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198-234
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 4, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Q-07A KUPARUK RIV UNIT 1Q-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/04/2025 1Q-07A 50-029-21234-01-00 198-234-0 W SPT 5977 1982340 1500 2600 2600 2600 2600 25 25 25 25 4YRTST P Guy Cook 7/2/2025 Test completed with a Little Red Services pump truck and calibrated gauges. 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 1Q-07A Inspection Date: Tubing OA Packer Depth 670 1800 1720 1720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250701125325 BBL Pumped:1.2 BBL Returned:1.2 Monday, August 4, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, July 15, 2021 P.I. Supervisor '(�� ( SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IQ -07A FROM: Brian Bixby KUPARUK RIV UNIT 1Q -07A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv�� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q -07A : API Well Number 50-029-21234-01-00 Inspector Name: Brian Bixby Permit Number: 198-234-0 Inspection Date: 7/12/2021 Insp Num: mitBDB210713095056 Rel Insp Num: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5977 - Tubing 2350 - 2354 2350 - 2350 1500 IA 810 1800 1730 1720 I OA 30 30 30 30 P Thursday, July 15, 2021 Page I of 1 Packer Well IQ -07A Type Inj V. TVD PTD 1982340 ;TypeTest SPT' Test psi BBL Pumped: ! 1 - 1BBL Returned: Intervale 4YRTST P/F Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5977 - Tubing 2350 - 2354 2350 - 2350 1500 IA 810 1800 1730 1720 I OA 30 30 30 30 P Thursday, July 15, 2021 Page I of 1 STATE OF ALASKA ALAPA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ® Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: AC/0 $17il4 if LAr i1 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 198-234 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number: 99510 50-029-21234-01 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 25641 KRU 1Q-07A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: • Total Depth measured 9,776 feet Plugs measured None EI tECE'VE® true vertical 6,277 feet Junk measured None feet SEP 0 5 2017 Effective Depth measured 6,762 feet Packer measured 7,239 feet true vertical 6,274 feet true vertical 5,978 feetA0GCC Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 feet 16 " 108'MD 108 TVD SURFACE 3,680 feet 9 5/8" 3,715' MD 3524 TVD PRODUCTION 7,507 feet 7 7,541'MD 6184 TVD LINER 2,525 feet 2 3/8" 9,764'MD 6275 TVD Tubing(size,grade,measured and true vertical depth) 3.5" J-55 7,268' MD 5,998'TVD Packers and SSSV(type,measured and true vertical depth) PACKER- BAKER RETRIEVABLE PAC 7,239'MD 5,978'TVD SAFETY VLV-Camco TRDP-IA-SSA(C 1,800'MD 1,800 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED Treatment descriptions including volumes used and final pressure: DEC 0 5 20_17 • 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 463 800 2285 Subsequent to operation: 0 0 693 650 2394 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil p Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG e GINJ 0 SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-258 Authorized Name: Jason Burke Contact Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer Authorized Signature. Date: Vail Contact Phone: (907)265-6097 — VTL to/l7-/i7 Form 10-404 Revised 4/2017 i'�f "�" ! 7 r,7.) -. 0 (�17 RBDNIS L Submit Original Only ' • • Well Header 1Q-07 Daily Operations Start Date Legal WellName Last 24hr Sum RIH WITH JSN, LOCK UP AT 8777.3' CTMD, LAY IN 100 BBLS ACID TO 7239' CTMD, POOH. PERFORM WEEKLY BOP TEST ****JOB 8/3/2017 1Q-07 COMPLETE**** KUP I IQ-07A IConoc1Phiilips 9. Well Attribut Max Angle TD Wellbore API/UWI Field Name Wellbore Status not ) MD ftKB Act Btm(ftKB) C:pnocaPhidips AI k Inc. 500292123401 KUPARUK RIVER UNIT INJ 99.40 9,481.99 9,776.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-07A,9/5/20174.28.01 PM SSSV:TRDP Last WO: 8/11/1990 41.49 2/15/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 7,789.0 10/6/2006 Rev Reason:FORMAT UPDATE Imosbor 4/3/2011 ItCasing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.652 37.0 108.0 108 0 62 50 H-40 WELDED HANGER,335v. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I SURFACE 9 5/8 8.697 35.5 3,715.4 3,524.5 36.00 J-55 BTC 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread J _? PRODUCTION 7 6.500 33.7 7,541.0 6,184.4 26.00 J-55 BTC I Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Y WINDOW 7 6.250 7,491.0 7,498.0 6,156.7 sums......o,,,,,,,,,,,,,,,,,,uu,.,., 1 .L o.,.,,,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 2 3/8 1.995 7,239.0 9,763.7 4.43 L-80 FL4S CONDUCTOR;37.0-108.0 Liner Details Nominal ID Top(ftKB) Top(TVD)(ORB) Top Incl C) Item Des Com (in) 7,239.0 5,977.8 45.76 DEPLOY DEPLOYMENT SLEEVE 1.969 r1 9,731.4 6,267.0 77.27 0-RING 0-RING SUB 1.901 SAFETY VLV;1,800.3 f'"1 r: Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.992 33.5 7,267.7 5,997.8 9.30 J-55 EUE MOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top(noir) Item Des Com (in) 33.5 33.5 0.02 HANGER CIW(McEvoy)Gen II Tbg Hgr.w/double pin pup 2.992 1,800.3 1,800.2 0.95 SAFETY VLV Camco TRDP-1A-SSA(CLOSED FLAPPER) 2.812 7,225.5 5,968.3 45.75 PBR Baker PBR W/10"STROKE 3.000 SURFACE;35.5-3,715.4-06 7,239.2 5,977.9 45.76 PACKER BAKER RETRIEVABLE PACKER 2.890 7,255.5 5,989.3 45.76 NIPPLE CAMCO'D'NIPPLE 2.750 7,266.9 5,997.3 45.76 SOS Baker SOS 2.992 GAS LIFT;7,101.2 Perforations&Slots Shot Dens Top(TVD) Btm CI-VD) (shots/ III Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 7,877.0 7,992.0 6,305.2 6,311.9 A-5,A-4,10- 12/21/1998 4.0 IPERF 07A PBR;7,225.5 8,064.0 8,142.0 6,310.8 6,312.0 A-4,1Q-07A 12/21/1998 4.0 (PERF 8,219.0 8,879.0 6,316.9 6,309.7 A-3,1Q-07A 12/21/1998 4.0 IPERF PACKER;7,239.2 8,931.0 9,059.0 6,306.7 6,299.0 A-3,1Q-07A 12/21/1998 4.0 IPERF • 1-iDi t Anwa I 1 9,149.0 9,300.0 6,294.2 6,284.8 A-3,A-4,A-3, 12/21/1998 4.0 IPERF 1Q-07A ME NIPPLE;7,255.5 9,330.0 9,422.0 6,282.7 6,276.8 A-3,A-4,A-3, 12/21/1998 4.0 IPERF ilt A-5,1Q-07A Mandrel Inserts SOS;7,266.9 5St ah on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 7,181.2 5,937.4 Merle TPDX 1 1/2 Gas Lift DMY RM 0.000 0.0 403/2000 WINDOW;7,491.0-7,498.0 Notes:General&Safety End Date Annotation PRODUCTION;33.7-7,541.0 12/15/1998 NOTE.CTD SLIMHOLE HORZ SIDETRACK 7/18/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 - 11.- IPERF;7,877.0-7,992 0 IPERF;8,064.0-8,142.0-. IPERF;8,219.0-8,879 0-. .- IPERF;8,931.0-9,059.0 IPERF;9,149.0-9,300.0 IPERF;9,330.0-9,422.0 0 , L LINER;7,239.0-9,763.7 4 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,July 17,2017 P.I.Supervisor i E'( 7 f j 7 SUBJECT: Mechanical Integrity Tests l l7 CONOCOPHILLIPS ALASKA,INC. 1Q-07A FROM: Guy Cook KUPARUK RIV UNIT 1Q-07A Petroleum Inspector Src: Inspector Reviewed ByY. P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-07A API Well Number 50-029-21234-01-00 Inspector Name: Guy Cook Permit Number: 198-234-0 Inspection Date: 7/15/2017 Insp Num: mitGDC170716141759 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Q-07A Type Inj W 'TVD 5977 ' Tubing 2400 2400 2400 • 2400. PTD 1982340 • Type Test SPT Test psi 1500 - IA 535 1800 - 1720 1700 BBL Pumped: 1.3 ` BBL Returned: 1.2 OA 330 350 350 350 Interval 4YRTST P/F P Notes: SCANNED SEP 2 52017, Monday,July 17,2017 Page 1 of 1 • of • • THE STATE Alaska Oil and Gas 0 j\. Conservation Commission 1 Sr1E_ 333 West Seventh Avenue r ^R GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Q. Main: 907.279.1433 ALAS1/ Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke SCANNED JUL 0 62017, Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1Q-07A Permit to Drill Number: 198-234 Sundry Number: 317-258 Dear Mr. Burke: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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, ia9121'\ Cathy P Foerster Chair DATED this Pr, day of June, 2017. RBDMS Jttd L 6 2617 !RECEIVED • • STATE OF ALASKA nJUN 1 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION ,✓J s C/2.42 l ( 7 APPLICATION FOR SUNDRY APPROVALS AOGO{ 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Acid Stimulate(] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 198-234 ' 3.Address: Stratigraphic ❑ Service 2. 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21234-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1Q-07A ' Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25641 - Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,776' 1 6,277' * 9762' 6274 • 2577psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 71' 16" 108' 108' Surface 3,680' 9 5/8 3,715' 3,524' Production 7,507' 7" 7,541' 6,184' Liner 2,525' 2 3/8 9,764' 6,275' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7877-7992,8064-8142,8219- 6305-631,6311-631,6317- 3.500" J-55 7,268' 8879,8931-9059,9149-9300 6310,6307-6299,6294-6285, 9330-9422 ' 6283-6277 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER RETRIEVABLE PACKER • MD=7239 TVD=5978 SAFETY VLV-Camco TRDP-1A-SSA(CLOSED FLAPPER) 4 MD=1800 TVD=1800 12.Attachments: Proposal Summary 0 Wellbore schematic LI 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service LI i 14.Estimated Date for 7/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG lI ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not - be deviated from without prior written approval. Authorized Name: Jason Burke Jason Burke Contact Name: Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com Contact Phone: (907)265-6097 Authorized Signature: . �/ Date: 7 j �_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t-I.... 2575._ Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No l Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: to 4 0 4 RDDNJS r� I.L Ji;lr [ 62017 APPROVED BY Approved by: ,, st..f.044.4____ COMMISSIONER THECOMMISSIONDate: /`J�M 6/iti s-, 1.040 po ACi vtt ,o/�gl� 7C// I ApO I / 11 L� Subin Form and Form 10-403 Revised 4/2017r d 666 I O Ild for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska,Inc. Nov Drilling&Wells ConocoPhillips Well Intervention Alaska 1Q-07 Acid Treatment (TBD) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars,perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to increase injectivity 1 • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU 1.5" CT, MU 5 port wash nozzle BHA 2. Begin RIH, enter slotted liner completion at 7239' MD. 3. Continue RIH until TD 9731' MD is reached or until CT locks up 4. When CT has reached ultimate depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH at a rate that will allow treatment to be spotted from final depth to 7239' MD (At 9731' MD 100 bbl/1 BPM=100 min & 2492 ft/ 100 min=25 fpm). Chase the DAD treatment out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 5. After an additional 5 bbl of fluid has been injected behind the treatment POOH 6. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal June 7, 2017 1Q-07 Well Work Procedure Page 1 of 1 z KUP di 1Q-07A Con©coPhillips a„um Well Attribu Max Angle D TD AI ISI4c:.Incw411F Wellbore API/WI UField Name Wellbore Status ncl(.1 MD(ftKB) Act Btm(ftKB) CacoPhihipc 500292123401 KUPARUK RIVER UNIT INJ 99.40 9,481.99 9,776.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1Q-07A,6/14/2017 2:26:41 PM SSSV:TRDP Last WO: 8/11/1990 41.49 2/15/1985 Verhoal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 7,789.0 10/5/2006 Rev Reason:FORMAT UPDATE Imosbor 4/3/2011 'll-r! Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread (E CONDUCTOR 16 15.652 37.0 108.0 108.0 62.50(1-40 WELDED HANGER,33.5 Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I. Grade Top Thread SURFACE 9 5/8 8.697 35.5 3,715.4 3,524.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 3 A PRODUCTION 7 6.500_ 33.7 7,541.0 6,184.4 26.00_J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread WINDOW 7 6.250 7,491.0 7,498.0 6,156.7 ,e,,.,,,.,,u«u.,,,,,i,n,,,.i,,.i,�,,,,,i.,,ei,„ .� a 11,6,1,.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).. Wt/Len(I .Grade Top Thread LINER 2318 1.995 7,239.0 9,763.7 4.43 L-80 FL4S CONDUCTOR;37.0-108.0 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,239.0 5,977.8 45.76 DEPLOY DEPLOYMENT SLEEVE 1.969 SAFETY VLV,1,800 3 9,731 4 6,267.0 77.27 0-RING 0-RING SUB 1.901 rte€??•;, Tubing Strings Tubing Desorption String Ma...ID tin) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(113/ft) Grade Top Connection TUBING 31/2 2.992 33.5 7,267.7 5,997.8 9.30 J-55 EUE MOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl)) Item Des Com (in) 33.5 33.5 0.02 HANGER CIW(McEvoy)Gen II Tbg Hgr.w/double pin pup 2992 1,800.3 1,800.2 0.95 SAFETY VLV Camco TRDP-1A-SSA(CLOSED FLAPPER) 2.812 I 7,225.5 5,968.3 45.75 PBR Baker PBR W/10"STROKE 3.000 SURFACE;35.53,715.4 '� Fa 7239.2 1977.9 45.76 PACKER BAKER RETRIEVABLE PACKER 2.890 7,255.5 5,989.3 45.76 NIPPLE CAMCO'D'NIPPLE 2.750 7,266.9 5,997.3 45.76 SOS Baker SOS 2.992 GAS LIFT;7,181.2 Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 7,877.0 7,992.0 1305.2 6,311.9 A-1 A-4,10- 12/21/1998 4.0 (PERF 07A PBR,7,225 8,064.0 8,142.0 6,310.8 6,312.0 A-4,1Q-07A 12/21/1998 4.0 (PERF 8,219.0 8,879.0 6,316.9 6,309.7 A-3,1Q-07A 12/21/1998 4.0 IPERF PACKER.7239.2 11 14 8,931.0 9,059.0 6,306.7 6,299.0 A-3,1Q-07A 12/21/1998 4.0 IPERF 1-1"Ejt 9,149.0 9,300.0 6,294.2 6,284.8 A-3,A-4,A-3, 12/21/1998 4.0 IPERF 1Q-07A NIPPLE.7,2555 _ 9,330.0 9,422.0 6,282.7 6,276.8 A-3,A-4,A-3, 12/21/1998 4.0 IPERF A-5,1Q-07A Mandrel Inserts SOS,7.266.9 St ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1 7,181 2 5,937.4 Meda TPDX 1 1/2 Gas Lift DMY RM 0.000 0.0 4/13/2000 WINDOW;7,4910-7,498.0 • Notes:General&Safety End Date Annotation PRODUCTION,33.7-7,541.0 12/15/1998 NOTE.CTD SLIMHOLE HORZ SIDETRACK 7/18/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 IPERF;7,877.0-7,992.0 -.in la -...t - IPERF;8,064.0-0,t42.0-. -.... ►- - IPERF;8,219.0-8,879.0 IPERF;8,931.0.9,058.0 IPERF,9,149.0-9,300.0 i - IPERF,9,330.0-9,422.0 gI tl LINER; .0-9 L E ,239 ,783.7 Agl La WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize materia] and digital information available for this individual Well History file and \\leather or not it is available in the LaserFiche tÌ le. Please insure that it remains as the first page in this file. I-fL .ßten History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Other # Yes No Yes No Yes No Mud Logs # General Notes or Comments about this file. Ifany of the infonnation listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433. or email us at: AOGCC - Librarian@admin.state.ak. us ~ MEMORANDUM TO: Jim Regg P.I. Supervisor ~ ~~ 7(~~'~ FROM: John Crisp Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 14, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Q-07A KUPARiJK RN LTNTT 1 Q-07A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -~+= Comm Well Name: KUPARUK RIV UNIT 1Q-07A Insp Num: miUCr090713075159 Rel Insp Num: API Well Number: 50-029-21234-01-00 Permit Number: 198-234-0 ~ Inspector Name: John Crisp Inspection Date: 7/12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~l 1Q-07A Type Inj. 'I'~ 5998 jA 100 1960 1900 1880 P.T.D 1982340 TypeTest Test psi 2000 QA 130 380 375 375 Interval 4YRTST P~ P -~ Tubing 2300 2300 2300 2300 Notes: 2.5 bbPs pumped for test.AOGCC required test pressure 1500 psi. I requested Operator to apply as much pressure as they felt comfortable with, could not move IA 500 psi above tubing pressure. --~ "4 ~ (1~:.> ~~y~; ~;t ~~ t ~ ti ., ~. s`; ,~ Tuesday, July 14, 2009 Page 1 of 1 • #~.'. C®nocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 1`~~~~3~ .~,~_a~A Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 20, 2008 and the corrosion inhibitor/sealant was pumped December 2-3, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klei 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 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 Q-01 184-231 10' 1.25 22" 11 /20/2008 6.80 12/2/2008 1 Q-04 184-234 10' 1.25 22" 11 /20/2008 3.40 12/3/2008 1 Q-07A 198-234 9' 1.10 24" 11 /20/2008 2.95 12/3!2008 1 Q-08A 197-093 8' 1.00 22" 11 /20/2008 3.40 12/3/2008 1 Q-09 184-192 2" NA 2" NA 4.25 12/2/2008 1 Q-11 184-199 4'S" 0.50 22" 11 /20/2008 4.25 12/2/2008 1Q-12 184-193 21" NA 21" NA 6.80 12/2/2008 1 Q-13 185-044 18" NA 18" NA 5.10 12/2/2008 1 Q-14 185-045 24" NA 24" NA 4.25 12/2/2008 1 Q-23 195-141 24" NA 24" NA 3.40 12/3/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Prod. to WAG ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhiIIIpS Alaska, InC. Development ^~ Exploratory ^ 198-234 / 300-095 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21234 01 7. KB Elevation (ft): 9. Well Name and Number: RKB 91' ~ 1 Q-07A " 8. Property Designation: 10. Field/Pool(s): ADL 25641 ~ ALK 2572 ~ I K ' ~ Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9776' feet true vertical 6278' feet Plugs (measured) Effective Depth measured 9732' feet Junk (measured) true vertical 6267' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 3715' 9-5/8" 3715' 3524' 3520 2020 PRODUCTION 7491' 7" 8098' 6310' 4980 4320 WINDOW 7' 7-5/8" 7498' 6157' A-SAND LINER 2521' 2-3/8" 9760' 6274' P f ti th M th d d d ' ' ' ' ' ' ' ' (~ ~ /c ' ~`~~'v C~ ' ' ' er ora on : easure ep ep : 7877 -7992 ;8064 -814 2 ;8219 -8879 ;8931 -9059 ;9149 -9300 -9422 ;9330 true vertical depth: 6305'-6312';6311'-631 2';6317'-6310';6307'-6299;6294'-6285';6283'-6276' I~A~ 2 ~ ~~08 Tubing (size, grade, and measured depth) 3-1/2", J-55, 7268' MD . Alaska Oil & Gas Cons. Commission Anchorage Packers &SSSV (type & measured depth) PKR =BAKER HB RETRV. pkr-- 7239' SSSV= SSSV SSSV= 1800' y 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 89 10 278 900 237 Subsequent to operation 369 500 2449 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 300-095 Contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz / ` ~r Title Production Engineering Technician D / ~ ~ ~ ~ Signature ~J/ /~J '~ ~'y~ ~J/ ~ Phone: 265-6471 ate ~ ~ ~ ~ ~ , , , ~ ~' v -' ~ ~ "~`~" ~' Pre aced b Sharon Allsu Drake 263-4612 Form 10-404 Revised 04/2006 - ~~~F~ a 100 S•3o.o$ Submit p~i~~- - • 1 Q-07A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/13/2000 MITIA (Initial pre conversion) passed. T/I/0=1050/520/0. Pressured up IA to 2500 psi with diesel, started MITIA, 15 minute reading-T/I/0=1100/2500/0, 30 minute reading- T/I/0=1100/2500/0. Bled IA, final T/I/0=1100/500/0 4/17/2000 Commenced WAG FOR Injection 2/14/2001 6/19/2004 Post CTD MITIA Passed @ 1990 psi (State witnessed). (/15/30 minutes: 1990/1960/1950 psi; lost 40 psi in 30 minutes. MITIA (4 year State witnessed) passed. T/I/0=1300/0/0. Pressured up IA to 2170 psi with diesel, started MITIA, 15 minute reading-T/I/0=1300/2110/0, 30 minute reading- T/I/0=1300/2090/0. Bled IA, final T/I/0=1300/0/0 1 Q-07A PTD (198-234) 10-404 corrections Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 21, 2008 3:45 PM To: NSK Well Integrity Proj Cc: Regg, James B (DOA); Fleckenstein, Robert J (DOA); NSK Prod.,E,ngr Tech;.NSK~ Problem Well Supv Subject: RE: 1Q-07A PTD (198-234) 10-404 corrections Perry, What you propose is acceptable. ~ ~ ~~0~ We look forward to the revised paperwork. ~~~~ ~~~ Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Friday, May 16, 2008 9:53 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Fleckenstein, Robert ] (DOA); NSK Prod Engr Tech; NSK Problem Well Supv Subject: iQ-07A PTD (198-234) 10-404 corrections Tom, In regard to 1Q-07A PTD # 198-234, we tracked the source of the erroneous 10-404 data back to our Oracle database and are in the process of correcting that issue. White investigating the problem we discovered a 10-403 request for sundry approval to convert from oil producer to WAG injector had been submitted in April 2000. The request was approved verbally by the commission on 4/7/2000 and in writing on 4/18/2000, sundry approval number 300-095. Our records don't indicate that the conditions of approval, subsequent MIT and 10-404, were ever returned to the state. What started CPAIs most recent 10-404, request for conversion of WINJ to WAG was the failure of 1 Q-07A to auto populate on the safety valve testing matrix. It appears as if the states database considers the well to be a water oily injector. I propose the following to close the sundry process and rectify the database discrepancies between AOGCC and CPAI. CPAI has corrected the tubing /casing errors you found in the original 10-404 and is prepared to resubmit. We have added the MIT information required by the 2000 sundry approval and subsequent state witnessed MITs since the well has been in operation as an injector. Enclosed is the MIT data from the 4/13/2000 test in AOGCC format. Please note this was pre side track and the well was 1Q-07 at that time. Packer depth at the time of the test was 5977/ 7239' with regard to TVD and MD respectively. Please respond with regard to the above proposal. Sincerely Pent' Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ~~~ ~~ ~~ 6/3/2008 ~c0 ~'. ~,i Fleckenstein, Robert J (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Friday, May 16, 2008 9:53 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Fleckenstein, Robert J (DOA); NSK Prod Engr Tech; NSK Problem Well Supv Subject: 1 Q-07A PTD (198-234) 10-404 corrections Attachments: MIT KRU 1Q-07.x1s ~~ N~® MAY 2 ~. 200 Tom, In regard to 1 Q-07A PTD # 198-234, we tracked the source of the erroneous 10-404 data back to our Oracle database and are in the process of correcting that issue. While investigating the problem we discovered a 10-403 request for sundry approval to convert from oil producer to WAG injector had been submitted in April 2000. The request was approved verbally by the commission on 4/7/2000 and in writing on 4/18/2000, sundry approval number 300-095. Our records don't indicate that the conditions of approval, subsequent MIT and 10- 404, were ever returned to the state. What started CPAIs most recent 10-404, request for conversion of WINJ to WAG was the failure of 1 Q-07A to auto populate on the safety valve testing matrix. It appears as if the states database considers the well to be a water only injector. I propose the following to close the sundry process and rectify the database discrepancies between AOGCC and CPAI. CPAI has corrected the tubing /casing errors you found in the original 10-404 and is prepared to resubmit. We have added the MIT information required by the 2000 sundry approval and subsequent state witnessed MITs since the well has been in operation as an injector. Enclosed is the MIT data from the 4/13/2000 test in AOGCC format. Please note this was pre side track and the well was 1 Q-07 at that time. Packer depth at the time of the test was 5977/ 7239' with regard to TVD and MD respectively. Please respond with regard to the above proposal. Sincerely Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 «MIT KRU 10-07.x1s» 5/19/2008 STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD (UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/1 Q-07 04/13!00 Howard Gober NA Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Q-07 Type Inj. N TVD 5,977' Tubing 1,050 1,100 1,100 1,100 Interval I P.T.D. 1982340 Type test P Test psi 1500 Casing 520 2,500 2,500 2,500 P/F P Notes: OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 10-07.x1s • • ~,. ;e i P ~ d ~ 4 S~ t.. ~ ~~ f~~ k ~Y~ 9 _r,t` ~.. C,~ ~~,~ 6,,.1 ~.