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200-194
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 5, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-04A KUPARUK RIV UNIT 1A-04A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 1A-04A 50-029-20621-01-00 200-194-0 N SPT 4798 2001940 1500 980 1230 1240 1250 320 320 320 320 REQVAR P Josh Hunt 7/8/2025 2-year MIT-IA required by AIO 2B.011 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 1A-04A Inspection Date: Tubing OA Packer Depth 390 3290 3230 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250709090124 BBL Pumped:1.7 BBL Returned:1.7 Tuesday, August 5, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 5, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-04A KUPARUK RIV UNIT 1A-04A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 1A-04A 50-029-20621-01-00 200-194-0 N SPT 4798 2001940 1500 860 3300 3140 3100 320 320 320 320 REQVAR P Josh Hunt 7/8/2025 2-year MIT-T Required by AIO 2B.011 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 1A-04A Inspection Date: Tubing OA Packer Depth 380 600 600 610IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250709085123 BBL Pumped:1.8 BBL Returned:1.5 Tuesday, August 5, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-04A KUPARUK RIV UNIT 1A-04A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-04A 50-029-20621-01-00 200-194-0 N SPT 4798 2001940 1500 1460 3020 2950 2920 292 292 293 293 REQVAR P Adam Earl 7/12/2023 MIT-T tested as per AIO 2B.011 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 1A-04A Inspection Date: Tubing OA Packer Depth 300 420 420 420IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714085440 BBL Pumped:1 BBL Returned:1 Friday, September 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-T AIO 2B.011 James B. Regg Digitally signed by James B. Regg Date: 2023.09.01 15:53:25 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-04A KUPARUK RIV UNIT 1A-04A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-04A 50-029-20621-01-00 200-194-0 N SPT 4798 2001940 1500 1390 1640 1660 1660 292 309 310 310 REQVAR P Adam Earl 7/12/2023 MIT-IA tested as per AIO 2B. 011 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 1A-04A Inspection Date: Tubing OA Packer Depth 280 3010 2950 2940IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714085815 BBL Pumped:1.8 BBL Returned:1.8 Friday, September 1, 2023 Page 1 of 1 9 9 9 9 9 9 99 99 9 9 9 9 AIO 2B. 011 James B. Regg Digitally signed by James B. Regg Date: 2023.09.01 15:50:57 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2021 TO: Jim Regg � P.1. Supervisor �� /(ol'JeL SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 A -04A FROM: Austin McLeod KUPARUK RIV UNIT 1A -04A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv�— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A -04A API Well Number 50-029-20621-01-00 Inspector Name: Austin McLeod Permit Number: 200-194-0 Inspection Date: 7/3/2021 Insp Num: mitSAM210704162042 Rel Insp Num: Packer Depth Well IA -04A -.Type Inj N 'TVD 4798 Tubing PTD 2001940 Type Test sPT Test psi 1500 IA BBL Pumped: 0.8 - IBBL Returned: 0.8 OA -- L -- - - I-nterval L REQVAR/P F P Notes: MITT, AIO 213.011. Plug at 8532' MD Pretest Initial 15 Min 30 Min 45 Min 60 Min 1400 3030 2970 2950 260 410 410- 410 - --- 270. 270 270 270 - — - — --- - Wednesday, July 14, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 A -04A KUPARUK RIV UNIT 1A -04A Sre: Inspector Reviewed By: P.I. Supry S6r— Comm Well Name KUPARUK RIV UNIT IA -04A API Well Number 50-029-20621-01-00 Inspector Name: Austin Mcleod Permit Number: 200-194-0 Inspection Date: 7/3/2021 ✓ Insp Num: mitSAM210704162340 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WellT 1A -04A Type Irij N" TVD 4798 Tubing 1350 - 1640 - 1660 - PTD 2001940 Type Test SPT" Test psi 1500 IA 300 3010 2930 - 2920 - ------� ----- BBL Pumped: 1 7 - BBL Returned: 1.6 - OA 270 -. 280 -280 - 280 � - Interval REQVAR p/F I P,✓ _ - Notes: M1TIA. AIO 2B.01 I Wednesday, July 14, 2021 Page 1 of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Thursday, April 2, 2020 5:04 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1A -04A (PTD 200-194) Follow up email Attachments: 1A -04A 90 day TIO trend 4.2.20.pdf Chris, Q4 of last year I spoke with you about A1O 26.011 for 1A -04A and whether or not it would need to be revised post 1A - 04A CTD lateral L1. The well was BO1 and passed a SW MITIA shortly after our conversation and has been online since. You had asked for a follow up email if I didn't hear from you first. My interpretation of the 10-401 for 1A-04AL1 (PTD 219-065) is that it does not affect A1O 26.011 governing 1A -04A (PTD 200-194) and the rules of AIO 26.011 remain in place with no need for revision. I intend to consider this matter closed unless you advise otherwise. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Cell phone: (808) 345-6886 Office phone: (907) 659-7224 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ric!>civM) NOV 14 2019 Annnn 1. Operations Abandon E]Plug Perforations ElFracture Stimulate E]Pull Tubing EJa Flu n ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WHIPSTOCKO 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service ❑ 200-194 3. Address: P. O, Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-20621-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25647 KRU 1A -04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,161 feet Plugs measured None feet true vertical 6,659 feet Junk measured None feet Effective Depth measured 9,062 feet Packer measured 6289, 6358 feet true vertical 6,587 feet true vertical 4796, 4842 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 feet 16 80' MD 80' TVD SURFACE 2,959 feet 10 3/4 " 2,990' MD 2631' TVD PRODUCTION 6,551 feet 7 6,580' MD 4987' TVD LINER 2,814 feet 4 1/2 " 9,160' MD 6657' TVD Perforation depth: Measured depth: 8848-8861. 8870-8916 feet True Vertical depth: 6434-6443. 6449-6482 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 6,357' MD 4,841' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER S-3 PACKER 6,289' MD 4,796' TVD PACKER - BAKER ZXP LINER TOP PKR 6,358' MD 4,842' TVD SSSV -NONE 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 Casing Pressure Tubing Pressure Prior to well operation: - - 1842 910 1 2585 Subsequent to operation: - - 2348 1269 1 2436 14. Attachments (required ger20 AAc 25.070, 25.071, a 25283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service E) Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG p GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-179 contact Name: James Hayes Authorized Name: James Ohlin er contact Email: James. C.Hayes@cop.com Authorized Title: Staff CTD Engineer ` Contact Phone: 907 265-6927 Authorized Signature: �- � ��� �'u/�—:• Date: Form 10-404 Revised 4/2017 VT` allk / diWr6 rq BDMS � NOV 18 2019 Submit Original Only 1A -04A SET WHIPSTOCK DTTM JOBTYP SUMMARYOPS START 10/1/19 DRILLING CompleteRD checklist on 1C-06, pull sub & pits off 1C-06, move to 1A -Pad, SIDETRACK spot over 1A-04, RU, begin testing BOP'S 10/2/19 DRILLING Test BOPS, Tested stripper, inner reel valve, PT coil connector to 4 k. PT SIDETRACK PDL's. PU & PD BHA#1, 0.6° motor. RIH, 1000 psi under the master, flush well with seawater, tag pinch point @ 8787'. Turn well over to DuoVis. Blow down out micromotion, milled window as planned. 10/3/19 DRILLING Finished milling window exit and rat hole to 8,810', performed reaming SIDETRACK passes and dry drift (clean), POOH, PUD milling assmebly, PU/PD build section assembly BHA #2, RIH, logged formation for depth control, drilled build section from 8,810'-9,360', pumped 5x5 sweep and chased to the window, opened EDC, POOH circulating 2.00bpm, tagged up, PUD build assembly, PU/PD Lateral drilling assembly KUP INJ ConoeoPh)lhpsdmo� ell Attributes AIdSiN, Y1C. NIPPLE WELLNAME 1A -04A WELLBORE 1A -04A 1AMgtt/11A1983i:31 PM WY/l Ytll Last Tag essalsols.-Noud) Annotation ..In Iftel EnE ORE Wellbo,e Lest Mod By ................................................. Last Tag:RKB 8,902.0 31262018 1q -04A 3hausen8 Last Rev Reason HANOER:]83 AnodW.n End Cap, WsR` Last Motl By Rev Reason. SET WH IPS I OCK 9112]2019 11A -04A IdOna, Casing Strings Casing Oescripuon OR (in) IO ImI Top InKR) sm 70d (nnRl sel0eptl,(rvD)... WULenp._Geada TOPTM1read CONDUCTOR 16 15.06 32.1 80.0 800 65.00 H-00 WELDED Casing Doneiplion OD (in) ID(in) Top She) Se[°epIM1 MIS 7et-dind(TVI4 YNLen(I... Grade Top SURFACE 10314 9.95 312 2,990.2 2,631.1 45.50 K-55 BUTT TM1read Casing Deaeriplbn 00 (n) ID Cn) Top IN161 SN CegM1(XKBI Set depth (ry0)... WVLen P... Grade Top PRODUCTION PORT ] 8.28 28.8 6,5800 4,986.7 26.00 K55 BTC Srt Thread ,M�CONOULTOR�32.1 PO. TURING IMPINGEMENT MD Casing Desctlplbn ODdu) ID (in) To (XKDI Bel DeptM1 (nKB) 97-Depth(TVD)... WIJU-ng Glede Top TM1read WINDOWA 7 6.00 614840 6,5050 4,938.5 26.00 K-55 Casing Desc,ipuon OD (in) ID (in) iep lM(a) Set DeptM1 (ttKBI Set Oeplh( D)... WN4n(I... Grade Tap TM1read LINER 41/2 3.96 6,345.6 9,160.0 6,656.6 12.60 LA0 NSCT Liner Details .,pp.,. I Top DUKE) Top(NO)WB) Top Ind fl Ifem Dq Com .mind IT en) 6,345.6 4,8340 4875 PBR PBR TIEBACK EXT. q]50 6.357.7 4,841.9 4881 PACKER BAKER 2XP LINER TOPPACKER 3.930 6,3677 4,8485 48.86 HANGER HMC HYDRAULIC LINER HANGER 3.958 8,532.6 6,208.5 4402 RIPPLE CARCO DB NIPPLE 3.750 SURFALE 3u-2 GO 2- 8,6890 6,320.2 44.56 NIPPLE CAMCO SEAL NIPPLE 3750 Tubing Strings Tubing description Sbing Ma... IO (in) Top (XKRI Se10epM (fl.. $e10epIM1 ITVOI I... Wt(IEIXI Gmde Top Connedhou TUBING 4112 3.9fi 2fi2 Set Deg gtd14 1250 L-80 T CJBT ompletion Details SLEEVE -C E=3 Top IND) I Top Incl Top Vi MKB) P) nem Dca Com 26.2 26.2 O.DD HANGER FMC HANGER Nominal ID (in) 4062 503.1 503.1 1100 NIPPLE CAMCO DB NIPPLE PSG 875"PACKINGB0RE 3.875 37.3 4 Q2 ,762.2 48.21 SLEEVE -C BAKER CMU SLIDING SLEEVE (SHIFTED CLOSED 12131/00) 3.8]5 fi,288.6 4,796.3 48.46 PACKER BAKERS -3 PACKER ,]"x4.5" 3.875 PAC K£RI EI 6,3052 6,3052 4,807.3 48.55 NIPPLE CAMCO DBNIPPLE 3.813 4,8335 48.75 SEALSTEM BAKER SEALSTEM 3.813 NIPPLE. e.3Ra.g 6,397.1 4,835.0 48.76 SEAL -ASSY BAKER 190-07 BH -22 SEAL ASBEMBLY-BTABS INTO LINER PBRIPACKER 3.956 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, Etc.) Top m'D) ropmM K°THREAD's3+3.e Top PIKE) 200.0 (n8e) 200.0 fl 000 Deo TUBING IMPINGEMENT Co. UBING IN WHIPSTOCK, CK, AB 0 RIFT ELY W/370"X18 FT WHIPSTOCK, ABLE TO PASS WI Run Dam 0012019 1377 37]0 3.83" GAUGE RING SEALASSY;dSOA 8,]85.0 6,388.6 44.40 WHIPSTOCK BAKER ENIID L A . "X4-1 "WHIP 0 K, LEFT IN HOLE DAL= 12.98', ORIENTATION IS 1.6" 91122019 1000 LOHS, RA TAG AT 8792.4MD Perforations & Slots snw ABiSi.