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186-196
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-05 KUPARUK RIV UNIT 3Q-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-05 50-029-21684-00-00 186-196-0 W SPT 6181 1861960 3000 2367 2370 2370 2370 0 0 0 0 REQVAR P Josh Hunt 8/28/2024 This is a 2 year MIT-IA required by AIO 2B.019. This well was tested to a starting pressure of 3300 psi 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 3Q-05 Inspection Date: Tubing OA Packer Depth 380 3300 3150 3130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240828160806 BBL Pumped:4.8 BBL Returned:4.4 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 99 99 Þ 9 9 AIO 2B.019 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 14:12:17 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-05 KUPARUK RIV UNIT 3Q-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3Q-05 50-029-21684-00-00 186-196-0 W SPT 6181 1861960 3000 1942 1948 1945 1944 4 2 0 0 REQVAR P Bob Noble 8/13/2022 MITIA to max anticipated injection pressure as per AIO 2B.019 and docket AIO 17-009 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 3Q-05 Inspection Date: Tubing OA Packer Depth 740 3300 3140 3115IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814153609 BBL Pumped:3.8 BBL Returned:3.3 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:34:13 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Tuesday, August 18, 2020 1,y �� Cj 7�Z c P.I. Supervisor t SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3Q-05 FROM: Brian Bixby KUPARUK RIV UNIT 3Q-05 Petroleum Inspector Src: inspector Reviewed By: P.I. Supry��z NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-05 API Well Number 50-029-21684-00-00 Inspector Name: Brian Bixby Permit Number: 186-196-0 Inspection Date: 8/15/2020' Insp Num: mitBDB200816075938 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-05 Type Inj W •TVD 6181 Tubing i 2540 2540 " 2540 2540 - 540"PTD1861960 PTD 1861960"Type Test II, SPT ITest psi 3000 " j IA 800 3290 3160 3130 - BBL Pumped: 3-9 " 'BBL Returned: 3.6 OA o 2 2 2 " Interval REQ VAR PIF P Notes: MITIA as per AIO 28.019 Tuesday, August 18, 2020 Page 1 of 1 pp u o = v , v 14.9 r. >c." 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It a a o 0 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �c (b 16 I I b DATE: Monday,August 08,2016 P.1.Supervisor (/ ` SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-05 FROM: Bob Noble KUPARUK RIV UNIT 3Q-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry,,)'— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-05 API Well Number 50-029-21684-00-00 Inspector Name: Bob Noble Permit Number: 186-196-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804102001 Rel Insp Num: • Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-05 W- 6181 2900 2900 - I 2900 • i 2900 . ,Type InI TVD Tubing PTD I 1861960 ' Type Test SPT Test psi 3450 IA 1260 3600 - 3550 - 3550 Interval REQVAR jP/F P • OA 9 187 - 176 169 - Notes: MIT-IA per AIO 2B.019 too 1.2 times max anticipated inject pressure. v SCANNED 41AY 1 9 L i Monday,August 08,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,October 09,2015 Jim Regg ( P.I.Supervisor C • �1 I Ulq 6(c SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 3Q-05 FROM: Jeff Jones KUPARUK RIV UNIT 3Q-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J P NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-05 API Well Number 50-029-21684-00-00 Inspector Name: Jeff Jones Permit Number: 186-196-0 Inspection Date: 9/25/2015 Insp Num: mitJJ150928084238 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well? 3Q-05 Type Inj w'TVD 6181 - Tubing l 2925 2925 - 2925 . 2925 ----- —— PTD L 1861960 Type Test SPT Test psi 3400 - IA ; 1000 3600 • 3510 _ 3480 - ,- Interval REQVAR P/F P ✓ OA 1 15 169 - 157 157 Notes: MITIA per AIO 2B.019;test to 1.2 X max.injection pressure.4.8 BBLS diesel pumped. 1 well inspected,no exceptions noted. Friday,October 09,2015 Page 1 of 1 0 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 08,2013 TO: Jim Regg ' 6.-e e- 101 4 3 '\ P.I.Supervisor - SUBJECT: Mechanical Integrity Tests ( / CONOCOPHILLIPS ALASKA INC 3Q-05 FROM: Bob Noble KUPARUK RIV UNIT 3Q-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J-C- --*--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-05 API Well Number 50-029-21684-00-00 Inspector Name: Bob Noble Permit Number: 186-196-0 Inspection Date: 10/6/2013 Insp Num: mitRCN131007152820 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ' -,- Well 3Q-05 Type Inj w "TVD 1 6181 - IA 1520 1 3600 - 1 3540 -1 3535 - i r I I PTD1 1861960 - Type Testi SPT Test psi 3472 ' 1 OA 5 147 - 140 I 140 _ I Interval REQVAR P/F P •/ Tubingli 2660 F 2660 2660 1 2660 ' 1 Notes: MITIA.As per AIO 2B.019, 1.2 times the max anticipated injection pressure.Max psi is 2893 1-- -, SCANNED 7r. ;11 , ‘'t :i Tuesday,October 08,2013 Page 1 of 1 . • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(cialaska.00v; AOGCC.Inspectors(rDalaska.gov; phoebe.brooks(Dalaska.govv chris.wallaceaalaska.00v OPERATOR: ConocoPhillips Alaska,Inc -2e f , +O)4I(3 FIELD/UNIT 1 PAD: Kuparuk/KRU/3Q Pad DATE: 09/27/13 OPERATOR REP: Byrne/Freeborn Set-Set- a tch .L 4_ AOGCC REP: Chuck Scheve 4 r U1We eiopIet. -.. Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-05 ' Type Inj.' W TVD . 6,182' Tubing ' 2,050 2,050 - 2,050 2,050 Interval V P.T.D. 1861960 ' Type test P ' Test psi '3472 Casing 500 3,540 -3,440 3,430 P/F F '' Notes: MITIA,as per AI0 2B.019. OA 6 42 40 37 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F_ Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA • TYPE INJ Codes TYPE TEST Codes SCAA •'ED D E. -. 1 ( L INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 30-05 09-27-13.xls • K' 39-05 • Pin I%igto0 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, October 01, 2013 8:51 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Dethlefs, Jerry C; NSK Problem Well Supv Subject: KRU state witnessed MITIA's: 1Q-11 (PTD#1841990); 2C-05 (PTD#1830990); 2T-28 (PTD# 1950920); 2U-07A(PTD#1850910); 30-17 (PTD#1880290); 3Q-05 (PTD#1861960) Attachments: MIT KRU 1Q-11 9-27-13.xls; MIT KRU 2C-05 09-27-13.xls; MIT KRU 2T-28 09-27-13.xls; MIT KRU 2U-07A 9-27-13.xls; MIT KRU 30-17 9-27-13.xls; MIT KRU 3Q-05 09-27-13.xls Please find attached forms for recently performed MIT's at KRU. The initial test pressures for well 3Q-05 (PTD #1861960) were not recorded before rigging down the pump truck and sending it to the next location, in an attempt to efficiently progress the work. Unfortunately, due to that the test pressure dropped below the lower threshold, despite passing parameters. This well was called a fail and will be scheduled for a re-test at first opportunity, and an inspector will be invited to witness. Please let me know if you have any questions. Thanks, Ron Wilson / Roger Mouser CPAI Field Supervisor, DHD Office: 659-7022 Cell: 943-0167 Pager: 659-7000; #121 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 02,2013 TO: Jim Rp P.I.Supervisor ����Ke4 t it 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-05 FROM: Chuck Scheve KUPARUK RIV UNIT 3Q-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-05 API Well Number 50-029-21684-00-00 Inspector Name: Chuck Scheve Permit Number: 186-196-0 Inspection Date: 9/27/2013 Insp Num: mitCS130929072328 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min o r Well 3Q-05 Type Inj w TVD 6181 IA T soo 3540 34 i — 1 1 PTD 1861960 ' Type Test SPT Test psi 3472 1 OA 6 1 42 40 37 Interval: Tested per AIO 2B.019.Per operator-The initial test pressures for well 3Q-05 I3Q 052050 (PTD#1861960)were 0not recorded j Notes: p p orded before rigging down the pump truck and sending it to the next location,in an attempt to efficiently progress the work. Unfortunately,due to that the test pressure dropped below the lower threshold,despite passing parameters. SCANNED DEL, 2 3.2013 Wednesday,October 02,2013 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 05, 2011 TO: Jim Regg e�y4 toko(t{ P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q -05 FROM: Lou Grimaldi KUPARUK RIV UNIT 3Q -05 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3Q -05 API Well Number: 50- 029 - 21684 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG111002145054 Permit Number: 186 -196 -0 Inspection Date: 10/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-05 ' 'Type Inj. W TVD 6181 IA 300 3606 3552 3531 " _ P.T.D 1861960 • TypeTest SPT Test psi 3600 OA 0 2 3 3 Interval REQVAR P/F P Tubing 2894 2893 2893 2893 Notes: 2 year MIT for waiver compliance A.A. 2B.019. 5.8 Bbl's to pressure up 5.4 retumed. Good test. Required test = 1.2 times max anticipated — injection pressure. Max historic injection x 1.2 = 3500 psi Wednesday, October 05, 2011 Page 1 of 1 ~~~'~~~ STATE OF ALASKA " a LASK~L AND GAS CONSERVATION COMMIS~N APR 1 3 .~~PORT OF SUNDRY WELL OPERATIONS 1. Operations Pe SC repair ~a,~t-1118$IORepairwell ~ Plug F~rforations r Stimulate r Other w/Platelets Alt~flt~lll/QE'r Pull Tubing r Perforate New Fbol ~ Waiver ~ Time Extensron r ~'c Nt Change Approved Program ~" Operat. Shutdow n r Perforate ~ Re-enter Suspended Well r ~ ~ c~EsS ~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-196 3. Address: Stratigraphic r Service r .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21684-00 7. Property Designation: 8. Well Name and Ngmber: ADL 25512 ALK 2553 \ 3Q-05 9. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 10145 feet Plugs (measured) None true vertical 6432 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 9674 true vertical 0 feet (true vertucal) 6181 Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 115 115 0 0 SURFACE 5019 15.25 5056 3647 3520 2020 PRODUCTION 9996 7 10031 6371 4980 4320 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9767-9830; 9770-9830' True Vertical Depth: 6230-6264; 6232-6264' t~ > y ~ ,_ ~ ~ ~ R. f ~ f = ,'s~~~ . . ~...,~_~ Tubing (size, grade, MD, and TVD) 2.$75, J-55, 9704 MD, 6197 TVD Packers &SSSV (type, MD, and TVD) PACKER - 2 7/8" X 7" CAMCO HRP-1-SP PACKER (PINNED 60K) 9674 and 6181 TVD SAFETY VLV - 2 718" CAMCO TRDP-IA-SSA SSSV, 2.312 ID @ 18 D and 1751 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-iVICf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 750 450 2800 Subsequent to operation 750 450 2800 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service r . Well Status afterwork : Oil r Gas r WDSPL r Daily Report of Well Operations X \ GSTOR r" W bA °{~" GASINJ ['" WINJ , 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. F~cempt: 310-069 Contact MJ Loveland/ferry Klein Printed Name MJ Lovel d Title Well Integrity Project Supervisor Signature `~~/~ / Phone: 659-7043 Date f 1 !~ Form 10-404 Revised 7/2009 $ APR 13 ~'~ ~ Submit Original Only RBDM /~'=~~~,/~ 3Q-05 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/11/10 04/11/10 Summary SC Leak Repair -Unsuccessful (Brinker Platelet), Initial T/I/0= 2870/450/0. Established 1st LLR - 6 gpm @ 40 psi. estimated hole size 6.03 mm, 2nd LLR - 7 gpm @ 50 psi.with estimated hole size 6.12 mm, 3rd LLR - 8 gpm @ 60 psi. estimated hole size 6.02 mm. Leak size is estimated between 6 - 7 mm. Start to deploy platelets with Gel diesel in OA, 30 x 12 - 7 mm spheres pumped for 30 minutes. No pressure build up. Injected 25 , 30 x 5 mm disc's followed with micro platelets (20g 600 - 1 mm, 20g - 30 mesh, 10g - 2 mm cubes). No pressure build up. Injected 25, 30 x 5 mm disc's, 20g 30 mesh, 10g 2 mm cubes, 50 5 mm cubes. No pressure build up. Injected 25, 20 x 5 mm disc's ,20g 30 mesh, 10g 2 mm cubes, 50 5mm cubes . No pressure build up Rig down 2" manifold on OA. Reached the 90 degree elbow going into the OA annulus valve we found 17 large disc's, 10 little disc's and 11 spheres jammed up in 90 degree elbow. The returns truck monitor any additional fluid build up in returns drum due to for thermal expansion of diesel. Night operator to monitor any fluid build up in returns drum during the night. Final T/I/0= 2870/450/0. Platelet repair attempt unsuccessful -well will continue to be operated under AIO 26.019 ~S~Q~fC~ 0~ Q~Q~~{Q /,E..~..E~.w~.o. MJ Loveland Well Integrity Project Supervisor v~e. t /~ ConocoPhillips Alaska, Inc. .~ C,:, P.O. Box 100360 ( Anchorage, AK 99510 ~ `(/' 1Q ~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 3Q-05 Sundry Number: 310-069 Dear Ms. Loveland: 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this A~ day of March, 2010. Encl. ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 6, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7`'' Avenue, Suite 100 Anchorage, AK 99501 REC~IVEC MAROg2010 +~lk8018AGy' g C on Dear Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 3Q-OS (PTD 186-196) surface casing repair with Platelets. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ~~~ "` MJ L veland ConocoPhillips Well Integrity Projects Supervisor U Enclosures STATE OF ALASKA • - ALASI~IL AND GAS CONSERVATION COMMISS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 3 1. Type of Request: Abandon r Ftug for Redrill r Perforate New Pool r Repair well ~ , Change Approved Program r Suspend ~"" Plug Perforatans r Perforate r Pull Tubing ~ Time Extension r Operational Shutdow n r Re-enter Susp. Well ~" Stimulate Aker casin 9 r Other:SC repair w/Platelets r' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-196 3. Address: Stratigraphic r Service ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 • 50-0 9- 4- • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Num where ownership or landownership changes: Spacing Exception Required? Yes r No r 3Q-05 9. Property Designation: 10. Field/Pool(s): ADL 25512 ALK 2553 Kuparuk River Field / Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY ' Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (n): Effective Depth ND (ft): Plugs (measured): Junk (measur 10145 - 6432 Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 5019 15.25 5056' 3647' 3520 2020 PRODUCTION 9996 7 10031' 6371' 4980 4320 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9767-9830; 9770-9830' 6230-6264; 6232-6264' 2.875 J-55 9704 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - 2 7/8" X 7" CAMCO HRP-1-SP PACKER (PINNED 60K) MD= 9674 ND= 6181 SAFETY VLV - 2 7/8" CAMCO TROP-IA-SSA SSSV, 2.312 ID MD= 1819 ND= 1751 12. Attachments: Description Sumriary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch (~ E~loratory r Development [" Service r' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: A ri16.2010 Oil r Gas [" WDSPL r Plugged r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned I- Commission Representative: GSTOR ~ SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Peny Klein Printed Name MJ Loveland 7 ~-~'''~ Title: Well Integrity Project Supervisor ,.-°~- Signature ~~/~*° ~ ~~,.-~ Phone: 659-7043 Date I1L17~Y ~ (~ C mm' Sundry Number: 7 ~ ~ _ /'y~.Ql _ Conditions of approval: Notify Commission so that a representative may witness ~ J VIFJ Plug Integrity ~ BOP Test [" Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: ~Q •Y(~y APPROVED BY Approved by: COMMISSIONER THE COMMISSION ~~~~~ Date: Form 10-403 Revise ~1L(~tl9" 11 ~ ~ ~ ~ ~ ~~~ ~ ~ 3 •~• Submit in Duplicate ~~~- .. ., C7 ConocoPhillips Alaska, Inc. Kuparuk Well 3Q-OS (PTD 186-196) SUNDRY NOTICE 10-403 APPROVAL REQUEST March 6, 2010 This application for Sundry approval for Kuparuk we113Q-OS is for the repair of a surface casing leak. Kuparuk River Unit well 3Q-OS (PTD 186-196) was drilled and completed in October 1987 as a development well and immediately converted to an injector. In September 2006 a surface casing leak was reported to the AOGCC. Subsequent testing indicates the leak depth in the surface casing is approximately 30' down from the OA valve. Due to the depth of the leak ConocoPhillips is planning a second repair attempt with Brinker Platelets. Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications and within the operating conditions of the well. Each partial is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: 1. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 & Cancel AA AIO 2B.019 • ^ STATE OF AU4SKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; tom.rr~a~rxler~a~sica.gov;b~.4ieckensteirs@ia~.gov;daa.aogcc.prudhoe.bay~alaska.gov Email to:guy.schwartz~alaska_gow OPERATOR: ConocaPhillips Alaska !ne_ FIELD I UNIT / PAD: Kuparuk / KRU / 3Q DATE: 1i~1~3I(f9 OPERATOR REP: 9v~ ,~ ~~t~y AOGCC REP: Jeff,lon~s Packer P'cetest leroi~o! 1S Min. 30 Min. Well 3Q-05 T In. W TVFEI 6,'f81` T` 2r~ 2,~ 2,86~ 2,865 Ir~terval V P.T.D. 1861960 T test P Test ~ 35(I~ 700 3,5(Im 3,420 3,400 PJF P Notes: pumped 4 bbls to ach~ 35aQ psi ~A U' U 0 0 Test AVO 26.019 M1TIA to 1.2 x rr~c iri ~ Well T In'. 7Vfl T' Interval P.T.D. T test Tesd " P!F Notes: OA Well T In _ N TVE} T" Ir~terval P.T.D. T test P Test ` Ca~i RIF Notes: ~~ Well T In"_ '~VD 'f ' Intenral P.T.D. T test Test ' PJF Notes: OA Well T tn _ TVD Tubi Interval P.T.D. T test 7'~t " P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TES~ Godes N! = Annulus ~tcni~wing P = Sian~rt! Presseue Test R= CrEte~rtra! R` ' Tracer Seervey A = T ~ S~r p ~ - ' T re Test ~~~t~ INTERVAL Codes I = Inidal Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in nMes) ~ "~.~~~,t:. , t .:,~ ~q~ r~~~ `~; ~. ~'~~~$~. MIT Report Form BFL 11/27/07 MIT KRU 3Q-0510-03-09.x1s • • ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 7, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 _ Dear Mr. Maunder: ~~~3 .