~;e.~ ' a J ° a _., 3 ~ y : r ~ ? ',, ` ~ 1 ~.~1 t~ ._.,} ~ SARAH PALIN, GOVERNOR ~"`~~ OI~ ~ ~ far 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOIK CODII-iI55IO1~T 1'` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. ~~~~ N1A`~ ~ ~ 2~0$ PO Box 196105 Anchorage, AK 99519-6105 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 Q-07A Permit to Drill: 198-234 ~ ~,,,'j~-~' ~~ , Dear Mr. Christensen: Enclosed is the recently. submitted Report of Sundry Well Operations (Form 10-404) relating to the above referenced well. We are returning this Report of Sundry Well Operations for editing and resubmission. There is significant information regarding the existing wellbore (1 Q-07A) missing from the form. Please see the returned form for hand-written notes. You have also not used the most current Form (10- 404). Current forms are available on the Commission web site, www.ao~cc.alaska gov. If you have any questions, contact Tom Maunder, PE at 793-1250. Sincerely, ~%~ Daniel T. Seamount, Jr. Chair DATED this ~ day of May, 2008 cc: Gary Targac, NSK69 Encl. ~ RECEIVE® STATE OF ALASKA MAY Q 6 20~$ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~'~ & ~~ Cons Cammissi~n 1. Operations Performe Abandon ^ Repair Well 0 ' Plug Perforations ^ Stimulate ^ Other ~ WINJ to WAGIN Iter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approve Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, In Development ^ Exploratory ^ 198-234 / 3. Address: Strati ra hic Service ~ g p ^ ^ 6. API Number: P. O. Box 100360, Anchorag Alaska 99510 50-029-21234-01 ` 7. KB Elevation (ft): 9. Well Name and Number. RKB 91' 1 O-07A 8. Property Designation: ~ 10. Field/Pool(s): ADL 25641, ALK 2572 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: i Total Depth measured ~'?7` feet r true vertical (,Z'7$ feet Plugs (measured) Effective Depth measured S,`,Dg feet Junk (measured) true vertical feet ~ v~~'nc~~aws ~r.~GtS`"~i ~~~ ~+, ~` ~. Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' '~ ''~QD-~LS~ 3624' 9 5/8" ' ' ~ ' `~ ~ - 3715 3524 ~ PRODUCTION 8007 7" 98' 6310' J -5~ ' ~ e Perforation depth: Measured depth: 7877-7992';8064'-8142';8219'-8879'; 31'-905;9149'-9300';9330'-9422' true vertical depth: 6305'-6312;631.i'-6312';6317-6310';630 '-6299';6294'-6285';6283'-6276' ----~ ,~Ih, S G C T bi i d ~ ~ ~ ~ d d d th 2 " ' p ) r, u ng (s ze, gra e, an measure e -3/8 , L-80, 9762 MD. Packers & SSS (type & measured de th) k BAKER HB R ' p p r- ETRV. pkr- 7239 } ~~ ~~ `~ SSSV= SSSV SSSV= 1800' 12. Stimulation or cement squeeze summary: _r ~ ~~~~ ` ~ ' Intervals treated (measured) ` ~ -~ Treatment descriptions including volumes used and final ressure: ~~ ~ ~~" ~ ~( '- p j ~j ~./ ~ ~ 13. Representative Daily Average Production or I ' coon Data Oil-Bbl Gas-Mcf Wate bl Casin Pressure Tubin Pressure Prior to well operation 50 546 Subsequent to operation 2874 1250 3523 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^~ GINJ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C. empt: A .contact, Bob Christensen /Bob Buchholz Printed Nams O D. C r' tensen Title Production Engineering Te nician Signature f ._ Phone 659-7535 Date ,,, Form 10-404 vlsed 04/2004 I G ~ ~ A L ~ ~ Submit Origina 1 Q-07A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/28/08 Commenced WAG FOR Injection ~~ _ MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg 0 - --J{ ~'-Ií) . \ "0rc> (~'? ~.c". P.I. Supervisor {, DATE: Wednesday, July 19,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IQ-07A KUPARUK RIV UNIT 1 Q-07 A q¡' 'd-1> ~ \0\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :fí3?---- Comm Well Name: KUPARUK RIV UNIT lQ-07A API Well Number 50-029-21234-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS060718100813 Permit Number: 198-234-0 Inspection Date: 7/17/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. IQ-07A I .!! ! I ! I ! Well I Type InJ. I W I TVD 5978 IA 410 ! 2970 2880 2860 I I 1982340 I 1500~OA I I I P.T. I iTypeTest I SPT I Test psi 0 I 20 20 20 I ! I 2300 --+---r- Interval 4YRTST P/F P Tubing i 2300 ! 2300 2300 I I i Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. NON-CONFIDENTIAL '~~ '. -- í' ¡)\¡JJ'\M\!t:;..; (; C' Wednesday, July 19,2006 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supenisor °11 (:(Z~C4 FROM: Chuck Scheve Petroleum Inspector \Vell Name: KLJPARUK RIV UNIT IQ-07A. Insp Num: mitCSO-10619201633 Rellnsp Num: State of Alaska Alaska Oil and Gas Consen'ation Commission DATE: \\'edne<;da~. June 23. 20~ SlIBJECT: Mechamcallntegrit) Tests CONOCOPHILLIPS ALASKA. INC I Q-07A KUPARUK RIV UNIT IQ-071\ Src: Inspector NON-CONFIDENTIAL Re\'iewed B}': P.I. Supn' ".~er.:- Comm API \Vell Number: 50-029-21234-01-00 Permit Number: 198-234-0 Inspector Name: Chuck Scheve I nspection Date: 6/19/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IQ-07A Type Inj. N TVD 6278 IA 0 2170 2110 2090 P.T. 1 98.:!3'¡0 TypeTest SPT Test psi 1'¡9675 OA 0 0 0 0 - I Interval n'"R TS T P/F P Tubing I l3ûO 1300 1300 1300 Notes: Pretest pressures observed for 30+ minutes and found stable. \\'ell demonstrated good mechanical integrity. \Vednesday. June 23. 200-1 Page I of 1 ,I' .f Mike Mooney ( ( Wells Group Team Leader Drilling & Wells P. O. Box 100360 Y Anchorage, AK 99510-0360 ConocoPh ill i pS Phone: 907-263-4574 December 18, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 a-07A (APD # 198-234) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 a-07 A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, l4~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 5 2004 Alaska Oil & Gas Cons. Commission Anchorage 5(;~~E[) JAN Z @ 2004 0 R \ G \ NA L ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. D Alter Casing D Repair Well D Plug Perforations D Stimulate 0 Time Extension D Other D Change Approved Program D Pull Tubing D Perforate New Pool 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 198-234/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21234-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 91' 1Q-07A 8. Property Designation: 10. Field/Pool(s): ADL 25641 ALK 2572 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9740' feet true vertical 6269' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 3680' 9-5/8" 3715' 3524' PRODUCTION 8065' 7" 8098' 6311' Perforation depth: Measured depth: 7877'-7992',8064'-8142',8219'-8879', 8931'-9059', 9149'-9300', 9330'-9422' true vertical depth: 6305'-6312',6311'-6312',6317'-6310', 6307'-6299', 6294'-6285', ~~é5 E IVE D Tubing (size, grade, and measured depth) 3.5" 12-3/8", J-55 1 L-80, 7239' 1 9762' MD. JAN 0 5 2004 Packers & SSSV (type & measured depth) pkr= BAKER HB RETRV. pkr= 7239' C ., SSSV= Cameo TDDP-1A-SSA SSSV= 1800' Alaska Oil & Gas Cons. ommlSSlon 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6890' Treatment descriptions including volumes used and final pressure: 720 bbls seawater 13. Representative Daily Average Production or Injection Data Oil.Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation - - -- Subsequent to operation - - 332 - - 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development D Service [2] Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader J, J Signature Phone Date / Z I z, '7/cJ 3- JANO1. Form 10-404 Revised 2/2003 . 0 R \ G \ N A L SU BM IT IN PUPLI CA TE ( ( ARCa Alaska, Inc.A GKA 1Q-O7A 1 a-O7 A API: 500292123401 Well Tvoe: INJ Anale IŒ TS: 46 dea IŒ 7387 SSSV Tvoe: TRDP 1A-SSA aria Comoletion: 12/22/98 AnQle @. TO: 76 dea @. 9740 SSSV Annular Fluid: DSL Last W/O: 12/21/98 Rev Reason: Set DMY bv ImO (1800-1801, Reference LoQ: Ref Loa Date: Last Update: 4/15/00 00:3.500) Last Taa: TD: 9740 ftKB TUBING Last Taa Date: Max Hole Anale: 99 dea @. 9482 (0-7239, Casina Strina - ALL 00:3.500, Size Top Bottom TVD Wt Grade Thread 10:2.992) 16.000 0 108 108 62.50 H-40 WELDED JROOUCTION 9.625 0 3715 3524 36.00 J-55 BTC (0-3715, 7.000 0 8098 6311 26.00 J-55 BTC 00:9.625, Tu~ing Str!!!g__.:.. TUê.!.NG c--- -------_:_------ -------. -----------'------------..---- ------------.--'----------------- Wt:36.00) Size Top Bottom TVD Wt Grade Thread 3.500 0 7239 5978 9.30 J-55 EUE MOD 2.375 7239 9762 9762 4.43 L-80 EUE MOD Penoratiol1s$ummarv< '. '. ~ Interval TVD Zone Status Feet SPF Date Type Comment 7877 - 7992 6305 - 6312 A-5,A-4 115 4 2/21/9 IPERF 8064 - 8142 6311 - 6312 A-4 78 4 2/21/9 IPERF 8219 - 8879 6317 - 6310 A-3 660 4 2/21/9 IPERF 8931 - 9059 6307 - 6299 A-3 128 4 2/21/9 IPERF PBR 9149 - 9300 6294 - 6285 A-3 A-4 151 4 2/21/9 IPERF (7225-7226, 9330 - 9422 6283 - 6276 -3,A-4,A- 92 4 2/21/9 ¡PERF 00:3,500) Gas Lift MandrelsNalves .' JROOUCTION Stn MD TVD Man Man V Mfr V Type V aD Latch Port TRO Date Vlv (0-8098, Mfr Tvpe Run Comment 00:7.000, 1 7181 5937 MERLA TPDX MERLA DMY 0.0 RM 0.000 0 4/13/00 Wt:26.00) Other {pluas,eauip.,etcJ -JEWELRY .'. Depth I TVD Type Description ID 1800; 1800 SSSV CAMCO TRDP -1A-SSA 2.812 72251 5968 PBR BAKER 10' STROKE 3.000 72391 5978 PKR BAKER HB RETRV. 2.890 General Notes ". Date I Note PKR 1/19/99 I CTD SLlMHOLE HORZ SIDETRACK (7239-7240, 00:6.900) - - Perf - - (7877-7992) - - - - - - Perf (8064-8142) - - - - - - - - Perf - - (8219-8879) - - - - - - Perf (8931-9059) == == - - - - Perf - - (9149-9300) - - - - - - Perf (9330-9422) - - - - - - - - CT LINER (7239-9762, 00:2,375, 10:1.901) (" 1Q-O7A Event History ( Date Comment 11/23/03 PUMP HPBD TO INCREASE INJECTION RATE INTO THE A SAND. PUMPED 720 BBLS OF 50 DEG SEAWATER @ MAX RATE POSSIBLE (6.5 BPM AVERAGE) @ 4000 PSI. PUMP 4 STAGES WITH 15 MIN SHUT DOWNS IN BETWEEN STAGES. [HPBD] Page 1 of 1 12/17/2003 'i~}8'234~0 ....................................... KUPARUK'RIv UNIT ' lQ'-07A 50- 029-21234'01 pHILLIPS ALASKA INC Roll #1: Start: Stop Roll//2: Start Stop MD 09776 TVD 06278 Completion Date: 12/22/98 Completed Status: 1-OIL Cnrrent: lWlNJ T Name Interval Sent Received D 9193 1 BHI GR OH 6/18/99 6/23/99 D 9194 1 BHI GR PBI OH 6/18/99 6/23/99 ,,~ L GR-MD FINAL 7500-9470 PB1 OH 5/28/99 6/3/99 /- L GR-MD FINAL 7452-9782 OH 5/31/99 6/7/99 ~'L GR-TVD FINAL 6033-6262 PB1 OH 5/28/99 6/3/99 ~'L GR-TVD FINAL 6033-6220 OH 5/31/99 6/7/99 f L GR/CCL/TEM FINAL 7100-9694 CH 5 1/6/99 1/15/99 R SRVYLSTNG BH 7400-9740. OH 1/28/99 2/1/99 R SRVYLSTNG BH 7400-9400 PB1 OH 1/28/99 2/1/99 T/C/D Thursday, January 25, 2001 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Alter casing __ Change approved program X Suspend __ Operation Shutdown __ Reenter suspended well __ Repair well __ Plugging __ Time extension __ Pull tubing __ Variance Perforate __ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1560' FNL, 1239' FEL, Sec 26, T12N, R9E, UM At top of productive interval: 4125' FNL, 3890' FEL, Sec 25, T12N, R9E, UM At effective depth: At total depth: 175' FNL, 2540' FEL, Sec 36, T12N, R9E, UM Stimulate __ Other __ 5. Type of Well: Development X..~_. Exploratory ~ Stratagrapic ~ Service ~. 6. Datum of elavation (DF or KB) 1 O6' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 1Q-O7A 9. Permit number: 98-234 10. APl number: 50-029-21234-01 11. Field/Pool: Kuparuk River Field/Pool feet 12. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Length Size Conductor 108' 16" Surface 3715' 10-3/4" Production 7491' 7" Liner 2-3/8" 9776 feet Plugs (measured) 6278 feet feet Junk (measured) feet Cemented Measured depth True vertical depth 240 sx CS II 108' 108' 650sx CS II, 850 sxCS III 3715' 3524' 613 sx Class G 7491' 6311' 15.8 ppg Class G 9760' 9762' Perforation Depth measured 7877'-7992',8064'-8142', 8219'-8879',8931'-9059, 9149'-9300', 9330'-9442', 9470'-9520', 9592'-9630', 9699'-9720' true vertical 6305'-6312', 6311'-6312', 6317'-6310', 6307'-6299', 6294'-6285', 6283-6275', 6271 '-6263', 6255'-6255', 6261'-6265' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, j-55, IPC Tubing @ 7268' MD. Packers and SSSV (b/ps and measured depth) Baker HB Packer @ 7239' MD; 3-1/2", Camco TRDP SSSV @ 1800' MD. RECEIVED APR 1 1 2000 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation Convert Oil Producer to WAG Injector- April, 2000 16. If pr4>l~<t.sal.was v~erballv approved Detailed operations program __ 15. Status of well classification as: i - Bate/approvedI Se~ice 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. BOP sketch_ Suspended__ Signed Title: Wells Engineering Tech Date 4/7/00 FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness Plug integrety __ BOP test __ Location clearance __ Mechanical integrety test j Subsequent form required 10- ~.~-t[ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY Robert N. Chdstensc,~ Commissioner IApproval No.~ (~0 SUBMIT iN TRIPLICATE ". '~ 1, Attachment 1 ( ~ Conversion to WAG Injection Kuparuk WeIl1Q-07A ARCO Alaska requests approval to convert Well 1 Q-07 A from an oil producer to a WAG injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No.2. Water or Gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6251' and 6317'. This interval correlates with the strata found in ARCO's West Sak River State Well NO.1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECE\VEO APR 11 2000 ka OU & Gas ,Coos. commission Alas AnchOrage INTEQ 7260 Homer Drive, Anchorage, AK 99518 June 17,1999 Lori Taylor AOGCC, 3010 Porcupine Drive Anchorage, AK 99501 Dear Data Distribution Recipient: This letter is intended to correct Well Header Information for a Gamma Ray log digital distribution. The Gamma Ray in question was logged by Baker Hughes INTEQ's MWD on Well 1Q-07A, Kuparuk River Unit, Nodh Slope, Alaska for ARCO Alaska, Inc. This log is dated 16 Dec 1998. The TVD's were reported as TVD's measured from the RKB. The TVD's will be documented as TVDSS (True Vertical Depth Sub-Sea). The header remarks have been modified to reflect this change. All TVD data reported on the log is also referenced to the subsea TVD's. The TD for the well 1Q-07A was incorrectly reported as 9440 feet MD. This has been corrected to 9740 feet MD. Thank you. Sincerely, Brij Potnis Technical Support Engineer INTEQ 7260 Homer Drive, Anchorage, AK 99518 June 17,1999 Lori Taylor AOGCC, 3010 Porcupine Drive Anchorage, AK 99501 Dear Data Distribution Recipient: This letter is intended to correct Well Header Information for a Gamma Ray log digital distribution. The Gamma Ray in question was logged by Baker Hughes INTEQ's MWD on Well 1Q-07APBI, Kuparuk River Unit, North Slope, Alaska for ARCO Alaska, Inc. This log is dated 10 Dec 1998. The TVD's were reported as TVD's measured from the RKB. The TVD's will be documented as TVDSS (True Vertical Depth Sub-Sea). The header remarks have been modified to reflect this change. All TVD data reported on the log is also referenced to the subsea TVD's. Thank you. Sincerely, Brij Potnis Technical Support Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~,51ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classilication el Service Well o,, 2. N~e of O~mtor 7. Permit Number AR~ Alaska, Inc. 98-234 3. Addm~ 8. APl Nu~er P. O. Box 100360, Anchorage, AK 99510-0360 5~029-212~-01 4. Location el well at suda~ ?~.~: ............... 1 ' ~' 9. Unit or Lea~ N~e L:~;"~?'?~;~]:; ~ ~ '~I ~ ~ Kuparuk River Unit 1560' FNL, 1239' FEL, SEC. 26, T12N, R9E, UM - ~ ~?~ ~~; 10. Well N u~er At T~ Pmdudng Inte~al ~''~ ~ 1Q-07A ~1 lot~ Deplh , ~. ~ ~~ ~ 11. Fiol0 an0 Pool 175' FNL, 2540' FEL, SEC 36, T12N, R9E, UM ....... ~ Kuparuk River Field 5. Elevat~n in feet (indi~te KB, DF, etc.) ~6. Lease Des~nat~n and Se~ No. RKB 91 leet~ ADL 25~1, ALK 2572 Kuparuk River Oil Pool 12. Date Spu~ 13. Date T.D. Rea~ 14. Date Co~., Su~. Or ~d. ~15. Water D~th, Il o~om 16. No. of Co~let~ns De~mber 3, 1998 De,tuber 16, 1998 De~mber~, 1998J N/A f~MSL 1 17. Tot~ D~th (MD + ~D) 18. Plug Ba~ D~th (MD + TVD) 19. Dimct~nal Suwey ~20. Depth where SSSV sel 21. Th~e~ of Pe~mst 9~6' MD/6278' ~D 9732' MD/626~TVD ~S ~ No D~ 1800, MD. fe~MD 1900' (approx) ~. T~ Ele~ or ~her Lo~ Run MEM G~CC~EMP, MWD 23. CASING, LINER AND CEME~ING RECORD S~ING ~PTH MD CASING SIZE ~. PER ~. G~DE TOP BO~OM HOLE SIZE CEME~ING RECORD~ AMOU~ PULLED 16' 62.~ H-40 Suda~ 108' 24" 240 Sx cs II 9-5/8" 3~ J-55 Suda~ 3715' 12-1/4' 650 Sx cs II & 850 Sx cs III 7' 2~ J-55 Suda~ 7~1' 8-1/2" 613 Sx Cla~ G 2-3/8' 4.4~ L-80 7239' 9760' 3' 30 ~ls 15.8 ppg Cla~ G 24. Pedorations open to Pmdu~ion (MD + TVD of Top and ~om ~d 25. TUBING RECORD intew~, size and nu~r) SIZE DEPTH SET (MD) PACKER SET (MD) 787T - 79~' MD; ~05' - 6312' ~D; ~ 4 SPF 3-1/2' 7268' 7239' 8064' - 8142' MD; 6311' - 6312' ~D; ~ 4 SPF 8219' - 8879' MD; 6317' - 6310' ~D; ~ 4 SPF 26. ACID, F~CTURE, CEME~ SQUEEZE, ~C. 8931' - 9059' MD; ~07' - 6~9' ~D; ~ 4 SPF DEPTH I~ERVAL (MD) AMOU~ & KIND OF MATERIAL USED 9149' - 930~ MD; 6294' - 6285' ~D; ~ 4 SPF 9~0' - 944~ MD; 62~' - 6275' ~D; ~ 4 SPF 9470' - 9520' MD; 6271' - 62~' ~D; ~ 4 SPF 959Z - 9630' MD; 6255' - 6255' ~D; ~ 4 SPF 9699' - 9720' MD; 6261' - 6265' ~D; ~ 4 SPF 27. PRODUCTION TEST Date Fi~ Produ~ion Meth~ of Operation (Flowing, ~s li~, etc.) Janua~ 6, 1999 Flowing ' Dato o~ l~t Hou~ l,st~ ~roduct~n ~or OIk-BBk ~8-MCF WAI[~-BBk GHOKfi SIZfi ~S-OIk ~110 Flow Iu~ln~ Gasino ~r~sum G~ulal~ OIk-BBk ~S-MGF W~I[~-BBk OIk G~VI~ - ~¢1 {co~) Pre~. 239 p~ 24-Hour Rate > 356 790 505 28. CORE DATA Brai de~ption of lithely, pomsi~, fractures, ~pamnt dips ~d pm~n~ of oil, ~ or water. Submit ~m ch~s. * ~is 10-407 is submitted as directed per ~e 10-401 form approved November 23, 1998 (Permit ~234) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME Top of Upper Sand Base of Upper Sand Top of Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 7388' 7540' 7821' TRUE VERT. DEPTH 6081' 6185' 6299' ...... ' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of 1Q-07A CT Sidetrack Drilling Operations + Survey. 32. I hereby certily that the following is true and correct to the best of my knowledge. Bruce E. Smith, P.E. AAI Coil Tubin,q Drillin,q Supervisor Date INSTRUCTIONS Prepared by Paul Rauf 263-4990. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. ~;,7 '.!' ;, tr. Item 28: If no cores taken, indicate "none". Form 10-407 1Q-07A DESCRIPTION OF WORK COMPLETED PRE COILED TUBING SIDETRACK PLUG & ABANDOMENT SUMMARY Date Event Summary 11/27/1998: 11/28/1998: 11/29/1998: 11/30/1998: 12/01/1998: 12/02/1998: 12/03/1998: 12/04/1998: 12/05/1998: 12/06/1998: 12/07/1998: 12/08/1998: 12/09/1998: 12/10/1998: 12/11/1998: 1 2/1 2/1998: 12/13/1998: 12/14/1998: 12/15/1998: 12/16/1998: 12/17/1998: MIRU CTU. Cont. RU CTU. Cont. RU CTU. PT'd BOPE. RIH w/BHA & tagged TOC @ 7339' MD. Milled Cement to 7507' MD & POOH w/BHA. RIH & milled pilot hole to 7531'. POOH. RIH w/CT to 7530' MD & pumped 5 bbls of 17 ppg Class G Cement. Sqz'd to 500 psi. Contaminated Cement w/Biozan and jetted out contaminated Cement to 7300'. WOC. RIH & tagged TOC @ 7320'. Milled Cement to 7451' MD. Milled Cement to 7485'. Swapped to FIo Pro & POOH. RIH & began time milling. Milled window through the 7" liner f/the TOW @ 7491' to the BOW @ 7498'. Drilled FM to 7504' MD. POOH. RIH & dressed window interval. Drilled to 7506'. Reamed/backreamed window area. Noticed pinhole leak in CT while in hole to 7500'. POOH. RD CTU to swap CT reel. Replaced CT reel. RU CTU. PT'd BOPE. RIH & performed LOT to EMW of 14.12 ppg. Drilled to 7680' MD. Drilled to 8117' MD & POOH. RIH & drilled to 8215'. Drilled to 8638' MD. Swapped to new FIo Pro. POOH. RIH & tagged BTM. Drilled to 9261' MD w/short trips to window. Drilled to 9470' & POOH. RIH & plug backed OH f/9100' to 8300' w/6.5 bbls of 17 ppg Class G Cement. Contaminated Cement w/Biozan and cleaned to 8740'. POOH. WOC. PT'd BOPE. RIH w/BHA & tagged TOC @ 8745' MD. Attempted to OHST but Cement was soft. Drilled Cement to 8849' & POOH w/BHA. RIH & drilled trough f/ 8830' - 8845'. Time drilled to 8848'. Had problems w/TF not holding & depth counter not working properly. Drilled OHST to 8890'. Drilled to 8912' & POOH. RIH & drilled to 8915'. Continued to have TF problems. POOH. RIH to BTM & drilled to 9212 MD'. Swapped to new mud. Drilled ahead to 9393'. Drilled to TD @ 9776'. Conditioned hole & spotted Hi Vis Pill in OH. POOH. RIH & worked the 2-3/8" liner to 9718' MD. Circulated Biozan Pill. Sidetrack Summary Page I 1 Q-07A DESCRIPTION OF WORK COMPLETED PRE COILED TUBING SIDETRACK PLUG & ABANDOMENT SUMMARY Date Event Summary 12/18/1998: 1 2/19/1998: 12/20/1998: 12/21/1998: 12/22/1998: Landed liner @ 9760' MD. TOL=7239' MD. Released off liner. Attempted to cement liner in place w/15 bbls of 15.8 ppg Class G Cement but no returns to surface during cement job. Unstung from liner & contaminated remaining cement w/Biozan. Jetted contaminated Cement to the Liner back door flapper located @ 9740' MD. POOH while laying in 12.5# brine to surface. RIH w/mem GR/CCL tools & logged Well. PT'd liner lap - test failed. Pumped Biozan & POOH w/logging tools. Memory GR tool failed. RIH & re-logged well. POOH w/logging tools, RIH w/CT. Tagged BTM @ 9728' MD. Spotted Biozan f/PBTD to 8000'. Displaced well to seawater. Performed liner lap / FM inject test. Layed in f/8000' MD 15 bbls of 15.8 ppg Class G Cement. PUH to safety, TOC -5880'. Slowly sqz'd Cement behind liner. Estimated 8 bbls of Cement placed behind pipe. Unable to achieve solid sqz press. Contaminated Cement w/ Biozan & cleaned out liner to 9732'. PUH to 7000' MD & maintained 1100 psi on wellhead. WOC. WOC. PT'd liner lap to 2500 psi for 30 minutes - passed. Displaced well to mud & brine. POOH w/CT. RIH w/Perf guns to PBTD @ 9732' & shot 1333' of Initial Perforations @: 7877' - 7992' MD (Zone A Sand ) 8064' - 8142' MD (Zone A Sand ) 8219' - 8879' MD (Zone A Sand ) 8931' - 9059' MD (Zone A Sand ) 9149' - 9300' MD (Zone A Sand ) 9330' - 9422' MD (Zone A Sand ) 9470' - 9520' MD (Zone A Sand ) 9592' - 9630' MD (Zone A Sand ) 9699' - 9720' MD (Zone A Sand ) Used 1-11/16" carriers & shot all Perfs @ 4 SPF, POOH w/guns. ASF. FP'd well. RDMOL. Placed well on initial production & obtained a valid well test. Sidetrack Summary Page 2 5400 -+- 5550 5700 ~ - 5850- 6000- 6150 6300 I ¥ 6450 Sfrucfure · Pod lQ Well · 1Q-O7A ~ Field · Kuporuk River Unif Location · North Slope, Alaska ARCO Alaska, Inc. Eosf (feet) -> Created b.y planner Data platted : ..xO-Occ-98 Plat Reference Is tQ-OTA Ve~llon #6. Coerclinates are [n t'eet reference 1Q-O?. 