° Sda0 PRODUCTION PORTN;."'GuePhasing Rbn Me) Top (rvDl Inns) Bhn mDl IIIKeI unxeazone Dme nobft (sWINDOW 1TyeRF F8,848.0 2 I "SHDD tleg 8,8160 6,449.4 8,4822 A -4,1A-04 222001 1 40IPERF lid 61-D DP 60 deg 12 phasing Frac Summary send do pmppanl Oesgned (III) P-ppant In ForRdIn QN) 2/172001 3tgY $br10a[e Top Depth (XKB) BII InKB) 1-blu, Fl.M System Voicissupid) 11SW71DOR 1 2/1]2001 8,848.0 8,916.0 Notes: General 8, Sahety End Dale AnncdRon 1213112000 NOTE SIDETRACKED WELL 8292009 NOTE WAIVERED WELL- PACKER SET TOO HIGH ]129/2010 .IJI ' MediaSCllenudi. Me Alaska SCRun iL9.0 sLms, s73e.c1301Da WHIPST°CM a,mo IPERF Brdbede a10 HPOO a.a+9.0 ( PER E; 8g`d gd80 LINER, 6Sd5.GG 1 W.0 MEMORANDUM State of Alaska Permit Number: Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, November 14, 2019 P.I. Supervisor 1((/�1 ry SUBJECT: Mechanical Integrity Tests 1 ConocoPhillips Alaska, Inc. FROM: Brian Bixby 1A -04A KUPARUK RIV UNIT IA -04A Petroleum Inspector 15 Min 30 Min 45 Min 60 Min Sre: Inspector Reviewed By: P.I. Supry UVR- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -04A API Well Number 50-029-20621-01-00 Inspector Name: Brian Bixby Permit Number: 200-194-0 Inspection Date: 11/10/2019 - InSp Num: mi[BDB191I l l 161834 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type In w -TVD 4798 Tubing 2590 2590 - zs90 - zsso - 0 ' rPumped: IType Test SPT Test psi 3000 IA 1080 3280 3210 ' 3200 1.5 BBL Returned: 1.5 OA 500 610 611 - 608 INITAL p/p p Notes: initial MITIA as per PTD # 219465 Thursday, November 14, 2019 Page 1 of 1 MEMORANDUM TO: Jim Reggj�p� 4 P.1. Supervisor Il -yq �I S j� I FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 30, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1A -04A KUPARUK RIV UNIT IA -04A Ste: Inspector Reviewed By: P.I. Suprv� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -04A API Well Number 50-029-20621-01-00 Inspector Name: Jeff Jones Insp Num: miU1190716084932 Permit Number: 200-194-0 Inspection Date: 7/14/2019 Rel Insp Num: Tuesday, July 30, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA -04A- -Typelnj N 1,TVD� 479, Tubing, 790 3;00 3210 718n PTD 2001940 Type Test, SPT Nest psi 1 3000 '1 IA 26s 197 495 49; BBL Pumped: i 3 BBL Returned: urned 1.3 OA 274 276 - 277 277 Interval REQVAR P/F P L— — Notes: 2 year MIT -T 3000 psi TTP set « 8533' MD per AIO 213.011. 1 well inspected, no exceptions noted. Tuesday, July 30, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission p TO: Jim Regg �� 8 i DATE: Tuesday, July 30, 2019 SUBJECT: Mechanical Integrity Tests P.I. Supervisor ((( ConocoPhillips Alaska, Inc. IA -04A FROM: Jeff Jones KUPARUK RIV UNIT IA -04A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -04A API Well Number 50-029-20621-01-00 Inspector Name: Jeff Jones Permit Number: 200-194-0 Inspection Date: 7/14/2019 ' Insp Num: mitIJ190716085643 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - --T IA 04A 1TYPe Inj N iTVDa798 Tubing' 88o Izoo Izzo - i»_o TD IPum 2ed940 a e BBL Ret Test psi 3000 IA zso 3300 3zoo ,zoo l r - -- BBL � _._� turned: I s "t OA - 276 293 294 ea L Interval REQVAR jP/F — P Notes: 2 Year MIT -IA 3000 psi per AIO 28.011. I well inspected, no exceptions noted. Tuesday, July 30, 2019 Pn_c I ,I I Originated: Schlumberger PTS-PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Deliveredto: �ry AOGCC ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commis[on 333 W. 7th Ave, Suite 100 ,qw Anchorage, AK 99501 20 J 1 94 TRANSMITTAL DATE TRANSMITTAL 0 , WELL NAME API # •r - SERVICE ORDER FIELD r NAME DESCRIPTION SERVICE DELIVERABLE DESCRIPTION DATA Color DATELOGGED Prints CD's to -04A 2A-09 1R-07 50.029.20621-01 50.103-20059-00 50-029-21332-00 EBNL•00001 EOSH-00041 5SH-00042 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL Caliper Revt Caliper Caliper FINAL FIELD FINAL FIELD FINAL FIELD 4 -Apr -19 17 -Apr -19 18 -Apr -19 1 1 1 2A-08 1y-11 50-103-20049.00 50-029-20926.00 DWUJ-00092 EBNL-00016 KUPARUK RIVER KUPARUK RIVER WL WL [PROF LDL FINAL FIELD FINAL FIELD130-Apr-19 28 -Apr -19 -19 1 1 2B-07 to-Ot 2X-10 50-029.21080-00 50-029-20590.00 50-029.21187.00 DWUJ-00093 EBNL-00018 DWUJ-00094 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL [PROF PPROF PPROF FINAL FIELD FINAL FIELD FINAL FIELD -19 -19 1 1 3H-21 25-315 50.103-20094-00 50-103-20776-00 EBSI.00004 EBNL-00020 KUPARUKRIVER KUPARUK RIVER WL WL Caliper PPROF FINAL FIELD19 FINAL FIELD 5 -May -19 1 1 UO 17 2 UO 119 to Sig Please return via courier or sign/scan and email a copy Date Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level atthis point. Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: 4 AOGCC -. ATTN: Natural Resources Technician II t" Alaska Oil &Gas Conservation Commislon �, 333 W. 7th Ave, Suite 100 -%j Anchorage, AK 99501 1! 194 I 620 TRANSMITTAL DATE 9 TRANSMITTALp' 1 WELL NAME 2B-10 1H-108 API # I;j I H 1 4 1 K 11 D r, EIT11111111111 50-029-23608-00 SERVICE ORDER I EOSH-00034 E540-00064 FIELD NAME KUPA1,411,14:4 IT" KUPARUKRIVER DESCRIPTION WL WIL DESCRIPTION ]PROF (PROF DATA FINAL FIELD FINAL FIELD Color r, • r Prints 26 -Mar -19 27 -Mar -19 r 1 1 1H-105 1J-156 1A -04A 50-029-20727-01 50-029.23311-00 50-029-20621-00 E540-00065 EA18.00008 E540-00068 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL IPROF (PROF Caliper FINAL FIELD FINAL FIELD FINAL FIELD 28 -Mar -19 29 -Mar -19 4 -Apr -19 1 1 1 3H-18 50-103-20095-00 EBLV-00002 KUPARUK RIVER WL IPROF FINAL FIELD 6 -Apr -19 1 2K-26 50-103-20126-00 EBLN-00004 KUPARUK RIVER WL Caliper FINAL FIELD 8 -Apr -19 1 10-06 50-029-21224-00 EBSI-00001 KUPARUK RIVER WL PPROF FINAL FIELD 10-Apr•19 1 8 Name Please return via courier or sign/scan and email a copy Date lumberger and CPAL Schlumberger -Private A Transmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU IA -04 Permit to Drill Number: 200-194 Sundry Number: 319-179 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ww .aogcc,alaska.gov Enclosed is the approved application for the 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, J ssie�ielowski Commissioner DATED this 1D day of April, 2019. RBDMS�A/W 112019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® APR 0 5 2p19 0i�C l AOG6 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Whipstock_ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ Sfrati9raphic Service El • 200-194 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-20621-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1A -04A Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25647 0 1 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): 9161' 6659' 9062' 6587' 2602 N/A Ni Casing Length Size MD TVD Burst Collapse Structural Conductor 48' 16" 80' 80' Surface 2959' 10-3/4" 2990' 2631' Production 6551' 7" 6580' 4987' Liner 2814' 4-1/2" 9160' 6657' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8848'- 8861' 6433'-6443 4_1/2" L-80 L- 6357' 8870'- 8916' 6449'- 6482' Packers and SSSV Type: Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 6289' MD / 4796' TVD Baker ZXP Liner Top Packer 6358' MD / 4842' TVD 12. Attachments: Proposal Summary Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/11/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑� GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. j Authorized Name: James Ohlinger Contact Name: Keith Herding Authorized Title: Staff CTD Engineer Contact Email: Keith. E. Herring(a)cop. corn Contact Phone: 263-4321 Authorized Signature: Date: / 1100- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 22 01 Plug Integrity ❑ BOP Test El Mechanical Integrity Test LY Location Clearance ❑ Other: tom✓ t 10 355_00 P5^-9 , ,SOP �}-i�rvlar�rt✓�v.!-Yv �sf"fin 25G�/�k5 Post Initial Injection MIT Req'd? rr riBDMSL'/APR 1 12019 Yes No ❑ Spacing Exception Required? Yes ❑ No Q/ Subsequent Form Required: f APPROVED BY r/ / µl. Approved by: COMMISSIONER THE COMMISSION Date: `o Submit Form and Form 10-403 Revised 4/2017 Approved applic to a NAL- m the date of approval. A chments in Duplicate '� ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 05, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set a whipstock in KRU 1A -04A (PTD #200-194) in order to drill a single CTD lateral using the coiled tubing drilling rig, Nabors CDR3-AC. Attached to this application are the following documents: - 10-403 Sundry Application for KRU 1A -04A - Operations Summary in support of the 10-403 sundry application - Proposed CTD schematic - Current wellbore schematic If you have any questions or require additional information, please contact me at 907-2634321. Sincerely, Keith Herring ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 1A -04A (PTD #200-194) CTD Summary for Sund Summary of Operations: KRU well 1A -04A is equipped with 4-1/2" tubing and 4-1/2" liner. The CTD sidetrack will utilize a single lateral to target the A -sands to the northeast of 1A -04A. The lateral will provide injection support to the recently drilled 1 B-16 CTD laterals. Prior to CTD operations slickline will obtain a SBHP and conduct a dummy whipstock drift. E - line will caliper the wellbore and set a whipstock at 8865' MD to facilitate cutting a window with CTD. CDR3-AC will mill a window in the liner at 8,865' MD and the 1A-04AL1 lateral will be drilled to TD at 13,000' MD, targeting the A -sand to the northeast. It will be completed with 2-3/8" slotted liner from TD up to 8,860' MD with a deployment sleeve. CTD Drill and Complete 1A-04AL1 Lateral: May 2019 Pre -CTD Work RU Slick -line: Obtain SBHP and conduct dummy whipstock drift. RU E -line: Caliper and set whipstock. Prep site for Nabors CDR3-AC. 