~ ?C~CI ~,~kP~'3d31A~S3~1 Please find the enclosed 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we113Q-OS (PTD 186-196, Sundry 308-421). The report records the unsuccessful surface casing repair attempt with Brinker Platelets. Please call MJ Loveland or Perry Klein at 659-7043 if you have any questions. Sincerely, MJ eland Well Integrity Project Supervisor • • ~.„~ ~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION t° k°~'~~ ~ ~.GO~ REPORT OF SUNDRY WELL OPERATIONS . ~, _ F~~,..,. r°nre-,rr,iss~®In 1. Operations Performed: Abandon ^ Repair Well Q Plug Pertorations ^ Stimulate ^ ~ ~40f8Q6 Q Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ SC repair w/ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ platelets 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 186-196 3. Address: Strati ra hic Service g p ^ 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21684-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 59' 3Q-05 ' 8. Property Designation: 10. Field/Pool(s): ADL 25512 `ALK 2553 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10145' ~ feet true vertical 6432' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 4996' 9-5/8" 5055' 3647 PRODUCTION 9972' 7" 10031' 6371' Perforation depth: Measured depth: 9767-9830; 9770-9830' true vertical depth: 6230-6264; 6232-6264' Tubing (size, grade, and measured depth) 2-7/g", J-55, 9705' MD. Packers &SSSV (type & measured depth) HRP-1 SP Packer 9674 SSSV= TRDP-1A-SSA SSSV= 1819' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: See dally report Of Well OperatlOnS 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A 350 275 2800 Subsequent to operation N/A N/A 350 220 2750 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.o. Exempt: 308-421 Contact Perry Klein/ MJ Loveland Printed Name MJ Loveland tine Well Integrity Project Supervisor Signature -~ ~,~ ~ . ~ Phone 659- 7043 Date . ~ C , ~ ~~, ~ ~ ~' Form 10-404 Revised 04/2004 ~ '~(t(~ Submlf~nginal my 3Q-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/24/09 Brinker Platelets SC Re air -unsuccessful. Initial T/I/0= 2750/250/0. Using tri-plex pump pumping diesel down the OA taking returns up the conductor out the down spout and into a catch drum. At a rate of 15 gpm @ 1000 psi. 5 batch of latelets were attem ted with no success. Batch #1= 50 - 5 mil. heavy platelets= batch #2= 250 - 5 mil. heavy platelets, batch #3, 4 & 5 were all 100 ea. 2 mil. lite platelets. Final T/I/0= 2750/250/0 01/28/09 Brinker Platelets SC Re air -unsuccessful. Rigged up LRS to the platelet skid and started pumping diesel down the OA and established a LLR of .5 bpm @ 925 psi. 4.1 bbls pumped. Loaded batch #1 50 -10 mm heavy platelets and pumped at a rate of .5 bpm @ 850 psi. 4.1 bbls pumped. Loaded batch #2 50 - 8 mm heavy platelets and pumped at a rate of .5 bpm @ 740 psi. 4.2 bbls pumped. Loaded batch #3 100 - 10 mm round heavy platelets and pumped at a rate of .5 bpm @ 590 psi. 3.8 bbls pumped. Loaded batch #4 50 - 15 mm round heavy platelets and pumped at a rate of .5 bpm '@ 600 psi. 4.0 bbls pumped. Loaded batch #5 250 - 5 mm heavy platelets and pumped at a rate of .5 bpm @ 900 psi. 3.7 bbls pumped. the 5 mm platelets held briefly at 900 Qsi. white. pumping and broke back durin the .5 r Loaded batch #6 250 - 5 mm heavy platelets and pumped at a rate of .5 bpm @ 400 psi. 4.6 bbls pumped. (saw another slight rise in si. to 700 with this batch also before breakin back). Loaded batch #7 250 -10 mm heavy platelets and pumped at a rate of .5 bpm @ 360 psi. 4.5 bbls pumped. Loaded batch #8 250 - 10 mm round heavy platelets and pumped at a rate of .5 bpm_ @ 500 psi. 4.0 bbls pu Rigged down LRS and platelet skid. Final T/I/O = 2800/275/0 02/03/09 Brinker Platelets SC Repair -unsuccessful. Initial T/I/0=2750/220/0. Rigged up LRS to the platelet skid and started pumping diesel the OA and established a LLR of .5 @ 330 psi. 2.4 bbls pumped. Loaded batch #1, 100 - 8 mm light cubed platelets and pumped at a rate of .5 bpm @ 290 psi. 3 bbls pumped. Loaded batch #2, 250 - 5 mm cubed platelets and pumped at a rate of .5 bpm @ 350 psi. 3 bbls pumped. Loaded batch #3, 50 - 25 mm x 5 mm disc platelets and pumped at a rate of .5 bpm @ 350 psi. 3 bbls pumped. Loaded batch #4, 150 - 6 mm cubed platelets and pumped at a rate of .5 bpm @ 300 psi. 3 bbls pumped. Loaded batch #5, 100 - 10 mm cubed platelets and pumped at a rate of .5 bpm @ 310 psi. 3 bbls pumped. Loaded batch #6, 150 - 10 mm x 10 mm x 5 mm cubed platelets and pumped at a rate of .5 bpm @ 300 psi. 3 bbls pumped. Loaded batch #7, 100 - 10 mm spheres platelets and pumped at a rate of .5 bpm @ 290 psi. 3 bbls pumped. Loaded batch #8, 150 - 5/16" core spheres platelets and pumped at a rate of .5 bpm @ 300 psi. 6 bbls pumped. Loaded batch #9, 25 - 25 mm discs platelets wrapped with copper tape, pumped at a rate of .5 bpm @ 300 psi. 1 bbl pumped. Got a seal @ 1500 psi, held it for 10 minutes before it released. Loaded batch #10, 17 - 25 mm x 7 mm disc platelets and pumped at a rate of .5 bpm @ 300 psi. 3 bbls pumped. Ri ed down LRS and platelet skid. Final T/I/0=2750/220/0. ~PLATELETS° Overview & Case Studies Product ®verviow Platelets° are an innovative means of sealing leaks in fluid flow applications such as pipelines, umbilicals and other items of system infrastructure. Platelets° are free floating, discrete particles which are injected into a system which has a known or suspected defect. The Platelets° are transported downstream with the flow in the system and when they reach a leak fluid forces entrain them into it thus providing a seal. This unique and innovative concept is based on the method the human body uses to heal .. wounds and can be optimised for a wide variety of fluid flow applications. Since Platelets° are deployed remotely they are a cost effective alternative to other remedial techniques such as clamps and wraps since direct access to the leak site, and therefore vessel intervention, is not required. Platelets° can be deployed in response to an emergency loss of containment incident but are most effectively incorporated as part of an ongoing integrity management programme to remove unnecessary system downtime. Platelet° material is selected depending upon the conditions within the system, such as pressure, temperature, fluid type, predicted leak geometry etc. but generally polymeric and elastomeric materials have the required characteristics for Oil & Gas applications. In all instances Platelets° are entirely inert and are therefore a low risk solution as they will have no negative effect on system infrastructure or indeed the carrier fluid. Platelets° can be introduced into a pipeline in a number of ways such as via pig launchers or by pumping through teeing points on the line; in all deployments to-date it has been possible to utilise existing infrastructure for injection and no modifications to the system have been required. Platelets° -The Facts • Remote deployment - no requirement for vessel intervention or access to leak site. • No requirement to shut-down, deployed whilst system operational. • Adaptability for variety of leak scenarios: corrosion pitting, fitting failures, hairline cracks, 6 o'clock grooves. • Emergency response or effective component of ongoing integrity management programme. • Temperature <_ 90°C, Pressure <_ 3,000 psi • 01eak/ Q1Pipeline = 1/20. • ,ilr'~~~~~'rr r~l~ ;VIII ~I`~'If(/~~ iL~ l_ .: ~~S~n,~. ,. AI.ASSA OIL A1~TD GAS COI~TSLRQATIOI~T COMl-IISSIOIQ MJ Loveland • SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Well Integrity Project Supervisor ConocoPhillips Alaska Inc. PO Box 100360 ~~,~~~~~~~ ~~~~ ~y ~~~~ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3Q-05 Sundry Number: 308-421 Dear Ms. Loveland: b \$~. i9 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cath P. Foerster Commissioner DATED this7.5 day of November, 2008 Encl. I ~ ~ • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 17, 2008 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we113Q-OS (PTD 186-196) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, °-~/ %~ r MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures C~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ APPLICATION FOR SUNDRY APPRC3VAL 20 AAC 2.5280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved ro ram p g ^ Pull Tubing ^ Perforate New Pool ^ SC repair w/ Re-enter Suspended Well ^ Platelets 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 186-196 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21684-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S NO Q 3Q-05 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25512 RKB 59' Kuparuk River Field /Kuparuk Oil Pool • 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10145' - 6432' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 4996' 9-5/8" 5055' 3647' 3520 2020 PRODUCTION 9972' 7" 10031' 6371' 4980 4320 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9767-9830; 9770-9830' 6230-6264; 6232-6264' 2-7/8" J-55 9705' Packers and SSSV Type: Packers and SSSV MD (ft) HRP-1 SP Packer 9674 SSSV= TRDP-1A-SSA SSSV= 1819' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December ~o, zoos Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval:- Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/ MJ Loveland Printed Name MJ Love nd Title: Well Integrity Project Supervisor Signature ~ Phone 659-7043 Date ~ ('(~(7 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~1 - c ~ Test ~ Plug Integrity ^ BOP Test ^ Mechanical Inte©t Location Clearance ^ Other. Subsequent Form Required: ~f~, ~~~ APPROVED BY HE COMMISSION //~ ~~~ ~~ Date: !( Approved by: COMMISSIONER T ,.., . ~Y.•- ./~ Submit in d~/!/~CJ$ Form 10-403 Revised 06/200f,~ ~ ~ ~ lj ~ ~„~ ConocoPhillips Alaska, Inc. Kuparuk Well 3Q-OS (PTD 186-196) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 17, 2008 This application for Sundry approval for Kuparuk we113Q-OS is for the repair of a surface casing leak. Kuparuk River Unit we113Q-OS (PTD 186-196) was drilled and completed in October 1987 as a development well and immediately converted to an injector. In September 2006 a surface casing leak was reported to the AOGCC. Subsequent testing indicates the leak depth in the surface casing is approximately 30' down from the OA valve. Due to the depth of the leak ConocoPhillips is planning a repair attempt with Brinker Platelets. Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications and within the operating conditions of the well. Each partial is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: 1. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 & Cancel AA AIO 2B.019 3 ~~ MEMORAND M ~ State of Alaska U n Alaska Oil and Gas Conservation Commission l ~~ DATE: Wednesday, October 01, 2008 TO: Jim Regg ~ ~~~I ~ ~,~ P.I. Supervisor StiBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-OS FROM: Bob Noble KUPARUK RIV UiVIT 3Q-OS Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: KUPARUK RIV UNIT 3Q-OS API Well Number: 50-029-21684-00-00 Insp Num: mitRCN080927 1 8 1 134 Permit Number: 186-196-0 / Rel Insp Num: Inspector Name• Bob Noble Inspection Date: 9/25/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well sQ-05 jType Inj. w TVD 6181 IA a5o la8o 18zo ~ 1800 P.T. ~ 1861960 'T)'peTOSt SPT ~ Test psi 1880 QA 0 -' 3 2.5 3 Interval REQVAR P~F P ~ Tubing i 2550 2550 ~ 2550 2550 Notes: ~_ ~ ~ ~ ~ ~ ~, . a, Wednesday, October 01, 2008 Page I of l d E ( � SARAN PALM, GOVERNOR OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL 2B.019 Ms. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. OrdiNWEV JUN 0 6 nil P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 3Q -05 (PTD 1861960) Request for Administrative Approval Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby grants ConocoPhillips Alaska Inc. ( "CPAI ")'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit ( "KRU ") 3Q -05 exhibits communication between the surface casing and conductor at approximately 30 feet below ground level. All positive pressure tests performed on the well's tubing, inner annulus ( "IA "), and wellhead seals have passed since communication was first identified and reported in September 2006. The Commission finds that CPAI does not intend to perform repairs at this time, but does intend to attempt a repair with new sealant option in the future. The Commission further finds, based upon reported results of CPAI' s diagnostic procedures and wellhead pressure trend plots, that KRU 3Q -05 exhibits at least two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in KRU 3Q -05 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 2B.019 • • October 22, 2007 n.— 2 of 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 6. The MIT anniversary date is October 1, 2007. 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. DONE at Anchorage, Alaska and dated October 22, 2007. 410t — _• . __ t7!�' ' orman Daniel T. Seamount, Jr. Cathy . Foerster Chairman Commissioner Commissioner k 1/4 k I i IN ,-?) ( 7 4 4 • a.~1 Re~~, James B (DOA) ~! lQ ~ ~ "I From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, October 15, 2007 9:50 PM To: Regg, James B (DOA) Subject: Emailing: 3Q-05 90 day TIO.gif Attachments: 3Q-05 90 day TIO.gif 3Q-05 90 day TIO.gif (35 KB) «3Q-05 90 day TIO.gif » Jim, Enclosed is the 90 day T/I/O plot for well 3Q-05, PTD # (186-196) Perry Klein Problem well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907} 659-7000 x909 n1617C~conocophillips.com 1 ~~+~~~.'~ N(~V ~ ~ 2007 1 l'nanp lemporen micrnci h~lesOLRZa~3O-U? YU au~ llU.q~t ~^'~--y t-y r-~ ~~ ~ ~ ~~ ~ ~ ~~. TRN ANNL ANNULUS F;REJSUf~E TREP11C7S JJJ '~F'F9 - WFT T NAMF WLKRU3Q-05 3000. 200. 3000. 3000. 30(10. 0. 0. 0. 0. 0. U. 0. 0. SC SC ~ " _ 3000 z7oo 2400 2100 1800 1500 1200 900 600 300 0 '------ - --------------------------------------------------------------------------------------------- - ----------------------------- - ------------------ - ----- ~---- ------ - ---, PLOT START TIME MINOR TIME PLOT' I)UF?A"I"[ON PL07' P:ND TIME 17-JUL-07 21:52 MAJOR TIME WEEK +021.60:00:00 j4(~~;15-OCT-07 21:52 PICK TI)i>i: D7-O CT-07 10:51:1 3 "~"` TiG NAME DESCRIPTION P-71, Lill ?-~',"`'' L;~TEST DRILLSITE WELL WL3Q-05-CHOKE FLOW TUBING CHOKE 7777777 ~ PREV WELL 3Q 0 5 SCRATCH 23 FLOW TUHIN(i PRESSURE SCRATCH_23 FLOW TUDINO TEMP ????77? NEXT WELL 7777777 ' ??????7 ETTI-R`~' TYPF.OPERATOR ????7?? ~ OPERATOR VERIFIED 23 SCRATCH d INNER ANNULUS PRES ??????? ~ '.~`~':;'1'I•:M At-7"fY) F:kaTFdY _ SCRATCH 23 L_; OUTER ANNULUS PRES 7???777 ~ BOTH • • file.///CVtemp/pemporan Internet Files/OLK24/3Q-lii Y(r da) TIO.gIf IU/lG/20(q 9:OG:59 AM MIT KRU 3Q 10- 01- 07.xis • Page 1 of 1 41111 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] �c �1 (D1)11-7 Sent: Wednesday, October 03, 2007 7:38 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) • Cc: NSK Problem Well Supv Subject: MIT KRU 3Q 10- 01- 07.xls Attachments: MIT KRU 3Q 10- 01- 07.xls �r � «MIT KRU 3Q 10-01-07.xls» \ Jim/Tom /Bob, Please find the attached data recording a passing diagnostic MITIA on 3Q -05 (PTD 186 -196). ConocoPhillips completed the test in preparation of applying for an AA for the well with known OAxOOA communication. The test will not reset the 4 year clock. The next scheduled MIT for the well is due in August 2008. Let me know if you have any questions about the test. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7043 SCANNED NOV 1 3 2007 Cell Phone (907) 943 -1687 II 10/3/2007 S • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_ Fleckenstein @admin.state.ak.us; Jim_Regg @admin.state.ak.us; Tom_Maunder @admin.state.ak.us,,,,, 43' 7 lq OPERATOR: ConocoPhillips 1---,2 (]I FIELD / UNIT / PAD: Kuparuk/ KRU/ 3Q �� b DATE: 1 0/01/07 �(� OPERATOR REP: Bates /Ives AOGCC REP: Packer Depth ,/ Pretest Initial 15 Min. 30 Min. Well 3Q -05 Type Inj. N TVD 6,181' Tubing 1775 1775 1775 1775 Interval 0 P.T.D. 1861960 Type test P Test psi 1545.25 Casing 180 3000 2950 2950 P/F P Notes: Diagnostic MITIA - Does not reset 4 year clock OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 3Q 10- 01- 07.xls • • IV ConocoPhillips �..� ��`' Alaska <<� � � P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 - 9510 -0360 8; 9 rii � :tj {i :�`i'' c� Vii: c.. t;. ��;�,« are ,-,-1:: October 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 JLJN 0 6 2011 Dear Mr. Maunder: 1 ConocoPhillips Alaska, Inc. presents the attached proposals as per AIO 2B, Rule 9, to apply for Administrative Approval to allow well 3Q -05 (PTD 186 -196) to be online in water only injection service with known OAxOOA communication. ConocoPhillips intends to pursue a sealant repair option for the surface casing leak in the future, however will apply for the appropriate 10 -403 approval before hand. If a successful repair is achieved we will request the well be returned to normal status and resume the ability for MI injection. If you need additional information, please contact me at 659 -7043, or Brent Rogers / Perry Klein at 659 -7224. Sincerely, ' ' ' 'I /.; c j - - - - --- - - - - - - " - - - - - - - - - - - - - - - - - - - - - - - - - ''' M oveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 3Q -05 (PTD 1861960) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection well 3Q -05. Well History and Status Kuparuk River Unit well 3Q -05 (PTD 1861960) was originally completed in October 1987 as a producer and was immediately converted to an injection well. 3Q -05 was reported to have developed a near surface outer annulus leak on September 21, 2006 and the well was immediately SI. Subsequent diagnostics located the surface casing by conductor leak at approximately 30'. This leak is too deep to excavate and patch as Conoco Phillips surface casing excavation and repair process is restricted to a maximum of 26'. g re a P p Additional diagnostic completed 9/25/06 and 10/01/07 confirm production casing and tubing integrity with a passing MITIA to 3000 psi, as well as, wellhead seal integrity based on passing tubing and IC packoff tests. ConocoPhillips intends to pursue sealant repair options for the leak in the future, however in the mean time, requests water only injection approval. Barrier and Hazard Evaluation Tubing: The 2 -7/8" 6.5# J -55 tubing has integrity to the packer @ 9674' MD, based on passing MITIA to 3000 psi on 09/25/06 and 10/01/07. Production casing: The 7" 26# J -55 production casing has integrity to the packer @ 9674' MD based on the passing MITIA tests outlined above. Surface casing: The well is completed with 9 -5/8" 36# J -55 surface casing. The surface casing leak is located approximately 30' below ground level and is contained within the conductor casing. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /IO plots will be compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Well Integrity Supervisor 10/2/2007 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_ Fleckenstein @admin.state.ak.us; Jim_Regg @admin.state.ak.us; Tom_Maunder @admin.state.ak.us OPERATOR: ConocoPhillips FIELD / UNIT / PAD: Kuparuk/ KRU/ 3Q DATE: 10/01/07 OPERATOR REP: Bates /Ives AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 3Q -05 Type Inj. N TVD 6,181' Tubing 1775 1775 1775 1775 Interval 0 P.T.D. 1861960 Type test P Test psi 1545.25 Casing 180 3000 2950 2950 P/F P Notes: Diagnostic MITIA - Does not reset 4 year clock OA 0 0_ 0_ 0 Well Type Inj. TVD Tubing Interval P.T.D._ _ Type test Test psi _ Casing P/F Notes: OA Well Type Inj. ND Tubing _ Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. • Type test _ Test psi Casing 1 _ P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 30 10- 01- 07.xls 1 KRU 3Q -05 il l ConocoPhillips Alaska, Inc. 3Q -05 API: 500292168400 Well Type: INJ Angle «8 TS: 58 deg @ 9763 SSSV Type: TRDP Orig Completion: 1/27/1987 Angle @ TD: 58 deg @ 10145 Annular Fluid: Last W /O: Rev Reason: TAG FILL SSSV Reference Log: Ref Log Date: Last Update: 5/12/2006 (1819 Last Tag: 9820' RKB TD: 10145 ftKB OD:2.875) Last Tag Date: 4/27/2006 Max Hole Angle: 59 deg @ 4900 Casing String - CONDUCTOR Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 Gas Lift Casing String - SURFACE 3ndrel /Dummy Description Size Top Bottom TVD Wt Grade Thread Valve 1 f SUR. CASING 9.625 0 5055 3647 36.00 J -55 000:4.:4.750) 750) J (30 1 i Casing String - PRODUCTION Description Size Top Bottom TVD Wt Grade Thread PROD. CASING 7.000 0 10031 6371 26.00 J -55 Gas Lift Tubing String - TUBING I 3ndrel /Dummy Size Top Bottom TVD Wt Grade Thread Valve 2 2.875 0 9705 6198 6.50 J -55 8RD AB MOD EUE (59265750 00:4.750) Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 9767 - 9770 6231 - 6232 C -4,A -1 3 12 3/4/1987 5" HSC 120 deg. phasing Gas Lift 0 Csq Gun 3ndrel /Dummy 9770 - 9830 6232 - 6264 A - 1 60 16 8/4/1987 2 1/8" Zero deg. phasing Valve 3 EnerJet (73384339, Gas Lift Mandrels/Valves 00:4.750) St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 1 3056 2573 Camco KBMG DMY 1.0 BK -2 0.000 3/5/1987 Gas Lift 2 5926 4106 Camco KBMG DMY 1.0 BK -2 0.000 3/5/1987 3ndrel /Dummy Valve 4 III Ill 3 7338 4894 Camco _ KBMG _ DMY 1.0 BK -2 0.000 3/5/1987 (7968 4 7968 5247 Camco KBMG DMY 1.0 BK -2 0.000 3/5/1987 OD:4.750) 5 8505 5550 Camco KBMG DMY 1.0 BK -2 0.000 3/5/1987 6 9040 5842 Camco KBMG DMY 1.0 BK -2 0.000 3/5/1987 7 9608 6146 MMH 2.875x1.5 DMY 1.5 TG 0.000 3/28/1987 Gas Lift Other (plugs, equip., etc.) - JEWELRY 3ndrel /Dummy 11 11111 Depth TVD Type Description ID (8505 Valve 5 1819 1750 SSSV Camco TRDP -IA -SSA' 2.312 00:4.750) 9657 6172 PBR Camco'OEJ' 2.297 9674 6181 PKR Camco'HRP -I -SP' 2.347 9692 6191 NIP Camco 'D' Nipple NO GO 2.250 9704 6197 SOS Camco 2.441 Gas 3ndrel/Dummry 9705 6198 TTL 2.441 Valve 6 1111 Fish - FISH (9040 - 9041, Depth Description Comment OD:4.750) 9924 1 1/2" DMY In Rathole Gas Lift el 3ndrel /Dummy 7 Valve 7 (9608 -9609, 00:5.500) PBR (9657-9658, OD:2.875) ILI PKR (9674 -9675, 00:6.151) NIP (9692 -9693, Li 00:2.875) TUBING (0 -9705, OD:2.875, j ID:2.441) SOS (9704 -9705, OD:2.875) Perf (9767 -9830) Perf (9770 -9830) -- 3Q-05 PTD# 186-196 surface casing leak . Tom & Jim, This afternoon a surface casing leak has been found on produced water injection well 30-05 PTO # 186-196. The well was in service for pit dewatering from Sept. 13 th until the 19th when it was placed back on produced water injection. The operator attempted to pressure up the OA with lift gas. After applying gas there was no increase in OA pressure. The sound of gas escaping could be heard in the gravel below the tree. The well was shut in immediately and OHO will troubleshoot the well tomorrow morning. I've included the 90 day well head pressures. There is no conclusive point that indicates a surface casing breach such as a rapid drop in OA pressure however the OA pressure has been historically low on this well. T/I/O prior to well being shut in was 2795/1502/25 psi Let me know if there are any questions. Perry Klein 2 V'1. '"Jí{'Ç', . CD . L·~\J<J !~^~NEv S I..! "I Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «30-0590 day plot.gif» «30-05.pdf» Content-Description: 3Q-05 90 day ·3Q-05 90 day plot.gif. Content-Type: image/gif Content-Encoding: base64 Content-Description: 3Q-05.pdf Content- Type: application/octet-stream Content-Encoding: base64 I of I 9/22/2006 II :00 AM 90 . . KRU 3Q-05 API: 500292168400 Well Type: INJ AnQle @ TS: 58 deQ @ 9763 SSSV Type: TRDP OriQ Completion: 1/27/1987 Anole (Q) TD: 58 deo (Q) 10145 Annular Fluid: Last W/O: Rey Reason: TAG FILL SSSV Reference Lao: Ref Loa Date: Last UPdate: 5/12/2006 (1819-1820, Last Tao: 9820' RKB TD: 10145 ftKB 00:2.875) Last.ate: 4/27/2006 Max HOle~~ 4900 I Description Size Top Bottom TVD I Wt Grade I Thread I I 16. 0 115 15 .r H-40 I Gas lift 3ndrel/Oummy I Description Top Bottom TVD Wt Grade I Thread Val\e1 SUR. CASING 0 3647 ... J-55 I (30$-3057, JDâliðíill:.bÆ_ì:1 00:4.750) Description I Top Bottom TVD Wt I Grade I Thread ".".,_""""'~Ir.: 7.. I 0 10031 6371 26.00 I J-55 I Gas lift ¡¡¡¡uli 3ndrel/Oummy Size I Top I Bottom I TVD I Wt I Grade I Thread Val\e2 2.875 I 0 I 9705 I.... I J-S5 8RD AS MOD EUE (5926-5927, 1~_.flnsI16mffiâ 00:4.750) Interval TVD Zone Status Ft SPF Date Tvoe Comment 9767 - 9770 6231 - 6232 C-4,A-1 3 12 3/4/1987 5" HSC 120 deg, phasing Gas lift Cso Gun 3ndral/Dummy 9770 - 9830 6232 - 6264 A-1 60 16 8/4/1987 21/8" Zero deg. phasing Val\e3 EnerJet (7338-7339, B§í1.lIlmliII' 004.750) St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt Gas lift 1 3056 2573 Cameo KBMG DMY 1.0 BK-2 0.000 0 3/5/1987 3ndrel/Oummy 2 5926 4106 Cameo KBMG DMY 1.0 BK-2 0.000 0 3/5/1987 Val\e4 3 7338 4894 Cameo KBMG DMY 1.0 BK-2 0.000 0 3/5/1987 (7968-7969, 4 7968 5247 Cameo KBMG DMY 1,0 BK-2 0.000 0 3/5/1987 00:4.750) 5 8505 5550 Cameo KBMG DMY 1.0 BK-2 0.000 0 3/5/1987 6 9040 5842 Cameo KBMG DMY 1.0 BK-2 0.000 0 3/5/1987 7 9608 6146 MMH 2.875x1.5 DMY 1.5 TG 0.000 0 3/28/1987 Gas lift tMl£fflllì __I? 3ndrel/Oummy Depth TVD Tvpe Description ID Val\e5 1819 1750 SSSV Cameo'TRDP-1A-SSA' 2.312 (8505-<1506, 00:4.750) 9657 6172 PBR Cameo 'OEJ' 2.297 9674 6181 PKR Cameo 'HRP-1-SP' 2.347 9692 6191 NIP Cameo 'D' Nipple NO GO 2.250 Gas lift 9704 6197 SOS Cameo 2.441 3ndrel/Oum my 9705 6198 TTL 2.441 Va¡\e6 (9040-9041, Depth I Description I Comment 00:4.750) 9924 11 1/2" DMY Iln Rathole Gas lift 3ndreliDummy Val\e7 (9608-9609, 00:5.500) PBR (9657-9658, 00:2.875) PKR (9674-9675, 00:6.151) ¡ NIP (9692-9693, 00:2.875) TUBING (0-9705, 00:2.875, 10:2.441) SOS (9704-9705, 00:2.875) Perf = (9767-9830) ~ Perf =,' (9770-9830) - -~ """"'" - ... === = """, '" ". MEM ORAND UM State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp Petroleum Inspector DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests CONOCOPIDLLIPS ALASKA INC 3Q-O5 KUPARUK RIV UNIT 3Q-O5 TO: ~~ s~~~sor ?~19Jt ZA /ù'r Src: Inspector Reviewed By: P.I. Suprv :5ß{!--- Comm Well Name: KUPARUK RIV UNIT 3Q-05 API Well Number: 50-029-21684-00-00 Inspector Name: John Crisp Insp Num: mitJCrO40810171749 Permit Number: 186-196-0 Inspection Date: 8/8/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-O5 Type Inj. N TVD 6431 IA 100 2410 2310 2300 P.T. 1861960 TypeTest SPT Test psi 1545.25 OA 50 50 50 50 Interval 4YRTST PIF p Tubing 3075 3075 3075 3075 Notes: NON-CONFIDENTIAL Wednesday, August 11,2004 Page 1 of! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 59 feet 3. Address P_ O. Box 100360 Anchorage, AK 99510-0360 Exploratory __ Stratigraphic _ Sewi~__X 4. Location of well at surface 2221' FNL, 2279' FEL, Sec. 17, T13N, RgE, UM At top of productive interval 951' FSL, 3545' FEL, Sec. 18, T13N, RgE, UM At effective depth (asp's 516057, 6025849) 4452' FNL, 3851' FEL, Sec. 18, T13N, R9E, UM (asp's 509218, 6023608) 12. Present well condition summary -I'otal depth: measured true vertical 101 45 feet Plugs (measured) 6432 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-05 9. Permit number / approval number 186-196 / 10. APl number 50-029-21684 11. Field / Pool Kuparuk Oil Pool Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 1875 sx Pole Set 115' 115' SUP,. CASING 4996' 9-5/8" 130o sx AS iV & 340 sx Class 6 5055' 3647' PROD. CASING 9972' 7' 300 sx Class G & 175 sx AS I 10031' 6371' -:~ M~ :. :~..D..~..;.':.~:~"-2'.'~,~ :.:,'.'~1~ :-~ 8.-'~g!. :. M D:-~. :. :, :.:. :-:-:. :. :. :. :, :,:.:-:.:. :. :-:-:. :. :.:. :. :.:.:-:. :. :.:.:. :-:. :. :. :. :. :.:. :. :. :-:. :-: .:. :-:-:-:.--:. :-:. :. :, :. :-:. :. :-:. :. :. :. :. :. :.:. :. :. :. :. :, :. :. :... :. :. :. :. :. :. :. :: i: :: !:i: !:i: !i;:::i:!:; :;: i: i:i:;: i: !: ;: !: ?!?~! E: E: !: !: i:i:i: ;: !: i: i; i'-!; ~-' ~; ii ii E:i: !; i ii~i: i: !~ !i ~!i ii ii!iii!i 13. Stimulation or cement Squeeze summary 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X i7. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~-A- ¢,~~-~ Title Production Engineering Supervisor JaffA. Spencer Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Questions? Call Jeff Spencer 659-7226 Prepared by Robert Chfistenser~ 659-7535 SUBMIT IN DUPLICATE 3Q-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALAb'r,~ OIL AND GAS CONSERVATION COMv._.~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360: Anchorage: AK 99510 4. Location of well at surface 2223' FNL, 2280' FEL, Sec. 17, T13N, RgE, UM At top of productive interval 954' FSL, 1531' FWL, Sec. 18, T13N, R9E, UM At effective depth 859' FSL, 3677' FWL, Sec. 18, T13N, R9E, UM At total depth 798' FSL, 3836' FWL, Sec. 18, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 60' 6. Unit or Property name Kuparuk River llnit 7. Well number 3Q-05 8. Approval number #7-809 9. APl number 5O-- 029-21684 10. Pool Kuparuk River Oil Feet 11. Present well condition summafr~ Total depth: measured"-', 145' MD feet true vertical6420' TVD feet Plugs (measured)NOne Effective depth: measured 9944' MD feet true vertical 6313' TVD feet Junk (measured) None Casing Structural Conductor Surface Production xxx xxxx Perforation depth: Length Size 80' 16" 5019' 9-5/8" 9996' 7" measured 9767' -9830' MD Cemented Measured depth 1875 Cf Poleset 1300 SX AS IV & 340 SX Class G 300 SX Class G True Vertical depth 115' MD 115' TVD 5056' MD 3642' TVD true vertical6230'-6263' TVD 10,031' MD 6359' TVD Tubing (size, grade and measured depth) 2 875" J-55 with Tail (a 9705' MD Packers and SSSV (tyRe and measured depth) HRP-1-SP pkr @ 9674' & TRDP-1A-SSA SSSV @ 1819' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 450 BOPD 700 MCFPD - BWPD 750 psig 130 psig Subsequent to operation 1000 BWPD 850 ps i g 1.1 Or) p, i g . 14. Attachments Converted from oil producer to water injector on 11/20/87 Daily Report of Well Operations I~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ , . Title Sr. Operations Engineer Date 2/25/88 Form 10-404 Rev. 12-~-8~ Submit in Duplicate ARCOAlaska, In¢ ~ S,~bsidiary of Atlantic Richfield Compan~'''~'' WELL SERVICE REPORT IDATE r"-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I TemP'Report 'F I Chill Fact°r [vlsibility°F miles Wind Vel. ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: December 10, 1987 Transmittal # 7027 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. 3Q-5 Kuparuk Well Pressure Report 11-19-87 Otis Static Anchorage Receipt Acknowledged: DISTRIBUTION: Date: D & M e ~-!0~ : BPAE Chevron Mobil Unocal SAPC ARCO Alaska. Inc. is a Subsidiary of. AtlanticRichfietdCompany ! , ARCO Alaska, Inc Post Office~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commi s s i oh Dear Mr. Chatterton' _. Attached in triplicate are multiple on Kuparuk wells. The wells were listed below. Applications for Sundry Approvals both conversions and fractures as Wel 1 Action Anticipated Start Date 2A-3 Conversion October 19, 1987 2A-6 Conversion October 19, 1987 2A-7 Conversion October 19, 1987 3K-15 Conversion October 15, 1987 3N-4 Convers i on 3N-5 Conversion 3N-11 Conversion October 15, 1987 October 15, 1987 October 15, 1987 3Q-5 Conversion 3Q-12 Conversion 3Q-15. Conversion October 15, 1987 October 15, 1987 October 15, 1987 If you have Sincerely, any questions, please call /Y~~llwood G. B Senior Operations Engineer GBS'pg'0117 Attachments cc' File KOE1.4-9 me at 265-6840. RECEIVED OCT 1 6 198'1 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALA~,.~A OIL AND GAS CONSERVATION CON~,,,,-ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~1 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [~1 Change approved program E~ Plugging [] Stimulate [] Pull tubing E3 Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360~ Anchora§e~ Alaska 99510 4. Location of well at surface 2223' FNL, 2280' FEL, Sec. 17, T13N, RgE, UM At top of productive interval 954' FSL, 1531' FWL, Sec. 18, T13N, R9E, UM At effective depth 859' FSL, 3677' FWL, Sec. 18, T13N, R9E, UM At total depth 798' FSL, 3836' FWL~ Sec. 18~ T13N~ R9E~ UM 11. Present well condition summary Total depth: measured 10145' feet true vertical 6420' feet Plugs (measured) 5. Datum elevation (DF or KB) RKB 60 6. Unit or Property name Kuparuk River Unit feet 7. Well number 3Q-05 8. Permit number 86-196 9. APl number 50-- 029-2]684 10. Pool Kuparuk River Oil Pool None Effective depth: measured 9944' feet true vertical 6313' feet Casing Length Structural Conductor 80' Surface 5019' Intermediate Production 9996' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Junk(measured) Cemented Measured depth True Vertical depth 16" 9-5/8" 7" 1875 # Poleset 115' 115' 1300 Sx A.S. IV 5056' 3642' 340 Sx Class "G" 300 Sx Class "G" 10031' 6359' 9767'-9830' MD 6230' -6263' TVD Packers and SSSV (type and measured depth) HRP-I-SP pkr @ 9674' & TRDP-1A-SSA SSSV @ 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Convert to ~ater injection. 13. Estimated date for commencing operation October, 15, 1987 14. If proposal was verbally approved Name of approver Date approved Signed15' ' hereby certify that ther'f°reg°ing is true and c°rrect t° tTest °f mY kn°wledge/~,~ A X~'''l'''vt~'cf~/~~f'f~ Title ~f~/Z,/~ ~._,< .~..~ ~'"~ Dat/'b.~~ Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date//~ -~;,~(~ .--¢¢/'~ Submit in triplicate 1. Status of Well Classification of Service Well OIL J~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .i 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-196 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21684 , 4. Location of well at surface 9. Unit or Lease Name 2223' FNL, 2280' FEL, Sec.17, T13N, RgE, UM Kuparuk River Unit '10. Well Number At Top Producing Interval 951' FSL, 3545' FEL, Sec.18, T13N, R9E, UM 3Q-5 At Total Depth 11. Field and Pool 831' FSL, 3845' FEL, Sec.18, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 59'I ADL 25512 ALK 2553 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore f 16. No. of Completions 01/20/87 01/26/87 04/27/87*I N/A feet MSLI 1 , 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. D~,ectional Survey I 20. Depth where sssv set 21. Thickness of Permafrost 10145'MD, 6431 'TVD 9944'MD, 6324'TVD YES I~t NO []I 1819' feet MD 1600' (approx) 22. 'Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR/FDC/CNL, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD ..... SETTING DEPTH'M'D CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6" ' 62.5# H-40 Surf 115' 24" 1875# Poleset 9-5/8" 36.0# J-55 Surf 5056' 12-1/4" 1300 sx AS IV & 340 sx Class G 7" "26.0# J-55 Surf 10031' 8-1/2" 300 sx Class G & 175 s.~ 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) 9767'-9830'MD perforated w/12 spf, '' 2-7/8" 9705' 9674' 6230'-6263'TVD @ 120° phasing "~61 ACID, FRACTURE, CEMENT SQUEEZE, ETCi' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED . , , See attached Addendum, dated 9/28/87.~ 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 F~RODUCTION FOR OIL-BBL GA$:MCF WATER-BBL' CliOrKE SizE I'GA~-oIL.'~ATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BB'L GAS-MCF WATER-BBL' OIL GRAVITY-APl (c0rr) ..... Press. 24-HOUR RATE Jl~ .... 