293.49 S 3554.04 W 4229.82 S 57 9 W 2531.43 S 3835.95 W 4595.94 S 56 34 W COMPUTATION DATE: 6-SEP-86 PAGE 5 ARCO ALASKA, INC. 3K-13 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: WEST INTERPgLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 69.00 FT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 69.00 69,00 0.00 0 20 S 10 23 E 169.00 169.00 100.00 0 31 S 1 21 ~ 269.01 269.00 200.00 0 29 S 5 0 W 369.01 369.00 300.00 0 32 S 3 21 E 469.02 469.00 400.00 0 26 S 6 19 E 569.02 569.00 500.00 0 24 S 4 59 W 669.02 669.00 600.00 0 25 S 10 53 W 769.02 769.00 700.00 0 26 S 9 45 W 869,03 869,00 800.00 0 25 S 12 58 W 969.03 969.00 900.00 0 21 1069.03 1069.00 1000.00 0 16 1169,03 1169,00 1100,00 0 29 1269,08 1269,00 1200,00 3 15 1369.56 1369,00 1300.00 7 36 1471,[1 1469,00 1400,00 12 13 1574,24 1569,00 1500,00 15 32 1678,72 1669.00 1600o00 18 29 1785,.49 1769,00 1700,00 22 21 1895,15 1869,00 1800,00 26 0 2008,05 1969,00 1900.00 29 20 2125,32 2069,00 2000,00 33 31 2247.81 2169.00 2100.00 36 54 2376.67 2269.00 2200°00 41 26 2514'50 2369.00 2300.00 45 4 2659.86 2469.00 2400.00 47 29 2807.54 2569.00 2500.00 46 47 2951,79 2669.00 2600.00 45 36 3094,36 2769.00 2700,00 45 9 3234,47 2869.00 2800.00 43 33 3372,13 2969,00 2900,00 44 6 3511,88 3069.00 3000,00 44 18 3650,86 3169,00 3100.00 43 20 3786.77 3269.00 3200,00 42 11 3922,28 3369,00 3300,00 43 8 4059,12 3469,00 3400,00 42 36 4'194,83 3569.00 3500,00 42 54 4331.,03 3669,00 3600,00 42 12 4464,60 3769,00 3700°00 40 53 4596,62 3869,00 3800,00 40 37 S 11 55 W S 20 48 w S 39 38 W S 69 42 W S 75 16 W S 77 57 W S 74 31W S 74 15 W S 73 6 W S 72 39 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.03 0.68 0.16 S 0.06 E 0.46 0.15 1.05 S 0.13 E 1.02 0.09 1.97 S 0.05 E 1.52 0.05 2.86 S 0.03 E 1.90 0.05 3.69 S 0.11 E 2.28 0.30 4.44 S 0.14 E 2.80 0.14 5.14 S 0.03 W 3,29 0.08 5,88 S 0,13 W 3.83 0,06 6,62 S 0.30 W 4.28 0.24 7.30 S 0.41 W 4.73 0.05 7.78 S 0.63 W 5.22 0.97 8.33 S 0.86 W 7'70 4.96 9.48 S 3.07 W 16,95 4.02 12.30 S 12.25 W 33.34 4.59 16.04 S 29.33 W 57,23 3,00 22,29 S 53,70 W 86,11 ,3.67 30.35 S 82,84 W 122.01 3.90 165,02 3,96 S 67 10 W 216,13 S 63 10 W 276,78 S 60 32 W 347,29 S 61 33 W 428.30 S 58 22 W 522.94 S 56 38 W 628,41 S 57 22 W 737,07 S 59 10 W 841,00 $ 59 53 w 942.55 S 60 28 W 1040.54 S 57 17 W 1135.05 S 55 56 W 1232.65 S 57 7 W 1329,14 S 58 45 W 1421.17 S 58 23 W 1512.58 S 59 30 W 1605.97 S 59 lO W 1697.59 S 58 53 W 1790.05 S 61 4 W 1878,47 S 60 38 W 1964,48 O. O0 N 0 0 E 0.17 S 21 25 E 1.06 S 7 14 E 1.97 S 1 25 E 2.86 S 0 41 E 3,69 S 1 44 E 4,44 S 1 45 E 5.14 S 0 16 W 5.88 S 1 17 W 6,63 S 2 36 W 7.31 S 3 12 W 7,80 S 4 35 W 8.37 S 5 55 ~ 9.96 S 17 55 W 17.36 S 44 51 W 33.42 S 61 19 W 58.14 S 67 27 W 88.23 S 69 52 W 41.10 S 118.59 W 125.51 S 70 53 W 53.35 S 161.84 W 170.41 S 71 45 W 4,04 3.77 3,06 3,39 3,86 0 · 37 1.71 0,60 0.90 1.14 71.50 S 210.92 W 222.71 S' 71 16 N 97.40 S 266.36 W 283.60 S 69 54 W 131.56 S 328.22 W 353.60 S 68 9 W 170.47 S 399.50 W 434.35 S 66 53 W 217.17 S 481,99 W 528.66 S 65 44 W 274.80 S 570.32 W 633.07 S 64 16 W 334.36 $ 661'.21 W 740.94 S 63 10 W 388.82 S 749.75 W 844.58 S 62 35 W 440.41 S 837.31 W 946.07 S 62 15 W 489.03 S 922.54 W 1044.14 S 62 4 W 3,10 0,48 1,65 0.50 0,97 1,24 2,55 1.88 0,90 0,71 536',91 S 1004.11W 1138,64 S 61 51 W 591.42 S 1085.09 W 1235,80 S 61 24 W 644,86 S 1165,45 W 1331,96 S 61 2 W 693,44 S 1243.63 W 1423.89 S 60 51 W 740.86 S 1321,81 W 1515.27 S 60 43 W 789.50 S 1401.56 W 1608.62 S 60 36 W 835.24 S 1481.07 W 1700.35 S 60 34 W 884.00 S 1559.64 W 1792.75 S 60 27 W 927.92 S 1636.52 W 1881-28 S 60 26 W 969.79 S 1711.85 W 1967.46 S 60 28 W COMPUTATION DATE: 6-SEP-86 PAGE 6 ARCO ALASKA, INC. 3K-13 KUPARUK NORTH SLOPEsALASKA DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 4728.29 3969.00 3900.00 40 37 4860.54 4069.00 4000.00 41 40 4997.83 4169.00 4100.00 44 1 5136.80 4269.00 4200.00 43 48 5275.17 4369.00 4300.00 43 53 5414.15 4469.00 4400.00 44 2 5553.59 4569.00 4500.00 44 17 5693.1Z 4669.00 4600.00 43 27 5828.96 4769.00 4700.00 42 28 5964.85 4869,00 4800.00 42 44 69. O0 FT 7436.03 5969.00 5900.00 40 24 7567.05 6069.00 6000.00 40 11 7697.70 6169.00 6100.00 39 54 7827.74 6269.00 6200.00 39 28 7956.67 6369.00 6300.00 38 55 8085.28 6469.00 6400.00 38 56 8214.05 6569.00 6500.00 39 16 8343.23 6669.00 6600.00 39 24 8473.59 6769.00 6700.00 40 14 8580.00 6850.22 6781.22 40 14 S 53 9 W 3871.10 S 52 37 W 3955.51 S 51 38 W 4039.26 S 50 49 W 4121.91 S 50 33 W 4202.75 S 50 11 W 4283.03 S 49 54 W 4363.50 S 49 41 W 4444.57 S 49 34 W 4527.44 S 49 34 W 4595.56 6101.16 4969.00 4900.00 42 50 S 53 42 W 2989.53 6237.89 5069.00 5000.00 43 11 S 53 24 W 3082.57 6375.33 5169.00 5100.00 43 25 S 53 15 W 3176.63 6513.11 5269.00 5200.00 43 13' S 53 10 W 3271.16 6646.57 5369.00 5300.00 40 20 S 53 22 W 3359.29 6778.02 5469.00 5400.00 40 28 $ 53 15 W 3444.39 6909~44 5569.00 5500.00 40 34 S 53 19 W 3529.45 7041.23 5669.00 5600.00 40 41 S 53 21 W 3615.09 7173.07 5769.00 5700,00 40 29 S 53 16 W 3700.80 7304.40 5869.00 5800.00 40 29 S 53 21 W 3785.74 S 60 7 W 2050.02 S 59 6 W 2136.48 S 56 48 W 2230.52 S 55 43 W 2327.00 S 55 19 W 2422.58 S 55 3 W 2519.04 S 54 49 W 2616.12 S 54 35 ~ 2713.33 S 54 36 W 2805.16 S 54 14 W 2897.05 FEET DEG/IO0 0.41 2.58 0.85 0.88 0.46 0.26 0.35 2.49 0.33 0.34 0.32 0.21 0.17 1.34 0.24 0.76 0.13 0.25 0.49 0.33 0.51 0.33 0.50 0.65 0.19 0.36 0.40 0.47 0.00 0.00 FEET FEET FEET DEG MIN 1012.11 S 1786.33 W 2'053.13 S 60 27 W 1055.75 S 1861.05 W 2139.65 S 60 26 W 1105.81 S 1940.66 W 2233.60 S 60 19 W 1159.52 S 2020.83 W 2329.86 S 60 9 W 1213.76 S 2099.59 W 2425.18 S 59 58 W 1268.83 S 2178.86 W 2521.38 S 59 47 W 1324.64 S 2258.40 W 2618.21 S 59 36 W 1380.91 S 2337.80 W 2715.18 S 59 25 ~ 1434.10 S 2412.77 W 2806.80 S 59 16 W 1487.61 S 2487.62 W 2898.49 S 59 7 W 1542.09 S 2562.55 W 2990.77 S 58 57 W 1597.54 S 2637.51 W 3083.60 S 58 47 N 1653.84 S 2713.14 W 3177.47 S 58 38 W 1710.62 S 2789.02 W 3271.83 S 58 28 W 1763.43 S 2859.85 W 3359.83 S 58 20 W 1814,36 $ 2928.29 W 3444.82 S 58 13 W 1865.36 S 2996.63 W 3529.78 S 58 5 W 1916.61 S 3065.49 W 3615.33 S 57 59 W 1967.88 S 3134.44 W 3700.98 S 57 52 W 2018.71 $ 3202,74 W 3785.86 S 57 46 N 2069.91 S 3271.32 W 3871.18 S 57 40 W 2120.91 S 3338.88 W 3955.55 S 57 34 W 2172.51 S 3405.27 W 4039.27 S 57 27 W 2224.58 S 3470.07 W 4121.91 S 57 20 W 2276.18 S 3533.02 W 4202.76 S 57 12 W 2327.68 S 3595.35 W 4283.07 S 57 4 W 2379.84 S 3657.50 W 4363.59 S 56 56 W 2432.65 S 3719.93 W 4444.74 S 56 49 W 2486.85 S 3783.6l W 4527.72 S 56 41 W 2531,43 S 3835.95 W 4595.94 S 56 34 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH ARCO ALASKA, INC. 3K-13 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: 6-SEP-86 PAGE DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: WEST 69.00 FT INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION AT ORIGIN= 1084' FSLs 316' FWL, SECCO~RDIN35 T13~EsRgEi t MEASURED DEPTH TVD RECTANGULAR BELOW KB FRaM KB SUB-SEA NORTH/SOUTH EAST/WEST 7967.00 6377.03 6308.03 2280.30 S 3538.02 W $07~.00 6~60.23 6391.23 2323.15 S 3589.90 W 8222.00 6575.15 6506.15 2383.08 S 3661.35 W 8385.00 6701.28 6632.28 2449.81 S 3740.15 W 8476.00 6770.8~ 6701.84 2487.86 S 3784.81 'N 8580.00 6850.22 6781.22 2531.43 S 3835.95 W ARCO ALASKA, INC. 3K-13 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 6-SEP-86 ~,~**~***~ STRATIGRAPHIC PAGE DATE OF SURVEY: 18-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: WEST SUMMARY ~~~ 69.00 FT MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN= 1084' FSL, 316' FWL SEC 35 T13~ R9E, TVD RECTANGULAR CD~RDIN,,.ES SUB-SEA NORTH/SOUTH EAST/WEST 7967.00 6377.03 6308.03 2280.30 S 3538.02 W 8074.00 6460.23 6391.23 2323.15 S 3589.90 W 8222.00 6575.15 6506.15 2383.08 S 3661.35 W 8385.00 6701.28 6632.28 2449.81 S 3740.15 W 8476.00 6770.84 6701.84 2487.86 S' 3784.81 N 8580.00 6850.22 6781.22 2531.43 S 3835.95 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8580.00 6850.22 6781.22 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4595.94 S 56 34 W SCHLUMBERGER O I RECT [ ONAL SURVEY COMPANY ARCO ALASKA INC NELL 3K- 13 F ! 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Il ] ~ '''~''':'''~'~l'.~--'~'--?--Y--t'''l ~ll'y't--?''?71'---?t-i--~'---'tl'?'?ll't'l' '''lt'''~l''t''~-- -'~-t'l't'"? ...... ,...~...tl..t ...... ~-'?'"t"'t ..... t l~ll'~ I ~ ..... ?