'rue Vergcal Depths ere reference r~b - USL = 91ft --- Baker Hughes INTEQ --- 1600 1800 2000 2200 2400 2600 2800 .3000 3200 .3400 3600 3800 4000 4200 4400 4600 i t ~ ~ ~ ~ ~ I ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ t I ~ ~ ~ ~ ~ ~ ~ 2000 2200 Tie on - 5998.86 Tvd, 2`309.32 S, 2381.66 E KOP - 7480 MD, 605;5.68 TVDss - 6053.68 Tvd, 2`348.13 S, 2425.1.3 E Tie on - 46.1`3 Inc, 7400.00 Md, 5998.86 Tvd, `3`315.69 Vs Dss - 47.37 Inc, 7480.00 Md, 605.3.68 Tvd, `3`37,.3.80 Vs ' I I i I i I I Ii I i I I I I I i I i I I i I iI I I I I I I II I I i i i i i i 3000 .3150 `3300 ~45° 3600 3750 3900 4050 4~00 4350 4500 4650 4800 4~50 5~00 5250 5400 ,5550 5~00 5850 6000 Verficol Secfion (feet) -> Azimuth 1;55.97 with reference 0.00 N, 0.00 E from 1Q-07 ~400 ~600 2800 0 3000 ,-i- 3200 V 3400 3600 3800 4000 ARCO Ataska, Inc. Pad lQ 1Q-O?A 1Q-07 Kuparuk River Unit North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 1Q-O7A Our ref : svy346 License : 50-029-21234-01 Date printed : 30-Dec-98 Date created : 16-Dec-98 Last revised : 30-Dec-98 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on 529617.731,5985877.038,999.00000,N Stot location is n70 22 5.613,w149 46 9.647 Slot Grid coordinates are N 5984312.302~ E 528385.036 Slot local coordinates are 1560.00 S 1239.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO ALaska, Inc. Pad 1Q,1Q-O7A Kuparuk River Unit,North SLope, Alaska SURVEY LISTING Page 1 Your ref : 1Q-OTA Last revised : 30-Dec-98 Measured [nclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 7400.00 46.13 131.80 5998.86 2309.32S 2381.66E 1.07 3315.69 7480.00 47.37 131.72 6053.68 2348.13S 2425.13E 1.55 3373.80 7506.00 49.00 136.00 6071.01 2361.56S 2439.09E 13.78 3393.15 7538.00 51.30 140.00 6091.52 2379.82S 2455.51E 11.99 3417.69 7558.00 53.10 144.30 6103.78 2392.29S 2465.20E 19.22 3433.40 G R I D C 0 0 R D S Easting NorthJng 530775.58 5982012.65 530819.20 5981974.02 530833.21 5981960.65 530849.70 5981942.46 530859.43 5981930.02 7570.00 53.40 141.20 6110.96 2399.94S 2471.01E 20.85 3442.94 530865.28 5981922.39 7599.00 56.60 142.00 6127.60 2418.565 2485.77E 11.26 3466.58 530880.11 5981903.84 7630.00 60.40 140.00 6143.79 2439.09S 2502.40E 13.43 3492.90 530896.82 5981883.37 7659.00 63.30 138.80 6157.47 2458.505 2519.04E 10.64 3518.43 530913.54 5981864.03 7690.00 66.50 136.00 6170.62 2479.15S 2538.05E 13.17 3546.48 530932.62 5981843.46 7721.00 69.60 133.10 6182.21 2499.31S 2558.54E 13.24 3575.22 530953.19 5981823.38 7755.00 72.60 129.60 · 6193.23 2520.55S 2582.68E 13.14 3607.27' 530977.42 5981802.24 7786.00 77.30 129.60 6201.27 2539.63S 2605.74E 15.16 3637.01 531000.55 5981783.26 7820.00 81.80 131.70 6207.44 2561.41S 2631.10E 14.56 3670.30 531025.99 5981761.58 7856.00 83.60 136.40 6212.02 2586.23S 2656.75E 13.88 3705.97 531051.74 5981736.86 7899.00 85.10 142.40 6216.25 2618.70S 2684.59E 14.32 3748.67 531079.70 5981704.50 7933.00 86.20 146.90 6218.83 2646.35S 2704.19E 13.59 3782.17 531099.41 5981676.94 7965.00 88.20 152.50 6220.40 2673.93S 2720.31E 18.56 3813,20 531115.64 5981649.42 7997.00 90.00 159.00 6220.90 2703.09S 2733.44E 21.07 3843.29 531128.88 5981620.32 8040.00 91.40 161.70 6220.38 2743.58S 2747.90E 7.07 3882.45 531143.50 5981579.89 8086.00 90.90 153.00 6219.45 2785.98S 2765.60E 18.94 3925.24 531161.36 5981537.56 8120.00 87.40 151.80 6219.96 2816.10S 2781.34E 10.88 3957.84 531177.23 5981507.51 8154.00 86.90 148.60 6221.65 2845.56S 2798.22E 9.51 3990.75 531194,21 5981478.11 8177.00 87.00 144.80 6222.87 2864.76S 2810.82E 16.50 4013.31 531206.90 5981458.97 8204.00 85.40 144.70 6224.66 2886.76S 2826.37E 5.94 4039.94 531222,53 5981437.04 8245.00 84.90 140.70 6228.13 2919.25S 2851.12E 9.'80 4080.50 531247,41 5981404.65 8287.00 87.90 136.50 6230.77 2950.68S 2878.84E 12.27 4122.36 531275,24 5981373.33 8332.00 90.80 135.40 6231.28 2983.02S 2910.12E 6.89 4167.35 531306.65 5981341.12 8372.00 91.40 130.40 6230.51 3010.23S 2939.41E 12.59 4207.27 531336,04 5981314.02 8413.00 91.40 127.50 6229.51 3035.99S 2971.28E 7.07 4247.95 531368.01 5981288.39 8446.00 93.10 125.70 6228.21 3055.65S 2997.75E 7.50 4280.48 531394.56 5981268.84 8480.00 95.30 122.10 6225.72 3074.56S 3025.89E 12.38 4313.63 531422.76 5981250.04 8521.00 94.50 119.00 6222.22 3095.32S 3061.06E 7.78 4353.01 531458,02 5981229.42 8558.00 92.90 116.00 6219.83 3112.37S 3093.81E 9.17 4388.02 531490.83 5981212.51 8607.00 91.80 109.40 6217.82 3131.25S 3138.95E 13.64 4432.97 531536.04 5981193.81 8643.00 91.50 111.20 6216.78 3143.74S 3172.70E 5.07 4465.41 531569.83 5981181.46 8694.00 90.20 114.90 6216.02 3163.70S 3219.61E 7.69 4512.36 531616.82 5981161.68 8745.00 89.40 119.90 6216.20 3187.16S 3264.87E 9.93 4560.69 531662.17 5981138.40 8784.00 89.20 122.40 6216.68 3207.33S 3298.25E 6.43 4598.39 531695.62 5981118.36 8832.00 87.30 126.60 6218.14 3234.50S 3337.78E 9.60 4645.40 531735.25 5981091.36 8867.00 90.20 126.60 6218.91 3255.36S 3365.86E 8.29 4679.92 531763.42 5981070.61 8883.00 91.90 125.90 6218.61 3264.82S 3378.77E 11.49 4695.68 531776.36 5981061.20 8914.00 93.90 121.20 6217.05 3281,92S 3404.56E 16.46 4725.91 531802.22 5981044.20 8951.00 96.20 121.40 6213.79 3301.07S 3436.05E 6.24 4761.56 531833.78 5981025.18 8988.00 94.50 124.70 6210.34 3321.16S 3466.92E 10.00 4797.46 531864.73 5981005.22 9034.00 90.30 128.30 6208.41 3348.49S 3503.85E 12.02 4842.78 531901.76 5980978.04 9086.00 93.30 131.10 6206.78 3381.68S 3543.83E 7.89 4894.43 531941.87 5980945.01 9124.00 93.50 132.00 6204.52 3406.84S 3572.22E 2.42 4932.25 531970.35 5980919.96 9165.00 92.10 127.10 6202.52 3432.90S 3603.79E 12.42 4972.93 532002.02 5980894.02 9200.00 91.40 123.50 6201.45 3453.12S 3632.33E 10.47 5007.31 532030.64 5980873.93 All data in feet unless otherwise stated. Calculation uses minimum curvature m~thod. Coordinates from 1Q-07 and TVD from rkb - MSL = 91ft. Bottom hole distance is 5535.05 on azimuth 134.26 degrees from wellhead. Vertical section is from wellhead on azimuth 135.97 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the CLarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1G,1Q-OTA Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 9235.00 94.20 122.70 6199.74 3472.21S 9261.00 96.00 122.50 6197.43 3486.16S 9331.00 93.50 130.70 6191.62 3527.72S 9371.00 93.70 135.00 6189.11 3554.86S 9408.00 93.40 139.50 6186.82 3581.97S SURVEY LISTING Page 2 Your ref : 1Q-OTA Last revised : 30-Dec-98 U L A R Dogleg Vert G R I D C 0 0 E O S A T E S Deg/lOOft Sect Easting Northing 3661.61E 8.32 5041.38 532060.00 5980854.96 3683.43E 6.97 5066.58 532081.87 5980841.09 3739.38E 12.21 5135.34 532137.97 5980799.76 3768.64E 10.74 5175.19 532167.34 5980772.73 3793.70E 12.17 5212.10 532192.50 5980745.72 9447.00 97.50 142.80 6183.12 3612.19S 3818.05E 13.47 5250.76 9482.00 99.40 147.70 6177.97 3640.63S 3837.77E 14.87 5284.91 9521.00 99.10 152.00 6171.70 3673.90S 3857.10E 10.91 5322.27 9561.00 95.60 153.90 6166.58 3709.23S 3875.14E 9.94 5360.20 9593.00 92.50 152.90 6164.32 3737.77S 3889.43E 10.18 5390.65 532216.97 5980715.60 532236.81 5980687.25 532256.26 5980654.05 532274.44 5980618.80 532288.84 5980590.32 9627.00 89.40 148.90 6163.76 3767.46S 3905.96E 14.88 5423.49 532305.48 5980560.70 9665.00 85.20 149.00 6165.55 3799.97S 3925.53E 11.06 5460.47 532325.18 5980528.27 9691.00 81.50 148.70 6168.56 3822.07S 3938.89E 14.28 5485.64 532338.63 5980506.22 9722.00 78.20 148.40 6174.02 3848.10S 3954.81E 10.69 5515.42 532354.65 5980480.26 9740.00 76.40 147.80 6177.98 3863.01S 3964.08E 10.52 5532.59 532363.98 5980465.39 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 1Q-07 and TVD from rkb - MSL = 91ft. Bottom hole distance is 5535.05 on azimuth 134.26 degrees from wellhead. Vertical section is from wellhead on azimuth 135.97 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes ]NTEQ ARCO ALaska, Inc. Pad 1Q,1Q-OTA Kuparuk River Unit,North SLope, ALaska SURVEY LISTING Page Your ref : 1Q-OTA Last revised : 30-Dec-98 Targets associated with this we[[path Target name GeograF~hic Location T.V.D. RectanguLar Coordinates Revised 1Q-OTehs 532250.000,5980500.000,0.0000 6220.00 3827.95S 3850.23E 2-Nov-98 ARCO Alaska, Inc. Pad lQ 1Q-O7pb 1Q-07 Kuparuk River Unit North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 1Q-OTA Plugback Our ref : svy347 License : 50-029-21234-?0 Date printed : 30-Dec-98 Date created : 16-Dec-98 Last revised : 30-Dec-98 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on 529617.731,5985877.038,999.00000,N Slot location is nTO 22 5.613,w149 46 9.647 Slot Grid coordinates are N 5984312.302, E 528385.036 Slot local coordinates are 1560.00 S 1239.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1Q,1Q-OTpb Kuparuk River Unit,North Slope, A Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 7400.00 46.13 131.80 5998.86 7480.00 47.37 131.72 6053.68 7506.00 49.00 136.00 6071.01 7538.00 51.30 140.00 6091.52 7558.00 53.10 144.30 6103.78 7570.00 53.40 141.20 6110.96 7599.00 56.60 142.00 6127.60 7630.00 60.40 140.00 6143.79 7659.00 63.30 138.80 6157.47 7690.00 66.50 136.00 6170.62 7721.00 69.60 133.10 6182.21 7755.00 72.60 129.60 6193.23 7786.00 ~r7.30 129.60 6201.27 7820.00 81.80 131.70 6207.44 7856.00 83.60 136.40 6212.02 7899.00 85.10 142.40 6216.25 7933.00 86.20 146.90 6218.83 7965.00 88.20 152.50 6220.40 7997.00 90.00 159.00 6220.90 8040.00 91.40 161.70 6220.38 8086.00 90.90 153.00 6219.45 8120.00 87.40 151.80 6219.96 8154.00 86.90 148.60 6221.65 8177.00 87.00 144.80 6222.87 8204.00 85.40 144.70 6224.66 8245.00 84.90 140.70 6228.13 8287.00 87.90 136.50 6230.77 8332.00 90.80 135.40 6231.28 8372.00 91.40 130.40 6230.51 8413.00 91.40 127.50 6229,51 8446.00 93.10 125.70 6228.21 8480.00 95.30 122.10 6225.72 8521.00 94.50 119.00 6222.22 8558.00 92.90 116.00 6219.83 8607.00 91.80 109.40 6217.82 8643.00 91.50 111.20 6216.78 8694.00 90.20 114.90 6216.02 8745.00 89.40 119.90 6216.20 8784.00 89.20 122.40 6216.68 8832.00 87.30 126.60 6218.14 8868.00 86.50 128.30 6220.09 8918.00 85.20 132.60 6223.71 8943.00 85.80 134.20 6225.67 8985.00 87.30 135.70 6228.20 9022.00 86.00 138.80 6230.36 9051.00 84.80 141.80 6232.69 9086.00 83.80 141.90 6236.17 9118.00 84.00 140.60 6239.57 9145.00 86.30 139.90 6241.85 9182.00 88.30 137.60 6243.59 laska SURVEY LISTING Page 1 Your ref : 1Q-OTA Plugback Last revised : 30-Dec-98 R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 2309.32S 2381.66E 1.07 3315.69 530775.58 5982012.65 2348.13S 2425.13E 1.55 3373.80 530819.20 5981974.02 2361.56S 2439.09E 13.78 3393.15 530833.21 5981960.65 2379.82S 2455.51E 11.99 3417.69 530849.70 5981942.46 2392.29S 2465.20E 19.22 3433.40 530859.43 5981930.02 2399.94S 2471.01E 20.85 3442.94 530865.28 5981922.39 2418.56S 2485.77E 11.26 3466.58 530880.11 5981903.84 2439.09S 2502.40E 13.43 3492.90 530896.82 5981883.37 2458.50S 2519.04E 10.64 3518.43 530913.54 5981864.03 2479.15S 2538.05E 13.17 3546.48 530932.62 5981843.46 2499.31S 2558.54E 13.24 3575.22 530953.19 5981823.38 2520.55S 2582.68E 13.14 3607.27 5309~r7.42 5981802.24 - 2539.63S 2605.74E 15.16 3637.01 531000.55 5981783.26 2561.41S 2631.!0E 14.56 3670.30 531025.99 5981761.58 2586.23S 2656.75E 13.88 3705.97 531051.74 5981736.86 2618.70S 2684.59E 14.32 3748.67 531079.70 5981704.50 2646.35S 2704.19E 13.59 3782.17 531099.41 5981676.94 2673.93S 2720.31E 18.56 3813.20 531115.64 5981649.42 2703.09S 2733.44E 21.07 3843.29 531128.88 5981620.32 2743.58S 2747.90E 7.07 3882.45 531143.50 5981579.89 2785.98S 2765.60E 18.94 3925.24 531161.36 5981537,56 2816.10S 2781.34E 10.88 3957.84 531177.23 5981507.51 2845.56S 2798.22E 9.51 3990.75 531194.21 5981478,11 2864.76S 2810.82E 16.50 4013.31 531206.90 5981458,97 2886.76S 2826.37E 5.94 4039.94 531222.53 5981437,04 2919.25S 2851.12E 9,80 4080.50 531247.41 5981404.65 2950.68S 2878.84E t2.27 4122.36 531275.24 5981373,33 2983.02S 2910.12E 6.89 4167.35 531306.65 5981341,12 3010.23S 2939.41E 12.59 4207.27 531336.04 5981314.02 3035.99S 