28. CORE DATA ,, , Brief description of lithol0gy, porosity, fractures, apparent dips and presence o~ oil, gas or water. Submit core chips. None Alaska 0il & Gas Cons. Comrniss!l *Note: Drilled RR 1/27/87, Perforated well & ran tubing 3/5/87, Fractured well 4/27/87. Anchorage Refractured well 8/11/87, , , Form 10-407 Rev. 7-1-80 STATE OF ALASKA ALASKA'OIL AND GAS CONSERVATION L,~OMMISSION WELL COMPLETION OR RECOMI LETION REPORT AND LOG ? WC3/Si :DAN i Submit in duplicat~ F CONTINUED ON REVERSE SIDE /, 29. · ~ 30. i . '~FORMATION TESTS GEOLOGIC MARKE S NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9763' 6227' N/A Base Kuparuk C 9768' 6230' Top Kuparuk A 9768' 6230' Base Kuparuk A 9872' 6286' 31. LIST OF ATTACHMENTS Addendum (dated 9/28/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~_~ ~)t')~/~(~.- ~.~'~'?~ ~l~,~ ~ Title Associ ate Engineer Date /0-/1~'-~:3~ 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- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3Q-5 4/27/87 Frac Kuparuk "A" sand perfs 9767'-9830' in 9 stages per procedure dated 4/24/87 as follows: Stage 1: 40 bbls 140° diesel w/5% Musol @ 4 - 5 BPM, 400-5530-4780 psi Stage 2: 125 bbls gel diesel @ 8-10-20 BPM, 6150-6800-6120 psi Stage 3: 155 bbls gel diesel @ 20 BPM, 5930-5650 psi Stage 4: 11 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 650-5550 psi Stage 5: 309 bbls gel diesel @ 20 BPM, 5550 - 5700 psi Stage 6: 19 bbls gel diesel @ 2 ppg 16/20 @ 20 BPM, 5700 5540 psi Stage 7: 18 bbls gel diesel @ 3 ppg 16/20 @ 20 BPM, 5540 5530 psi Stage 8: 35 bbls gel diesel 4 ppg 16/20 @ 20 - 18 BPM, 530 - 6690 psi Stage 9: 5 bbls 5 ppg 16/20 @ 18 - 15 BPM, 6690 - 7800 psi Screen out to 7800 psi. Fluid to Recover: Sand in Zone: Avg Pressure: Sand in Csg: 717 bbls 500# 100 mes and 2000# 16/20 carbo prop 5700 psi 5700# 16/20 5/15/87 7/21/87 8/02/87 RU CTU & tst; OK. RIH & CO to 9900'. Pmp total of 250 bbls gel/diesel; rec'd 240 bbls. Back flush w/80 bbls diesel; rec'd 75 bbls. Pmp'd @ 1.5 BPM, 4000 psi. Turn well over to Production. RU CTU, RIH, start gel diesel @ .5 BPM. Cont in hole to 9700', in¢ rate to 2 BPM, 4000 psi. Wsh heavy sand f/9700'-9970' CTU meas in 50' intervals w/no back press. Circ 75 bbls cln gel diesel on btm. Displ w/80 bbls cln diesel, POOH, RD CTU. Turn well over to production. RU CTU, CO well. Displ w/cln diesel & N2, POOH. .RD & release well to Production. · ~ask'a Oil 8, Sas Oo~s. Oommiss~ ~chorage ADDENDUM WELL: 3Q-5 (Cont'd) 8/11/87 Re-frac Kuparuk "A" sand perfs 9767'-9830' & 9770'-9830' in 10 stages per procedure as follows: Stage 1: 97.7 bbls gel diesel @ 18 BPM, 6400 psi Stage 2: 302.4 bbls gel diesel @ 20 BPM, 5930 psi Stage 3: 20 bbls gel diesel 2 ppg 20/40 mesh @ 20 BPM, 5930 psi Stage 4: 40 bbls gel diesel 4 ppg 20/40 mesh @ 20 BPM, 6230 psi Stage 5: 40 bbls gel diesel 6 ppg 20/40 mesh @ 19 BPM, 6800 psi Stage 6: 40.3 bbls gel diesel 7 ppg 20/40 mesh @ 17 BPM, 6780 psi Stage 7: 20 bbls gel diesel 8 ppg 20/40 mesh @ 18.5 BPM, 6740 psi Stage 8: 10.2 bbls gel diesel 9 ppg 20/40 mesh @ 18.5 BPM, 6760 psi Stage 9: 12.4 bbls gel diesel 10 ppg 20/40 mesh @ 18.5 BPM, 6800 psi Stage 10:56.3 bbls gel diesel flush @ 19.5 BPM, 6500 psi Fluid to Recover: 601 bbls Sand in Zone: 34,141 20/40 mesh Avg Press: 6700# Sand in Csg: 1177 psi - 'D~illing Supervisor Oil & Gas Cons. Commiss r Anchorage STATE OF ALASKA (~//~ ALASKA'OIL AND GAS CONSERVATION C~lvlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-196 3. Address ~ ~ 8, APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21684 4. Location of well at surface 9. Unit or Lease Name 2223' FNL, 2280' FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 951' FSL, 3545' FEL, Sec.18, T13N, R9E, UM 3Q-5 At Total Depth 11. Field and Pool 831' FSL, 3845' FEL, Sec.18, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 59' ADL 25512 ALK 2553 12. Date Spudded01/20/87 13. Date T.D. Reached01/26/87 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns04/27/87* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10145'MD, 6431 'TVD 9944'MD, 6324'TVD YES ~ NO [] 1819' feet MD! 1600' (approx.) 22. Type Electric or Other Logs Run D I L/SFL/SP/Cal/GR/FDC/CNL, GR/CBL/CCL, 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" 1875# Pol eset 9-5/8" 36.0# J-55 Surf 5056' 12-1/4" 1300 sx AS IV & 340 sx (lass G 7" 26.0# J-55 Surf 10031' 8-1/2" 300 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) 2-7/8'' 9705 ' 9674 ' 9767'-9830'MD perforated w/12 spf, 26. ACID, FRACTURE, CEMENTsouEEzE,ETc. 6230'-6263'TVD ~ 120° phasing · DEPTH INTERVAL(MD) AMOUNT& KINDOF MATERIAL USED See attached adde~,dum~ dated 5/5/87 for fracture ata 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE siZE ~GAS-OILRATIO TEST PERIOD ~ I . Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · NOTE: Drilled RR 01/27/87. Perforated well & tubing run 03/05/87. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate¢ GEOLOGIC MARKERS' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9763' 6227' N/A Base Kuparuk C 9768' 6230' Top Kuparuk A 9768' 6230' Base Kuparuk A 9872' 6286' , 3:1 LIST OF ATTACH E M:NTS AacTendums (dated 3/19/87 and 5/5/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,0~(_,..,. ~_~' Title Associate Engineer Date -~ /'~.~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 ADDENDUM WELL: 3Q-5 4/27/87 Frae Kuparuk "A" sand perfs 9767'-9830' in 9 stages per procedure dated 4/24/87 as follows: Stage 1: 40 bbls 140° diesel w/5% Musol @ 4 - 5 BPM, 400-5530-4780 psi Stage 2: 125 bbls gel diesel @ 8-10-20 BPM, 6150-6800-6120 psi Stage 3: 155 bbls gel diesel @ 20 BPM, 5930-5650 psi Stage 4: 11 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 650-5550 psi Stage 5: 309 bbls gel diesel @ 20 BPM, 5550 - 5700 psi Stage 6: 19 bbls gel diesel @ 2 ppg 16/20 @ 20 BPM, 5700 5540 psi Stage 7: 18 bbls gel diesel @ 3 ppg 16/20 @ 20 BPM, 5540 5530 psi Stage 8: 35 bbls gel diesel 4 ppg 16/20 @ 20 - 18 BPM, 530 - 6690 psi Stage 9: 5 bbls 5 ppg 16/20 @ 18 - 15 BPM, 6690 - 7800 psi Screen out to 7800 psi. Fluid to Recover: Sand in Zone: Avg Pressure: Sand in Csg: 717 bbls 500# 100 mes and 2000# 16/20 carbo prop 5700 psi 5700# 16/20 Drilling Supervisor Date ADDENDUM WELL: 2~27~87 2/16/87 3Q-5 Arctic Pak w/175 sx AS I & 60 bbls Arctic Pak. RU Gearhart, rn GR/CBL/CCL f/9941'-7809'. Rn gyro. Rn JB/GR to 9946', RD Gearhart & wait on compl rig. Drilling Supervisor' ~ ~ate February 26, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70017 Well: 3Q-5 Field: Kuparuk North Slope, Alaska Survey Date: February 15, 1987 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NI. Sperry-Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 D I~ .~. [~ i ~! [: hSPERRY-SLIN WEI_L ::;IIRVEYING COMPANY 'L"%. L I ¥ ~.~/ ...................... "':: .... '"-- ANCHCIRAGE ALASKA ARCO ALASKA, INC. :3e-5 APR 0 KLIPARUK '~C.A'~[A' ...................... Ataska'-'O,""&'-'Gas Cons:' Commission ........................................ Anch0ra~e .......... ':'7:VER¥iC'AL SECTION CALCULATED ALONG CLOSURE COMPIJTATION DATE ........ ~'~_BRI-IAR~" 15'/:'--~'9;:=:7 .. DATE OF SURVEY FEBRUARY 15, 1987 BOSS GYROSCOP I C__-S_:_L!R_V._EY ............... · ...lOB NUMBER AK-BO-70017 KELLY BUSHING ELEV. = 59.00 FT. OPERATOR-MCGU I RE "~EF TH 600 700 ,_ C)Q ......... 90C) ........................ .1:000 TRUE SUB-SEA L._ LIRoE VER T I C:AI'7 ...... O'E::'RT':I' ~_~.~A-~_ ...... I NcL'I N~?'I Oi~i .... . . DEF'TH DEPTH DEG M I N .................... 6': 00 -59. oo 100, 00 41.00 200, 00 141, O0 -:}.':00'-: 00 241.00 400.00 '341.0 C) 4. 99.9'.-? .......... 440.99 1 I00 C I ...'00 I 190.97 11 ":-' 1 97 · -.'q5 "' '-"-' . :. 1:300 1.~. ...... 60 1 ~...-6.6::-: 1400 1378. '78 1 '-' .:, 19.78 1500 147(:). 42 1411.42 .......................................................16(:)0 :t 5/_-,C.D.._-,._,'"' ~ ...................... l~"='._,.(¥'ii ....... ':;"5.:,._ ..... ...................................... . l o,--, ..~, 37 :<::::.::::,-.:..:.~.~,~ 17:_::4 '-'.=, ................... . .:,._ 1675. .:,._, "'::"'::":::::::':'i"i:::::'"!' ":! -.':000 1,~,'::" 17 , c,.." '" 1 ,-'7.-=;,°._ ,_,, 6:-7' .~. :i :'::.: ::::.::.:i :: .:... :.: * .... · "' ' - ' ...... ::.57'.7/_, '""-'"" zOO0 J. 8 1 76 ............................... :2Y'i50 ....... i 9 7`5.2.'5: ............... i'91'~, .'":,:'!3"' ~ "~" ?~. :::!::i:'~ ~.::z--, .,, c, ,,.:, ., ,., :;.: 1'!~ ~-~ ,:,0. . ~_'-, <:)6' ~.'-',. 90 .~400 2'. 1 'Pi'). '-'~ .... .~.o 21.'-';1 2,500 2,<.._ 4 96 195, 96 ........................ ..... !'.2/-, Cx-~') 2 .'.5: i-6': ":'... 1 .,'? .... '? :57.21 .......................................... 2700 2:::.:74., 'PO '--":' 15.9(:) .......... i~ ' ";'::::(') ('D 24:32. () c:, 237:3 08 C:OURSE DOG-LEG TOTAL D I REC:T I ON ....... S~VER I'TY RECTANGULAR COORD I NATE:.:; DE:GREE::; DEG/100 NORTH/:=;OLITH EA:$;T / WE:=;T 0 o N .... 6':" 'b-~ ................ 0 4 Iq 9 '-,':" · :, Y W 0. ' "" · . (.)o 0 q N '-~"-' .:,~ A9 E O. 10 '-CT-'-f'g ............ 'gl ............ 'i. 1-:? E .........0, 17 0 26 N '..'/ .: (.) W 0 1:3 0 '-'(' · .r, .) N '-"-' . . z..:,. 6'P ~ C) 0. O0 0. O0 0.07 N 0,01 W 0.24 N 0.0o, E 0.58 N O. 11 E 1.1'.-? N 0.06 E 1.98 N 0.19 W ,, ;,,. :..:.---~5 VERTICAL SECTION .'=;';,':'/" 'P9 =- (' ~ "' '? ..... q':/ "' ..................... :5 ":'o '-'" ..,7 N 0 79 .:,4":/;'0.-.-.5 ................ 0 ......... i~'i ............... ,, ,_,,_- .... .-. w t ,-. = ,-- ...o . . . · ._1 i_1 · 699 '- =' .... . ;,._, 640.:-T,5 '-.--' 10 S 6:3 69 W 1:37 1 .91 N '2 91 799, 71 740.71 .=i '"/ '-' 6.'_:: 60 W :3 4:3 1 10 g ,.-..,'-' ':~:-q.. ,.. ._ ._5 L~, ..., . · - - , % E: 49-. ,, z~.:-';-... ............. 7 ¥":: (.) ........... 4- :=;..: ..................... 6 .:,:::~'._, .......... S 60. F,_ C). W ..'-.'. 09 ,.,":'. 60 ...,o 1 .'_::. 6, 7 8 ':.?.. '-:',.. 01 840. C) 1 :::: (')_ S /:, 2 . :'::._ 9. W 2 . :38 6 .62 .=,'-' 19. ..--'-'. '=._, '.-797 .=i., c, ,:~.-,,-, .=,-:, c. . .... , - .-, --, o =..' , ..... , · ._ .. .-..:,,: ...... 11 40 ./:.,...(:_,.~. 1.0. W.:, · 7z. .1..:,, .'...., c, .:,4. ,'_',8 .... :i ()'}2j:'~,.-,>;";;-- 'o ' Tx:=;'~'--;~; i5',. ~.,._', ._,. o ,.., ................ 1:'4 40 :3 68. ._"q':~.. W ._,':'. (:)4 =":'"".~.. 7.,':'-' "'..-., .=;, ='._ ._,, 72 29.._,':,'-.',. S 70 .19. W ~.,'-'. 46 1(')2,. :3`5 o'-' 45 21 S 71.50 W 2.38 11~.07 S 316.74 W W .',./',o 1.:,--,..6 ;=, .:,/_',.-..44 W 72. q c/ .-, --, .~'=' ',';,_ ,---. .-, ,::, ........ '7" . .......................... .-.. ......... ..-. ............................................................. 73.6.0 W 2.73 1 .... :,. lb: ._, 426.70 W 7:3.6, 0 1.4 :2.27 171.0:3 :_:; 4 :.-37. :34 W 73 :::::9 W 2:42 1 :::o..=i.,':' ':' "'i ~': C) 1 W '7:3.80 W 2.59 :2(.]:3.92 S 617:30 W 516.34 4:_:,' 24 S 73 .... :::¢) W o'-'. 06 ~..- ,-""°o .28 .=,"' Pi(') '='= ... 2.5'3 .... ,._, S 7:.3. :q':;' W 250.8.0 S .=i ':' '-' · :, 1. :'_'-:; '7 Cf: 19 W 5:..' /',C) 27:_:: '":;":' S .. . · .. 54 3 ./:, S '7:3.8':7, W I. ":"z' 296,. 4. 4 S I:;:' .... , :3'7 S '7 4. :}.i 5:' W J · J. ("D 3 J. 8. :E:4:3 ................ /:,87 ,-,o .... . ,:,,.=, W ::!:!: · '::vs:,,.;¢ ':' ,. ::,: 7/:_,g....?_:~ ,W, .' "., eo I ,:.2~. ':":'/' 69 W ~'-'0 '~ i..., ....i ~1. 914.34 ~ 961. 1~ ?';~:::. 25 w ..10..43.1_~_ ......... .. ARCO ALASKA, INC. 3Q-5 KUPARUK ...... SPF..RRY-S!..IN WFI. I.. 'F;IJRVE¥INr~ Ci3MPANY ANCHORAGE ALASKA COMPUTATION DATE FEBRUARY 19, 1:987 VERTICAL SECT'II~iN CALCULATED ALONG C'~{_n]SO-R~ ......................................... !;>Z:/,i? :::..':: :: . ~ :%'.~'~?: ::' · TRUE SUB-SEA COURSE COURSE DOG-LEG ~SASURED VER T I CAL VERT I CAL I N c'L"f~'~¥~F~ ...... ~'i R~'I i~i~ ...... ~i~VER l TY - ~.2PTH .............DEPTH " DEPTH DEG MIN DEGREES BEG/100 DATE OF SURVEY FEBRUARY 15, ........ I~87"~:':~:'~.~i~'i~ Bubo GYROSCOPIC SURVEY dOB NUMBER AK-BO-70017 KEI~LiY 'BusHINO ELEV.' = '"oPERA TOR-MRGU I RE TOTAL RECTANGULAR C:OORDINATES NORTH/SOLITH ...... EAST/WEST 5'-2. O0 FT. VERTICAL SECTION :: :.:. :::~:.~'?'". 3100 ,,. :, ¢ '> <,:~:'~:.,:.,s:>...,: ',... - - 3200 ...... ': ..... ~:':":' "'3400 ......... ~i7._,4 ''~ ..... ........ 9500 o,:,0,:, 3600 2860 .-.4o,:,. 04 2429. (.]4 56 19 S'' ~'~:-'i'9 'W o. 'gA 340 57 S · -,5 '-, - . oy W 1 11 361 44 S · -'..4..'.81 24t=:3 81 57 15 S 75.'~- . . · . .:.o I 75 S '--'='-" 18 ~._,o7 1~: 5H 13 S 76 '--'C . ..- ._! .'.~ ~. '--~'~- '~ - - · ..JJ W 1 (]2 '-"-' "2/_-,481/::2 :":->._,.. :,. .................. .... =,:-"'_-. .............................................. s 7 ?.' 0 w 0".]:7 ..................... 6177"; 'r "zg ......... 2701 14 '.-,642 14 ~'-' '-' · _,z, 7 '-' ' F, .... =, Z,. 5C) W 1 34 421 64 ~ · · ._l 2727.'-"-' .......... ~'/- ,--, 'qc, - --, -'._.6,_-. 57 21 .'.¥ 74 ?:'9 o._', W 41 432.61 S 75 .-,,,'.,,r,~ 75 ' '~'" ' .... ' '-'"' " '---"-' 57 ._-~ 0 .:, 7._-,, ,:, ::~ W 0. o ~ 444 12 S ,~:,, ,..,, ,~ '.,.,' i I · ~ Pi '-'. · - 1.5 :.-.'749 15 ._7 ._6 ;_~74 ~,~ W 0 81 467,00 ~ 67 .7,,=, - ?;,_-, · --~,01.67 ._,_, 40 S 75 ...... 30 W 0.:::'~ 489 ta]'-" o '~ 1073.23 W 1154.24 W :lSO~-~!ili::?.::i:!"': 1 ':'::!6..._ :S___u .......... :i ====================== 1319.17 W 137e,64 i 4o i. 8:2 w ........... --f'zP:,-gTS'6 .............. 1 65 w .................... ..... 1-'4:Z:3. 1:3 W 1564.58 W 1' 63'2 1646.77 W IYI7.27 37 O, 0 2'P 12. · ~ ---i" .~......~.... ~ .:, 7 .:, 0 .::, ,:~ .';, :zl. .:, o 00 2964. ~ 3900 :3019. 4000 3076. ,.(~. 4100 31:33. .......... , ...... 4 ~ .)0 :3188'. 4225 3202. 4300 :::243. o.. :::_ 2869.0 :.-3 5:3 4 '? S 76 . 0 W 0 ,, .2'..-,.. ._,""- 16, · 51 '..-]; 17 Pi._ 4.4 '7 88 2_905, :--::--: ."_:;7 45 S 76.8':? W 1.88 5:30, 46 :_:; 1812. :36 c,":'-':O ...... -:~--:----;s":...-. 60. o 0 ................ ._,a'.'e..., ..... ._-:~;;7 ................. ,:,'"' ........ 74.6 ;..-~:: ................... W '-",: .... -",5':1 ...................... .~'~-' ';:--:5., ._, ¢.). -. ....... 4 ;~o ......... l ;s;":5,_, ~ .... .... 37 W '."55 '-'" -='= oO 17 · ......,1 ..° S 72. '"0 972 ,:,. W 1 62 57:3.97 S 1 40 W 24 3074.24 ,~= 43 '-' 73. =' 92 _ .... c, R7. S '.-'Cx~ 1 22 ,_.~ ,=, :~9 W 0 71 .... W ::: 9 '--' 129 o c ~.]/. c,,:, · _, ~,..~ ........... ~.--.; 7.'.:.: '-'] q · oC W 0.99 621 ""'-' ...... o o ._ 2 :l..'7.':0 "? :.-'." W . ,:.~ ,-, - _ =- / ,-.- ._ ,:, 314:3.5,~-: ._, .-, 57 S '7:3 . :::_ 9. W 1.28 627 19. :3 21 .:, 1.01 W ....................................... o._ lo4 ')= Z_-,44'~ '-=5 c._-, 57 4.'.:.: S 74, 19. W 1 . C):--,'.. _ ~,._ :--: ~...'-"-' :l 1 · 7.':: W 2302,63 -':. ·::.:,:<::,. , , .., :~:. 26 · ..: :~ o~ ,_, 56 2;6 '-' :, 72 60 N _t 75 ~6,:, 54 24 N I II 0 · .~ ._--'.~-, [..' ,:,:, ._,71.:,C W 1 48 6.~4c/:.~ ~ 2371 16 W .,,~:.~' . ~:~ ._q=o o.J4'-"~' '"~ ~"~ 56 '-"' S ........ ,=,._ ~, 171 . A9 W 0 90 ?'.'.'0 58 S 2449 '~'-' :34~;ji"~ 1,9 ..... :~:404 1 '9 .... !~;'~ .... !~?~- ........... ~i"-~'~-~']~-i~?---i~ 1, ,:. ._'":' =; 746 ,44 .c;._ 2529, 69 W 2636, 52 ................. · -,. ......, 1606 '-'.'_-, ~._ 75 ......... 06 P?::' :_--::,.-7S 7'.7_'.5(.'.') W 0.9i "7'~'2"~'i}';'%"i~i ................ 2610 .62 W 2721 , :::h]A7 .... . ._5i'~;o ................ .:,:s'R"~.."e" ' ":;'-'-_ '.. c ..... =. .....'9;, ,.":'.'"]._ S 7"-' .... . ~ '-.--'. W 1 . 07' 7 ................................ 97 . :--:_ o. S ..,__,.. ~.._ .5/. o-7 '"'"il W 2007.00 3618. ' '"* 355'9.63 ._,='-Y 0 '-' ~' '---"- '"" ,':,o .... ,_-, 1 .:, .-.- 1.51 S 2775.02 W : ~'-, ' .,.:.:::.~,~:'' ' ......... :;:-::'" '.'" '---' 63 W :'::/-,Ag. ,_,..'::5 .=,610. :-~5_ _ ._ .- 11 S 74 . 19. W O. 09 844 .97 ~; ..'o._, :::7":',~. 1 ....... ,:..':-7,..,, o66..'"--' '-' .d~ .... .'=;':'~0 ...,,z. 73 . :::'9 .... W 0 ._,.~.c:":' ooo'-'~ ':", 54 .:,'-' .'-"~"-Y40 . 1 ..~'-' W o,oo,~.'~"""", :::77~7:': 0'6 ........ -}~-~'T'~:~i~J'~i' .............. 5i:--.i .......... ?,7~; .................. S"73': 39' W .................. '0'· 57 :.:.:92.63 F-; 3022.2? W :3150.11 '-"-"-'"" P:':: .... ::10:.3 ;:::'.'..? W ~--'.=~5 40 · -----,.c..., 1:3 ..... 3766 18 :27 :.z.: 7:::. 0 {4 0 :::,':':: ':?17 :d::.~ c. .-_,.-,._-, ....... ~ - # '- ~-.' · .' I, ,_~ '-- - · # ,- . :ii{: 877.90 :'=: 81 :=2: .90 ..'":; .... '7 F:; 4 :S; 72 . ::::_ 9. ~ 0 ..... F, A 942 .20 S 3 ~ .-,'"".J =' . 12 W ~o<0'~ '~''' '. 36' · . 4600 4700 4900 ' ""' ................... 000' .~ O0 ~00 5:_'-:00 · - ..,0( ) :ii:ARCO'~ ALASKA, I NC. KUPARLIK ALASKA ::i;I'"'I":'I";;!5:_Y.:':SLIN WE:iLL '.':;UI:(V[':Y I NO CnI'II':'('tNY ANCHORAGE ALASI<A DATE OF SURVEY FEBRUARY COMPUTATION DATE BOSS GYROSCOPIC: SURVEY FEBRUARY 19, 19:-_-:7 ,_lOB NUMBER AK-BO-70017 KELLY BUSHING ELEV. --'- OPERATOR-MCGLI I RE VERTICAL SECTION F:ALCULATED ALONG CLOSURE -/~' ' 'ASLIRED._.~.: TRUE . _.~!J B~.S_EA ...... C:.O!_JR..'S E .................................................... VERT I r:AL .. VERT I CAL. I NCL I NAT I ON DEPTH [. EF 1 H nEPTH DEG M I N ............................................................................................................ 59. O0 FT. C:OLIRSE DOG-L. EG TOTAL I REF:T InN ....SEVER'l Ty ........ F~-EC.TANGU.L..AR .......... CL]OR[~ INA TLS ............ DEGREE::-: DEG/1 O0 NORTH/SOUTH EAST/WEST SECTION ..... 5700 5900 6000 6100 ::::::::::::::::::::::::::: :- :.._.~ ~'- ....... · ,.:~ ,.~.':?::: ::. .... ... 6300 ....... - 6400 6500 6600 ........................ 6 'I 00 6~0(.. C 6900 7000 :~'-?::: ~ 03 'W"-"-.' 0:3 . -- ~. ,--*/,*:.. m :3'.-:, 84:27 'q'--"-' =- · ,...--..'-..,. 27 "~j .--I I i 4c._-,7 7.9 3978 ?.9 l'4 o S,'l '· 5B ........ -~'(]!i:-~ ~':'S'~ ......... 4145 =''-' ........ 408/-", 52 . ..-J .,,. · ........... 41.99.70 414C). 70 57 45 S 72.60 57 31 :--; 72.5(:) r_- - · _, 7 ..._ S "'72. ,_'-, 0 57 15 8 72. :30 57 7 S 72. 10 4254.15 4 ....I-'~.. ........... 5.1 ._,~' ........................ .:,6~: ............. ._,._.,~':s .................... .-_,"~' ....... 7~:-; ...... 1 0 4.:,Oo. 91 4249 ~-.? 1 =,'<. ..... ,:, 41 '-' o 72.10 4364.00 '-' = ._, 4o0o. 00 =/' '--'/- . -44. l':?. 4:'.]:7 ............... 4'~:~15:"~:~, ................ 56' ..... 10 s 7 ~. ,,-..'? 4.47P] '26 4416 26 K;5 ='"' . ........ 