--ltll ~ ltl ::::::::::::::::::::::: :::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: :::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::: --~'~"y-V-r"~-V-T'--~ ...... V'V'~'"V'~'"y-V'~ "T'" "T-T'"T"'~ ...... ?'-Y'T-Y'i-'V'~"'Y'Y'~-?'Y'?--~-" '"~"'~-?'?"~-'?'~'"~-'~ ...... ~"'~'"~'"~ ...... ?~"'f'"~ ..... ~"'~'"~"'~' ~' ? 7"T"T ..... ~ "~'"~ .... 1'7 'f' 7' '?'~'"?-?~"?"?'~ ..... ~'--?-~'--r-t'~-?-'~ ...... ~-~nD~?-~?'~'"~-'~-'~"'~'~"-l--~'-'~'i-'~ ....... ~,'"?'~'"tt~'"~"'~ ...... ~"H'"~"~'"~"~'"~'"~ '"y~'?'~'": :"~'~ ~ '~ ~'~': ~'~'~': ~'"~ 237, ,-, II (D (D PROJECTION ON VERTICAL PLANE 2~7. - S7. SCALEO IN VERTICAL DEPYHS HORIZ SCALE = 1/1000 IN/FT ARCO Alaska, Inc. Date: August 5, 1988 . Transmittal Ct: 7249 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. · - 31-03 Kuparuk Stimulation Summary 7-29-88 #230DS361L ~ 1A-10 Kuparuk Stimulation Summary 7-27-88 Ct230DS10AL ~ 3C-08 Kuparuk Fluid Level Report 8-01 -88 Tubing · 1 G-06 Kuparuk Fluid Level Report 8 - 01 - 8 8 Tubing '~' 3 K- 0 6 Kuparuk Fluid Level Report 8 - 0 1 - 8 8 Tubing ' 2 W- 0 5 Kuparuk Fluid Level Report 8 - 0 2 - 8 8. Tubing ~, 1 C- 0 8 Kuapruk Fluid Level Report 8 - 0 2 - 8 8 Casing 3 K- 1 3 Kuparuk Well Pressure Report 4- 1 8 - 8 8 Amerada ., Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska SAPC Un( Mobil Chevron STATE OF ALASKA ALASi-,~ OIL AND GAS CONSERVATION COMw,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other'[] 5. Datum elevation (DF or KB) RKB 69' 6. Unit or Property name KuDaruk River Unit 7. Well number tK-13 / ~ ? 6 oJ 2. Name of Operator ARCO Alaska, ];nc 3. Address PO Box 100360, Anchorage, AK 99510 - 4. Location of well at surface 1084' FSL, 316' FWL, 5ec.35, T13N, R9E, UM 8. Approval number #7-614 9. APl number 5O-- 029-21630 10. Pool Kuparuk River Oil Pool At top of productive interval 1_196' FNL, 1535' FWL, Sec. 2, At effective dep_th !404' FNL, 1288' FWL, Sec. 2, ¢~t¢1 depth FNL, 1237' FWL, Sec. 2, T12N, R9E, UM T12N, R9E, UM T12N, R9E, UM Feet 11. Present well condition summary. Total depth: measured ,.,580' MD feet true vertical6850' TVD feet Effective depth: measured 8476' MD feet true vertical6771' TVD feet Plugs (measure~One Junk (measured)None Casing Length Size Cemented Structural Conductor 80' 16" Surface 4415' 9-5/8" xxx~Yefl~h,'e~te Production 8527' 7" xxxxL>~xxx & 175 SX AS Measured depth True Vertical depth 1540# Poleset 115' MD 115' TVD 1230 SX ASIII 4452' MD 3760' TVD & 300 SX Class G 325 SX Class G 8562' MD 6839' TVD I Perforation depth: measured 8058'-8078', 8118'-8128', 8299', 8307', 8311', 8313 truevertica~448,_6463,, 6494' -6502', 6641', 6644', 6646', 6651 Tubing (size, grade and measured depth) Additiona 2-7/8", ,]-55, tbg w/Tail (a 8185' H~¢c~ekr~ a~d7~%~V, (ty e_ and measured depth) , ~t¢ pkr @ 8157' & TRDP-1A-SSA SSSV ~ 1806' I~ ~2t~', ~2 12. Stimulation or cement squeeze summary I~ L.. ~, ~ 8250' 8253' 8256' 8259' 8292' MD ' 8320' 8323' 8327' 8372' -8382' MD 6597', 6599', 6602',6604',6630',6635'T~ ', 6654', 6657', 6691'-6699' TVD 1 Perfs: 8258'-8260', 6603'-6605' 8287'-8290', 6625'-6628' l\lFh N/A Intervals treated (measured) Treatment description including volumes used and final pressure JUN 2 2 1988 Oit & 6as Cons, Commission Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 337 BOPD 425 MCFPD 0 BWPD 0 BOPD 0 MCFPD 1133 BWPD Casing Pressure 1050 psig 700 psiq ~bing Pressure 1!0 psig 1300 psi§ 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /,~ ¢&.,..,..,] Form 10-404 Rev. 12-1'-85 Title Sr. Operations Engineer Date (.;'//~"¢'¢i Submit in Dupl~cate~,~ ARCO Alaska, Inc/~:~ Subsidiary of Atlantic Richfield Company 'l PBDT WELL NTRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME JDAYS l DATE · RECEIVED JUN 2 2 1988 Alaska Oil & Gas Cons. Commi.~s!on Anchorage [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots ARCO Alaska, Inc' Subsidiary of Atlantic Richfield Company ,NTRACTOR REMARKS IFIELD - DISTRICT- STATE IOPERATION AT REPORT TIME WELL SERVICE REPORT .b t ~PLAC..~ ~ou ~ o u~ $, jUN ~ ~ Alask~ Oil & Gas Cons. Commission F-'I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemP'Report OF Chill Fact°r [ Visibility IWindVel' ISigned°F miles knots ARCO Alaska, Inc. Subsidiary ~f Atlantic Richfield Company WELL IPBDT NTRACTOR REMARKS FIELD- DISTRICT. STATE IOPERA ION AT REPORT TIME WELL SERVICE REPORT Bc~e,O q" A~,.uu/..u5 '-rD 7~o ,~1 Alaska 0ii & Gas Cons. Commission Anchora(]e CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots ISigned STATE OF ALASKA ALASgA OIL AND GAS CONSERVATION CON .... ~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing E] Time extension F! Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1084' FSL. 3.16'..FWL, Sec 35 T13N R9E UM At top of producz~ve ~merva ' ' ' ' 1196' FNL, 1535' FWL, Sec. 2, T12N, R9E, UM At effective depth 1404' FNL, 1288' FWL, Sec. 2, T12N, R9E, UM At total depth 1447' FNL, 1237' FWL. Sec. 2: T12N; RgE, UM 11. Present well condition summary Total depth: measured 8580' MD feet true vertical 6850' MD feet Effective depth: measured 8476' MD feet true vertical feet 6771' MB 5. Datum elevation (DF or KB) RKB 69 feet 6. Unit or Property name Kunaruk Rivpr Unit ! 7. Well number 3K-13 8. Permit number Permit #86-136 9, APl number 50-- 029-21630 10. Pool · K,,n~r,Jk R'ivc, r flil , ~, ~ ~, ~ · - Plugs (measured) None Junk (measured) None Casing Length Size Cemented Measured depth Structural 80' 16" 1540# Poleset 115' MD Conductor Surface 4415' 9-5/8" 1230 SX ASIII & 4452' MD XXX)k3~Rrx'~:~te 300 SX Class G Production 8527' 7" 325 SX Class G 8562' MD 6839' TVD xxxk-~38~xxxx & 175 SX ASI Perforation depth: measured 8058'-8078', 8118'-8128', 8250', 8253', 8256', 8259', 8292' MD 8299', 8307', 8311', 8313', 8320', 8323', 8327', 8372' -8382' MD True Vertical depth 115' TVD 3760' TVD true vertica16448'-6463' 6494'-6502' 6597' 6599' 6602' 6604' 6630' 663 6641' 6644' 6646' 6651' 6654' 6657' 6691'-6699' TVD ~bing(size, grade and measured depth) Additional Perfs' 8258'-8260' 6603'-6605' 2-7/8", d-55, tbg ~/tail @ 8185' 8287'-8290' 6625'-6628' Packers and SSSV(type and measured depth) HRP ~kr ¢ 7967' DR ~k~ O Rlg7' ~ TPRP-IA-qq~ qqqv ~ 1R~, 12.Attachments Description summaryofproposal [] Detailed operations program [] Convert well from oil producer to water in~ctnr 13. Estimated dateforcommencing operation October 1, 1987 Subsequent Work Reported on Form No. ~ Dated../_~'l~/~ BOP sketch [] Date approved 14. If proposal was verbally approved Name of approver Date9/16/87 15. I hereby qertify that ther!oregoing is true and correct to the best of my knowledge /~/,¢]~,2~Tl¢,~,'[,,6.,~"¢z-~:f Title Sr. Operations Engineer Signed Conditions of approval Commission Use Only IApprOval NO' /~- by order of the commission Date Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance . -. : ~ <':. =:. ~ , : .;. ¢.~ : ; ~ -. ...... ; :~ : ' '-" :- Commissioner ~.-~ . Approved by 'TVD Form 10-403 Rev 12-1-85 Submit in triplicate STATE OF ALASKA ALA,_. ,A OIL AND GAS CONSERVATION COM~wlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate~ Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 69' 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1084' FSL, 316' FWL, Sec.35, T13N, R9E, UM At top of productive interval 1196' FNL, 1535' FWL, Sec. 2, T12N, R9E, UM At effective depth 1404' FNL, 1288' FWL, Sec. 2, T12N, R9E, UM At total depth _ 1447' FNE, 1237' FWL, Sec. 2, T12N, RgE, UH 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-13 8. Approval number 7-192 9. APl number 50-- 029-21630 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 8580 'MD 6850 ' TVD measured 8476'MD true vertical 6771 'TVD Length Size 80 ' 16" 4415' 9-5/8" Casing Conductor Surface Production 8527' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 1540# Pol eset 115'MD 1230 sx AS III & 4452 'MD 300 sx Class G 325 sx Class G & 8562'MD 175 sx AS I True Vertical depth 115 'TVD 3760 'TVD 6839 'TVD Perforation depth: measured See attached true vertical See attached Tubing (size, grade and measured depth) 2-7/8", J-55 tubing w/tail ~ 8182' Packers and SSSV (type and measured depth) HRP pkr @ 7964', DB pkr @ 8154' & TRDP-1A-SSA SSSV ~ 1803' 12. Stimulation or cement squeeze summary n e.e at.tac, hed. a¢~endum, d&ted 5/16/87 ~ervals trea~eotmeasureo) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Addendum, dated 5/16/87) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~_~ ,.