2971.28E 7,07 4247.95 531368.01 5981288°39 3055.65S 2997.75E 7,50 4280.48 531394,56 5981268,84 3074.56S 3025.89E 12,38 4313.63 531422.76 5981250,04 3095.32S 3061.06E 7,78 4353.01 531458.02 5981229.42 3112.37S 3093.81E 9,17 4388.02 531490.83 5981212,51 3131.25S 3138.95E 13.64 4432.97 531536.04 5981193,81 3143.74S 3172.70E 5.07 4465.41 531569.83 5981181.46 3163,70S 3219.61E 7,69 4512.36 531616.82 5981161.68 3187.16S 3264.87E 9.93 4560.69 531662.17 5981138.40 3207.33S 3298.25E 6,43 4598.39 531695.62 5981118.36 3234.50S 3337,78E 9,60 4645.40 531735.25 5981091.36 3256,35S 3366.31E 5,21 4680.95 531763.87 5981069.62 3288.70S 3404.25E 8.96 4730.57 531801.94 5981037.42 3305,82S 3422.36E 6,82' 4755.47 531820.11 5981020.37 3335~44S 3452.03E 5,05 4797.38 531849.89 5980990.88 3362.56S 3477.10E 9.07 4834.30 531875.07 5980963.86 3384,80S 3495.56E 11.11 4863.12 531893,62 5980941.70 3412,18S 3517.07E 2,87 4897.77 531915.24 5980914.40 3437,00S 3536.99E 4.09 4929.45 531935.25 5980889.67 3457.68S 3554.19E 8.90 4956.28 531952.53 5980869.05 3485,46S 3578.56E 8.23 4993.19 531977.00 5980841.37 Alt data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 1Q-07 and TVD from rkb - MSL = 91ft. Bottom hole distance is 5211.91 on azimuth 134.35 degrees from wellhead, Vertical section is from wellhead on azimuth 135.97 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1Q,1Q-O7pb Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 1Q-OTA PLugback Last revised : 30-Dec-98 Measured lnclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 9222.00 88.50 137.00 6244.71 3514.85S 3605.67E 1.58 5033.16 532004.23 5980812.09 9260.00 87.00 134.40 6246.20 3542.02S 3632.19E 7.89 5071.13 532030.85 5980785.03 9299.00 84.50 135.90 6249.09 3569.59S 3659.62E 7.47 5110.01 532058.39 5980757.57 9335.00 82.90 137.40 6253.04 3595.61S 3684.18E 6.07 5145.79 532083.05 5980751.65 9367.00 80.00 138.50 6257.80 3619.10S 3705.37E 9.68 5177.41 532104.33 5980708.25 9400.00 78.40 136.70 6263.98 3643.04S 3727.23E 7.23 5209.81 532126.28 5980684.40 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 1Q-07 and TVD from rkb - MSL = 91ft. Bottom hole distance is 5211.91 on azimuth 134.35 degrees from wet[head. Vertical section is from wellhead on azimuth 135.97 degrees, Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1Q,1Q-OTpb Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page Your ref : 1Q-O7A Plugback Last revised : 30-Dec-98 Targets associated with this we[tpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1Q-O7ehs 532250.000,5980500.000~0.0000 6220.00 3827.95S ~850.2~E 2-Nov-98 1/11/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 12216 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 1 C- 15 STATIC PRESS/TEMP 981230 1 1 1 C- 17 SCMT 981224 1 1 1 C- 17 SCMT 981224 1 1 1Q-07A GR/CC L/TE M P 981212 1 1 SIG Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Alaska Oil & G as COilS. Andiorage TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Novmnbcr 24. 1998 Drew Hembling Drilling Team Lcadcr ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99519-6612 Re; Kuparuk River Unit I Q-07A ARCO Alaska. Inc. Pcrmit No: 98-234 Sur. Loc. 1560'FNL, 1239'FEL, Sec. 26, T12N, R9E. UM Btmholc Loc. 110'FNL. 2609'FWL. Sec. 36. TI2N. R9E. UM Dear Mr. Hcmbling: Enclosed is thc approved application for permit to drill thc above rcfcrcnccd well. Thc permit to drill docs not exempt you from obtaining additional permits rcquircd by law from other governmental agencies, and docs not authorize conducting drilling opcrations until all other required permitting dctermmations arc made. The blowout prevention equipmcnt (BOPE) must bc tcstcd in accordance with 20 AAC 25.035; and thc mechanical integrity (MI) of thc injection wells must be dcmonstratcd under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficicnt notice (approximately 24 hours) of thc MI test bcforc opcration, and of the BOPE tcst pcrformcd before drilling bclo,,v thc surface casing shoe, must be given so that a rcprcscntativc of thc Commission may witncss the tests. Notice mav be given bx' contacting the Commission pctrolcum field inspector on thc North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffEnclosurc cc~ Department of Fish &Gamc. Habitat Section w/o cncl. Departmcnt of Environmental Conservation w/o cncl. ARCO Alaska, Inc. "' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 20, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Q-07A Permit to Drill Dear Mr. Commissioner: Enclosed is a revised Permit to Drill to change the bottomhole location for KRU 1Q-07A. If you have any questions, please free feel to call me at 263-4107. Sincerely, D. Hembling Drilling Team Leader DH/skad STATE OF ALASKA ALAd74A OIL AND GAS CONSERVATION COMb~SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill E~ Redrill X lb Type of Well Exploratory F'~ StratigraphicTest ~ Development Oil X Re-Entry F~ Deepen FJ service E~ Development Gas E.'" Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 91' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25641, ALK 2572 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 1560' FNL, 1239' FEL, Sec.26, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8, Well number Number 1416' FSL, 1137' FWL, Sec. 25, T12N, R9E, UM 1Q-07A #U-630610 At total depth 9, Approximate spud date Amount 110' FNL, 2609' FWL, Sec. 36, T12N, R9E, UM November 25, 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 9822' MD 559' @ TD feet No close approach feet 2560 6331' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 7525' feet Maximum hole angle 91 o Maximum sudace 3150 psig At total depth (TVD) 3800psig @ 6291' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2.75" 2.375" 4.6# L-80 FL4S 2572' 7250' 5985' 9822' 6331' 15 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet ~ '¢tue,'V~rtical depth Casing Length Size Cemented Mea~d~e~th ...... Structural ~' ~ Conductor Surface ~. Intermediate Production Liner Pedoration depth: measured~! lu.,-~ '~"' ~' ~'~'"~6 true vertical - 20. Attachments Filing fee X Property plat [~ BOP Sketch X Diverter Sketch [~ Drilling program X Drilling fluid program F~ Time vs depth plot ['-] Refraction analysis [~ Seabed report ~ 20 AAC 25.050 requirements Fi 21. I hereby certify that the foregoing is true and correct to the best of my knowledge // Signed I,.~.. ~__c~¢4,.~ ..;~'~;¢..~¢/~ Title Dr illin gTe am Leader Date ii/. Commission Use Only ' Permit Number I APl number I Approval date /,~ A I See cover letter for .,~¢''~ ,Z-..,,,~ ~',,/ 50- o~---~;~- ~ /,~....~ ~/-' ,¢~ / ~[ ~ '~ other requirements Conditions of approval Samples required ~ Yes ,.~ No Mud log required Fi Yes ~ No Hydrogen sulfide measures ]~ Yes ~' No Directional survey required ,~ Yes [~ No Required working pressure for BO 2M Fi aM Fi ~5/"~"M) FI 10M ~ 15M v Other: Original Signed By David W. Johnston by ordero, /~. /~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 triplicate Kuparuk 1Q-07A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore with 17 ppg cemenL Mill window in 7" liner. Directionally drill a horizontal well from the existing Wellbore. Complete with 2-3/8" blank liner. Cement liner in place. Perforate. Intended Procedure: Cement squeeze the existing perforations with 17 ppg cement. Leave top of cement ~ -7475' md to act as a cement whipstock. Mill window in 7" liner at 7525' md. Drill 10' of formation and perform leak offtest to 0.5 ppg above the highest anticipated mud weight. Directionally drill 2-3/4" x -2296' horizontal well to access Kuparuk A Sand reserves. Run 2-3/8" blank liner to TD. Cement in place. Perforate appropriate intervals. · Place on production. Drilling fluids will be injected at Kuparuk 1R-18 disposal well. November 6, 1998 Kuparuk 1Q-07A Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 3800 psi ~ 6291' TVD, 6200'ss (11.6 ppg EMW) estimated pressure in C sand. Reservoir frac gradient is -0.8 psi/ft or 15.4 EMW, 5060 psi. Plans are to drill with 10 ppg mud which is less than kill-weight fluid. While circulating at least 1 bpm, BHP will exceed reservoir pressure due to high ECD. However, when circulation is shut down, the reservoir will be underbalanced by 530 psi. Maintain at least 1000 psi WHP when not circulating to prevent reservoir in-flux and maintain formation stability. Monitor return-line flow rate and pit volume continuously.. If crude enters the pits, take all returns to an outside tank first. Have kill weight fluid on location for well control. 300 bbls 12.5 ppg Sodium Bromide viscosified kill weight fluid in a 400 bbls upright. Viscosify with a nominal 1/3 Flo-Vis and 2/3 Biozan (-45K LSRV) and add 2% Lubetex. Maximum anticipated WHP w/full column of gas: -3150 psi assuming 0.1 psi/ft gas gradient. Pad lQ 1~-07 Kuparuk River Unit North $1ope~ ALaska PROPOSAL L [ ST I NO by Baker Hughes ~NTEQ Your caf : IG-OTA version #6 Our ref i prop116 Date printed : 20-N°v-gS Date created : 29-0ct-98 Last revfsed : 20-Nov-98 FieLd ;. centred on n70 16 18.576,wlSg 5 56.536 Structure is centred en 529617.T51,S985~7?.O38,999.00OOO,N Stet [oration is nTO 22 5,613,~149 45 9.64? SLot Orid coordinates ore N 59a~]1~.302, E 528385.036 Stet Local coordlnatea are 1560.00 S 123~.00 ~ Projectfon type: aLe,ko - Zone 4, spheroid: CLarke - 18&6 aeference North is True ................ ,-,~ ,-,-~ ,~n~,, 'rTaa_.~aT_.~nc-,;-r-rT i~:llI, JT .c::lHqNH Nq')IHI:[ ARCO A[esks, ]nc, Pad 10,10-07 Kuparuk RiYer Unit,North elope, A Measured ~n'clin Azimuth True Vert Depth Degrees Degrees Depth 7400.00 46.13 131.80 5998,86 7425.00 46.32 131.77 6016.13 7450.00 46.90 131.75 6033,2? 7475.00 47.29 151.72 6050.29 ?,80.00 47,$? 131.72 6053.68 7500,00 49.34 132.19 6066.96 T525,DO 51.80 132.76 6082.84 7550,00 5*.2? 133,25 6097.8? 7575.00 56.74 133.73 611~.03 7600.O0 59.21 134.98 6125.29 7625.00 6t,68 134.61 6137.6~ 7648.~6 6~,00 135,00 6148,33 7650.00 6~.11 '1~5.07 6149.00 7675.00 65.86 1~6.13 6159.57 7700.00 67.62 1~7.17 6169.~4 77Z5.00 69.39 138.18 6178,61 7750.00 71,16 139.16 6187.05 7775.00 72.95 140.13 61~4.7~ 7800.00 7~.72 1~1.07 6201,72 7825.00 ?6.50 142,01 6Z07.93 7850.00 78.29 142.92 6215,$9 7875.00 80.08 1~S,83 6~18.08 7900,00 81.87 144o?~ 6222.00 7~5,00 83.67 145,61 6225.1~ 7950.00 85.&7 146.~9 62~?.51 7975.C0 87.Z? 1,7.37 62~9.09 8000.00 89,06 148.Z5 6~29.89 8013.00 90.00 1~8.70 6230.00 8025.00 90,27 148.03 6229.97 8050,00 90.82 146.64 6299.74 80?5.00 91.37 145.Z4 6229.26 8100,00 91.93 143.85 6228.54 8125.00 92.68 142.45 6227.57 8150,00 93.03 141,06 6226.37 8175.00 93.58 139.66 6226.93 8200.00 94,13 138.g6 6223.25 8225.00 94,67 136.~ 6221,33 8240.23 95.00 136.00 62~0.05 82~0.00 94.86 135.43 6219.21 8~75.00 94.51 133,97 6217.17 [asks PROPOSAL LISTING Page 1 Your ref z I~-O?A Version #6 Lo~t revised : 20-NOV-g& R E C T A N ~ U L A R Dogleg Vert O R I D C 0'0 ~ O $ C 0 o R O ! N A r E S Dee/IOOf: Sect Eaetfng Northtr~ 2309.325 238~.66~ 0,00 3315,69 ~30775,58 5~82012.65 ~3Zl.37S 239§.15E 1.55 3333.7~ ~30789.1! 5~82000.66 2333.~9S 2408,72E 1.55 3351,87 53080~,73 5~81988.59 2345.68S 242~.38E 1.55 $370.13 530816,4~ 5981976.&5 2348.13$ 2425.13E 1.~5 3373.80 530819.20 59819?4.02 23~8.1~S a~36.24E 10.~0 3388,71 530830.3S 5~81966.07 2371.16S 2~50.49E 10.00 3407.98 530~.6~ 59819~1.09 238~.78S 2465.10E 10.00 3427.93 53085~.30 5981937.53 2398.96S 2480.0~E 10.00 ~448.51 53087A.31 5981923.~1 2413.67S Z~95.30E ld.O0 3469.69 2428.~S 2510.83E 10.00 3~91.43 S~090~.21 5~81893,61 2443.59S 2525.6~E 10.00 3512.29 5309Z0.0~ 5~81878,97 244~,57S ZS26,62E 8.00 3513.