4._=; ._,':' 1 .4. 6 4472.4/:.,. ._,"-' ._, ~'- :.--.: 7 S 71 . 10. a ,=;,::, o -~ r', A '=: <'.',:'/ · 1' ._. m~, ,,_J · .,!. -.- -i-*--. at~ .. · ,,i, -., .-...--. ,~:..~, '..' · . 4,'"'.451'-'"' "='"": ':""; ~; o .,= '+ ,..,,:, o. 12 6 71 1 '='"' .. . . ' ' '--' '--' '---' .=;,.1. ~'-" ':' '7(2) '-'",? 470z 48 464o.4c . · ,_-,~ ........ O. 17 967.25 S .=,~66.05 W 0 16 9.92 49 ~; '-"-' · .:,.:,46. '-'"5 0.24 1017.82 ~ ..,4..-'7.44 W 0.14 104:3.11 S 3.507.87 W 3658.49 0 3 0 i (')/-,:~:-.' 4 9 S '-'":' '-"-'. ....... :,..,,_-,,:, 14 W 3742.68 0.21 1094.19 '._--; 3668. 17 W 3826.73 ~ ~ : .... ~..,...~ .=.,,~ ~^ - 0.24 1119. :-.?7 S :3747..9'..-? W . ' ' - 0.19 i 145.68 '--' ':":"-' 0 ;.?.6~ 1171.40 s ......?/ ............... O. 37 1197.32 S :39 C-':6.07 W ................. .4,,..!....~(~....-...'~ ........... 0.46 1 .'-" .,"-' .:,'-'. 72 ':'"..:,4 ('). ~:.,_ 4. '74 W 4 -'-"~' 4 '-:3.92 () 5:6 .1. '-' =' ') 4 4:3 02 '--'"' .. ~....,C. 45S 1 . W 4._,~.6.62 7100 7..-oo ,--, .) C) 7500 05 1356.94 S 4454.08 W ........................ ~.~.~.~_;_.3~Z. _ 28 1383.96 S 4532. :.'::1 W 4738.12 22 ],411.12 S 4610.32 W 4820 05 1438.26 S 4688.24 W ol 146._,. '~'~ . ..o ~s~ : 7600 7700 7800 7900 · _,o.:,.=~ 44 49:::c}. 44 ~A ...... ~. '_-, .... 71 '::; (h'-"/.=; (').~] .~,(')5:/- C).=; =; ~= ~,z, .......................... , ._,.., S 71.60 '::' 71 :q9 S 71.60 W 0 .... " 1 .~44 73 '--' · ,::..: ...... 500 :sd. '79 W · ?- ~] - ~(. ,-, W 0 ..7 ).._7(.).'.:,'1 '-' ....,:, ,),-. 04 W 51o9.(.)5 14 0 '~3 1597 09 ~ 0.22 1623.54 S 5236.97 W 0.45 1650.22 ~ ~315.14 W 5264.52 5205.52 55 16 S 71.30 W 5321.35 5262.35 55 28 S 71.1.9 W 5377.72 5318.72 55 54 S 71.10 W 54.33.82 5374.82 55 50 S 70.69 W 549(},,(}0 5431.00 55 48 S 70.39 W 5545.98 5486.98 56 7 S 70.30 W 5235.26 ,.=;,317, 77 .................. .56AZ._~9 ARCO ALASKA, 3Q-5 KUPARUK ALASKA INC. 'F;F'ERI'?Y.--..:~:I...IN WEI..I,. '..-..;I. IRVFFYTNF.~ COMF'ANY ... ANCHORAGE ALASKA COMF'LITATION DATE FEBRUARY 1':?, 1787 .... T~TVKRTICAL SE~.~IO'~- CALCULATED ALONG ci"_Di~,i-I~E .. . ?..?-'?.' TRUE SUB-SEA COURSE COURSE DOG-LEG '-('" .............. ]DEPTH DEPTH DEPTH DEG M I N DEGREE'.=S DEG/100 ............ pAOE 4 . DATE OF SURVEY FEBRUARY S' ~?, ~:~ '-':' BOSS GYROSCOPIC: SURVEY JOB NUMBER AK-BO-70017 KELLY 'BUSHING ELEV. = ...................... OPERATOR-MCGU I RE TOTAL VEIRTIF:A'L .......... ~'~'~]~.-~-- ....~-~'i~:L~'~"~A'i"iFil~i" DIRECTION :SEVERITY RECTANGI_iLAR cOORDINATES 59.00 FT. NORTH / SOUTH VERT I CAL EAST/WE:ST SECT I ON 8600 ....... ~'t'-,(:~"~ .... 47 ~:,54,.. 47 ._, ~, '._-'::;; S 75~ .'=~5" '~- ......... 0 .36 8700 5A ~";/-, '"'= ' = '--' ...... =,._, 5597 ....... 35 '-~/-,._,7 ._, 70 50 W O.=',0 L~r)O 571 C), 9:3 =z ?, cj.:, F,'-' ':' 7(') 50 W 0.0:3 · _,,_-,._ 1 ...... 8 .... - ....... '.=;7/-,P; .... . ::{~=,, ........ :~,,~'2i'2-Y-T~:i?'; .............. ";.... 7 ........ j. ¢'i. ............. F;' 70 . 0 -W .......... 0.. 52 .. ,-, ,~ W 0, :Z 1 Pi'-' 9. PT' c,.-., ,:. 6?.? ,-,," " · _o.l 4:!. 5760 41 ._ 7 · ~ .,... ,_1 i -- . .=,,-,'.-, z'l ............ , _. . · _o7.=,. 5814 21 .=_;7 :31 S 6.c~.:::'~~ W 0 16 f.~20~.~ .......... 5'P2~:~ 61 5867 ..... ~1 57 ~', ................ .:,'=:-'$"5o.~. · :. ..... ~ ;~'-'"~w 0.71 87,'00 9100 1760.70 o ~' 17~8.67 S 1816.64 S ............ i'i~i'~:4":"9:-.-, s 'o C.I.-, 1 ,.,7:3, '-' 1".9o2.8qS ..... I PJ~. 34 S 5627.75 W 5706.53 W ~79. ~4:iLi!~!]'C:-: '- .".'~_~'_.."_ :,...i_..? · .o64 47 W 6147 56 57,4:'_:~. 5() w ...................... ~'9"~']"~;'9- ............... 6.).:~./=.6 W 6315 87 ' ::.,=, W ~..-,00 9400 9500 9700 '.-]800 C 9.900 10000 10100 10145 2,14. 0. :':: .... q' 2, (')::,' 1 . :::_.9 .~._ 7 4 ....~ ..... 61 .=;A 47 /-,0'-.77 47 .=,'~ ':'/- 6 i ,~:'_:~ .... 7'?~---;~_::'~[".'~J'4"':""~"~ ................. ~,=,'_ ,:.. .......... ,=,,-', .C-,247 C= ' 'A':, '='. 5 --'- · .)._, o z ~. ,.,. 0.., ,. 7 ..' 6:2:00, ._ 7 6241 ,57 ._,, 49 ....... -- 6..:,._,.=,. 8:_'-: t'_-,2'.--,~4.83 5'7 49 6407.09 6:348,U' "".-.~ '.:, ...... 7 4.'P ............. 6431 · ") =' . _ C ._, /_-,.'_--:72, 0.~ ._ 7 49 ............ "-'.:, 68. . :30 W C). 2:3 S /=,8. :3'.-.? W 1. (.".)7 2064.00 .:, 6440. tlC-.': W '.=; /-':' 10 W 1 (')~ .-,0,-,= ,=,=, ,-. /_,4,~.?~ .=,,:r~ W # . _ .~2~ . ,:i._l......;I ~ _ , _ ,, ._ .. _~ ~_m i S ~ c: · .-, ~-.-., - :,,_ 10 W 0.67 ~117..,~ ~ 6574.11 W ':' 2, c,. 1 (') W 0 '-' =' :21 /- '-' · :,.J 4.9.02 S ~.65~ 49 W tS; 6Ei. i't".~ W ............. n' 00 ................ ;;!il'-'(' 5:-.-' S 6731 02 W - · O .). S 68. 1(:~ W 0 ...... O0 2212. 16 '.=; 6809 =i"'":, W ., i"~ S 6,_-,. 10 W 0 00 '-, '-."-' z: ':~ .... . ~,_..:: .... 7 S 6,'=':44 ,'::'~ W . 1'~ '-' 28 '-' ~6-... S 61 1 11 W :"~:!~':6484':i'9~i~!~!ii?! m'fl ~ ............. ......... i.'~.'.'2~_:.~C2_:S: .... ,'--.~,.'--.,.!?._, .04 w - 656e · · .-.' 0 '.--' :~. 42 c. .-, .-,,-, 6.Z,.Z,,Z, =~ ...........· _, . , 14 Z-,/_-,5::~_ _ _, 58 .....X..,4, 6,('.-, .:, 6417 (.')4 14 67:37, 676:3, I = ~ ~. 58 . HORIZON'FAL DISPLACEMENT 7197.86 FEET Al' SOLITH 7I [Et) MIN WEST AT MD = 10145 .................. 'yHE F:AL--iLTLiL]'h'r'~.]~i'N F'qR _H_.EDLIRE' .:,'-' ARE BA'.5:I~F£i-'iS~'=i=R-E-i3L~:-ES'"iS'F~"=i=Fii~'E:E D I MEN:_--: I ONAL RAD I ~J.:,"' OF C:, IRVATt ~RE_ _ 7075, 42 715.9.86 71.97.86 'ARCO ALASKA, INC. 30-5 KUPARUK ALASKA DEPTH 0 1000 2000 ....................... o~ ~.. ;. · _... (.) 00 4000 5000 6000 7000 10000 10145 .'::PERRY-:-:;I IN WE[.I_ ;=.LRVEYING COMPANY ANCHORAAE ALA..'KA COMPUTATION DATE FEBRUARY 17, 1987 DATE OF SURVEY FEBRUARY 1.51:~:~¢!~~;~! ,..lOB NIJMBER AK-BO-70017 ...... KELLY BUSHING ELEV. = .5~.00 FT. OPERATOR-~CGU I RE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH "';IIRI_E SUB-SEA .................................. TOTAL VERTIC:~ ....... VERTI'CAL RECTANGULAR COORDINATES MD-TVD '' VERTIC:AL DEPTH ............................ D~;~H ..... No'RTH/SOUTH EAST/WEST DIFFERENi~iE ..................... c'OR'R'EcTION 0 · oo - 59.00 0.00 0.00 0. oo 'P';'7. ~"-' c¢.-,,---, ?]2 13, 9.=: .c; 34 AF.: W 2 48 '-' 48 . ._1.~ ..._'i,.-i. _ . _ ._ . _ _ ,, ~ . ................ '1 :..=.:'?'7'.' 76 1 '-"-"~' ....................... ,=,.:,,=, 76 ' .............. i"P-?-7-i":~i ?:: .............. 4:.-,~-."¢'ii"'~ ...................... i"6:~ 24 ,~,P. 7,::, . ~.'::' :~.. 4 ._'='. 81" 2483.81 361 .44 ._~ i 1 ._"-', 4 .24 W 457 .19. --,.=, =._, 4.96 ...7.~, 'F¢7 S 1'P'72 40 W :=:076..._"5.~._ 3017 · ._.~=~._ .~ "" . . ':.? 2 :':] .4..5 46/=,. .~.'-'='..., 361'-' /=,3 .:,'-'~-~-°..,._, .... 6'---'._-, 8;.':' ] . 51 S ,:.77._'-' 5 . 02 W 1 .:,,:, 1..:,7'-"-' '-' i~.i. II ' '--" ':'.~'q':' 14 W 1 '-'F, 48 4145 ?'~2 40,_-,¢-,. 52 1 AAA 4?) :.=.; o., ._ i.. ~,.i · ,I i c'-' 4:_=` . '-' /. '-,Pi . 47.)...-. 4643, 4-6: 13:30 15 S 4.=,7:,, ,:.._ W 2297 52 r=;.=,/.12~ -' ~.._...=; ......... ~'¥=_;'='~'"'"i;=';- ............... ~=;.~= ..... ~ ;'? "":: ...... 5 .................. W.:.-.-,p-,. ,..:, ............. ,.,-'- ...,.:: (.)..,.._, ..-'. 1 ._,; 7, 0 :: .:, 1 P]'::~ 0 !51 W .,." 7.: .... 4,=, "i':' 1 '.:.,' 41 ..=l 7/-, C) 4 ]. 1 c, 7':' '""-' ':' .5'.'.-~ 4 ::: P; 0 W 318 0 .~:; 9 ..... . ,.., ,.., · ,~,.:~ ._, · .... . -. ..... /.=, .=, '-," ..-, ...... .:,,· :=, -,'- ,=: 62'.:.?4 , :=:.=, .... ..... '6'4::~:-i'-: 05 /=,.:,7,:. 05 457.93 47o. 11 443.04 THE ~ALE. L L~ IuN PRuI,.E[LRE.:, ARE B~._ED ON THE USE ~nF THREE 371 '-' DIMENSIONAL ARCO ALASKA, 3Q-5 KUPARUK ALASKA INC. .~oLIRED 5.9 15.9 .................................. 25.9 :35.9 45.9 55.9 659 7~,:~ .960 :_::F'ERRY-SLIN WEI.I_ '.' ~RVEY ING COMF:'ANY PAGE .._ ANCHORAGE ALA.:,KA DATE OF SURVEY FEBRUARY 15, 1~87 COMPUTATION DATE .................... -F'E~RuARY 19, 1987 ........................... -.JOB NUMBER AK-BO-70017 KELLy BUSHING ELEV. = 5.9.00 -' OPERATOR-MCGU I RE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA VERT I CAL VERT I CAL DEPTH DEF'TH .......... ~TOTAi~ ...................... RECTANGUL. AR C:00RD I NATE:3 MD-TVD NORTH/SOLITH EAST/WEST DIFFERENCE 0. O0 -5.9. O0 59.00 O. O0 i._,'='"::,. o'i]f-- ......... f o6': 60- ..... .:.._"" =;'--,'... 00 200 .00 0. :'::.. 9. N '-"=':,' 00 300 00 ("). '-'"" N · .:,._~; ,, , _ 4.~;'9'. 00 4o~5766 ................................... i"":-2_-,'~'""' 'N =; .- ,..-,~. .- ..... :,; O0 500. O0 z. 42 N 65'F/, 00 600. O0 2.5'2 N 759- o'~f ............... 76Ci;556 ....................... o_'. 47;;. N c,.=;,:;, 00 '-" ') oOC 00 4 14 S ,#.l ..,. ,. · · u 959.00 '.-700.00 10. 8'7 S " '~' 19 47.3/:, W 106.., 1 o.~':>. 06 ........... 'l"i~(~O'."bi"-i ........................... .-.~ ,:. VERTI'CAL CORREC'I' I ON O. 00 O. 00 0.00 0.01 N 0.00 W 0.00 ........ 6.'i 6" N ....0 01 "W ......................... 0':"~5C] ............ 0. ll E 0.00 0. 11 E 0.00 0.04 W O. 00 0.44 W 0.01 1.5:3 W O. 02 5.86 W 14.63 W .,: 7. '.'70 W O. 00 0.00 0.00 0.00 0 O. 01 6 Fl4 ........................................... o ' ..... ~. :2 O. 64 0.5() 1.76 1.12 , ..,o ,:,..:, 7 12.71 5. 1'3 19.61 6.90 28 42 8. ':"-.' m ,...~ ,.~., 3'2.4.9 1 I. 0,/::, 53.22 13.74 70 '-'C · ..') 16..98 ARCO ALASKA, INC. 3Q-5 KUP ARL K 6.',I':'E:'.RRY-.:E;I..U',I WEI... I '!i:I,.U'?VF;Y I NG COMPANY ANCHORAGE ALASKA COMPLITATION DATE FEBRUARY 19, :1987 INTERPOLATED VALUES FOR EVEN 1987. DATE OF SURVEY FEBRUARY ,_lOB NUMBER Ak'/~B0-L'7-Oo17 KELLY BUSHING ELEV. = OPERATAR-MCGU I RE 100 FEET OF SUB-SEA DEPTH C TRUE SUB-SEA TOTAL" · E.~.~.{.i.R.~.t~l ..... . _ VERT I cai ........... VERT I CAL RECTANGUL. AR Ii:FIORD I NATES ......... b'~'~-'~i;i' ............................... [,EP'TH ......................... DEP~'H ...........NORTH/SOLITH EAST/WEST '-'=" '=',')0 '"':~'~ 92 22 ' '. 1951 lc,._,~/ O0 1 O0 144 73 S :30 W 21 _ ~ '= ~C:' 2078 .... ...z.?'J_~' "'=9~ O01900, O0 167.13 S 474.1 z- N 119.71 27 . · - .<, o A ~,:y .._, .... y. (.)._, N 1 3:3 .............................~o..,._~=s~e~'~'~ ............ ='-' 15?. O0 .................. 21 O0, O0 21 ?. 71 S ~ .... =;4. 'F'4 W 194 .60 ' ...... 41 . 2506 ":"?=;':~ 0C} 22('x} O0 ':'~]":' 24 S 7/-,~ 81 W 247.4..5 2847 '-' ='- ~, - - o o,r~ 40 S 1 (3:':: 1 '$,~ '-,,-,,:, .=4.., ~. O0 ~4(.}0 O0 W 75 ........ · _ o c .... 7 5 3029 z'-'=~O.-,.- .. ,')A =~,L)O"' = ' O0 :367. ~H'-' <' · _ ,=, 1178 67 W 476). 94 -. . .,~, ..i* ._m , - - . ............ :3407 ,."::'7=?r~._ .. ............ (}0 2'700,'(')('~ 4.4.5, '~7 S 14:E:'F~ ~;,r, W ~=,4,:,"". ?1 ::,::,-'-' . ..................................................................... · :~.., s- c, .a c,._, Y 0 0 "" '~' ' ' 8 8 . .~ oO 0.00 48:3.32 S 1644. I 1 W 7:3'7.7:3 . :3~"~' 295? O0 2900. O0 ='-'"' '-'= "' - ' .... '~':;:':~:;=:... 3969 '-" ='- · .:,(.).-, Y 00 '~' ' ' ~()OO, C)O = Y4o, 27 W 910, 24 ,:,0. . o66.50 S 1'- '-' '-' :~';~? 4145 3159. O0 3100. O0 - c, --,- o · ~,.T~,- ';' ?":'/- 04W 1 (") 7 () ':":' 4..~ = ] :'::'~ P~ 9 00 ::: 2 (') (') 00 /-, ~] 1 42 '.S 84, ......................... 4'~'i"~;~ ....... ::::~57_ _ .0'0 ............ 3300.00 697 . (')~. _ S ~:.:,7 ;'"-' ':~ .42 W 1151. . ._M':',.., o(.)."~ ' ..................... ~7~;';~;'~ ............... 3'459';Cf6' ....................... ~'O'~j~"L-()O .................... 74'~"~")~4 ;6 ....... :~'~'?:"":~9 W .t'-''~''~ 81, - · ~l-J, ..S,. :::?:...,::?~..~:~::?..: w~,¢~ .:,~,.-,; ...... ~: :,.,:,. 60H 1324. ~ . ?0, . o40 O1 c. ~,:,4(.) 12 W 1419 81 95. .... ... _ MD-TVD VERT I iS:AL D I FFE'RENCE CORRECT I ON 59. O0 FT. · -- . ,,, ~ ,.--,., .',, ,. ] 54 :34 ~..~ r"2' ..- ,. ...... : ~.- --. ..... ~,.-.:4 · 10 :'-:' 20 ....... 1 'P ................................ ':. ,p:.-_.: .............................................................................. F:: 7 20 .. ......... ..................... . ....... ::.: :,~,.;~L~>~'~/:?:~,;f,' (.'):iii: -/0 5 '? 96 ARCO ALASKA 3Q-5 KUPARUK ALASKA DEPTH I NC:. i RL E .c;I IB-::;EA VERT I F:AL VERT I CAL DEPTH DEPTH 5273 3759.00 5464 '-"--'='- · .:, c,.J '.'7. () · _,6._,." '--"-"~'"'~ .::, .-....~ :, , 6(: 24 41 .~'~, ':;F'ERRY-.,:::I.IN WFI I '.:":1. IRVF'Y T NG ¢:I'.:~MI":'ANY ANCHORAGE ALASKA INTERPOLATED VALUES FOR EVEN TOTAL REL. FAN _,LILAR COORD I NATES NORTH/SOLITH EA.ST/WEST 6::--:6.07:3 3000.2'2 14 3700.00 3800. O0 00 3'..-?00.00 00 ......... 4000",' 00 O0 .............. 4i0'0 :'00 4200. O0 · -., ?,,:',, ~, - · ':::::.,~.' 6::3904 .... .-.. 00 4~00. O0 6570 4459.00 4400. O0 674 ,'_.:: :a.+ ._,=- ...,,=: ;5.~ ," 00 4 .=;_ (-). 0.. 00 6/..4 4/-,.=;9 O0 4600.00 ............................... ?09',P' 475'F,. O0 47¢:>('), 00 7277 -,,:,._ .~ ........ 4~,¢ O. 00 7454 4959. O0 4'..~00, 00 · =; 00.00 781 :--: 51 P'; 9.00 ._ 1 ............................................. 7.9 ¢,~..: 0" .:.,.~:._,'": '"' ':' ";':.. 00 .. ~ ~":, .. r) A.., 00 ..................... ~i'i"Z-,Z-: ........... .... .=,'-'.=,'-f':, ._ :.. 'r.~ u ~ ....................... ._,~:::'"'._-, u u'; ........... u:":o ' :::::::::::::::::::::::::::::::::::::::' ..=,45¢¢ oo",.' .... 5400.00 · _ c, O0. O0 COMPUTATI ON DATE FEB~iLi~RY ~'.~, '-'i-987 ........ dOB NUMBER AK-BiD'-"70017 . . KELLY BUSHING ELEV. = OF'ERATOR-MCGU I RE DATE OF SURVEY FEBRUARY 100 FEET OF SUB-SEA DEPTH 59. O0 FT· MD-TVD VERT I C:A[_ D I FFERENC:E CORREC:T I ON I 122.25 S 1169.08 S 1215.96 S ............ .I.' ''':~';...: ;:".:, ...-,,:;; .......... 4:7 ...... .::,':~: '"' 1 :_::0':?. 96 5:; 1356.82 S 1514. i 1 94. :30 C:,, '--, '--, '--' '--: '3 ') ~'' ....oo. 2:4 S.., 1~/-,.. _. ~._ W 16L ~,. 43 91. . .'_=:2 "' ":.5PE5-?,'1, .... .... :ii ............. ,:,:s:":i~';-;..:, J,:, ....... <:,¥' 0 '= ............................... W 16 ;':.~ :"-..:,. ..................................................... 61 '=":' 1 ,..,':' I..I I__I I 1("-' oF, "' F,'-], '-.":' .),-7. S W .1. 7,C:¢) 51 · :.. 4 ._ .-. i-' ~lI -- . i · · .. · q' =' .R-7--; ' ' R~ 41 1074.87 S 3608 1 ! N 1 ,:,:,._,.. _ ~._,. ~,-,.=,e 06 14 1.949 ,-,o R':' 96 ............. oo'-'"--"c~'--'...~. · 84 14 '-' ' '---' 'R'- ']'-' "" ......... .,: 0.=, !. 96 . 4041 94 W ':'111 '."::'4 79. -'-' · ~_ . . .............. 4 i":"" ',::, i <"-'i ~,:'i"-' N ....... ................................................................................. '-"- · ,::,'-":,:~..-'=.._, 7 7. ,:,'-' i ........................................................................ 431 Y 6:3 W '-"-'~ '" .:: ~-:. :,...,. 27 7.5 =":' · I ,. ,,~. 44!53.71 W 2:340.5:3 7 14~'~'~'i~i0-'':'' 4.=,9.:.; ..... 7._.=, W .................... :S',4"~";.:F",~]' ........................................................ 77 '.-?.1. ,_t ., . a.. · *'., "? 3. o_~ ~ '1' '~' 145:R "-' 47:30 '-"- W ':'"'-'= 63 77 19 .............. .................. 1501 ~ ' '--'?,-"'--"-" ........ ~,-~?F":::, ..... ;-: ............... b'-')" '-' F, ':~'-' 1._4,:: .... ::,7 .::, ..:,C 1° 62 N . .,.,.. (: .... 4 78. ,.1, · -.~ . ,% ...5 ,. .~ ~ c, 7':, .1. '~';'-','4 F',':' S 51 ._ .1 1 W 1 :'-:0 7/'_', 47 · .., .. · .....~, · ._ ,~ ._l · · ................................................................ 1641 27 :S ~'""-' '=' '- '~' ,-,,-,p-7 · ~.~,=, .... ~;,-, W 76 :::0 · .. ~,=, .... 61 1/_-,o~ 56: t-; ~ -, .- ,;, . o ,.-., W 2885.84 78 23 .... ::::::::::::::::::::::: ...... :_ .. ':., ::::::::::::::::::::::::: ........................................... :: ARCO ALASKA, 3Q-5 KUFARUK ALASKA · . "-(E'~'~URED ..... DEPTH INC. .":;F:'FRRY .... ::-:LIN WI.::I. L 'DURVEYI hi'3 (':OMF'ANY ANCHORAGE ALASKA COMPUTATION DATE FEBRUARY 1 'P, 1::/87 DATE OF SURVEY FEBRUARY 15, 1~87':Y.-':i:~?::::~.'' JOB....NUMBER. gl<-BO-7c)O 17... .... KEL..L..Y.....~U.~H I NO ELEV.. _= 59. OO FT.,. OF'ERATOR-MCGU I RE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 'FRI IE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH TOTAL. RECTANGULAR COORDINATES MD-TVD ..... 'V~ICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION . . 8704 >' ..'-<:. ;:;~ ., '_' '"'"' 'ii': ..... '---' 9073 ~"-'~'-? ._i ,--, ._1 .': '--~'-"' C) "~ 2-'"0 . .- ...- · · 9448 ,'-,05'P. ~ ...... .... .... ; .:. '~ ~_,c~4 61 ~'P. AO 9822 625'F/. ~':':'::iY. I'0:00'9 6359.00 1C 14._, ~J, Zl.:;::'l"~' 05 C) 0 5800.0 c) c)o' ............... 5":. 0Ci :'66"' 00 6000.00 6100.00 2065.47 S 6444.27 W 6200.00 2124.50 S 65~1.4~ W 6300.00 2183.66 S 6738.64 W 6372.05 :2226.37 S 6844.8~ W 3475.71 86.64 3563.21 87.51 3650.71 87.50 :371:3.95 63.24 .................. YRE'"'"~:fiE'CjL~LnT I ON 'i~;R'i~i'CE'rJ'ORE~i""'i'isE n L I NEAR I NTERF'QLAT I ON BETWEEN ,,,~ ....... ,.,:.,..,, :: THE NEAREoT '?o FOOT MD (FROM RADILIS OF hlJRVATI_IRE) POINTS .ARCO ALASKA, INC. 3Q-5 KUPARUK ALASKA 'C.S'~'iEURED TRUE SUB-SEA · VERTICAL VERTICAL DEF'TH DEPTH DEPTH 9763 6227. 16 61'68.16 ·.. · 9768 ,_, ~ ...-/. ---, .-,- c,... o4"" 6170, 84 9768 z -:,.-,,.? ,=,~ 6170 P, 4 .................................. F_AOE DATE OF SURVEY FEBRUARY 15, K;F'r'f;:RY...":.-.:!..IN WI':'I. I. ANCHORAGE ALASKA '-'.';!..II"~VF.'.¥.T NG f.':OMF'AI',IV dOB NUMBER AK-BO-70017 .KEL_LY......B.U..S.H I NG ELEV. = OPERATOR-MCGU I RE COMPUTATION DATE FEBRUARY 19, 1;787 INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS ................. -~5-fAIZ ........................... RECTANGLILAR F:OORD I NATES .o. NoRTiLI/SOUTH EA._-, F/WE.=,T 2105 '~"' .o:~ S 6545. 16 W 2107.45 S 6549.08 W .... , ........ :)~-"2i' i~' ';-:: ........... ~ =-",:~.. _ .:: i C 7. ~._, o c,._,4 .~ 0:-'_: W .................... i ......... ~'07'~ ............. 62:_--:5 ~6,6" ............... /_-,,.Z/_-,.':'~ .......... 66 2i'4'0.1',_=; 'S; 6 :, ..--.. 0/- '-". 50 ' W .......................... -~';:.~66 .............. 6:Soo. 57 ............... ~.'2~ l; 57 ::::.,14.~,. o2 s /_-.65'2.4:~ w ~_...,-.-.-4. O0 6265. O0 ,'.1 _,z. 91 ..-, 6687.04 W --, '_-~ 0 6431,05 6o7..-- ,05 2226. '--'7._, ._.c; 6,_,44. ,-- .-. W MARKER ............................................................ TOP KLPARUK C BASE KLIPARUK C 59.00 FT. TOP KUPARUK A BASE 'i ' ' ' K,..IF ARLIK A · :,L RVEY DEPTH PLUG BACK'TD TOTAL DEPTH DRILLER ARCO ALASKA INC. 3Q-5 STRATIGRAPHIC SUMMARY DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA CooRD INAT~S =='Z=---MARKER ....... MEASURED DEPTH ........ TVD THICKNESS WITH REF. ....,.:,. BKB BKB SUB-SEA VERTICAL ( ORI G : ~;7%::':'~":' ""' SEC 17 T I~,~ -~'~i'~;'=~~'~pA R UK C ................... '~'76!3 ......... BASE KUF"ARLIK C: ~768 '"i"i??i!i!i!!:~OP 'KUPARUK A 9768 ..... '"":'?:~BASE KLIFAR_K' ' '11" A 9,_0,72 .... :'!:'""'PLUG BACK TB 9944 TOTAL r'IEF'TH [IRILLER 10145 ...............6227 .16 61 A~-'_ o. ........................................................................................... 16 2 !05 . :38S 6545, _16W 6229.84 6170 L---.,'4. ..- 107 4.5 6229.84 6170. o4 .-"':" 107 . 45S 6285.66 6..----6.66 ..'=' 140 . 18S 6o..'- 4. O0 6265. O0 2162.91S ............. 6431 (")Fi /.-,-.-, --,--,.~/ q c. · . _ :,.:, 7 z.. 0 6844.8~W NEAR E X TRAP'OLAT_T ON BELOW DEEPEST :=;TAT I ON. '~i~?C:OMPUTI=R ..... PRF,=iRAM - SPERRY ~I:=,LN THREE D IMEN:=;T_ONAL RAr'I~ Ii:-=:_.=' OF !.I_RV~TLIRE-'I' ' . C:ALCULAT I ON AND ! NTERPOLAT_I' ON BY RAD I US i_"'iF.. C._-11RVATLIRE' ' DATE OF SLIRVEY I=EBRLIAR~ ....... l"~"~ ....... i9L--:7 C. OMPUTATION DATE , FEBRUARY 1 '-=' 1 '- '-' .., :/o7 ,_lOB NUMBER AK-BO-70017 KELLY BUSH I NG F..LEV. -=._,~'-~. 0(') FT. 5PERR"i' -,.SUN 5CRLE :- [ INCH TO 1000.00 / IO00. O KUPRRUK RRCO RLRSKR. ~Q-5 FEBRURRT AK-BO-7001? INC. [98? TRUE t'O, O0 -60~10. O0 -5000. O0 -40~]0. O0 --?OO HOR ]~ ZONTIClL PROJECT I ON ~ORIH --1000.00 --2000.00 -.-3000.00 SPERRY -SUN O. O0 SCALE KUPflRUK 3Q-5 AK-BO-70017 INCH TO 1500.00 / 1500,0 ARCO ALASKA. INC. FEBRUARY 15. 1987 1500.00 3000.00 4500.00 6OOO. OO 7500.00 643[. 05 10145 VERT I CRL PROJECT I ON 1360. o03o~o. co~36o. oo~o6o. o0~s'o0. c- STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COM, ~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate,~ Pull tubing [] COMPLETE Alter Casing [] Other 2. Name of Operator ARCO Alaska_. Inc. 3. Address P.0. Box 100360 Anchorage~ AK 99510-0360 4. Location of well at surface 2223' FNL, 2280' FEL, Sec.17, T13N, RgE, UM At top of productive interval 951' FSL, 3545' FEL, Sec.18, T13N, R9E, UM At effective depth 894' FSL, 3687' FEL, Sec.18, T13N, R9E, UN At total depth 831' FSL~ 3845' FEL~ Sec.18, T13N~ R9E~ UN 11. Present well condition summary Total depth: measured 10,145'MD true vertical 6431 'TVD Effective depth: measured 9944 'MD true vertical 6324 'TVD Casing Length Size Conductor 80' 16" Surface 5019' 9-5/8" Production 9996' 7" feet feet feet feet 5. Datum elevation (DF or KB) RKR 59' 6. Unit or Property name Kuparuk River Unit 7. Well number 3Q-5 8. Approval number 9. APl number 10. Pool Kuparuk River Plugs (measured) None Junk (measured) None Feet Cemented Measured depth 1875# Pol eset 115 ' MD 1300 sx AS IV & 5056'MD 340 sx Class G 300 sx Class G & 10,031 'MD 175 sx AS I Rue Vertical depth 115'TVD 3648'TVD 6370'TVD Perforation depth: measured true vertical 9767'-9830'MD 6230'-6263'TVD 12. Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 9705' Packers and SSSV (type and measured depth) HRP-1-SP pkr ~ 9674', & TRDP-1A-SSA SSSV @ 1819' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final Pressure RECEIVED A? R 0 1 1.r 87 Alaska 0il & Gas Cons. Anch0r~ge 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 (Completion Wel] Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ c~. -/o?..- O~; Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (Dani) SW02/1 2 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or weli is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Fie~d ILease or Unit I Well no. Kuparuk River ADL 25512 3Q-5 Auth. or W.O. no. ~Title AFE AK1592 I Completion Nordic #l Operator I A.R.Co. W.I. ARCO Alaska, Inc. Spudded or W.O. begun Date Complete 3/04/87 3/05/87 Date and depth as of 8:00 a.m. 3/06/87 Complete record for each day reported API 50-029-21684 [Total number of wells (active or inactive) on this i 56 24?0 ICOSt center prior to plugging and I }abandonment of this well I }Hour I Prior status if a W,O, 3/4/87 ! 0400 hrs. I 7" @ .~ 10.0 ppg Brine Accept rig @ 0400 hrs, 3/4/87. ND tree, NU & tst BOPE. 7" @ 10,031' 9944' PBTD, Displ'g well w/diesel Tst BOPE. RU Gearhart, perf w/5" guns, 12 SPF, 9767'-9830', RD Gearhart. RU & rn 2-7/8", J-55, FL-80 8RD EUE AB-Mod tbg. Tst tbg/ann to 2500 psi. ND BOPE. NU & tst tree to 5000 psi. Displ well w/diesel. 7" @ 10,031' 9944' PBTD, RR Fin displ'g well w/diesel. RR @ 0830 hrs, 3/5/87. (SSSV @ 1819', HRP-1-SP Pkr @ 9674', TT @ 9705') Old TD New TD Released rig Date 0830 hrs. Classifications (oil, gas, etc.) Oil PB Depth 3/5/87 K nd of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 9946' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signatu~ ~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Supervisor ARCO Alaska, Inc Post Office i~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5936 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. 2A-12 CET. 3-8-86 6410-7007 · 3F-16 CET 1-13-86 7740-8443 2A-10 CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 -3Q-7 CBL 2-i5-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL '2-15-87 7843-9752 ___3Q-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-10 CET 9-4-86 4700-8118 'Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanllcRichfieldCompany ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 Transmittal # 5925 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. ~' -~, 3Q-6 OH LIS Tape + Listing 2-2-87 #72187 3Q-2 OH LIS Tape + Listing 2-2-87 ~: : 3Q-5 OH LIS Tape + Listing 1-26-87 . 3M-1 OH LIS Tape + Listing 2-19-87 ~7219 Receipt Acknowledged: DISTRIBUTION: D. Wetherell . Commission Date: ARCO Alaska, Inc. is a Subsidiary ol AriantlcRichfieldc°mpany STATE OF ALASKA ALAS, , OIL AND GAS CONSERVATION COM~, ...,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown-.~ Re-enter suspended well [] Alter casing L~ Time extension [] Change approved program D Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate [] Other 2. N ~,g_,of, Q per, ator z-~.~,u ALaska, Inc 3'A~Jd. rec~.s Box 100360 Anchorage,. AK 99510-0360 4. Location of well at surface 2223' FNL, 2280' FEL, Sec. 17, T13N, R9E, UM At ~)oSP49f productive interval FSL, 1531' FWL, Sec.18, T13N, R9E, UM (approx) At§~¢~ti~es~e, pt~677' FEL, Sec.18, T13N, R9E, UM (approx> At~d~, 3836' FEL, Sec.18, T13N, R9E, UX (approx) 5. Datum elevation (DF or KB) RKB 60' u'Unit Ar P~e~ly a e paruK ~anTt 7. Well number 3Q-5 8. Permit number 86-196 9. APl number 50__029-21684 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured 10,145' ND feet true vertical 6420' TVD feet Effective depth: measured 9944' ND feet true vertical 6.313' TVD feet Casing Length Size Conductor 80' 16" Surface 5019' 9-5/8" Production 9996' 7" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Plugs (measured) None Junk (measured) None Cemented Measured depth 1875# Poleset ll5'MD 1300 sx AS IV & 5056'MD 340 sx Class G 300 sx Class G 10,031'MD ~ue Verticaldepth ll5'TVD 3642'TVD 6359'TVD None Packers and SSSV (type and measured depth) None 12.Attachments Well History Description summary of proposal [] Detailed operations program _~ BOP sketch 13. Estimated date for commencing operation April, 1987 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 ~) ¢/),'~,/~ / ,~,'Lj.~.~j.i~... Title Assoc~t~ Eng'in~r Date Commission Use Only (BANT~ ~A9 Conditions of approval Notify commission so representative may witness ~ ~ppro~l-~o. ~ Plug integrity ~ BOP Test ~ Location clearanceJ ~ -/~ ....: ~' ~ by order of Commissio e the commission Date ~~ Approved by ~'~i~~;~ ~'~',:"~'~~,~ ...... ~.~?~ Form 10-403 Rev 124-85 ,, Submit in triplicate ARCO Oil and Gas Company Wall History - Initial Report - Dally Instructions: Prepare and submit the ,Initili Rel~ort~' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Sl3Uddlng should be summarized on the form giving inclusive dates only. District Alaska Field County, parish or borough North Slope Borough ILease or Unit ADL 25512 ITitle Drill Kuparuk River IStete Alaska IWell no. 3Q-5 Auth. or W,O. no, AFE AK1592 Doyon 9 AP1 50-029-21684 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUnspudded IDate 1/20/87 1H°ur 1200 hrs. JPr, or status if a W.O. Date and depth as of 8:00 a.m, 1/21/87 1/22/87 1/23/87 1/24/87 thru 1/26/87 Complete record for each day reported 56.24% 16" @ 115' 2398', (2283'), Drlg Wt. 9.3, PV 13, YP 30, PH 8.5, WL 12.8, Sol 5 Accept rig @ 0800 hfs, 1/20/87. NU diverter sys. S~ud well @ 1200 hfs, 1/20/87. Drl & surv 12¼" hole to 2398'. 553', .5°, N12.SE, 552.99TVD, -1.22VS, 2.35N, .53E 919', 8.8°, S60.2W, 917.82TVD, 20.12VS, 4.92S, 19.54W 1317', 20.3°, S67.5W, 1301.89TVD, 120.95VS, 47.65S, lll.80W 1884', 34.4°, 870.3W, 1805.19TVD, 378.49VS, 139.32S, 352.94W 2260', 43.9°, S72.4W, 2096.23TVD, 615.83VS, 212.84S, 578.62W 16" @ 115' 4681', (2283'), Drlg Wt. 9.2, PV 15, YP 21, PH 8.5, WL 9.2, Sol 5 Drl & surv to 4681'. 2449', 49.6°, 872.3W, 2225.68 TVD, 753.44 VS, 254.568, 709.75W 3352', 57.6°, S73.1W, 2742.09 TVD, 1493.10 VS, 465.738, 1418.72W 4223', 57.1°, S73.2W, 3200.28 TVD, 2232.84 VS, 655.178, 2134.62W 9-5/8" @ 5056' 5075', (394'), Displ cmt w/wtr Wt. 9.2, PV 11, YP 10, PH 8.5, WL 10.2, Sol 4 Drl & surv 12¼" hole to 5075', short trip, POH. RU & rn 127 its, 9-5/8", 36#, J-55 BTC csg FC @ 4973', FS @ 5056'. Cmt w/130Osx AS IV lead slurry & 340 sx Class G tail slurry. Displ w/wtr. 4675', 57.6°, S70.6W, 3444.14 TVD, 2613.36 VS, 773.40S, 2496.33W 4975', 59.4°, S73.4W, 3600.88 TVD, 2869.11VS, 852.438, 2739.57W 9-5/8" @ 5056' 10,145', (5070'), Short trip Wt. 9.9+, PV 13, YP 9, PH 9.0, WL 4.4, Sol 11 Fin displ'g cmt, bump plug. ND diverter, NU & tst BOPE. Tst- csg to 2000 psi, drl 10' new hole & conduct formation tst to 12.5 ppg EMW. Drl & surv 8%" hole to 10,145'. 5,282', 58.9°, S74.1W, 3758.31TVD, 3132.61 5,788', 57.6°, S71.3W, 4024.57 TVD, 3562.83 6,295', 56.9°, S71.5W, 4298.84 TVD, 3989.16 6,798', 55.6°, 871.3W, 4578.28 TVD, 4407.30 7,299', 55.7°, 870.7W, 4860.97 TVD, 4820.78 7,800', 55.7°, S70.4W, 5143.30 TVD, 5234.41 8,179', 55.7°, S71.8W, 5356.87 TVD, 5547.39 8,464', 56.1°, 871.5W, 5516.66 TVD, 5783.36 8,747', 57.0°, S69.7W, 5672.65 TVD, 6019.34 9,232', 57.8°, S70.8W, 5933.95 TVD, 6427.60 9,631', 57.6°, S69.2W, 6147.15 10,040', 58.2°, S69.2W, 6364.49 VS, 926.18S, 2992.60W VS, 1054.12S, 3403.36W VS, 1190.13S, 3807.50W VS, 1323.52S, 4203.87W VS, 1458.18S, 4594.76W VS, 1596.008, 4985.22W VS, 1697.41S, 5281.42W VS, 1771.71S, 5505.42W VS, 1850.14S, 5728.13W VS, 1988.20S, 6112.67W TVD, 6764.53 VS, 2103.55S, 6429.58W TVD, 7110.41VS, 2226.58S, 6753.47W The ab~-~ correct Signa~~ ~ For form prepar~p/and_ distributio~[~.P see ProceduresLM,~nual, Section tO, Drilling, Pages 86 and 87. Date [ Title I Drilling Supervisor AR3B~459-1-D Number all daily well history forms consecutively as they are prepared for each welt. Pag~ no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Filial Report" on the first Wednesday after allowable has been assigned or well ia Plugged, Abandoned, or Sold. "Final Report" should be aubmlttee}:e.lao when operations are suspended for an indefinite or appreciable length of time. On workovera when an official teat ia not required upon completion, relx~¢t ~f31ttlMetlon and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is availablef District lCounty or Parish 1 Alaska Field ILease or Unit I Kuparuk River Auth, or W.O. no. ~Title I AFE AK1592 Doyon 9 tAccounting cost center code State Alaska North Slope Borough ADL 25512 Drill no. 3Q-5 API 50-029-21684 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 1/20/87 Date and depth Complete record for each day reported as of 8:00 a.m. 1/27/87 1/28/87 I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our ~ Prior status if a W.O. 1200 hrs. 9-5/8" @ 5056' 10,145', (0'), POH, LD DP Wt. 10.0, PV 15, YP 6, PH 9.0, WL 4.2, Sol 11 RU Schl, rn OHL, RD Schl. Circ hole cln, spot diesel pill, POH, LD DP. 7" @ 10,031' 10,145' TD, (0'), RR 10.0 ppg NaCl/NaBr RU & rn 231 its, 7", 26#, BTC csg w/ FC @ 9944', FS @ 10,031'. Cmt w/100 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65, and 200 sx C1 "G" w/3% KCl, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.0 ppg brine, bump plug. ND BOPE, N~ &tst tree to 5000 psi. RR @ 2400 hrs, 1/27/87. ~ Old TD New TD Released rig Date 2400 hrs. Classifications (oil, gas, etc.) 0il 10,145' TD ]PS Depth 1/27/87 ]Kind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 9944 ' PBTD Rotary Well no. Oate Reservoir Producing interval Oil or gasTest time Production OII on teat Gas per day , Pump size, SPM X length Choke aize T.P. C.P. Water % GOR Gravity Allowable Effective date corrected see Procedurea M'~"nual, Section 10, Drilling, Pagea 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively las they are prepared for each well. iPage no 2 Dlvllton of AtlantlcfllchfleldCompany ARCO Alaska, Inc. ~ Post Office ~ ,100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 9, 1987 Transmittal #: 5912 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. OH Finals: 3Q-5 2" DIL 1-26-87 5060-10130 Cyberlook 1-26-87 9500-10100 2" FDC Raw 1-26-87 7844-10104 ~.~ 2" FDC 1-26-87 7844-10104 Porosity 5" FDC Porosity 1-26-87 7844-10104 5" FDC Raw 1-26-87 7844-10104 5" DIL 1-26-87 5060-10130 3Q-8 5" FDC Raw 1-18-87 8740-9366'~ 2" FDC Raw 1-18-87 8740-9366 2" DIL 1-18-87 4940-9392 ............ ~_j- 5" DIL 1-18-87 4940-9392 5"FDC Porosity 1-18-87 8740-9366 2" FDC Porosity 1-18-87 8740-9366 Cyberlook 1-18-87 8850-9300 Receipt Acknowledged: DISTE%BUTION: NSK Drilling Vault (film) Rathmell D & M L. Johnston (Vendor pkg) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany December 29, 1986 ~. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy.' (907) 276-7542 Re: Kuparuk River Unit 3Q-5 ARCO Alaska, Inc. Permit No. 86-196 Sur. Loc. 2223'FNL, 2280'FEL, Sec.17, T13N, R9E, UM. Btmhole Loc. 859'FSL, 1230'FWL, Sec. 18, T13N, R9E, UM. Dear Mr. Kewin: EnClosed is the approved application for permit to drill the above referenced well. The permit t° drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing 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. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~.~truly llpurs, J Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE COPSMISSION dif 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 ~..,.. AND GAS CONSERVATION CC..,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill ~'~¢ Redr, ll ~1 lb. Type of welI. Exploratory© StratigraphicTest [] DevelopmentO,I I~ Re-Entry Deepen Service [] Developement Gas [] Single Zone/~ Multiple Zone ..... 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 60' , PAD 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Ri vet Oil Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2223'FNL, 2280'FEL, Sec.17, T13N, R9E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 954'FSL, 1531'FWL, Sec.18, T13N, R9E, UM 3Q-5 #8088-26-27 At total depth 9. Approximate spud date Amount 859'FSL, 1230'FWL, Sec.18, T13N, R9E, UM 01/25/87 $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 3Q-6 1 0238 ' MD 12;~0'f~ Total de[~th feet 2S' (~ surface feet ;Z560 f64Rl'TVD) feet 16. To be complete(:J for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depthc00 feet Maximum hole angle 56 0 Maxirnumsurface 2185 psig At total depth (TVD) 3147 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2~:'' 15" 52.5# H-IlO Wcld MO' ~5' ~5~ 115' 1157 +200 of 10-1 /~LllO--~. /~!I ~' r,~ I_~.~. I~T(~ [~I ~.~' i ~r.i ~r~l ~1Q1 I ~[;o(~ I I I,'~/~ rv AC; I I I HF-EE.W 3z+O s× Class n b~epd 8-1/2" 7" 26.0# J-55 BTC 0204' 34' 34' 0238' 6481 ' 200 Ex Cla.~.~ Gfol~nimum HF-EFW TOC 5 O' al;)ov.,· tOD of Kuparvk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~ ! !; i'i ~ !;J !i ':' ,i ::-~ Surface ~ -~; .... ' i: ~,,, ~ ..... Intermediate Production [,' i!'i.;i;; /:. ,,::- Perforation depth: measured true vertical '20. Attachments Fil!n~] fee i~' Property plat [] BOP Sketch ,1~ Diverter Sketch~ Drilling program/~ Drilling fluid program'~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements r~ n~/true and correct to the best of my knowledge z/~,~ 21. I hereby ce t the foregoi Signed ~ Title Regional Drilling Engineer Date/' Commission Use Only (HRE) PD/022 ,/ ,/ i~, number .. I ~,ro~/d~ See cover letter Permit Number,, ~._~.;. /¢('~' 50-- t %'~ ...'c./ Oi.~ ¥ /86 for other requirements Conditions of approval Samples required [] Yes 2% No Mud Icg required [] Yes E~"No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No Required worki~orBO/PE~2M; j~3.M; [] 5M; [] 10M; [] 15M Other: by order of ~L.~~ Approved by ~k ~' X~/'' ~k ~~~~ Commissioner the commission Da Form 10-401 Rev. 1. 85 / . Su plicate ARCO ALASKA. ~HCo '- ....... ....................... PAD' .,7.0. WELL NO~ 5 PROPOSED KUPAFUK FIELD.i NORTH SL~OPE. ALASKA t, 000 I ' ~ ' , I 1 ! I I I I 200( 210( 2201 2401 2501 KUPARUK RI VER UNIT 20' D IVERTER SCHEMATIC & DESCRIPTION 1 .16" CONDUCTOR 2. FMC SLIP-ON W~LD STARTING HEAD 5. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLING SPOOL W/lO" OUTLETS 5. 1 O" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOffiATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWINO DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, IN~., REQUESTS APPl~OVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. lDO, NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES t: · 7 6 5 4 2 DIAGRAM #1 13-5/8" 54EX30 PSI RSRRA BOP STACK I. 16' - 212X~ PSI TAI~ STARTING HEAD 2. II" - 3000 PSI CASING FEAD 3. II" - 34X:)0 PSI X 13'-5/8" - 5000 PSI SPAQ~ SPOCL 4. 