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. J' 2. 1A-04AL1 Lateral (A4 sand - Northeast) !� a. Mill 2.80" window at 8,865' MD. b. Drill 3" bi-center lateral to TD of 13,000' MD. � ✓J c. Run 2%" slotted liner with deployment sleeve from TD up to 8,860' MD. 3. G\� Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return well to injection. Page 1 of 1 4/5/2019 1A -04A Proposed CTD Schematic 16" 65# H-40 shoe @80'MD 2990' MD MD KOP @ 8865' MD -sand perfs 8848' 8861' MD 8870'- 8916' MD 4-1/2" 12.6# L-80 shoe @ 9160' MD 4-1/2" Camco DS nipple @ 503' MD (3.875" min ID) 4-1/2" 12.6# L-80 NSCT Tubing to surface Baker CMU Sliding Sleeve @ 6237' RKB (shifted closed 12/31/00)(3.675" min ID) Baker S-3 Packer @ 6289' RKB Camco DB landing nipple @ 6305' MD (3.813" min ID) Liner tap Baker ZXP liner top packer @ 6358' MD Baker HMC liner hanger @ 6368' MD Camco DB Nipple @ 8533' MD (3.75" min ID) Camco Seal Nipple @ 8689' MD (3.75" min ID) 1A-04AL1 wp01 TD @ 13,000' MD KUP INJ WELLNAME 1A -04A WELLBORE 1A -04A Alaska. InG.IVER Cono�o�111��IFi$ftomc butes MaxAngie&MD Frew wellW,c APuuLM wNIMres1Y115 11°) MB line UNIT 500292062101 INJ 8.01 ].556.0] TD Fci Blm(DID) 9,161.0 COmmeat H251ppm1 SSSV:NIPPLE Oa1e Mnda4an EnBGale NBGN(tt Lag WO: 12]312000 39.01 Rigg -Odle 81911981 +AOKA.unrm191amuA3a Last Tag VeNwleGem.ue mash AnnoWbn I Depm(IIKe) I End Data I Wel. I Leri MOe By - - ..grr .Ou] CONOOCTOR',. 1KA0 MPPLE: SISI SLIFSACE. 31 ZCGQ2 SLEEK£{:8,$3].3 PACKER: 1...-6,344. NIPPLE;6an] KO THREAD; a TGS SEPLAasr:6.sn.1 WINWWA8995.06,50fi.0 PRO... PGSTST. IPERF', 8,&&08.891.0 Kp80; 8.SNG (PERE 6MOG.9160 IINER: 8318.... Last Tag: RIGS 8,900.0 11162018 1A -04A fer9uaP Last Rev Reason nnnolation Endo We1'.. LULMW By Rev Reason: Tag 1116/2018 1A -04A lerguap Casing Strings Caring Description 00gnl 10(in) Top INKS) SOrrpih DKB1 SN Depth (ND1... W.GrdGrade CONDUCTOR 16 15.06 32.1 800 80.0 65.00 H40 1,... p TIo. WELDED Ceshp Oewtlgkn 00(m1 10 (as Topn1KB) Set Dpth(NKBI Set Depth(iVD)... YMen g... Grade SURFACE 10314 9.95 31.2 2,990.2 2.631.1 45.50 K-55 TapTh. BUTT Caaing Desswimn 0Dpn) Mg.) Tp(NNe) SN OepN MKBI SH Depth jNOI... WGTen P- Grade PRODUCTION POST J 6.28 28.9 6,580.0 4,986.7 26.00 K.55 S? TOPTh-J BTC Cesllq Description OD on) ID en) Top INKBI Set.SIDDIIKel Set Depth pVDl... whien(L. Grater WINDOW 7 6.00 6.494.0 6,506.0 4938.5 2600 K-55 Tap Thread Casing Description GG'., 10(ni rp(NKBI SelDpih (NK81 SN Main (DID) WIILen (1... Got. LINER 412 3.96 6,345.6 9.160.0 6,656.6 12.60 L-80 Top Thlead NSCT Liner Details Na 1na110 Top MKB) ToppVD)NdUd Topinclr) Item Des I Com (in) 6.345.6 4.834.0 48.75 PBR PBR TIEBACK EXT. 6,357.7 4,841. 1 PACKER BAKER ZXP LINER TOP PACKER t3.958 6,367.7 4,848.5 48. HANGER HMC HYDRAULIC LINER HANGER 8532.8 62085 440 NIPPLE CAMCO DB NIPPLE 8.689.0 63202 4477 NIPPLE CAMCO SEAL NIPPLE 3750 Tubing Strings Tubing Description smog ma... 1D(inl rp MKe1 SN cepm m.. setDpth(N01 (....(I. Grade Top Co-fir>n TUBING 4112 396 26.2 6.356.9 4,m i.4 1260 L-80 IST Completion Details Top UDrD) Top Incl Nominal Tp(hKB) (NKBI V) Item Des Com ID (a) 26.2 26.2 0.00 HANGER FMC HANGER 4.062 503.1 503.1 0.00 NIPPLE AMCO DB NIPPLE w13.875'PACKING BORE 3.875 6237.3 4J623 48.21 SLEEVE -C BAKER CMU SLIDING SLEEVE(SHIFTED CLOSED 12,31730) 3.875 6,28.6 4,796.3 48.46 PACKER BAKERS -3 PACKER,]' x 4.5° 3.875 6305.2 4. 7. 48.55 NIPPLE CAMCO OB NIPPLE 3813 -STEM 4, .5 48.75 TEAL BAKER EA -STEM 3.813 6347.1 4,835.0 4876 SEALASSY BAKER 19047 GBH -22 SEAL ASSEMBLY -STABSINTO-LINED 3.958 PBA PACKER Perforations & Slots Tp RS) Btm(NKB) TopfP]ol ( B. jlYDI (M(BI WkMlone DaM1 Dens Den (andslfl I Type Pqm 81848.0 8,861.0 6,433.7 6443.0 A -5, 1A-04 2 Deli 4. IPERF 2T8"SHO DP 60 deg phasring 8,8]0.0 8.916.0 6,449.4 6, 482.2 A- 4, 1AK4 2I2Y1001 4.0 ,PERF 27I8'SHDDP fiO deg p0"a-G Frac Summary Sart DesPeopgMOUlpned BW Proppdo In Formation gat V17209t S'Do SUrl .inTop Oepte (nNS1 Btm DIN.) Ins, to Fluid System"Ckanthdl 1 2102001 8,848.0 8.9160 Vol Sluery (hhD Notes: General & Safety End Dale Mmtalbn 121312000 NOTE: SIDETRACKEDWELL 81292009 NOTE: WAIVERED WELL- PACKER SET TOO HIGH 7l 2010 INCITE : View SchhTdddcwl Alaska SceemahC9.0 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 11,2017 TO: Jim Regg (t`01(l P.I.Supervisor � SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1A-04A FROM: Adam Earl KUPARUK RIV UNIT 1A-04A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv;)› NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-04A API Well Number 50-029-20621-01-00 Inspector Name: Adam Earl Permit Number: 200-194-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708070429 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-04A - Type Inj W-TVD 4798 ' Tubing 440 3300 - 3200- 3160 - PTD 2001940 , Type Test SPT Test psi 3000 - IA 200 440 450 • 450 BBL Pumped: 1.5 - BBL Returned: 1.5 - OA 440 440 • 440 - 440 Interval REQVAR P/F P Notes: MITT against plug at 8,553ft.As per MO 213.011 .i SCANNED SEP 2 5 2017 Tuesday,July 1 I,2017 Page I of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 11,2017 TO: Jim Re P.I.Supervisor e i/ ?(i����7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1A-04A FROM: Adam Earl KUPARUK RIV UNIT 1A-04A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.(2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-04A API Well Number 50-029-20621-01-00 Inspector Name: Adam Earl Permit Number: 200-194-0 Inspection Date: 7/7/2017 - Insp Num: mitAGE170708065950 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA-04A Type Inj ®TVD 4798 - Tubing l 430 750 - 760 760 - PTD 2001940 - Type Test Crest psi 3000 - IA 110 3280 3210 - 3195 - BBL Pumped: 3.5 BBL Returned: 2.1 OA 438 — 450 450 450 - Interval REQVAR P/F P Notes: MIT IA as per AIO 2B4O11 v SCANNED SEP 2 5 2017 • Tuesday,July 11,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 18,2016 TO: Jim Re P.I.Supervisor ee(e( (Z�11 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-04A FROM: Lou Grimaldi KUPARUK RIV UNIT 1A-04A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J 2_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-04A API Well Number 50-029-20621-01-00 Inspector Name: Lou Grimaldi Permit Number: 200-194-0 Inspection Date: 5/12/2016 Insp Num: mitLG160512193628 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' IA-04A [Type Inj N 'TVD 4798 ' Tubing 520 . 880 910 - 920 — PTD 2001940 Type Test!SPT!Test psi 3000 - IA 85 3300 3235 - 3225 Interval REQVAR JP/F P OA ' 377 - 383 - 383 383 - Notes: MIT IA as required by AIO 2B.011.All required paperwork provided prior to test.See prior MITT for casing test. Erk-tt` i.A.r1rLGi' -12_t 9.5133 SCANNED SEP. 2 7 2016 Wednesday,May 18,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 18,2016 TO: Jim Regg (25 Jl P.I.Supervisor 1 r, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-04A FROM: Lou Grimaldi KUPARUK RIV UNIT 1A-04A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1 e-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA-04A API Well Number 50-029-20621-01-00 Inspector Name: Lou Grimaldi Permit Number: 200-194-0 Inspection Date: 5/12/2016 Insp Num: mitLG160512185133 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1A-04A N 4798 75 3310 3210 3190 .H Well} Type Ind TVD Tubing I PTD I 2001940 - Type Test SPT Test psi 3000 - IA 115 140 - 140 - 140 - Interval_—I _ -- --�--_ P 380 • 378 - 377 378 REQVAR P/F OA Notes: MITT as required by AIO 2B.011.All required paperwork provided prior to test.See subsequent MIT IA for casing test. L1 i(coCvz-ti36z56 SCANNED SEP. 2 7 2016 Wednesday,May 18,2016 Page 1 of 1 ZGG1 2_ WELL LOG TRANSMITTAL#902971123 DATA LOGGED 2./4/201G, K BENDER To: Alaska Oil and Gas Conservation Comm. January 15, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 2 0 2U AOGCC RE: Multi Finger Caliper: 1A-04A Run Date: 12/9/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-04A • Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20621-01 Multi Finger Caliper (Field Log) 1 color log 50-029-20621-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari SCANNED $.`` 9 Y; 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 104/2 ,a yrc 1 XHVZE Ima~roject Well History File Cover~l~ge This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. E} Maps: D Grayscale items: [] Other, No/Type D Other items scannable by large scanner E] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~~NINDY Scai~ning Preparation C:~ x 30 = BY: BEVERLY ROBIN VINCENT SHERY~--~NINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER iN SCANNING PREPARATION: YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAN~ERE FOUND: YES .......... NO BY~ BEVERI..Y ROBIN VINCENT SHERYL MARIA(WInDY) DATE:~...~~S/~/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON A~AL PAGE BASIS RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: tst Q u a l ity C h ec ked :;: ~.::~-~,::: 12/10/02Rev3N OTScanned wpd MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE:Friday,June 01,2012 Jim Regg ��f` P.I.Supervisor /C `itl/?