~ 530921.06 59818~.~ 2460.76S 2542,47E 8.00 3536.33 330936.97 5981861.87 2~77.46S 2558,2~E 8.00 3589.30 53~52.80 2q94.~S 25~.90E B.O0 358Z.5~ 530968.5~ 5981828,10 9512.33S ~589.44E B.O0 3606.0~ 53098&.14 5~81810.49 2530.~5S 2604.~3E 8.00 3629.78 53~.61 5981792.43 2549.00S 2620.07E 8.OO 3053.71 531~1~,~Z 598~7~.e~ 2567.96S 2635.13E 8.00 3677.81 ~31030.05 5981755,04 2587.31S Z650.OOE 8.00 3702.05 531~6.99 59~1~5.76 2607.0ZS 2~.~E 8.00 3726.~0 531059.71 5981716.11 Z627.06S 26~.0~ 8.00 3750.83 5~107~.20 5981696.1~ ~6q7.~ZS 26~3.22E 8.00 3775.31 26~.06S 2707,12E 8.00 37~.8~ 26~.97S 27ZO.~E 8.00 3SZ6.31 531116.12 5~81634.39 2710.11S 2~.Oq~ 8.00 3~8.76 531129.51~ 5981613.30 2721.20S 27~0.8~E 8.00 3861.~6 531136.3~ ~98t602.~4 2~1.61S 2~7.16E 6.00 3~.17 5311~2.69 5981592.05 2752.A6S 2760.63E 6.00 3897.~ 53115&.26 5981571.~ 27~.16S 277~.63E 6.00 3922.30 531170.3~ 598~50.~1 2~3.52S 2789.12E 6.00 3q47.01 53118~.91 5981530.12 2813.51S 2806.10E 6.00 3971.~ 531199.97 5981~10.19 9833.12S 2819.56E 6.00 3996.&~ 531215.51 5~1~90.~ 285~.36S 2835.~8E 6.00 4091.52 531231.50 5981~71.~9 2871.15S 2851.86E 6.00 4066.~3 2~9.50S 2868.~E 6.00 4071.35 53126~.85 2900.54S 28~.15E 6.00 ~086.53 531275.35 5981~.~6 2907.51S 2885.94E 6.00 4096.26 53128~.17 ~981~16.53 2225,03S 2~03,65E 6.00 ~121.17 531~99.95 59813~.07 83~0.00 96.15 132.51 6215.28 Zg42.11S 2921.81E 6.00 ~146.07 ~31318.18 5961382,0? 832~.00 93,79 131.05 62~3.55 Z958.72S 2940.41E 6.00 ~170.9~ 531336.84 5981365.~3 8350.00 93.43 129.59 6Z11.97 2974,875 2959.43E 6.00 ~195.77 531355.92 $981349.46 8375.00 93.07 128.13 6210.56 2990.52S 2978.87E 6.00 ~220.53 531375,~2 5981333.88 8~Oe. O0 ~2.70 126.68 6209.30 3005.695 29~8.?0E 6.00 ~245.22 5313911,31 5981318.80 8~25,00 92.33 125.22 6208.20 3020.35S 3018.92E 6.00 4269,8~ 8450,00 91.96 123.77 6207,~6 3034.50S 3039.51E 6,00 ~294,$0 8*75.00 91.59 122.31 6206.G9 30q~.125 3060,46E 6.00 0318.65 8500.00 91,2~ 120.86 6205.8? 3061.21S 3081,?~E 6.00 ~342.86 ~525,00 90.85 119.61 6205.4~ 3073.76S $103.36E 6.00 4366.91 531415.59 5981304.20 531436,23 5981~90.15 531~57.~3 3981276.61 531478,57 5981263.61 ~31500.23 5981251.1~ ALI data [n feet unless otherwfse stated. CslcuLetfon use~ mfnlmum curvature method, Coordinates tram 18-07 and TVO ~rom ?kb - ~SL ~ ~lft. Bottom hole d{atence ~ 5419.98 on azi~uth 134,92 degrees from wellhead, Vertfca[ section iu fre~ wetlhood ~ a~fn~th 135,97 degrees. ~rid ia alaska - Zone 4. Grid coordinates tn FEET and computed USing the Clarke - 1866 spheroid Presented by asker Hughes [N~EQ ............ ,-..~ .c n~ ^nu T. zqq-~q~-~06'OI 0-31NI S3HDAH ~3~tJE t. · ARCO Pad 10,1Q-07 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page Your ref : I=-O?A Vermien#6 Laat revised : 20-Nov-98 Meaaured lr~c[in Azln~th True Vert R E C T A N G U L A R Deg[eg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T ~ $ Oeg/lOO~t Sect 8550.00 90,48 117.g~J 6205,13 3085.76S 31~5,29E 6.30 4390.78 8575.00 90,10 116.50 6205.01 3097.20S 31~7.52E 6.00 4414.45 8581,92 90.00 116.10 6205.00 3100,26S 3153.T~E 6.00 85~.08 89.50 117.00 6205.07 3107,93S 316~.08E 6.00 ~437,15 8600,00 89.50 117.06 6205.08 31o8,355 316~.~0E 4,00 4438,02 8625.00 89.~8 118,0~ 6205.31 ]119.91S $192,06! ~.eO 8650.00 89.46 119.04 6205,5~ 3131.85S ~214.02E 4.00 8675.00 89,66 120.0~ 6205.78 31~,18S ~5.77E ~,OO ~09.56 8700.00 B9.6~ 1Z1.0~ 62~,03 3156.885 3~57.30E 4,00 87~5,00 89.GO 12~.0~ 6~.29 3169.95S 3278,61E ~.00 8750.00 8~.38 123.0~ 620&.55 3183,~0s 3~,~8~ R,O0 ~582.18 87~.00 S9.36 lZ~.O~ 6~06.83 3197.21S 3~gO,~2E ~.00 ~606.60 ~00.00 Se.3A 125.0~ 6207.11 3211.39S ~361.11E &.O0 ~5.00 S9,3E 1~6.04 6207,40 3225.92S 3361.45E ~,00 8850.00 89.30 127.05 6207,70 ]240.81S 3381.53E 6,00 a873.00 69.29 128,05 62~8.01 3g~6.0~S 3~01,35E ~.00 L?05,07 8900.00 89.27 129,05 6208.32 3~71.6~S 3~20.90e 4.00 ~729.86 89~0.00 89.~] 1~1.0~ 6208.9~ ~0~,~ ~$9.17~ 4.00 897~.00 ~9,~1 132.05 6~09.~ ~320.36~ ~,~E ~.00 ~80;.~1 9000.00 89,~0 1~.0~ 6209.67 ~3~7.27S 3t96,~0~ ~.00 9025.00 89,18 1~4.0~ 6210.0~ ~54.~9S ~1~.~1~ ~.00 9050.00 89.16 115.05 6210.~8 3372.03S 35]~.2~ ~.00 9075.00 89.1~ 115.05 6~10.~ ~38~.87S S549.~E ~.00 4904,4~ 9100.00 89.1~ 117.05 6211.I~ ~08.02S ~5~.92E ~.OO 4929.42 91~5.00 89.11 138.0~ 6Zl1.51 3~26,475 3583.79E 4.00 4954.41 ~1S0.00 89.10 139,06 ~211.90 3445,~0$ 3600.34E 4,00 4979.~8 91~.00 89.0B 140.06 6212.30 3~.2]S 3616.55E ~.00 5004.33 ~00,00 89.07 1~1,06 4212.70 548~.~3~ 363~.43E ~,00 ~22~.00 89,0~ 14~,06 6213.11 ]~0],11~ ]6~1,~7~ ~,00 505~.1~ 9250.00 89.0~ 143.06 6213.53 3522.95S 3663.17E ~.00 5078.95 ~2~.~ 89.02 144.06 6213.95 3563.06S ]678.02E 4.00 5103.73 ~300.00 89.01 145.~ 6~14.38 3563.43S 3692.51E ~.00 5128.44 ~3~5.00 89.00 146.~ 6~14.82 3586,04S 37~.65E 4.00 5153.09 9350.00 8~,98 147.~ 6215,26 3604.90S 3720.42E 4.00 5177.~ 9375.00 ~.97 148.06 ~215.70 ~6~6.00S 3~3.82E ~.O0 520~.14 9400,00 ~.96 149.07 6~16.16 3~7.33S 3746.~E 4.00 9425.00 ~.9& 150.0r 6216.62 3~8,888 3759,52E &.O0 5250,8~ 9450.00 ~,93 1al.Or 6~17.08 3690.65S 3771,80E ~.00 5275.02 9475.00 ~.92 152.0r 6217.55 ~712.~3S ]783.70E 6.00 5299.10 ~00.00 88.91 153.07 6218.02 3~.alS 3~5.22E ~.00 9S25,00 88.90 154.07 6218.50 3~7.20S ~06.3~E 4.00 5346,88 9550.00 88.89 155.07 6218.~ 37~,7~S 381r,OgE ~,00 ~F0.56 9575.00 ~,88 1~6.0? 6219.~7 3SO~.f3S 3827.41E 4,00 5394.11 ~600.00 ~.87 157.07 6219.97 3825.46S ~37+35E 4.00 5417,51 ~601.6? ~.86 157.14 6220.00 3~27.00S 3838.00E 4,00 ~419,07 ORID COORDS Eaatlr~ Northi~ ~31550.69 5981224.85 531566.0? 5981217.2~ 5~1566.89 5~81 531611.1t ~9~1193.50 531632.91 ~981181,~7 53165~.48 5961168,65 531675.~ 5~S1155.~ 5316~.~ 59811&2.30 53171~.85 ~1128.57 531~8.50 5~1114.4~ 531~8,~ 5981100,0S 5~ 1779.03 531798.91 ~31818.52 5981054.57 531837.86 5~10~8.~ 531856.91 59~102Z.56 5318~.68 5981006.~ 5~189~. 16 5980989.~3 5~1912.]5 59809~.08 5~19]0.2S 598095~.61 ~319~7.80 ~9~09~6.~ 551965.06 59~18,76 53198Z .00 5980~00,38 531~8.6g 5980881, ~3g01~.91 598086~. 76 S~Z030.~ 598084~.5Z 532061.75 598080~.~ 5~2076.68 598078~. 17 5~2091 .~5 532105.47 5980743.3t 53~119.3~ 5980722.5S 532~32,81 5980701.~6 53~I~5.93 5980~0.19 5321~B.67 5980658.69 '53~171,~ 5980636,97 53~183.03 53219~.63 5980~9Z.91 532216.~ 5980548.0~ 532227,09 5980525.33 53Z~37.11 5980502. All data in feet unless otherwise stated, Calculation uses mlni~a curvature ~th~. Coordinates from la-07 and T~ fro~ rkb - NSL ~ 91ft. aett~ hole distance i~ 5&19.98 on azi~th 134.92 degroe~ fro~ Vertical section is fr~wellhead on a~l~th 135.~7 degrees. Grid ~a alaska - g~ne 4. Grid coordieatea In EEET end c~ut~ u~fn~ the Clarke - 1866 Presented ~ Baker Hus~ea INTE~ *,n'J Tr,,",'nk, oC.,T c~n n7 ^nkl Tzqq-.~qz-)OR:'C[]~ 031NI $3HgNH :aq)lW8 ARCO Alaskn, l~c. Pad la, lq-O? Kupsruk ~ivor 13Itt,North ~lOl~, Alaska PROPOSAL LiSTInG Page 3 Your ref : l~-07A Veratofi #6 Last revi~cd z 20-Nov-98 Cmment~ fn weLtpath NO T~ Rectsnguter Coords. Coe~ent 7~0.00 &053.68 234G,15~ 2625.13E KOP - 7480 NO, 6053,68 TVOss 80t3.00 6230.00 2721,20S 2760.84E $ - 62301 8581.92 6205.00 31~0.26S 3153.73E 4 - 6205' Targets a~aoclated ~ith this -.LLpath Target na~e Geographfc Location T.V.D. Eectongu[ar coerd{nates Revised 1a-O?eh~ 5~2250.000,5980500.000,0.0000 6220.00 3827.95S )8~0.2~E 2-Nov-9~ ITT KRU 1Q-07A Proposed CT Sidetrack Horizontal 3-1/2" 3-1/2" Camco TRDP SSSV Packer 7239'~ D Nipple 7255' Top of 2-3/8" Liner in 3-1/2" Tbg. tail @ ~7250' Tbg Tail 7268' 2-3/8" Cemented Liner ~7250' to TD 2-3/8" Liner to be perforated Junked 3-1/2" tubing stub 7573' Packer 7677' Tbg StubTail 7708 7" casing shoe @ 8089' Window cut in 7" at 7525' Current perforations to be cement squeezed with t7 ppg cmt 2-3/4" Open hole TD @ ~ 9822' LIJ ARCO Alaska Struciure : Pod iQ Slot: 1C-07 } I Field ' Kuparuk River Un'~t Location : North Slope, Alaska, £ast (feet) -> ! t_ _: I , I I , , I ' I - ! I ! I I I : I ~ T;, er. - 5,95~.66 Tvd, 230S.32 ~ 2~B1.66 £ KGF - 746C M3, 605J.6~ .-~Dss 3- 5230' ~-- 6205' -.5. & E:d o,~ =-'cc- - 522C.0.'I Tvd, 5827.GP, $, 5~5E.OC, E T.' iC-C7eEs · on - 46.:5 inc, 7~30.C0 Me, 59~E.85 Tvd, 35:5.5S v~ - 62C5' ~ i m m m I m m m m m , . I '1 'm I I---. , m , , i m I I , i v .. .... . .. Vertical Section (feet) -> F ~ 2zoo - 3CCC -- - 3200 '. ! ! -3830 !: . . ftc -- L. Azimuth 1 35.57 with reference C.CO N, O.OOE from " STATE OF ALASKA .... - ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abando Alter casing _ Change approved program 2. Name of Operator Suspend _ Repair well _ Plugging __ Pull tubing 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1560' FNL, 1239' FEL, Se¢.26, T12N, R9E, UM At top of productive interval 1416' FSL, 1137' FWL, Sec. 25, T12N, R9E, UM At effective depth At total depth 1038' FSL, 1557' FWL, Sec 25, T12N, R9E, UM Operation Shutdown __ Re-enter suspended well _ Time extension _ Stimulate_ Variance Perforate Other -- 6. Datum elevation (DF or KB) 91' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1Qo07 9. Permit number 84-218 10. APl number 50-029-21234 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8013' feet Plugs (measured) None 6479' feet 7806' feet Junk (measured) None 6354' feet Casing Length Structural Conductor 108' Surface 3680' Intermediate Production 8065' Size Cemented 16" 240 sx CS II 108' 9.625" 850 sx CS III 3715' & 650 sx CS II 7" 613 sx Class G 8098' Liner ,n depth: measured 7388'-7464', 7522'-7540', 7600'-7608', 7758'-7775',7788'-7808', 7903'-7909' true vertical 6078'-6127', 6165'-6i'77', 6216'-6221 ', 6319'-6330', 6338'-6352', 6413'-6417' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7268' Packers and SSSV (type and measured depth) Baker 'liB' Retr. Pkr @ 7239', Camco SSSV TRDP-1A-SSA @ 1800' Measured depth True vertical depth 108' 3524' 6620" i!~i 13. Attachments Description summary of proposal X Detailed operation program B~.sketch ~ 14. Estimated date for commencing operation November 1998 Oil X 16. If proposal was verbally approved . Name of approver Date approved Service 17. I hereby certify that the foregoij;K~is true ~. _r~l.. correct to the best of my knowledge. Signed t _.._.:~...;¢,~?f.t<.,,~ ~.~'?¢~ Title Kuparuk Drilling Team Leader '~'-"- "-"- FOR COMMISSION USE ONLY O0r~ditions of approval: Notify Commission so representative may witness 15. Status of well classification as: Gas _ Suspended_ Date f ! f ¢ ,¢c Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN T/~ICATE · WELL PERMIT ~CKLIST COMPANY ,~.?~ _ WELL NA_M_ E ,~, ~.,~', .//~(~) -~.,~,,~. PROGRAM: exp [] dev~'redrl~-~e-~'v [] wellbore segl, ann. disposal para req, FIELD & POOL. C/. _..~...~;,. ADMINISTRATION 1. ~ D T /~-~5. INIT CLASS ~ Permit fee attached ....................... 2. Lease number appropriate ................... 3 Unique well name and number .................. 4 Well Iocaled in a defined pool ................. 5 Well Iocaled proper distance from drilling unil boundmy. . . 6 Well Iocaled proper distance from other wells ......... 7. Sufficienl acreage available in drilling unil ......... 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued wilhout conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... t5. Surface casing protects all known USDWs ........... 16 CMl' vol adequale to circulate on conductor & surf csg ..... ! 7. CMI vol adequate to tie-in long string to surf csg ........ 18. CM 1' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23, If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .5"oroo .psig 27. Choke manifold complies w/APl RP-53 (May 84) ........ GEOL AREA ~,,~--~ UNIT# ON/OFF SHORE C9 N (~N C~ N (~N 28. 29. GEOLOGY 30. 