13-5/8" - 5000 PSI PIP~ ~ 5. 13--5/8" - 5000 PSI DRILLING SPOOL W/CHO<E AN3 KILL LII~_S 6. 13-5/8' - 5000 PS! ~ PJ~ W/PIF~ ~ CN TOP, ACCLM. LATOR CAPACITY TEST 13--5/8" STACK TEST I. FZLL-I~P s'r~3( ~ ~ i~e~iz~ Q-~CI( THAT ~ LOCI( ~ ~ ZN flJ. LY EETI~CTE:D. SEAT TEST PLUG IN WITH RII~NING JT ~ U IN L~ SC~. L~I~ VALVES ~ TO !~ 81'A~ ALL 4. PI~ LI~ TO ~ PS! ~ I~ ~1~ CI~ PEES~ TO 3000 I~! ~ HOLD FCI~ I0 M~N. ~ m~n PI~ TO 0 PSI. LI~E VALVE~. CLO~ TOI· PIPE ~ ~ H(~ VALVES 6. TEST TO 2~ PSI AI~ 3000 PS! AS IN STEP 4. ?. o:~rrI~ TESTING ALL VALVF~o LI~.So AI~ ~ A 250 PSI LOW AI~ 3000 PS! ~IGH. TEST AS IN 8. ~ TCI~ PIPE RAIvI) AN:) CL~ BOTTO~I PIPE EAIVlB. TEST l)Ol-r~ PIPE, ~ TO ~ ~I ~ ~ ~I. I0. ~ ~l~ ~ ~ ~ TO ~ ~I ~ ~ ~I. ~F~ ~ LI~ ~ ~ ~ ~I~ ~UID. ~ ~ V~ IN ~I~I~ ~ITI~ 12. ~ $T~I~ V~, ~Y, ~Y ~S. ~I~ PI~ ~ V~, ~ I~I~ ~ TO ~ ~I ~ ~ ~I. I~. ~~ ~ST I~TI~ ~ ~~ ~ ~T F~, SI~, ~ ~ TO ~I~I~ ~I~. 14. ~~~ ~ ~T~ ~I~ ~ ~Y ~ ~I~LY ~~ ~ ~Y. ' Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 9-10 9.5-10.5 9.5-10.5 Solids 10± 4-7 9-12 Drillin~ 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 In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal, , GENERAL DRILLING PROCEDURE 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 co 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 psis. 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 standing 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. .-~ DEeASSER t SHALE MUD CLEANER SHAKERS STIR ~..~ STIR _., STIR I CLEANER, LWK4 / ih TYPICAL MUD SYSTEM SCHEMATIC · *ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3Q Pad (Wells 1-16) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/dmr GRU1/44 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ..,,.! m 8 17 16 VICINITY IMP SCAL£' I" · Z MILES ALL WELLS LOCATED IN SEC. 17, TISN, R9E, UMIAT MERIDIAN. N07~S: I. AIL. CC)O,OmATES A,~ A.S.R, ZONE 4. 2.ALL. DISTAdK:EI ~ AI~ l'lK~. 3.ELEW~I'K~IS AI~ B.P. Id.S.k. 4.1~F. FIELD BOOK LN-16, Pe~I 21-22. 5. O. G. ELEVATIONS 'HOld F.R. BELL & AS~3CIATES. ~NTS PER LHD i="! 6,025,86T. K) 6,025,861.28 6,025,855.29 6,025,8 49.$6 6,025,843.37 6,025,837.44 6,025,831.43 6,025, 813.50 6,0:~5,807.25 6,025,801.31 6,02~, 795.53 6,025~ 789.31 6,025, ?85.47 6,025, 777.44 6,025, 771.55 'Y' ASPs" 'X' I LATITUDE 70° 2 8' 54.T58" 515, 959.92 515, 984.20 516,008 516,032 .St 516,056.99 516,081.28 516,105.64 516,129.72 516,202.58 516,226.82 516,251.42 516, 275. ~ 516,2t9.52 516,323.80 516,~4t.20 516,3'~.31 70° 28'54.T01" ?O0 2( 54.639" ?0o 28' 54.58C)" ?O0 28' 54.52 ?O0 28' 54.462" 7o0 28'54.40~" 70° 28' 54. 343~ 70° 28' 54. 165' 7O0 28' 54. I05" 7O0 28' 54.o44" TO0 28' 53.987" 7O° 28' 53.925" ?0o 28' 53. ~ 28' 53.8c~" ?O0 28' 53. LONGITUDE 149052' I0.512" 149° 5~' 09.798" 14ge 52' 09.0~" ~4e,, 52'06.944" 14~ 52' 06.220' ~4t, 52'o5. ~.o" 14~e52'03.370'' 14~° 52'02.665" 149° 52'01 · 942" ~46,, 52'0i .240" 14f' ~.' oo. 52O" 14~1~ 51' 59.814 14~O 51' 59.C~7'' 149° 51'58. 580" DIsLEN.L. 2 Igt' 2205° 2211' 2217' 2225' 222~' 223e' 2241' 2265' 2271' 22TT' 22O3' 22~ 2301' i'll ^"" .= Dist. F.. E.L. .0.£1 :~, 2377' 2352' 2320* 2304* 2280* 2255* 2231' 2207' 2134' 2110' 2065' 203T' 2o1~' toot' I?.1 17.1 I?.1 17.2 17.2 IT. 3 17.3 17.4 17.5 17.3 17.5 17.5 17.5 17.5 21.7 21.7 21.8 21.6 220 2LO 22.O 220 22.0 22.O 21.t 21 .t 21.6 21.t 21.0 I HEREBY CERTIFY THAT I AM PROI:~RL,Y REGISTERED Al'K) LICENSED TO PRAC- TICE LANO SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ~ OR UNDER MY SUPERVISK)N, AND THAT ALL DIMENSIONS ANO. OTHER D~TAILS ARE CORRECT AS OF 11/2/86. eeeeee · * · ° ' *~ ' e eeeee° JOHN W. TAYLOI ee D.S.$Q WELL CONDUCTOR ASBUILT [MN BY, AdH J CHI( IY, JWT DATE, II/iO/N NSK 6. 317. d3 -CHFflK LIST FOR NEW W~.~. PERMITS (2) Loc (2 thru 8) (9: t_.hru 13)/; ,:.., 10. (10 ~d 13) ' 12. 13. (3) Admin (4) Casg /~//,~ ~/.. ,.g-~4-g~ (14 thru 22) 28) (5) BOPE . 3. 4. 5. 6. 7. 8. YES Is the permit fee attached .......................................... ~.~ Is well to be located in a defined pool ................ ~ Is well located proper distance from property i~'~.i. [ ~ i i ii Is well located proper distance from other wells .... 111. [1 ....] i.. . . Is sufficient undedicated acreage available in this pool ......... ~ .... ~ Is well to be deviated and is wellbore plat included .:'...-. ..... ,'.~.:.'~ .... '~.~ Lease & Well No. ,K_,../g~'~, Y~-,~ ...... NO ~ Is operator the only affected party /~' Can permit be approved before fifteen-day wait ...................... ~-~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ............................... ' ...... Does the well have a unique name and number ......................... 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will sUrface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety' in collapse, tension and bUrst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagr~m~ and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to $ CP~ psig .. Does the choke manifold comply w/API RP-53 fMay 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER 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 (6) Add: 32 Additional requirements ' Geo logy: gngin.ee~-ing: '~ LCS ~f~BEW---' rev: 0 1151 6 6.011 UNIT ON/OFF 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING .VP OlO.H02 VERIFICATION LISTING PAGE I ~ REEL HEADER ~ ~ERViCE NAME :EDIT )ATE :87/0Z/ 8 )RIGIN : IEEL NAME :149585 ;ONTINUATIGN ~ :Oi ~REVIOUS REEL : ;OMMENTS :LIBRARY TAPE ~* TAPE HEADER ,~ ~ERVICE NAME :EDIT )ATE :871021 8 )RIGIN :FS1A FAPE NAME : ]ONTINUATION ~ :01 ~REViOUS TAPE : ~OMMENTS :LIBRARY TAPE ~ FILE HEADER ~ :ILE NAME :EDIT .00I SERVICE NAME : VERSIDN # : 2ATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : INFORMATION RECORDS MNEM CONTENTS UNIT TYPE CATE SIZE COOE I i I I CN : ARCO ALASKa, INC. 000 000 018 065 WN : 3Q-$ 000 000 004 065 FN : KUPARUK 000 000 008 065 R~NG: gE 000 000 002 065 TOWN: 13N 000 000 004 065 SECT: 1? 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065 ST~T: ~LASKA 000 000 006 065 CTRY: USA 000 000 003 065 MNEM C~NTENTS UNIT TYPE C~TE SIZE CODE IIII IItI IIII l--II .VP 010.H02 VERIFICATION LISTING PAGE 2 $ SCHLUM6ERGER ~ ,ALASKA COMPUTING CENTER ;OMPANY : ~RC~ ~L~SK~ INC ~ELL = 3Q-5 :IELD = KUPARUK :DUNTY = NORT;~ SLOPE ;TATE = ALASKA JOB NUMBER AT AKCC: 72177 ~UN ~1~ DATE LOGGED: 26-JAN-87 .DP: RICK KRUWELL 3ASING FYPE FLUID DENSITY IISCOSITY :LUID LOSS ~.AT RIX SANDS'TONE : 9.623" ~ 5055' - BIT SiZE : 8°5" T6 10145' : LSND POLYMER : 9.9 LB/G RM : 5.18 @ 69 DF = 40.0 S RMF : 4.26 @ 69 OF : 9.0 RMC : 4.5 @ 69 DF : 4.4 C3 RM AT .SHI : 2.59 ~ 1,45 OF ~OTE: REPEAT FILE MERGED WITH LOG FILE TO PRESENT DATA DOWN TO DEEPEST FIRST READING OF OF 10130' 1.) DUAL INOU:CTION REPEAT MERGE'O WITH LOG ~ 9952' / ,VP OlO.HO2 VERIFICATION LISTING PAGE 3 2.) FORMATION DENSITY REPEAT MERGEO WiTH LOG ~ 992?' 3.) COMPENSATED NEDTRON REPEAT MERGED WITH LOG @ 9912" 4.) GAMMA RAY REPEAT MERGED WITH LOG ~ 9870' 5.) THERE WILL BE AN APPARENT SP SHIFT ~ 9952' gUE TO DIFFERING VALUES OF SP FROM REPEAT T~ LOG FILED ~"'""-'-"'-,--,--,,-,- THIS DATA HAS NOT BEEN DEPTH SHIF'T~O_ - OVERLAYS FIELD PRINTS -,-".~,-,,~-,-;~ SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC T~PE: $' DUAL IND~CTION SPHERICALLY FOCUSED LOG (OIL) -~ DATA AVAILABLE: 10130 TO 506,0 ~-"- FORMATION D=NSITY~ COMPENSATED LOG (FDN) -,- COMPENSATED NEUTRON LOG (FDN) -,-'* DENSITY D~TA AVAILABLE: 10104' T~ 7840' -,- NEUTRON DATA AVAILABLE: ~10089 TO 7840 .,- GAMMA RAY IN C~SING (GR.CSG) ~ O~TA ~VAILABLE: 5049' TD .VP OtO.H02 VERIFiCATiON LISTING PAGE 4 DATA FORMAT RECORD ....... -,-~,, ~NTRY BLOCKS TYPE 2 8 9 16 0 qNEM SPECIFICATION BLOCKS SERVICE SERVICE UNiT ID ORDER ~ ]EPT FT' SFLU DIL OHMM ILD DIL OHMM ILM OIL OHMM SP OIL MV 2R DIL GAPI TENS DIL LB ~R FDN G4PI CALI FDN iN RHOB FDN G/C3 DRHO FDN G/C3 NRAT FON RNRA FDN NPHI FDN PU DPHI FDN PU NCNL FON CPS FCNL FON CPS TENS FDN LB GR CSG GARI TENS CSG L8 SIZE 1 1 4 I 1 APl 4Pi LOG TYPE CLASS O0 000 O0 O0 220 01 O0 120 46 O0 120 44. O0 010 Ol O0 310 01 O0 635 21 O0 310 Ol O0 280 01 O0 350 OZ O0 356 O1 O0 420 O1 O0 000 O0 O0 890 O0 O0 890 O0 O0 330 31 O0 330 30 O0 635 21 O0 310 O1 O0 635 21 REP R CODE ,66 6~ 65 66 66 API FILE MOO NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S! :ENTRY 0 1 60 .lin 1 O. ZE SPL 4. 1 4 1 4 ! 4 1 4 1 4 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 REPR CODE 68 68 68 6a 68 68 68 PROCESS (OCTAL) O00OO000000000 00000000000000 000.00000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 -,-.- D~TA DEPT SP CALI RNRA FCNL DEPT SP CALi RNRA FCNL 10161.0000 SFLU -44.6875 GR 6.7305 RH05 3.3770 NPHI 603.5000 TENS 10100.0000 -42.8750 GR 7.3085 3.5410 NPHi 594.5000 TENS 7.1715 91.3125 2.0977 ~+1. 8457 1035.0000 4.2276 92.5000 2.2168 37.8905 4588.0000 ILO TENS DRHO DPHi GR ILO TENS DRHO DPHZ GR 6.1400 1035.0000 0.0933 33.~520 -999.2500 4.0530 ~588.0000 0.0693 26.2621 -999.2500 ILM 8.5589 GR 91.3125 NRAT 3.3047 NCNL 2039.0000 TENS -999.2500 ILM 4.2731 GR 92.5000 NRAT 3.1230 NCNL 2106.0000 TENS -999.2500 .VP OlO.H02 VERIFiCATiCN LISTING PAGE 5 )EPT ;P :ALI ~NRA :CNL )EPT ~P ;ALI ~NRA :CNL )EPT ~P iALI ~NRA :CNL )EPT 5P ;ALI qNRA :CNL DE PT SP CALI RNRA FCNL DEPT SP ~ALI RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALi RNRA FCNL DEPT SP CALi RNRA FCNL 10000,0000 SFLU -32,2500 GR 8.7500 RH08 3.4766 NPHi 559,0000 'TENS 9900,0000 SFLU -36.6563 GR 8,8828 RHOB 3.3418 NPHI 589.5000 TENS 9800.0000 SFLU -54.5000 GR 8.6797 RHC~ 2.7676 NPHI 931.0000 TENS 9700.0000 SFLU -31.1562 GR 9,2422 RHO8 3.5391 NPHI 485,5000 TENS 9600,0000 SFLU -26,0156 GR 9,6094 RHOB 3,6797 NPHI 499,0000 TENS 9500,0000 SFLU -17.6406 GR 9,5859 RH05 4,1523 NPHI ~11.7500 TENS 9400,0000 SPLU -16,8750 GR 9,2813 RH06 4.0352 NPHI 439,0000 TENS 9300,0000 SFLU -19.2656 GR 8,8359 RH05 3,1367 NPHI 754.0000 TENS 9200.0000 SFLU -25.5156 GR 9.9219 RHOB 3,7422 NPHI 458.7500 TENS 4,0316 ILD 237.8750 TENS 2.3906 DRHO 39,9414 DPHI 4488,0000 GR 4.6757 ILO 99.5625 TENS 2,3652 DRHO 41.3574 DPHI 4420,0000 GR 66,9338 ILD 55,4688 TENS 2,2637' DRHO 30,5664 DPHI 420.4.0000 GR 3,8706 ILO 93,5625 TENS 2,33'79 DRHO 42,5'781 DPHI 4268.0000 GR 2,9583 ILD 109,3125 TENS 2,4199 DRHO 40,8691 DPHI 4200,0000 GR 3.7149 ILD 131.0000 TENS 2.3418 DRHO 47,1680 DPHI 4108,0000 GR 5,8110 ILD 212.8750 TENS 2,3887 DRH~ 4~.6289 DPHI 4034.0000 GR 3.4829 ILO 293.0000 TENS 2.5332 DRHO 34.8145 DPHI 3930.0000 GR 6.6250 iLD 211.3750 TENS 2.3672 DRHO ~2.2552 DPHi 3830.0000 GR 4,0374 ILM 4~88,0000 GR 0,0337 NRAT 15,7281 NCNL -999'2500 TENS 4.5238 ILM 4420,0000 GR -0'0010 NRAT 17,2668 NCNL -999,2500 TENS 45,2018 ILM 4204,0000 GR -0,0054 NRAT 23,4215 NCNL -999,Z500 TENS 2,6024 ILM 4268.0000 GR 0.0391 NRAT 18.9238 NCNL -995.2300 TENS 3.3586 ILM 4200.0000 GR 0.0166 NRAT 13.9527 NCNL -999.2500 TENS 3,6004 tLM 4108,0000 GR 0,0049 NRAT 18,6871 NCNL -999.2500 TENS 5.2520 ILM 4054.00~0 GR -0.0024 NRAT 15.8465 NCNL -999,2500 TENS 3.8566 ILM 3950.0000 GR 0,0054 NRAT 7.0879 NCNL -999.2500 TENS 5.8525 ILM 3830.0000 GR 0.0176 NRAT 17.1484 NCNL -999.2500 TENS 4. 143.2 237.8750 3.. 3438 1944,0000 -999,2500 4.6974 99.5625 3.4316 1970.0000 -999.2500 44.8484 55.468B 2.7910 2578,0000 -999.,2500 2.7637 93.5625 3.52'73 1719.0000 -999.2500 3.2635 109.3125 3.4629 1837.0000 -999.2500 3.7031 131.0000 3.8047 1710.0000 -999.2500 5.2567 212,8750 3.6426 1772.0000 -999.2500 4.0480 293.0000 3.0703 2366.0000 -999.2500 5.7319 211.3750 3.5664 1717.0000 -999.2500 .VP OlO,H02 VERIFICATION LISTING PAGE 6 DEPT :ALi RNRA =CNL DEPT SP CALI RNRA ~CNL DEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL OEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALl RNRA FCNL DEPT SP CALl RNR~ FCNL 9t00,0000 SFLU -24.3906 GR 10,4063 RHOB 3.3047 NPHi 559.0000 TENS 9000.0000 SFLU -40.6563 GR 10,0938 RHO5 3,6328 NPHi 548,5000 TENS 8900,0000 SFLU -48,9062 G.R 10.976,5 RHO8 3.334'0 NPHI 585.5000 TENS 8800.0000 SFLU -38,1250 GR 9,4609 RHOB 3.1387 NPHI 704.0000 TENS 8700,0000 SFLU -28.2656 GR 11.0547 RHO5 3.2168 NPHI 703.5000 TENS 8600.0000 SFLU -14.8906 GR 8.8828 RHOB 3.1133 NPHI 763.5000 TENS 8500.0000 SFLU -15,3828 GR 8.8750 RH05 3.4727 NPHI 631.5000 TENS 8400.0000 SFLU -20.2656 GR 9.4609 RH05 3.6074 NPHi 535.0000 TENS 8300.0000 SFLU -25.8905 GR 9.8516 RHO5 3.3047 NPHi 618.5000 TENS 4.9748 165.0000 2.3965 39.8437 3760.0000 3.5160 119.5000 2.3965 36.1816 3834.0000 4.4672 116.1250 2.4375 34.7656 3764.0000 4.8128 96.2500 2.4668 34.3750 395&.0000 4.3077 106.3125 2.4283 34.4238 3934.0000 1.8939 85.8750 2.37?0 31.8359 4034.0000 1,8588 101.6250 2,3516 42.0410 4000.0000 1,8576 94.8750 2.4258 40.3809 4034,0000 3.5223 130,7500 2.4063 35.5957 394~.0000 ILO TENS DRHO DPHi GR ILD TENS DRHO DPHI GR ILO TENS DRHO DPHI GR ILD TENS DRHO DPHi 6R T~NS DRHO DPHI GR iLD T~NS DRHD DPH~ TENS DPHI GR ILD TENS DRHO DPHI GR ILD TENS DRHO DPHI GR 4.9067 ILM 376.0.0000 GR 0.0244 NRAT 15.3730 NCNL -999. 2500 ~TENS 3.9002 ILM 3834,0000 GR 0,0234 NR~T 15-3730 NCNL -999,2500 TENS 4,6987 ILM 3764.0000 GR 0,0488 NRAT 12,8875 NCNL -99~,2500 TENS 5,6296 ILM 3954,0000 GR 0,0171 NRAT 11,1121 NCNL -999.2500 TENS 6.8678 ILM 3934,0000 GR 0,0156 NRAT 9.8102 NCNL -999.2300 TENS 2.0468 ILM 4034.0000 GR 0.0122 NRAT 16.5566 NCNL -999.2500 TENS 2,2387 ILM 4000,0000 GR 0.0400 NRAT 18,0953 NCNL -999.2500 TENS 2.0362 ILM 4034.0000 GR 0.0535 NRAT 13.5977 NCNL -999.2300 TENS 3.9244 ILM 3944.0000 GR 0.0444 NRAT 14.7812 NCNL -999.2500 TENS 4,7976 166.0000 3.4727 1848,0000 -999.2500 3,95.28 119,5000 3,2580 1993.000'0 -999.2500 4,6872 116,1250 3,2266 1953,0000 -999.2500 5.8023 96.2500 3.0977 Z210.O000 -999.2500 4.9356 106,3125 3,2109 2264.0000 -999.2500 2.0734 85.8750 2.8926 2378.0000 -999.2500 2.2949 101.6250 3.4688 2194.0000 -999.2500 2.1432 94.8750 3.4238 1931.0000 -999.2500 3.9586 130.7500 3.1953 2045.0000 -999.2500 .VP OIO.H02 V!ER!FtCATION LISTING PAGE 7 )E PT ;P ;ALI ~NRA :CNL )EPT ~P :ALI ~NRA :C NL )EPT ~P :ALI ~NRA :CNL DEPT ~P 2, ALi ~:NRA :C NL ]EPT :ALI ~NRA :CNL DEPT SP :ALI RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALi RNRA FCNL DEPT SP CALI RNRA FCNL 8200,0000 SFLU -23.4844 GR 9,4141 RHOB 3,6426 NPHI 545.5000 TENS 8100.0000 SFLU -33.7813 GR 10.2031 RHOB 3.1719 NPHI 586,5000 TENS 8000,0000 SFLU -13.8906 GR 8 · 9766 RHOB 3,3418 NPHI 586,5000 TENS 7900,0000 SFLU -20,1406 GR 9.4922 RHO5 3.5352 NPHi 544,5000 TENS 7800.0000 SFLU -18,6563 GR -999,2500 RHO5 -999,2500 NPHi -999,2500 TENS 7700,0000 SFLU -24,1406 GR -999.2500 RH08 -999,2500 NPHI -999,2500 TENS 7600,0000 SFLU -33.7500 GR -999.2500 RHOB -999.2500 NPHZ -999.2500 TENS 7500.0000 SFLU -20.6406 GR -999.2500 RHOB -999,2500 NPHI -999.2500 'TENS 7~00,0000 SFLU -19.9219 GR -999.2500 RHOB -999.2500 NPHi -999.2500 'TENS 2,7711 ILO 117.43'75 TENS 2,3613 DRHO 42,8223 DPHi 3680.0000 GR 3.6462 ILD 148.8750 TENS 2.4336 DRHO 40.2344 OPHI 3644.0000 GR 2.0.376 ILO 97.0625 TENS 2,3613 DRHO 40.3320 DPHi 3610.0000 GR 2,0327 ILD 82,0625 TENS 2,3965 DRHO 40,7227 OPHI 3694.0000 GR 1.8346 ILD i04,5000 TENS -999,2500 DRHO -99.9.2500 DPHI -999.2500 GR 3.2745 ILO 110.3750 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 GR 2.8776 I:LD 113.8750 TENS -9:99.2500 DRHD -999.2500 DPHI -999.2500 6R 2,4700 ILO 92,1250 TENS -999,2500 DRHO -999,2500 DPHI -999,2300 GR 3.026~ iLO 109.6873 TENS -999.2500 DRHO -999.2500 DPHI -9~9.2500 GR 3.1791 !LM 3680.0000 GR -0.0005 NRAT 17.5035 NCNL -999,2500 TENS 4,1727 ILM 3644,0000 GR 0,0220 NRAT 13,1242 NCNL -999.2500 TENS 2,0610 ILM 3610,0000 GR 0,0278 NR~T 17,5035 NCNL -999.2500 TENS 2,1950 ILM 3694,0000 GR 0,0259 NRAT 15,3730 NCNL -999,2500 TENS 2.1149 ILM 3800.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 2.9367 ILM 3764.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 3,2567 ILM 3634,0000 GR -999.2500 NRAT -9'99.2500 NCNL -999.2500 TENS 2,6958 ILM 3824.0000 GR -999.2300 NRA'T -999.2500 NCNL -999.2500 TENS 3.2163 !LM 3590.0000 GR -999.2~00 NRAT -999.2300 NCNL -999.2500 TENS 3.1534 117.4375 3.5547 1988.0000 -999.2500 4,2261 148,8750 3,4766 1861,0000 -999,2500 2.0833 97.0625 3.3809 1961.0000 -999.2500 2.2434 82,0625 3.4453 1925.0000 -999.2500 2.0854 -999.2300 -999.2500 -999.2500 -999.2500 3.0270 -999.2500 -999.2500 -999.2500 -999.2500 3.2605 -999.2500 -999.2500 -999.2500 -999.2500 2.7134 -999.2500 -999.2500 -999.2500 -999.2500 3.2476 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 8 ]EPT ~P :ALI ~NRfl :CNL DEPT SP :ALI RNRA ~ C N L DEPT SP CALI ~NRA ~CNL DEPT SP C A L i RNRA F~C NL DEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL OEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL OEPT SP CALi RNRA FCNL 7300.0000 SFLU -16.4063 GR -999.2500 RH05 -999,2500 NPHI -999,2500 TENS 7200,0000 SFLU -18,2500 GR -999.2500 RHO5 -999,2500 NPHZ -999,.2500 TENS 7100,0000 SFLU -15.6328 GR -999,2500 RH05 -999,2500 NPMI -999. 2500 TENS 7000,0000 SFLU -16.6563 GR -999,2500 RHOB -999.,2500 NPHZ -999,2500 TENS 6900,0000 SFLU -19,2813 GR -999,2500 RHO5 -999,2500 NPHZ -999.2500 TENS 6800,0000 SFLU 6.1211 GR -999.2500 RHOB -999.2500 NPHI -999.2500 TENS 6700,0000 SFLU 17,7344 GR -999,2500 RH05 -999,2500 NPmI -999,2500 TENS 6600,0000 SFLU 15.0938 GR -999.2500 RHOB -999,2500 NPHi -999.2500 TENS 6500.0000 SFLU 20.9844 GR -999.2500 RHOS -999.2500 NPHi -999.2500 TENS 3.3450 ILD 87.7500 TENS -999,2500 CRHO -999.2500 OPHI -999,2500 GR 4.0261 ILO 110,5000 TENS -99:9.2500 DRHO -999.2500 OPHI -999,2500 G~. 