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Home My WebLink About185-223MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-07 KUPARUK RIV UNIT 3A-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3A-07 50-029-21444-00-00 185-223-0 W SPT 5915 1852230 1500 1700 1700 1700 1700 380 540 540 540 4YRTST P Austin McLeod 8/4/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3A-07 Inspection Date: Tubing OA Packer Depth 60 2530 2430 2415IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250804190245 BBL Pumped:2.4 BBL Returned:2.2 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:26:51 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska .Alaska Oil and Gas Conservation Commission DATE: Thursday, August 26, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3A-07 KUPARUK RIV UNIT 3A-07 Src: Inspector Reviewed By;_� _ P.I. Supry j— Comm Well Name KUPARUK RIV UNIT 3A-07 API Well Number 50-029-21444-00-00 Inspector Name: Brian Bixby Permit Number: 185-223-0 Inspection Date: 8/24/2021 Insp Num: mitBDB210825103120 Rel Insp Num: Thursday, August 26, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-07 Type Inj W- TVD 5915 Tubing 2900 2900 , 2900 2900 PTD 1852230 Type Test SPT Test psi 1500 IA 140 2000 1935 1920- I3I3L Pumped: 1-5 BBL Returned: 1-5 OA 620 790 790 790 Interval 4vRTST P/F P r Notes: Thursday, August 26, 2021 Page I of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, December 4, 2020 7:40 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: KRU 3A-07 (PTD 185-223) Report of OA pressure increase update 12/4/20 Attachments: ` 3A-07 90 day TIO trend 12.4.20.pdf, MIT KRU 3A-07 diagnostic MITIA 10-05-20.xlsx Chris, KRU 3A-07 (PTD 185-223) was reported for suspect OA pressure increase on 10/3/20. Since that time the well passed a diagnostic MITIA, MITOA, inner casing pack off tests, and then the well was placed on a 60 day monitor period which is ending now. The well did not exhibit OA pressure increase or any other type of suspect annular communication during the monitor period. CPAI intends to return the well to 'normal' at this time. A 90 day TIO trend and 10-426 for the MITIA are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, October 3, 2020 12:12 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: _ KRU 3A-07 (PTD 185-223) Report of OA Pressure Increase Attachments: 3A-07.pdf; 3A-07 90 Day TIO 10-3-20.pdf; MIT KRU 3A PAD 08-03-17 Revised.xlsx Chris, KRU injector 3A-07 (PTD 185-223) is exhibiting an unexplained OA pressure increase. It is currently on water injection service. CPAI intends to perform diagnostics to help determine the cause of the increase. The most recent MITIA was the four year AOGCC-witnessed MITIA on 8/3/17. Following diagnostics, the well will be placed on a 60 day monitor period on water injection. A 60 day monitor period is needed (rather than a shorter one) due to the slow rate of OA pressure increase the well has exhibited so far. Depending on the results of the diagnostics and monitor period, the proper paperwork for continued injection or repair will be submitted. Attached are the schematic, 90 day TIO plot, and 10-426 from the most recent MITIA mentioned above. Please let me know if you have any questions or disagree with this plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 10,2017 TO: Jim Regg P.I.Supervisor If, rc� £(Zi 7 I� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3A-07 FROM: Chuck Scheve KUPARUK RIV UNIT 3A-07 Petroleum Inspector SCANNED e 2 3 20 j) Src: Inspector IJReviewed Bye P.I.Supry 2_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3A-07 API Well Number 50-029-21444-00-00 Inspector Name: Chuck Scheve Permit Number: 185-223-0 Inspection Date: 8/3/2017 Insp Num: mitCS170806082506 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-07 " Type Inj W •TVD 5915 Tubing 2000 2000 - 2000 2000 • PTD 1852230 " Type Test SPT Test psi 1500 - IA 1060 2800 2720 - 2710 BBL Pumped: 23 BBL Returned: 1.5 OA 730 930 - 930 - 930 Interval T 4YRTST P/F P / Notes: • Thursday,August 10,2017 Page 1 of 1 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ' ,' DATE: Friday, June 10, 2011 TO: Jim Regg �• 6 is tc P.I. Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A -07 FROM: John Crisp KUPARUK RIV UNIT 3A -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3A -07 API Well Number: 50- 029 - 21444 -00 -00 Inspector Name: John Crisp ' Insp Num: mitJCr110605211927 Permit Number: 185 -223 -0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3A -07 Type Inj. W ' TVD 5915 IA 500 2300 - 2220 2200 - P.T.D 1852230 TypeTest SPT Test psi 1500 - OA 420 480 480 480 Interval INITAL p/F P Tubing 1550 1550 1550 1550 Notes: 1.3 bbls pumped for test. Post CTD sidetrack. Pos' Ck= fl 0E : - C7L i C leL 4 :.. � i rnl 7 _ ng , 'JET F zI,f, !i Friday, June 10, 2011 Page 1 of 1 STATE OF ALASKA - ALASKA* AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell ❑ Plug Perforations ❑ Stimulate ❑ Other p Prod to WINJ Alter Casing ❑ Pull Tubing r Perforate New Pool ❑ Waiver r Time Extension r Change Approved Program ❑ Operat. Shutdown r Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pi Exploratory ❑ _ -• 185 -223 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service ❑ — b 06 4 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ._ ° I V ADL 25632 — ., 3A-07,1,A; 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 4/6sF';1 r'; ` 10. Present Well Condition Summary: 1 ;tinG. y /lr r/ S/8 n' "p+nfeg0 . Total Depth measured 7325 feet Plugs (measured) None true vertical 6328 feet Junk (measured) None Effective Depth measured 7191 feet Packer (measured) 6791, 6923, 6955 true vertical 6225 feet (true vertucal) 5916, 6020, 6046 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104 104 0 0 SURFACE 3145 12 3176 3086 0 0 L1 WINDOW 5 7 6987 6070 0 0 PRODUCTION 7258 7 7281 6295 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 6888 - 6922,6990- 7010,7024- 7060,7118 -7128 True Vertical Depth: 5993 - 6019 ,6073 - 6088,6099 - 6126,6171 -617 "4;-,r �,_ 1 Tubing (size, grade, MD, and ND) 3.5, L80, 6978 MD, 6046 ND Packers & SSSV (type, MD, and ND) PACKER - FHL PACKER 6791 MD nd 5916 ND PACKER - BAKER "F -1" PR ION PACKER @ 6923 MD and 6020 ND SHOE - 5 1/2 ", 15.5 #, L -80 MULE SHOE JOINT WITH WEARSOX @ 6955 MD and 6046 ND SAFETY VLV - TRMAXX- CMT -SR -5 SCSSV W/2.813" 'X' PROFILE @ 1779 MD and 1779 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 4 481 519 1950 258 Subsequent to operation 3071 350 2461 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service ® r!1 Stratigraphic ❑ 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Daily Report of Well Operations GSTOR r WINJ p WAG r GINJ ❑ SUSP r SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -146 Contact Darrell Humphrey /Bob Christesen Printed Name : ob Chri ensen Title Production Engineering Specialist Signature g Phone: 659 -7535 Date /_ /Y/ f 1 ` C � L r Form 10 -404 Revised 10/2010 RBDMS MAY 0 9 2011 .>� ,4 ‘ • /d Submit Original Only • 3A -07 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/07/111 REPLACED DV © 6706' RKB w/ 5/16 "OV, COMPLETE. 05/09/11 BRUSH AND FLUSH TBG TO 6898' SLM, SET 2.81 XX PLUG IN X NIPPLE @ 6812' RKB, PULL OV F/ STA # 1 AND REPLACE W/ DV @ 6706' RKB, PREFORM MITT & MITIA BOTH PASSED. JOB IN PROGRESS 05/10/11 (PULLED AVA CATCHER AND XX PLUG FROM "X" NIPPLE @ 6812' RKB 05 /12 /111Commenced Water Injection • of 1.- KUP 3A -07 • C0nocoPhillips ell Attributes ax Angle & MD TD AL-1 .e I /r_ Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) i <,m. /MI.4K 500292144400 KUPARUK RIVER UNIT INJ 41.06 3,200.00 7,325.0 Comment H2S (ppm) Date Annotation End Date K8 (R) Rig Release Date "' SSSV: TRDP Last WO: 1/6/2011 36.48 10/25/1985 Well Contg. -3A -07 5/1520111258'.21 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod .., End Date Last Tag: SLM 7,128.0 3/20/2010 Rev Reason: GLV C/O Imosbor 5/15/2011 I Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 29 CONDUCTOR 16 15.062 30.7 104.0 104.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 30.6 3,176.1 3,085.5 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 23.7 7281.3 6,294.8 26.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd L.. L1 WINDOW 7 6.000 6,982.0 6,987.0 6,070.3 Tubing Strings Tubing Description String O_. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Completion Details 3 1/2 2.992 Top Depth 28.7 6,997.0 6,078.0 9.30 L -80 EUE8RD coNOU 1 -104 ITVD) Top Incl Nomi... Top (ftKB) IRKS) ( °) Item Description Comment ID tin) SAFETY VLV, t 0 J 1 28.7 28.7 0.44 HANGER FMC Gen 4 Turing Hanger 2.992 1,779 1,779.5 1,779.5 0.20 SAFETY VLV TRMAXX- CMT -SR -5 SCSSV W/2.813" 'X' PROFILE 2.812 6,761.0 5,891.9 36.39 SEAL ASSY 22.21 -ft Baker 80-40 Seal Assembly w/ 7 -ft spaceout 2.990 6,768.3 5,897.8 36.50 PBR 20' "PBR" Polish Bore Receptacle 4.000 6,791.3 5,916.4 36.82 PACKER FHL Packer 2.930 + 6,812.9 5,933.6 37.12 NIPPLE HES "X" NIPPLE 2.812 6,920.8 6,018.5 38.75 SEAL ASSY 7.12 -ft GBH - 22 Bonded Seal assy. 1' Space Out Above String Weight. 2.970 SURFACE, • 31 - 3,176 6,922.5 6,019.9 38.77 PACKER Baker "F -1" Production Packer 3.980 6,925.0 6,021.9 38.79 SBE Baker 80-40 Seal Bore Extension 4.000 6,955.1 6,045.4 39.07 SHOE 5 1/2 ", 15.5#, L-80 Mule Shoe joint with Wearsox 5.070 GAS LIFT, 6,706 1-17 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Ben (ftKB) ( Bl (ftKB) Zone Date (se••• Type Comment 6,888.0 6,922.0 5,993.1 6,019.5 C C - 2, C 11/24/1985 12.0 IPERF 120 deg. phasing; 5" Csg Gun SEAL ASSY, - ) UNIT B, 3A -07 6,761 6,990.0 7,010.0 6,072.6 6,088.0 A -3, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 2 1/8" SG PBR 6766 _ 6,990.0 7,010.0 6,072.6 6,088.0 A -3, 3A -07 3/16/1986 4.0 RPERF 0 deg. phasing; Bar Kone II PACKER, 6,791 _ ' 7,024.0 7,060.0 6,098.8 6,126.4 A -2, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun s 7,024.0 7,060.0 6,098.8 6,126.4 A-2, 3A -07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II NIPPLE, 6,813 l 7,118.0 7,128.0 6,170.7 6,178.3 A -1, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun 1. 7,118.0 7,128.0 6,170.7 6,178.3 A -1, 3A -07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II • Notes: General & Safety End Date Annotation 11/9/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT 3/9/2011 NOTE: NEW CTD LATERALS Lt, L1 -01, L1 -02 6.866 • IPERF, 6,888 -6.922 SEAL ASSY, 6,921 PACKER. 6923 -- SBE. 6,925 SHOE, 6.955 L1 WINDOW, 6,982-5,987 - 1 RPERF, 6,990 -7,010 _- IPERF, 6990 -7,010 IPERF, 7 7,02 ERF, 7,024 -7,960 Mandrel Details RPERF, Top Depth Top Port 7,118 -7.r2a (TVD) Incl OD Valve Latch Size TRO Run IPERF, Stn Top (ftKB) (RK ( "1 Make Model lin) Sery Type Type (in) (psi) Run Date Core... 7,118 - 7,128 1 6,706.4 5,847.2 35.63 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/9/2011 2 6,866.1 5,975.8 37.87 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/4/2011 PRODUCTION, 24 -7,281 TD 13A-07), 7,325 Slots, 6,915 -8,107 • Slots. 8,108-9305 2LINE L1 -02 LINER, 6.914 -9,306 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, May 10, 2011 10:53 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: NSK Problem Well Supv Subject: 3A -07 (PTD 185 -223) Pre injection MITIA �� Attachments: MIT KRU 3A -07 pre injection MITIA 05- 09- 11.xls All, Attached is the test form for the pre- injection MITIA performed on 3A -07 following a CTD sidetrack. Once the well has been brought on injection and thermally stabilized, the North Slope inspectors will be notified to witness the initial MITIA. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 + NO NOCED AUG 0 5 201) 8/4/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(6alaska.dov; doa .aogcc.prudhoe.bavekilaska.00v: phoebe.brooks(r6alaska.gov; tom.maunder(8alaska.aov OPERATOR: ConocoPhillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 3A DATE: 05/09/11 OPERATOR REP: Walsh - HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3A-07 Type Inj. N TVD 5,916' Tubing 1,000 1,100 1,100 1,100 Interval O P.T.D. 1852230 Type test P Test psi 1500 Casing 950 2,550 2,500 2,500 P/F P Notes: Pre - injection MITIA post CTD sidetrack OA 680 760 760 760 Well Type tnj. ND Tubing Interval P.T D. Type test Test psi Casing P/F Notes: I 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 1= 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.= Temperahne Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MR' KRU 3A -07 pre injection MITIA 05-09-11 ids • S LivIE rpF ALAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMI►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Darrell R. Humphrey Wells Engineer 0.,g3 ConocoPhillips Alaska, Inc. r- MA" 0I 2 r 0 i Rs_ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A -07 Sundry Number: 311 -146 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, AP Daniel T. Seamount, Jr. d Chair DATED this ?' day of May, 2011. Encl. v AND G S COMMISSIO 1 RECEIVED ALASIC/11 APPLICATION FOR SUNDRY APPROVA APR 2 7 ?Oil 20 AAC 25.280 1. Type of Request Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r kliAtereiltainigeesanGoinnission Suspend r Plug Perforations r Perforate r RffI Tubing r ATIPPPIOn r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: Prod to WINJ PI - 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r - Exploratory r 185 -223 - 3. Address: Stratigraphic r Service r 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21444 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number where ownership or landownership changes: Spacing Exception Required? Yes r No pi 3A -07 , 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25632 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7325 . 6328 ' 7191' 6225' Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 104' 104' SURFACE 3145 12 3176' 3086' L1 WINDOW 5 7 6987' 6070' PRODUCTION 7258 7 7281' 6295' Perforation Depth MD (ft): Perforation Depth TVD (tt): Tubing Size: Tubing Grade: I ubing MD (tt): 6888-6922,6990-7010,7024-7060,7118- 7128 5993 - 6019 ,6073 - 6088,6099 - 6126,6171 -6178 3.5 L80 6978 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - FHL PACKER MD= 6791 TVD= 5916 PACKER - BAKER "F -1" PRODUCTION PACKER MD= 6923 TVD= 6020 SHOE - 5 1/2 ", 15.5#, L -80 MULE SHOE JOINT WITH WEARSOX MD= 6955 TVD= 6046 SAFETY VLV - TRMAXX- CMT -SR -5 SCSSV W/2.813" 'X' PROFILE MD= 1779 TVD= 1779 12. Attachments: Description Summary of Proposal r' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r • GINJ r WAG I`" Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey /Bob Christesen Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature ILL,-----V Phone: 659-7535 Date t4- 2-5 - 1. ( Commissio Use Only Sundry Number '3 11 —/ -/ 60 Conditions of approval: Notify Commission so that a representative may witness JJJJ � ��/// / Plug Integrity r BOP Test r Mechanical Integrity Test iI Location Clearance r Other " /Up rot ytehr fn C.J■ e-ss Mt = /A '- Vey-i -f ,i/6( s r isoi Subsequent Form Required: v 1 o .JY sY f APPROVED BY ` Approved by: � C OMMISSIONER THE COMMISSION Date: � � h( A � ZOII � I V L � y zg :� � te � �. it R 1\1 A 'eubmit in DO lica Form 10 -403 Revised 1/2010 0 0 j • 3A -07 • - q DESCRIPTION SUMMARY OF PROPOSAL ;3A-07 ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3A -07 from Oil Production service to Water Injection service. Well 3A -07 was produced to reduce formation pressure prior to CTD drilling. CTD has been completed in the Kuparuk formation The 16" Conductor was cemented with 150sx AS II (104' and / 104' tvd). The 9 -5/8" Surface casing (3176' and / 3086' tvd) was cemented with 1000sx AS III and 350sx Class G. The 7" Production casing (7281' and / 6295' tvd) was cemented with 125sx Healy Fly Ash and 300sx Class G and 175 sx AS I The top of the Kuparuk C was found at 6888' and / 5993' tvd. The top of the Kuparuk C1 was found at 6908' and / 6009' tvd. The top of the Kuparuk B was found at 6021' and / 6019' tvd. The top of the Kuparuk A was found at 6973' and / 6059' tvd. The injection tubing /casing annulus is isolated via FHL packer 6.151" OD x 2.930" ID located @ 6791' and / 5916' tvd. An MIT -IA was last performed on 58/9/09; 4 year State waived MITIA - passed. Initial T /I /0= 2775/675/360, pressured up IA with 1.3 bbls diesel. T /I /0= 2825/2000/550, 15 min T /I /0= 2825/1880/550, 30 min T /I /0= 2825/1860/550. Bled IA Final T /I /0= 2825/640/380 i KUP 3A -07 Conocorhiflip5 0° ell Attributes ax Angle 8 MD TD y Wellbore API /UWI Field Name Well Status Incl ( °) MD IRKS) Act Btate, (RKB) f 500292144400 KUPARUK RIVER UNIT PROD 41.06 3,200.00 7,325.0 Comment H25 (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TROP Last WO: 1/6/2011 36.48 10/25/1985 Well cords' - 3 11 PM Schema tic -AcN Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,128.0 3/20/2010 Rev Reason: GLV C/O Imosbor 4/17/2011 Casing Strings Casing Description String 0... String ID... Top (RKB) Set Depth (f... Set Depth (TVO)... String Wt... String... String Top Thrd HANGER, 29 CONDUCTOR 16 15.062 30.7 104.0 104.0 62.50 H WELDED Coning Description String 0... String ID ... Top (RKB) Set Depth It Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 30.6 3,176.1 3,085.5 36.00 J - 55 BTC - ^ • Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I": %' PRODUCTION 7 6.151 23.7 7,281.3 6,294.8 26.00 J - 55 BTC I . Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd L1 WINDOW 7 6.000 6,982.0 6,987.0 6,070.3 Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f_. Set Depth (TVD) ... String Wt... String . String Top Thrd TUBING 31/2 2.992 28.7 6,997.0 6,078.0 9.30 L-80 EUE8RD CONDUcroR, Completion Details 31 104 -` Top Depth (TVD) Top Incl hoed... I I I Top (RKB I RKS) (°) Item Description Comment ID (In) SAFETY W.V. 28.7 28.7 0.44 HANGER FMC Gen 4 Tubing Hanger 2.992 1,779 '} 1,779.5 1,779.5 0.20 SAFETY VLV TRMAXX- CMT -SR -S SCSSV W/2.813" 'X' PROFILE 2.812 6,761.0 5,891.9 36.39 SEAL ASSY 22.21 -ft Baker 80-40 Seal Assembly w/ 7 -ft spaceout 2.990 6,768.3 5,897.8 36.50 PBR 20' "PBR" Polish Bore Receptacle 4.000 O 6,791.3 5,916.4 36.82 PACKER FHL Packer 2.930 6,812.9 5,933.6 37.12 NIPPLE HES "X" NIPPLE 2.812 SURFACE, J l 6,920.8 6,018.5 38.75 SEAL ASSY 7.12 -ft GBH - 22 Bonded Seal assy. 1' Space Out Above String Weight. 2.970 31 - 3,176 6,922.5 6,019.9 38.77 PACKER Baker "F -1" Production Packer 3.980 6,925.0 6,021.9 38.79 SBE Baker 80-40 Seal Bore Extension 4.000 6,955.1 6,045.4 39.07 SHOE 5 1/2", 15.54, L-80 Mule Shoe joint with Wearsox 5.070 GAS LIFT, 6,706 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (RKB) Btrn (RKB) (RKB) (RKB) Zone Date lob... Type Comment 6,888.0 6,922.0 5,993.1 6,019.5 C-4, C-2, C-1, 11/24/1985 12.0 IPERF 120 deg. phasing; 5" Csg Gun SEAL ASSY UNIT B, 3A -07 6,761 6,990.0 7,010.0 6,072.6 6,088.0 A -3, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasing; 21/8" SG PBR, 6768 - 6,990.0 7,010.0 6,072.6 6,088.0 A-3, 3A -07 3/16/1986 4.0 RPERF 0 deg. phasing; Bar Kone II PACKER, 6,791 ® 7,024.0 7,060.0 6,098.8 6,126.4 A -2, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun 1111 . 7,024.0 7,060.0 6,098.8 6,126.4 A -2, 3A -07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II NIPPLE, 6,513 6X,.,. 7,118.0 7,128.0 6,170.7 6,178.3 A -1, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun 7,118.0 7,128.0 6,170.7 6,178.3 A -1, 3A -07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone ti Notes: General & Safety End Date Annotation 11/9/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 3/9/2011 NOTE: NEW CTD LATERALS L1,11-01,11-02 6,888 PERF, 6 888 -6, 922 I SEAL ASSY 6,921 , 1 1 1 PACKER, 6,923 SBE, 6,925 SHOE. 6,955 L1 WINDOW, 6,982 -6,987 RPERF, 6,990 -7,010 IPERF, 6,990.7,010 IPERF, 7,024-7,080 7,024-7,060 Mandrel Details RPERF, Top Depth Top Port 7,118-7,128 (RKB) I l ° ) I Make Model (I ) Sere Type Type 1 T IPERF, Stn Top (RKB) (pni( Run Date Com... 7,1137,128 1 6,706.4 5,847.2 35.63 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 4/7/2011 2 6,866.1 5,975.8 37.87 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/4/2011 PRODUCTION, 237,291 7,325 Slots, 6,91543,107 Slots, 8,108 - 9,305 L1-02 LINER, 6,914 -9,306 • • APR 2 7 2011 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 • ♦ asks f, C t , , c omm i ss i on PO Box 196105 Anchorage, AK 99519 -6105 C OflOCOPI1 i ps M Anchorage Phone: (907) 659 -7535 Fax:659 -7314 April 25, 2011 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 J ) Anchorage, AK 99501 1 e 6 Dear Mr. Seamount, ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3A-07, 3A -07L1, 3A- 07L1 -01, 3A- 07L1 -02 from Oil Production service to Water Injection service. The well was produced to reduce formation pressure prior to CTD drilling. CTD was completed in the Kuparuk formation on March 03, 2011. Conversion to Injection service is required due to potential reservoir depletion. Enclosed you will find 10 -403 applications for Sundry Approval for ConocoPhillips Alaska, Inc. for 3A -07, 3A -07L1, 3A- 07L1 -01, 3A- 07L1 -02 (PTD 185- 223,211 -211- 0,211- 012 - 0,211- 028 -0). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, A Darrell R. Humphrey Attachments Sundry application Well schematic • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 1, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: GR/CCL Correlation: 3A -07 ikiW MAR 2,0 Run Date: 1/29/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21444 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 - 3535 -3a rafael.barre`ln 1 ' tl +.c Date: FEB E ( 2011 Signed: 6 Oil & Gas Cons. Commission An aon STATE OF ALASKA ALASKA* AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Fbrforations r Stimulate r Other � CTD Set -up Alter Casing r Pull Tubing F7 Perforate New Pool r Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185 -223 3. Address: 6. API Number: Stratigraphic [ Service Pr P. O. Box 100360, Anchorage, Alaska 99510 -- 50- 029 - 21444 -00 '-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25632 3A -07 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7325 feet Plugs (measured) None true vertical 6328 feet Junk (measured) None Effective Depth measured 7191 feet Packer (measured) 6791, 6923 true vertical 6225 feet (true vertucal) 5916, 6020 Casing Length Size MD TVD Burst Collapse CONDUCTOR 104 16 104 104 SURFACE 3145 9 -5/8" 3176 3086 PRODUCTION 7258 7 7281 6295 AitiikED FEB 1 1 2U1u C taro. R w n "'-� y,� r Perforation depth: Measured depth: 6888'- 6922', 6990'- 7010', 7024'- 7060', 7118' -7128' =1 ' 9 4 ill True Vertical Depth: 5993'- 6020', 6073'- 6088', 6099'- 6126', 6171' -6178' A* 4.9 '9 fle' r Cons. C: ssion Tubing (size, grade, MD, and TVD) 3.5" , L -80, 6997 MD, 6078 TVD 't °fk( „a hge Packers & SSSV (type, MD, and TVD) PACKER - FHL PACKER @ 6791 MD and 5916 TVD PACKER - BAKER "F -1” PRODUCTION PACKER @ 6923 MD and 6020 TVD SSSVs - TRMAXX- CMT -SR -5 SCSSV W12.813" 'X' PROFILE @ 1779 MD and 1779 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation Si Subsequent to operation Si 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development f Service' Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR WIND WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -388 Contact J. Brett Packer 265 -6845 Printed Name J. tt Packer , - � Title Wells Engineer Signature ?