/ SUBJECT:Mechanical Integrity Tests L CONOCOPHILLIPS ALASKA INC 1A-04A FROM: Bob Noble KUPARUK RIV UNIT IA-04A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 10--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-04A API Well Number 50-029-20621-01-00 Inspector Name: Bob Noble Permit Number: 200-194-0 Inspection Date: 5/19/2012 Insp Num: mitRCN120522061554 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA-04A - 1Type Inj N-TVD 4798 IA 1 220 3320 - 3240 3230 - I PTD I 2001940 - Type Test SPT Test psi 3000 . OA 540 - 540 540 540 I` Interval REQVAR 1_P/F P - Tubing1 950 _� 1300 1300 1300 - Notes: 1\?IT-IA A:R-5' 2---g.11 SCANNED MAR 1 3 2(114 Friday,June 01,2012 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,June 01,2012 Jim Regg P.I.Supervisor ��i9 6( I 1 z_, SUBJECT:Mechanical Integrity Tests ( � CONOCOPHILLIPS ALASKA INC 1A-04A FROM: Bob Noble KUPARUK RIV UNIT 1A-04A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry „Tie- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-04A API Well Number 50-029-20621-01-00 Inspector Name: Bob Noble Permit Number: 200-194-0 Inspection Date: 5/19/2012 Insp Num: mitRCN120522060828 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-04A ' Type Inj N -TVD 4798 - IA 220 270 - 270 270 - PTD 2001940 Type Test SPT Test psi 3000 . OA 540 - 540 540 540 - Interval REQVAR P/F _L P Tubing, 940 - 3320 3240 3210 Notes: MIT-T z ( SCM4NED MAR 1 3 2014 Friday,June 01,2012 Page 1 of 1 • Nov Conoco Phillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 11. _ off JUL 0 8 20 Commissioner Dan Seamount Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 V ri :;t404." g® "' ci1� S10l1 Anchorage, AK 99501'' "fly Commissioner Dan Seamount: 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 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 on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, f MJ L veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft pal 1A -03 50029206150000 1810880 16" N/A 23" N/A 1.7 6/20/2011 1A-04A 1 50029206210100 2001940 F 18" N/A 23" N/A 2.5 I 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B-03 50029205880000 1810560 _ SF _ N/A 23" N/A _ 5 6/21/2011 1B -04 1 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21/2011 1B-05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6/21/2011 1B-07 50029206160000 1810890 _ 7'2" 1.00 22" 5/9/2011 2.5 6/21/2011 1B-08A 50029206350100 1971120 18'8" N/A 29" N/A 4.5 6/21/2011 1B -09 50029206550000 1811340 SF N/A 23" N/A 5 6/20/2011 1B-10 50029206560000 1811350 SF N/A 23" N/A 6 6/21/2011 1B -12 50029223650000 1930610 _ 13'4" 2.00 24" 5/9/2011 6 6/21/2011 1B-101 50029231730000 2031330 3" N/A 22" N/A 1.7 6/21/2011 1B -102 50029231670000 2031220 11'2" 0.60 36" 5/9/2011 1.7 6/21/2011 1E -05 50029204790000 1800580 19" N/A 19" N/A 1.7 I 6/19/2011 1E-22 50029208840000 1822140 14" 1.75 17" _ 3/21/2011 1.7 6/19/2011 1E-23 50029208580000 1821840 _ 58' 10.75 2'5" 5/23/2011 3.4 6/19/2011 1E-30 50029208140000 1821390 15'5" 1.75 16" 3/21/2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 1841810 14'9" 2.00 35" _ 5/23/2011 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 1951210 7'8" 1.00 12" 5/9/2011 5 6/18/2011 1Y-02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 Page 1 of 3 • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Monday, February 07, 2011 8:47 AM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Cc: Cecchetti, Elmo B; Long, Jill W; Bommarito, Forest; NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 1E-08A Plan Forward (PTD 210 -181) Guy, Thank you for the information. I guess we will pursue an MI service option at the same time as the AA process for the high packer (after the pre production period). The AA would be similar to the 1A -04A (200 -194, AA AIO2B.11) amendment application. Additionally I believe they are planning on running some extra cement bond type logs on 1 E -08A to prove up cement/tubular integrity during the sidetrack/RWO process. Hopefully by that point well have enough integrity data for MI approval, or at least enough information to support an MI trial with before and after RST Togs to confirm in zone injection.... Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz ©alaska.gov] Sent: Friday, February 04, 2011 4:39 PM To: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 1E -08A Plan Forward (PTD 210 -181) MJ, This well for some reason was permitted as a development well... although internally we knew that it was intended for injection service once the CTD sidetracks were drilled. The cementing and completion is less than optimum but we should be able to work out a more strenuous MIT cycle for an Admin Approval . I didn't realize you were also looking to inject MI in this well..... This is the first I have heard about MI. We haven't discussed internally about limiting the well service as of yet. The upcoming well work ( cement squeezing of the liner) doesn't really impact our decision....it is mainly for CTD kickoff and A/C isolation issues as I understand. Regards, Guy Schwartz Senior Petroleum Engineer 4/7/2011 Page 2 of 3 • • AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Friday, February 04, 2011 9:56 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj Subject: FW: 1E -08A Plan Forward (PTD 210 -181) Tom and Guy, As I understand the CoP workover folks have been in contact with the Commission about the 1 E -08A (PTD 210- 181). Please confirm the planned side track completion on 1 E -08A (201 -181) will allow for miscible or gas injection. I have attached a proposed schematic for your review. Please let me know if you have any questions or would like to discuss. This well is next in our well work schedule, therefore a timely response would be appreciated. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 CeII (907) 943 -1687 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, January 26, 2011 8:24 AM To: Cecchetti, Elmo B Cc: Long, Jill W Subject: RE: 1E -08A Plan Forward (PTD 210 -181) Elmo, As we discussed last night... the commission approves the lower packer location and in general the completion plan for the well as you have outlined and shown in the last updated schematic. With the marginal cement coverage above the target injection zone there will be additional UIC monitoring requirements once the CTD sidetracks are drilled and the well is put on injection service. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Cecchetti, Elmo B [mailto: Elmo .B.Cecchetti @conocophillips.com] Sent: Tuesday, January 25, 2011 4:41 PM To: Schwartz, Guy L (DOA) Subject: 1E -08A Plan Forward 4/7/2011 Page 3 of 3 • Mr. Schwartz, Currently Doyon 141 is prepared to set the lower production packer and tubing tail on e -line. The production packer will be placed at 7220' MD (please note change in depth from 7250' MD). The top straddle packer will be placed with a work string above the upper perforations located at 7175' MD. To isolate the A/C sands, ConocoPhillips is proposing the following perforation and squeeze plan off rig: 1) E -line perforate at 7538', 7575', and 7656' MD. 2) CTU cement the perforated interval. 3) CTU clean out liner. Thank you, Elmo 4/7/2011. • MEMORANDUM TO: Jim Regg ~ ~ Z~ ~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, June O1, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 A-04A KUPARUK RIV UNIT 1A-04A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv.~~-- Comm Well Name: KUPARUK RN UNIT 1A-04A Insp Num: mitJCr100523105836 Rel Insp Num: API Well Number: 50-029-20621-01-00 Permit Number: 200-194-0 Inspector Name: John Crisp Inspection Date: 5/22/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min.- 60 Min. Well 1A-04A 2001940- P.T.D'~ Type Inj. ~ peTest N V 47984798 /i IA 140 SPT i 15pp A ~ 320 Test psi 3020 ~ 320 ~ 2940 320 2930 320 _ Interval REQvAR p/F P / Tubing 650 97s lozs lots NOteS: MITIA per AIO 2B.01 ] (revised). 2.4 bbl's pumped for test. No problems witnessed. Tuesday, June O1, 2010 Page 1 of 1 C~ MEMORANDUM TO: Jim Regg P.I. Supervisor ~~ `~ ~~~ ~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, June O1, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 A-04A KUPARUK RIV iJNIT 1A-04A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 1A-04A Insp Num: mitJCr100523105835 Rel Insp Num: API Well Number: 50-029-20621-01-00 Permit Number: 200-194-0 Inspector Name: John Crisp Inspection Date: 5/22/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IA-oaA P.T.D, 2001940 - Type Inj. ! N TypeTest SPT -- - TVD Test psi -- 4798 ~ IA 1500 OA ~ 150 320 160 320 160 320 160 320 Interval REQvAR p/F P Tubing ~ 9so 3ozo .-~ z9zo 2900 Notes: MITT per AIO 2B.011 (revised). 1.2 bbl's pumped for test. No problems witnessed. Tuesday, June 01, 2010 Page 1 of 1 i _ 1A-04A Schlumberger I re,-- -c..-__:.—, ConocoPhillips Alaska. Inc. [ L FINAL A r Kuparuk River Unit E c -. North Slope State: Alaska lir RST Sigma Log with Gradio Post MI Pass J Y N a 0 -July -2009 Q 1019' FSL & 312' FWL Elev.: KB. 95.90 ft aei z G.L. t w ¢ U - D.F. d , U o o ¢°, c 0 Permanent Datum: MSL Elev.: 0.00 ft T T Log Measured From: RKB _ 95.90 ft above Perm. Datum C c Drilling Measured From: RKB L o a , iZi `i 0 E API Serial No. Section Township Range it _ 0 50-029- 20621 -01 5 11N 10E ogging Date 4-Jul-2009 L lun Number ONE depth Driller 8944 ft ;chlum berger Depth 89•5 ft lottom Log Interval 8945 ft ' op Log Interval 6050 ft rasing Fluid Type Injected Water lalinity • )ensity r luid Level BIT /CASING/TUBING STRING lit Size 6.25 in • rom 0 :asing/Tubing Size 4.5 in Veight 12.6 Ibm /ft 'rade L-80 i :rom 0 ft - o 9160 ft Aaximum Recorded Temperatures 125 degF I 1 _ogger On Bottom I Time 4-Jul -2009 I 5:00 1 Jnit Number Location 2196 I Prudhoe Bay lecorded By L. Climer / J. Wible Witnessed By J. Condio REMARKS: RUN NUMBER 1 REMARKS: RUN NUMBER 2 Log correlated to SLB RST Sigma Log with Gradio dated 05- May -2009, Objective: Record RST log post MI to be compared to baseline log ran 05 -May -09 to demonstarate no MI migration out of zone. Results: 1. Recorded 3 passes from 8945-6100' at 60 fpm, 2. Overlayed passes to confirm data quality, 3. Compared Data from RST ran 05- May -2009. 