~-~ ~7/-~ Signed ?y~~,/'~,L/ /~~.._~ Title Associ ate Engineer Form 10-404 Rev. 12-1-85 (Dani) SW02/34 Submit in Duplicate Feet REPORT OF SUNDRY WELL OPERATIONS 3K-13 Continued Item 11. MD Perforation Depths: 8058' - 8078'* 8118' - 8128'* 8250' 8253' 8256' 8259 8292 8299 8307 8311 8313 8320 8323 8327 8372 - 8382' TVD 6448' - 6463' 6494' - 6502' 6597' 6599' 6602' 6604' 6630' 6635' 6641 6644 6646 6651 6654 6657 6691 - 6699' Perforated w/1 spf, 0° phasing * Perforated w/12 spf, spiral phasing SWO/142 ( p. 2 ) 12-11-86 ADDENDUM WELL: 8/19/86 2/02/86 4/11/87 3K-13 RU Schl, rn GR/JB f/8400'-surf. Rn CET f/8455'-6849'. Rn gyro f/8412'-surf. Frac Kuparuk "A" sand perfs 8250', 8253', 8256', 8259', 8292', 8299', 8307', 8311', 8313', 8320', 8323', 8327' & 8372'-8382' per procedure dated 1/13/87 as follows: Stage 1: 100 bbls gelled diesel @ 20 BPM, 6237'-6200 psi Stage 2: 20 bbls gelled diesel pad @ 20 BPM, 6194'-6139 psi Stage 3: 25 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 6139'-6120 psi Stage 4: 250 bbls gelled diesel pad @ 20 BPM, 6120-5900 psi Stage 4: 35 bbls gelled diesel w/2 ppg 20/40 mesh @ 20 BPM, 5945-5913 psi Stage 5: 35 bbls gelled diesel w/2 ppg 20/40 mesh @ 20 BPM, 5945-5913 psi Stage 6: 38 bbls gelled diesel w/4 ppg 20/40 mesh @ 20 BPM, 5913-6200 psi Stage 7: 6 bbls gelled diesel w/6 ppg 20/40 mesh @ 20 BPM, 6200-7500 psi Well screened out 6 bbls into 6 ppg stage. Attempt to re-pressure & break down. Fluid to recover: 463 bbls gelled diesel Sand in zone: 2231# 20/40 mesh & 1000# 100 mesh Sand in Csg & Tbg: 7023# Avg Pressure: 6100 psi Re-frac'd Kuparuk "A" sand perfs 8250', 8253', 8256', 8259', 8292', 8299', 8307', 8311', 8313', 8320', 8323', 8327' & 8372'-8382' in 10 stages per procedure dated 3/12/87 as follows: Stage 1: 20 bbls 140° diesel w/5% Musol @ 2 BPM, 3800 psi Stage 2: 100 bbls gel diesel @ 10 - 20 BPM, 7000 - 5450 psi Stage 3: 20 bbls gel diesel @ 20 BPM, 6220 - 6350 psi Stage 4: 24 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 6350 - 5780 psi Stage 5: 250 bbls gel diesel @ 20 BPM, 5780 - 5900 psi Stage 6: 32 bbls gel diesel 2 ppg 20/40 @ 20 BPM, 4900 - 6040 psi ADDENDUM WELL: 3K-13 (cont'd) Stage 7: 32 bbls gel diesel 4 ppg 20/40 @ 20 BPM, 6040 - 6200 psi Stage 8: 32 bbls gel diesel 6 ppg 20/40 @ 20 BPM, 6200 - 6160 psi Stage 9: 25 bbls gel diesel 8 ppg 20/40 @ 20 BPM, 6160 - 6300 psi Stage 10:49 bbls gel diesel flush @ 20 BPM, 6300 - 5200 psi Underflushed by 1 bbl. Job complete 4/11/87. Rel'd well to Production. Fluid to Recover: Sand in Zone: Sand in Casing: Ave Pressure: 584 bbls 1000~J 100 mesh & 27,730~! 20/40 270~ 20/40 6000 psi D~il~ng Superv r WELL COMPLETION OR RECOMPLETION REPORT & LOG 3K-13 (Cont.) Item 24. Perforation Depths: MD TVD 8058' - 8078'* 8118' - 8128'* 8250' 8253' 8256' 8259' 8292 8299 8307 8311 8313 8320 8323 8327 8372 - 8382' 6448' - 6463' 6494' - 6502' 6597' 6599' 6602' 6604' 6630' 6635 6641 6644 6646 6651 6654 6657 6691 - 6699' Perforated w/1 spf, 0° phasing * Perforated w/12 spf, spiral phasing WC2/O51a 03/02/87 ADDENDUM WELL: 8/19/86 2/02/86 4/11/87 3K-13 RU Schl, rn GR/JB f/8400'-surf. Rn CET f/8455'-6849'. Rn gyro f/8412'-surf. Frae Kuparuk "A" sand perfs 8250', 8253', 8256', 8259', 8292', 8299', 8307', 8311', 8313', 8320', 8323', 8327' & 8372'-8382' per procedure dated 1/13/87 as follows: Stage 1: 100 bbls gelled diesel @ 20 BPM, 6237'-6200 psi Stage 2: 20 bbls gelled diesel pad @ 20 BPM, 6194'-6139 psi Stage 3: 25 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 6139'-6120 psi Stage 4: 250 bbls gelled diesel pad @ 20 BPM, 6120-5900 psi Stage 4: 35 bbls gelled diesel w/2 ppg 20/40 mesh @ 20 BPM, 5945-5913 psi Stage 5: 35 bbls gelled diesel w/2 ppg 20/40 mesh @ 20 BPM, 5945-5913 psi Stage 6: 38 bbls gelled diesel w/4 ppg 20/40 mesh @ 20 BPM, 5913-6200 psi Stage 7: 6 bbls gelled diesel w/6 ppg 20/40 mesh @ 20 BPM, 6200-7500 psi Well screened .out 6 bbls into 6 ppg stage. Attempt to re-pressure & break down. Fluid to recover: 463 bbls gelled diesel Sand in zone: 2231# 20/40 mesh & 1000# 100 mesh Sand in Csg & Tbg: 7023# Avg Pressure: 6100 psi Re-fra¢'d Kuparuk "A" sand perfs 8250' 8253', 8256', 8259', 8292', 8299', 8307', 8311'. 831~'. 8320', 8323', 8327' & 8372'-8382' in 10 stages per procedure dated 3/12/87 as follows: Stage 1: 20 bbls 140° diesel w/5% Musol @ 2 BPM, 3800 psi Stage 2: 100 bbls gel diesel @ 10 - 20 BPM, 7000 - 5450 psi Stage 3: 20 bbls gel diesel @ 20 BPM, 6220 - 6350 psi Stage 4: 24 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 6350 - 5780 psi Stage 5: 250 bbls gel diesel @ 20 BPM, 5780 - 5900 psi Stage 6: 32 bbls gel diesel 2 ppg 20/40 @ 20 BPM, 4900 - 6040 psi ADDENDUM WELL: 3K-13 (cont'd) Stage 7: 32 bbls gel diesel 4 ppg 20/40 @ 20 BPM, 6040 - 6200 psi Stage 8: 32 bbls gel diesel 6 ppg 20/40 @ 20 BPM, 6200 - 6160 psi Stage 9: 25 bbls gel diesel 8 ppg 20/40 @ 20 BPM, 6160 - 6300 psi Stage 10:49 bbls gel diesel flush @ 20 BPM, 6300 - 5200 psi Underflushed by 1 bbl. Job complete 4/11/87. Rel'd well to Production. Fluid to Recover: Sand in Zone: Sand in Casing: Ave Pressure: 584 bbls 1000~/ 100 mesh & 27,730~/ 20/40 270~/ 20/40 6000 psi D~il~~g Superv~-s~r '-- STATE OF ALASKA ALAb.,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend © Operation Shutdown ~ Re-enter suspended well ~ Alter casing Time extension ~ Change approved program ~ Plugging .rq, Stimulate ~ull tubing Z Amend order ~ Perforate~Other 2. Name of Operator ARCO Alaska, Inco 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1084' FSL, 316' FWL, Sec.35, At top of productive interval 1196' FNL, 1535' FWL, Sec. 2, At effective depth 1404' FNL, 1288' FWL, Sec. 2, At total depth 1447' FNL, 1237' T13N, R9E, UM T12N, RgE, UM T12N, R9E, UM FWL, Sec. 2, T12N, RgE~ UM 11. Present well condition summary Total depth: measured true vertical 8580 ' MD feet 6850 ' TVD feet 5. Datum elevation(DF or KB) RKB 6~' 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-13 8. Permit number 86-136 9. APl number 50_029-21 630 10. Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured true vertical Casing Length 8476 ' MD feet feet 6771 ' TVD Size Junk (measured) None Cemented Measured depth True Vertical depth Conductor 80' 16" Surface 4415' 9-5/8" Production 8527' 7" 1540# Poleset 1230 sx AS Ill & 300 sx Class G 325 sx Class G & 175 sx AS I Perforation depth: measured true vertical See attached sheet. See attached sheet. Tubing (size, grade and measured depth) 2-7/8", J-55 tbs w/tail ~ 8182' Packers and SSSV (type and measured depth) HRP pkr ~ 7964'; 12.Attachments 115'MD 115'TVD 4452'MD 3760'TVD 8562'MD 6839'TVD RECEIVED !~Ji...-'~!::,!' o , 'i q o .. /~i~ska 0~1 ~ 6as C'~x~s. Comm~ssioo DB pkr (~ 815~-'$ TRDP-IA--c, RA RSSu r~ !803' Description summary of proposal ~ Detailed ~)perations program~ BOP sketch 13. Estimated date for commencing operation March 22, 1987 14. If proposal was verbally approved Name of approver B. Wondzel 1, AOGCC feet Date approved 03/20/87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~'~' ?~I,]J~,,"L.~' Title Associate Engineer Commission Use Only (JG) 5A2/29 Date Conditions of approval Notify commission so representative may witness Approval No. [] Pug integrity [] BOP Test ~ Location clearance 7 ""/~'~'- Approved by Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate APPLICATION FOR SUNDRY APPROVALS 3K-13 Item 11. Perforation Depths. MD 8058 -8078' 8118 -8128' 8250 8253 8256 8259 8292 8299 8307 8311 8313 8320 8323 8327 8372 -8382' TVD 6448 -6463I 6494 -6502' 6597 6599 6602 6604 6630 6635 6641 6644 6646 6651 6654 6657 6691 -6699' SA2/29a APPLICATION FOR. SUNDRY APPROVALS 3K-13 3K-13 was fracture stimulated in the "A" sand during January, 1987. Following a CTU clean-out, the well shorted no post-frac rate increase. Therefore, ARCO Alaska, Inc., proposes to reperforate and perform a second fracture stimulation treatment on the subject well. (See attached procedures.) Oil E,~ G;~:~ I.;ons. $omi-dsE.~in~.' SA2/29a Attachment II Kuparuk Well 3K-13 "A" Sand Re-perforating Procedure AFE ~AKl~52 1. Set up cleanup/frac tanks. 2. MIRU Perforating E-Line unit. 3. RIH with CCL/perf guns/magnetic decentralizer. Tie in depth using the following logs: Schlumberger DIL/SFL dated 07-28-86 Schlumberger CCL/CET dated 08-17-86 5. Open well to tanks to shoot underbalanced. 