�- /��`' Phone: 265 -6845 Date a73/ BQD Form 10 -404 Revised 10 m FEB 0 4 . 2 _ 741 Submit Original Only ;," 764 e1. 9 71------'\ KU P 3A -07 CC3Ci(3 1 N ps 4 ' W ( Attributes I Max 0 An le & MD TD A/a,,, Inc , ', - Wellbore APUUWI Field Name Well Status Inc! (") MD (ftKB) Act Btm (ftKB) 1;�r�toYhti 500292144400 KUPARUK RIVER UNIT INJ I 41.06 3.200.00 7,325.0 '"' Comment H2S (ppm) Date An tatron End Date KB Grd (ft) Rig Release Date ••. well 59559 3A -w 1/27x2811 1:10: PM SSSV' TRDP I Last WO' 1/6/2011 36 48 10/25/1985 � � Schematic Actual _ Annotation (Depth (KK O _ B) (End Date (Annotation Last Mod . End Date Last Tag SLM I 7,128 -0 1 3/20/2010 Rev Reason. WORKOVER, GLV C1 Imosbor 1 1/27/2011 Casin Stnn•s Casing Desc pt n Str g 0... String ID .,. Top (808) Set Depth (0.. Set Depth (TVD) ... String Wt... String .. String Top Thrd C ONDUCTOR 16 15.062 30.7 104.0 104.0 62.50 H - 40 WELDED HANGER, 29 '= '':- Casing Description 1Strin 9 0... String .. Stri Wt... Siring 9 - -� String Top n t Thrd 9 ID ... Top (ftKB) ) Set Depth P ( 1. Set Depth P (TVD) ... !SURFACE 95/8 8.921 30.6 3,176.1 3,085.5 36.00 J - 55 BTC ,Casing Description String 0,,, String ID ... Top (ftKB) Set Depth (1... Set Depth (TVO) . String Wt... String .. String Top Thrd 1 PRODUCTION 7 6 -151 237 7,281.3 6,294.8 2600 J -55 I 13 C ' T Strings Tubing Description String 0. String ID ... (Top (ftKB) (Set Depth (1... 'Set Depth (TVD) ... String Wt... St tng ... String Top Thrd I UBING 3 1/2 2.992 287 6,997.0 lI 6,078.0 9 30 L -80 EUE8RD 8 Completion Details Top Depth - -� - (TVD) Top Intl Nomi „- Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) CONDUCTOR, 28.7 28 7. 0.44 HANGER FMC Gen 4 Tubing Hanger 2.992 31 - 104 1,779.5 1,779.5 0.20 SAFETY VLV TRMAXX- CMT -SR -S SCSSV W/2.813" 'X' PROFILE 2.812 1 6,761.0 5,891.9 36.39 SEAL ASSY 22.21 -ft Baker 80 -40 Seal Assembly w /7 -ft spaceout 2.990 SAFETY VLV, 6,768.3 5,897.8 36.50 PBR 20 "PBR" Polish Bore Receptacle 4.000 1,779 - '� 6,791.3 5,916.4 36.82 PACKER FHL Packer 2,930 6,812.9 5,933.6 37.12 NIPPLE HES 'X' NIPPLE 2.812 6,920.8 6,018.5 38.75 SEAL ASSY T 7.12 -ft GBH - 22 Bonded Seal assy. 1' Space Out Above String Weight. 2.970 6,922.5 6,019.9 3877 PACKER Baker "F -1" Production Packer 3.980 ' 6,925.0 6,021.9 38.79 SBE Baker 80-40 Seal Bore Extension 4.000 6,925 0 1 6,025.0 38.83 XO Enlarging Ported Cross over Coupling 4.380 Shoe joint _. - - -- B 3007'MULE SHOE 5 Mule with Wearsox 5.070 SURFACE, 6,929.0 31 -3,176 Perforations & Slots Top (TVD) Btm (TVD) Dens Top (ftKB) Blm (fIKB) (ftKB) (11KB) Zone Date (sh-. Type Comment GAS LIFT, 6,888.0 6,922.0 5,993.1 6,019.5 C-4, C -2, C -1, 11/24/1985 12.0 IPERF 120 deg. phasing; 5" Csg Gun 6,706 UNIT B, 3A -07 6,990.0 7,010.0 6,072.6 6,088.0 A-3, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasing; 2 vr SG 6,990.0 7,010.0 6,072.6 6,088.0 A 3, 3A -07 3/16/1986 4.0 RPERF 0 deg. phasing; Bar Kone II 7,024.0 7,060.0 6,098.8 6,126.4 A -2, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun al 7,024.0 7,060.0 6,098.8 6,126.4 A -2, 3A -07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II SEAL ASSY, 6,761 - ° 7,118.0 7,128.0 6,170,7 6,178.3 A -1, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun PBR, 6,768 - r j 7,118.0 7,128.0 6,170.7 6,178,3 A -1, 3A -07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II Notes: General & Safety _._. ff End Date Annotation I .. - 11/9/2010 __ S NOTE: View Schematic w/ Alaska Schematic9 0 NIPPLE,6,813 GAS LIFT 6 d66 SEAL ASSY, � 6 I: IPERF, _'__... 6,888 -6,922 _ -- 6,921 PACKER, 6,923 - - ° - "- . SBE,6,925 Liiiii F J: 1 , MULE SHOE, -' ' 6,955 I IPERF, 6,990 -7,010 RPERF, i' 6,990 -7,010 s Mandrel Details Top Depth Top Port ( (TVD) Inc! OD Valve Latch Size TRO Run RPERF, Stn Top,(ftKB) (ftKB) (1 Make Model (in) Seri Type Type (in) (psi) Run Date Com... 7,024-7,060 LIFT D _ r- - , 1 6,7064 5,847.2 35.63 CAMCO KBMG 1 GA LI FT DMY BK 0 0.0 1/i 512011 IPERF. �:_. _ _ �___- -__ . - _ 7,024 2 6,866.1 5,975 8 37.87 CAMCO 1 GAS LIFT DMY BK -5 0.000 0.0 1/4/2011 RPERF, 7,118 -7,128 PERE, 7,118-7,128 '' .7. - .. ; :: . ' '''''' PRODUCTION, 24 -7,281 -",,,__ TD, 7,325 3A -07 Well Work Summary DATE . SUMMARY 10/25/10 PRE RWO T -POT ( PASSED ), T -OOT ( PASSED ), IC -POT ( PASSED ), ICOPOT ( PASSED ) FT -LDS ALL NORMAL MIT -OA ( PASSED ). 11/22/10 DISPLACED TBG WITH 50 BBL'S.DRIFTED THROUGH 2.75" BPI @ 6938' RKB WITH 2.30" TO 6959' RKB.SET 2.25" CA -2 PLUG @ 6959' RKB.SET CATCHER ON CA -2 PLUG.PULLED NEW STYLE 2.75" AVA BPI FROM 6938' RKB.MEASURED "C" SAND SBHPS =3632 psi @ 6906' RKB WITH GRADIENT.PULLED 1.5" DV FROM 6730' RKB.IN PROGRESS 11/23/10 PULLED CATCHER SUB FROM TOP OF CA -2 PLUG @ 6959' RKB.PULLED 2.25" CA -2 PLUG FROM 6959' RKB.LOCKED OUT BAKER FVL SSSV @ 1811' RKB.PASSED BELOW FLAPPER WITH 2.79" GAUGERING WITHOUT HANGING UP. 11/24/10 PERFORM 3 RUNS ON 3A -07. ONE CORRELATION LOG AND TWO RCT TUBING CUTS. THE ✓" FIRST CUT WAS IN THE PUP JOINT AT 6934.7' RKB. THE SECOND RCT TUBING CUT WAS IN 3.5' TUBING AT 6850' RKB BELOW THE INJ MANDREL. RCT VERIFIED FOR SUCCESSFUL FIRE ON BOTH RIH. 1/14/11 PULLED BALL AND ROD FROM 6813' RKB.IN PROGRESS 1/15/11 REPLACED 1" SOV WITH DV @ 6706' RKB. PULLED RHC PLUG BODY @ 6813' RKB.MITIA PASSED • Conoco Phillips Time Log & Summary We'Mew Web Reporting Report Well Name: 3A - 07 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/22/2010 2:00:00 PM Rig Release: 1/5/2011 10:00:00 PM Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T Comment 12/21/2010 24 hr Summary RDMO 2X -PAd. Begin moving to 3A -Pad. 20:30 00:00 3.50 0 0 MIRU MOVE MOB P Move Rig off of 2X -18 Well Slot. Begin to mobilize Rig towards 3 -A Pad. 12/22/2010 Continue moving Rig to 3A- Pad. MIRU at 3A -07 Well Slot. 00:00 06:00 6.00 0 MIRU MOVE MOB P Continue with Rig move to 3A -Pad. 06:00 08:00 2.00 MIRU MOVE OTHR P Rig Arrived At CPF -3. Hold Rig For 2 hours for Field Crew Change Out. 08:00 14:00 6.00 MIRU MOVE MOB P Continue with Rig Move from CPF -3 to 3A -Pad. Hang New Wellhead Tree in Cellar after Rig On Locations. 14:00 15:30 1.50 MIRU WHDBO OTHR P Rig Over Well. Accepted Rig @ 1400 hrs. 15:30 22:30 7.00 MIRU WHDBO OTHR P Spot Equipment. Berm up Around Cutting Box. Hook Up hard Line Equipment. Swap Out Cutting Box. Area between Rig & Next Well Was to close ). Load pit with 11.8 ppg Brine. Hook up hoses in cellar. 22:30 00:00 1.50 COMPZ WHDBO KLWL T Install Lubricator and Attempt to pull BPV. Having problems Pulling Valve. 12/23/2010 Kill Well with 11.8 lb /gal Brine. Install BPV. Nipple down Tree. Inspect Tubing Hanger lift threads...bad. Install Blanking Plug. Nipple up BOP Stack. Attempted to perform the initial BOPE test. 00:00 02:30 2.50 COMPZ WHDBO KLWL T Attempting to Pull BPV. Installed Heat to tree and valve. Able to Pull BPV. 02:30 08:00 5.50 COMPZ WHDBO KLWL P PJSM. PT Lines to 250/3500 psi. Pumped 40 bbls Hi -Vis Sweep @ 2 bpm. Chased sweep with 11.8 ppg Brine to 6780'. Close in IA and Bullheaded Pill into Perforation. Open the IA and continue to circulate 11.8 ppg Brine down tbg taking returns up IA. Seen trace of Gas and Pressure increase while circulating Brine around. Circulated a total of 305 bbls around before seeing 11.8 ppg at surface. Total return to Kill Tank ( 364 bbls) ICP 230 psi @ 2 bpm / ICP on IA 40 psi, FCP on TBG (0) /FCP on IA (0)wellonVac. 08:00 09:00 1.00 COMPZ WHDBO KLWL P Load Pits with second load of 11.8ppg Brine. Monitor Well. Page 1 of 13 lime Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:45 3.75 COMPZ WHDBO NUND P PJSM. Set BPV. ND Tree. Inspect Tubing Hanger threads. Bad. (Note: Will need to "spear" the Tubing Hanger when pulled). 12:45 16:00 3.25 COMPZ WHDBO NUND P PJSM. NU BOPE & Function Test. 16:00 16:30 0.50 COMPZ WHDBO SFTY P PJSM. Test All Electric Alarm on Rig 16:30 23:00 6.50 COMPZ WHDBO BOPE T Attempted testing BOPE. However, it was determined that the threads in the Tubing Hanger are allowing pressure to leak by the Blanking Plug. Discuss a plan forward with Anchorage Engineer and the AOGCC. Decession made to test surface equipment per normal test procedures and to do a temporary "rolling test" on the BOP components. Tested all valves in the 60 Choke Manifold, the Dart Valve, the Hydraulic Valve on the Top Drive and the manual Top Drive Valve at 250/3,500 psi. All good tests. Per verbal agreement a "rolling test" was performed on the BOP components. Both the upper and the lower 2 7/8" x 5" Variable Bore Pipe Rams were tested, using the 3 1/2" Test Joint. Both rams were tested at 250/3,500 psi. However the results, as expected, a loss of -40 psi on the low test in 5 minutes and a loss of -1,000 psi in one minute on the high test. The Annular was also tested using the 3 1/2" Test Joint with the same low /high pressure loss results. The Blind ram was tested with the some low /high results, too. 23:00 00:00 1.00 MIRU WHDBO BOPE T PJSM. FMC Service Rep pulled the Blanking Plug. 12/24/2010 Pull Blanking Plug and the BPV. Rig up S -Line. Set CAT Plug in the SSSV at 1,811 -ft. Pressure test Plug. Plug leaking by. Pull CAT Plug. Set M -1 Plug. Pressure test Plug. Plug also leaks. Suspend S -Line Ops so Crew can get some rest. No relief Crew available. 00:00 02:00 2.00 0 0 COMPZ WHDBO BOPE T Repair Pulling Tool. Pull BPV. Begin to load 3 1/2" Drill Pipe in Pipe Shed. 02:00 03:30 1.50 COMPZ WHDBO BOPE T Prep for S -Line to set Plug in SSSV. Nipple down Flow Nipple. Nipple up Shooting Flange. 03:30 05:00 1.50 COMPZ WHDBO BOPE T Allow the S Line Crew to get proper rest. Continue to load and tally Drill Pipe. 05:00 06:00 1.00 COMPZ WHDBO BOPE T Call out S -Line Crew. Continue to load and tally Drill Pipe. 06:00 07:00 1.00 COMPZ WHDBO SFTY T Slick -Line Crew and Equipment on Locations. PJSM with HES & Nordic Rig Crew. Page 2 of 13 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:00 2.00 COMPZ WHDBO PULD T Unload Slick -Line Lubricator, Pump & Sub And Bop and Riser to Rig Floor. 09:00 12:00 3.00 COMPZ WHDBO SLKL T Start Slick -Line Operations. RI with a 2.865" Swedge. Set down at 29 -ft. RIH with a 2.490" Centralizer and Brush. Set down in the same spot. RIH with a 2.500" Bailer. Worked through. Continue down to the SSSV at 1,809 -ft slmd. 12:00 15:00 3.00 COMPZ WHDBO SLKL T Continue with S -Line Operations. RIH with LIB to get an impression at 29 -ft. Tap down. POOH with LIB. See picture with a 45 deg shoulder. LIB inconclusive. Ponder next run. Discuss options and a plan forward with Anchorage Engineer. 15:00 17:30 2.50 COMPZ WHDBO SLKL T Set back S -Line Lubricator. Pick -up a Joint of 3 1/2" and screw into the Tubing Hanger threads. Add 2 more feet of 7" Lubricator to cover the tubing stick -up. Stab S -Line Tool String with 2.865" Swedge into the Tubing Joint. Set down Lubricator. RIH with Swedge down to the SSSV No -Go at 1,819 -ft slmd. (Note: saw Fluid Level at 700 -ft). 17:30 18:00 0.50 COMPZ WHDBO SLKL T RIH with 2.81" CAT Plug. Set same in SSSV profile. POOH for pressure test. Set back S -Line Lubricator. 18:00 19:00 1.00 COMPZ WHDBO SLKL T Lay down Joint of Tubing. Close Blind Ram. Pressure up on CAT Plug with Rig Pump. Plug leaking. Isolate surface equipment. Tried several times to pressure test at 3,500 psi. Pressure fall -off averaged -300 psi/minute. 19:00 21:00 2.00 COMPZ WHDBO SLKL T Make up Tubing Joint again. Rig S -Line back on Well. RI with GS Spear. Latch and pull CAT Plug. Inspect CAT PLug. Packing normal. Marks on No-Go. Looks like it was stuck in the profile. 21:00 22:00 1.00 COMPZ WHDBO SLKL T RI with 2.810" M -1 Plug w /Kobe Knock -Out. Set in SSSV at 1,818 -ft slmd. 22:00 23:00 1.00 COMPZ WHDBO SLKL T Set back Lubricator. Lay down Joint of Tubing. Close Blind Ram and pressure test the M -1 Plug. This Plug also leaking. However, not as bad. Tried several times again at 3,500 psi. Pressure fall -off -75 - 100 psi /minute. Leave Plug set. Page 3 of 13 S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 COMPZ WHDBO SLKL T Secure S -Line equipment for the night. Secure and continue to monitor Well. Send S -Line Crew to Camp proper for er rest. No Relief Crew P available to continue S -Line work. Order out a Weatherford WRP for next run. 12/25/2010 Continue with S -Line Ops. Set WRP Plug. Test Plug. RD S -Line. Perform Initial BOPE Test. RU S -Line to pull Plugs in the Tubing. 00:00 07:00 7.00 0 0 COMPZ WHDBO SFTY T S -Line Crew in Camp for proper safety rest. Continue to Monitor Well. Rig Crew maintain Rig and perform miscellaneous maintenance. Practice Rig Drills. Clean on Rig. Plan to resume S -Line Operation at 07:00 hrs. 07:00 07:30 0.50 0 COMPZ WHDBO SFTY T PJSM With Rig Crew, HES Crew and Weatherford. 07:30 08:30 1.00 COMPZ WHDBO PULD T Load Weatherford Tools To Rig Floor. 08:30 09:30 1.00 COMPZ WHDBO SLKL T MU Slick -line tools And Weatherford WRP. 09:30 10:30 1.00 COMPZ WHDBO SLKL T RIH with WRP to 92' slm and start the setting process. Unable to Set WRP. POOH 10:30 11:00 0.50 COMPZ WHDBO OTHR T Trouble Shoot Setting Tool for WRP. 11:00 12:00' 1.00 COMPZ WHDBO SLKL T RIH with WRP and Attempt another set. Start Setting Process again. 12:00 12:30 0.50 0 92 COMPZ WHDBO PULD T OOH with Sligk -Line j WRP Set @ 92— .stand.. Rig Back Slick -line equipment for testing. 12:30 13:00 0.50 COMPZ WHDBO PRTS P Shell Test BOP's and WRP. Fail Test The First Time, Passed the second time. 13:00 14:00 1.00 COMPZ WHDBO PULD P L/D Slick -line tools, Lubricator and Pump & Sub and BOPE. 14:00 15:15 1.25 COMPZ WHDBO NUND P PJSM. ND Shooting Flange, and NU Riser Flange. 15:15 15:30 0.25 COMPZ WHDBO SFTY P PJSM. Discuss hazard of Testing BOPE. 15:30 20:30 5.00 COMPZ WHDBO BOPE P Perform Initial BOPE Test per Conoco /Phillips and AOGCC requirements at 250/3,500 psi. Test Annular at 250/3,500 psi. All tests bt; f passed and recorded on Chart. Perform Koomey draw down test. 1� Good. The State's right to witness &1 the test was waived by J. Jones. Rig down test equipment. e isdis 20:30 22:30 2.00 COMPZ WHDBO BOPE P PJSM. Nipple down Flow Nipple. ti a Call out S -Line Crew to return to Location. Nipple up Shooting Flange. Page 4 of 13 Time Logs Date From To, Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 COMPZ WHDBO BOPE P S -Line Crew arrived on Location. PJSM with All. Discuss cold weather operations. Plck up the 3 1/2" Tubing Joint and screw into the Tubing Hanger. Rig up S -Line Lubricator. Run in with a 2.270 Equalizer Tool. Tap down to equalize the WRP. POOH. Run in with the WRP Pulling Tool. 12/26/2010 S- Line Ops continue. Pull the Wireline Retrievable Plug and the M -1 Plug. Rig down Slick Line. 00:00 03:30 3.50 COMPZ WHDBO BOPE P Continue with S -Line operations. Release and POOH with the WRP. Recovered complete. Run in with a 1.500" Bailer and equalize the M -1 Plug in the SSSV. Run in with a GS Pulling Tool w /M -1 Prong (shear -up). Attempt to release Plug. However, GS sheared before releaseing Plug. POOH. Run in with a GR Pulling Tool (shear - down). Released M -1 Plug. Start POOH. Plug hung up at 68 -ft. Work through. Hung up at 61 -ft. Work through. Continue to surface. Recovered M -1 Plug complete. 03:30 06:30 3.00 0 COMPZ WHDBO BOPE P Rig down S -Line equipment. Lay down the 3 1/2" Tubing Joint. Nipple down the Shooting Flange and nipple up the Flow Nipple. 06:30 07:00 0.50 0 0 COMPZ RPCOM PULD P PJSM.Load Spear & Camco Spooler To Rig Floor 07:00 08:00 1.00 0 31 COMPZ RPCOM FISH P MU Spear, and engauge Tubing Hanger. BOLDS. Un -Land Hanger. Up Wt 135k. Pull hanger to Floor. 08:00 09:00 1.00 31 0 COMPZ RPCOM PULD P Lay Down Tubing Hanger. Install Treating Iron. Secure Control To Spooling Reel. 09:00 10:00 1.00 0 0 COMPZ RPCOM CIRC P Reverse Circulate down IA, taking Returns UpTubing @ 2 BPM. ICP On Annular Psi 80 / Tubing Psi 0. Circulated 63 bbls to Surface and Lost 85 bbls to formation. 10:00 10:15 0.25 0 0 COMPZ RPCOM OWFF P Monitor Well For Flow for 15 mins 10:15 10:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard of Tripping Pipe. 10:30 14:00 3.50 6,780 4,978 COMPZ RPCOM TRIP P POOH laying down TBG and spooling control line and removing bands.Up Wt= 89k 14:00 14:30 0.50 4,978 4,978 COMPZ RPCOM PULD P Lay Down SSSV and Secure Control Line On Camco Spooler. Lower down spooler to Camco truck. Release Camco Rep. Note: Recoved All 31 Control Bands. First Full Joint below Tubing hanger Was bent. Page 5 of 13 Time Logs • _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 18:00 3.50 4,978 2,800 COMPZ RPCOM TRIP P Continue to single down the 3 /2" Completion from 2,800 -ft. Up Weight = 50K. Down Weight = 45K. 18:00 22:30 4.50 2,800 0 COMPZ RPCOM TRIP P Finish out with the completion down to the PBR at 6,780 -ft. Recovered a total of 217 Joints Tubing, SSSV, 1 ea GLM, 3 1/2" Pup Joints. Clear and clean Floor. 22:30 22:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazards with pick -up the BHA. 22:45 00:00 1.25 0 220 COMPZ RPCOM PULD P Install Wear Bushing. Make -up BHA #2 as follows: Itco Spear w/3.947" Nom (catch range 3.874" - 4.026" ) Grapple, Bumper Sub, Oil Jar, Pump- Out -Sub, 6 ea 4 3/4" Drill Collars, Intensifirer 12/27/2010 Run in with BHA #2 with single 3 1/2" Drill Pipe from the Pipe Shed. Plant Spear in the PBR. Release Baker FHL Packer. TOOH and lay down FHL Packer. Make up BHA #3. TIH tag top of Blast Joint Section. Plant Overshot. Pull Blast Joint section free. Start TOOH. 00:00 05:30 5.50 220 6,775 COMPZ RPCOM TRIP P Run in with BHA #2 with single 3 1/2" Drill Pipe Joints from the Pipe shed. 05:30 06:00 0.50 6,775 6,785 COMPZ RPCOM FISH P PJSM. Engage Fish @ 6782'md, No-Go out @ 6785' md. Pick -up Wt= 165k and Sheard Packer, move Packer up hole to 6775' md. 06:00 07:00 1.00 6,785 6,775 COMPZ RPCOM OWFF P Monitor Well for gas. Crew C /O, PJSM. 07:00 11:30 4.50 6,775 220 COMPZ RPCOM TRIP P POOH with DP & Packer, Seen 10k overpull @ 6665' md. Continue TOH, pumping 4 bbls every 5 stands. Up Wt =130k, no gas seen @ surface. 11:30 12:00 0.50 220 220 COMPZ RPCOM SFTY P PJSM, Before laying down BHA and Removing Packer. Monitor Well For Pressure. 12:00 14:00 2.00 220 0 COMPZ RPCOM PULD P Continue OOH and SB/ DC and UD Fishing Assembly and Lay Down Jewerly from Well. 14:00 14:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM on Beaver Slide Operation. 14:15 15:00 0.75 0 0 COMPZ RPCOM PULD P Lay Down Baker Tools from Rig Floor, and Load Next Set of Tools to Rig Floor. 15:00 15:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard of MU Baker Fishing BHA. 15:15 16:30 1.25 0 249 COMPZ RPCOM PULD P MU Fishing Assembly and start Rattler before TIH. 16:30 20:15 3.75 249 6,854 COMPZ RPCOM TRIP P TIH w /Fishing Assembly. 20:15 20:45 0.50 6,854 6,859 COMPZ RPCOM FISH P Up Weight = 127K. Down Weight = 105K. Tag top of Blast Joint section at 6.854-ft.dpmd. Swallow 5 -ft inside Overshot down to 6,859 -ft Pull up hole with 2K drag. Set back down and re -tag at the same place. Pull back up hole with same amount of drag. Blast Joint section is free. Page 6 of 13 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:00 1.25 6,859 5,385 COMPZ RPCOM TRIP P Start Trip out with 3 1/2" Drill Pipe standing back in Derrick. Stop to service Rig 22:00 00:00 2.00 5,385 5,385 COMPZ RPCOM SVRG P PJSM. Cut and Slip Drilling Line. 12/28/2010 Trip out with 3 1/2" Drill Pipe, BHA #3, and the Blast Joint section. Break down fish. PU and MU fishing BHA #4 and RIH, engage fish at 6,940 -ft. Pull seals from Packer. POOH and lay down seal assy fish. PU _ and MU Milling BHA #5. 00:00 03:30 3.50 5,385 0 COMPZ RPCOM TRIP P Continue to trip out with 3 1/2" Drill Pipe standing back in Derrick. 03:30 06:00 2.50 0 0 COMPZ RPCOM PULD P Lay down BHA. Blast Joint section at surface 06:00 07:00 1.00 0 0 COMPZ RPCOM SFTY P PJSM. Review the Cold Weather operating Guidelines. Going to keep Folk -lift and outside operations to a minimum. Used the buddy system during outside operation. Derrick hand will take break every 15 min, and follow Cold Weather Guideline at all times. 07:00 09:00 2.00 0 COMPZ RPCOM PULD P Lay Down Tools From Rig Floor and PU next set of tools to Rig Floor. Clean Rig Floor. 09:00 09:30 0.50 COMPZ RPCOM SFTY P PJSM, Discuss Hazard of making up Next Fishing Assembly. 09:30 10:30 1.00 0 219 COMPZ RPCOM PULD P MU Fishing Assembly (5 7/8" Close Catch Grapple ) 10:30 16:00 5.50 219 6,938 COMPZ RPCOM TRIP P RIH w/ fishing assy #4 from 219 -ft to 6,938 -ft. 130k up wt, 110k do wt. 16:00 17:00 1.00 6,938 6,909 COMPZ RPCOM FISH P Locate TOF at 6,939 -ft and workover and engage at 6,940.5 -ft. Pull 5k OSW, and POOH for 30-ft. Blowdown Top Drive. 17:00 17:30 0.50 6,909 6,909 COMPZ RPCOM SFTY P Held PJSM on POOH with Drill pipe and BHA. Discussed cold weather operating guidelines. 17:30 21:30 4.00 6,909 219 COMPZ RPCOM TRIP P POOH from 6,909 -ft. to 219 -ft. to BHA #4 21:30 22:15 0.75 219 0 COMPZ RPCOM PULD P POOH with BHA #4 and release Overshot from Fish. Lay down fish and breakdown Overshot. 22:15 22:45 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with bringing tools up Beaver slide. Discussed working in extreme cold weather. 22:45 23:30 0.75 0 0 COMPZ RPCOM OTHR P Bring fishing tools to rig floor via Beaver slide. Steam tools to warm up prior to make up. 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD P Begin PU and MU Milling BHA #5 12/29/2010 Continue to PU and MU Milling BHA #5. RIH and tag up at 6,868 -ft. work down to 6,892 -ft. POOH and PU BHA #6 (String Mill Assy) RIH to 6,952 -ft. (Top of Packer). POOH and Lay down BHA #6 00:00 01:30 1.50 0 336 COMPZ RPCOM PULD P Continue to PU and MU Milling BHA #5 to 336 -ft. 01:30 04:30 3.00 336 6,877 COMPZ RPCOM TRIP P RIH w/ BHA #5 from 336 -ft. to 6,877 -ft. and set down. 04:30 05:30 1.00 6,877 6,892 COMPZ RPCOM MILL T Work thru to 6,892 -ft, unable to work any deeper. Page 7 of 13 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:00 0.50 6,892 6,676 COMPZ RPCOM TRIP T POOH to 6,676 -ft. and hung up. 06:00 08:00 2.00 6,676 6,764 COMPZ RPCOM OTHR T Held crew change and work pipe free, begin circulating at 5 bpm will rotating 08:00 12:00 4.00 6,764 0 COMPZ RPCOM TRIP P Able to work dp free. Continue ooh standing back DP and BHA #5 12:00 12:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard of Picking up tools thru beaver slide. 