4---- 4. No delta Sigma noted at perfs or above packer. 5. Delta porosity noted at perfs due to lower apparent porosity of gas. 6. No delta porosity noted above packer indicating presence of gas. 7. No evidence found of presence of MI above perfs or packer, RST Zoned parameters: 8945 -6494 ft CSIZ= 4.5 in CWEI =12,6 lb 6494 -6100 ft CSIZ= 7 in CWEI= 38.6 lb SLB Crew: Cunnington, Collins, Drover, Ornquist, NW /AC: 10092053 / Z (16 RUN 1 RUN 2 SERVICE ORDER #: AYKP -00029 SERVICE ORDER #: PROGRAM VERSION: 17C0 -154 PROGRAM VERSION: FLUID LEVEL: FLUID LEVEL: LOGGED INTERVAL START STOP LOGGED INTERVAL START STOP EQUIPMENT DESCRIPTION RUN1 RUN2 SURFACE EQUIPMENT WITM -A PSC_16MHZ DOWNHOLE EQUIPMENT MH-22 49.6 MH -22 LI EQF -43 �r 46,0 EQF -43 it 1 EQF-43 f 42.0 EQF -43 is ii 11 Detail MT 11 TeiStatus PSPT -A/B CTEM _ 36.0 36.0 PSC -A PSTC PSPT-B 3748 CQG FMano GR I . _. 32.3 RTD Thermometer �3 GR CCL Well Temp , 1 29.3 PBMS CQG Nfanom / 28.9 CCL II `r 28.5 onnee DDT(' 07 •.. -- — ■.•.. S111S1111111111111111111111110111,_ 4111i111 _— •ME_— •/l. —' 1I111uu • 1111�� -- �1•I--/1� —c isisoisiiii 6200 IIIIIIIIIIIEI hlihl • --•ice --m—■ •—mme- -I - -! •• -- •_L__. ••----- •-- -- L1111111111= ••—Is:■•I--MIII—E •-- ---II------;a1IIII■■III—• ••—•►71•—r1111=111s •—•■II■--•—•— MIN NMI ra1111■--• IIIIIIIIINIIIIIIMMIll 111111=11116=smr =I --•—•—•--•--M uIuhIIIII1II �lllilll�l,- 6233.0 FT IIIIIIIIIIIIPAlili1 ••—■� 11 Era w._ _ CMU IIi__i_I 11111111M1113111: 1 - IIIIIIIIIii i __ iii miummil•IIIIIMIIIII �---��—II�—E 0—�.�■.�-1.....■I. —s �- --- I •11�—■ ......7...... III •--•-►�•. OMMEl� MUIIM .� ..: , " ',1n rill' iiii #f U —t — •— •It1•�[l•i - l {E : .. . .. it, s : ' d ••. �f:r;, 111 IIIIIIIII INININIIIIMIIIIMIIIIIN MINIM flIMIIIIF II lir •-- •—�r�■t�—■ i 111111111111111111111111111K lid' milli IIIMMIIIM•1111111111111•L�IIIIM/C�" 1111MINIII•INIIIIIN 11111•111111111111 t. INEMI - - - _ -. — •--- 1■1— /11111111 6 284.0 FT �■O :_ __ _� IIIIIII 1 1. 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Mae 111111111 IllIlLIi APENA ar.■■■s, ■■f ■ 111M1111111111 ■ inmut 8848.0 FT MIMI .,.- I L F A -5 � ��� I mo El I 11 0111 111111111E ■.■�.■■■.■. . ■ ■ :.. ■■ 8870.0 FT EN ` 11. 1! _ _ i - I f r ^"' ^�' ' 1 I r o -.••• I RST Sigma (SIGM) . j.. 6100 ''"' tom. s. " ..-- --3.---- - l . C rTk4 1 ! F rP 4 h 1 _ o 2 m , 5C-- P01 CCL —, e ■-____ t ? ' i i ' el 1 _ _I___ MN ' 1 , i {;r { I ,ii II °> °° �s� i,{l{(11 i 1 :`:i1i I!-� . _ ti ll ii _ { � : : =,..i ! I • .i tf . iu :. • � . ,: . .::'ii.:: ' ,. H .. 3b . ! i .4 MI ISM II sii• !iii; : js : !s � ii �fnii iiui r.:rsisssi pris:i:u risusiisuis•.:iaiss. ' " si ° :iiniiasuii»un t ii .....' Pm _ i 6200 ii DE I In . I 1111 1111M111111111111 . NM MAR . WJ. a _ . M1MIIIIIIIIIIIMIIIIIIIIr 6233, FT -own 'ow mo a CMU NM LIN — _ MI 111111111111■111111ML. t._I I d il • I ti NW 1=111111111■111111111K IIIMINIIIIIIMINININIIMIL `w . NM OINIIII■111111M. MR IIMIIMIIIIIIIIIIIMIII .... , MIN IIMMIIIIII■11 —MIIIIIIMIMIIIIIIIP . El ill _ ...i -► -�∎• 0 MII MO r ®t � � , _ , _ 6284 FT •- .1111111111M MI ∎��w PACKER �� - — — _ 111111111E11111 1 _1111111111 0111111111 8700 - so --- _ : Cla . tw mummosolimimimmi 1111M11111111•111111111111 .111=11 _ iiiiriuui i ii1■7i_R _ 111111111 8800 ,. ammowilmonsialiimisi . _ . _ � • . -0- _ r�L 3P. F"j tl TWIN li a 1111'tfil f : 1 .. 4:1= -- • = t n frhAni 4 f •t ...' t orlHt , a . nt 1 tt14:4 mx i • altRnnfatimx ru litnhr M. allEWMEOPIIMEMMINMEMMi t�l # �tfiflu 1EuU51 Irammomt ihzumnimo 111' 11011 4 Irds.„. ZEN 8848.0 FT , ■501 - \i �i A -5 \\iiiLai IMM 4111•111=111111111111111111111 ���� _ i _ � _ . 8870.0 FT _� nil _ 1111111111111111111111111•11•111 A -4 r i •__: (P01CCL) Pe rfo TPHI POST -MI INJECTION (TPHI 02 (V) -1 Zone 0.6 ( - - - -) 0 (POILGR) UeeZe TPHI PRE -MI INJECTION (TPHI 01) d.n ~~~W~~~r~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well , -: 3 ,. 4 } k~~ ..i ~ " ~ tf. S:'~ 6.u L+ 7~ ".. ~ Yii0.Y ,~~ 1..t tv .d ~~. p,: ~t Job # Log Description ~ ~~ 07/1I/09 NO. 5314 Company: Alaska Oil & Gas Cons Comrr~ Attn: Christine IVlahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color Cd ~ • ;,,, }~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. 7hank you. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Field: Kuparuk ~~~ V Well Job # ~~r~~~~~ ~~,I` ~~ '_ Log Description JUN ~ g ZOG9 Kaska ail ~ Cas Cons. Colnmissi~r~ N0. 5284 Anch®ra~~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD 06/17/09 1 B-19 ANHY-00091 PRODUCTION PROFILE L- < 05/27/09 1 1 3K-16 ANHY-00094 GLS ~' 05/29/09 1 1 3G-10 B04C-00058 - INJECTION PROFILE ~ 05/31/09 1 1 1J-160 B2WY-00006 MEMORY INJECTION PROFILE ~ - - 05/31/09 1 1 iJ-164 B2WY-00009 MEMORY INJECTION PROFILE 06/01/09 1 1 iJ-160L2 AXBD-00028 MEMORY INJECTION PROFILE( 06/07/09 1 1 1 A-04A B04C-00040 RST ~ C 05/05/09 1 1 3M-03A AZJZ-00011 CH EDIT SFRT 01/11/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • WELL LC7 TIgANS~TTAL To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 ~,~~y and ~ _ /cj~~ r.~zc a ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~,,. ~ t~ 130 West International Airport Road ! r Suite C Anchorage, AK 99518 Fax: (907) 2458952 1) Injection Profile 2&Mey-09 1A-04A 2) Signed Print Name: 'a_, ail Gas Cons. Ccmmissian chorage PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD $UITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 Fax: (9071245-88952 E-MAIL : pdsanchoraaetrrDmemoryloa.com WEBSRE : www.memorylog corn C:\Docum~ts and Settings\Ownei\Desktop\Transmit_BP.docx 1A-04A (PTD 200-194, AA AIO 26.011) i Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, February 05, 2009 11:17 AM To: 'NSK Well Integrity Proj' Cc: 'NSK Problem Well Supv ;Maunder, Thomas E (DOA) Subject: RE: 1 A-04A (PTD 200-194, AA AIO 26.011) ~~~ ?~15~u~~1 Sorry about the weli name errors -should be KRU 1A-04A not 1A-05A. Page 1 of 2 Also appreciate you looking into the passibility of running some type of gas finder log {run as baseline and after completing an MI cycle) as additional support for whatever decision we make on the Admin Approval. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Thursday, February 05, 2009 10:54 AM To: 'NSK Well Integrity Proj' Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 1A-04A (PTD 200-194, AA AIO 26.011) MJ - as discussed this morning, CPAs is authorized to place this well on MI to obtain a spinner survey (M! injection profile). Please provide the results of the spinner survey when completed and continue to follow the monitoring/reporting requirements of AIO 28.011. 1 do not see a need for the caliper survey at this time. 1 agree that the pressure monitoring data provided by CPAI on monthly basis for KRU 1A-05A indicate no mechanical integrity cancerns. Only apparent reason for admin appraval AIO 28.011 is the packer setting depth {approximately 2500 feet above injection perfs}. A final decision about the Admin AppravaE -modify AA to allow Ml?; cancel AA {recognizing the permit action for KRU 1A-05A as autharizing the alternate packer setting depth)? - Will be made ante We have reviewed the spinner survey data. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Sunday, January 18, 2009 6:18 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1A-04A (PTD 200-194, AA AIO 26.011) Jim, 2/5/2009 1 A-04A (PTD 200-194, AA AIO 26.011) Page 2 of 2 • The ConocoPhillips Reservoir and Development groups in town have requested that I contact the Commission and request a modification of AA AIO 26.011 for well 1A-04A (PTD 200-194) to allow MI gas injection. The well does not have any known integrity issues, however does have an active AA because it does not meet the requirements of 20 AAC 25.314 (b) as the packer is greater than 200' above the perforations. Since the purpose of the requirement is to ensure that the injection string can be monitored throughout its length for possible leakage, ConocoPhillips proposes the following alternative integrity testing for the potential of allowing MI injection. In addition to the 2 Year MITT and MITIA specified in the AA, ConocoPhillips would complete an MI injection profile every two years and an annual tubing caliper survey. Please let me know if the additional testing would demonstrate wellbore integrity and injection zone isolation to a degree that would permit MI gas injection in this well. A 3 month TIO plot and Schematic are attached. Let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «1A-04A Schematic.pdf» «1A-04A TIO.png» 2/5/2009 KRU 1A-04A PTD 200-194 I /18/2009 TIO Pressures T1110 Plot -1 A-04 2000 1500 a 1000 500 0 01-Noy-08 01-Dec-08 Date 01-Jan-09 200 150 a 100 ~ d v 50 0 • .