6. Perforate the following intervals as indicated. The 'V' phasing will require 2 gun runs each at 1 spf for each set of perfs. Shot Phasing Interval Depth (MD-RKB) Density (degrees) , "A3" 8258'-8260' 2 spf 60 'V' "A2" 8287'-8292' 2 spf 60 'V' 18 total shots Flow the well for 10 minutes after each gun run. SI well and POH for next gun run. 8. RD E-line unit. Attachment I I I KUPARUK WELL 3K-13 FRACTURE PROCEDURE March 12, 1987 AFE~ AK1452 SUMMARY: Well 3K-13 will be fracture stimulated in the 'A' Sand with gelled diesel and propped with 20-40 M sand. The treatment consists of a pre-pad, pad with 100 M sand, and 20-40 M sand stages pumped "on-the-fly" at 20 bpm. Silica flour and 100 Mesh sand are used as leak-off control agents. The 8 PPG and flush stages have NO SILICA FLOUR. PROCEDURE: 1. Pressure up annulus to 3500 psi. 2. RU fracture equipment. Install 'Tree Saver'. 3. Check diesel for contamination prior to gelling- i.e. "black diesel" water, etc ! · Pump fracture treatment per attached schedule. * * Ail slurry stages to be mixed "on-the-fly". * * Ramp-up slowly between stages avoiding high density spikes. * Call flush as densometer drops from 8 PPG. N O * If the fracture treatment screens out, RU with CTU ASAP T before gel breaks. Clean out to PBTD. E S * Expected Wellhead Treating Pressure WHTPE = 5110 psig Fracture Gradient = 0.75 psi/ft TVD Tubing Friction = 305 psi/1000 ft 5. SI well for 24 hours after treatment to allow the fracture to heal and prevent flowback of proppant. 6. Bring well back per normal flowback schedule. Record tank straps, choke settings, and WHP's during flowback period. 7. Take BS&W samples after every choke change and every 8 hrs. Inspect samples for frac sand. If found increase WHP by 100 PSI and contact Operations Engineering (O'Dell/Sloan). Well can be turned into CPF when BS&W is less than 2%. 8. Following flowback, obtain a post-frac "A" sand test. ARCO Alaska, In(. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 11, 1987 Transmittal # 5933 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-16 CET/CEL 9-15-86 8181-8720 2T-12A CET/CEL 9-27-86 4595-6644 2A-11 CET/CEL 3-14-86 5800-6564 3A-9 CET 7-26-86 2000-6299 lA-1 CEL/CET 8-29-86 2708-7255 3A-9 CET/CEL (After Squeeze) 7-31-86 1H-3 CET 7-16-86 6891-7617 3K-13 CET/CEL 8-17-86 6849-8455 3K-14 CET/CEL 8-18-86 7215-8844~ 3I-1 CET/CEL 1-24-86 7588-8887 3F-15 CET/CEL 1-13-86 6600-7384 2128-6039 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil .SAPC Unocal Vau'i t (film) Chevron ARCO Alaska, Inc. is a Subsidiary of AllanticRichfleldCompany -, r_~- STATE OF ALASKA '- ALASK. )IL AND GAS CONSERVATION COMM~,..JION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~- Perforate ]~ Pull tubing Alter Casing Fq Other COqPLETE 2. Name of Operator ARCO Alaska, Inc, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1084' FSL, 316' FWL, Sec.35, T13N, R9E, UM At top of productive interval 1196' FNL, 1535' FWL, Sec. 2, T12N, R9E, LH At effective depth 1404' FNL, 1288' FWL, Sec. 2, T12N, RgE, UM At total depth 1447' FNL, 1237' FWL, Sec. 2, T12N, R9E, LH 11. Present well condition summary Total depth: measured 8580 'MD true vertical 6850'TVD Effective depth: measured 8476 'MD true vertical 6771'TVD feet feet feet feet 5. Datum elevation (DF or KB) p, KB (;9' 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Approval number 325 9. APl number 50-- 029-21630 10. Pool Kuparuk River Oi 1 Pool Feet Plugs (measured) None Junk (measured) None Casing Length Size Conductor 80' 16" Surface 4415' 9-5/8" Production 8527' 7" Cemented Measured depth 1540~ Poleset 115'MD 1230 sx AS III & 4452'MD 300 sx Class G 325 sx Class G & 8562'MD 175 sx AS I True Vertical depth ll5'TVD 3760 'TVD 6839 'TVD Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8182' Packers and SSSV (type and measured depth) HRP pkr @ 7964', DB pkr @ 8154' & ~D~-~-ss~ sssv @ ~8o3' 12. Stimulation or cement squeeze summary InterN~/a'als treated (measured) Treatment description including volumes used and final press[Jre 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil. Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History w/Addend~, dated 9/02/86) Daily Report of Well Operations __~ Copies of Logs and Surveys Run ~( Gyro 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~.~- ~-: / .~7~ Signed ~'O ~ ~1/~¢,.,, Title ~sscx~iate Erloi fleer Form 10-404 Rev. 12-1-85 ~ (DAM) SWO/142 Submit in Duplicate REPORT OF SUNDRY WELL OPERATIONS 3K-13 Continued Item 11. Perforation Depths: TVD 8058' - 8078'* 6448' - 6463' 8118' - 8128'* 6494' - 6502' 8250' 6597' 8253' 6599' 8256' 6602' 8259' 6604' 8292' 6630' 8299' 6635' 8307' 6641' 8311' 6644' 8313' 6646' 8320' 6651' 8323' 6654' 8327' 6657' 8372' - 8382' 6691' - 6699' Perforated w/1 spf, 0° phasing * Perforated w/12 spf, spiral phasing SWO/142(p.2) 12-11-86 ARCO oil and Gas Company .~, Daily Well History-Final Report reo:~:res ~so;~ 3or~s~e~ion. feoo-t 33ms?.t;,sn anG :'eo:'ese~la'-.~.e ~es: ;a;a '~ ~"e "Final Rel~ort" ~sr,m --a~ ~,e ~5e': fo' -e;c,:-~ "o e~t='e Alaska Field e or Kuparuk River Auth. or W O. no. AFE AK1452 Nordic 1 North Slope Borough Alaska ADL 25629 Completion 3K-13 AP1 50-029-21630 Operator A.R.Co W I ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 12/5/86 Date and depth Complete record for each day reported as of 8:00 a.m. 12/06/86 thru 12/07/86 Iotal number of wells (active or reactive) on th~s PSt center prior to plugging and bandonment of this well our J Prior stalus if a W.O. I 1115 hrs. 7" @ 8562' 8476' PBTD, RR 6.9 ppg diesel Accept ri~ @ 1115 hrs, 12/5/86. NU & tst BOPE. RU WL, perf A-sand f/8372'-8382', 1 SPF @ 8327', 8323', 8320', 8313', 8311' 8307' 8299' 8292', 8259' 8256' 8253' & 8250', perf , , s , , w/5" gun, 12 SPF f/8118'-8128' & 8058'-8078'. Make GR/JB'rn to 8425'. RIH, set pkr @ 8157' (WLM). RU & rn 244 jts, 2-7/8", 6.5#, J-55 EUE 8RD tbg w/SSSV @ 1803', HRP pkr @ 7964', DB pkr @ 8154', TT @~' Tst tbg & ann to 2500 psi. ND BOPE, NU & tst tree; OK.~, ~opi well to diesel. RR @ 1445 hrs, 12/6/86. Old TD New TD 8476 ' ?BTD Released rig Date 1445 hrs. Classifications (oil, gas, etc.) 0±1 Producing method Flowing Potential test data PB Depth Kind of rig 12/6/86 Type completion (single. dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct /ZZ~ L~/ ge Drilling Supervisor For form preparation and distribution, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as hey are prepared for each well. iPage no. 1 DIH,~on of Atlanlld:llchlleldCompan¥ ADDENDUM WELL: 8/19/86 3K-13 RU Schl, rn GR/JB f/8400'-surf. Rn CET f/8455'-6849'. Rn gyro f/8412'-surf. Drilling Supervisor ~/~ Date ' STATE OF' ALASKA ALASK 'IL AND GAS CONSEt:::IVATION COMM REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown - St~muiate % P!ugg~ng - Alter Casing ._- Other ~ r-r'~pl ~ · ~ i/~.~ I i,~ Perforate ~ Pull tubing 2. Name of Operator AP,03 A]aska, 3. Address P.0. Box 100360 Anchorage, AK 99.510-0360 4. Location of well at surface 1084' FSL, 316' FWL, Sec.35, T13N, R9E, LN At top of productive interval 1196' FNL, 1535' FWL, Sec. 2, T12N, RgE, LN At effective depth 1404' FNL, 121~' FWL, Sec. 2, T12N, RgE, At total depth 1447' FNL, 1237' F~, Sec. 2, T12N, R.9E, LN 5. Datum elevation iDF or KB) PCB 69' 6. Unit or Property name Kuparuk Ri vet Un11: Feet 7. Well number 8. Approval number 326 9. APl number 50-- 029-216~ 10. F~ol Kuparuk River Oi 1 Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' '44!5' 8527' . Producti on 8,580 I ~D 6850'TVD 8476 6771'TVD feet feet feet feet Plugs (measured) Junk (measured) No~ Size Cemented Measured depth 16" 1~ Poieset 115'~ 9-5/8" 1230 sx ~ !il & 4452'~ 303 sx Ci~s G 7" 325 sx Class G & 8.562'~ True Vertical depth 115'iP/D 3760 'TVD 6839'~FD Perforation depth: measured true ve~isal See_ A:~a~ Tubing (size, grade and measured de,tn) 2-7/8", J-55, ~ w/~ii ~ 8!82' Packers and SSSV (ty~e an~ measure~ depth) . r' I :--~' HR.P pkr ¢ 7964', DB m<r e o~.. ~ & ~..3?-:A-ss.:. sssv ~ z9c3' 12. Stimulation or cement squeeze summary Inte~/~s treated (measured) Treatment description including volumes useC and final .~ressbre 13. N/A Prior to well operation Subsequent to operation ~epresentat~ve Daily Average Production or Injection Data O~i-Bbi Gas-Mcr Water. BPI Casing Pressure TuDin~ Pressure 14. Attachments (CoTple'don ': '~ ~, History w/AOdendu'n, dated 9/02/86) ,,.,~,=~ o~ Logs and Surveys Ru~ Z~' Daily Report of Well Operations ~ "'"' ~ , 15. i hereby certify that the foregoing ~s true and correct to the best of my knowiedge Signed &~'~7,_.