12:15 12:45 0.50 0 0 COMPZ RPCOM PULD P Load Mills & Crossovers to Rig Floor, and steam connection. 12:45 14:00 1.25 0 346 COMPZ RPCOM PULD P MU 6 1/8" Dual String Mill. 14:00 17:30 3.50 346 6,654 COMPZ RPCOM TRIP P RIH Dual String Milling Assembly from 346 -ft. to 6,654 -ft. 17:30 19:30 2.00 6,654 6,952 COMPZ RPCOM MILL P MU Top drive and ream from 6,654 -ft. to 6,910 -ft. Parameters 125k up wt, 110k do wt, 125k ROT wt, at 120 rpm's with 5k free torque circulating at 3 bpm at 340 psi. Continue to ream down to Top of packer at 6,952 -ft. 19:30 20:00 0.50 6,952 6,952 COMPZ RPCOM SFTY P Held PJSM on Blowing down Top drive, POOH and laying down String Mill assy. Discussed using scraper tool to clean string magnets. 20:00 23:30 3.50 6,952 358 COMPZ RPCOM TRIP P Blow down Top drive, POOH to BHA #6 at 358 -ft. 23:30 00:00 0.50 358 0 COMPZ RPCOM OTHR P Lay down string mills. Dump boot baskets and recovered 2.5 gallons of scale. Small amount of iron recovered on string magnets. 12/30/2010 PU and MU BHA #7 (Packer Milling Assy) RIH to 6,952 -ft. Gather Parameters and mill up packer. Chase to top of fill at 7,112 -ft. Spot hi visc pill and POOH with BHA #7. RIH w/ BHA #8 (Spear assy) and fish Packer., POOH and laydown fish. 00:00 01:00 1.00 0 336 COMPZ RPCOM PULD P PU and MU BHA #7 (Packer Milling Assy) and Rlh to 336 -ft. 01:00 04:00 3.00 336 6,952 COMPZ RPCOM TRIP P RIH w/ BHA #7 from 336 -ft. to 6,952 -ft. 04:00 06:00 2.00 6,952 6,954 COMPZ RPCOM MILL P Gather Parameters - 125k up wt, 110k do wt, 120k ROT wt at 80 Rpm's with 5k Free torque, circulating at 3 bpm at 340 psi. Begin Milling at 6,952 -ft. and mill down to 6,953.5 -ft. in 2 hrs 10 minutes. 06:00 06:15 0.25 6,954 6,954 COMPZ RPCOM SFTY P PJSM. Crew Change Out. 06:15 08:00 1.75 6,954 7,103 COMPZ RPCOM MILL P Continue with milling operation. Ream out tight spot at 6948'md, push packer down to 7103'md. Spot 35 bbl Hi -Vis pill on bottom. 08:00 12:00 4.00 7,103 336 COMPZ RPCOM TRIP P PJSM. Blow down Top Drive. POOH f / 7103'md while pumping proper pipe displacement every 5 stands. Up Wt 125k. Page 8 of 13 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 336 0 COMPZ RPCOM PULD P PJSM. Lay Down Milling BHA. Boot Basket was full of Metal Shaving. Clean Floor of Tools. Load Tools to Floor. 13:00 13:30 0.50 0 312 COMPZ RPCOM PULD P MU Spear & Grapple and Fishing Assembly. 13:30 17:00 3.50 312 7,088 COMPZ RPCOM TRIP P PJSM.MU Up Drill Collars and Continue to Trip In Hole With Drill Pipe from 312 -ft. to 7,088 -ft. 125k up wt, 110k do wt. 17:00 18:30 1.50 7,088 7,088 COMPZ RPCOM CIRC P Change hole over from 11.8 ppg Brine to 10.8 ppg Brine at 4 bpm at 1,080 psi ICP 800 psi FCP. 18:30 19:00 0.50 7,088 7,088 COMPZ RPCOM OWFF P Monitor well for flow - fluid level dropping slowly. 19:00 19:30 0.50 7,088 7,103 COMPZ RPCOM FISH P RIH from 7,088 -ft. to 7,103 -ft. 130k up wt, 110k do wt. and engage fish, PU and seen slight overpull. 19:30 20:00 0.50 7,122 6,605 COMPZ RPCOM TRIP P POOH from 7,122 -ft to 6,605 ft. Seen 10k overpull while pulling through perfs. 20:00 20:30 0.50 6,605 6,605 COMPZ RPCOM OWFF P Monitor well for flow on trip tank - loosing 1.2 bhr. 20:30 23:30 3.00 6,605 331 COMPZ RPCOM TRIP P POOH from 6,605 -ft. to 331 -ft. with 3 1/2 DP to BHA #8 23:30 00:00 0.50 331 0 COMPZ RPCOM PULD P POOH and laydown fish. 12/31/2010 PU and MU BHA #9 and RIH to 5,040 -ft. Slip and Cut drill line. Continue to RIH and C/O to 7,193 -ft. POOH and LD C/O BHA #9. PU and RIH w/ F -1 Pkr asst' to 1,825 -ft. 00:00 01:00 1.00 0 296 COMPZ RPCOM PULD P PU and MU BHA #9 (Double String mill C/O Assy) to 296 -ft. 01:00 03:30 2.50 296 5,040 COMPZ RPCOM TRIP P RIH w/ BHA #9 from 296 -ft. to 5,040 -ft. Secure well 03:30 05:30 2.00 5,040 5,040 COMPZ RIGMNT SLPC P Hang Top drive, Slip and cut drill line and service draw works. Inspect brake assembly. 05:30 06:00 0.50 5,040 7,078 COMPZ RPCOM TRIP P Continue in hole w /Drill Pipe to 7078'md. Up Wt =130k / Down Wt =110k 06:00 09:00 3.00 7,078 7,189 COMPZ RPCOM CIRC P PJSM. Clean Out from 7078' and to 7189' and @ 8 bpm with 2580 circulating psi. Had Swival Seal packing on start leaking. Blow down Top Drive and PUH above perf to 6880' and and secure well. 09:00 10:00 1.00 7,189 6,880 COMPZ RIGMNT RGRP P PJSM. Change Out Swival Packing. 10:00 12:30 2.50 6,880 7,196 COMPZ RPCOM CIRC P Continue back down to 7196' Circulating @ 8 bpm, 2500 psi, pumped 35 bbl Hi -Vis Sweep and CBU 1.5 + times. PUH and Blow down Top Drive. Up Wt 125k 12:30 13:00 0.50 7,196 6,880 COMPZ RPCOM SFTY P PJSM. Discuss Hazard of TOOH. 13:00 17:30 4.50 6,880 296 COMPZ RPCOM TRIP P POOH, S/B DP. 17:30 18:00 0.50 296 296 COMPZ RPCOM SFTY P At Surface With Drill Collars. PJSM, On laying down Drill collars. Page 9 of 13 Time Logs Date From To . Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 296 0 COMPZ RPCOM PULD P Lay Down Drill Collars and Milling Assembly. 19:00 19:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM on offloading Baker tools down Beaver slide. 19:30 21:00 1.50 0 0 COMPZ RPCOM OTHR P Send Baker tools out Beaver slide and Pipe shed. 21:00 21:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM on PU and MU of Packer assy. 21:30 00:00 2.50 0 1,825 COMPZ RPCOM TRIP P PU and MU F -1 Pkr assy. RIH on 3 1/2 DP to 1,825 -ft. 01/01/2011 Continue to RIH from 1,825 -ft. to 7,000 -ft. RU E line and correlate by GR. POOH and RD E line. Drop Ball and place Pkr on depth of 6,922 -ft. Set Pkr and release off, POOH and lay down setting tool. PU and RIH w/ 3 1/2 Selective completion. Locate and space out seals. Drop ball and rod, Set FHL Pkr and shear out of L' PBR. POOH laying down 31/2 DP and Running tool. Wash BOP stack and Set test plug. Conduct weekly BOP Test. RIH with 31/2 Selective Completion to 650-ft. 00:00 02:00 2.00 1,825 7,000 COMPZ RPCOM TRIP P Continue to RIH from 1,825 -ft to 7,005 -ft. 02:00 02:30 0.50 7,000 7,000 COMPZ RPCOM SFTY P Held PJSM with E line and Rig crew on PU tools and equipment. 02:30 04:30 2.00 7,000 7,000 COMPZ RPCOM ELOG P RU well control equipment and GR / CCL tools. 04:30 08:30 4.00 7,000 7,000 COMPZ RPCOM ELOG P RIH w/ GR and CCL to 6,856 -ft. and corralate to 10 -ft pup jt at 6,824 -ft. 08:30 09:30 1.00 7,000 7,000 COMPZ RPCOM ELOG P POOH and RD E line. Down load Data from log. Tie -into log , had 3' correction. Discuss results with town engineer. RD E -Line. 09:30 10:00 0.50 7,000 6,922 COMPZ RPCOM PACK P Marked DP at rig floor. PUH 3' feet. Dropped 1 7/16" Ball, Allow ball to free fall for 10 minutes. PSI up on Packer to 3620 psi PUH and Shear off and set Packer © 6922' md. Set back down on packer and confirmed packer set. 10:00 10:15 0.25 6,922 6,900 COMPZ RPCOM SFTY P PJSM. Discuss Hazard of TOOH. 10:15 14:00 3.75 6,900 0 COMPZ RPCOM TRIP P Remove Treating Iron. POOH. 14:00 15:30 1.50 0 0 COMPZ RPCOM PULD P PJSM. Remove Setting Tools and Baker BHA. 15:30 16:00 0.50 0 0 COMPZ WHDBO BOPE P Set Test Plug. Rig Up Testing Equipment. 16:00 20:30 4.50 0 0 COMPZ WHDBO BOPE P Start Weekly BOP Test at 250/3,500 psi. 24 hr Notice was given to AOGCC © 07:30 hrs on 12- 31 -10. Bob Noble waived right to witness 08:20 hrs on 1 -1 -11. 20:30 21:30 1.00 0 0 COMPZ WHDBO BOPE P Pull Test Plug and Install wear ring. 21:30 22:00 0.50 0 0 COMPZ RPCOM OTHR P Prep Rig floor for picking packer. 22:00 23:00 1.00 0 166 COMPZ RPCOM PULD P PU and MU 3 1/2 Selective Completion and RIH to 166 -ft. 23:00 00:00 1.00 166 650 COMPZ RPCOM TRIP P RIH w/ 3 1/2 Selective Completion on 3 1/2 DP from 166 -ft to 650 -ft. Page 10 of 13 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/02/2011 24 hr Summary Continue to RIH with 3 1/2 Selective Completion from 650 -ft. to 6,929 -ft. and NO -go out. Pull seals from packer and spot 25 bbls of CI 10.8 ppg NaBr / KCL brine. Stab seals into F -1 Packer and space out. Drop t/ ball and rod. Set FHL packer and shear out of PBR. PT IA @ 1,500 psi - good test. Suspend ops due to Phase three conditions. 00:00 03:30 3.50 650 6,933 COMPZ RPCOM TRIP P Continue to RIH w/ 3 1/2 Selective Completion from 650 -ft. to Top of F -1 Packer at 6,922 -ft. Found Top of F -1 at 6,926 -ft and Work seals into 6,933 -ft. and no go. Pull back above F -1 Packer.. 03:30 04:30 1.00 6,924 6,924 COMPZ RPCOM CIRC P Pump 25 bbl CI 10.8 ppg NaBr / KCL brine and chase with 39 bbls of KWF. Circulating at 3 bpm at 280 psi. 04:30 05:00 0.50 6,924 6,768 COMPZ RPCOM PACK P RIH and Nogo, space out 1 -ft. Drop ball and Rod. Pressure up to 2,600 psi and set FHL packer at 6,791 -ft with top of PBR at 6,768 -ft. Hold 1,500 psi and Shear out of PBR. 05:00 05:30 0.50 6,768 6,768 COMPZ RPCOM PRTS P Pressure test IA at 1,500 psi for 15 minutes and chart. 05:30 06:00 0.50 6,768 6,736 COMPZ RPCOM PULD P Pull seals from PBR to 6,738 -ft. and Blow down Top drive. Install TIW valve. 06:00 06:15 0.25 6,736 6,736 COMPZ RPCOM OTHR P Continue to rack and tally 31/2 TBG completion prior to POOH laying down 3 1/2 DP. Recieved announcement that Kuparuk was in Feild wide Phase three conditions and secured well and set to monitor off trip tank. 06:15 00:00 17.75 6,736 6,736 COMPZ RPCOM OTHR T Phase Three Weather Condition. Cease operation until weather condition improve. 01/03/2011 Suspend operations till Phase three restrictions are lifted. Able to return to normal operation at 2030 hrs after v' digging out equipment and secondary containment. Start POOH laying down Drill Pipe and setting tool. 00:00 12:00 12.00 6,736 6,736 COMPZ RPCOM OTHR T Operations suspended do to Phase three conditions. 12:00 19:00 7.00 6,736 6,739 COMPZ RPCOM OTHR P Start Back to Work after Phase III Condition. Start Checking Equipment and Start Digging Out Tools and Secondary Containment. Current Condition Phase II on main roads. Contacted CPF 3 Drill Lead asks if we can start Digging Out equipment around location. He gave us the go ahead. Page 11 of 13 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:30 1.50 6,739 6,739 COMPZ RPCOM CIRC P Do to no fluid movement in 38 hrs, since 05:00 hrs on 1 -2 -11. Decision was made to Circulate 1 hole volume of 237 bbls at 4 bpm at 400 psi. Returning fluid temp at bottoms up was 48 degrees and fluid temperature in was 56 degrees. Shutdown pumping ops and monitor well while waiting phase three pad restriction to lift. 20:30 22:30 2.00 6,739 6,739 COMPZ RPCOM OTHR T Operations suspended do to Phase one conditions from CPF3 to 3H pad and phase three restrictions on 3A pad. CPF 3 Drillsite lead called and lifted Phase three restrictions at 22:30 hrs on 1 -3 -11. 22:30 00:00 1.50 6,739 5,429 COMPZ RPCOM PULD P Open TIW valve and remove. Begin POOH from 6,739 -ft, laying down 3 1/2 DP. 01/04/2011 Laying Down Drill Pipe From 5,429.0 to seal assy and lay down same.PU and RIH with 3 1/2 upper completion as run order. Land hanger with seal assembly approximately 7' from fully located. Test tubing to •/ 3,000 •si and IA to 3,500 psi. Close SSV and test below to 1,000 psi. Bleed pressures to zero. 00:00 08:00 8.00 5,429 0 COMPZ RPCOM TRIP P Continue POOH, Laying Down Drill Pipe From 5,429.0 to seal assy and lay down same. At 04:30 hrs, We held a full camp fire evacuation drill - Total evac time was 4 minutes. Great participation by all! 08:00 08:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with crew and Baker Completion hand on pulling wear ring, changing over to 3 1/2 TBG equip. and RIH with 3 1/2 Completion. 08:30 09:00 0.50 0 0 COMPZ RPCOM OTHR P Pull wear ring and Change over to 3 1/2 TBG equipment. 09:00 15:00 6.00 0 5,000 COMPZ RPEQP1 TRIP P PU and RIH with 3 1/2 upper completion as run order to 5,000'ft 15:00 21:00 6.00 5,000 6,778 COMPZ RPCOM TRIP P Remaining 55 jts were banded with 59 stainless steal C/L bands to 6,778' MD, Up weight 87K Down weight 80K, verify seals engaged in PBR. Re -tag and space -out with 7' "sticking up ", lay down joint 213, make up four pup joints for space -out 26.63'. Joint #213 just below hanger, make up hanger assembly and landing joint. 21:00 22:00 1.00 0 0 COMPZ RPCOM PULD P Land hanger, RILDS. PJSM. Rig up kill lines for testing. Page 12 of 13 Time : Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 COMPZ RPCOM PRTS P PT tubing to 3,000 psi for 30 mins, good test. bleed tbg 2,500 psi and test IA to 3,500 psi, (chart recorded) good test for 30 mins, bleed tbg and IA to zero. Pressure up on IA to 1,950 psi shear SOV. Test SSSV below flapper to 1,000 psi, good test. Lay down landing joint, set BPV. 01/05/2011 NU 3.5" tree and test pack- off /tree 250/5,000 psi. Displace well over to Corrosion inhibited sea water. Freeze protect with 70 bbls diesel to 2,000'. Release Rig. 00:00 06:30 6.50 0 0 COMPZ RPEQPI NUND P Changed out 4 Koomey hoses for a total of 6 of the 12 on BOP stack. ND BORE. 06:30 10:30 4.00 0 0 COMPZ RPEQPI NUND P Stab adapter and 3 1/8" 5M tree. Orientation was verified by DSO. NU and set test plug. PT pack off at 250 / 5,000 psi and held for 10 min. -good test. PT tree against test plug and chart for 10 min. - good test. 10:30 11:00 0.50 0 0 COMPZ RPEQP1SFTY P Held PJSM on changing well over from 10.8 ppg NaBr / KCL to CI 9.6 KCL brine. Discussed blowing air to tiger tank to verify line clear. Verifying tank volume prior to circulating. 11:00 14:00 3.00 0 0 COMPZ RPEQP1CIRC P RU to swap out 10.8 ppg to 9.6 ppg CI brine. Circulate 140 bbls at 2 bpm at 400 psi ICP and 1,250 psi FCP while holding 500 psi back pressure. 14:00 15:30 1.50 0 0 COMPZ RPEQPI FRZP P PJSM with LRS and RU to IA. PT treating lines at 2,500 psi. Pump 70 bbls of 60° LEPD diesel at 2 bpm @ 1,550 psi ICP and 2,050 FCP. RD LRS. 15:30 17:30 2.00 0 0 COMPZ RPEQP1OTHR P Utube IA x TBG for 1 hr. Pressure balanced at 300 psi. RD hoses and Blow down kill line. 17:30 18:00 0.50 0 0 COMPZ RPEQPI MPSP P RU lubricator, lube in BPV and LD Lubricator. 300 psi on TBG below BPV 350 psi IA 500 psi OA 18:00 22:00 4.00 0 COMPZ RPEQP1OTHR P Dress and clean tree. Back rig off well, clean and clear cellar area, pull off well, inspect location. Release Nordic Rig at 22:00 hrs on 01- 05 -11. Page 13 of 13 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 7, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Correlation: 3A -07 Run Date: 1/1/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21444 -00 WANIVEDFEB r 2011 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. 3 L S " as 3 Anchorage, Alaska 99518 3 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halbn,cor Date: °' ' ,a Signed: . • Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Friday, December 24, 2010 6:56 AM ( " 7/ Z .' I O To: Packer, Brett B ll Cc: Regg, James B (DOA) Subject: RE: Well 3A -07 (PTD #185 -223) BOP Test Mr. Packer, I have discussed your request with my supervisor Mr. Jim Regg and your request for a BOPE test variance is granted, based on our telephone conversation and the information you have provided. Please keep the AOGCC informed of any change to your forward plan that relate to this variance. Jeff Jones AOGCC 9E1 k Original Message From: Packer, Brett B [mailto:J. Brett .Packer @conocophillips.com] Sent: Friday, December 24, 2010 5:08 AM To: Jones, Jeffery B (DOA) Cc: Nordic 3 Company Man; Gober, Howard; Nelson, Erik Q; Packer, Brett B Subject: Well 3A -07 (PTD #185 -223) BOP Test Jeff, Yesterday 3A -07 was killed by circulating 11.8 ppg NaCl /NaBr kill weight brine around. The well was stable, a BPV was set in the tubing hanger, and when the tree was removed, a visual inspection of the lift threads showed indication of damaged threads. Regardless, we attempted testing the BOPE by setting a Blanking Plug in the damaged lift threads, but as expected, we were seeing fluid leaking by those threads and down the tubing. After discussions around the group and with your verbal approval, we determined that the best and safest course of action would be to: 1. Test all surface equipment as per normal testing procedure. r 2. Conduct a rolling test to 250/3,500 psi on all BOPE components that we are capable of testing at the time. 3. RU Slickline 4. Pull the BPV. 5. RIH and set a plug in the 2.81" profile of the SSSV at 1811' RKB, test the plug to 3500 psi. 6. Perform full BOPE test to 250/3,500 psi, testing against the plug in the SSSV. 7. Pull plug from SSSV. 8. RDMO Slickline. 9. Continue with workover as planned and attempt to pull tubing. Last night, we tested all valves in the Choke Manifold, the Dart 3Lalve, the Hydraulic Valve on the Top Drive and the manual Top Drive Valve at 250/3,500 psi. All good tests. Per verbal agreement, a "rolling test" was performed at 250/3,500 psi on both the upper and the lower 2 7/8" x 5" Variable Bore Pipe Rams and the Annular using the 3 1/2" Test Joint. However the results, as expected, showed a loss of -40 psi on the low test in 5 minutes and a loss of 1,000 psi in one minute on the high test. The Blind ram was tested with the some low /high results too. No leaks were observed at the flanges or on any surface components. 1 1 Currently, Slickline is on its way and we will continue with the plan as previously outlined. We will not attempt to pull the tubing until we hav- . •leted a successful full BOP test on this well. This email is to document the current steps to en an• e plan forward. We are seeking your written approval of our plan forward, but meanwhile will continue down that path unless we hear otherwise from you. If you have any additional questions, please contact me at 230 -8377 or the Nordic 3 Rig Supervisors at 659 -7446. I look forward to your response. Thank you, Brett Packer Wells Engineer 2 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 30, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: 3A -07 Run Date: 11/24/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21444 -00 F bUr$ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 v Z C t Y - 00 3 Office: 907- 273 -3527 Fax: 907 - 273 -3535 2 056 klinton.woetl@lialOthlo Date: Signed: ;1444k,1 r SEAN PARNELL, GOVERNOR AaASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 J. Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. %aW&D NOV 2 4 1010 P.O. Box 100360. Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 3A -07 Sundry Number: 310 -388 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. R , rman sioner DATED this 23 day of November, 2010. Encl. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 A ECE IV ED November 19, 2010 q a N 1 � 9 2010 #s b�la �'��I ii� COQSr j3aiiiilltlN�l/Y�t1 Commissioner Dan Seamount Ai'd.4craga State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 3A -07 (PTD 185 -223). 3A -07 was originally completed in November 1985 as a selective single A & C sand producer. It remained on production for 5 years and was then converted to an injector. The injection in this well has been shut in since March of 2010, and in an effort to depressure this area, the well was flowed back for 5 months between May and September 2010. Prior to the flowback, the A & C sand SBHP's were measured to be 4650 psi and 4709 psi respectively. Following the flowback, the current A -sand SBHP as measured on 10/12/10 is 3355 psi at a mid -perf depth of 7060' MD (6126' TVD) which has dropped considerably. The C -sand pressure is estimated to be , similar or lower than the current A -sand pressure as the C -sand is more prolific and has a higher permeability. The purpose of this workover is to set it up for the upcoming CTD sidetrack. Plans are to pull the current 3 ''h" x 2 7 /8" selective completion and replace it with an all 3 '' /z" selective completion. Currently there is nothing wrong with the well, but this well was identified as a good candidate for a CTD sidetrack to target reserves at risk. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, �2 J. Brett Packer Wells Engineer CPAI Drilling and Wells STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION�� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ red Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing Q ime Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: CTD Set -up Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 185 -223 3. Address: Stratigraphic ❑ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21444 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ 3A -07 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25632 ' I Kuparuk River Field / Kuparuk Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7325' 6328' Casing Length Size MD TVD Burst Collapse Conductor 104' 16" 104' 104' Surface 3146' 9 -5/8" 3176' 3086' Production 7257' 7" 7281' 6295' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6888 -6922, 6990 -7010, 7024- 5993 -6020, 6073 -6088, 3 -1/2 ", 2 -7/8" J -55 6965' 7060,7118 -7128 6099 -6126, 6171 -6178 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FVL SSSV 1811' MD, 1811' TVD Baker FHL Pkr 6794' MD, 5919' TVD Baker FBA Pkr 6946' MD, 6038' TVD 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/3/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ Q r GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brett Packer Printed Name J. Brett Packer ( Title Wells Engineer Signature l Phone 265 -6845 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3jo '�)v C T'tp SET cc.a Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: r 3 500 „o Sc. 16 A e S h 4`2 Ps[. / P - � Subsequent Form Required: 1 APPROVED BY Approved by: O 1 SIONER THE COMMISSION Dater 11171111L)III.M119110 MY - ��.1,3•t® Itt 0111.11 -'0 Form 10 -403 Revised 1 /20'fD �.Y Submit in Dup'cat�� f1 1�1 3A -07 Rig Workover, CTD Setup (PTD #: 185 -223) Current Status: Injection on well 3A -07 was shut in March 27, 2010. The well was flowed back from May 26, 2010 to Sept. 14, 2010 to depressure the pattern for the upcoming RWO. The well is currently shut -in. 1 7 » 1 Scope of Work: Pull the 3 /z " x 2 /8 selective and replace with an a113 ii selective completion. During the workover the tubing ead and IC ackoffs will be replaced. g P P General Well info: MASP: 2,742 psi Reservoir pressure/TVD: 3,355 psi / 6126' TVD (10.53 ppg) Wellhead type /pressure rating: FMC Gen 3, 7- 1/16" 5K psi top x 11" 3K btm BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -T— passed on 8/5/10, MIT -IA— passed on 8/9/09, MIT -OA— passed on 3/24/09. Well Type: Injector Earliest Estimated Start Date: December 3, 2010 Production Engineer: John Tonello / Len Janson Workover Engineer: Brett Packer (265 -6845 / j. brett.packer @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. Set 2.25" CA -2 plug in the `D' nipple at 6959' MD. Set catcher sub on top. b. Pull BPI sleeve from AVA nipple at 6938' MD. c. RIH w/ dual panex gauges. Obtain 30 min. C -Sand SBHP at 6906' MD, PUH to 6780' MD to obtain, 15 min. gradient stop. POOH. d. Pull DV in GLM @ 6730' MD. Pull catcher sub. e. Pull 2.25" CA -2 plug from the `D' nipple at 6959' MD. - f. Lock out SSSV @ 1811' MD. _ 2. RU E -line: a. RIH w/ the RCT (w/ GR & CCL) and cut the 3 -1/2" pup joint at exactly 6934' RKB (2' from the top of the collar below the blast rings). POOH. b. RIH w/ the RCT (w/ GR & CCL) and cut the 3 -1/2" tubing at 6850' RKB (10' below the injection mandrel). POOH. Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Reverse circulate 236 bbls KWF through open GLM at 6730' MD. Bullhead �yr an additional 25 bbls to the formation. Verify well is dead. --1w 2. Set BPV & FMC blanking plug. ND tree, NU BOPE & test. 3S� / �� 3. Pull blanking plug & BPV. Circulate bottoms up. 4. MU landing joint, BOLDS, and attempt to pull tubing from the PBR. a. If tubing does not pull free, RU E -line and RIH w/ the RCT and cut the tubing at 6755' RKB (middle of the full joint above the PBR). POOH. RDMO E -line. 5. POOH laying down 3 -1/2" EUE 8rd J -55 tbg spooling up control line. 6. MU overshot and single in on 3 -1/2" IF drillpipe. a. If tubing was cut, latch onto tubing and jar seal assembly from the PBR. POOH standing back drillpipe, lay down fish. RBIH w/ overshot dressed for 5.125" OD PBR. 7. Latch onto PBR and jar FHL packer free. OOH standing back drillpipe, lay down fish. 8. MU 80' washpipe, grapple for 3 -1/2" tubing, and RIH to 6850' MD, slowly wash over blast rings, latch onto 3 -1/2" tubing stub and POOH w/ blast ring section standing back drillpipe. 9. MU overshot dressed for 3 -1/2" tubing and RIH to tubing stub at 6934' RKB. Latch onto stub and jar seal assembly from FB -I sealbore extension. POOH standing back drillpipe. 10. MU packer mill and RIH to 6946' RKB, establish circulating parameters, record up /down weights, commence milling FB -I packer. POOH standing back drillpipe. 11. MU spear and RIH to retrieve FB -I packer, POOH standing back drillpipe. 12. RU E -line: MU 50' of 5 -1/2" liner w/ 6" OD Wearsox and F -1 packer w/ SBE, RIH w/ E -line setting tools and set packer at 6925' MD. POOH. RDMO E -line. 13. MU FHL straddle packer assembly and RIH on drillpipe to top of F -1 packer. 14. Spot corrosion inhibited brine below FHL. 15. Sting into SBE until fully located, pull up 1', drop ball & rod, set the FHL w/ 2500 psi. PT the IA to 2500 psi. Shear the PBR. POOH laying down DP. ..,��,I ex a. On TOH w/ drillpipe, set storm packer at —100'w/ drillpipe hanging below. NDBOP. b. Replace tubing head & IC packoffs. ✓ c. NU BOP & test d. Release storm packer and POOH laying down storm packer. 16. Unload old tbg, load & strap new 3 -1/2 ", 9.3 #, L -80 8rd EUE tbg into pipe shed 17. Redress seal assy. (if needed) and single in w/ new 3 -1/2" tubing. Install SSSV at 2000' MD. Continue RIH to just above the PBR. Sting into PBR, space out 7' from fully located, mark pipe and pull out of PBR. 18. Load IA w/ corrosion inhibited brine. 19. MU tubing hanger w/ pups and land the hanger. - 20. PT the tubing to 3,000 psi, bleed tbg to 2500 psi, PT the IA to 3500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 21. Pull landing joint, set two -way check, NDBOP 22. NU and test tree. Pull two -way check, freeze protect, and set BPV. 23. RDMO Nordic 3 Post -Rig Work: 1. Pull BPV. 2. Pull ball & rod. Pull SOV and install DV. Pull RHC plug body. 3. Turn well over to CTD. tdG�ldl q1��d ,% •� N 01- Q � JVfr /��#G,;,� 7V Po 7 V * P a crp Po telteick 05slig ip ri e A ty re- o o*/ .41 /1��4 fi , KUP 3A-07 ConocciPhi' ip5 eiiAi#ributes " I' 7 An le 8't NiE1h, T s Welibore APVUWI Plaid Name Well Status Incl I') MID(ftK19) Act Btm (RKB) Imo 500292144400 KUPARUK RIVER UNIT PROD 41.06 3,200.00 7,325.0 Comment H25 (ppm) Date Annotation I End Date KBGrd (ft) Rig Release Date SSSV: TRDP Last WO: 36.48 10/25/1985 Well'''DOn 1 3A -07.STR0102`50'S9 RM Schematic AduaE Annotation Depth (RKB) Entl Date Annotation Last Mod By End Date Last Tag: SLM 7,128.0 1 3202010 I Rev Reason: SET BPI Imosbor 8/7/2010 'fix: ° V I Ili9liu �Casina Sfirin s .. - -._ -. .......... String OD String ID Set Depth I Set Depth (TVD) String Wt String it Casing Description (in) (in) Top (RKB) (RKB) (RKB) (Ibs/ft) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 104.01 104.0 62.50 H-40 CONDUCTOR,. - SURFACE 95/8 8.765 0.0 3,176.01 3,085.5 36.00 J -55 104 PRODUCTION 7 6.151 0.0 7,281.01 6,294.6 26.00 J -55 TublingliStrings it Safety Valve, Stnng OD String ID Set Depth Set Depth (TVD) String Wt String 1,811 Tubing Description (in) (in) To 1ftK8) (RKB) (RKB) (IbsRt) Grade String Top Thrtl TUBING 1 31/21 2.992 0.0 6,941.0 6,034.4 9.30 J -55 18RD EUE TUBING 1 27/81 2.4411 6,941.01 6,965.01 6,053.2 6.50 J -55 18RD EUE SURFACE. Other'ItY� Hole A[I Jewel :. Tubin Run & Retrievable, Fi'sh etc. I !...' 3.176 Top Depth (TVD) Top Ind Top (RKB) (ftK8) V) Description Comment Run Date ID (in) y _ 1,811 1,811.0 0.17 Safety Valve Baker'FVL' 1124/1985 2.812 GAS LIFT, 1, 6,730 5,866.7 35.96 GAS LIFT MERLA/TPDX/1.5/DMY/T -0// Comment: STA 1 1/311991 2.875 6,730 6,780 - 5,907.3 36.66 PBR Baker PBR 11/24/1985 3.000 pi. 6,794 5,918.5 36.86 PACKER Baker'FHL' PACKER 1124/1985 3.000 6,832 5,948.7 37.39 INJECTION CAMCO/KBUG/1/DMY /BK -2// /Comment: STA2 2/29/1996 2.875 6,938 6,032.1 38.91 NIPPLE AVA'BPL'Nipple w /27/8 "XO 11124/1985 2.750 PBR, 6,780 = 6,936 6,032.1 38.91 SLEEVE -C AVA; BPt SLEEVE 815/2010 2.310 6,946 6,038.4 38.99 PACKER Baker'FB-1' PACKER 11/24/1985 3.000 6,959 6,048.5 39.11 NIPPLE Camco'D' Nipple NO GO 11124/1985 2.250 6,964 6,052.4 39.16 SOS Carl 11/24/1985 2.441 [ 7 PACKER, 6,794 6,965 6,053.2 39.16 TTL 1124/1985 2.441 Perf&at[ans &Slots - "" Shot Top (TVD) Bum (TVD) Dens Top (RKB) Btm IRKS) (RKB) (ftKB) Zone Date (an •^ Type Comment : A wJEC 6. �q ''�' 6,888 6,922 5,993.1 6,019.5 C-4, C -2, C -1, 1124/1985 12.0 IPERF 120 deg. phasing; 5" Csg Gun x,832 T L UNIT B, 3A -07 _ Ca../' 6,990 7,010 6,072.6 6,088.0 A -3, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 2 1/8" SG 6,990 7,010 6,072.6 6,088.0 A -3, 3A -07 3/16/1986 4.0 RPERF 0 deg. phasing; Bar Kone II 7,024 7,060 t6,O98.8 6,126.4 A -2, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun IPERF, - 7,024 7,060 6,126.4 A -2, 3A -07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II 6,888 -6,922 7,118 7,128 6,178.3 A -1, 3A -07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun 7,118 7,128 6,178.31A-1, 3A -07 311611986 4.0 RPERF 190 deg. phasing; Bar Kone II NIPPLE, 6,938 SLEEVE -C, 6,938 PACKER, 6,946 NIPPLE, 6,959 SOS, 6,964 TTL, 6,965 IPERF, 6,990 -7,010 RPERF, 6,990 -7,010 RPERF, 7.024-7,060 . IPERF. 7,0247,060 RPERF, 7.118 -7,128 IPERF, 7,11 &7,128 - PRODUCTION, - 7,281 TD, 7,325 s s WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 21, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 3A -07 Run Date: 10/12/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21444 -00 Bottom Hole Pressure Survey Log NO V 16 2D10 1 Color Log 50- 029 - 21444 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 �� a Office: 907 - 273 -3527 Fax: 907 -273 -3535 klinton.woo halliburton.com 0 Date: Signed: .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI N REPORT OF SUNDRY WELL OPERATIONS ~. operations Performed: Abandon [ Repair w ell ~ Plu Perforations Stimulate Other WINJ to Prod. 9 C ~ wi ARer Casing r Pull Tubing r Perforate New Pbol ~ Waiver C Time Extension ~"~ Change Approved Program ~ Operat. Shutdown [' Perforate ~ Re-enter Suspended Well 2.Operator Name: 4. Current Well Status: . Permit to Drill Number: Inc. ConocoPhillips Alaska Development ~ Exploratory ~ 185-223 , 3. Address: Stratigraphic r Service ~ ~. API Number: 50-029-21444-00 P. O. Box 100360, Anchorage, Alaska 99510 7. Properly Designation;r 8. Well Name and Number: ` ADL 25632 3A-07 Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 7325 feet Plugs (measured) None true vertical 6328 feet Junk (measured) None Effective Depth measured 7191 feet Packer (measured) 6780, 6794, 6946 true vertical 6225 feet (true vertucal) 5907, 5919, 6038 Casing Length Size MD TVD Burst Collapse CONDUCTOR 104 16 104 104 0 0 SURFACE 3176 9.625 3176 3085 0 0 PRODUCTION 7281 7 7281 6294 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 6888-6922,6990-7010,7024-7060,7118-7128 True Vertical Depth: 5993-6019,6072-6088,6098-6126,6170-6178 ~~~~~~~~ Tubing (size, grade, MD, and TVD) 2.875, J-55, 6965 MD, 6053 TVD ~ u ~ 2 ~ Z ~ ~ a Packers & SSSV (type, MD, and TVD) PBR -BAKER PBR @ 6780 MD and 5907 TVD Ala$ke 0~ & air bt~a~lr. Wi0'tfft~SS~O PACKER - BAKER'FHL' PACKER @ 6794 MD and 5919 TVD {IiOGliflr~3~8 PACKER - BAKER'FB-1' PACKER @ 6946 MD and 6038 TVD TRDP - BAKER'FVL' @ 1811 MD and 1811 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ; 4 ~,.,, L * . ,~ , ,? ! " ~' '? (~ 3ly 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1500 850 2800 Subsequent to operation 1 0.35 1000 1460 148 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development C Service 15. Well Status after work: Oil ~ Gas ^ WDSPL (i Daily Report of Well Operations X GSTOR r WAG ~ GASINJ [ WINJ ~ SPLUG 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: 310-141 contact Bob Christensen/Darrell Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date - Cv Zl ~ ~ - - - --~~ ~w tutu ~ Form 10-404 Revised 7/2009 ~~ 7•zz -~~ Submit Original Only • • 3A-07 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/26/10 Well converted to production to releave pressure for drilling. Put on production at 0944 hours. _,, ~\~ KUP a 3A-07 ~Or10CV t"I II~~IpS Well Attributes Max An le 8r MD TD Al,ttiK n t I WellUOra API/UWI Fieltl Nanw Well Btatue Incl (°) MD If[KB) Act Btm (RNB) , 500292144400 KUPARUK RIVER UNIT INJ 41.0 6 3,200.00 7,325 .0 Comment H2S (ppm) Daie Annotation Eno Date KB l'irtl (R) Rig Release Date -- SSSV: TRDP Last WO: 36.48 10/25/1985 Wsll Co nfi :-3A-07326/2010 m:1 s.o 3 AM hemalp-ACNaI Annotation Depth (ftKB) Entl Date An notation Laet Motl By Entl Date Last Tag: SLM 7,128.0 3/20/2010 Rev Reason: TAG, Pull Plug/Gauges Imosbor 3/26/2010 Casin Strin s Deecrl Caein tlon string OD lint String ID lint (ftKB) To set Depth (RKB) Set Depm (TVD) IRNB) string Wt (IDel/t) string Oratla String Top 7hrtl p g CONDUCTOR 1 6 15.062 p 0.0 104.0 104.0 62.50 HAO coNOUCroR, SURFACE 95/ 8 8.765 0.0 176.0 3 085.5 3 36.00 J-55 101 , , II PRODUCTION 7 6.151 0.0 7,281.0 6,294.6 26.00 J-55 Tubin Strin s Bafery Veiw, String OD String ID Bet Depth Set Depth (TVD) String Wt String 1,811 Tu Ding Deecriptlon (In) (In) Top (ftKB) (RNB) (RNB) (IDe/ft) Ontle Btring Top Thrtl TUBING 3 1 2 2.992 0.0 6,941.0 6,034.4 9.30 J-55 SRD EUE TUBING 2 7/ 8 2.441 6,941.0 6,965.0 6,053.2 6.50 J-55 SRD EUE suRFACE, 1 Other In Hole A ll Jewel :Tubin Run & R etrievable, Fish, etc. 3,176 Top Depth (TVD) Top Incl Top (fINB) (RNB) (`) Descriptlon Comment Run Date ID (in) 1,811 1,811.0 0.17 S afety Valve Baker'FVL' 11/24/1985 2.812 cns uFr, 6 730 866.7 5 35.96 G AS LIFT MERIA/TP DX/1.5lDMY(f-2/// Comment: STA 1 1/3/1991 2.875 s,730 , , 6,780 5,907.3 36.66 P BR Baker PBR 1124/1985 3.000 6,794 5,918.5 36.86 P ACKER Baker'FHL' PACKER 11/24/1985 3.000 6,832 5,948.7 37.391N JECTION CAMCOIKBUG/1/DMY/BK-2l//Comment: STA2 2129/1996 2.875 6,938 6,032.1 38.91 N IPPLE AVA'BPL' Nipple w/ 2 7/8" XO 1124/1985 2.750 P6R, s,7eD 6,938 6,032.1 38.91 S LEEVE-0 AVA; BPC SLEEVE 6/2/1999 2.310 6,946 6,038.4 38.99 P ACKER Baker'FB-1' PACKER 11/24/1985 3.000 6,959 6,048.5 39.11 N IPPLE Camco'D' Nipple NO GO 11/24/1985 2.250 i 6,964 6,052.4 39.16 S OS Camco 11/24/1985 2.441 PACKER, x,794 6,965 6,053.2 39.16 T TL 11/24/1985 2.441 t ~: 1 Perforations 8 Slots Shot Top (TVD) Btm (TVD) Dans Top (ftKB) Btm (RKB) (RNB) (RNB) Zane Date 1°h..' Type Comment INJECnoN, 6,888 6,922 5,993.1 6,019.5 C -4, C-2, C-1, 1124/1985 12.0 IPERF 120 deg. phasing; 5" Csg Gun s.B3z U NIT B, 3A-07 6,990 7,010 6,072.6 6,088.0 A -3, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasirg; 2 1/8" SG 6,990 7,010 6,072.6 6,088.0 A -3, 3A-07 3/16/1986 4.0 RPERF 0 deg. phasirg; Bar Kone II 7,024 7,060 6,098.8 6,126.4 A -2, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun IPERF, 7 024 7 060 6 098.8 126.4 A 6 -2 3A-07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II 6,868-B 922 , , , , , 7,118 7,128 6,170.7 6,178.3 A -1, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun 7,118 7,128 6,170.7 6,178.3 A -1, 3A-07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II NIPPlE, 6,938 6LEEVE~O,~ " 6.938 PACKER, 6,946 J 1 -- - " 1 NIPPLE,6959 505. 6.961 ~ TTL, 6,965 IPERF, 6,990-7 010 RPERF, 8,930.7 010 RPERF, 7 024-7060 IPERF, T,024.],OW RPERF, ],118-],128 IPERF, 7,118-7,128 PRODUCTION, 7281 TD, 7325 • • Darrell Humphrey Production Engineering Specialist ~~ ConocoPhillips Alaska, Inc. ~ / P.O. Box 100360 ~~ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 3A-07 .,_ , ~ , Y_y;,, , ~ ~ ~ '`. ~~ ~ ~ ~ Sundry Number: 310-141 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~~ DATED this ? day of April, 2010. Sincerely, Daniel T. Seamount, Jr. Chair Encl. • • • Conoco`Phillips April 24, 2010 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7~` Ave. Ste. 100 Anchorage, AK 99501 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 3A-07 from Water Injection Service to Oil Production service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3A-07 (PTD 185-223). If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659-7535. Sincerely, ~ Q . ~~ Darrell R. Humphrey Attachments Sundry application Well schematic ' ~~ °" ~~~r~ STATE OF ALASIG4 (~{~ ~ () ~ ALAS IL AND GAS CONSERVATION COMMISSI~ (~~~ Q~~~~ Q,i APR 2 ~AICATION FOR SUNDRY APPROVALS u ~IN 20 AAC 25.280 ~ ~ Plug for laedrtll [" Perforate New Pool ~ F~pair w etl ^ 1. Type of Request: a Change Approved Program ("_I, n Suspend __ Plug Fi'rforations ~ Perforate ~ Pull Tubing ^ Time Extension [1 Operational Shutdow n ~ Re-enter Susp. Well ~ Stimulate rF Atter casing Other: WINJ to Prod. ~ ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ~"; Exploratory ('~ 185-223 ~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: • P. O. Box 100360, Anchora e, Alaska 99510 50-029-21444-00 7. If perforating, Gosest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number. where ownership or landownership changes: Spacing Exception Required? Yes ~ No y; 3A-07 9. Property Designation: 10. Field/Pool(s): ADL 25632 Kuparuk River Field / Kuparuk OiI P of • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7325 6328 7191' 6225' Casing Length Size MD ND Burst Collapse CONDUCTOR 104 16 104' 104' SURFACE 3176 9.625 3176' 3085' PRODUCTION 7281 7 7281' 6294' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 88-6922,6990-7010,7024-7060,71.18-71 5993-6019,6072-6088,6098-6126,6170-6178 2.875 J-55 6965 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PBR -BAKER PBR MD= 6780 ND= 5907 PACKER - BAKER'FHL' PACKER MD= 6794 ND= 5919 PACKER - BAKER'FB-1' PACKER MD= 6946 ND= 6038 TRDP - BAKER'FVL' MD= 1811 ND= 1811 12. Attachments: Description Summary of Proposal ,I; 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch r E~loratory r Development (~! • Service ~ ! 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2010 Oil r` Gas ^ WDSPL ~ i Suspended ~" i 16. Verbal Approval: Date: WINJ r GINJ ^ WAG ^ Abandoned Commission Representative: GSTOR [~ SPLUG [ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Christensen/Darrell Humphrey Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature ~ ._ Phone: 659-7535 Date ~ { •Zy- `(~ C mmi i n Use nl Sundry Number:, O , ~~ t Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test ~ Location Clearance r Other. Subsequent Form Required: ~ ~ . [ O I ~~~~/~ Approved by: COMMISSIONER .THE COMMISSION Date: Form 10-403 F~1 dIPR 2 8 20 YZY ~b Submit in Du licate ORlGlNAL ~- ~~i'~~~~ Y1~1~%~~ • • a ~ ~r 3A-07 DESCRIPTION SUMMARY OF PROPOSAL The proposed 3A-17A CTD Sidetrack will be targeting the fault block in which the 3A-07 injector is located. It is expected that the pressures measured in the 3A-07 injector will be equal to the area that the 3A-17A will be penetrating. Pressures in the 3A-07 fault block currently exceed the pressure limits of the CDR2-AC CTD rig. In order to successfully drill the 3A-17A CTD Sidetrack, a proposal has been made to flowback the 3A-07 injection well to the production facilities. A flowback will allow for sufficient depressurizaton of the target fault block. It is expected that the required time for flowback will be ~ 3 months based on analog data. Pressures will be taken throughout the flowback to determine progress of depressurization. :08/09/09: State witnessed MITIA passed ~ , 03/24/09: MITOA passed (Waived) ~~~ KUP ~ 3A-07 ~OfIOCOrI ll~~lPS ell Attributes ax An le S MD TD Wellbore API/UWI Field Nama Well Status Inc! (°) MD (ftKB) Acl Blm (ftKB) Af,l~,i., 1, 11, _ 500292144400 KUPARUK RIVER UNIT INJ 41.06 3,200.00 7,325.0 C omment H2S (ppm) Date Annotation End Data KBl3rtl (R) Rlg Release Date "' SSSV: TRDP Last WO: 36.48 10/25/1985 Well Conf, - 3A-07 3262010 1 J 15 J3 hemalic-AcNal AM A nnotation Depth (ftNB) Entl Date Annotation Laat Mod By Entl Date Last Tag: SLM 7,128.0 3I20I2010 Rev Reason: TAG, Pull Plug/Gauges Imoslwr 3/26/2010 Casin Strin s __-_ - String OD String 10 Set Depth Set Depth (TVD) String Wl String Caain Oeacri tlon lint tin) Top (RNB) IRKB) (RKB) p6sttt) Oretle String Top Thrd p g CONDUCTOR 16 15.062 0.0 104.0 104.0 62.50 H-00 coeoucroR. 101 SURFACE 95r8 8.765 0.0 3,176.0 3,085.5 36.00 J-55 PRODUCTION 7 6.151 0.0 7,281.0 6,294.6 26.00 J-55 Tubin Sfrin s Bhing OD String ID Sat Depth Sat DepN (rVD) String Wt String Sakry Valve, 1 811 0 Tu Ding Descriptlon tin) (in) Top (ftl(B) (RKB) (RKB) (IDSRt) Oratle String Top Thrtl TUBING 3 1/2 2.992 0.0 6,941.0 6,034.4 9.30 J-55 SRD EUE TUBING 2 7/8 2.441 6,941.0 6,965.0 6,053.2 6.50 J-55 SRD EUE 6URFACE ~ ~ Other In Hole A ll Jewel :Tubin Run 8 R etrievable, Fish, etc. , 3,176 Top Depth (TVD) Top Inc! Top (RKB) (RKB) (°) Descriptlon Comment Run Date ID Iln) 1,811 1,811.0 0.17 Safety Valve Baker'FVL' 11/24/19&5 2.812 GAS LIFT, 6 730 6,730 5,866.7 35.96 GAS LIFT MERLA/TPDXII.S!DMYlf-2l// Comment: STA 1 1/3/1991 2.875 , 6,780 5,907.3 36.66 PBR Baker PBR 11/24/1985 3.000 6,794 5,918.5 36.86 PACKER 0aker'FHL' PACKER 11/24/1985 3.000 6,832 5,948.7 37.39 INJECTION CAMCO/KBUGl1/DMY/BK-21ll Comment: STA2 2/2911996 2.875 6,938 6,032.1 38.91 NIPPLE AVA'BPL' Nipple w/ 2 7/8" XO 11124/1985 2.750 PBR, 6.780 6,938 6,032.1 38.91 SLEEVE-O AVA; BPC SLEEVE 61211999 2.310 6,946 6,038.4 38.99 PACKER Baker'FB-1' PACKER 11/24/1985 3.000 6,959 6,048.5 39.11 NIPPLE Camco'D' Nipple NO GO 11/24/1985 2250 I 6,964 6,052.4 39.16 SOS Camco 11/24/1985 2.441 6 965 6 053 2 16 39 TTL 11/24/1985 2'441 PACKER, 6,791 . , . . (- ,. Pertora tions & Slots snag roplrvD) etm IrvD) Dena Top (RKB) Btm (RKB) IRKB) (RKB) Zone Date (°h... type Comment INJECTION 6,888 6,922 5,993.1 6,019.5 C -0, G2, G1, 11/24/1985 12.0 IPERF 120 deg. phasing; 5" Csg Gun . s,e3z U NIT B, 3A-07 6,990 7,010 6,072.6 6,088.0 A -3, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasing; 2 1/8" SG 6,990 7,010 6,072.6 6,088.0 A -3, 3A-07 3/16/1986 4.0 RPERF 0 deg. phasing; Bar Kone II 7,024 7,060 6,098.8 6,126.4 A -2, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun IPERF, s fifia89zz 7,024 7,060 6,098.8 6,126.4 A -2, 3A-07 3/16!1986 4.0 RPERF 90 deg. phasing; Bar Kone II , 7,118 7,128 6,170.7 6,178.3 A -1, 3A-07 11/24/1985 4.0 IPERF 90 deg. phasing; 4" Csg Gun 7,118 7,128 6,170.7 6,178.3 A -1, 3A-07 3/16/1986 4.0 RPERF 90 deg. phasing; Bar Kone II NIPPLE,6938 6LEEVE D, 6,938 f PACKER, 6,9/6 I / 1 NIPPLE, 6,959 SOS, 6961 TTL, 6.965 IPERF, 6,99D-7 010 RPERF, 6,990-7,010 RPERF, 7 024-7 060 IPERF, 7,oz/-7.oso RPERF, 128 7 118 7 , - . IPERF, 7.118-7,128 PRODUCTION, 7,261 TD, 7 325 ConocoPhillips ~ ~2E~~I~IE~ APR (1 5' X010 ~~~c~asconsa~~®~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 3~ 07 ,,u ~ ,~ ..~ Dear Mr. Dan Searriount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLI). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, trop of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/31/10 3A, 3B, 3C, 3G, 3H, 31, 3J, 3M, 30 8< 3R PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surface n/a 26" Na 4.25 3/29/2010 3A-04 50029214330000 1852070 SF Na 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF Na 25" Na 4.25 3/29/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/29/2010 3B-10 50029213660000 1851140 6'6" n/a 6'6" n/a 25.5 3/28/2010 3C-11 50029213570000 1851020 SF Na 25" n/a 4.25 3/27/2010 3G-08 50103201280000 1900650 SF 0.65 27" 3/2/10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 3/28/2010 3H-01 50103200840000 1871100 SF n/a 21" Na 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-14B 50103200920200 2050210 SF n/a 23" n/a 3.4 3/29/2010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF Na 22" n/a 3.4 3/28/2010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3!29/2010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/29/2010 30-09 50029218250000 1880610 SF Na 23" n/a 4.25 3/27/2010 30-16A 50029217960100 1880430 SF n/a 22" n/a 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF Na 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/27/2010 ~:~- Schlumberger -DCS ~~'~ 2525 Gambell Street, Suite 400 ~ ~-~,~ Anchorage, AK 99503-2838 ~ ' ATTN: Beth ~~ Well Job # Log Description NO.4985 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11 /25/08 2V-07 12096561 INJECTION PROFILE ~ 10/31/08 1 1 3A-11 12100434 INJECTION PROFILE 10/31/08 1 1 1G-09 12100434 INJECTION PROFILE 3 v 11/01/08 1 1 2V-11 12061724 PRODUCTION PROFILE ~- ~ 11/02/08 1 1 2C-14 12096565 PRODUCTION PROFILE ~/ - 11/04/08 1 1 30-01 11975792 LDL ~j 11/05/08 1 1 3F-09 12100435 PRODUCTION PROFILE 11/06/08 1 1 2V-12 12096567 PRODUCTION PROFILE 11/06/08 1 1 3A-07 12096568 INJECTION PROFILE 11/07/08 1 1 2A-20 12100434 INJECTION PROFILE - 11/08/08 1 1 1G-17 11975792 LDL 11/09/08 1 1 2U-04 12100434 INJECTION PROFILE f. 11/10/08 1 1 2U-05 12096572 INJECTION PROFILE ~ -- 11/12/08 1 1 1 F-06 12100457 PRODUCTION PROFILE 11/13/08 1 1 iB-06 12080456 PRODUCTION PROFILE 11/13/08 1 1 1 B-05 12080457 INJECTION PROFILE (~(} 11/14/08 1 1 2U-10 12080459 PRODUCTION PROFILE - 11/16/08 1 1 2C-15 12100462 PRODUCTION PROFILE Z 11/18/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ) MEMORANDUM TO: Jim Regg 'I) oJ _ j P.I. Supervisor /<,11 11/ "10<; FROM: Jeff Jones Petroleum Inspector Well Name: KUPARUK RIV UNIT 3A-07 Insp Num: mitJJ050909121005 Rei Insp N urn Packer w;iïl"-'3A-07 ITyp~·inj. I W ! T'VD P.T.