3,0295 ILD 58,9375 TENS -999,2500 DRHD -999,2500 DPHI -999,2500 GR .2,9436 ILD 108,8'750 'TENS -999,2500 DRHD -999,2500 DPHI -999.2500 GR 3,0249 ILD 110.0625 TENS -999,2500 DRHO -999,2500 DPHI -999.250'0 GR 2,4395 ILD 105.0625 TENS -999.2500 DRHO -999.2500 DPHI -999,2500 GR 2.5281 ILD 115,1250 TENS -999,2500 DRHO -999.2500 DPHI -999.2500 GR 3,4304 ILD 107.2500 TENS -999.2500 DRHO -999.2500 DPH! -999.2500 GR 3,6871 iLD 90.8750 TENS -999.2500 CRHO -999.2500 DPHI -999.2500 GR 3,9591 ILM 3614,0000 GR -999,2500 NRAT -999.2500 NCNL -999.2500 TENS 4,5160 ILM 3484,0000 GR -999,2500 NRAT -999,2500 NCNL -999,2500 TENS 3.5148 ILM 3544.0000 GR -999.2500 NRAT -999.2500 NCN~L -999.2500 TENS 3.2638 ILM 3530.0000 GR -999.2500 NRAT -999,2500 NCNL -999,2500 TENS 3.3229 ILM 3404.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 .TENS 3,0230 tLM 3274.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 2.7992 ILM 3650.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 3.6764 ILM 3184.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.9629 iLM 3244,0000 GR -999.2500 NRAT -999.2500 NCNL -999,2~00 TENS 4.1336 -999.2500 -999,2500 -999,2500 -999,2500 4,2697 -999,2500 -999,2500 -999,2500 -999,2500 3.4546 -999.2500 -999.2500 -999.2500 -999.2500 3.2466 -999.2500 -999.2500 -99:9.2500 -999.2500 3.3090 -999.2500 -999.2500 -999.2500 -999.2500 2.9612 -999,2500 -999.2500 -999.2500 -999.2500 2.7565 -999.2500 -999.2500 -999.2500 -999.2500 3.6539 -999.2500 -999.2500 -999.2500 -999.2500 3.9984 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 9 ).EFT 6400.0000 SFLU ;P 23.7031 GR ;ALI -999.2500 ~NRA -999.2500 NPHi :CNL -999.2500 TENS )EFT 6300.0000 SPLU iP 24.1250 GR 'ALI -999.2500 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EFT 6200.0000 SFLU ~P 26.8594 GR ~ALI -999.2500 RHOB ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EFT 6100.0000 SFLU ~P 28.4844 GR :.ALI -999.2500 RHDB ~NRA -999.2500 NPHI :CNL -999°2500 TENS ]EFT 6000.0000 SFLU ~P 24.9844 GR :ALI -999.2500 RHO5 ~NRA -999.2500 NPHi :CNL -999.2500 TENS )EFT 5900.0000 SFLU 5P 26.?344 GR :ALI -999.2500 RH08 ~NRA -999.2500 NPHI =CNL -999.2500 TENS 3EFT 5800.0000 SELU 5P 25.5781 GR :ALI -999.2500 RHg~ RNRA -999.2500 NPHI :CNL -999.2500 TENS 3EPT 5700.0000 SFLU SP 24.3281 GR CALi -999.2500 RHO5 RNRA -999.2500 NPHI FCNL -999.2500 TENS DEFT 5600.0000 SFLU SP -0.774~ GR CALI -999.2500 RHO5 RNRA -999.2500 NPHI FCNL -999.2500 TENS 2.8762 ILD 90.2500 TENS · -999.2500 DRHO -999.2500 DPHI -999.2500 GR 3.0913 ILO 100.7500 TENS .-999.2500 DRHO -999.2500 DPHI -999.2500 GR 2.6423 ILD 96.0000 TENS · -999.2500 DRHO -999.2500 DPHI -999.2500 GR 2.4608 ltd 101.4375 TENS -999.2500 DRHD -999.2500 OPHI -999.2500 GR 2.8804 ILD 91.1875 TENS -999.2500 gRHO -999.2500 DPHI -999.2500 GR 3.1932 ILD 89.5000 'TENS -999.2500 DRHO -999.2500 DPHI -9'99.2500 GR 0.5341 ILD 96.0625 TENS -999.2500 DRHg -999.2500 DPHI -999.2500 GR 0.8129 ILO 102.3750 TENS -999.2500 DRHD -999.2500 DPHi -999.2500 GR 2.3672 ILD 109.6230 TENS -$99.2500 DRHO -999.2500 DPHI -999.2500 GR 3..12~5 ILM 3224.0000 GR -999,2500 NR~T -999.2500 NCNL -999.2500 TENS 3.4656 ILM 2990.0000 GR -999.2500 NRAT -999.2500 NCN!L -999.2500 TENS 2.94~9 ILM 2960.00'00 GR -999.250'0 NRA'T -999.2500 NCNL -999.2500 TENS .2.7343 iLM 2840.0000 GR -999.2500 NRAT -99~.2500 N'CNL -999.2500 TENS 3.35~7 ILM 2840.00'00 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 3.3023 ILM 2734.0000 GR '-999.2500 NRAT · -999.2500 NCNL -999.2500 TENS 0.0693 ILM 2694.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 0.2445 ILM 2720.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 2.7928 ILM 2574.0000 GR -999.2500 NR~T -999.2500 NCNL -999.2500 TENS 3.1478 -999.2500 -999.2500 -999.2500 -999.2500 3.3975 -999.2500 -999.2500 -999.2500 -999.2500 2.887'9 -999.2500 -999.2500 -999.2500 -999,2500 2.6655 -999.2500 -999.2500 -999.2500 -999,2500 3.2436 -999.2500 -999.2500 -999.2500 -999.2500 3.0530 -999.2500 -999.2500 -999.2500 -999.2500 0.1836 -999.2500 -999.2500 -999.2500 -999.2500 0.4926 -999.2500 -999.2500 -999.2500 -999.2500 2.7365 -999.2500 -999.2500 -999.2500 -999.2500 .VP OiO.HOZ VERIFICATION LISTING PAGE 10 )EPT 5500.0000 SFLU ;P -15.7578 GR :ALI -999.2500 RHOB {NRA '-999,2500 NPHI :CNL -999,.2500 TENS )EPT 5400.0000 SFLU ~P -11,4297 GR ~ALI -999.2500 RH06 ~NRA -999,2500 NPHI :CNL -999,2500 TENS )EPT 5300.0000 SFLU ~P 7.3320 GR ~ALI -999,2500 RHOB ~NRA -999,2500 NPHI =CNL '-999,2500 'TENS 3EPT 5200.0000 SFLU ~'P 14.9922 GR ~ALI -999.2500 RHO5 ~NRA '-999,2500 NPHi =CNL -999,2500 TENS ]EPT 5100.0000 SFLU SP 15.0781 GR ;ALI '-999.2500 RHOB RNRA -999,2500 NPHi =CNL -999.2500 TENS DEPT 5000.0000 SFLU SP -999.2500 GR SALI -999.2500 RHOB ~NRA -999.2500 NPHi =CNL -999.2500 'TENS 3EPT 4900.0000 SFLU SP -999.2500 GR SALI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS DEPT 4800.0000 SFLU SP -999.2500 GR CALI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 TENS DEPT 4700.0000 SFLU SP -999.2500 GR CALl -999.2500 RHO5 RNRA -999.2500 NPHI FCNL -999.2500 TENS 3.6439 iLO 90.6250 TENS -999,2500 DRHO -999.2500 DPHI -999.2500 GR 2.9702 iLD 92.3750 TENS -999.2500 DRHO -999.25:0'0 DPHi -999.2500 GR 2.9232 ILO 89.3750 :TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 2,9088 ILO 93,6250 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR 3.6917 ILO 98.8750 TENS -999.2500 DRHO -999.~500 OPM! -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 ILD -999.2500 TENS -9'99.2500 DRHO -999.2500 DPHi -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999,2500 ~PHi -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHD -999.2500 DPHI -999.2500 GR 4.,2501 ILM 2580,0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 2,8755 ILM 2620.0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 3.1983 ILM 2490,0000 GR -999.2500 NRAT -999.2500 NCNL -999,2500 TENS 3,2633 ILM 2500.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 TENS 4.1191 ILM 2554.0000 GR -999.2500 NRaT -999,2500 NCNL 67.5625 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 60.6250 TENS -999,2500 ILM -999,2500 GR -999.2500 NRAT -999.2500 NCNL 50.0625 TENS -999.2500 iLM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 55.7813 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 42.5000 TENS 4.1656 -99'9.2500 -999.2500 -999.2500 -999.2500 2.8438 -999,2500 -999,2500 -999.2500 -9'99,2500 3.2496 -999.2500 -999.2500 -999.2500 -999.2500 3.2397 -999.2500 -999.2500 -999.2500 -999.2500 4,0283 -9'99,2500 -999.2500 -99'9,2500 2824,0000 -999.2500 -999.2500 -999,2500 -999.2500 2464.0000 -999.2500 -999.2500 -999.2500 -999.2500 2444.0000 -999.2500 -999.2500 -999.2500 -999.2500 2420.0000 -999.2500 -999,2500 -999.2500 -999.2500 2384,0000 .VP OlO.H02 VERIFICATION LISTING PAGE I1 )EPT 4600.0000 SFLU ~p -999.2500 GR ;ALI -999.2500 RHOB ~NRA -999,2500 NPHI =CNL -999,2500 TENS )EPT 4500,0000 SFLU ~p -999,2500 GR ;ALI -999,2500 RHO~ ~NRA -999,2500 NPHI :CNL -999,2500 TENS )EPT 4400.0000 SFLU ~P -999,2500 GR ;ALI -999.2500 RHO~ ~NRA -999,2500 NPHI :CNL -999,2500 TENS )EPT 4300,0000 SFLU ~P -999,2500 GR ]ALI -999.2500 RHOB ~NRA -999,2500 NPHI =CNL -999,2500 TENS ]EPT 4200.0000 SFLU 5P -999,2500 GR ;AL1 -999,2500 RH05 ~NRA -999,2500 NPHI =CNL -999.2500 TENS ]EPT 4100.0000 SFLU ~P -999,2500 GR ;ALI -999.2500 RHO5 ~NRA -999.2500 NPHI :CNL -999.2500 TENS )EPT 4000.0000 SFLU SP -999.2500 GR 3ALI -999,2500 RHO~6 RNRA -999.2500 NPHI ;CNL -999.2500 TENS DEPT 3900.0000 SFLU SP -999,2500 GR CALI -999.2500 RH06 RNRA -999.2500 NPHZ FCNL -999,2500 TENS DEPT 3800.0000 SFLU SP -999.2500 GR CALl -999.2500 RHO5 RNRA -999.2500 NPHi FCNL -999.2500 TENS -999,2500 ILD -999,2500 TENS -999,2500 DRHO -999,2500 DPHI -999,2500 GR -999.2500 ILD -999,2500 TENS -999,2500 DRMD -999,2500 DPHI -999,2500 GR -999,2500 ILD -999.2500 TENS -999,2500 DRHO -999.2500 DPHI -999,2500 GR -999,2500 ILD -999,2500 TENS -999,2500 ORHO -999,2500 DPHI -999,2500 GR -999.2500 iLD -999,2500 TENS -999,2500 DRHO -999.2500 DPHI -999,2500 GR -999.2500 tLD -999.2500 TENS '-999.2500 OReO -999.2500 DPHI -999.2500 GR -999,2500 ILO -999,2500 TENS -999,2500 DRHO -999,2500 DPHI -999,2500 GR -999.2500 ILD -999,2500 TENS -999,2500 DRH~ -999,2500 CPHI -999,2500 GR -999.2500 ILD -999.2500 %ENS -999,2500 DRHO -999.2300 CPHI -999.2500 GR -999,2500 !LM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 53.3438 TENS -999,2500 ILM -999,2500 GR · -999.2500 NRAT -999,2500 NCNL 58.7188 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 64.8750 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 46.0938 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 54,2187 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 41.3125 TENS -99'9,2500 ILM -9'99,2500 GR -999,2500 NRAT -999,2500 NCNL 28,6250 TENS -999,2500 iLM -999,2500 GR -999,2500 NRAT -999.2500 NCNL 48.7188 TENS -999.2500 iLM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 23.3125 TENS -999,2500 -999,2500 .-999,2500 -999,2500 2414-0000 -999.2500 -999.2500 -999.2500 -999.2500 2374.0000 -999.2500 -9:99,2500 -999.25'00 -999,2500 2304,0000 -999.2500 -999.2500 -999.2500 -999.2500 2250,0000 -999-2500 -999.2500 -999.2500 -999.2500 2224.0000 -999.2500 -999.2500 -999.2500 -999.2500 2294.0000 -999,2500 -999,2500 -999,2500 -999,2500 2240,0000 -999.2500 -999.2500 -999,2500 -999.2500 2210,0000 -999.2500 -999.2500 -999.2500 -999.2500 2140.0000 LVP OiO.HOZ VERIEICATION LISTING PAGE 12 DEPT SP CALI RNR4 F C N L DEPT SP CALI RNRA FCNL DEPT sp CALI RNRA FCNL DEPT sP CALI RNR.~ F C N L DEPT SP CALI RNRA FCNL OEPT SP CALl RNRA FCNL DEPT sP CALI RNR4 FCNL DEPT SP CALI RNRA FCNL OEPT SP CALI RNRA FCNL 3700.0000 SFLU -999,2500 GR -999,2500 RH08 -999-2500 NPHI -999.2500 TENS 3600,0000 SFLU -999,2500 GR -999.2500 RH08 -999,2500 NPHi -999.2500 TENS 3500.,0000 SFLU -999,2500 GR -999,2500 RHOB -999,2500 NPHI -999,2500 TENS 3400,0000 SFLU -999.2500 GR -999,2500 RHOB -999,2500 NPHI -999,2500 TENS 3300.,0000 SFLU -999,2500 GR -999,2500 RHD5 -999,2500 NPMI -999,2500 TENS 3200,0000 SFLU -999.2500 GR -999,2500 RHOB -999,2500 NPHi -999,2500 TENS 3100,0000 SFLU -999,2500 GR -999.2500 RH06 -999.2500 NPHi -999,2500 TENS 3000,0000 SFLU -999,2500 GR -999,2500 RHgB -999.2500 NPHZ -999,2500 TENS 2900.0000 SFLU -999.2500 GR -999,2500 RHD5 -999.2500 NPHZ -999.2500 TENS -999,2500 -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999,2500 GR -999,2500 ILO -999,2500 TENS ,-999.2500 DRHD -999.2500 DPNI -999.2500 GR -999.2500 I:LD -999,2500 TENS -999.2500 DRHO -999.2500 OPHi -999.2500 GR -999,2500 ILO -999,2500 TENS -999.2500 ORHO -99~9,2500 DPHi -999,2500 GR -999,2500 ILD · -999,2500 TENS -999,2500 DRHO -999,2500 DPHI -9919,2500 GR -999,2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 GR -999,2500 ILO -999,2500 TENS -999,2500 DRHO -999.2500 OPHI -999,2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 ILD -999,2500 TENS -999.2500 DRHO -999,2500 DPHI -999.2500 GR -999.2500 ILM -999,2500 GR -999.2500 NRAT -99'9,2500 NCNL 23.9375 TENS -999,2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 51.3438 TENS -999,2500 ILM -99'9.,2500 GR -999,2500 NRAT -999,2500 NiCNL 58.5313 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 33.4063 TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999..2500 NCNL 44.4688 TENS -999,2500 ILM -999.25'00 GR -999,2500 NRAT -999,2500 NCNL 25.7856 TENS' -999.2500 ILM -999,2500 GR -999,2500 NRAT -999.2500 NCNL 61.0313 TENS -999,2500 ILM -999,2500 GR -999.2500 NRAT -999.2500 NCNL 47.5313 TENS -999.2500 ILM -999.2500 GR -999.2500 NR~T -999.2500 NCNL 42.?500 TENS -999,2500 -999,2500 .-999,2500 .-999,2500 2064,0000 .-999,2500 .-999.2500 -999,2500 -999,2500 2064,0000 -999,2500 -999,2500 -999,2500 -999,2500 2025,0000 -999.250:0 -999.2500 -999.2500 -999.2500 2045,0000 -999.2500 -999.2500 -999.2500 -999.2500 1955.0000 -999,2500 -999,2500 -999.2500 -999.2500 1930.0000 -999.2500 -999.2500 -999.2500 -999.2500 1875.0000 -999.2500 -999.2500 -999.2500 -999.2500 1885.0000 -999.2500 -999.2500 -999.2500 -999,2500 1865,0000 .VP OlO.H02 VERiFICAT!GN LiSTiNG PAGE' 13 )EPT 5P ;ALi ~ N R A :CNL DEPT ~P ~ALI ~NRA :CNL )EPT ~P iALI RNR A :C NL ]EPT 5P ]ALI RNRA =CNL ]EPT 5P SALI RNRA :CNL ]EPT SP SALi RNRA FCNL DE PT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL 2800.0000 SFLU. -999,2500 GR -999,2500 RH05 -999,2500 NPHI -999,2500 TENS 2700.0000 SFLU -999.2500 GR -999.2500 RH05 -999,2500 NPHI -999.2500 TENS 2600.0000 SFLU -999,2500 GR -999,2500 RHD5 -999,2500 NPHI -999,2500 TENS 2500.0000 SFLU -999,2500 GR -999,2500 -999,2500 NPHI -999,2500 TENS 2400,0000 SFLU -999,2500 GR -999,2500 -999,2500 NPHI -999,2500 TENS 2300.0000 SFLU -999.2500 GR -999,2500 RHOB -999,2500 NPHI -999,2500 TENS 2200,0000 SFLU -999,2500 GR -999,2500 RHO~ -99'9,2500 NPHi -999.2500 TENS 2100.0000 SFLU -999,2500 GR -999,2500 RH05 -999,2500 NPHI -999.2500 TENS 2000.0000 SFLU -999.2500 GR -999.2500 -999.2500 NPHI -999.2500 TENS -999.2500 ILO -999,2500 TENS -999.2500 ~RHD -999.2500 OPHi -999,2500 GR -999.2500 IiLD -999,2500 TENS -999,2500 DRHO -999.2500 DPHI -999,2500 GR -999.2500 iLO -999,2500 TENS -999,2500 ORHD -999.,2500 DPHZ .-999,2500 GR -999,2500 ILD -999,2500 TENS -9'99.2500 ~RHG -99:9,2500 OPHI '-999,2500 GR -999.2500 ILD -999,2500 TENS .-999,2500 DRHO -'999.2500 DPHi -999.2500 GR -999,2500 I'LD -999,2500 TENS -999,2500 DRHO -999,2500 OPHI -999.2500 GR -999,2500 ILO -999,2500 TENS -999,2500 DRHO -999.2500 OPHI -999.2500 GR -999,2500 ILD -999,2500 TENS -999.2500 ~RHC -999.2500 DPHI -999.2500 GR -999.2500 iLD -999,2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999.2500 ILM -999.2500 GR -999.2500 NRAT -999,2500 NCNL 39.1562 TENS -999.2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 33,3?50 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999.2500 NCNL ~8'0000 TENS .-999,2500 !LM -999,2500 GR -999,2500 NRAT -999,25'00 NCNL ~6.9062 TENS -999.2500 ILM -999'2500 GR -999.2500 NRAT -999.2500 NCNL 30.8750 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 37.2500 TENS -999.2500 iLM -999.2500 GR -999.2500 NR~T -999.2500 NCNL 45.2813 TENS -999,2500 ILM -999.2500 GR -999,2500 NRAT -999.2500 NCNL 43,7500 TENS -999.2500 iLM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 31.5719 TENS -999.2500 -999,2500 -999.2500 -999.2500 1775.0000 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1805.0000 -999.2500 -999.2500 -999.2500 -999.2500 1790.0000 -999,2500 -999,2500 -999.2500 -999,2500 1780.0000 -999,2500 -99'9,2500 -999,2500 -999,2500 1760.0000 -999.2500 -999.2500 -999.2500 -999.2500 1775.0000 -999,2500 -999,2500 -999.2500 -999,2500 1780,0000 -999.2500 -999.2500 -999.2500 -999.2500 1730,0000 .'VP OlO.HO2 VERIFICATION LISTING PAGE 14 DEPT ~P :ALI ~NRA :CNL DEPT ~P 3ALI ~N RA =CNL ]EPT SP 2ALi RNRA :CNL DEPT SP ~ALI RNRA =CNL DEPT SP ~ 4 L i RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALi RNRA FCNL OEP'T SP CALl RNRA ECNL DEPT SP CALl RNRA ECNL 1900.0000 SFLU -999.2500 GR -999.2500 RHOB -'999,2500 NPHI -999.2500 TENS 1800.0000 SFLU -999.2500 GR -999.2500 -999,2500 NPHI -999.2.500 TENS 1700,0000 SFLU '-999.2500 GR -999.2500 RH05 -999.2500 NPHI -999,2500 TENS 1600.0000 SFLU -999,2500 GR -999,2500 RHOB -999.2500 NPHI -999.2500 TENS 1500.0000 SFLU -999,2500 GR · -999,2500 RH05 -999.2500 NPHI -999.2500 TENS 1400.0000 5FLU -999.2500 GR -999 500 RH05 oo.oooo -999.2500 GR -999.2500 RHO6 -999.2500 NPHI -999.2500 TENS 1200.0000 SFLU -999.2500 GR -999.2500 RHOE -999,2500 NPHI -999.2500 TENS 1100.0000 SPLU -999.2500 GR -999.2500 RHO~ -999.2500 NPHI -999.2500 TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.2500 -999,2500 -999,2500 -999.2500 .-999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -959.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILO TENS DRHG DPHi GR iLD TENS DRHO DPHI GR ILD 'TENS DRHO ~PHI $R ILD TENS DRHO OPHl GR iLO TENS DRHO DPHI GR ILO TENS DRHO DPHI GR iLD 'TENS DRHO DPHi GR TENS DRHO OP~l GR IhD TENS DRHO DPHI GR -999.2500 -999.2500 -999.2500 -999.2500 20.5156 -999.2500 '-999,2500 -999,2500 -9:99.2500 42,2500 -999,2500 -999,2500 -9'99,2500 -999,2500 ~0.6250 -999,2500 -999.2500 '-999.2500 -999.2500 21.8437 -999,2500 -999,2500 -999,.2500 -999.2500 30.7969 -999.2500 -999.2500 -999.2500 -999.2500 16.17i9 -999.2500 -999.2500 -999.2500 -999.2500 39.6563 -999.2500 -999.2500 -999.2500 -999.2500 39.0313 -999.2500 -999.2500 -999.2500 -999.2500 44.9687 iLM GR NRAT N:CNL TENS iLM GR NRAT NCNL TENS ILM GR NRAT NCNL TENS ILM GR NRAT NCNL TENS ILM GR NRAT NCNL TENS ILM GR NR~T NCNL TENS ILM GR NRAT NCNL TENS ILM GR NRAT NCNL TENS ILM GR NR~T NCNL TENS -999,2500 .-999.2500 -999,2500 -999,2500 1685,0000 -999,2500 -999,2500 -999,2500 '-999.2500 1670.0000 -999.2500 -999.2500 -999.2500 -999.2500 1655.0000 -999.2500 -999.2500 -99'9.2500 -999.2500 1600.0000 -999.2500 -999.2500 -999.2500 -999.2500 1565.0000 -999.2500 -9'99.2500 1560,0000 -999.2500 -999.2500 -999.2500 -999.2500 1505.0000 -999.2500 -999.2500 -999.2500 -999.2500 1470.0000 -999.2500 -999.2500 -999.2500 -999.2500 1395.0000 .VP OiO,HOZ VERIFICATION LISTING PAGE 15 )EPT 1000.0000 SFLU ;P -999,2500 GR :ALI -999,2500 RH08 ~NRA -999,2500 NPHI :CNL -999,.2500 TEN.S )EPT 976,5000 SFLU ~P -999,2500 GR :ALI -999.2500 RHOS (NRA -999,2500 NPHI =CNL -999,2500 TENS -999,2500 ILO -999.2500 TENS -999.2500 DRHO -999,2500 DPHI -999.2500 GR -999,2500 ILD -999,2500 TENS -999,2500 DRHO -999,2500 DPHI -999,2500 GR -99'9,2500 -999,2500 -999,2500 -999,2500 53,7500 -999.2500 -999.2500 -999.2500 -999.2500 50.68'75 i LM GR NRAT NCNL TENS I LM GR NR AT NCNL TENS -999.2500 -999.2500 -999.2500 -999.2500 1330.0000 -999.2500 -999.2500 -999.2500 -999,2500 1325.0000 ~, FILE TRAi:LER :ILE NAME :EDIT .001 ~ERVICE NAME : /ERSION ~ : )ATE : 4AXIMUM LENGTH : i024 :ILE TYPE : ~EXT FILE NAME ,-., TAPE 'TRAILER ** SERVICE NAME :EDIT ]ATE :87/02/ 8 ]RIGIN :FS1A TAPE NAME : SONTINUATION ~ :01 ~EXT TAPE NAME : COMMENTS :LIBRARY TAPE ** REEL TRAILER ** SERVICE NAME :EDIT DATE :87/02/ 8 ORIGIN : REEL NAME :149585 CONTINUATION ~ :01 NEXT REEL NAME : COMMENTS :LIBRARY TAPE