~,,/C~L/j.(./i,~, Title Form 10-404 Rev. 12-1-85 // - Date Submit ~n Dup!:cate REPORT OF SUFSRY ~'ELL OPERATIOh.% 3K-13 gon'ci nued Iten 11. Perforation Depths' 8058' - 8078'* 8118' - 8128'* 8250' 8253 8256 8259 8292 8299 8307 8311 8313' 8320' 8323' 8327' 8372' - 8382' TVD 6448' - 6463' 6494' - 6502' 6597' 6599' 6602' 6604' 663O 6635 6641 6644 6646 6651 6654 6657 6691' - 6699' Pe~ora~ w/1 spf, 0° phasing * Perfora~ w/12 spf, spiral phasing S"~/142(p.2) i2-1!-86 ARCO Oil an~_ Jas Company L .,y Well History-Final Report Kuparuk River .~2 2562¢ AFE .~K1452 ~ Completion Nordic 1 AP1 50-029-21630 ARCO Alaska, Inc. 56 24% ',cos: ce-ce. ~r.or ': O;ug~ ~; a-~ · ~aDanoo~e~t oI '- 5 Spu:ceo cr -t~ ~ =egu~ ~a:e I~o~r ~r~c, Complete 12/5/86 { 1115 hrs. Oate an: :eot~ ~o~e:e recor~ 'Or eac~ ca~ as of 8 00 a ~ 12/06/86 thru 12/07/86 7" @ 8562' 8476' PBTD, RR 6.9 ppg diesel Accept ri~ @ 1115 hrs, 12/5/86. NU & tst BOPE. RU ~, perf A-sand f/8372'-8382', 1SPF @ 8327' 8323' 8320' 83!3' 8311', 8307', 8299', 8292', 8259', 8256', 8253' &'8250', perf w/5" gun, 12 SPF f/8118'-8128' & 8058'-8078'. Make GR/JB'rn to 8425'. RIH, set pkr @ 8157' (WLM). RU & rn 244 its, 2-7/8", 6.5#, J-55 EUE 8RD tbg w/SSSV @ 1803', HRP pkr @ 7964', DB pkr @ 8154', TT @ ~'. Tst tbg & ann to 2500 psi. h~ BOPE, NU & tst tree; OK. / Displ well to diesel. RR @ 1445 hfs, !2/6/86. i 8=76' PETD ~e easec - g i445 hrs. ) 12/6:"~6 R:.tarv C~ass;'::a:;=~s ,:~.. ;as. et: -~;e ::-: e: :- s -; e :.a e::. Oil S:ngle =-~:~-.; ~et~: C~.::a, .e~ ' ~a-e s E!owing Kupa~:k Sa=~s Drilling Super~iscr AR3B-45~3-C ADDENDUM WELL: 8/19/86 3K-13 RU Schl, rn GR/JB f/8400' Rn gyro f/8412'-surf. -surf. Rn CET f/8455'-6849' DrO~· l~xlng Supervisor Dare ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 2, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5841 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole Finals (1 blueline of each unless otherwise specified) /3K-2~'-, 2" FDC Porosity 7-4-86 4800-8895 Cyberl ook 7-4-86 8200-8905 2" FDC Raw 7-4-86 4800-8895 5" DIL 7-4-86 4689-8919 ~5" FDC Raw 7-4-86 4800-8895 ~""2" DIL 7-4-86 4689-8919 ~5" FDC Porosity 7-4-86 4800-8895 /3K-'~'-J5'' FDC Porosity 7-12-86 6900-8110 ~' Cyberlook 7-12-86 6900-8050 ~2" FDC Porosity 7-12-86 6900-8110 ~2" DIL 7-12-86 2400-8134 '~2" FDC Raw 7-12,86 6900-8110 ~"~5" FDC Raw 7-12-86 6900-8110 '~5" DIL 7-12-86 2400-8134 3K-13~. Cyberl ook ~ ~2" FDC Raw ~"~ 2" FDC Porosity "-5" FDC Porosity ~5" FDC Raw ~2" DIL '~'-5" DIL 7-28-86 7650-8500 7-28-86 4467-8556 7-28-86 4467-8556 7-28-86 4467-8556 7-28-86 4467-8556 7-28-86 1000-8582 7-28-86 1000-8582 Receipt Acknowledge~~~~:f~/~/~6 Distributio~~~l 1 i n ' NSK g Rathmel 1 D&M ............. ~:~,~ ~i..~?~,.,~.~;.~.. ~]~ ~ Vault (film) L. Johnston (vendor pkg) TKKW'pg' 0040 (MF)' ARCO Alaska. Inc. --~ Post Office B, 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 · RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 10-07-86 TRANSMITTAL # 5786 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: GO: One * of each 3K-13 CBL 09-22-86 Run #1 6546-8452 Receipt Ackno~ ^,.ol, q 0il & GaS Cons. C0~[S$iOD Date: '- ...... Anchorage ,BPAE*b 1 ~h~ on*b 1 / se Mob il*b 1 / se ~0C~*bl/se ~ate~bl/s~~ , .NSK ~iles*bl ~'ault*f i~s SAPC*bl/se Drilling*bi ARCO Alaska. Inc. is a Subsidiary ol AlianticRichfieidCompan¥ STATE OF ALASKA ALASK,~ OIL AND GAS CONSERVATION COMM. _.51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon -- Suspend -- Operation Shutdown~ Re-enter suspended well - Alter casing - Time extension-~ Change approved program Z Plugging C Stimulate ~ Pull tubing - Amend order- Perforate'' Other ' 2. Name of Operator ARCO Alaska, Inc. 3. Address Po 0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1084'FSL, 316'FWL, Sec.35, T13N, RgE, UM At top of productive interval 1289'FNL, 1369'FWL, Sec.2, T12N, RgE, UM (approx.) At effective depth 1394'FNL, 1990'FWL, Sec.2, T12N, R9E, UN (approx.) At total depth 1437'FNL, 1940' FWL, Sec.2, T12N, RgE, UH (approx.) 5. Datum elevation (DF or KB) 69' RKB 6. Unit or Property name K,,,narllk Riv~.r [init- 7. Well number 8. Permit number 86-136 9. APl number 50-- 029-21630 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 8580 ' MD feet 6831 ' TVD feet 8476'MD feet 6751 ' TVD feet Producti on Length Size 80' 16" 4415 ' 9-5/8" 8527 ' 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 1540# Pol eset 115 ' MD 1230 sx AS Ill & 4452'MD 300 sx Class G 325 sx Class G 8562'MD Rue Vertical depth 115'TVD 3752'TVD 6817'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packe~s and SSSV (type and measured depth) None 12.Attachments Well Hi story Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation December, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ./ Signed ~~ ,~LLL~ Title Associate Engineer Date ('/ Commission Use Only (DAM) SA/093 Conditions of approval Notify commission so representative may witness I Approval No. ~,' Plug integrity ~ BOP Test ~ Location clearanceI ',~ ,....~c;,< f,~?. .............. '~'~- ~ by order of Approved by ~' J¢~'~J~ ~, ~1~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company,~,'~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1452 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25629 Title Drill IState Alaska IWell no. 3K-13 Doyon 9 API 50-029-21630 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. I ARCO w.I. IDate IHour Prior status if a W.O. 7/22/86 0630 hrs. iComplete record for each day reported 56.24% 7/23/86 7/24/86 7/25/86 7/26/86 thru 7/28/86 7/29/86 s correct Drilling, Pages ~d~7. 16" @ 115' 2639', (2524'), TIH Wt. 9.2, PV 17, YP 15, PH 9.5, WL 13.2, Sol 6 NU diverter sys. Spud well @ 0630 hrs, 7/22/86. Drl 12¼" hole to 1200' KOP, DD to 2639'. 1140', Assumed vertical 1291', 4.2°, S74.0W, 1290.90, 5.30 VS, 1.53S, 5.32W 1762', 21.4°, S73.7W, 1747.89, 107.19 VS, 26.89S, i10.10W 2233', 36.4°, S60.9W, 2158.44, 331.14 VS, 112.37S, 321.33W 2548', 45.7°, S57.7W, 2394.29, 539.15 VS, 213.99S, 503.28W 16" @ 115' 4472', (1833'), Prep to rn 9-5/8" Wt. 9.5, PV 22, YP 18, PH 9.0, WL 14, Sol 8 Drl & surv 12¼" hole to 4472', 36 std short trip, C&C, TOH. 2805', 46.7°, S57.2W, 2572.17 TVD, 724.64 VS, 313.79S, 659.64W 3405', 44.7°, S56.0W, 2991.22 TVD, 1154.02 VS, 550.18S, 1018.14W 3973', 43.5°, S59.7W, 3399.12 TVD, 1549.28 VS, 760.52S, 1352.81W 4412', 41.5°, S62.2W, 3722.78 TVD, 1845.27 VS, 904.53S, 1612.08W 9-5/8" @ 4452' 4472', (0'), Tst BOPE Wt. 9.2, PV 14, YP 12, PH 9.0, WL 15.2, Sol 6 RU & rn 111 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 4452', FC @ 4369'. Cmt w/1230 sx AS III w/10#/sx Gilsonite, followed by 300 sx C1 "G" w/2% CaCl2 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 1600 hrs, 7/24/86. ND diverter. NU & tst BOPE. 9-5/8" @ 4452' 8580' TD (4108'), Logging Wt. 9.9, PV 16, YP 11, PH 9.5, WL 4.2, Sol 10 Tst BOPE. Drld FC & FS. Tst formation to 12.5 ppg EMW-ok. Drld f/4482'-8580' TD. Short trip 20 stds circ. hole clean. Spot 50 bbl 10% diesel pill. Drop svy. TOOH f/logs. RU WL. Log open hole. 9-5/8" @ 4452' 8580' TD, (0'), Rn'g 7" Wt. 9.9+, PV 12, YP 7, PH --, WL 4.2 Rn DIL/GR/SP/SFL/CAL f/8580'-4467', FDC/CNL f/8580'-7650' & 4650'-4467'. Rn GR f/8580'-1000', RD Schl. TIH, pmp hi-vis pill, spot 10% diesel pill, TOH, LD DP. Chg rams to 7" & tst. RU & rn 7" csg. IDate ~/~ I Title Drilling Supervisor ARCO Oil and Gas Company .~, Daily Well History-Final Report Instructions: Prepare and submil the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length el time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting District ICounty or Parish ]State Alaska North Slope Borough Field JLease or Unit Kuparuk River I ADL 25629 Auth. or W.O. no. ~Title AFE AK1452 I Drill cost center code Alaska JWell no. 3K-13 Doyon 9. Operator ARCO Alaska, Inc. Spudded or W.O. be9un JA.R.Co. Date Spudded Date and depth as of 8:00 a.m. Complele record for each day reported API 50-029-21630 W.I. ~otal number of wells (active or inactive) on this Jcost center prior to plugging and J 56.24% Jabandonment el~ this well I JHour J Prior status if a W.O. 7/22/86 J 0630 hrs. I 7/30/86 7" @ 8562' 8580' TD, 8476' FC, RR 9.9 ppg NaC1/NaBr Brine Rn 208 jts, 7", 26#, J-55 BTC csg w/FC @ 8476', FS @ 8562'. Cmt w/100 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65, followed by 225 sx C1 "G" w/.9% D-127, .3% D-13, .2% D-46 & .3% KC1. Displ w/9.9 ppg NaCl/NaBr brine,~ lp~_g~ CIP @ 1210 hrs, 7/29/86. ND BOPE, instl packoff & tbg head & tst to 3000 psi. RR @ 1700 hrs, 7/29/86. Old TO I New TD PB Depth 8580' TD 8476' PBTD Released rig Cate K nd of r g 1700 hrs. 7/29/86 Rotary Classifications (oil, gas, etc.) ] Type completion (single, dual, etc.) Oil J Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on lest Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected TheaJ~ ; islcorrect sFeOi fl~"rro~ e~~n, ds'ed ic~t.