-1852230 ITypeTest I SPT I Test psi .J)lterval 4YRTST P/F P ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, September 12, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A-07 KUPARUK RIV UNIT 3A-07 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-21444-00-00 Permit Number: 185-223-0 Depth 5919 Pretest 500 Initial 3120 580 3110 580 15 Min. I IA lOA 1_.__- I Tubing I 1479.75 280 ___~~~~._J 2450 2500 Notes 2.4 BBLS diesel pumped. 1 well house inspected; no exceptions noted. Monday, September 12,2005 qÇìfì\) . _ ,..,-. (' C 'D ~~. Ú¡ t.. U l\ <- ~ct' ~~¥~~NEt ~) 1:_l (,. ". \" ~ b."¡.," t ~,r \Cb Reviewed By: P.I. Suprv ,jtÞ Comm Inspector Name: Jeff Jones Inspection Date: 8/30/2005 30 Min. 45 Min. 60 Min. I ._-j------ "--1----'----- L_.___ 3090 too 580 2500 Page I of 1 Schlumberger NO. 3231 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 0/06/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Rðcf-p3( J 1E-119 10884033 SCMT 10104/04 I crt) - t) :3 if /1 L-09 10802915 PRODUCTION PROFILE W/DEFT 07/26/04 1 /?'5- t)~1 J2V-14 10884026 PRODUCTION PROFILE W/DEFT 09/27/04 1 / 8~- I;L I 2K-02 10884027 PRODUCTION PROFILE W/DEFT 09/28/04 1 / q~ - (t/'4; 3J-17 10884031 PRODUCTION PROFILE 10/02/04 1 /~5 - 22:; . 3A-07 10884030 INJECTION PROFILE 10/01/04 1 /80 -057 J 1E-04 10884023 INJECTION PROFILE 09/24/04 1 1 E-11 10884024 INJECTION PROFILE 09/25/04 1 /?J.. - Ð5¡ J 2H 12 10884022 PRODUCTION PROFILE 09/23/04 1 !~5 - ~(p'2.. - R" -kL Kuparuk ,~ Color CD 1 ~' DATE: 1'rf f SCANNED NO\! 5 Please sign and retur 0 e copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: JulJe Heusser Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 21, 2001 THRU: Tom Maunder .- c~ FROM: John Crisp .~ '~\'t, ~> ~ =3 ~t..~, Petroleum Inspector NON..- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips Alaska 3A Pad 3A-02,04,06,07,10 GKA Kuparuk River Field wa~I P-T.D.I ~' Well i..P-T-D,~i Packer .,.Depth Pretest Initial 15 Min. .... 30 Min. 3A~ I T~pe~.j.I S I T.V.D. I '~0 I Tuan~l ~J001 2~01 2~.1 2~, I~,.te~val 4 ~~ I~"e~estl, '" I~,'~,1 ~458 Icasi"gl 27,06 1 ~° I ~2° I .~°°. I "~: I-" Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in norms) Test's Details These wells passed the Standard Annulus Pressure tests. 2 annulus pressures were high considering they were bled down the previous day. 5 MIT's no failues witnessed. M.I.T.'s performed: Attachments: Number of Failures: 0_. Total Time during tests: 3 HRS. ,.cc..'. MIT report form 5/12/00 L.G. MIT KRU 3Aa 7-21-01jc.xls 7/23/01 STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION ~ ~. REPORT OF SUNDRY WELL OPERATIONS 1. Operation performed: Operation Shutdown __ Stimulate _ Plugging __ Perforate _ Pull tubing __ Alter casing Repair well __ Pull tubing __ Other X 2. Name of Operator 5. Type of Well: 6, Datum elevation (DF or KB) Development ~ ARCO Alaska, Inc. Exploratory _ RKB 73' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service ~ ~/~ Kuparuk River Unit 4. Location of well at surface 8. Well number 623' FSL, 744' FEL, SEC 7, T12N, R9E, UM 3A-07 At top of productive interval 9. Permit number 1123' FNL, 1285' FWL, SEC 17, T12N, R9E, UM 85-223 At effective depth 10. APl number 1264' FNL, 1418' FNL, SEC 17, T12N, R9E, UM 50-029-21444 At total depth 11. Field/Pool Kuparuk River Field 1324' FNL, 1485' FWL, SEC 17, T12N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7 3 2 5' feet Plugs (measured) true vertical 6327' feet Effective depth: measured 71 91 ' feet Junk (measured) true vertical 6 2 2 5 feet Casing Length Size Cemented Measured depth True vertical depth Structural *Conductor 60' I 6" 185 SX AS II 1 04' 1 04' *Surface 3132' 9 5/8" 1000 sx AS III & 3176' 3085' intermediate 350 sx Class G *Production 7237' 7" 125 sx Healy Fly Ash +7281' 6295' Liner 300 sx Class G + 175 sx AS I Perforation depth: measured 6888-6922' 6990-7010' 7024-7060' 7811-7128' true vertical 5993-6020' 6073-6088' 6099-6126' 61 71-61 78' Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ibs/ft, J-55 EUE Tbg; Tail @ 6961'MB Packers and SSSV (type and measured depth) Baker FVL SSSV @1808'; Baker FHL Pkr @ 6791'; Baker FB-1 Pkr @ 6~B~3~[: ~~r~ !13. Stimulation or cement squeeze summaryrrk r-I~,1'-I¥ ~' """ Intervals treated (measured) JAN 2 ]99]. Treatment description including volumes used and final pressure '. 14.Representative D~,il¥ Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (producing) 937 1123 0 720 1 62 Subsequent to operation (injectincj) -" - 3400 480 2000 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Water Injector Daily Report of Well Operations ~, Oil _ Gas Suspended __ Service 17. I herE~,, certify that the foregoing is true and correct to the best of my knowledge. Signed '1 . Title Senior Operations Engineer Date I-/~ '"~(' Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE .ARCO Alaska, Inc - Subsidiary of Atlamic Richfield Company WELL IPBDT SA- ? I . '~TRACTOR REMARKS WELL SERVICE REPORT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME IDAYS [--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather J TemP.Report 'F ] Chill Factor [ VislbllitY, F miles; Wind Vel. knots J Signed ARCO Alaska, In~.c. {) .. Su~. l~idl~y of Atl~ntlc Riclffteld Cot/'" O CONT~CTOR REMARKS WELL SERVICE REPOR' tFIELD - DISTRICT. STATE DAYS OPERATION AT REPORT TIME · J""J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weathm'Report ITsmp' 'F F miles r STATE OFAI.ASKA ~-' 0 J~ ! ,':.~ i' !!~I ~ ~ ~ OIL/~ID GAS CI~$ERVATION COMMIbo~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other ~X 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 623' FSL, 744' FEL, SEC 7, T12N, R9E, UM At top of productive interval 1123' FNL, 1285' FWL, SEC 17, T12N, R9E, UM At effective depth 1264' FNL, 1418' FNL, SEC 17, T12N, R9E, UM At total depth 1324' FNL, 1485' FWL, SEC 17, T12N, R9E, UM 12. Present well condition summary Total Depth: RKE~ 7. Unit or Property name Kuparuk River Unit 7;~' fee~ 8. Well number 3A-07 9. Permit number 85-223 10. APl number 50-029-21444 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool measured 7325' feet true vertical 6327' feet Plugs (measured) Effective depth: measured 71 91 ' feet true vertical 6 225 feet Junk (measured) Casing Length Size Structural *Conductor 6 0' 1 6" *Surface 3132' 9 5/8" Intermediate *Production 7237' 7" Liner Cemented Measured depth 185 sx AS II 1 0 4' 1000 sx AS III & 31 76' 350 sx Class G 125 sx Healy Fly Ash +7281' 300 sx Class G + 175 sx AS I Perforation depth: measured 6888-6922' 6990-7010' 7024-7060' true vertical 5993-6020' 6073-6088' 6099-6126' Tubing (size, grade, and measured depth) 3 1/2", 9.3 lbs/fi, J-55 EUE Tbg; Tail @ 6961'MB Packers and SSSV (type and measured depth) 7811-7128' 6171-6178' True vertical depth 104' 3085' 6295' REEEIVED DEC 1 1 1990 Alaska 0fl & Gas Cons. mch'oraget Baker FVL SSSV @1808'; Baker FHL Pkr @ 6791'; Baker FB-1 Pkr @ 6943' 13. Attachments Description summary of proposal .X_.. Convert to Water Injection Detailed operation program BOP sketch X.~ 14. Estimated date for commencing operation 12/12/90 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY '" Conditions of approval: Plug integrity _ BOP Test Mechanical Integrity Test '~ Notify Commission so representative may witness Location clearance Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Form 10-403 Rev 09/12/90 Commissioner IApproval_LNo. ~.~ . SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kuparuk River Unit Well 3A-07 Conversion to Water Injection Service Well 3A-07 is currently an oil producer. This Application for Sundry Approval is for converting this well to water injection service. A Wireline BOP will be used during the portions of the conversion procedure which require wireline work. Expected static bottom-hole pressure is 2700 psi. No workover fluid will be used during the conversion procedure. An MIT will be performed prior to conversion as required; upon completion, the MIT form will be forwarded to the State. RECEIVED DEC 1 1 1990 Alaska 0il & Gas Cons. C;omm~sSior~ Anchorage 3 I II .- i! ~ I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRE:LINE: RAMS (VARIABLE SIZE:) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF RECEIVED DEC 1 1 199~ Alaska Oil .& Gas Cons. Comm~ss~o~ Anchorage Id l REL I NE BOP EQU l PHENT ii i i ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 9951070360 Telephone 907 276 12i5 December 6, 1990 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached are a number of Applications for Sundry Approvals and Reports of Sundry Well Operations on the following Kuparuk wells. Applications for Well 3A-07 3Q-02 Sundry Approvals Reouest Conversion Conversion Anticipated Start Date Dec. 12, 1990 January, 1991 Reports of Sundry Well Operations Well. Operation 1 B - 0 4 Conversion 1 B- 0 6 Perforate A Sand 1 B - 0 7 Conversion 1 B - 0 8 Conversion 1 B - 0 9 Conversion 1 B - 0 9 Perforate C1 Sand 1 B- 1 0 Conversion 1 B- 1 I Conversion 1 B-1 1 Perforate C1 Sand 2 B - 1 3 Repair Tubing 2 B - 1 3 Refrac A Sand 2 H- 1 2 Repair Tubing 2 H - 1 2 Refrac A Sand If you have any questions, please call me at 263-4123. Sincerely, /y , R. W. Chivvis Operations Engineer RECEIVED DEC 1 1 1990 Alaska 0il & Gas Go~s. uut~missiO~ Anchorage ARCO Alaska, Inc. is a Subsidiary of At!anticRichfieldCompany ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL ACTION 3A-07 Stimulate If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlaniicRichfieidCompany STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing __ Alter casing Repair well Pull tubing __ Other 2. Name of Operator ARCO Alaska. Ins. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 623' FSL, 744' FEL, SEC 7, T12N, R9E, UM At top of productive interval 1123' FNL, 1285' FWL, SEC 17, T12N, R9E, UM At effective depth 1264' FNL, 1418' FNL, SEC 17, T12N, R9E, UM At total depth 1324' FNL, 1485' FWL, SEC 17, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 6. Datum elevation (DF or KB) feet Plugs (measured) feet Junk (measured) RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-07 7~' feet 9. Permit number 85-223/~-~ ~- · - 10. APl number 50-029-21444 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 7325' true vertical 6327' Effective depth: measured 71 91 ' feet true vertical 6 2 2 5 feet Casing Length Size Cemented Measured depth Structural *Conductor 60' I 6" 185 SX AS II 1 04' *Surface 3132' 9 5/8" 1000 sx AS III & 3176' Intermediate 350 sx Class G *Production 7237' 7" 125 sx Healy Fly Ash +7281' 6295' Liner 300 SX Class G + 175 s× AS I True vertical depth 104' 3085' 13. Perforation depth: measured 6888-6922' 6990-7010' 7024-7060' true vertical 5993-6020' 6073-6088' 6099-61 26' Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ibs/ft, J-55 EUE Tbg; Tail @ 6961'MB 7811-7128' 6171-6178' iZEC iVED Packers and SSSV (type and measured depth) Baker FVL SSSV @1808'; Baker FHL Pkr @ 6791'; Baker FB-1 Pkr ~ 6943; Stimulation or cement squeeze summary : ~-:-J~] U~! .& L~S (.L,,[~, ~ .... Intervals treated (measured) 6990'-7128' Treatment description including volumes used and final pressure 372 bbls cjelled water; 32,000 lbs 16/20 Carbo-Lite; final pressure = 3649 psi. 14.Representative Daily Average Production or Injection Data Prior to well operation (producing) Subsequent to operation (producing) 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 507 320 5 g00 146 1214 1480 5 570 154 16. Status of well classification as: Water Injector Oil x Gas Suspended Service 17. I her,~/~,~,~y~at thel;, f~e,~.~n(,.foe, going is true and correct to the best of my knowledge. Si~ned Ir f.///~ '",,,,2 · f,,,,~4'~ Title Senior Operations Engineer Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE 'ARCO Alaska, Inc. O · Subsidiary of Atlantic Richfield Company WELL IPBDT .~iTRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT - STATE /~ c/ OPERATION AT REPOR.~T,TIME //3o t/o o [] CHECK'THIS BLOCK IF SUMMARY CONTINUED ON BACK knot, ~. /~'-_ . ~. ~. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 April 19, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 3A-07 Stimulate April, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 REt EIVED APR 2 5 1990 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlaniicRichfJe!dCon~pany STATE OF ALASKA ~ OIL/~JXlD ~ CO~$ERV^TION COMi~,,oSIO~ APPLICATION FOR SUNDRY APPROVALS 1. TYpe of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 623' FSL, 744' FEL, SEC 7, T12N, RgE, UM At top of productive interval 1123' FNL, 1285' FWL, SEC 17, T12N, R9E, UM At effective depth At total depth 1324' FNL, 1485' FWL, SEC 17, T12N, RgE, UM 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) RKB 73' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-07 9. Permit number 85-;~23 10. APl number 50-029-21444 11. Field/Pool Kuparuk River Field Kuparuk_~iv__or_Qil .~o~ ~ 12. Present well condition summary Total Depth: measured true vertical Effective depth: Casing Structural *Conductor *Surface Intermediate *Production Liner 7325' feet Plugs (measured) 6327' feet measured 7191' true vertical 6225' Length Size 60' 1 6" 185 sx AS II 104' 104' 3132' 9 5/8" 1000 sx AS III & 31 76' 3085' 350 sx Class G 7237' 7" 125 sx Healy Fly Ash + 7281' 6295' 300 sx Class G + 175 sx AS I feet Junk (measured) feet Cemented APR 5 1991) Alarm 011 & Gas Cons, Measured depth A~al depth Perforation depth: measured 6888-6922', 6990-7010', 7024-7060', 7811-7128' true vertical 5993-6020', 6073-6088' 6099-6126 ' 61 71-6178' Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, EUE TBG, Tail @ 6962' Packers and SSSV (type and measured depth) Baker FHL Packer @ 6791', Baker FB-1 Packer @ 6943', Baker FVL SSSV @ 1808' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch Re-fracture Treatment of A SD 14. 16. Estimated date for commencing operation If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~; Gas t Service Suspended 17. I herel~y, certify th~at the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ORLY Conditions of approval: Notify Commission so representative may witness Plug integrity t BOP Test_ Location clearance m Mechanical Integrity Test~ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH IApproval /~,..prOVed O°P~J Commissioner Date WELL 3A-07 GW FRAC DATA TABLE I ' STAGE CLEAN voLUME PROPpANT b~RTY vOLUME CUMULATIVE STAGE HITS . (BBL). (POUNDS) . (BBL) , DIRTY V0.L.(BBL) PERES @ (BBL) BREAKDOWN 120 '" 0 120 120' ' 61 ..... SD FOR ISIP, PROVE FLOWMETER. I. PAD 210 0 2'10 330 "' 181 , , , SLURRY '" 2PPG 18 1544 .... 20 350 .... 39'1' ......... 4 PPG 21 3570 25 375 411 6 PPG 24 5979 30 405 436 8PPG 30 9936 40 445 466 .... 10PPG 21 8745 30 475 506 ....... 12 PPG 7 3296 1 0 485 536 ,, , FLU..O~ 59 .... 0 59 544 ' '- ........ TOTAL 51 0 33070 544 , ,, ,, VOLUME TO PERFS (UAL) = 61.3 ...... I PROPPANT = 16/20M CARBOLITE or LwP" , , ,, , 'PuMP RATE = 20 BPM BREAKDOWN = GW + 40 PPT Silica Flour + 8 Hour Breaker , 'l cUt XL during last,part (flush) of aD stage , PAD = GW + 40 PPT Silica Flour + 8 Hour Breaker SLURRy = GW + 8 Hour Breaker (no Silica,Flour) · FLUSH = Slick Diesel Low Temp Breaker during last half of flush Estimated Surface,Treating Pressure . .--. 4100 psi (includes exces, s perf friction) KDR 4/16/90 3A-07 Refrac SUndry Attachment 4/18/90 xOp upar~k ~ell ~ ,~ ~and inter~,~-u7 is sc~ . . r~over ~,.:7~' A pum~'~m, ea for a ~ ~ ected ~_-~us Will b~ ~ acnedule r~.~tracture t ~ '~Servoir ~ ~ require~ ~ '~ the i~ , reat~nt ~ ~cSSure ~_ . ~ tot ~:_ ~ is at,~- . °f the · or the ~ ~_.ms stim,~.. ~ac~e~. ~ ~'O/ ~e~ . u~O0D .__ ~ ~ "~s 2600 Psi. treatment. RE£EIV E',D APR 2,5 1990 011 a 6a~ Cons. ComPri Anchorage ARCO Alaska, Inc. Date: June 30, 1989 Transmittal #: 7501 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmiltal. 3 C- 0 5 Kuparuk Well Pressure Report 4 - 2 3 - 8 9 Sand 'A' 3 C- 1 2 Kuparuk Well Pressure Report 4 - 2 3 - 8 9 Sand 'A' 3C..-05 Sub-Surface Pressure Survey 4 - 2 3 - 8 9 # 6 3 9 4 0 3 C- 1 2 Sub-Surface Pressure Survey 4 - 2 3 - 8 9 # 5 8 2 3 1 3 A- 01 Kuparuk Fluid Level Report 6 - 2 7 - 8 9 Tubing 3A-07 Kuparuk Fluid Level Reporl 6-27-89 Tubing Receipt Acknowledged. .. ........................... Date' AlaSka Oil & Gas Oons. Commission ....... .A.n.rtj.orage .DISTRIBUTION: _ BP Chevron Uncoal Mobil Slale of Alaska D&M GLM DV o~ GLV i KUPARUK FLUID LEVEL REPORT W~ ~'A-0'3. Fluid Level Shot Down: Cuing x' Tubing CSG P~e~e During Shot TBG Prell Outing Shot Reason For Shooting FL: . .. To Determine OI3erlting Valve x/ . S,~,~f~ 13¢.~(~,....,~a,.~,,o .... £,~ '/~ ., ,~,: Well Stat~l: On Continu~ GL Oiling CSG Prm. GL R~te (If Avel~e). On Intermittent GL On Time.., Min. Off Time = Hr. Min. _ Delta Time From Encl Of On Cycle- , Commentl: Min. RECEIVED L - -~ ]S89 Gas Cons. /~,nehorage ARCO Alaska, Inc. Date: March 7, 1989 Transmittal #: 7438 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 A- 0 7 Kuparuk Well Pressure Report 8 - 2 9 / 3 0 - 8 6 Sand 'A' 3 A- 0 7 NL Sperry Pressure Build Up 3-03-86 #AK-MS-60022 Receipt Acknowledged: Alaska 0il & Gas Cons. Commissi0rl ~ Anchorage ~ ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron I/- ~/--7-,- ~Z. STATE 'OF ALASKA '"" ALASK~.OIL AND GAS CONSERVATION L,,JMMISSION WELL COMI L,I:TION OR RI:COMPLETION REPORT AND Leo 1. Status of Well Classification of Service Well REV I SED OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, i nc. 85-223 3. Address ' 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 ~ 50- 029-2144/+ 4. Location of well at surface 9. Unit or Lease Name 623' FSL, 774' FEL, Sec.7, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1123' FNL, 1285' FWL, Sec.17, T12N, R9E, UM 3A-7 At Total Depth 11. Field and Pool 1324' FNL, 1485' FWL, Sec.17, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/20/85 10/24/85 10/25/85'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7325'MD,G327'TVD 7191 'MD,6225'TVD YES~ NO [] 1811 feet MD 1550' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 10/+' 2/+" 185 sx AS II 9-5/8" 36.0# J-55 Surf 3176' 12-1/4" 1000 sx AS III & 350 sx Class G 7" 26.0# J-55 Surf 7281' 8-1/2" 125 sx Healy Fly ash, 31)0 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) 7024' - 7060' w/4 spf, 90° phasing 3-1/2" 6965' 6794' & 6946' 7118' - 7128' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6922' - 6888' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Addendum attac led to Wel 1 Completion Repot ;, dated 3/31/86. 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Al~Sk~ Oil & Gas Oons. oommisstor~ * NOTE: Tubing was run and the well perforated 11/2/+/85. Form 10-407 Rev. 7-1-80 GRU1/WC06 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKER~5 MEAS. DEPTH TRUE VERT. DEPTH 30. FtJRMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. I . Top Kuparuk C Base Kuparuk C Top Kupauruk A Base Kuparuk A 6884' 6922' 6973' 7131' 31. LISTOF ATTACHMENTS None 5989'' 6019' 6059' 6180' N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS GeneraI' 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 I.njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska. In,,. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 . RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: lA-7 lA-14 1H-4 1H-8 1H-$ lQ-9 lQ-13 2C-16 2E-9 2E-15 2E-16 2H-10 3A-7 3A-11 3A-12 3A-13 3A-14 3C-13 3F-5 3F-6 3F-9 3J-5 12-03.85 Run #3 7585-8532 · 12-05-G5 Run #1 4550-4850 12-26-85 Run #2 6893-7466 12-08-86 Run #3 7875-8368 12-09-86 Run #4 7850-8450 01.-28-85 Run #1 4898-6534 06-02-85 Run #1 5300-7621 02-19-85 Run #1 7200-8294 01-14-85- Run #1 6780-8052 01-12-85 Run #1 3350-6874 01-12-85 Run #1 4840-7578 12-05-85 Run #1 6500-7863 11-04-85 Run #1 5726-7164 12-15-85 Run #1 5796-7206 12-16-85 Run #1 6426-7768 12-29-85 Run #2 5644-7482 12-29-85 Run #2 5462-7744 10-30-85 Run #1 7075-9474 11-13-85 Run #1 6947-8647 11-13-85 Run #1 4600-7570 12-19-85 Run #1 6188-7490 12-22-85 Run #1 7000-8636 DATE 09-15-86 TRANSMITTAL ~ 5761 Please acknowledge receipt and One * of each Receipt Acknowledged: S~o' ' o~ AK*b 1/~~ Vault*films ~~ NSK Files*bl ARCO Alalkl, Inc. mt a Subsidiary of AllanticRichliel~lComplny STATE OF ALASKA '--' ALASF... OIL AND GAS CONSERVATION COMN.._,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other [] Stimulate [] Plugging [] Perforate~ Pull tubing [] . 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, ]:nc RKB 73' 6. Unit or Property name 3./~d(~lr~ 100360, Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 623' FSL, 774' FEL, Sec. 7 T12N R9E UN At top of productive interval ' ' ' 7. Well number 3A-7 8. Approval number Permit #85-223 1123' FNL, 1285' FWL, Sec. 17, T12N, R9E, UM At effective depth 1251' FNL, 1414' FWL, Sec. 17, T12N, R9E, UM At total depth 1324' FNL, 1485' FNL~ Sec. 17, T12N, R9E, UM 11. Present well condition summary Total depth: measured 7325 feet true vertical 6327 feet 9. APl number 50-- 0_e9-2!444 10. Pool KuDaruk River Oil Pool PlUgs (measured)None Effective depth: measured 6168 feet true vertical 6209 feet Casing Structural Conductor 80' Surface 3145 ' XXXl~'~~e Production 7250' xxx~<xxxx Perforation depth: measured Junk._._,(measured) None ,. Length Size Cemented_ Measured depth True Vertical depth true vertical 5993'-6019' TVD; 6072' 6088' TVD; 6098'-6126' TVD 16" 185 SX 'ASII 104' MD 104' TVD 9 5/8" 1000 SX ASIII 3084' MD 3012' TVD 340 SX Class G 7" 125 SX Healy 7281' MD 6295'.""TVD Fly Ash & 300 S~' Class G 6888'-6922' MD; 6990'-7¢10' MD; 7024'-7060' MD; 7118'-7128' MD _ -;.~ 6170'-6178' Feet 'riD Tubing (size, grade and measured depth) 3½", ,]-55 with tail set @ 6965' .V EH 12. Stimulation or cement squeeze summary N/^ Intervals treated (measured) AUG 1'8 ]986 13. Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission /~nnhor~ge Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 55 22 0 550 430 136 54 0 780.~/' 4.75 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ .~ ...- (~(¢'-~/¢ Form 10-404 Rev.¢/12-1-85 Title Sr. Operations Engineer Date , Submit in Duplicate ADDENDUM STATE OF ALASKA AOGCC REPORT OF SUNDRY WELL OPERATIONS KUPARUK RIVER UNIT WELL NO. 3A-7 3/16/86 RU Dresser. Pr test BOP and lubricator. Open well to tanks. Perf 6090' - 7010' (MD-RKB), 4 SPF with 2-1/8" through tubing guns. POOH. All shots fired. RDS'pg-O042 REC . JVED Alaska Oil & Gas Cons. ,r '~ STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION COry, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator -' 7. Permit Number ARCO Alaska, Inc, 85-223 3. Address 8. APl Number 029-21444 P. 0. Box 100360, Anchorage, AK 99510 S0- 4. Location of well at surface 9. Unit or Lease Name 623' FSL, 774' FEL, Sec.7, T12N, R9E, UM Kuparuk River Unit 10. Well Number At Top Producing Interval 1123' FNL, 1285' FWL, Sec.17, T12N, R9E, UM 3A-7 At Total Depth 11. Field and Pool 1324' FNL, 1485' FWL, Sec.17, T12N, R9E, UM Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/20/85 10/24/85 10/25/85* N/A feet MS L 1 I 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7325 'MD ,6327 'TVD 7191 'MD,6225'TVD YES [~(X NO [] 1811 feet MD 1550' (Approx) I 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 5urf 10~,' 2~,'' 185 sx A5 II 9-5/8" 36.0# J-55 Surf 3176' 12-1/4" 1000 sx AS Ill & 350 sx Class G 7" 26.0# J-55 Surf 7281' 8-1/2" 125 sx Healy Fly ash 8 300 sx Class G . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7024' - 7060' w/4 spf, 90° phasing 3-1/2" 6965' 6794' & 6946' 7118' - 7128' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6922' - 6888' w/12 spf, 120° phasing DEPTH INTERVAL(MD) AMOUNT& KIND OFMATERIALUSED See attached Add,;ndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE e 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVI D APRO 1986 Form 10-407 "~ NOTE: Tubing was run and the wel 1 perforated 11/24/85. GRU1/WC06 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kupauruk A Base Kuparuk A · . GEOLOGIC MARKERS M EAS. DEPTH 6884' 6922' 6973' 7131' TRUE VERT. DEPTH 5989' 6019' 6059' 6180' 30. FORMATION TESTS Incluc~e interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 7[0 ~ Associate Engineer Signed ~ ~ Title Date INSTRUCTIONS General' This form is designed fOr submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection fOr in-situ combustion. Item 5: Indicate which elevation is used as reference (where not' otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data .pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23': Attached supplemental records for this well should show the details of any multiple stage cement- 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 Injectio, n, Shut-in, Other-explain: , .' .....: - Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/05/85 12/16/85 3A-7 Rn CET log f/7191'-5726'. Rn GCT gyro f/7120'-surf. Frac well w/total of 226 bbls diesel, 504# 100 mesh & 3700# 20/40 sand @ avg rate of 5 BPM, 3030 psi. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 5, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, A1 aska 99501 Dear Mr. Chatterton: Attached in triplicate are intent notices on the following Kuparuk River Field: Well Action Anticipated Start Date 3A-7 Perforate March 7, 1986 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS: pg: 0013 Attachment cc: File KOE1.4-9 well RECEIVED 0 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of Well SURFACE LOCATION: 623' FSL, 774' FEL, SEC. 7, T12N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 73' (RKB) 12. 7. Permit No. 85-223 8. APl Number 50- 029-21~.qq 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 3A-7 1 1. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RIVER 0IL POOL ADL 25632, ALK 2565 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" Sand be perforated for production. Procedures call for the well to be perforatec thrmgh tubing ~th 4 SPF. Proposed Interval (MD)' 6990- 7010 ANTICIPATED START DATE- March 7, 1986 RECEIVED MAR 0 5 1986 Alaska Oil & Gas Cons. commission Anchorage 14. I hereby certify that the fore,~oing is true and correct to the best of my knowledge. Signed E~./~_.. , Title Kuparuk The spa(~e below f(~Commission use - Sr. Operations Engr. Conditions of Approval, if any: AF )rovec~ Cc~py Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Be,.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-7 Dear Mr. Chatterton' Enclosed is a copy of the 3A-7 Well History to include with the Well Completion Report, dated 1/27/86. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L99 Enclosure cc' 3A-7 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday afte; a well Js spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District ~County, parish or borough Alaska I! North Slope Borough Field Lease or Unit Kuparuk River ADL 25632 Auth. or W.O. no. JTitle AFE AK0308 I Drill Parker 141 API 50-029-21444 State Alaska IWell no. 3A-7 Operator ARCO Alaska, Inc. Spudded 10/20/85 0245 hrs. Date and depth as of 8:00 a.m. lO/19/85 thru 10/21/85.. 10/22/85 10/23/85 10/24/85 Complete record for each day reported IARCO W.I. Prior status if a W.O. 16" @ 104' 2554' (2450'), Web & rm to btm Wt. 9.1, PV 10, YP 10, PH 9.0, WL 20.2, Sol 5.8 Move f/3A-6. Accept ri~ @ 2200 hrs, 10-19-85. NU diverter sys. Spud @ 0245 hfs, 10-20-85. Drl to 1928', DD to 2554', POOH, LD DD. PU BHA, TI~ to 1897', wsh & rm to btm. 2057', 5.3~, S34E, 2056 TVD, 5.72 VS, S4.87, E3.28 2463', 16.8~, S40.4E, 2454 TVD, 84.48 VS, S66.59, E53.46 9-5/8" @ 3176' 3197' (643'), Tst BOPE Wt. 9.5, PV 16, YP 12, PH 9.0, WL 17.4, Sol 8.8 Drl 12¼" hole to 3197', C&C, short trip, POM. RU & rn 80 Jts, 9-5/8", 36#, J-55 HF/ERW csg w/FS @ 3176', FC @ 3091'. Cmt w/1000 sx AS III lead & 350 ax cl g. tail. Good rtns thru out job. ND diverter sys. NU &tst BOPE. 2609', 18.8°, S48.5E, 2593.25 TVD, 129.02 VS, 98.42S, 84.69E 3045', 36.1°, S46.5E, 2979.54 TVD, 327.66 VS, 233.70S, 230.13E 9-5/8" @ 3176' 5900' (0'), Turbine drlg Wt. 9.5, PV 7, YP 5, PM 10, WL 12.6, Sol 9.2 Tst BOPE, RIM, tag FC @ 3091', tst csg to 1500 psi. DO cmt & flt equip. Conduct leakoff tst to 12.5 ppg EMW. Turbine drl to 5900'. 3272', 41.4°, S46.4E, 3156.51TVD, 469.68 VS, 331.00S, 333.07E 3950', 40°, S50E, 3670.62 TVD, 911.13 VS, 635.16S, 653.58E 4900', 36°, S52.2E, 4418.93 TVD, 1494.71VS, 1003.10S, 1108.29E 5765', 40.1°, S47.9E, 5107.26 TVD, 2017.56 VS, 1341.49S, 1507.57E 9-5/8" @ 3176' 7250' (1350'), TOM Wt. 10.0+, PV 9, YP 5, PM 9.0, WL 9.4, Sol 13 Turbo drl to 6811'. POOH, chg BHA, drl to 7350'. Short trip 10 stds. Wash & ream to btm. POOH to log. 6200', 39.8~, S48.7E, 5440 TVD, 2296 VS, S1527.30, 1716.12E 7014', 38.5~, S42.3E, 6076 TVD, 2803 VS, S1856.90, 2101.55E 7275', 43~, S43.6E, 6274 TVD, 2973 VS, S1981.63, 2217.60E 9-5/8" @ 3176' 7325' (75'), Rn'g 7" csg -Wt. 10.0, PV 12, YP 11, PM 9.0, WL 7.8, Sol 12 RU Schl, log DIL/SFL/SP/GR f/7248'-3176', FDC/CNL f/7248'-6650' & 5300'-4750', CAL f/7248'-4350'. TIH, circ hi-vis sweep, 10 std short trip, TOH, LD DP. RU & begin rn'g 7". 56.24% The above is correct Signature For form preparation and diatri~ion, see Procedures Manual, Section'10, Drilling, Pages 86 and 87. JOate [ Title Drilling Superintendent ,RCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Dislrict Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0308 Parker 141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 10/26/85 thru 10/28/85 ICounty or Parish Lease or Unit Title North Slope Borough ADL 25632 Drill API 50-0029-21444 IA.R.Co. W.I. 56.24% JDate 10/20/85 Accounting cost center code State Alaska Complete record for each day reported JWell no. 3A-7 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 0245 hrs. I 9-5/8" @ 3176' 7325' TD, 7191' PBTD, RR 10.0 ppg NaC1/NaBr Rn 168 its, 7", 26#, J-55 HF/ERW cs W/FS @ 72'81' FS @ 7191'. Cmt w/125 sx 50/50 Healy Flyash w]8% D-20, .5% D-65, .5% D-112 & .2% D-46, followed by 300 sx Cl "G" w/3% KC1, .8% D-127, .25% D-13 & .2% D-46. Displ w/10.0 ppg brine, bump plug. CIP @ 1330 hrs, 10/25/85. ND BOPE, NU & tst wellhead. RR @ 1830 hfs, 10/25/85. Old TD Released rig 1830 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowin§ Potential test data New TD J PB Depth 7325' TD (10/24/85) 7191' PBTD IDate I Kind of rig 10/25/85 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 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 Signature,~-----~[ ~,,_,,~_~_~, j r Date ITitle For form preparation a-nd d;tril~utdn7 -- -- see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 27, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT. 3A-7 Dear Mr. Chatterton. Enclosed are the Well Completion Report and gyroscopic survey for 3A-7. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L31 Enclosures RECEIVED JAN ! Oil & Gas Cons. Cor~missior~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA t _ AND GAS CONSERVATION CC '~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-223 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21444 4. Location of well at surface N [~ L ~ ! V ~-. U 9. Unit or Lease Name 623' FSL, 774' FEL, 5ec.7' T12N, RgE, UN Kuparuk River Unit At Top Producing Interval ~ '~[ 3 ~ ~9~ 10. Well Number 1123' FNL, 1285' FWL, Sec.17, T12N, RgE, UN - - 3A-7 At Total Depth 1324' FNL, 1485' FWL, Sec.17, T12N, R9E, UN Alaska 0i~ & Gas Cons. C0r,qmissi0~ ll. Field and Pool &nnhoraoe Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation an~ ~-r-iai N~. Kuparuk River 0i 1 Pool 73' RKBI ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/20/85 1 0/24/85 10/25/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7325 'MD ,6327 'TVD 7191 'MD,6225'TVD YES I-~X NO []I 1811 feet MD 1550' (Approx) 22. Type Electric or Other LOgs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL/Gauge ring, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 185 sx AS II 9-5/8" 36.0# J-55 Surf 3176' 12-1/4" 1000 sx AS Ill & 350 s:. Class G 7" 26.0# J-55 Surf 7281' 8-1/2" 125 sx Healy Fly ash & 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7024' - 7060' w/4 spf, 90° phasing 3-1/2" 6965' 6794' & 6946' 7118' - 7128' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6922' - 6888' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~ 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 Form 10~07 * NOTE: TUbing was run and the well perforated 11/24/85. TEMP3/WC55 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. " . ~ , : . G'~:OLO"GICMARKERS : ' ' ~ ' ':"FoRMATION' TESTS ' NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6884' 5989' N/A Base Kuparuk C 6922' 6019' Top Kupauruk A 6973' 6059' Base Kuparuk A 7131' 6180' 31. /IST OF ATTACHMENTS Well History {completion details)~ ^ddendum (dated 12/11/85), Gyroscopic Survey {2 copies) 32. I hereby certify that the fore§oing is true and correct to the best of my knowledge Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).- Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation:' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District JCounty er Parish I Alaska Field ~Lease or Unit I KuparUk River Auth. or W.O. no. ~Title I AFE AK0308 Nordic 1 North Slope Borough ADL 25632 IAccountlng Slate cost center code Alaska IWell no. 3A-7 Completion AP1 50-029-21444 Operator Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% IDate 11/23/85 Complete record for each day reported 11/23/85 thru 11/24/85 Iotal number of wells (active or inactive) on this i DSt center prior to plugging and bandonment of this well our I Prior status if a W.O, I 0745 hrs. 7" @ 7281' 7191' PBTD, Ri{ Diesel Accept rig @ 0745 hrs, 11/23/85. ND tree. NU BOPE & tested. RU Schl, perf w/4" gun, 4 SPF f/7045'-7060', 7118'-7128', 7030'-7045', 7024'-7030'. Perf w/5" gun, 12 SPF f/6908'-6922' & 6888'-6908'. Make 6-1/8" gage ring & JB rn. RU, rn & lnd 3½" CA W/tail @ 6965' (no other compl detail reported). ND BOPE, NU &tst tree. Displ well to diesel. Set BPV. RR @ 1115 hrs, 11/24/85. RECEIVED Alaska Oil & Gas Cons. Commission Ant,borage Old TO 7191' PBTD Released rig 1115 hrs. Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data INew TD Date I PB Depth IKind of rig 11/24/85 I JType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands IWell 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 Signature I Date / ] Title _/~-"~~ I/~"/zT///F'~'' I Drilling Superintendent For form preparation af~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 11/05/85 3A-7 Rn CET log f/7191'-5726' Rn GCT gyro f/7120'-surf. Alaska 0i~ & Gas Cons. Comm~ss~O~ Drillin~ Superintendent Date 8UB. SURIIA DIRECTIONAL SURVEY r-~'l UIDANCE ~]ONTINUOUS [~OOL ARCO ALASKA INCORPORATED Company - 3A-7 (623' FSL, 774' FEL, S7, T12N, R9E, UM) Well Name ....... . KUPARUK, NORTH SLOPE, ALASKA Fleld/L~atlon - I I ~ Job ,Ref, erlncl No~. 71099 Loaaed HALFACRE 19-DECEMBER-85 Comput~ BOLAM ]~'T DIR-CT!]NAL SURVEY "ijST3M~E LISTING ALASKA, INC. 3A-7 KUP~RJK NO,2TH ~LOPE,ALASKA SURV;¥ DAT$: O~-NOV-B5 HALF,ACRE T92L LSCATiDN: TANSENT!:L- £NT£RPJ~ATI31'~: L~N~AR V~RTiC~L 3 .... "TI3N: 12R~:. CIST, DEVIATION AND P~J=CT~D ONTO A TARGET AZIMUTH AZIMUTH OF S3UTH ~7 9 MIN EAST 3,3 ALASK.&, Z~iC. -7 ~TH SLOPE,ALASKA iNTT-RPOLATED VALUES ~OR TRUE SUB-SEA SURED VERTICAL V=RTZCAL EPTH DEPTH DEPTH O.OO 0.00 -73.00 00.00 100.00 27.00 00.00 200.00 127,00 00,00 300,JO 227,00 O0.O0 400.00 327.00 00.00 500.00 427.00 00.03 599.99 O0.O0 699.99 625,99 00,00 799.99 725,99 00.00 599,99 ~25.99 O0.O0 999.9`) 925.99 00.09 1099.99 1025,99 00.00 1199.99 1125,99 00.00 1299.99 1225.9~ 00.00 1399.99 1325.99 00.00 1499,99 1425.99 00.00 15~9.99 1525.99 00.00 1699.')9 1525.99 00.00 1799.99 172~.99 00.00 1899.~9 1825.~9 00.00 1999.95 192S.95 O0.O0 2099.el 2025.5! 00.09 2195.52 2125.62 O0.O0 2296.82 2223.:~2 O0.OO 2393.9~ 2320.9~ 00.00 2~89.75 241~.75 30.OO ZEBE.0O 2512.00 JO.OO 2579.i0 2505,10 00.00 2771.12 269~.12 00.00 2860.26 27d7.20 00.00 2945.59 2372.59 O0.OO 3026.5~ 2953.5'~ 00.00 3105.15 3030.15 00.00 317.3.53 3105. 53 00.00 3254.i~ 3151. 00.00 332`).91 3255.91 00.00 3~05.33 3332.'~3 00.00 3~31.98 00.30 3558.19 3455.19 00.00 3634.57 356i.57 ~ATE: 19-3EC-85 =VEN 100 ~EET OF MEASURE COURS~ V=qTICAL DOGL6,3 RECTAN DEVI~TIDN AZIMJTd S~CTION SEVERITY NORTH/ DEG'~':'IN 5EG MIN :FEET DES/100 FEE 0.00 0.00 O.OB 0,50 -0,14 0.35 -0.59 0.09 -0.95 0.10 -1.05 0.20 -0.99 0.13 -0.93 0.12 -1.05 0.18 -1.24 0.07 0 0 N. 0 0 0 20 S ,3 31 0 19 N S; 21 0 16 N 5313 0 8 N 32 12 0 2 S 71 14 0 !2 S 46 10 0 12 S 55 7 0 12 N S5 29 W -1.54 0,07 W -1,77 0,21 W -1,81 0,08 4 -1.84 0.30 w -2.16 0.43 W -2.31 O.OB ,4 -2.45 0.0~. ',,..; -2.53 O.lO ~' -2,51 0.23 W -2.S1 0,57 PAGE DATE OF SURVEY: 04-N]V-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE DEPTH GULAR COCROIN&TES SOOTH EAST/NEST T FEET 1 73.00 FT 33 36 S 47 33 39 5 S ~7 12 ~1 3 S ~7 7 40 5.5 S 47 35 40 43 S ~ 21 40 !8 S 42 42 40 20 S 45 17 *0 20 S 4~ 4~ ~0 1 S 5g 7 0.00 N 0,00 E 0.23 S 0'.15 W 0.54 S 0.6'~ W 0.38 S 1.15 W 0.15 S 1.43 W 0.06 S 1.49 W 0.19 S 1.53 W 0,46 S 1,70 W 0.65 S 2.03 W 0.74 S 2,37 N 0.63 S 2.69 W 0.41 S 2.80 W 0.40 S 2.83 W 0.53 S 3.01 W 0,40 S 3.31 W 0.19 S 3.34 W 0,16 S 3.49 W 0.25 S 3.58 W 0,40 S 3,,)2 N 0.38 S 4,18 .W -0.94 3.81 1. 7.01 3.45 8. 20.45 3.10 20. 39.05 3.64 35. 52.75 3.15 52. 91,27 1.18 73. 121,70 2,21 94, 155.43 3.50 116. 19~.57 g. O7 142, 239.82 4,52 172. ~91 `)Z 4.49 207. 350.52 ~.32 247, 414,81 0,53 291, 430.52 0.6* 335. 545.91 '3.19 379. 611.21 0-33 423, 675.27 0.35 466. 7~I.05 0.42 505. 305.74 0.42 550. 870.22 0.53 592. 92 S 3.05 85 S 1.3.5 56 S 8.82 ~+2 S 20.41 80 S 36.61 91 S 55.'93 75 S 78.10 87 S 103.66 69 S 133.03 87 S 166.75 90 S 205.33 57 S 245.46 30 S 295.58 90 S 343.84 76 S 392.35 26 S 441.06 35 S 439.84 89 S 538.73 90 S 588.01 38 S 637.46 HORIZ RTURE DI~ T.::i 'U'TH FEET 0.00" 0 0.32 S",28137 0.88 5:51' 5,5 1,21 ~ 71'" 47 1.44 ' 8¢.. 7 1.49 $ 87 50 1.~5 S 82 48 1.7,5 S 74 58 Z.13 S 72 17 2.~8 S 72 43 2.76 S 75 45 N 2.83 S 81 38 W 2.86 S 82 0 ~1 3.06 S 79 56 W 3.34 S 83 6 W 3.34 S 86 40 W 3.49 S 57 25 W 3.69 $ ~6 10 N 3.94 S 84 11 W 4.19 S ~+ 51 W 3.61 S 57 53 W 8.96 S 8 42 E 22.37 S 23 12 E 40.88 S 29 57 E 64.25 S 34 44 E 92.69 S 37 6 E 122.7'9 S 3'9 29 E 156.22 S 41 34 E 195,08 S 42 59 E 240.19 S 43 58 E 292.20 350.75 415.00 480.58 546.03 611.30 675.33 741,08 805.75 ~70.22 S 4& 38 E S 45 6 E S ~+5 25 E S 45 40 E S 45 56 E S 46 10 E S 45 24 E S 45 37 E S 46 51E S 47 5 E ARCO ALASKA, .INC. 3A-7 KUPAROK NORTH SLOPE,AL~A 19-DEC-85 DATE aF SURVEY: 04-N]V-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 73.00 FT ZNTERPOLATED YALJ'ES FOR EVEN 100 TRUE SdS-SEA qEASORE9 VERTICAL VSRTICAL DEATH DEPTd 3EPTH 4000.03 3711.4; 3538.45 4100.00 37.38.77 3715.77 4?00.00 3~56.5~ 3793.68 ~300.03 3945.26 3872.25 ~400.00 402~.2~ 3951.28 ~500.00 41J3.,,56 aO3f].66 4500.OJ .1{3.il ~110.11 4700.03 4252.53 ~1~9.53 ~800.09 4342.78 ~2~9.73 ~gOO.O0 4423.34 ~350.$4 5000.00 4505.05 5100.00 ~5.55.33 4513.33 5200.00 4667.~B 5300.00 4748.~9 5400.00 ~,329.59 4755,.5~ 5500.00 4903.5'9 ~835.59 3500.00 4987.53 5700.00 5065.25 4932.25 5800.00 5141.'9~ 506~.~9 5900.0} 521~.J4 51~.54 5000.00 5235.25 ~222.25 6100.JO 5372.30 5299.3'$ 6200.00 5449. ~4 .5300.00 5527.54 54J0.J0 5505.'3 5532.,53 6500.00 5584.35 5~i1.05 6500.03 3753.il ~6~3.Zl 670~.00 5342.75 576~.7~ 5300.00 j922.~4 6900.00 6001.~4 7000.00 6079.55 5005.55 7100.00 6156.21 ~0~3.21 7200.00 5232.24 515~.24 7300.00 630~.20 ~235.26 7325.00 5327.25 5254.26 CSJ2S~ 35 2.5 35 52 36 O 35 53 37 .54 39 45 39 56 40 1 35 37 37 36 !9 3 55 3O 3 .,, ~., ! 0 3~ 40 4O 40 ~,,9 29 S 4g 5 E 25 S 44 ~5 31 S 44 16 c 31 5 ¢4 15 5 ~ 44 15 V=RTIS&L S:CTI!]N FEET 934.07 9'97.36 1059.93 1121.61 !182.59 1243.2~ 1333.69 1364.02 1423.49 14~1.86 1540.04 159~.11 1555.78 1714.31 1773.25 133~.32 1~9~.60 1958 · ,50 2'322.71 2037.04 2151.14 2214.70 1277.77 2340.62 ;2403.08 !464. ~6 '2525.~1 ~5~~ 25 27,37.11 2773.03 2534.19 2399.07 2'953.96 29~0.18 FEET OF DOSLEG SEV:RITY DES/lO0 0.42 0 · 7 ;3 0.75 0.32 0.53 0.30 0.21 0.45 1.78 0.14 0.62 0.23 1.65 0.38 1.89 0.$5 1 · 79 0.99 0.28 0.54 0.82 0.73 0.49 0.55 0.60 1.19 0.18 0.41 1.61 2.32 1.17 1.16 0.00 0.00 0.00 MEASURED DEPTH RECTANGULAR NORTM/SJUTH FEET 533.25 S 573.51 S 713.05 S 751.70 S 789.54 S 826.52 S 863.~4 S 900.01 S 935.97 S 972.22 S COORDINATES EAST/WEST FEET 685.55 E · '735.63 E 784.30 E 832.57 E 880.78 E 92~.98 :- 977.28 E 1025.64 =' 1073.41 E 1119.~9 E 934.0'7 S" 47 997-38 S 47 I059.'98 $, 47 1121.71-$ 47 1182.85 S 4~ 1243.51' S 4~ 1304.07 S 48 1364.54 S 4~ 1~24.17 'S 4~ 1~82.65 S 49 1008.53 1044.61 1080.35 1117.52 115~.98 1193.82 1232.87 1274.12 1316.74 1359.28 S 1165.07 E S 1210.51 E S 1256.33 E S 1301.68 E S 1347.33 E S 1394.59 E S 1441.96 E $ 14~9.63 E S 1537.53 E S 1585.81 E 1540.95 1599.14 1656.96 1715.58 1774.52 1835.78 1897.16 1960.19 2024.30 2088.55 1~01.15 1442.29 1483.02 1523.20 1562.69 1601.33 1538.72 1575.76 1712.97 1753.19 S 1634.41 S 1682.94 S 1731.18 .S 1779.64 S 1~28.Z0 S 1875.77 S 1925.39 S 1973.05 S 2020.49 S 2066.19 2152.7~) 2216.42 2279.53 2342.49 2405.06 2467.09 2528.11 258:~.65 2648.90 2709.76 1797.12 S 2111.26 E 1842.64 S 2156.54 E 1889.13 S 2201.92 E 1935.55 S 2247.27 E 1947.28 S 225~.51 E 2772.55 2836.55 2901.25 2965.97 2982.15 .,OEP4RTURE 'AZIMUTH MIN 19 E 31 E 43 E 55 E 7 ~ 20 32 m 43 E 54 E 1 E S 49 7 E S 49 1Z E S 49 18 E 549218 S 49 23 E S 49 26 E S 49 28 E S 49 27 E S 49 25 E S 49 23 E S 49 23 E S 49 24 E S 49 24 E S ~+9 26 E S ~9 28 s ,, S 49 35 ~ S 49 39 E S 49 42 E S 49 41 E S 49 35 E S 49 29 E S 49 22 E S 49 15 E S 49 14 E ARCO .~Lf~S<A, I~C. 3A-7 KUPARUK NOOTH SLOPE, ~LX3,q;1 TRUE ~ZASURE] V~ERTIC~L DEPTH DEPTH O.OO 0.00 lO00.O0 999.99 2000.03 1999.96 3000.00 .2945.59 ~030.00 3711.45 5900.00 4505.05 6930.03 5ZgS.L5 7000.00 5079.55 7325.00 5327.!6 INTERPOLATED VALUES FOR S'.JB-S ~A CO.JeSL V£RTiCAL DEV DEPTH, -73.00 0 O N 0 3 ')26.99 0 !0 q 5! 5~ !926.96 2 54 S 35 ~ 2572.59 33 36 S ~7 3~ 363:~.45 39 30 S 50 Z~ ~432.06 33 ~5 S 51 39 .5222.25 39 33 S 49 36 6006.55 39 29 S 45 5 6254.26 40 31 $ 44 16, S~T=: 19-0~C-35 EVEN 1000 F~ET OF V:RTICAL DOGLeg S~CTI'DN SEV~RiTY FEET D:S/IO3 MEASU PAGE DATE OF SURVEY: 04-NOV-SD KELLY 3USMING ELEVATION: ENGINEER: HALFACRE RED DEPT RECTANSUL&R COORD NORTH/SOUTH 'EAST/ 'FEET FEET 73.00 0.00 0.00 0 -1.54 0.07 0 -0.94 3.51 1 2 ~ 1.92 4.49 207 934.07 ,3 .~2 633 1540.0~ 0.62 1008 ~151 14 0 32 1~01 2'170.03 1.17 1797 2980.18 0.00 1947 .00 N 0.0 .63 S 2.6 .92 S 3.0 .90 S 203.3 .25 S 586.6 .53 S 1165.0 · 13 S 1634.4 .12 S 2111.2 .28 S 2258.6 INATE S WEST DI F~ o ~ o,j 9 W 6 W 3.61 3 E 292,20. 5 E 93z+. 07 7 e 154'0.95 i E 2152.79 6 E 2772.55 I E 2982.15 .DEPARTURE ZIMUTH EG MIN FT 0 0 E 75 45 W S 57 53 W S 44 38 E S 47 19 '- S 49 7 ')~ S 49 23 S 49 35 E S 49 14 E ARCO ALASKA, 3A-7 KUPARUK N3RTH GLOPE,~L~SKA TRUE ,1E6SURS] VERTIC&L DEPTH OEPTH O.OO 73.00 73.30 173.00 173.00 273.00 273.00 373.00 373.00 ~73.00 470.00 573.00 573.00 573.0~ o73.00 77,3.01 773.00 ~73.01 973.01 '973.00 1073.01 1073.00 1173.01 1173.00 1273.01 !273.00 1373.01 1373.J0 1473.01 14'73.00 1573,01 1573,00 1573.01 1673.00 1773.01 1773.~0 1873.01 1073.J0 1'9'73.01 1973.00 , 2073.25 2073.;]0 2174.04 2173.00 2275.67 2273.00 2373.3~ 2373.00 2~2.~5 2473.0~ 2587.37 23T3.00 ~69~ ~5 2673."~0 2~02.08 2773.J0 2914.67 2873.00 3033.19 2973.00 3150.09 3073.00 3292.63 3173.00 3424.85 3273.00 3556.7~ 3373.00 3585,2i 3~73.00 3819.&2 ~573.00 3950.13 3573.00 4079.63 3773.~0 4208.03 3373.00 COMPUTATi]N D~T~: 19-DEC-S5' ZNTERPOL~TEO VALUES FOi4 :,.:V'EN 100 ,mEET SUB-S:A CDjRSE VERTICAL ,POGL V£RTICAL DEVI~TI,DN AZiM~JTi SECTION S~VE DEPTH 9EG MIN -73.00 0 0 W 0 O E 0.00 O 0.00 0 19 S 25 35 k 0.05 0 100.00 0 gO S '72 O ,~' -9.04 0 200.00 0 15 N 62 57 N -0.46 0 300.00 0 10 N 45 22 ',,I -0.87 0 400.00 0 1 ~ 2,5 22 ;'t -1.04 0 5O,?.O0 0 6 S 7 3~ ',J -1.OZ 0 503.00 0 12 S 39 58 W -0.:~3 0 700,00 0 13 S 64 1Z W -1,02 0 500,00 0 1Z S 35 2'7 N -1.16 0 ~!30.00 2239.30 !I 31 S 2300.0'3 14 36 S 42 35 2~C0.:'30 ! I 1 2503 30 =700. OO 2'300,03 29 50 ,~00.'~0 35 '~ S 47 27 3000.00 40 ~ 31OJ.O0 *0 5.3 3200.33 40 ~ S 3330.00 ~O 35 ~ 43 35 - 3430.30 ~O 23 3 ~9 !3 E_ 3~00.00 40 i{ £ 49 55 = 3500.00 39 45 S 5, S 15 3700.0J 3'9 14 S 3800.0J 3~ 27 S 51 7 -1,45 -1,73 -1 -1,81 -2.07 -2.28 -2.42 -2,53 -2.56 -2.75 -2.03 4.40 16.41 -2 e,. 08 S7.20 85.05 117,75 153.09 195.45 247.10 310.63 30~.67 475.73 552,16 648,20 733,43 91,3.30 '~02.30 1064.94 PAISE DATE CF SURVEY: O~-NDV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE OF SUB-SEA DEPTH EG RECTANGULAR RiTY N3RTH/SOUTH lO0 FEET COOR EAST FEE 73.00 FT .00 0.00 N O. .39 0.15 S O. · 50 0.52 S O. .12 0.44 S 1. ,21 0,21 S ,11 0,06 S 1. .1~- 0.14 5 1. · 11 0.3:3 S 1. .09 0.60 S 1. .16 0.74 S O. 17 0.58 S 0.14 0.47 S O. 27 0.37 S 0.27 0.50 S O. 25 0.47 S 0.17 0.23 5 O.OB 0.15 S 0.23 ' 0.21 S 0.20 0.37 S 0.20 0.39 S 3.69 1.00 S 2.94 6.48 S 3.75 17.08 .S 3.65 31,67 S 3.08 48.59 S 1.2~ · 70.11 S 1.75 92.15 S 3.53 115.30 S 4.05 143.28 S 4,4~ 177,74 S 4,57 220,53 S 2.19 273.52 S 0.62 332.57 S 0.22 390,61 S 0.20 447.79 S 0.42 503.92 S 0.38 559.00 S 0.70 612.95 S 0.50 565.35 S 0.82 716.20 S DINATES /WEST T O0 E 06 W 53 W 38 W 47 W 52 W 63 W 94 W 2.27 W , 2,62 N 2.79 W 2.81 w 2.93 W 3.25 W 3.32 W 3.43 W 3.54 W 3.84 W 4,.13 W 3.71 W 0.02 W 6.53 E iT.iO ~ 32.35 E 52.33 E 75.13 E 101, 86 ~: 133.69 E 172,16 E 219,12 E 276.42 E 340.30 E 404.44 E 468.76 E 532. ~5 E 597.52 E 562.15 ~ = 725.65 E 788.21 E D 'E P ~ R T U R E AZIMUTH OI :'DEG MIN o o'; :$ z3 i2 0.74 $ 45 50 ~ 1.13 S: 67 O N 1,'40 S 81 27 ""'~ 1.48 S 87 39 ! 1.53 S 8~ 47 N 1.58 S 75 45 W 2.03 S 72 52 W 2.39 S 71 57 W 2,71 2,83 2,83 2,98 3,29 3,33 3,44 3,65 3,86 4,15. 3,84 5,48 18.29 35.99 58.74 87.~9 118.90 153.