# -- C~nocc~Phill~s Alaska, fnc. KRU 1A-04A 1A-04A API: 500292062101 Well T e: INJ An le TS: 44 de 8534 SSSV Type: NIPPLE Orig 12/31/2000 Angle @ TD: 44 deg @ 9161 ~ COm letion: NIP (503-504, oD:a.SOO) . Annular Fluid: Last W/O: Rev Reason: POST FCO TAG TUBING ~ ~ Reference Lo Ref Lo Date: Last U date: 8/7/2006 (o-szea, ~ Last Ta : 8906 TD: 9161 ftKB oD:a.soo, ID:3 958) Last Ta Date: 8/2/2006 Max Hole An le: 58 de 7556 . Casin Strin -ALL Descri lion Size To Bottom TVD Wt Grade Thread SLEEVE-c CONDUCTOR 16.000 0 80 80 65.00 H-40 (6237-sz3a, OD:5 562) t SURF CASING 10.750 0 2990 2631 45.50 K-55 . PROD CASING 7.000 0 6494 4931 26.00 K-55 TIEBACK LINER 4.500 6288 6345 4834 12.60 L-80 IBT MOD LINER 4.500 6345 9160 6657 12.60 L-80 NSCT SIDETRACK WINDOW 6.250 6494 6506 4939 0.00 Tubin Strin -TUBING ~, Size To Bottom TVD Wt Grade Thread 4.500 0 6288 4796 12.60 L-80 IBT MOD Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8848 - 8861 6434 - 644 3 A-5 13 4 2/2/2001 IPERF 2 7/8" SHD DP 60 deg phasing PKR (sz6s-szso , OD:5.962) ~~, 8870 - 8916 6449 - 6482 A-4 46 4 2/2/2001 IPERF 2 7/8" SHD DP 60 deg hasin Stimulations & Treatments Interval Date T e Comment 8848 - 8916 2/17/2001 High Pressure Break NIP - -- -- Down (6305-6306, oo a soo , ' Other lu. s e ui etc. - JEWELRY : . ) De th TVD T e Descri lion ID 503 503 NIP Camco'DB' Ni le 3.875 6237 4762 SLEEVE-C Baker Model'CMU' Slidin Sleeve shifted c losed 12-31-00 3.875 6289 4797 PKR Baker'S-3' Packer; 7" x 4.5" 3.875 SEAL 6305 4807 NIP Camco'DB' Ni le 3.813 (s3a7-s3aa, ~ 6347 4835 SEAL Baker Seal Assembl '190-47 GBH-22' 4.000 OD:4.750) 6357 4841 PKR Baker ZXP Liner To Packe, wlfieback Ext. 3.930 8533 6209 NIP Camco'DB' Ni le 3.750 9095 6610 SBE Camco Sealbore Ni le 3.750 9158 6655 SHOE Baker Float Shoe 0.000 PKR (6357-635$ ' ~ ' OD:6.013) PROD ~' ' CASING (0-6494, OD:7.000, Wt26.00) I i i I NIP ~ ---- - , (8533-8534, OD:4.500) High .... ... II Pressure Break Down ~... - (8848-8916) !i ~ ' - Perf _ - .. (8848-8861) ~._ ~.. .. I Perf ~{ I (8870-8916) Q- _ LINER ~ - ~'_ ' ~ (6345-9160, ~ - OD:4.500, -- - ~. W 1:12.60) ~ SBE (9095-9096, • STATE OF ALAS ALASKA OIL AND GAS CONSERVATION,C~N~{VI4~~~~$ REPORT OF SUNDRY WELL (tt~~.•~l!!''..((~~gq: TIONS;,,„ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perfo~t~~~f~ ~ ~rHr ~ ~ Other ^ Alter Casing ^ Pull Tubing ^ ~? ~ ' 8 Perforate New Pool ^ ~`~i2~er 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: COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 200-194 / 3. Address: Stratigraphic ^ Service ^~ ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20621-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 26' ~ 1 A-04A ' 8. Property Designation: 10. Field/Pool(s): ADL 25647 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9161' ~ feet true vertical 6659' feet Plugs (measured) Effective Depth measured 9062' feet Junk (measured) true vertical 6587' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 2894' 10-3/4" 2990' 2631' PRODUCTION 6398' 7" 6494' 4931' WINDOW 12' 5-1/2" 6506' 4939' TIEBACK LINER 57' 4-1/2" 6345' 4834' Perforation depth: Measured depth: 8848'-8861', 8870'-8916' true vertical depth: 6434'-6443', 6449'-6482' ..~r:,~~~~+~ r~ ~ ~ - ~ ~~ ~ ~ '~ t~ i.J ~,~ ~, y, ~,~~~ Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6288' MD. Packers & SSSV (type & measured depth) Baker S-3 pkr @ 6289' and Baker ZXP liner top packer @ 6357' Cameo DB nipple @ 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8848' 8916' MD 138 bbls seawater 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 SI Subsequent to operation SI -- 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 NIA if C.O. Exempt: none Contact Guy Schwartz @ 26 958 Printed Name Guy Schwa Title Wells Group Engineer Signature ` Phone: 265-6958 Date ~~~~ -~$ Pre ared b Sha n Allsu -Drake 263-4612 Form 10-404 Revis d 04/2006 ®~ ~ ~ ~ '~+ '~r~,'`~~T~~;J rJ` Submit Original Only `?-` /~ s/~/d8 " DATE " SUMMARY 1A-04A Well Work 7/6/08 ATTEMPT POOR BOY HPBD~MPED TOTAL OF 138 BBLS 45 DEGR, RATE DECREASED TO 0.9 @ 4000 PSI. FREEZE PROTECTED WI 0 BBLS 60/40, TURNED OVER TO DSO. 7/22/08 TAGGED DB NIPPLE @ 8533' RKB. TAGGED BOTTOM @ 8762' RKB, EST. 54' FILL. MEASURED BHP @ 8862' RKB: 4133 PSI. COMPLETE. I • ~ KUP ~t?!'tt,'~CO~~tI~~~~S !~ ~ ~, Well Attributes > ... _ 1 _ ...well, c~ ~ .1 ~ ~. n F~ I CONDUCTOR, eo i ~ sssv so3 ~[ , SURFACE, 2.990 SLEEVE-C, 6,237 PACKER, 8,289 NIPPLE, 6,3118 TIEBACK LINER, 6,346 SEAL, 6,347 PACKER, 8,387 PRODUCTION, 6,494 WINDOW, 8,808 NIPPLE, 8,533 PRODUCTION, B,fi00 ~I it IPERF, i 8,848-8,861 HPBO, 8,848 IPERF, ~ ~- 8,8704f,878 ~ SBE, 9,095 SHOE, 9,158 1 A-04A Wellbure FF4UV:1 500292062101 rlela name !net utua KUPARUK RIVER UNIT ~INJ , Maximum lnchnaoon t-1 Dotal Depth lltNbt 58.04 9,160.0 ~ Comment H2 5 (ppm) Dale iAnnofation ;Entl Date ~--a(ft) iRig Release Date .NIPPLE ... I ~~ Last WO: I 12!31/2000 39.01 I 8/9/1981 Annotation Depth (RKB) End Date Annotatlon -- Entl Date --- ( ~Last Tag: 8,863.0 ( 8/3/2008 Rev Reason: TAG FILL SLM ! 8/7/2008 Casing Strings Set flvpth iT'VD/ 'ra ~ Set Depth ~~.. Casing Description , OD (in) ID lin) Top (RKB) (RKB) (RK B) i (IbzlR) ! Onde Top Thread CONDUCTOR 16 15.062 0.0 80.0 80.0 65.00 H-00 SURFACE 103/4 9.794 0.0 2,990.0! 2,635.1 45.50 K-55 PRODUCTION 7 6.059 0.0 6,494.0' 4,934.9 26.00 K-55 i i WINDOW ~ 6114; 6.250 6,494.0 6,506.0 4,946.5 TIEBACK LINER 1 4 12' 3.958 6,288.0 6,345.0 4,837.6 12.60 L-SO IBT MOD LINER _.. 41/21 3.958 6,345.0! 9,160.0 6,660.7 12.60 L-SO NSCT Tubing Strings . L ,t,11 Tubin Descrl g ptio~ t) Top (RKB) nNE1 SCI CJey1h IT C I D1i; ~L fn HPI T! Ilh 111 Gr Jr Top in,ran TUBING 1 ,.'d18 0.( ... 1 .. I. ~L-~~ CtT `A _1U ~pYher In Hole (Al l Jewelry: Tubing Run & Retrievable, Fis - h, etc.) Top (Rl(B) Des~npti, -.n - cnl ~' rtun Date ID (in) 503.0 SSSV NIPPLE Camco DB' Nipple 12/29/2000 3.875 6,237.0 SLEEVE-C 1 Baker Model'CMU' Sliding Sleeve (shrfted closed 12-31-00) 12129/2000 3.8751 6,289.0 PACKER ' Baker'S-3' Packer; 7" x 4.5" ' ' -- 1 212 9/2 0 00 ~ 3.875..1 6,305.0 NIPPLE Camco DB Nipple - 2/29/2000 !' 3.813! 6,347.0i SEAL Baker Seal ASSembly'190d7 GBH-22' j 122920001 4.000 6,357.OI PACKER Baker ZXP Liner lop Packe, wReback Ext. ~ 12/26(2000. 3.930 8,533.0 NIPPLE Camco'DB' Nipple 12(26(2000 3.750 9,095.0 SBE Camco Sealbore Nipple 12/26/2000 3.750 9,158.0 SHOE Baker Float Shce 12262000 Perforations snot Top (ND) ~ Btm (T1/D) Dens I Top (RKB( Btm (RKB) (RKB) (RKB) Type Zone (shot... Date Comment 8,848.0 8,861.0 6,437.8 6,447.0 IPERF A-5, 1A-04 4.0 2/2/2001 2 7/8" SHD DP 60 deg phasing j 8,870.0 8,916.0 6,453.5 6,485.9 IPERF A-0, 1A-04 4.0 2/22001 2 7/8" SHD OP 60 deg phasing '~ Stimulations & TrBBtrn®Ot8 _. Mm Top Max btm ~~ ~~ 1 (hKB) (RKB) Dale Type Comment TD nA-00. BEM®~N~UM To: Jim Regg ~ v~,~, s (3i~~ J` P.I. Supervisor FROroI: Bob Noble Petroleum Inspector LJI State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 28, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ] A-04A KUPARUK RIV UNIT 1A-04A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~F(~% Comm Well Name: KUPARUK RIV UNIT IA-04A API Well Number: 50-029-2062 1-0 1-00 Inspector Name: Bob Noble Insp Num: mitRCN080523062100 Permit Number: 200-194-0 ~ Inspection Date: 5/22/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. T-- _ _ ------~ -~-- r --- - - -- - -- -- ------7 - Well IA o4A 'TYPe Inj. N '', TVD ~ a797 ~ IA i 100 ~ 160 ~ 160 160 __ _ - -- ---~- --1- - ---- - - -- _.1- - - '- - - P.T. i zoo1940 ;TYPeTest SPT 'l`est pSl ', 2700 ~ DA ~ 320 320 320 320 I Interval _ --- P/F - ~ -- g~_ - _- ____ ____ ';_- ------ _--.. - _- ----- REQVAR P TUbin 1990 2700 / 2680 2680 i Notes: MIT-T ~6t~E~ JUN ~ ~ 20~~ Wednesday, May 28, 2008 Page I of l MEMORAND M • U To: Jim Regg '~ -- P.LSupervisor ~~~~~ ~~~~~ FROM: Bob Noble Petroleum Inspector n ~J State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 28, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC I A-04A KUPARUK RIV UNIT IA-04A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-'~ Comm Well Name: KUPARUK RN UNIT IA-04A API Well Number: s0-029-20621-O1-00 Inspector Name' Bob Noble Insp Num• mitRCN080s23062427 Permit Number: 200-194-0 ~ Inspection Date: 5/22/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. T----- ~ --- ~ - - .. _. _ _ ._~~ __ - Well 1A-04A Type Inj. I N ~TVD a~9~ IA loo zsoo I 2a6o ~ __ ~ 2001940 ISPT X500 P.T. ~ ~TypeTest ,Test psi ~~ - OA 3zo 3so I 3so ~ sso r -_____ ,_ _ --- --- ~ -- -_ __ ~----L- ----- ---- -- -+- --- r-- - _ .. --- - ___ Tubin 1300 Isso I Isso Interval_ REQvAR p/F P g lsso - _. _..- NOteS: MIT-IA ~NEt~ JUN ~ ~ 200 Wednesday, May 28, 2008 Page t of I • • FRAAIJC H. MUR6COWISPCl, GOI/ERMOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 rAX (9071276-7542 ADMINISTRATIVE APPROVAL AIO 2B,011 yIr. Jerry Dethlefs Problem VG'ell Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99~ I0-0360 RE: Kuparuk River Unit 1A-04A (200-194) Request for Administrative Approval Dear Mr. Dethlefs: ~~~~~ ~A~ a ~ 2oos On ~1ay 28, 2006 ConocoPhillips Alaska, Inc ("CPAI") requested an administrative approval under Rule 9 of Area Injection Order ("AIO") 2B to allow continued water injection in Kuparuk River Unit ("KRU") well 1A-04A (PTD 200-194). The Alaska Oil and Gas Conservation Commission ("Commission") GRANTS CPAI's request for WATER ONLY service, as detailed below. 