~ nb u~ ~)o, n, L_J ~/~ Drilling Supe tv is or Drilling, Pages 86 and 87, ARCO Alaska, Inc Post Office 15ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 08-08-86 TRANSMITTAL # 5744 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes: Schl: One copy of each 3K-13 Run ~1 07-28-86 0998.5-8597.5 Receipt Acknowledged: State of AK July 15, 1986 Hr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Ar~chorage, Alaska 99510-0360 Telecopy .- (907) 276-7542 Re: KuparoJ-~ River Unit 3K-13 ARCO Alaska, Inc. Permit No. 86-136 Sur. Loc. 108~'FSL, 316'F~, Sec. 35, T13N, R9E, UM. Btmhole Loc. 1426'F~U~, l154'FtqL, Sec. 2, TI2M, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required bY law from other governmental agencies prior to commencihg operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %?here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Con~nission may witness testing before drilling below the shoe of the conductor pipe. : '"' ii. .~ . ~-~ ,'--2'2 .............. C. V. Chatterto~ Chairman of Alaska Oil and Gas Co~Iservation Co~ission By OP~}ER OF ~E COI'~9.{ISSION dlf Enclosure cc-. Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA _,L AND GAS CONSERVATION C,_.vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill [Z]I lb. Type of well. Exploratory [] Stratigraphic Test ES Development Oil Re-Entry ~ Deepen©1 Service ,m, Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Ri ver Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25629 ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1084'FSL, 316'FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 1289'FNL, 1369'FWL, Sec.2, T12N, R9E, UM 3K-13 #8088-26-27 At total depth 9. Approximate spud date Amount 1426'FNL, 1154'FWL, Sec.2, T12N, R9E, UM 07/18/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 8589 ' MD .1084' ~ surface feet 3K-5 250' ~ ~urfa¢~feet 2560 (6788'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth1 200 feet Maximum hole angle 44 0 Maximum surface 2226 psig At total depth O-VD) 3385 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) 9/tll I ¢;lf ~O [-/¢- I.I _ I, ~ ldO'IN I~1 ~i I ~1~ ! '~ I 11~:, 1"1 ~ ! .I. 0 B I'~ !2-'~/z+".q-='/R'' 36.n~ ~-55 RTC /+3a.a.' 35' 35' a. 379' 3759' !230 sx AS !! ! HF-FRW ~nll ~× ~ln~ G hl~nH _ 8-1/2" 7" 26.0# J-55 BTC 8555' 34' 34' 8S89' 6788' 200 sx Class G~minimum HF-ERW TOC 5(,0' abov~ top of Kuparuk 19. To be completed for Redrill, Fie-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 Structural Conductor RECEIVED Surface Intermediate J U L ]. ]. Production Liner Alaska 0il & Gas Cons. 60mmissi0rt Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch"l~ Diverter Sketch ~ Drilling program ~ Drilling fluid prog,,ca~ Time vs depth plot [] Refraction analysis ? Seabed report .m 20 AAC 25.050 requirements 21. I hereby cer/t,f~y t~at the foregoin.,.g is t/us and correct to the best of my knowledge //////~, ,,,,/'~-'~' // ' / Regional Drilling Engineer Date~.~,//~ Signed f ///~.¢..¢.,~-,'/2.'/"/?"'-, ~/ ..,¢-~.&,' Title ".-// "'-/~"/ L/' "///- ' '"' ' Commission Use Only (HRE) PD/PD292 /'Y Permit Numl~'~r /.,/ J APl number I Appr9.v.i~l,cja_te._ _ I See cover letter . ,¢.~..j....5.~ ~/ j 50-- ,~¥'~ -"~ ~ ~0 J U//l.b/~bI for other requirements Conditions of approval Samples required [] Yes ~- No Mud Icg required ~%' Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required 5C-Yes ~ No Required wor~~2~~j 5M; ~ 10M; © 15M Other: by order of Approved by ~k~ ~. '/"'- k_'~..~._~ Commissioner the commission Date I=nrm 1f~-4f')1 Rn.v -g,G triplicate : ~ ALASK.-A, [NC, - ~- PAD 3K;. 't/ELL NO · 13 PROPOSED _._ - - - ~ - - - KUPARUK__F[ELD,:._ .N_QR:TH- .S~O_PE.,. ' AL ASKA .. _ _' EASTtt.*~ I, IttI~$TOCKi., · _ r , rq · . 7000. KOP' TVD-1200 TIID'1200 DEP'O 2raa3 15 BASE:PERIIAFROST TVD-l?21~ Tt'ID-17'28 DEP-?2 _~! ................. ~u.._z PER 1 .... ~-;- -- EOC --TVD-2526-.TIID 2666 DEP-- 36--: .......... ~ .... .~ ......... ~O_P UONU SNDS TVD'2684 TPID'2885 DEP"688i i'_ __. ~, AVERAGE ANGLE DE6 59 HI N --- K-5 TV0'5684 TPID'?05$ DEP-3584 ~-~-'ZONE D TVD=6254 TIID-Z84Z DEP-4134 · , r/ ZONE A TVD-6524 TPID-8223 DEP-4~)95 Alaska Oil TARGET CNTR TVD-6584 Tt'ID-8;~06 DEP=4453 B/ KUP SNDS TVD-6644 TI~D-8~589 DEP-4511 rD CLOG PT) TVD-6?SB Tt'ID-8589 DEP-4650 0 1000 ~000 ~OOO 4.000 5000 VERTICAL SECTION TARGET CENTER TVD-,65~4 DEP-4453 SOUTH 24O4, UEST 37'48 TARGET LOCATION ~ 1320' F#L, 1320' FWL SEC. 2, T I2N, RgE TD LOCATION ~ 1426' FNL, 1154' FWL SEC. 2, T12N, R9E ~ z o , 1 000 _ 0 I ZON TAL-~.. SCALE I IN, 2000 _ 3000 _ ARCO ALASKA, INC'~ PAD 3K. NELL NOI 13 PROPOSED KUPARUK FIELD, NORTH SLOPE, ALASKA .. EASTHAN WHIPSTOCK. INC, 5000 4000 -- WEST-,EAST -- ~'- i .... ;~000 2000 ] 000 p,~ i ' ' , . S 57 DEG 19 MI N W 4453' (TO TARGET) ] 000 ; ~URFAGE LOCATION.' I0~'¢' F~I,., 31~' FWL ! t ~: :'~::~~--'-, ~ ~ . ~ ~ '.~ : : ' :--: ~ · -~' : ~ ! ' : ' ' : i ~:~'.~ i : ~- :'-:::-~: ~ t:~:'~:~::t:~: .... :-~-:-:----:T: .... : ? :-: ...... ?:":~?-:-~-: ...... ~':_:'-' [ .......... ~ ' - _z :_L . :_2 .... ~_~ ..... :-~ .... :1 '_~-_'-72¥_. ~ ............. :... ........ 1 1 ~~~-~':' - ........ : ............... :~ 7 : -- ~ ~ ..... ~ _~~~ ~ · t ........................ '::::)::.~':' :::Z:/::.:z::: :Z '?::':- :::-: o-~:~::~: ................ ~ ........... : - '- _L:L:~.;:::~::::- ::::-~.:::-':-[: ~:: ~ ======================================= ~.: ..... . _.: · ~ ........ : ........ ~ ..... :_L ....... ~ ........ + ...... ; .... :__ . L .... _i~tt~~ ..... I ~ t -~ . .._ ~ ~ -~-~ ..... ~__ _ ~.~ .~ ........ ~_ ....... ~._. ~:__~~_~ ........ . ~ . ~ _ -i~-- :-'-7 : --- i~ ...... ~ ..... ~ .:~i ~--:-- ~ ....... fi -: ..... ~ ..... --aa~ ' --~ ......... ~-'~ - ~ ' - ~ . ; - . . . ~~, ~ - _~ ..... ~ . --~:~ i · ~ .... ~:'::::~-: ..... I ....... ~-;_~ms~ ......... :--/-- t ..... ~ ...... v ..... ~ ~ ..... ,---~< ~ ....... ~.- - ~ :--: .... - ...... I'-:' - -:-~-~-- .... ::z:'.::: ":F':~:'::::~_ ::_::::Z~::--~ _::- :-:-~_. :.'.~_:: S.--. ' ' ~' - :'--~'" - ~: .... : .... ~ ..... ~:_ : ~ : , ............. . , . ~ ~ ........ -~_~~: ~ ~ : . ~ __. ~- ~.., . , :. _ _., .... :. , _~ ~0 .... ~:_ : ::.:': ~-- :-: . :-~:::-:¥:' .::-: ::-_::~_-: ~i6s~-::::-.-:_:::--~- . -~ .... , ~ , . ~ ? I ~ . . , i : --, .... ~ ......... ~~ .... ~ ............. :-z. : -- :' ..... I~ ....... ~ -'- ' ~Sg[._ ZOO_ : ........ :, ..~ ~ .... · _1 . _ :. .... ~ .... /.: _ ~ I , ~~ : / ~ ~ -- ~-I. 902 - - '- .. .............................. ~8o2 ~, 6.0.~.__ .......... :. / -~ _. ~ I ....... ~ - - - ..... t" .:' ; - : , R C /v D ....... ,r ~ .... 'I . f -.. ~ / JUL Z 1 I986 '- Anchorage ~ 1 9 51 -- N~-- -' , 1 -- ~ ! [~~ ,-. ~ ................. 400 ....... . . _ . ~. .. J i j i i i i i .... ' ::: 0 ' i O0 200 300 400 500 600 .--:: KUPARUK R I VER UN I T 20" D I VERTER SCHEMAT I C DE SCR I PT I ON i 8 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY, S. TANKO UPPER QUICK-CONNECT ASSY. $. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20' 2000 PS1 ANNULAR PREVENTER. 4 . ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S . 035 (b) MA I NTENANCE & OPERAT I ON i I. LA°ON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH O I VERTER L I NES EVERY 12 HOURS. 3. CLOSE ANNLLAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPRO~IATE VALVE TO ACHIEVE DOIN~INO DIVERSION. A,o'~orsoe U~ER ANY C I RCUMSTRNCES. m m SI (X)84002 RIO 7 6 5 4 3 2 ACCLMJLATOR CAPACITY TE~T I. Q-~O( AN~ FILL ACOJVM. ATQR RESI[RVOIR TO LEVIE. WIll-i HYCRN/.IC FLUID. AS~LRI[ TNAT A~TCR PR~SSI. RE IS _3003__ PSI WITH 1500 PS! I:X:lte~~ (:F ~ RE.01JLATC~. 3. ~ TI~o Ti-EN O..OSE ALL UNZTS SINU_TN~Y ALL LI~T$ ARE CLOSED WITH Q-IN~IN~ ~ CFR. 4. EEO:RD CN NN3C ~P4:349'. ~ ACCI~:~rAI~__F_ LONER LIMIT IS 45 Si[~ CLC~ZNG TI~ N~D 1200 PSI PRESSURE. 