31. 32. 33. ANNUL__..._~A_R. DISPOSAL 35. With proper cemenling record'~his plan (A) will contain waste in a suitabl~.receiving .z.j~e; ....... APPR DATE ([3) will not contaminate freshwater;"~.c~ drilling waste... to surface; ........ (C) will not impair mechanicaLin~grity of'ff~,~well used for disposal; (I)) will not damage producing formation or im"pa, ir recovery from a po(fi; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. G EQ_L.~_ _y.: ENGINEERING: UIC/A/ula'r" COMMISSION: JDH ~ N Work will occur without operation shutdown ........... N Is presence of H2S gas probable ................. N Permit can be issued w/o hydrogen sulfide measures ..... YvY N .~_.__;. ,,~ Dala presented on potential overpressure zones ....... Y ..... .7'- ........................................................................................................................................................ Seismic analysis of shallow gas zones. ' Seabed condition survey (if off-shore) ............. Cogtacl,nam. e/phone for weekly progress reports ....... // Y N lexp~oratory only] Y N Y N Y N Y N Y N DWJ ~ RNC Cornmentsllnstructions: M cheldl,'~,l 'u;v 05/291gB alii C ~m';{)lh( ~?\wt)l(lli'llJ\(Jl;ililJ\, 11~ ,, I h,I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 99/ 6/14 BHI 01 **** TAPE HEADER **** MWD 99/ 6/14 102544 01 LIS Customer Format Tape LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ Remark File Version 1.000 Extract File: header.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information STRT.F 7400.0000: Starting Depth STOP.F 9500.0000: Ending Depth STEP.F 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ARCO Alaska, Inc. WELL. WELL: 1Q-07APB1 FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 1560' FNL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1 3/4" NaviGamma -Gamma Ray REF . JOB REFERENCE: 102544 DATE. LOG DATE: 10 Dec 98 API. API NUMBER: 500292123470 ~Parameter Information Block #MNEM.UNIT Value Description # FL 1239' FWL : Field Location SECT' 26 : Section TOWN.N 12N : Township RANG. 9E : Range PDAT. M.S.L. : Permanent Datum EPD .M 0' : Elevation Of Perm. Datum LMF . KB : Log Measured From FAPD.FT 91' : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 91' : Elevation Of Kelly Bushing EDF .F N/A : Elevation Of Derrick Floor EGL .F N/A : Elevation Of Ground Level CASE.F 7498 : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (3) Ail True Vertical Depths are reported as Subsea (TVDSS) with reference datum KB of 91'. (4) Ail Gamma Ray data (GRAX) presented is realtime data. (5) Well 1Q-07APB1 is represented by runs 5, 7, 8 and 9 which are all Directional with Gamma Ray. (6) Well 1Q-07APB1 was kicked off @ 7490' MD (6062' TVDSS), from the the wellbore originally drilled for Well lQ-07. (7) Run 1 through run 4 were milling runs, and no logging data was acquired in new hole. (8) The gap in the log from 8589' MD (6218' TVDSS) to 8607' MD (6217' TVDSS) was due to a depth adjustment applied after a tie-in. (9) The interval from 9426' MD (6263' TVDSS) to 9443' MD (6263' TVDSS) was not logged due to the sensor to bit offset. (10) Well 1Q-07APB1 was drilled to 9443' MD (6263' TVDSS) on Run 9. The TD was shifted to 9470' MD (6263' TVDSS) after applying a post run tie-in depth adjustment o~ 27' (11) A Magnetic Declination correction of 27.23 degrees has been applied to the Directional Surveys. (12) The gamma ray log presented here is the Primary Depth Control per Doug Dickey at ARCO Alaska. ~Mnemonics ROPS -> Rate of Penetration (ft/hr) GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) TVD -> True Vertical Depth (Subsea), feet ~Sensor Offsets RUN GAMMA DIRECTIONAL 5 12.31 ft. 16.51 ft. 7 16.80 ft. 21.00 ft. 8 16.70 ft. 20.90 ft. 9 16.70 ft. 20.90 ft. Tape Subfile: 1 75 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 1Q-07APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~234567890~234567890~234567890~23456789~~234567890~234567890 !!!!!!!!!! !!!!!!!!! Remark File Version 1.000 1. The data presented here is the Primary Depth Control for the well per Doug Dickey at ARCO Alaska. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0 . 0 * FORMAT RECORD (TYPE% 64) Entry Type 1) Size 1) Data record type is: Entry Type 2) Size 1) Datum Specification Block Entry Type 3) Size 2) Datum Frame Size is: Entry Type 4) Size 1) Logging direction is down Entry Type 5) Size 1) Repcode(66) 0 Repcode( 66 Type is: 0 Repcode( 79 12 bytes Repcode(66) (value= 255) Repcode 66) Optical Log Depth Scale Units:' Feet Entry Type 8) Size 4) Repcode Frame spacing: 0.500000 Entry Type 9) Size 4) Repcode Frame spacing units: [F ] fndun c IF ] 1.00000000 Entry Type(11) Size( 4) Repcode Number of frames per record is: Entry Type(13) Size( 1) Repcode One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode Datum Specification Block Sub-type is: 1 Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 68) 65) 3 68) 84 66) 66) Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 4 2 ROPS MWD 68 1 4 * DATA RECORD (TYPE% 0) 1014 BYTES * Total Data Records: 51 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape File Start Depth = 7400.000000 Tape File End Depth = 9500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 12607 datums Rep Code: 79 2 datums Tape Subfile: 2 58 records... Minimum record length: 18 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER **** MWD 99/ 6/14 102544 01 1 3/4" NaviGamma, Gamma Ray Log Data **** REEL TRAILER **** MWD 99/ 6/14 BHI 01 Tape Subfile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 14 JUN 99 5:49a Elapsed execution time = 1.09 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 7400. 7400. 7500. 7600. 7700. 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 GRAX 0000 -999. 5000 -999. 0000 126. 0000 109. 0000 133. 0000 138. 0000 106. 0000 112. 0000 97. 0000 124. 0000 62. 0000 76. 0000 62. 0000 -999. 0000 66. 0000 98 0000 120 0000 133 0000 144 0000 130 0000 120 0000 151 0000 -999 ROPS 2500 -999.2500 2500 -999.2500 0000 18.0000 2000 23.4280 5000 41.3000 0000 49.5620 4740 94.7000 5000 102.8000 5000 81.8000 5000 38.0290 1220 78.2000 5000 85.7000 5990 116.1000 2500 46.9960 0810 97.2000 7850 109.0000 0000 22.9000 5000 100.0000 0000 83.7000 2500 102.5790 0000 92.3000 5000 75.0000 2500 -999.2500 Tape File Start Depth = 7400.000000 Tape File End Depth = 9500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 99/ 6/14 BHI 01 **** TAPE HEADER **** MWD 99/ 6/14 102544 01 LIS Customer Format Tape LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ Remark File Version 1.000 Extract File: header.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block ~MNEM.UNIT Data Type STRT. F STOP. F STEP. F NULL COMP WELL FLD LOC CNTY STAT S RVC TOOL REF DATE API 7400.0000 9800.0000 0.5000 -999.2500 COMPANY WELL FIELD LOCATION COUNTY STATE SERVICE COMPANY TOOL NAME & TYPE JOB REFERENCE LOG DATE API NUMBER CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth : Ending Depth Level Spacing Absent Value : ARCO Alaska, Inc. : 1Q-07A Kuparuk River Unit : 1560' FNL : North Slope Alaska : Baker Hughes INTEQ : 1 3/4" NaviGamma - Gamma Ray 102544 16 Dec 98 500292123401 ~Parameter Information Block %MNEM.UNIT Value Description ~ -- FL 1239' FWL : Field Location . SECT 26 : Section TOWN.N 12N : Township RANG. 9E : Range PDAT. M.S.L. : Permanent Datum EPD .M 0' : Elevation Of Perm. Datum LMF . KB : Log Measured From FAPD.F 91' : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 91' : Elevation Of Kelly Bushing EDF .F N/A : Elevation Of Derrick Floor EGL .F N/A : Elevation Of Ground Level CASE.F 7498 : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks 1) Ail depths are Measured Depths (MD) unless otherwise noted. 2) Ail depths are Bit Depths unless otherwise noted. 3) Ail True Vertical Depths are reported as Subsea (TVDSS) with reference datum KB equal to 91'. 4) Ail Gamma Ray data (GRAX) presented is realtime data. 5) Well 1Q-07A is represented by runs 10, 12 and 14 which are all Directional with Gamma Ray. . (6) Well 1Q-07A was sidetracked @ 8745' MD (6216' TVDSS), from the wellbore of Well 1Q-07APB1. (7) The log for Well 1Q-07A has been consolidated with that of Well 1Q-07APB1. Further details can be obtained from the log of Well 1Q-07APB1. (8) The interval from 9724' MD (6173' TVDSS) to 9740' MD (6173' TVDSS) was not logged due to the sensor to bit offset. (9) Well 1Q-07A was drilled to 9740' MD (6173' TVDSS) on Run 14. The TD was shifted to 9782' MD (6173' TVDSS) after applying a post run tie-in depth adjustment of 42'. (10) A Magnetic Declination correction of 27.23 degrees has been applied to the Directional Surveys. (11) The gamma ray log presented here is the Primary Depth Control (PDC) for the well 1Q-07A per Doug Dickey at ARCO Alaska. ~Mnemonics ROPS -> Rate of Penetration (ft/hr) GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) TVD -> True Vertical Depth (Subsea), feet ~Sensor Offsets RUN GAMMA DIRECTIONAL 10 16.18 ft. 20.36 ft. 12 16.72 ft. 20.72 ft. 14 16.18 ft. 20.38 ft. Tape Subfile: 1 73 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 1Q-07A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~234567890~23456789~~234567890~234567890~234567890~234567890~23456789~ !!!!!!!!!!!!!!!! ! !! Remark File Version 1.000 1. The data presented here is the Primary Depth Control for the well per Doug Dickey at ARCO Alaska. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entr.y Type 1) Size( 1) Repcode 66) Data record type is: 0 Entry Type 2) Size( 1) Repcode 66) Datum Specification Block Type is: 0 Entry Type 3) Size( 2) Repcode 79) Datum Frame Size is: 12 bytes Entry Type 4) Size( 1) Repcode 66) Logging direction is down (value= 255) Entry Type 5) Size( 1) Repcode 66) Optical Log Depth Scale Units: Feet Entry Type 8) Size( 4.) R~pcode 68) Frame spacing: 0.500000 Entry Type 9) Size( 4) Repcode 65) Frame spacing units: IF ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 4 2 ROPS MWD 68 1 4 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 58 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape File Start Depth = 7400.000000 Tape File End Depth = 9800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 14407 datums Rep Code: 79 2 datums Tape Subfile: 2 65 records... Minimum record length: Maximum record length: [] 54 bytes 1014 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER **** MWD 99/ 6/14 102544 01 1 3/4" NaviGamma, Gamma Ray. Log Data. **** REEL TRAILER **** MWD 99/ 6/14 BHI 01 Tape Subfile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 14 JUN 99 5:39a Elapsed execution time = 1.21 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 7400 0000 7400 5000 7500 0000 7600 0000 7700 0000 7800 0000 7900,0000 8000,0000 8100.0000 8200.0000 8300.0000 8400.0000 8500.0000 8600.0000 8700.0000 8800.0000 8900.00O0 9000.0000 9100.0000 9200.0000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 GRAX -999.2500 -999.2500 126 0000 109 2000 133 5000 138 0000 106 4740 112 5000 97 5000 124 5000 62 1220 76 5000 62 5990 -999 2500 66 0810 92 0440 132 8600 65 700O 114 3500 85 1420 94.3830 132.1300 164.9800 139. 6730 127.0200 -999.2500 ROPS -999.2500 -999.2500 18.0000 23.4280 41.3000 49.5620 94.7000 102.8000 81.8000 38.0290 78.2000 85.7000 116.1000 46.9960 97.2000 105.8000 75.0000 100.0000 107.1170 70.5000 65.4000 116.1000 40.2820 23.3170 48.6000 -999.2500 Tape Tape File Start Depth = 7400.000000 Tape File End Depth = 9800.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Subfile 3 is type: LIS