~5 195.96 247.45 310.88 388.87 ~75.89 562.27 548,27 733,46 818.31 902,30 9~4.51 1065.00 S 75 27 W S 89 31 W S 82 23 W S 80 22 W S B1 42 N S 86 1 N S 87 31 W S 85 44 W S 84 28 W S 84 35 W S 74 51 W S 0 9 N S 20 55 E S 28 22 E S 34 0 S 35 44 ~ S 39 11E S 41 27 ; 's o S 44 SE S 44 48 E S 45 18 E S 45 38 E S 45 59 E S 45 18 E S 46 36 E S 46 54 E S 47 12 E S 47 28 E S ~7 44 E ~CS AL.&SK&, iNC. ]RTH SLOP~,AL-~SK& CDqPLJTAT'Z]':,i OATE: 19-DF-C-35 £NT~RPDLATE3 VALiJ~S FiR -V~N 100 F~:T OF TRU: SJS-S'::~ NSURED VERTiC&L VERT!~AL )EPTH DEPTq D!~PTM 535,18 3973.00 3900.00 ;61.3~ 4073.00 4000,03 587,27 ~173.0J 4100.00 713.02 4273,00 $203.00 337,30 ~373.0J ~50,54 4473,00 ]~3,.5~ 4573,.]0 45'3~.00 ~36,29 ~673,0J 4600.00 ~29,'79 4773.00 ~700,00 ~54,59 4873.00 ~SOO.O0 5bl.43 4973.00 $903,00 FlO.09 50'73,00 5009 {40.49 5173.00 51JO.O0 ~71.05 5273.00 3200.00 L00.78 5373.00 5305.00 !29.6B 5~73.00 3403.30 ~58,23 5573.33 5500.00 ;85.97 5673,00 512.33 5773.00 5700.00 /37.9'9 5a73.00 ~00.00 303.39 5973.03 5900.00 )91.52 6073.03 503,}.03 [22.07 '5173,0J OliO.JO :)53,52 52F3,00 ~23,00 5327,25 o25~.25 CDJRSE V~RTiCAL DOGLEG DE¥:I ~TI.DN A'Z iM:JT~ ]=CTIDN '.SEVERITY D~.G' MIN DES MZ'~ FEET DEG/iO0 37 52 S ':1 47 : i143.17 0,58 37 26 S 5~ .... P9 : 1219.87 0.41 37 26 S 5.2 ~4 ": 12'95.99 0.15 37 8 S =3 11 :_ 137t.:5~ 0,47 35 53' S 5,1 5,) 1445.27 J.97 35 39 S 51 33 _'- i517.09 3.31 35 26 S 51 JO - i583,6~ 0,47 3J 33 S 51 7 ~ 1659,44 1,61 35 57 S 50 39 i5 1731,77 0,65 37 53 S 50 35 ~ 1~06,45 1,35 ,35 1 S 50 22 _:: 1384.18 O.B4 39 ~7 .~ 4,~ 17 1955.07 0.62 40 5 S 4~ $2" .... = 2Q48.74 'O 35 39 ~ S 49 26 ,E 2!32.65 0,66 39 19 S 49 4~ = ;2215.20 0,71 39 1 $ 53 15 ~ 2296,43 0,51 33 ~ S 50 57 ~ !377,07 0,48 33 12 S 51 5~ ~ 2456.34 1,36 37 24 S 52 23 ~ !533.27 0.19 37 7 $ 51 55 '- !609,06 0.61 B7 ~3 ~ 47 47 = 258~.57 3.79 3'a "Z4 '~ ~5 lZ ~ Z75~.64 1,34 40 ~1 S 44 15 E 2.54~,$0 2,00 40 ~1 S 44 16 :_ 2~B3,86 0,00 40 ~1 S 44 iA = 29~0.15 0.00 PAGE' 5' DATE 3F SJRVE¥: Oi-N]V-85 KELLY BUSHING ELEVATION: 73.00 ENGINEER: HALFACRE FT SUB-SEA DEPTH RECTANGULAR C03ROINATES H]RIZ, RTURE NDRTH/SOUTH E~ST/WEST DIST': iMUTH FEET FEET FEETii, MIN i i :." i220.i0',.',:S,"~:¢.'78 !296,35' .,.S' 48 765.12 S 312,35 S ~55,75 S 90~,73 S 949,3B S ~94,24 S 1035,75 S 1082.55 S 1128.61 S 1176,08 S 1225,56 S 1278.~3 S 1333,99 S 13B9,14 S 1442,61 S 1494,99 S 1546,30 S 1595.01 S 1543.28 S 1589,89 S 1737.79 S 1793,31 S 1352,88 S 1914,07 S 1947,2B S 849,54 E 910.35 E 971.12 E 1031,94 E 1372.38. 1090,68 E 1~46,00 1147.03 E 1517.95 1203.35 E 1589.6~ 12~9,17 E 1560,62 1315.21 E 1733.07 1373.03 E 1807,87 4'8 49 49 59 15 30 45 57 4 11 18 21 25 1433.15 E 1885,72 1494,45 E 1966,66 1557.04 E 2050,34 1620.33 E 2134.29 1683.32 E 2216.91 1745,54 E 2298,24 1807.94 E 2379.01 1869,94 E 245~,44 1931.02 E 2535.59 1991.17. ~ 2511.61 S 49 S 49 S 49 S 49 S 49 S S 49 S 49 S 49 S 27 27 24 23 25 27 31 36 4O 2049,73 E 2587,25 2107,44 E 2757,17 2166,58 E 2550,83 2226,2~ E 2935,95 225~.51 E 2982,15 S 49 42 E S 49 36 E S 49 27 E S 49 18 E S 49 14 E 3A-7 KOPARUK NORTH SL~3PE,ALAS~A C3!'qPUT;TZ3~ DATE: 19-DEC-~5 PA'GE 6 DAT5 OF SURVEY: O~-N3V-$5 KELLY 5USHING ELEVATION: 73.00 ENGINEER: HALFACRE FT TOP KUPARUK Z 5,AS~ K'JPA:qUK C T'JP ~UPARUK ~ BASE KUPARUK A P3TD INT.: RPOL a,T~ 3 ,. ~IEASU2,'-5 3 ?TH 592Z.00 7131.00 7191.00 7325.0.0 ' i-~3 S r:. N HORIZONS 59.3'9.23 5219.05 505~.69 5179.79 5225.40 6327.26 O~IGl'q: 623' TVO .SJ~-SEA 5916.26 59~,5.05 59.~5.59 6106.79 6152.¢0 6254.26 S~RFACE :ON FSL, ?74' FEL, SEC , R9E,OM REC TANGULAR:'!i ~ATES 17¢6.3g S' 2059.0Z 1762.70 S 2076.05 1785.06 $' 2099.08 1857.03 S 2170.63 1854.9~ S 219T.3~ 1947.28 S 225'8.51 CO AL~SK~ ZWC. ,-7 IPARUK IRTH SLSPE,AL&S~& C]~lP',JT~T'ZBN D&T =; 19-S~-'C- B 5 DATE 3F SURVEY: 04-NDV-85 KELLY BUSHING ELEVA'TISN: 73.00 ENGIN:ER: H&LFACRE FT MA-?K£R TJP KUP~RUK TBP KUP~RJK PBTD TO 2ZNAL WmLL ~IEASJRES 5922.00 6973.00 ~0 7131. ,~ 7191.00 7325.00 9qZSZN: 623' FSL, TVD 59B9..25 591.5.25 .5D19.05 5945.05 505B.59 5955.59 617'9.79 6105.79 5225.40 5152.~0 5327.26 525~.26 774" F R'EC 'NO EL, SEC 7,. 9E,UM T~NGULAR COORDINATES RTH/SDUT'i EASTiNrEST 7t, 6 752 7B5 857 ::~ 47 .39 S 2059.02 E .70 S 2076.05 E .05 S 2099.08 E .OB S 2170.53 E .94 S 2197.8~ E .28 S 2258.61 E q~]RIZ]NTAL 3':PARTURE DISTANCE AZIMUTH '~:~T BEG MIN 7325.00 5327.£5 5Z5~.25 29B2.15 S 49 14 E SCHLUMBEROER O I REC T I ONAL SURV E Y COMPANY WELL ARCO ALASKA INC. 9A-7 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 000071099 WELL NAME: 3A-7 SURFACE LOCATION:-~623' FSL, 774' FEL, S7, T12N, R9E, UM VERTICAL PROJECTION -500 0 0 500 1 ~ 1500 201::]0 2f~00 ~lO00 3500 ~i i T~~ ~~T]' i i i: , i i i i i i i i i i T] ] ii ] i i [iY']ii [ i [ i [ i"F'"TT"T~.""T'T-T~ .....?-t'?"t" ? ...... : .... .-,-. _:-?_: ..._ ; : ; : ' ; ; ; : ",~,.._: : : : : i ; : : ; ; ; ] [ ~ : ] i i i i i ; : ; [ [ ~ : ~-.~ ~ ~ -i ! ! ! ] i :,4._.._L~..i-_~ !-i. +l L~ ! ! ! 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RAToR, I.fELL ~AHI~ ~0 NO~ER ' - . 'aReports and Hateria!s to be received by: . //~ ' ' Requir~' Daie Received Remarks , "Samples .:!/, ~ : ~ " Hud Log ,. :-:':::': ,0 l Cbr~ 'De~ertptfon Inclination Survey , Drill Stem Test Reports . ,, Production ~est Reports ..... [P:~:~ ,~-_~ · Digitized Data L.FJ.04 ARCO Alaska, inc. Post Office Bo.. ,00360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC o ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are t_he following items. return one signed copy of this transmittal. OPen Hole Finals/ Schl/ One * of each 3A-10 ~--~- 5. DIL/SFL /~ ~ 2" DIL/SFL ' ~5" Den/Neu ~ ~2" Den/Neu ~ ~5" Den/Neu ~ ~2" Den/Neu ~Cyberlook (poro) (poro) (raw) (raw) DIL/SFL-gr DIL/SFL-?r Den/Neu-gr (poro) Den/Neu-gr (poro) Den/Z~eu-gr (raw) Den/Neu-gr (raw) Cyme rlook 11-09-85 Run# 1 11-09-85 Run#1 11-09-85 Run#1 11-09-85 Run#1 11-09-85 Run#1 11-09-85 run#1 11-09-85 Run#1 10-30-85 Run#1 10-30-85 Run#1 10-30-85 Run#1 10-30-85 Run#1 10-30-85 Run#l 10-30-85 Run#1 10-30-85 Run#1 3A-7 ~ ~ 5" ~ -- 2" ~ ~5~! ' - 2" 5" D!L/SFL-gr DiL/SFL-gr Den/Neu (poro) Den/l{eu (poro) Den/Neu (raw) Den/Neu (raw) ~ ~ Cyberlook 10-24-85 Run#1 10-.24-85 Run#1 10-24-85 Run#1 10-24-85 Run#1 10-24-85 Run#1 10-24-85 Run#1 10-24-85 Run#1 DATE 12-19-85 TRANSMITTAL # 5481 B Please acknowledge receipt and 3211-6988 3211-6988 6180-6962 6180-6962 6180-6962 6180-6962 6400-6800 3161-7080 3161-7080 6390-7055 6390-7055 6390-7055 6390-7055 6490-7030 1950-7238 1950-7238 4750-7212 4750-7212 4750-7212 4750-7212 6650-7189 Receipt Acknowledged: STATE OF AK*BL&SE RATHNE~L*BL NSK CLERK*BL DRILLING*BL VAULT*FILMS DEGLOYER & MACNAUGHTON*BL Date: ARCO Al~'$[a. InC ,$ a Subsidiary of AtlamlicR~chheldComl~an)' ARCO Alaska, Inc. Post Office £ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11- 07- ~ 5 TKANS~ITTAL NO: 5431 JTURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-illLB P.O. BOX 100360 ANCHORAGE, AK 99510 LANSMITTED ~CEIPT AND zEN H~QLE LIS TAPES PLUS LISTING/ 33--8" 10-16-85 RUN %1 2188 HEREWITH AmLE KETURN ONE SI THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE GNED COPY OF THIS TRANSMITTAL. SCHL/ ONE COPY OF EACH · 5-7344. O~D~74~-S-~/~eU~ 5/~- 73z/~ 1748 0-7585.0~d~7~3~~- /~-~~ 1994~ 0-8647. ~~7~-J-~fe~-/~-~7 3030.0-6900. 3692.5-68s[. 5 o&7 4050·0-s425. 34[0. 0-7617 33'-7~/ 10-09-85 RUN 3F-5~' 10-20-85 RUN 3~F-4 ? 10-13-85 RUN $~_-16 ~ 09-29-85 ~- 15'"" 10-08- 85 RUN ~C-14 '--~10-15- 85 RUN ~_~- ~_ 10-24-85 RUN ~- 6 -~" 10-18-85 RUN 3~-5~''~ 10-11-85 .RUN CEIPT ACKNOWLEDGED: AE CURRIER- ~JVRON M DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON P~OBIL PHILLIPS OIL NSK CLERK J..!%ATHMELL ARCO Alaska, Inc. is a SubsiO~ary ol AtlanticRichfieldCompany ARCO Alaska, Inc. ~-~,_ Post Office B 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the October monthly reports 1B-1 (workover) 3A-7 3C-15 3J-6 2A-8 3A-8 3F-3 3J-7 2D-12 (workover) 3C-6 3F-4 3J-8 3A-5 3C-13 3F-5 4-21 3A-6 3C- 14 3F-6 4-22 If you have any questions, Sincerely, d. Gruber Associate Engineer please JG/tw GRU12/L80 Enclosures for call me the following wells: 9-24 L2-3 9-36 L2-13 16-17 L3-5 16-18 L3-11 18-6 (workover) at 263-4944. [ ECEiVED Alaska Oil & Gas Cons. gomm!ssJon Anchorag~ ARCO Alaska, Inc. is a Subsidiary o! AtlanficRichfieldCompany ' --- STATE OF ALASKA ~-- ._..¢ , ~ ' '-.. ALASKA C __ AND GAS CONSERVATION CO, .41SSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-223 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21444 4. Location of Well atsurface 623' FSL, 774' FEL, Sec.7, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 25632 ALK 2565 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. October ,19 85 12. Depthatend of month, footagedrilled, fishingjobs, directionaldrillingproblems, spud date, remarks Spudded well e 0245 hrs, 10/20/85. Drilled 12-1/4" hole to 3197'. Ran, cmtd & tstd 9-5/8" csg. Drilled 8-1/2" hole to 7250'. Ran logs. Cont'd drlg 8-1/2" hole to 7325'TD (10/24/85). Ran, cmtd & tstd 7" csg. PBTD = 7191'. Secured well & RR ~ 1330 hrs, 10/25/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 104'. Cmtd w/185 sx AS 11. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3176'. Cmtd w/lO00 sx AS Ill & 350 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7281'. Cmtd w/125 sx Healy Flyash & 300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/7248' - 3176' FDC/CNL f/7248' - 6650' & 5300' - 4750' Cal f/7248' - 4350' 6. DST data, perforatingdata, showsof H2S, miscellaneousdata None RECEIVED NOV A/aska 0ii & Gas Cor~s. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Aj~0h0j.~ SIGNED ~'0~ ~~,~ j TITLE Associate Engineer DATE NOTE--Report on~/his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/MRS0 Submit in duplicate September 18, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, - Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-7 ARCO Alaska, Inc. Permit No. 85-223 Sur. Loc. 623'FSL, 774'FEL, Sec. 7, T12N, R9E, DM. Btmhole Loc. 1456'FNL, 1477'F~PL, Sec. 17, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to 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. I.~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. tr~~~rs~ ~ C. V. Chatt~rtdn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~' Post Office Bo_ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 4, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-7 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3A-7, along a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore with o A proximity plot o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on October 2, 1985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/JFB/tw PD/L169 Enclosures RECEIVED SEP 1 0 I9B5 ARCO Alaska, Inc. Js a Subsidiary of AtlanticRichfieldCompany la. Type of work. 2. Name of operator ARCO Alaska, Inc, r-''~ STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION COk,,vllSSlON P'ERMIT TO DRILL 2O AAC 25.005 I DR ILL I~ I lb. Type of well EXPLORATORY [] REDRILL [] I DEVELOPMENT OIL [~X DEEPEN [] DEVELOPMENT GAS [] SERVICE [] STRATI G R~H~C SINGLE ZONE ~[~ MULTIPLE ZO,~I2 [] 9. Unit or lease name Kuparuk River Unit 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 623' FSL, 774' FEL, Sec.7, T12N, R9E, UM At top of proposed producing interval 1260' FNL, 1256' FWL, Sec.17, T12N, RgE, UM At total depth 1465' FNL, 1477' FWL, Sec.17, T12N, RgE, UN 10. Well number 3A-7 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 73', PAD 41.1' ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 3A-6 well 25' @ surface feet 18. Approximate spud date 10/02/85 16. Proposed depth (MD & TVD) 7378' MD, 6323' TVD 19. If deviated (see 20 AAC 25.050) 2671 psig@ 80°F Surface KICK OFF POINT 1933 feet. 3070 psig@, 5963 ft. TD (TVD) 21 14. Distance to nearest property or lease line miles 3803 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 40 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program SIZE Hole 2bt'' il 2-1/4" .8-1/2" Casing 16" 9-5/8" 7" 22. Describe proposed CASING AND LINER Weight Grade I Coupling H-40 ~ Weld 36.62.5#0# -55/HF- E~W' BTC / 26.0# -55/HF-EIW BTC / program: Length SETTING DEPTH MD TOP TVD 80' 32' I 32' 3223' 32' I 32' I I 31' I 31' 7347' M D BOTTOM TV D 112' 112' 3255'I 3152' 7378'1 6326' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 720 sx AS Ill & 350 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7378' MD (6326' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA ROPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2671 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3A'7 will be 25' away from 3A-6 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) . 23. I hereby certj;~y~that the foregoing is true and correct to the best of my knowledge SIGNED ///~/~,/,~ //~~ TITLE Regional Dril Iing Engr, DATE Th e space b ~/l~/W~o-r~o~ m-Co n-~uu se , 7 - Samples required F-lYES ~-NO Permit number APPROVED BY Form 10401 CONDITIONS OF APPROVAL Mud log required Directional Survey required I APl number I-lYES .[~NO [~'ES []NO J 50- O ~,~- 'Z_ / ~/~' ~/ Approval date 09/.,18. 85 SEE COVER LETTER FOR OTHER REQUIREMENTS ~',/_ ~ ,COMMISSIONER DATE SeDtember ]8 ] gR~ { ',~ F' ( ~1¢~~'/it¢I~ by order of the Commission '~ P~/PD16'~J''~ / ! Submit in triplicate PERMIT TO DRILL 3A-7 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ? ECEiVED S E? 1 0 ~,laska 0~ & Gas Cons. Commissior~ Anchora.g~ .... ~RCO iA~^sK~,~ ~I,~C.-~ !. ~: --~: !:':~--: i-:-' ..... :-:-:-,dh,' :'-' ' - ::-:-- ~ ":'. ..... ~_-'i-- -' :--~:--:P^D-.3A.' ::~ELE':NO, :7:-:'PRoPOSED:':.::L:-_i'_: :'_:__:i::-~. ~ ~ 'N, ' ::~--- ~--/ i-' --- :-!:::-:::' i" ::: L.~ ; . :>~-:'KUPA_RU__K'- F_.-t-_EL~& NO__RT_H:-S_~D~E_~:-:^LjAS~A_:_-':~?,-_ \) :--:. ':_'-..-__ :::::: .... :-:--: . :::: -_~' .... '.::2: ::_ ..... } ...... -._::. :>2':':.:'-. _[':: -:~ > !: :: :'...':'-~_ ::.:: :_ ~::::_:-'._ .L:-:::_:':,..::. !-_L :::'::-~ L::-:_-.:: :_ :.. :::_ :-:':':::: i .-'.: ::: ;_:-:..: -..- ' -'-~-~:: '~- ..... I'~ ...... :-'4-~--~; ..... : ..... ~-:-- .... -- --; .... _~ '-. .... ~-: ...... F-:- :~"-: ...... -". ................ ; ....... :-:': '-- ~ ........ :'. ..... ! ..... '.- .... :- : ......... ": .............. : .... ' : - . ._ i , ' - · ~ . ~ . _ _.:- ~ .......................... ~, .... ~_-.- _ ---~ _- ...... -' : ': : ' i" ' .__- ~ .~ - _ .... . ...... -_, _: ....... - : : : --.._::-_-:' :'::-- ':- i .... . '' :: ' '- ': ' '-: .... :, .....~ -: .... ~ - " - ' .... '-"- ' ~ ' . _ ................ - ......... . ................................. _ - : . - _ _ _ . .~ · ........ . --~-'- ~-:. -- - -' I -- : ' -- . :' - - - . ~ '' .... ~. . . : ....... . .... . ........ · : ~ ' 1000~ .......... ........... : .......... -:- - '~ - ' :- '- - : :- : ........ ' ::--::;'-?:-':---; ::-:;--: : .... -::-"-----'-.- :-:' ::-:-:-::-;i-- ~ - - ' .... :::-:::-: '-':: -" '-- , ' ' .... ~' '"-- .__ · -, . _ . ._2, : ; . ! .:. ..... . '. .... :, ~ ,~ . ._ . . ; . . : . . .. : ? ...... . -'-B^$E--P£RM^~ROST .... T¥~1 552 ........ - ..... ~ ..............................' ........ --:' ........... KOP 193. THD= 9*~-:--t---'-D£P=o ...... T OP--UON U'- -S N'D S --~T¥-D'~-i-9§2-:-T-MD~-f'9-~2 ---DE P ' - ''-- '-: ' ' .... -' ' ; ' ...... 9 . - BUILD 3 DED ~ - ' -- ...... : ::' 15 .... : :PER 100 FT- i ' ~ _-:2~: TOP i~/ S^K -$NDS TVD~-26721THD--2692 DEP=149 - -- : ..... : _-. . - . ~- . _ _ :. - : .... : ~/D=2952.r,u uo ~+"%'=3';'-Og'DEP-~'~94 ' ' ' ' m K-32 T .-: .... -. : .... ~ .... >..-.- ....... - _ m ;-: -Se EOC (CSG 'PT) TVD=3152 TIED=3255. DEP=439 ..... - .: . ::~- ' ...... ' ..... :' "' ~ .... i ' ' - ' ? -'-. .... ' .......... ' ...... : . :. .... i .......! -. : .....-~:-~_._- '. '"~-' - i '--}': ......... ' ' ; ..... -: -- : .... - ................ : .......... ' .... ! ........... ~ .... ~ .. . ! _ · .> :. AVERAGE ANGLE.~ ..... ~ : ....... ':- _ . . .... .. - : _ . . -- _.- . _ _ . - .. . : - . -.-.; ._ -~- ......... "--- 39 D:EG 39 ~IN' ,o ............. ; _ _ _:-~ . : i.'-- : . - .:--"i .... - ..... ~ - . . ~ : .... ,. _ : _ _ . : . _ . . ~ . ..... ~ ......... - - - . -- K;'$- TYD-4622 TrOD--SI64 DEP=~6$8 ...... . ~: - -- _ _ ~ .......~ - . ~ - : . . . _ .: -. - : - _ -_ ...... - . .~ .... - , ~ ........; - . .... ~ ._ _- + .,. ....... ; ....... ...... : .... , .. -_ _ .~. ......... ; 1_ i ..... ;_ _ . - _ ::-_;~ '~_ :_ _ ' ~-- - ' _ _ ? -_ _ : : - :.~---~-:-----' ' ' '- ............. -- i ..... : ...... ! - - : --- i~. ............ -! -~-:--'--i - i ........ ; ..... '-~.:.! -- - --"-:'---nnn-- : ..... ~---- .... ! .... : ........ i - -: 'X,'- !-TOP UPPR 'SNDS-: 'TVD=5963' !TIMID'6906 DEP'2??O .... -----: .... !-~ ....... i" .... :-'!<-~--::-' .... !-----'--- ~, ' TARGET :CNTR':-:TVD='6068 ~T.I"ID=?043 DEP=2857 ' ~ ~ i ;.i~-_:~:-.--_::¥:_:_:-~-~ :.:-?:.:/: :i .... -'::-:.:_:-:-::----~'- .... --':BASE KUP .SNDS: .TYD=61~72-TI"ID=7178 DEP=294; _ . . ~ -: ~ ,~- -i * ........... i. ~- --.~- ,~,; ~r -'_-_~ ,-4- ...... l- ....... ~ .:.~,-~: .... _j___~-.~.~:: ........ ~ ......... ' .....~ :_ ; ' _g..---.._-~ '. : .{ - .: :'_':~ '-'-;- -'-' ',--: "'' . . , '-' .... _~'_n00- .... -~ .................... :-: -" ' - ~ -~ ....... ~ ...... ~ ......... ~-- 'P : :':_::_--Ti::~--:;::_:-:?: :.:2:.'_.I-000~:~2; ~:_ ~000---:-:'--:-.3000---:-: ..... : 4000 -::-i - - ~ ' ::::. :_ L:_:_ i_~.i:_:~_i_l_~__v. ...... :_~_i ............. '~ ~- v:- ~:-~-- ER:T.~C^Ld-SECT!-ON--_--, _--:--:--:-... -' ----'-- - -! .... -'-::- i-:. - .... '-'-:'" ; ...... ' .... J- ........ ' ....! .... - -'" ......... :--'~ :': ' : ; .... ":- '" - ' ..... -~ :-' '-- ,. uARchorane i ...... '- : ?---: : .... ~:_ -_ - PADARCO3A,ALASKA"',/ELL "Io, -N 7 . PROPOS.ED -_ . ! - _ . L_-~.-'/II . ' -~ KUPARUK' FIELD..- NORTH ~SLOPE . .=_-'ALASKA :. ~-,,/' .. ~..t~ --~. '-- - ' . .. . . . ;_ . _ ~ooo . o _.- '~'.~-__looo : i---2ooo ~ 3000 ".:.';~ooo' :.. - . ':-Y~ - ~ '- ---'~; '----, -- '-~ : 623' FSL, ~74' eEL ..... -.'~ ......... : ...... ; ..... ' ............. --- - -' ....... ' .... : SEC; 7, T I~, RgE - ~ ...... ...... :_7. _ ......... ' ............... ~. .; .... ~ -_:-.~.T-:-~ .... ::-;.._---:-'; .... _ ....... . . ~ _~ ~ - . _- .... : _ _. - ............. ............ - : _ - ._ . ;: . : _~ - ...... ~ ....... ~. ; _ ~' ... ~ ~_.-__ _- , _ . :._~ ..... ~ ....- _ i__.-__.,. ......... ; - . -- . -~' - ..~_. --- _ .- - _ . . _ - ~ .. : _' :- .. :-~ .; .... -~ ............. ' , .... ~ -.--- ~ . .._ _ . . _ .~ :~_ : _ ~ ~ ............. ~_.: ........ ; . ~ ...... . ~ ......... ~ __ : _ : _ ... :.~..~__. ' '.. , .... ~ ' - ' - ": ...... ~ ................. ~. ~ T~-70~ " _ _ ~ ..... ~ ..... . . . _ .............. : .................... - . - ....... - ........ ~ ..... - ......... -; ..... SOUTH 19~ ......... : ...... ........................ -- ....... . ................ : : . · _ ; . _ ; .. ~ _. _ .. - ..... . .... . . . : --~ ..... :~ - ~;~OOO~ : 1320'-FNL-, 1320' -FWL-- ~ ~ .... . · -~--: ~ -- ' ~C-;~TI'2N ;~'R~'-~ : -' - ......... : .................. , ......... ~ ............... : ........ ~ .... : - . - 1465' 'FNL, 147Z' FWL ........... '- - ~ SEC. I'7,-T12N, RgE __ _- .......................... - ..................... - ........ - ~ .... . - i-~----- i ......... : ........ { ..... ; ' ' ' i ; ; ~ --- ,' ' : ' : . ~ , . ~ .: .... ~-~.t::~::~ ....... ~---~¢---:-}-'-'-:--S~4 DE¢: '9~--:MIN:-::E~: . ............... ~ ........ i ..... ~ ........... :-- ----r - ~- i --- ' ' ' i ............ ........... ~ ..... ~ ........ ~ ...... , ....... -_~ ....... ~_~ ......... -_~ ....... ~ .....~ .... ~ .... -._: -- : :.. : - - - j ; ......... i . , ........ I ...... i . - - ~-~ ~ ......... ~ ~ -~ ~-I ~ · ' .-~ · ~ ~ ~ ..... : .... ~ - ' ' : ..... ~ ,:., ......... [;.. ,:>,~, ~..:_~_191._=; .....:.,_ ...... P~D-3A;L~ELL NO, 526:7-8 PROPOSED ~077Z z ~: =~ff~, 7v-:-:~,=-:~-I :: --:7 .....;,~ ........ i . -- :- ' . ~ " ': · .. . .........~ '~ :'' .... ' '-' ~ EXTE"D BEYOND; .......... ' ..... ' .... TE PATHS --: .... THIS' V ~E~JH~.~NDO~ -;' -'t455 ......... ' ; ' ' : :' : ' ' ' ~ i ; ~ : :;; -: %2888 .... , .... ' '.. "~ .......... : .:_:: - !:: :-::: i/ _.::...::,._? . __ :_: .~ _ ._:_L '-_: : _:.~__' ._____:._+ _ ~ . " ; .... :_ "..'::"::-:-::- ' : :-::- F' .... :-- ========================== ;..:::: ,-::_:_:::::-:: .: :,,.=*--.;:- . ~ ' . ..:: i ' ~---: t-:..! ':~': ~ ~' - < -.: ....... ........ -.- :-- : - -: : .::. - : :' : - - : : ' ' :' ................ ~455 ...... ; ............ _:__: .... - = . ~ : ...... : .: ...... : ........... ~ . _ . _ , . . _ ~ ............................... · .... - ..... . , · - . .; : ._ ; __. ! ............... i 4 ..................... ~ i': ---:. -'-:: '-:: -<'--':'- ~ ':-~4 .............. ' '~ .... ~ ' - '172~ : --, 152~. - _ -_2. - . . . ~ . ........ 4,502 ' 1 ~4.0 .......... ; . . : ........ -_~ ......... __~ _. & ......... : ......... ? . . ~ !__ _ ::::__L._ - ._ =.. .__~_ . .... __ __: .... . ...... :. ........ . . : . _ : ...... :. . · : i-_:__L_-._ _ 573 _.___L_ _ . · · . ......... - · . ...... ' _ . ' 1802 - 62;~: ........ . ~ ; ...... --' 457'$ ............ ~I ................. .. i : ~' ! '. ' ..... ~ _:.: _. = .~ : . : ~ : .:__.~ .......... ;- ........ ......... _. - - _. -_ :.._ .... : ........... -~ . ._..._ .-. %--i-=--: ' ........... __- ...... :---i. ............ - .:.,. .................... ~ 1875_ ' ' .... : !--: ~. - ................... ................. ~ - . - . - :. ....... _: _ - .............. _ . . __' _ -~ -- .,;..,.2 _ ~ .: . : . : ..... .............. ¢ . . ...... " - ........ ':-:; ' 1:""":".~,,,¢~ ' ' ' - ............ ............. · : ~-!:-::- ' ': -'--' .... : :--4 ' ...... ~ ' *..' ' ' ~ ':~.9So .......... L_ :.__:__'._: __-_ . : : : . . ~ ! : ..; - ~ :_ ~ ~ . :::-I-:7--7-...,. :-'~ .... .1 7?tii ' -------':- ..... :--': !-:": .... : ' --. . - -- ..... ~ .......... ..___ - , ..~ : . . ....................... ~ ...... ;. =: .... ...... : . : .... -_.j_= ....... _~- _- ._ .................................... ! ................ .: __:_ :- :. -:; '- ' -, ~ -72bOO. - ~ .... I · · : - ~ "' . ----- ! ..... : .... , ; '' , , - :7 -:'-' .......... .... t ; : ' ' · . ... , -~ ~ ':' :' ~ ~:-4 :-: ~ __:-._:_~ .... -.__:_: ...... : i --: - :'-~-5'~ ...... -' ' .......... . ;.. ~ :.;~-~ .................. : . ~ . '--~: . -~ ...... : -, ....... : : · , ~ . ': , ,~ ~ i - . ~-l~tas~8-8~i ':~ ' ' ' ............. · ~ -: ............. ~ .... . : ! ~' ,. .~ .~ -_ :--~.-.-:-.--,--:---' --; --' *. ~. ,--, .......... . ~, : ........' -" .... -/~,,' -~'~-¢~,~,..-' ' ......... -~- ; :.:: ....... ;;___...,_: '...--. :.~7 ' : ; ; i : : : : ~ .... ' i +--:--T-.--'-~ ...... ~: ! .... I-:-'I--' ' ' -~ ' ' '--- ; ....... J '-'-; ' ..... · '; ........ T ........... ....... ' '[ ' ~ - ---4--.' '~ .... ~ ...... 'X ........ . ; f ~ ,; ' i :-~--: ~ : : , i - : ~ ' ........... ; ..... ; _ __; _-.; _! _:: _: ._. -, .~ ....... _ ........... - ............. ~ . _ . :'-.:-:--; _-----'-:-.