13-,5/8" BOP STACX TEST I. FILL BOII STA(3( A~O C3-K3(E MANIFCID WITH ARCTIC DIF. SI~. 2. Q-[CX THAT ALL LOO( D(3~ S(3qL:'V~ IN ;'~LL}'EAO FLI. J.Y ~"T~ACTI~. ~AT TE, ST PLUO IN WITH RUI~INO ,JT AI~ RLI;I IN LCX3<I:X3~ SQqL:'V~. 3. CL(::~F AhI',LILA~ PI~ AI',~ MA~ KILL AhD ~ Llh[ VALVE~ ~ TO B(]~ STACX. ALL 4. ~ UP TO ~ ~I-10LD FCI:~ IO MIN. IN- ~ PI:~_~¢~__.!~ T~ AhD ~ FC~ I0 MIN. BLEED Pf~~ TO 0 PS~. 5. (:PEN~ ~ ~~ KILLAN3~E L[~ VALVES. CLOSE TOP PIP~ P. AMS AN~ H(~ VALVES Cl4 KILL AhD ~ LII~=.S~-------,,, 6. TEST TO 250 PSI AhD ~ IN STEP 4. 7. CCI4TIhIJ~ TESTINO ALL"-¥AL"~=~o LIhE~o Ah~ WITH A 2..50 PSI LC~ At',D ~ PSI HIOH. TEST AS iN STI~ 4. OO NOT l::'f~.q.q~l;~ TE.~T ANY O-40(E THAT NOT A FULL CLOSIN0 p~;~ITI'VE SEAL (~JCD0~. CN.Y ~ICI4 TEST ~,.9 THAT C)O NOT FL,4.LY CLC:~. 8. C]:M~4 TCP PII=~ R,NVIS AhD CL0~; BOTTCM PIP~ TEST BOTTCM PII:ME RAM~ TO 2.50 I:~I ~ ~ PSI. 9. ~ BOTTCM PII=~ P, AIV~° BACX CUT RUF~I~ JT AhD I0. CLC~F BLIN:) RAMS AhD TEST TO 2_50 I:~I AhD 3000 PSI. II. C;P[N 8LIr~) I~A,,;~S AhO I:~='T~!'EVE-TEST PLUO. ~V4<E MANIFCLD AhD LIr,~$ ~ FULL Cl' r,Z]4-FR~E'ZIN0 FLUID. ~ ALL VALVES IN C~ILL. INO PO~ITICI4.. 12.- TEST ST~IP~ VALVES° KELLY,. KELLY COQ<S. C:~ILL PIP~ SAFER VALVE. ~ INSIE~ B(]:~ TO 2..90 PSI 3000 PSI. 13. 1:~ TEST It,,.m'~TIC]q C]4 BLONOIJT I;:M::;~-VENTF_R TEST FCt~, SIQN, Ah~ ~ TO DRILLINO ~ISCR. ~F. RFC~ C~ET~ BC~ TEST AFT~ NIPPLING UP ~Y THEREAFTER ~IC~I. LY CP~m, AT~ BCPE DAILY d U L i .,, 510084001 REV. MAY I 5,. ~9~ GENERAL DRILLING PROCEDUR~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. ' 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole scanding tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. F~ DE(~SSER t SHALE l I~T STIR SHAKERS [- I S IcLEANER F LWK4/ih TYPICAL MUD :SYSTEM SCHEMATIC DRILLING FLUID PROGRAM Density PV YP Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - · Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih J U L I 1,986 Alaska Oil & C-as Cons. .% ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of A1 aska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3K Pad (Wells I - 18) Dear I.Ir. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Encl osure If ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany LOCATED IN PROTEAOTED LOCATED IN PROTRACTED SECTION 55~ T. 15N.~ R. 9E.~.M. SECTION X · 5~,~.19 L~G. 149'45'~.93~ X - 529,~5,73 L~. 149'45'~.9774" 5 - Y - 6,~,3~.~ ~T. 70'~'01,795~ 14 - Y · 6,~,0~.76 ~T. 70025'59.0923 6 - Y - 6,~,253.70 ~T. 70'26'0~.~ 17 - Y X ' 5~,~5.92 L~G. 249'45'~.~" X - 529,~5.73 L~G, 149'45'~.~77" NOTES . I.A~L COORDINATES ARE A.S.R~ZONE ~ALL DISTANCES SHOWN ARE TRUE. 5. HORIZONTAL POSITIONS BASED ON ~K CONTROL MONUMENTS PER LHD 4. VERTICAL POSITIONS BASED ON 3K TBM No.4 ~ TBM No. 5 PER LHD ~ ASS~. 5.0.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3070 rev.~ I CER~FICATE OF SURVEYOR: i HEREBY C~l~ THAT I AM PROPERLY ;~, REGISTERED AND LICENSED TO PRACTICE LAND *~'.-"~":~ ~ %':':- '- SURVEYIN~ IN ~E STATE: OF ALASKA ~O THAT ~ ~.. : ..... ~THIS PLAT REPRESENTS A LOCATION SURVEY ~. -.. ,- ' MADE: BY ME OR UN~R MY SUPERVISION, THAT ~LL DIMEN5 IONS AND OTHER DETAILS '~ SURVEYED FOR: ~ A Alaska, Inc. . .. ~~' ~ KUPARUK PROJECT /. ~ - .... ~..w.~ DRILL SITE 5K CONDUCTOR ' '"' ~uleva~, Suke 201, Anchorage, Ala~a 99503 IIS~LE NOT TO SCALE i i i CHECK LIST FOR NEW WELL PERMITS Company ~ ~;4 Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee ~'~ 7-/cf~ 1. s the permit fee attached .......................................... (~. thru 8) (3) Admin '(10 and ~ (4) Casg (1~ thru 22) (23 thru 28) (29 thru 31) 2. Is well to be located in a defined pool ................. ~_ 3. Is well located proper distance from property line. i~iii iii iii ! 4. Is well located proper distance from other wells .... ' .' 'i ' ~ 5i Is sufficient undedicated acreage available in this poolI ..... i i.i ~~ ' 6 Is well to be deviated and is wellbore plat included ... i ~ 7 Is operator the only affected party .................... '' .. .. ~ ' 8 Can pe,rmit be approved before ten-day wait .............. , 9~ 10. 11. 12. 13. Does operator have a bond in force .................................. Is a conservation order needed ..................................... Is administrative approval needed · eeIeee~eeeeeeeele~eee®e®eeeeeeeeete -'" Is the lease number appropriate ..................................... ~j Does the well have a unique name and number ......................... ~ , 14. Is conductor string provided ........................................ 15. Will surface casing protect fresh water zones ....................... 16. Is enough cement used to circulate on conductor and surface ......... 17. Will cement tie in surface and intermediate or production, strings ..o 18. Will cement cover all known productive horizons ..................... 19. ~Will all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~_~_~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented REMARKS O 32. Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. bYP 0!O.F~O~ '¢E~iFiCA"~IP~ blSTI,~G P~GE i SERVICE NAME DATE :~6/Og/ 5 ORIGIN : REEL NA~E :14,956~ CONTINUATION ~ PREVIOUS REEL COMMENTS ; LIBRAkY TAPE SERVICK NAME ;EDIT DATE ;~ml08/ 5 ORIGIN :FSIA TAPE NA;qE : CONTINUATION ~ :01 PREVIOI~S TAPE : CONHENTS :LIBRARY TAPE ** FILM HEADER ** FILE NAME :EOIT ,001 SERVICE NAME : VERSION ~ DATE : MAXIMU~ L, ENGTt'~ : 10,24 FILE TYPE'. PREVIOUS F!bE ** INFORMaTiON RKCC)RD$ ** U~I'I' TYP~ CATE SIZE '¢' 000 000 018 065 CN : AR..O ALASKA, INC, WN : 3N-13 000 000 006 065 FN : KUPA.RUK 000 000 008 065 RANG: 9E 000 000 002 065 TOWN: ~.3N 000 000 004 065 SECT: 35 000 000 002 065 COUN: NOSTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 00~ 065 Ui'~IT TYPE CATE SIZE CODE PRES: ** COM~E;I,ITS ***************************************************************************************** AbAS, KA CO~VJPLiTING CENTER ********************************************************************************************* ARCO 3~'13 'YPE FLLII {) ~i SC OS ! I:¥ '6U1D LOSS 9,625" ka 446'!' ' Btlr SIZE = 8,5" TD 8588~' 44,0 $ i~'~F : 3,.,150 ~ 65 OF 9,5 R~C = 1,:880 ~ 65 OF 4.4, C3 a~ A,I' BH"J' = 2,042 (~ 152 DF THIS DAT,a HAH:, NOT {.1EEi:',~ DEPTH Si,lIFTED - OVERLA~S FIEGD PRINTS FOR~iATIi3N 9ENSII'Y CO~E,~SAT~JD LOG ~AIA AVAILA~bF:: 8556' %{3 4467' RAY Ii~ CA~]NG DATA A~'AII, ABL~: 4467' '1"0 1000' ** DATA FgRMAT RECON, D ** TYPE SIZE REPR CODE ENTRY 2 ]. 66 0 ,i 1 66 16 1 66 1 0 i 66 DATUM SP~';CIFICRTION BbOCK$ MNEM S~iRV,,ICE SERVICE [}ig!T AP1 ~PI APl AP1 FibE SIZE ~PL REPR ID ORDER ~ OEP T 4 SFLU 'DIL 4 ISD 015 4 I~ OIL 4 hOG TYPE Ct,,ASS MOD NO. 00 000 00 0 0 O0 22O Ol 0 0 0 o 120 46 0 0 O0 120 44 0 0 PROCESS CO,D~ (OCXAb) I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 V P 0 1 0, H 0 ~ V E R I F [ C .A T i. [) i.~ .L: I $ T t i~I ~i~ P A G E 4 DATA ;P ~H 0 B I p H 1 ;P ;P I P H I )EPT ~PHI ) E; P 't ~ t.:~ H 1 ~PHI )EPT ~Pal ;t H (.) 5 H. 500.0000 ,q F L U ' 2,4,4951 G a 8400.0o00 -,24.9951 2. ,i 651, ,i, 1,. ~ 94 5 80uO. O00U -74,9'!27 22.7051 't 900. r.~ 000 -46. 7383 ~.5432 3,4631 ]:,bO 2.7893 87.4648 G~{ 87'4648 0't18'7 NRAT 2,7209 2183.5000 FCNi., '769.8125 3,1 389 9. 3 6 2109~5000 FCNL 2 9163 lbo 96 4048 GA 0 1460 NRAT 1673 6~75 F'CN~ i 68 00000000000000 i 68 00000000000000 1 6~ 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 6~ {)000000000 '800~ 1 68 0000000000~ O0 '1 68 00000000000000 1. 68 00000000000000 i 6~ 00000000000000 1 68 00000000000000 Ii,,,M 3 3030 CALl 8 3613 RNRA 2 8342 C;a -999 2500 ], 1 :]50 IbM 3,2249 ,. 0~. 4023 CAI~I 8.~691 1584 R~',IRA 3, 932 640:3! 25 GR -99'9. 2500 96.4548 .Ahi 8 832 3,4514 RNRA 3 4827 480.]90b (;R -999 2500 31,8799 ILD 17,7236 b9 'lJt) b g~ 59,7305 0,0425 ~!R~'i' 2.6682 22o'1.5000 FCNL: 827,3125 5 0242 lbo 0.0229 .2o97.5000 '?.0~4:3 ILD 85.3398 GR 9.0088 kAAi 2391.5000 FCN[. 2742 90'3398 2.8U70 712.3125 18,6299 C,- .Abi ,8 8535 R,~ R A 2~ 7385 (;R -999. 2500 l.l.,~ 5 2781 CALl 9~2051 RmRA 2,943b GR '999,2500 7.4929 85.3398 CAbI 2,9338 R~RA 765.3125 (;ii e,. 6 '? 65 1 L, I.) 2471 .SOO0 3.99a3 lbo 123.0273 G~ 4,504b Ib~ 80.8398 CALl 2.3147 RaRA 1046.6875 GR 3.9,'$75 123.0273 CALl 2.822b RNRA '1.4929 9.0723 -999.2500 5,168'1 9.2441 2,Smlb -999.2500 9.5332 2.9553 LVP oiO.H02 V~;RIFICA'rI');~ L, IST.[NG PAGE Alpl't 1 29.980~ tqCN.b DEPT 7800.0000 SrLO SP -40.7383 Gk RMOB 2,4280 DRHO ~PHI 42,041~ NCMb DEPT 7100.0000 SKLo SP - .t4.2~83 GR RHOB 2.3967 DRHO ~PHI 41.7480 NC~U OEPT ~600!0o00 SFbU SP -43 7383 G~ RHOB 999 2500 NPHi -q. 99.2500 DEPT 7~00.0000 SP 56.4883 RHnB -999.2500 NFHI -999,2500 ~CNb DEPT "1400 0000 SF,LU SP -48~88~ RdOB -999,~500 DRHO NP!tI -999,2500 NCNb D~PT 7300,0000 SFI..,U sP .. 44;;0508 GR DEPT 7200,.0000 SFLU ~P}"{I 999, O0 NCNB DEPT 7100.0000 SP -46'2695 RHO~ -999,2500 NPHi -999,2500 NCNb DEPT 7000,0000 SFbU 5P -40.9'883 <;K RHOB -999,~500 D~O NPHI -999.2500 NC~tL D~PT b900'O000 Sp -5.1'7695 GR RHOB -999;2500 :NPHI -999,2500 NCNb 9 E P T 6 ] 00,0000 S F L 0 sP 54.o~,95 n~,'~ 2107.5!300 2.7249 'IbP 1.18.7'173 GR 0,0151 i735.6875 FC~qb 3,7229 TbD 155,0625 GR 0.0430 M8AT 1805,6875 FCNO 1,4493 IUD 378,8906 GR -999 2500 NRAT -999:2500 FCNb 3,8499 127,464'8 -999.2500 '999..2500 !. 349'1 ILD 135.-.4.375 GR :999. 2500 099.2500 FCNL 2.062'7 l'bD 106.0898 GR ,g99,2500 NRAT '999,2500 ~CNL 4,(~8'7 IbO 78. 73 GR -999'2500 NRAT -999,2500 FCNb 2 5393 Ibi) 112 0898 GR '999 2500 NRA'I: -999 2500 FCNb 2 5745 lbo 102 96,48 GR -999 2500 bRAT -999 2500 VCi~L 2,785~ !L!) 1.04,3398 GR -99g,2500 NR. 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' :999,2500 i99,2500 99,2500 999.2500 2 1975 -999i2500 -999 2500 -999,2500 2.5823 -999'2500 -999:2500 -999.2500 2.7424 -999,2b00 -999,2500 -999,2500 2,9749 -999,2500 -999,2500 -999,2500 -9'9912500 ..999,. 500 -999,250(i) . 3. 2034 -999, O0 '999, ~500 5OO :999' ~500 ggg, 2500 2,3792 -999. O0 -999,2500 2,4709 -999;2500 "999 ' ~:2500 '999',2500 2,8459 '":~99 * 2500 ' 99. 2500 '999'2500 440o -999 2300 177 O, 6 ti75 FCNL, - 999 2 -999 2500 -999 2~00 .-999 2bOu "999.2500 lbo -999,2500 Ga -999,2500 l'.i 2 ! T -999.2500 FCNL, -999.2500 lbo - 99 q. 2500 G -999.2500 -999. 2500 F C "~ [., -999. 2500 ! L, 9 -999,2500 GR - 999,2 5 n 0 F C !'~ !.~ -99q. 250u - 999,250 -999.2500 -979.25()0 -9~_J9. 2500 I -o99.250u - o 99,259 u :'~ .R a !.' - 9 ~, q. 2500 F'C ',~ 5.1453 95,964~ 3.1~99 RNRA 532.8125 3,3147 Ii~a 98,5273 C^bl 3,7346 RII'~RA 428,6406 GR -999.2500 -999.2500 -999,2500 RNRA '999,250(! GR 999,250u IP~ 999.2500 CALl -9< 9. 5 -99q. 250() Ga 2500 lbl~ - 999, .... ) C -q99.25( 0 Ab J[ -999,2500 Rt~R.A -999,2500 -999.2500 :IbM -999.2500 CALl -999.2500 RiiRA -999,2500 GR -999.2500 1999.2b00 CALl 199q.2500 R!qRA -999.2500 Gl{ -999.2500 -999,250U -999.2500 -9q9,2500 Ga -999.2500 ]lbm -999.2500 CALl -q99.2500 RNRA '9~9.250U -~99.2500 CaLl. -999.250<) RN~A -999.2b00 GR t.9656 10,5957 3.322~ 1.~.4l*1875 12.01,76 109,8~98 -999 2500 -999 2500 -999 2500 51 9492 - 999.250 0 -999,2500 -999.250U .4e,e242 - 999 . 2500 -999.2500 -999i2500 59.9805 -999.25OO -999*2500 -999.250G 39,6367 -999.2500 -999.2500 -999.2500 65,9492 -999.2500 -999.2500 -999.2b00 b0.8242 -999.2500 -999.2500 -999.2500 i4.9492 -999.2500 -999.2b00 -999.2500 42.9492 -999,2500 -999.2500 -99g,2500 '-,YP Olo,rlo2 VERIFiCaTIO~ .L, ISTI~r,~G PAGE 9 )EPT 3500. 0000 SF ~P -999.2500 ~dOB -999.'2500 qPHI -999.'2500 NCNL ~EP'r 3400,0000 SFbO SP -999,2500 GR RHOB -999,2500 DRHU ~IPHI -999,~500 NCNb DEPT. !300iOuOu SFI,U SP 999 .2500 GR Rd[30 999 2500 DKF!O '~P~I -99~..2500 ~CNL DEPT 2~200 0000 SFbU ~HOB -999.2500 DR'MU NPHI -999.2b00 NCNb 3100 0000 SFLU '999,2500 GR -999,2500 DKHLi -999.25(.)0 NCNI~ D E P T 3000,00 o 0 $ F I, U SP "999,2500 DEPT 2900,00(10 SFI,,U SP ' 999 ' NPH I -999 · 25 O0 N Cr'l h D E P T 2800,0 S p - 999.2 R fl 0 $ - 9 9 9 ~PHi -999:500 NCNI~ DEpT 2700,0000 SP =999,2500 Ga Ri'iOB -999.2500 NPHI -999,2500 NCNb 2600.00( 0 S~ LO '999 ' 2500 '999 ~ 2,500 D -999,2500 NC DEPT 2509, 0000 SFLU SP -999,2500 GR R H 0 ~ - 999.2 !500 i') R iq 0 -999.2500 'IUD -999.250O GR _ . , -999,2500 FCNL -99g.2500 -o99,2500 -999.2500 -999.~500 -999.2500 lbD ~999!2500 GR ,f 999 2500 999. 2500 FCNL -999.2500 IbD i09q. 2500 G~{ 999,2500 FCNb -999 2500 I~ -999,~500 GR -999.2500 NR~T '999,2500 FC b -999,2500 '999.2500 GR -999,2500 NRAT -999,2500 FCNb -999 2500 It, D -999 O0 '999 ~00 -999 2500 FCNb -999,2500 II~D -999,2~00 GR -999,2500 NRAT -999.2500 -999 2500 IbP ~999 2500 -999 2500 -999 2500 FCNL, -999" 2500 NRAT -999' 2500 PCNL, -999,2500 -999,2500 -999 ?500 -g9g 2500 IbM -999.2500 RNRA -999.2500 GR '999.2500 IbM '999,2500 CAbI -999.2500 RNRA -999.2500 GN -999,2500 -999.2500 -999.2500 29.47]6 -999,2500 -999.2500 -999 ~500 -999 2500 Ib~ 999,2500 -999::!50(, CAbI :999,2500 -999 500 Ri, RA -999,2500 -999 500 GR 49.136"7 -999.~500 IbM -999. 500 CAbl '999,2500 RNRA '999,~500 '999,2500 '999.2500 CALl -999,~500 RNR. A -999, 500 GR "999,2500 I~M' 'g99.2500 CAbi -999,2500 RNRA -999,2500 GR -999,2500 ' 999 , 2500 C A -999~2500 Ri, RA -9:99;~500 GR -999,2500 -999.2500 CALl -999,2500 RNRA -999,2500 GR -999 2500 - 999 2:500 -999 2500 -999 2500 CALl RNRA 00 ...ALI ~999 ~00 RNRA . -999~2500 GR -999 2500 tihM ' 2500 C' A. b ,i -999,2500 RaRA '999,2500 '999.2500 '999'2500 32. 386'7 -999,~500 -999, 500 -999,2500 34,9180 '999,2500 -999,2500 -999 i2500 42,2930 -999 2500 -999 .... 62 6055 -999,2500 -999,2500 -'999 2500 247,12467 -999,2500 -9:99,2500 -999; 2500 52,9180 -999,2509 -999,2500 -999,~2500 44;6992 '999,2500 ..999, '5oo 999. 2500 } E: P T i 7 00. q 00 t,) ;P -999.2500 Git ~;'tOB -999,2300 ~PHi -999,2~00 ~,iCNb )EPY ,tSO0,O000 ~P -999.2500 Gig ]dOb --999.2500 ~Pfll -999.2500 400, -999 . 2500 -099 2500 -999 2500 GR -999 2500 -999 2500 FCN'b '999,2500 I' ",~' -9992.500 (I~ -999:2500 NRAT -99~,2500 FCNL, -999,2500 IhD -999;~500 GR -999 500 {:Nb -99'9 2500 ~99' - ,2500 '.. 99,2S00 :999,250~ 999,2500 GM -99'9,2500 -999,2500 FCNb -999,2500 ILO -999,2500 GR '999,2500 NRAT -999,2500 FCqL, -999.2500 -999.2500 GN -999,2500 FC~I, -n99,2509 Ik, P -999,2500 GR -999,2500 -999,2500 FCNb -999.2500 I~9 -999,2500 GR -099.2500 r'~[~I -999,2b00 FCNL, -999.250~ -999,2500 -999 , 2500 -999.2500 -999.2500 CALl -999 '2500 RNRA -999,2500 G R -999,2500 '999:'2500 CALl -999,2500 R, NRA -999"2500 GR -999,2501:1 (~i,,~ '999,2500 AL1 '999,:2500 RNRA -999,2500 GR q99.2500 999.2500 CADI 999,2500 RNRA -999..2500 GR -999,2500 IbM -999.2500 CAL, I -999 2500 RNRA ' ,~.~ -999,2500 G~ -999,2500 Ib~i -999.,2500 CALl '999,2500 RNRA '999,2500 GR '999,2500 Ib~ -999.2500 CALl -999.2500 RNRA -999,2500 ~R '999,2500 Ib~ '999,2500 CALl :~99 2500 RNRJq 99~250U GR -999.2b00 Ib~ -999.2500 CALl -999,2500 RNRa -999,2500 GR -999.2500 IbM -9~9.2500 CAhi -999,2500 RNRA -999,2500 GR -999.2500 :[b~ -999.2500 CALl 41,0742 '999,~500 '999,500 "999,2500 32.9492 -999.2500 '999,2500 '999,2'500 45,6055 '999,2500 '999,2500 ~999,2500 50,7305 -999. 2500 .999; ~soo . 999.2500 28,6924 ' 999,2500 2999,2500 .999. 2500 2 ,::) ~ 'l 236 -999.2500 , "999,2500 '999,2500 ~9,0742 :999,2500 999.2500 '999.2500 26.8330 -999.2500 -999,2500 '999.2500 40.9805 -999,2500 -999.2500 -999,2500 25.1611 -999.2500 -999,2500 -999,250') 3B.9805 -999 2500 -999:1~500 999 2600 I',;R&T -999 2500 R,qRA -999,2500 ~gR~iOBpNI -999. q99: 2500250,) D[{HOi,~C~,Ou '-999:2500 F'CNL -999:2500 GR 27,4736 DEPT SP 13OO,OOO0 SFLO -099.2b00 -99912500 -999,2500 NCNb -999.2500 2999,2500 GR 999.2500 -999,2500 ECNL Sp RtiOB q P g I 1200.0000 SF'I~U 99,~500 -999,2500 '999 2500 lbo -999i2500 (;R -999 2500 NRAT -999,2500 FCi~h OEP'r 1100.0000 SFI,U SP -999'2500 GR RPiOtt -999 2500 Or, MU NPHI -999 ~ 2500 NCNb -999 2500 -999,2500 GR -999,2500 -99q.2500 DEPT lO00,,O00O SFLO 5P -999,2500 RH06 -999,2500 NPHI -999.2500 NC~:h -999 2500 IL~D -qgq ' ...... ,2500 GR 'I~ '999.2500 '999.2500 FCNh SP "999,2500 GR'999,2500 GR R~OB -999,2500 DRHO -g9g, 2500 tx}RAT N P a I - 999,250 o N C N i;, - 999,2500 F C N h ** FILE TRAILE~ ** FILE N A~!~E :EDIT SERVICE N,h~i E VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE N:EXT FILE NA~E : ** TAPE TRAIbE!~ SERVICE NAME DATE 1~6108t 5 ORIGIN ;F$:IA TAPE NANE CONTINUATION # :01 N'EXT TAPE NA!~E COMMENT6 :LIBRARY TAPE ** REEI~ TRAILER ** SERVICE NAME :EDIT DATE 186/08/ 5 -999,2500 -999,2500 CALl -999.250U R~RA -999.2500 GR -999.2500 IbM -999.250U CAI.,I -999.2500 RNRA -999,2500 GR '999,2500 IbM -999,2500 CALl -999,2500 RNRA -~99,2500 GR :999 2500 Ib~ 999:2500 CALl '999.2500 RNRA -999.2500 GR : 99,2500 IbM 99.2500 CAbl :999,2500 RNRA 999,2500 GR :9992500 q99:250U -999,2500 53.6680 '9'99,2500 '999.2500 '9992500 '999,2500 '999,2500 '999'2500 38.7~17 -999 .~500 -999~ 500 -999~2500 52,6055 -999.2500 -999 2500 -999 2500 52 7930