~-:- _,__:_;__ ~:: ...... : .... . . _ ........... - · I KUPARUK RI VER UNIT 20" .DI VF_.J~TER SCHEMAT I C DE S CR I P T I ON ill !. 16' C~CTOR. 2. TANi,<O STARTER HEAD. 3. TAl,a<O SAVER SUB. 4. TANKO LO~R OOICK-C~CT ASSY. 5. TAN<O UPPER OUICK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I O' 6XJTLETS. ~/" ?. I O" HCR BALL VALVES W/I O" DIVERTER LINES° VALVES OPEN AUTON~TICALLY UPON CLOP~RE OF ANI~AR PREVENTER. 8. 20" 2000 PSI AINt~LAR PREVENTER. 5 %%% 2 MA:[ NTENANCE & 0PERAT. I ON i. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES ' HAVE OPENED PROPERLY. 2. CLOSE A~LAR PREVENTER AI~ BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE AININMLAR PREVENTER IN THE EVENT 'THAT AN Ii. LUX ~ WELL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, I~I~ALLY OVERRIDE . CLOSE APPROPR I ATE VALVE TO ACH.I EVE DO~INWI IND DIVERS I ON, DO NOT SHUT IN ~ELL UNDER ANY C~}~~$~T/~E$. ,\ Lk.. L7. i V EL/ SFP 10 1985 Alaska Oil & Oas Cons. Commission Andmr2n¢. .... ti 7 6 5 4 3 2 DIAGRAM #1 1 3-5/8" 5CXD(D P$~ RSRRA BC~ STA(D< L// I. 16' - 2~ ~I T~ ST~TI~ 2. I1' - ~ ~I ~I~ 5. 1~8" - ~ ~I ~I~I~ ~ ~~ KI~ LI~ ACCL~ATOR CAPACITY TEST I. C~ECX AhD FILL ACCL~TCR RE~OIR TO PRCI~ LEVEL WITH ~~IC ~UID.' 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ t~ ~I ~T~ ~ ~ ~~T~. 3. ~~ TI~, T~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~E L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ P~~. 13-5/8" BOP STACK TEST 1. FILL BOP STACX AN3 CHOKE MANIFOLD WITH ARCTIC DIESEL° 2. (~(~ THAT ALL LOCX ~ ~ IN ~ ARE FULLY RETRACTS. SF_AT TEST WITN RLt~ING JT Ah~ RUN IN L~ SCREV~. LIhE VALVES ADJAaD~ TO BOP STACX, ALL CFFi-E~ VALVES AND ~ SHOULD BE CPEN, PRE~ UP TO 2.50 PSI~A~D~-I-K~ FCR i0 MIN. IN- ~ PRE~ ~ P~Ah~) HOLD FCR I0 MIN. BLEED PRE~ LI~E VALVES. CLOSE TOP PIPE RA~ A~ HCR VALVES TEST TO 250 PSI AND~_C~ ~ AS IN STEP 4. C~INJE TESTING ALL-~VES, LIDF_S, A~D CHOKES WITH A 25O PSI LOW A~D 7~DO0 PSI HIGH. TEST AS IN STEP 4. DO NOT F~~ T~$T D~DT A FULL CLOSIN(~ POSIT~V~ SEAL C~. CN_Y Ft~ION TEST CHCKE$ THAT DO hOT ~LY CLOSE. OmEN TOP PIPE RA~ AlxD CLOSE BOTTOM PIPE RA~. TEST BOTTOM PIPE ~ TO 2_,50 PSI Ah~ 3000 PSI. OmEN BOTTOM PIPE RA~, BACX OUT Rt~ING JT AhD CLOSE BLIhD ~ AhD TEST TO ~ PSI AAD 3000 PSI. · ~ BLIND RAMS AND ~-TRIEVE TEST PLU~. ~ SUR~ 'MANIFOLD AND LZ~S ARE FULL CF N~WFm~-ZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STA~IPE VALVES, KF~Iy, KELLY COCXS, DRILL PIPE SAFETY VALVE, AhD Ih~IBE B(:P TO 2S0 PSI A~D 3000 PSI. 13. RECCRD TEST IAFO~MATION ON BLC~ PRE-VF_N~15~ TEST r} D FC~, SIGN, Aha) SEND TO DRILLING SUPERVlS(~. ~F_EKLY THEREAFTER FlUIdLY C:PERATE BOI::~ DAILY. SEP 1 o i985 Alaska Oil & Gas Cons. Commission A,,cho,~g., ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 . .7A 7 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 3A 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, · Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG .t 0 19B~ Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldCompany t6'.~6 ~0:9 7 8 18 17 NOTES :. SJCRDINAT~S ARE A.S.P,ZONE 4 2. SECTION ~NE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BAOED CN THE D.S.- 3A WEST ~ 3AMID PER LHD ~ ASSOC. ~.V~RTICAL POSITION BASED CN 3A EAST ~ 3A MID PER LHD ~ ASSOG. 5.OG. EL~VATIONStNTERPOLATED FROM S/C DW6. CED-RIXX- 30ZO re~ ,, ~ ~e ee e~~eeeel~ee ·" HEREBY CERTIFY THAT I A M PROPERLY REGISTERED AND LI$CENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF AUGUST 14,1985 LOCATED IN PROTRACTED SEC. 7,T 12 N. 12 7 THIS SU~ Oil & 9, '-,. AS BUILT CONDUCTORS I- 16 Y=5,996,860.05 LAT= 70°2~,'09.520'' X: 507,712.01 LONG= lt, 9°56' 1~,.020" 4/8' FSL, 736' VEL, 36.8' OG, ~0.8 PAD 2- Y:5,996,88~. 17 LAT: 70°7/,' 09. 758" X= 507,705.57 LONG: 1z, 9°56' I~.207" . 503' FSL, 7~3' VEL, 35.8 05, :,0.9 PiG 3- Y=5,996,908.32 LAT-- 70o2;'0,.~.]95'' ×= 507,699.06 LONG= 1~,'~056' 527' ;SL, 7~9'VEL, 36.7 06, /,,3.8 PAD ~,- Y=5,996,932.72 LAT-- 70°2~,' 10.235'' X: 507,592.55 LONG= 1b, 9°56' 1b~.581'' 5S1' ESL, 756' ~'EL, 36.7 OG, ~,0.8 ~- Y=5,996,956.61 tAT= 70°2~' 10.~,70" ~,= 507,686.21 LONG= t&9°56'l&.773'' 575 FSL, 762':EL, 36.50G, ~,0.9 P&D 6- Y=5,996,980.8~ LAf= 70°2~' 10.709" X= 507,679.66 LONG= 1~,9°56' lz~.963" 599 FSL, 768' FEL, 36.50G, ~,0.8 7- Y--5,997,00~*.90 LAI- 70°2~,' 10.9~5" X= 507,673.26 LONG= 1~,9°56' [5 151" 623 FSL, 774'FEL, 36.5 0";, 8- Y=5,gg7,029.03 LAT= 70°2~' ! . i53" X--- 507,666.81 LONG= i~.9°56 15 5z,? FSL, 781' FEL, 36.~, OG, ~,0.9 P.'AD 9- Y=5,997, 101.24, LAT= 70°24' t .893" X= 507,6~,7.70 LONG= 1~9°56 15 896" 720 FSL, 800' FEL, 36.30G, ~,1.7 PAP 10- Y=5,997, I25.66 LAT= 70°2~' i2. 13~" X= 5.]',6z, 0.89 LONG= IZ, 9°56 16 095" ?~,4, C'L, 806.~ FEL, 36.30G, z, 1.6 PAD ll- Y=5,99~, 14`9.8~ LAT: 70°2z~'12.37~'' X= 507,63~+.~,~ LONG: i~9°56 16 283" 768 FSL, 813 FEL, 36.2 OG, qL2 PAD I2- Y=5,997,173.97 LAT: 70°2~'12.509'' X= 507,627.96 LONG= 11~9°56 [6 .,; !." 792' FSL, 819 FEL, 36.I OG, 13- Y=5,997, 198.08 LAT= 7002L,' 13.8~.5" X: 507,621.~8 LONG= l'.9°56 ~§.~<-" 817' FSL, 825 FEL, 36.00G, 61.3 16- ~'=5,997,222.29 t~= 70°24' !3.98~" X= 507,615.0 LONG= 1~9°55 16.35:" 84,1' FSL, 832 VEL, 35.8 15- Y=5,997,2,6.z,~, LAT: 70°2~,' 13.322" EIVED .,= ,o,.6o,.,, LONG= 14g°56' 17.03'.~" 865' F-SL, 838 FEL, 35.6 OG, al.3 ~: 5n ~,b02. lO LONG: i~,9°55' I 7. -." Gas Cons. Commis~JFofi' ; :-, 5 .~ z, ; £ L, ? 5. $ 0,3, -". [. i ' - mchorage F. Kuparuk Pro~ec f CONDUCTOR AS- DUI LT LOCATIONS ,~I aSSgE I:),~'e AUG. ,6, ,,es Stole; I" : 3.".. Drafted by:~./_.~ Bwg. no.: NSK 85- 16 CHECK LIST FOR NEW WELL PERMITS Company /~ Lease & Well No. ITEM APPROVE DATE (1) Fee .. (2) Loc ...... (2 thru 8) (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. '19. 20. 21. YES NO 1. Is the permit fee attached ................................ , ..... ,... // 2. Is well to be located in a defined pool ..' ...... ~-. 4. Is well located proper distance from other wells ....... ............. .A.~ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can pe~it be approved before ten-day wait .......................... 22. 23. 24. 25. 26. REMARKS 27. Does operator have a bond in force .................................. /~-.~ Is a conservation order ded · ~ nee ....................................... Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... ~ ..... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productiVe horizons ..................... Will surface casing protect fresh water zones ....................... 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 ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to.~DO psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78).~. ............... Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: Geology: Eng ~neerin~: HWK ~ LCS WVA':~ff.~ MTM ~ HJH ~y . JAL ~~._ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE · Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under AppENDIXi No special'effort has been made to chronologically organize this category of information. o. :',~ .... SCHLUMBERGER .... ~ LIS T4PE VER!FiC,ATION LISTING LVP OlOoH02 VERIFICATION LISTING PAGE 1 -,-~ REEL HEADER ~ SERVICE NAME :EDIT DATE :85/10/30 ORIGIN : REEL NAME :149246 CONTINUATION ~ :Oi PREVIOUS REEL : COMMENTS :LIBRARY TAP~ ~-~-T.~p~ HEADER SERVICE NAME :EDIT OATE ORIGIN :0000 TAPE NAME :0912 CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS :LIBRARY TAPE -'-~- FILE HEADER FILE NAME :EDIT SERVICE N~ME : VERSION # : OATE: MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS ~ILE -~-,- IN=ORMAT'ION RECOROS ~ M:NEM CONTENTS .... CN : ARCO ALASKA INC B-2 WN : 34-7 FN : KUPARUK RANG: gE TOWN: SECT: 7 COUN: N. SLOPE STAT: CTRY: USA MNEM CONTENTS PRES,: E ~::q~ COMMENTS .....,;~ UNIT TYPE CA'TE SIZE CODE 000 000 019 065 gO0 000 004 065 000 000 008 065 OOO 000 002 065 000 000 004 055 000 0:00 002 065 000 000 012 065 00,0 000 006 085 000 000 003 065 UNIT TYPE CATE SiZE CODE 00 O 0 O 0 001 065 LV,~ OlO.H02 VE~!r-IC~TION LIST!N~ P~E 2 '"' SCHLUMBERG~ ;~ 4LASKA COMFUTZNG CENTER .,.., ..... ,..,..~..~. ~. ~..,..~..,.., ......... . .,..~. .,..~..,. 4..~..,..~. ~..,. -~..,..~..~..~ .~. ~ .,..~..~ ..... ........ ~..,..~ .,..,..,o .,o.,o .~..v COMPANY = ARCO ~LASKA ZNC W:LL : 3~-7 FIELD : KUPARUK COUNTY = NORTH SLOPE BOROUGH STATE = ~LASKA JOB NUMBER AT ~CC: 70912 RUN ~1, DATE LOGGED: 2~ OCT 85 LOP: HOWARD BOL4N C~SING TYPE FLUIO DENSITY VISCOSITY PH FLUID LOSS MATRIX SANg = 9.623" @ 3176.0' - BIT SIZE : 8.5" TO 7249.0' = LOW SOLIDS : .10.00 LB/G RM : 5.920 @ 53.0 DF : 33.0 S RMF : 5.500 @ 52.0 D~ : 9.0 RMC : 3.690 ~ 6~.0 DF = 9.4 C3 RM AT BHT = 2.337 @ 1~5. DF LVP OlO.H02 VE~IFICATIDN LISTING PAGE 3 THIS O.~TA HAS NOT .~EEN DEPTH SHIFTED- OVERLAYS FIELD PRINTS ~-~','-'~.,~ SCHLUMB=RGER L~GS INCLUDE~ WITH THIS MAGNETIC TAPE: DU~L INDUCTION SPHERICALLY FOCUSED LOG (DIL) OAT~. ~VAILABLE: 7238.0' TO 3176.0' FORMATION DENSITY COMPENSATED LeG (FDN) COMPENSATED NEUTRON LOG CFDN) DATA .~VAILABLE: 7212.0' 'TO 4750.0' GAMMA RAY IN CASING (GR.CNL) DATA AVAILABLE: 3180.0' TO 1948.0' ~ DATA FORMAT RECORD ~ ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 ~ i 66 1 8 ~ 73 60 9 4 65 .liN LVP OlO.H02 VERIFiCA'TION LISTING 16 1 65 ! 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT ID ORDER ~ OEPT FT SFLU DIL OHMM ILM OIL CHMM !LO DtL OHMM SP OIL MV GR DIL GAPI GR FDN GAPI 'CALI 'FON IN RHOB FDN G/C3 ORH'O FON G/CS NRAT FDN RNR~ FDN NPHI FDN PU NCNL FDN CPS FCNL FDN CPS GR CNL GAPI APi 4PI AP1 AP1 FILE LOG TYPE CLASS MOD NO. O0 000 O0 0 0 O0 220 O1 0 0 O0 1ZO 44 0 0 O0 120 46 0 0 O0 010 O1 0 0 O0 310 O1 0 0 O0 310 01 0 0 O0 280 O1 0 0 O0 350 02 0 0 O0 356 O1 0 0 O0 4.20 O1 0 0 O0 000 O0 0 O0 890 O0 O. 0 O0 330 31 0 0 0,0 330 30 0 0 O0 310 Ol 0 0 DATA DEPT 7269.0000 SFLU SP -36.3945 GR RHOB 1.4395 DRHO NPHi 45.0684 NCN'L OEPT 7200.0000 SFLU SP -27.5~20 GR RHOB 2.2483 DRHO NPHI 45.7520 NCNL DEPT ?100.0000 SFLU SP -28.5420 GR RHOB 2.4182 DRHO NPHI 34.4727 NCNL DEPT 7000.0000 SFLU SP -48.3945 GR RHOB 2.2717 DRHO NPHI 32.~707 NCNL DEPT 6900.0000 SFLU SP -48.0508 GR RHOB 2.4397 DRHO NPHi 31.0547 N,CNL DEP'T 6800.0000 SFLU SP -2'7.1514 SR RHOB 2.3284 DRHO NPHI 50.5859 NCNL 3.5374 ILM 121.0273 GR -0.0054 NRAT 1868.6875 FCNL 2.8831 ILM 120.2148 GR 0,.0771 NRAT 1843.6875 FCNL 4.7468 ILM 94.3398 GR 0.0112 NRAT 2079.5000 FCNL 32. 6992 iLM 59. 3555 GR 0.0005 NRAT 2629. ,5000 FCNL 18.7393 ILM 58.2617 GR -0.0034 NRA'T 2313.5000 FCNL 1.6006 ILM 113.0898 GR 0.0181 NRAT 1822..6875 FCN:L SIZE 4 4 4 4 4 4 4 4 4 SPL 1 1 I i 1 1 1 1 I 1 1 I 1 1 1 2.9592 121.0273 3.6018 4?:4.8906 2.5667 120.2148 .3.5999 427.3906 4.6453 94.3398 3.0002 67il.3125 25.8018 59.3555 2.8655 801.8125 14.94'73 58.2617 2.7756 768.3125 1.7755 1!3.0898 4.0320 ,~"~.8906 REPR CODE 68 68 68 68 68 68 68 68 68 68 68 6.8 68 68 68 68 ILO CALI RNRA GR ILD CALI RNRA GR ILD CALI RNRA GR ILO CALi RNRA GR ILO CA:LI RNR4 GR ILD CALi RNRA GR P ( 00000000 00000000 00000000 00000000 00000000 00000000 00000000 000000'00 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 2 8 3 -999 2 8 4 -99 9 4 8 3 -999 26 8 3 -999 13 8 3 -999 1 10 4 '-999 ROCES OCTAL 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 .5784 .5020 .9338 .2500 .6292 .0175 .3132 .2500 .5476 .0959 .2500 .7549 .025~ .2776 .2500 .939.5 .0488 .0100 .2500 .6299 .0645 .2898 .2500 LVP OlO.H02 VERIFiCaTION LISTIN~ PAGE 5 DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RH08 NPHi 9EPT SP RHOB NPHI OEPT SP RHOB NPHI DEPT RHOB NPHI DEPT SP RHOB NPHI OEPT SP RH08 NPHI DEPT RHOB NPHI DEPT SP RHOB NPH1 DEPT SP 6700.0000 SFLU -30.370! GR 2.4319 DRHO ~4.6777 NCNL 6500.0000 SFLU -33.4258 GR -999.2500 DRHO -999.2500 NCNL 6500.0000 SFLU -33.6133 GR -999.2500 9RHO -999.2500 NCNL 6400.0000 SFLU -38.7,383 GR -999.2500 DRHO -999.2500 NCNL 6300.0000 SFLU -37.8,533 GR -999.2500 DRHO -999,2500 NCNL 6200.0000 SFLU -38.6758 GR -999.2500 ORHO -999.2500 NCNL 6100.0000 SFLU -41.5195 GR ,-999.2500 DRHO -999.2500 NCNL 6000.0000 SFLU -54.8008 GR -999.2500 DRHO -999.2500 NCNL 5900.0000 SFLU -5!.0195 GR -999.2500 DRHO -999.2500 NCNL 5800.0000 SFLU -39.9883 GR -999,2500 DRHO -999.2500 NCN,L 5700.0000 SFLU ,-44.6445 GR -999.2500 DRHO 2.4377 ILM 114.4023 GR 0.0278 NRAT 1824.68T5 FCNL 2.9319 ILM 143.8125 GR -999.2500 NRAT -999.2500 FCNL 4.6726 ILM 257.3906 GR -999.2500 NRAT -99'9.2500 FCNL 4.0437 ILM 166.1875 GR -9'99.2500 NRA'T -99'9.2500 FCNL 3.5081 ILM i61.0625 GR -999.2500 NR4T -999.2500 FCNL 3.2444 ILM 123.9023 GR -999.2500 NRA'T -999.2500 F'CNL 4.7390 ILM 100.9648 GR -999.2500 NRAT -999.2500 FCNL 4.9148 ILM 96-7148 GR -999.2500 NRA'T -999.2500 FCNL 5.7390 ILM 84.9548 GR -999.2500 NRA'T -999.2500 FCNL 2.8'948 iLM 104.5898 GR -999.2500 NR4T -999.2500 FCNL 3.297! I'LM 108.7773 GR ,-999,2500 NRAT 2.2932 ILD 114.4023 CALI 3.6663 RNRA 443.8906 GR 2.5452 ILK -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.3420 ILD -999.2500 CALi '999.2500 RNRA -999.2500 GR 3.4983 ILO -999.2500 CALI -999.2500 RNRA -ggg, 2:500 GR 3.1721 1LD -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.1096 ILD -999.2500 CALl -999.2500 RNRA -999.2500 GR 4.3835 iLD -999.2500 CALl -999,2500 RNRa -999.2500 GR ~.0'789 D _999.2:500 ~L ~:LI -999.2500 RNRA -999.2S00 GR 5.6101 ILD -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.0374 ILD -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.1350 iLO -999.2500 CALI -9'99.2500 RNRa 2.2092 9.5332 4.1101 -999.2500 2.5081 -999.2500 -999.2500 -999.2500 3.2737 -999.2500 -9'99.2500 -999.2500 3.5,276 -999.2500 -999.2500 -999.2500 3.1506 -999.2500 -999.2500 -999.2500 3.0374 -999.2500 -999.2500 .-999.2500 4.2625 -999.2500 '-999.2500 -999.2500 3.6936 -999.2500 -999.2500 -999.2500 4.7937 -999.2500 '-999.2500 -999.250,0 3.0685 -999.2500 -999.2500 -999.2500 3.1389 -999.2500 -999.2500 LVP OlO.H02 VERIFICA'TION LISTING PAGE NPHI DEPT SP NPHi DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI OEPT SP RHOB NPHI OEPT SP RHOB NPHI OEPT SP RHOB N PHI SP RHOB NPHI DEPT SP -999.2500 NCNL 5600.0000 SFLU -36.6445 GR · -999.2500 DRHO -999. 2500 Nr~NL 5500.0000 SFLU -34.'7070 GR -999.2500 DRHO -999.2500 NCNL 5400,0000 SFLU -36.1133 GR -999.2500 DRHO -999.2500 NCNL 5300.0000 SFLU -53.5195 GR 2.4045 DRHO 42.1875 NCNL 5200.0000 SFLU -36.3008 GR 2.3186 DRHO 48.3398 NCNL 5100.0000 SFLU -36.0820 GR 2.3401 DRHO 44.9219 NCNL 5000.0000 SFLU -36.9570 GR 2.3538 DRHO 40.673~ NCNL 4900.0000 SFLU -42.6758 GR 2.3713 DRH3 40.0391 NCNL 4800.0000 SFLU -37.2383 GR 2.3362 DRHO 42.4316 NCNL 4700.0000 SFLU -37.6758 GR -999.2500 DRHO -999.2500 NCNL ~600.0000 S~LU -38..4255 GR -999.2500 FCNL 2.8733 ILM 104.9023 GR -999.2500 NRAT -999.2500 FCNL 3.2385 ILM 128.4375 GR -999.2500 NRAT -999.2500 FCNL 2.1721 ILM 120.7773 GR -999.2500 NRAT -999.2500 FCNL 4.0789 iLM 130.6875 GR 0.0322 NRAT 1728.6875 FCNL 1.6182 ILM 165.4375 GR O. 0176 NRAT 1789.6875 FCNL 1.5587 ILM 143.3125 GR -0.0039 NRAT 1904.6875 FCNL 2.1135 ILM 1~48'I875 GR 0.0137 NRAT 2032.68 75 FCN'L 3.7073 iLM 173.68'75 GR 0.031'7 NRAT 1927.6875 FCNL 2.1135 ILM 122.8398 GR 0.0117 NR4T 1865.6875 FCNL 2,6'936 ILM 83.0898 GR '-999,,,2500 NRAT -999.2500 FCNL ,2.5471 ILM 87.4023 GR -999.2500 GR 3.0491 ILD · -999.2500 CALI -9~9.2500 RNRA -999.2500~ GR 2.5413 ILD -999.2500 CALI -999.2500 RNRA -999.2500 GR 2.0979 ILD -999.2500 CALi -999.2500 RNRA -999.2500 GR 3.9,299 ILD 130.6875 CALI 3.5139 RNRA 496.1406 GR 2.7424 ILO 165.4375 C4LI 3.7542 RNR4 433.3906 GR 1.8340 ILO 3125 CALI 14:5901 RNRA 456~1406 GR · t875 CALI 3.~362 RNRA 540. 1 25 GR 3.2874 ILD 1'73.6875 ,CALI 3.3538 RNRA 4~6.1406 GR 2.2502 ILO 12:2.8398 CA'LI 3.451,4 RNRA 470.6406 GR 2.7952 ILD -999.2500 CALI -999. 2500 RNRA -999.2500 GR 2.6643 ILO -999.2500 CALZ -999.2500 3.033~ -999.2500 -999.2500 -999.2500 2.4709 -999.2500 -999.2500 -999.2500 2.0764 -999.2500 -99'9.2500 -999.2500 3.8948 9.3379 3.4827 -999.2500 2.5393 8.1738 4.1295 -999.2500 1.8809 8.4473 4.1726 -999.2500 2.3987 8.1660 3.7581 -999.2500 3.2776 8.8223 3.96'51 -999.2500 2.2776 8.4238 3.9631 -999.2500 2.8596 -999.2500 -999.25:00 -999.2500 2.7092 -999.2500 LVP OlO.HO2 VERIFICATION ~-ISTING PAGE T RH05 -999.2500 DRHO NPHI -999,2500 NCNL DEPT 4500,0000 SFLU SP -38,4883 GR RHOB -999,2500 DRHO NPHZ -999,2500 NCNL SEPT ~400,0000 SFLU SP -40,!758 GR RHOB -999,2500 DRHD NPHI -999,2500 NCNL DEPT 4300,0000 SFLU SP -40,2383 GR RH08 -999,2500 DRHO NPHI -999.2500 NCNL DEPT 4200,0000 SFLU SP -41,9883 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNL DEPT 4100,0000 SFLU SP -42,8008 GR RHOB -999,2500 DRHg NPHI -999,2500 NCNL DEPT 4000,0000 SFLU SP -44,9883 GR RHOS -999,2500 DRHO NPHI -999,2500 NCNL DEPT 3900.0000 SFLU SP -42,8005 GR RHOB -999,2500 9RHO NPHI -999,2500 NCNL DEPT 3800.0000 SFLU SP -43.8633 GR RHOB -999.2500 DRHO NPHI -999,2500 NCNL OEPT 3700.0000 SFLU SP -44,988,3 GR RHOB -999,2500 ORHO NPHI -999,2500 NCNL OEPT 3600.0000 SFLU SP -45,3320 SR RHOB -999,2500 DRHO NPHI -999,2500 NCNL DEPT 3500.0000 SFLU '-999,2500 NRAT -999.2500 FCNL 2,4,573 ILM 79,5895 GR -999,2500 NRAT -999,2500 FCNL 2,3225 'ILM 81,4023 GR -999,2300 NR4T -999,2.500 FCNL 2,4807 ILM 100,2148 GR -999,2500 NR4T -999,2500 FCNL 2,3518 iLM 93,9648 GR -999,2500 NRAT -999,2500 FCNL 2.1956 ILM 132.6875 GR -999,2500 NRAT -999,2500 FCNL 2,3538 ILM 123,3398 GR .-999,2500 NRAT .-999,2500 FCNL 2,8264 ILM 95,46~8 GR -999°2500 NRAT -999,2500 FCNL 3,7522 ILM 101.,4023 GR -999,2500 NRAT -999,2500 FCNL 3,6838 ILM I 05. 8398 GR -999,2500 NRAT -999.2500 FCNL 4,9617 ILM 100,4023 GR -999,2300 NRAT -999,2500 FCNL 3,6174 ILM -99'9,2500 RNRA -999,2500 GR 2,4953 ILO -999,2500 CALI -999,2500 RNRA -999,2500 GR 2,6155 ILO -999,2~00 CALI -999,2500 RNR~ -999,2500 GR 2,66.24 ILO -999,2.500 CALI -999,2500 RNRA -999,2500 GR 2,6545 ILO -999,2500 CALI -999,25D0 RNRA -999,2500 GR 2,7854 ILO -999,2500 CALI -999,2500 RNR~ -999,2500 GR 2,5569 'ILO -999,2500 CALi -999,2500 RNRA -9'99.25'00 GR 3,1838 ILO -999,2500 CALi -999,2500 RNRA -999,2500 GR 4,0789 ILO -999,2500 CALI -999,2500 RNRA -999,:2500 GR 4'0095 ILO -999,2500 CALI -999,.2500 RNRA -999.2500 GR 5.2625 ZLD -999,2500 CALI -999,2500 RNRA -999-2500 GR 3,8889 ILO -999,2500 -999,2500 2.5471 -999,2500 -999,2500 -999,2500 2,7092 -999,2500 .-999.2500 -999,2500 2.7229 -999.2500 -999.2500 -999.2500 2,7385 -999,Z500 .-999,2500 -999,2500 3.0022 -999.2500 ,-999,2500 -999.2500 2.6624 -999.2500 -999.2500 -999,2500 3,9612 -999,2500 -999,2.500 -999,2500 4,2546 -999,Z500 -999.2500 -999,Z500 ~.1804 -99'9.2500 -999,.2500 -999.2500 5.5125 -999,2500 '-9'99,2500 4.0906 LVP OlO.H02 VERIFICATION LISTING P~GE 8 SP -42.7383 GR RHOB -999,2500 DRHD NPHI -999,2500 NCNL OEPT 3400,0000 SFLU SP -40.1445 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNL OEPT 3300.0000 SFLU SP -44.6133 GR RHOB -999.2500 DRHO NPHI -999.2300 NCNL OEPT 3200,0000 SFLU SP -45,8008 GR RH08 -999,2300 DRHO NPHI -999,2500 NCNL DEPT, 3100,0000 SFLU SP -999,2500 GR RHOB -999,2500 DRHO NPHZ -999.,2500 NCNL DEPT 3000.0000 SFLU SP -999.2500 GR RHOB -999,2500 DRHD NPHI -999.2500 NCNL OEPT 2900,0000 SFLU SP -999,2500 GR RHO8 -999,2500 ORHO NPHI -999.2500 NCNL DEPT 2800,0000 SFLU SP -999,.2500 GR RHOB -999,2500 ORHO NPHI -999.2500 NCNL OEPT 2700,0000 SFLU SP -999,2500 GR RHO8 -999,2500 ORHO NPHi -999.2500 NCNL OEPT 2600.0000 SFLU SP -999,2500 GR RHOB -999,2500 DRHO NOHI -999.2500 NCNL DEPT 2500,0000 SFLU Sm -999,2500 GR RHOB -999.2500 DRHD NPHI -999.2500 NCNL 102,2148 GR -999,2500 NRAT -999,2500 FCNL 3,9944 ILM 101,3398 GR -999,2300 NRAT -999,2500 FCNL 5,2703 ILM 84.7773 GR -999,2500 NRAT -999,2500 FCNL 5,4773 ILM 81,0.273 GR -999,2300 NRAT -999,2500 FCNL -999,2500 ILM -999,2500 GR -999,2500 NRAT -999.2300 FCNL -999,2500 ILM -999,2500 GR .-9'99,2500 NRAT -999.2500 FCN:L '-999,2500 ILM -999,2,500 GR -999,2500 NRAT -999.2500 FCNL -999.2500 iLM -999.2500 GR -999.2500 NRAT -999,2500 FCNL -999,2500 ILM -999.2500 GR -999-2500 NRAT -999.2500 FCNL · -999.2500 ILM -999,2500 GR -999.2500 NRAT -999,.2500 FCNL -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 FCNL -'999.2500 CALI -999.2500 RNRA -999,2500 GR 3,8772 ILD -999,2500 CALi -999,2500 RNRA -999,2500 GR 5.7312 ILD -999,2500 CALI -999,2500 RNRA -999.2500 GR 5,8250 I.LD -999.2500 CALI -999,2500 RNRA -999,2500 GR -999.2500 ILD -999.2500 CALl -999.2500 RNR~ -9!99.2,500 GR -999.2500 ILD -999,2500 CALI -999,2500 RNRA -999.2,500 GR -999,2500 ILD -999,2500 CALl -999,2500 RNRA -999,2500 GR -999,2500 !LD -999.2500 CALI -999.2500 RNRA -9'99.2500 GR -999,2500 ILD -999,2500 CALi -999,2500 RNRA -999.2500 GR -999,2500 ILD -999,2500 CALI -999.2500 RNR~ -99'9.250.0 GR -999,2500 ILD ,-999.2300 CALI -999,2500 RNRA -999.2500 GR -999.2300 -999,2500 -9'99,2500 4.0789 -999.2500 -999.2500 -999.2500 5.9968 -999,2500 -999.2500 -999.2500 7.0085 -999.2500 -999.2500 76. '7773 -999.2500 -999.2500 -999.2500 56.5117 -999.2500 -999.2500 -999.2500 64.4023 -999.2500 -999.2500 -999.2500 60.2930 -999.2500 -999.2500 -999.2500 50.7617 '-999.2500 -999.2500 -999'2500 36.7930 -999.2500 -999,2500 -999.2500 50,6680 -999,2500 -999,2500 '-999,2500 41,324.2 LVP OiO.HOZ VERIFICATION LISTING PAGE 9 DEPT 2400.0000 SFLU SP -999.2500 GR RHO$ -999.2500 DRH~ NPHI -999.2500 NCNL DEPT 2300.0000 SFLU SF -999.2500 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 2ZO0.O000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO NPHI -999,2500 NCNL DEPT ZlO0.O000 SFLU SP -999.2500 GR RHDB -999,2500 DRHO NPHI -999.2500 NCNL OEPT 2000,0000 SFLU SP -999.2500 GR RHOB -999..2500 DRHO NPHZ -999,2500 NCNL DEPT 1948,0000 SFLU SP -999.2500 GR ~HOB -999.2500 DRHO NPHI -999.2500 NCNL -999.2500 ILM -999,2500 GR -999.2500 NRAT -999,2500 mCNL -999.2500 ILM -999.2500 GR -999.2500 NRAT -999,2500 FCNL -999,2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILM -999.2500 GR -999,2500 NRAT -999.2500 FCNL -999,2500 ILM -999.2500 GR -999,2500 NRAT -999.2500 FCNL -999,2500 ILM -9'99.2500 GR -999.2'500 NRAT -999,2500 ~CNL ¢~ FILE 'TRAILER PILE NAME :EDIT .001 SERVICE NAME VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : ,~ T~PE TRAILER SERVICE NAME :EDIT DATE :85/10/30 ORIGIN :0000 TAPE NAME :091,2 CONTINUATIDN ~ :01 NEXT 'TAPE NAME : COMMENTS :LIBRARY TAPE REEL TRAI,LER ~- -999.2500 iLO -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILD -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILD -999,2500 CALI -999.2500 RNRA -999,2500 GR -999,2500 ILD -999,2500 CALl -999.2500 RNRA -999,2500 GR -999,2500 iLD -999,250'0 CALI -999,2500 RNRA -999.2500 GR -999.2500 ILO ,-999,2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 -999.2500 -999.2500 ~4.3867 -999.2500 -999.2500 -999.2500 27.0830 -999.2500 -999.2500 -999.2500 60.7617 -999.2500 --999.:Z500 -999.2500 32.1055 -999.2500 -999.2500 -999.2500 45.1387 -999,2500 -999,2500 -999.2500 35,5430 LVP OlO.H02 VERIFICATION LISTING PAGE 10 SERVICE NAME :EDIT DATE :85/10/30 ORIGIN : REEL NAME :1~9Z~6 CONTINUATION ~ :01 NEXT RE~L NAME : COMMENTS :LIBRARY TAoE