1 A-04A is a redrill of 1 A-04. The new bottom-hole location was accessed by plugging the original well and exiting the production casing at about 6494' measured depth ("md"} and drilling new hole to 9160' md. A 4-1/2" liner was set from total depth to 634' md. The liner was cemented to provide required formation isolation. The well is equipped with a 4-1 /2" tubing string that is stung into the liner top with a packer set at 6288' md. The shallowest perforation is at 8848' md. As constructed, 1A-04A does not meet the requirements of 20 AAC 2.412 (b) for an injection well which is required to be equipped with a packer set not more than 200' measured depth above the top of the perforations. The purpose of this requirement is to ensure that the injection string can be monitored throughout its length for possible leakage. As constructed, over 200' of this w-ellbore cannot be monitored. Where fresh water is not affected, 20 AAC 2~.4~0 gives the Commission authority to approve less stringent well construction and integrity requirements. For wells similarly constructed, the Commission has exercised this discretionary authority and approved injection operations with the fluid limited to water only. CPAI has provided pressure test information using water that demonstrates that the injection string (combination of tubing and liner) and the production casing (the 7" casing above the packer) do have integrity. Accordingly, the Commission believes that the well's condition will not result in an increased risk of movement of fluids outside the injection zone. V • II Administrative Appro a1 A10 2B 0 June 27, 2006 Page 2 of 2 Per Rule 9 of Area Injection Order 2B, the Commission hereby grants CPAI's May 28, ?006 request to continue injection in KRLT 1A-04A on the following conditions: 1. Injection is limited to V4'ATER ONLY; 2. CPAI shall perform a mechanical integrity test of the tubing,-liner string (~`~IIT-T") every 2 years by employing the nipple profile at 8533' and to demonstrate continued integrity of the injection string; 3. CPAI shall perform a mechanical integrity test of the inner annulus ("MIT- IA") every 2 years to demonstrate continued integrity of production casing; 4. CPAI shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and ~. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection; 6. Monthly reporting of daily rate and pressures is not required since this well does have a separate production casing string and does not demonstrate integrity loss. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 Pl~I on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. $~~ ~I~rage, Alaska and dated June 27, 2006. N an Daniel T. 5`~eamount, Jr. Cathy~P. Foerster ~ Commissioner Commissioner \' } ~ 7 } ~ ~~~~ _ "\ __ ~~~ ' > ?` a~ ~~-J . . if 00- -1" q MECHANICAL INTEGRITY REPORT' '- :.~G REL~;~S~ = . OPER & FIELD <-~ L \L. Q '-.) -W""ELL NUKBER \ ~-Ol.\. J\ 5?UD D.:.::::: ~r'i ç.LL DATA rn: C\\5'6 Jill.. (,(o55TVD: ?BTD: '\OC\S"' HD G,<.,\ ò TVD Cë.sir:.g: Shoe: HD TVD i DV: l1D _:...:-:.e::: 4l(;' Shoe: ~ \S~' MD Co~S~ TVI) j :CP:' "S'-\ÇHD . _JD:!.:;g: ,-\\/;)' Packe=-<Od'&~ till ~)~\ TVD¡ See ê.C :-:ale Size <;s-2, 1'-\ ana '~( II~ ; Perfs . . 'Iv!) L\ <6SS" :~7D c,)~~ ~Co\ Co r ~'.\Q :-::EC7"þ~,rIC;.L INTEGRITY - PART /l Annulus Press Test: ~p 15 unn 30 min Cowments: r- :-ŒCH?_1I1ICAL INTEGRITY - PART /2 ," %--:> b":>\> Cement Volumes:' þ...mt:. Liner Lt)C)s'¡(.; Csg ; DV Ci:üC ~J"ol to coveZ" pe=-=s \1;-b\>\.... ~~,ó.~\ ~LC~~~ ~~""SCÚ( c: ,,0 ¿c 'i <s rb.eoreeical TOC ~ 30(0 '{.. ~ <:...~~Y\.:\-~().:)\d~'-.){ ~,,-~~ckJ ~ò.tcat~\~ \0 ~<J \roC' '0~'~{ c.\'<.!'J..x· ~ e'\oao ' J ~ ~ J...,f; \ I~-(J \ Cement Bond Log (Yes or No) '(è<? : In AOGCC File 'C(£~ . \.AjL\\ ~~,\,,\e~\> CBL ~valuation, zone above perfs oS~)O~(¿ ~<t,\4 Proàuction Log: Type Evaluati.on CONC;LUSIONS: ? ar C : 1 : ? ar:: : Z : • RECEIVED • JlJN ConocoPhillips Alaska Alaska Oil &Gas 0 Cons . 2006 Commission P.O. BOX 100360 Anchorage ANCHORAGE, ALASKA 99510 -0360 11W1.'� APP et 8 2011 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Kuparuk Well 1A -04A (PTD 200 -194) Request for Administrative Relief Dear Mr. Maunder: ConocoPhillips Alaska, Inc., requests approval to continue operations into Kuparuk well 1A -04A (PTD 200 -194). This request is pursuant to Area Injection Order No. 2A, Rule 9 Administrative Relief. Kuparuk well was completed with a packer that does not meet construction requirements in 20 AAC 25.412 (b). Pressure testing of tubing and casing strings indicates the well has competent mechanical integrity and can be safely operated. Three barriers have been defined that will prevent an inadvertent release and confine fluids to the approved zones. The attached Technical Justification includes a proposed operating and monitoring plan. Daily monitoring of the wellhead and casing mechanical integrity tests are proposed to verify the well continues to be safe to operate. Should observations or tests indicate a compromise of well integrity the well will be shut -in and the AGOCC will be notified. There is no source of underground drinking water in this area and so is not endangered by this proposal. If you need additional information, please contact me or Jerry Dethlefs at 659 -7043, or Marie McConnell / Perry Klein at 659 -7224. Sincerely, MJ oveland Well Integrity Project Supervisor Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 1A -04A (PTD 200 -194) Technical Justification for Administrative Relief Request Proposal ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request for an exception of 20 AAC 25.412 (b) well construction standards for Kuparuk injection well 1A-04A. Well History and Status Kuparuk River Unit well 1A-04 (PTD 181 -096) was originally completed in August 1981 as a producing well. In December 2000 the well was sidetracked to a new bottom -hole location and re -named 1A -04A. The well was converted from a producing (development) well to a water injector (service well) during the permitting process for the sidetrack and subsequently converted to a MI injection well shortly afterwards. The completion subsequent to the sidetrack in 2000 includes a packer that was set at 6357' MD (4841' TVD) and a packer that was set at 6237' MD (4797'). The top of the perforated zone in ' the completion configuration well is 8848' MD (6434' TVD). As per 20 AAC 25.412 (b), uration t p g does not meet the 200' maximum distance from the packer to the approved injection zone. The distance between the packer and perforations is 2559' MD (1593' TVD) from the bottom packer and 2611' MD (1637' TVD) from the top packer. The completion includes a nipple profile in the liner section at 8533' MD (6209' TVD), but it is also not quite within the depth requirement of 20 AAC 25.412 (b). This profile was used to test the production casing between the packer and perforated interval via setting a plug and performing an MIT. The distance between the profile and perforations is 315' MD (225' TVD). A State witnessed MITIA and MITT (with TTP set at 8533' RKB) passed on 05/30/06 and a MITOA passed on 04/08/06 showing that the well currently has three barriers from the surface to the reservoir. Barrier and Hazard Evaluation Tubing: The 4.5 ", 12.6# L -80 tubing passed an MITT to 8533' RKB on 5/30/06 to 3000 psi. Production casing: The 7" 26# K -55 production casing has integrity to the top packer @ 6289' MD based on the passing MITIA test on 05/30/06 described above. Surface casing: The well is completed with 10.75" 45.5# K -55 surface casing with an internal yield pressure rating of 3580 psi and passed a MITOA to 1800 psi. The surface casing is set at 2990' MD (2631' TVD). Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Third barrier: The surface casing and cement shoe will act as a third barrier should the first two barriers have failures. NSK Problem Well Supervisor 6/4/2006 • • Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. Proposed Operating and Monitoring Plan 1. Approve service for water only injection; 2. Perform MIT -IA at 2 -year frequency to verify tubing and production casing have not developed communication problems; 3. Perform MIT - Tubing at 2 -year frequency by setting a plug in the nipple @ 8533' MD (6209' TVD) to verify integrity of the production casing from the packer to the approved zone within the depth criteria required in 20 AAC 25.412 (b); 4. Notify the AOGCC should MIT test results, injection rates or wellhead pressures indicate annular communication problems have developed. Placing the well on the Monthly Failed MIT Report to the AOGCC is not proposed at this time. The well currently has three tested barriers and additional reporting is not warranted. NSK Problem Well Supervisor 6/4/2006 2 s6 PHILLIPS Alas, Anc. • KRU 1A -O4A A Subsidiary of PHILLIPS PETROLEUM COMPANY 1A -04A API: 500292062101 Well Type: INJ Angle A TS: 44 deg as 8534 NIP (503504, SSSV Type: NIPPLE Orig 12/31/2000 Angle @ TD: 44 deg @ 9161 OD:4.500) Completion: Annular Fluid: Last W /O: Rev Reason: FCO tag fill, Sleeve update by ImO Reference Log: Ref Log Date: Last Update: 7/7/2002 Last Tag: 9066 CTM TD: 9161 ftKB SLEEVE -C Last Tag Date: 7/29/2001 Max Hole Angle: 58 deg as 7556 (6237 Casing String - ALL OD:5.562) Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H -40 I SURF CASING PROD CASING 10.750 0 2990 2631 45.50 K -55 TUBING 7.000 0 6494 4931 26.00 K -55 (06288 TIEBACK LINER 4.500 6288 6345 4834 12.60 L -80 IBT MOD LINER 4.500 6345 9160 6657 12.60 L -80 NSCT OD:4.500, CSG WINDOW 6.250 6494 6506 4939 0.00 ID:3.958) Tubing String - TUBING Size Top Bottom TVD Wt Grade Thread 4.500 0 6288 4796 12.60 L - 80 IBT MOD Perforations Summary PKR Interval TVD Zone Status Ft SPF Date Type Comment (6289-6290 I 8848 - 8861 6434 - 6443 A -5 13 4 2/2/2001 IPERF 2 7/8" SHD DP 60 deg 00:5.962) 1 phasing 8870 - 8916 6449 - 6482 A-4 46 4 2/2/2001 IPERF 2 7/8" SHD DP 60 deg phasing Stimulations & Treatments NIP Interval Date Type Comment (6305 -6306, 0 - 0 2/17/2001 High Pressure 00:4.500) Break Down Other ( lugs, equip., etc. - JEWELRY Depth TVD Type Description ID 503 503 NIP Camco 'DB' Nipple 3.875 SEAL 6237 4762 SLEEVE -C Baker Model 'CMU' Sliding Sleeve ( shifted closed 12- 31 -00) 3.875 6289 4797 PKR Baker 'S -3' Packer; 7" x 4.5" 3.875 (7 04:4.750) 6305 4807 NIP Camco'DB' Nipple 3.813 6347 4835 SEAL Baker Seal Assembly '190-47 GBH -22' 4.000 6357 4841 PKR Baker ZXP Liner Top Packe, w /Tieback Ext. 3.930 8533 6209 NIP Camco 'DB' Nipple 3.750 9095 6610 SBE Camco Sealbore Nipple 3.750 PKR 9158 6655 SHOE Baker Float Shoe 0.000 (6357358 General Notes 00:6.013) Date Note 2/2/2001 Drifted tubing to 9067' WLM w/23' x 2.565" dummy gun PROD --/ CASING (0 -6494, 00:7.000, W1:26.00) NIP (8533-8534, 00:4.500) Perf — (8848 -8861) -- Pert — (8870-8916) -- - SBE - (, 00:4.500) Page 1 of • • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Monday, July 06, 2009 3:16 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 1A -04A (PTD 200 -194, AA AIO 2B.011) AA XXL request Guy, We only have an electronic copy of the PDS memory Spinner. The SWS RST is in paper form. Our preference would be to cancel the current AA and return the well to normal status versus amending the current AA. However, since both options arrive at the same results it really doesn't matter. Thanks! MJ Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 CeII (907) 943 -1687 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, July 06, 2009 2:52 PM To: NSK Well Integrity Proj; Regg, James B (DOA) Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 1A -04A (PTD 200 -194, AA AIO 2B.011) AA XXL request MJ, Data shown looks good. Do you have the PDS version of RST overlays to email to us ?? !would like to see the lower part of the perforations ... the RST overlay log stops about where the perfs were actually taking the MI gas according to the PDS IPROF log. (Won't change the fact that above the perforated intervals there is no gas migrating out of zone so mission accomplished on that part!) I will confer with J Regg when he gets back on Wednesday this week. I believe we will modify or amend current AA AIO 2B.011 to reflect the change in injection status instead of cancelling it. Have a great day... we are looking for shade in Anchorage! Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Sunday, July 05, 2009 9:08 AM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) 10/26/2009 Page 2 of e • Subject: 1A -04A (PTD 200 -194, AA AIO 26.011) AA XXL request Jim, The MI gas injection cycle and diagnostic logs have been completed for 1A -04A (PTD 200 -194). Please find the attached electronic copy of the AA cancellation request that you will be receiving in the mail. Let me know if you have any questions about the well or the request. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, February 09, 2009 3:08 PM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: FW: 1A -04A (PTD 200 -194, AA AIO 2B.011) Tom - .d I agree with the approach. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite , I Anchorage, AK 99501 907- 793 -1236 From: NSK Well Integrity Proj [mai , :N1878 @con• ophillips.com] Sent: Saturday, February 07, 2009 1:' ' PM To: Regg, James B (DOA); Maunder, Tho • s . (DOA) Cc: NSK Well Integrity Proj; NSK Problem Supv Subject: FW: FW: 1A -04A (PTD 200 -194 2B.011) Jim, Our data gathering plan is as fo .ws: 1. Run base line RST whit- well is on water injection 2. Run memory injectio .rofile while on MI injection 3. Repeat RST log a r MI cycle (back on water) and overlay results w q first log to look for residual gas. Let me know if y% have any questions MJ Lovela Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 10/26/2009 • • Page 1 of 5 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 3:10 PM To: Regg, James B (DOA) Subject: RE: FW: 1A-04A (PTD 200 -194, AA AIO 2B.011) Jim, There are a number of other wells monobores and monodiameters) out there with long single pipe sections. I ( ) g g pp think this diagnostic approach is what we have advocated for some time but there was push back. I guess they really want to get MI into this well. Tom From: Regg, James B (DOA) Sent: Monday, February 09, 2009 3:08 PM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: FW: 1A -04A (PTD 200 -194, AA AIO 2B.011) Tom and I agree with the approach. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Saturday, February 07, 2009 1:47 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: FW: FW: 1A -04A (PTD 200 -194, AA AIO 2B.011) Jim, Our data gathering plan is as follows: 1. Run base line RST while well is on water injection 2. Run memory injection profile while on MI injection 3. Repeat RST log after MI cycle (back on water) and overlay results with first log to look for residual gas. Let me know if you have any questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 10/26/2009 • • Page 2 of 5 From: Hazen, Mike C Sent: Friday, February 06, 2009 7:37 AM To: NSK Well Integrity Proj Subject: FW: FW: 1A -04A (PTD 200 -194, AA AIO 2B.011) MJ, We talked about an operational plan and this is what we'd propose in order to identify near well bore gas. Mike From: Jason Wible [mailto:jwible @prudhoe- bay.oilfield.slb.com] Sent: Friday, February 06, 2009 6:49 AM To: Hazen, Mike C Subject: Re: FW: 1A -04A (PTD 200 -194, AA AIO 2B.011) Mike, Good approach would be 1. Run baseline RST Sigma after a long period of water injection and prior to putting well on MI. 2. Put well on MI for extended period. No eline logging during this time. Slickline could do a memory IPROF. 3. Put well back of water for a short period of time 1 -2 days and repeat a RST Sigma log. Overlay logs 1 and 3 to identify nearwellbore gas. Regards, Jason At 01:53 PM 2/5/2009, you wrote: Jason /Stephen, MJ is trying to formulate a plan whereby we could establish a baseline MI injection log to determine gas injection zones and then after some pre - determined period of subsequent water injection, another log which would help show whether said MI is staying in zone or migrating to other zones (packer to perforations in particular). Could we run a subsequent log which could show, behind pipe, near wellbore gas characteristics. This could be after some sort of SL deployed memory MI profile, or even after an e -line IPROF, if we ever determined that that is something we would want to do. Any ideas? Mike From: NSK Well Integrity Proj Sent: Thursday, February 05, 2009 11:30 AM To: Versteeg, Joseph R; Kovar, Mark; CPF1 Prod Engr; CPF1 DS Lead Techs Cc: Fitzpatrick, Charles J (Fairweather); Kennedy, Chris; NSK Problem Well Supv; Hazen, Mike C; NSK Well Integrity Proj Subject: FW: 1A -04A (PTD 200 -194, AA AIO 2B.011) 10/26/2009 Page 3 of 5 All, We got approval from the State for an MI trial in 1A -04A. Before we can commence MI injection we need some sort of a baseline log -Mike Hazen is tracking down some details for this. During the MI cycle we need an MI injection spinner. Then after the cycle we will follow up with another log (PNL ? ? ?) to see if the baseline has changed. If all looks good the state will modify or cancel the AA to allow MI with out restrictions. Let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 From: Regg, James B (DOA) [ mailtojim.re•g(aalaska.gov] Sent: Thursday, February 05, 2009 11:17 AM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 1A -04A (PTD 200 -194, AA AIO 2B.011) Also appreciate you looking into the possibility of running some type of gas finder log (run as baseline and after completing an MI cycle) as additional support for whatever decision we make on the Admin Approval. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 om: Regg, James B (DOA) Sen . • sday, February 05, 2009 10:54 AM To: 'NSK We - • rity Proj' Cc: NSK Problem Wel . = • Maunder, Thomas E (DOA) Subject: RE: 1A -04A (PTD 201- • , AA AIO 2B.011) MJ - as discussed this morning, CPAI is authorized to • : - this well on MI to obtain a spinner survey (MI injection profile). Please provide the results of the spinner survey when c eted and continue to follow the monitoring /reporting requirements of AIO 2B.011. I do not see a need for the caliper survey a time. 1 agree that the pressure monitoring data provided by CPAI on monthly basis for KRU 1A-11' , dicate no mechanical integrity concerns. Only apparent reason for admin approval AIO 2B.011 is the packer setting dept i oximately 2500 feet above injection perfs). A final decision about the Admin Approval - modify AA to allow MI ?; cancel A • nizing the permit action for KRU 1 A -05A as authorizing the alternate packer setting depth)? - will be made once we have revi- - • the spinner survey data. 10/26/2009 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .-' 1-- ;: /" , '"'. -11r ' . . ! ~I ,,-'I "",t-.:..' DATE: Wednesday, May 31,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC lA-04A KUPARUK R]V UNIT lA-04A /\C\Ù{ ~~\7 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: ~ P.I. Suprv.JÞt::- Comm NON-CONFIDENTIAL Well Name: KUPARUKRIVUNIT IA-04A Insp Num: mitTJ060530155954 Rei Insp Num API Well Number 50-029-20621-01-00 Permit Number: 200-194-0 Inspector Name: Jeff Jones Inspection Date: 5/30/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: lA-04A ¡Type Ioj. IN! TVD .~ 4797 j IA : 800 1 900 i 900, i 900: , P.T. I 200]940 iTypeTest I SPT ! Test psi ]500 i OA I 420 ! 420 I 420 I 420 I 1 " , ~ubiog i,' 2200 ! 3000 -+---;oõ~ - 3000 --I ------¡-~- Interval OTHER P/F p. ! I i , Notes This well does not meet the AOGCC requirements for packer placement in an injection well. A tubing tail plug is set at 8533' to facilitate the MITT. 1 well house inspected; no exceptions noted. ! - \....-.. -., ,/ /? " ¡(:?1'íJ..;;Gb~s '!'''-'f '. v (.(; r..("-¡''''Cc'.' P~"'ì"\J :-<W J:.",..:.-...... ~ '"" ,'" '- ~ -, qppr¿)...J>:·c? I~')'·~j. Z..(.~L' - l c¿ 4 '\¡'<£11 .. ~.. 11'11'''' 1'\ ?nn5 ~Ç(í\NNti: ,j~~¡~ ~ ¡y....' Wednesday, May 31,2006 Page I of I MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor í7 ¡J,-i- I'V?1t¡ -"'1::> ILl DATE: Wednesday, May 31,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC IA-04A KUPARUK RIV UNIT IA-04A ;}.,bQ ~ \ q If FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~L Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-04A API Well Number 50-029-20621-01-00 Inspector Name: Jeff Jones Insp Num: miOJ060530161727 Permit Number: 200-194-0 Inspection Date: 5/30/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I IA-04A !Type Inj. I N ! TVD 4797 I IA I 820 1660 I 1610 1600 I I I I i I i I I I I I , I i P.T. I 2001940 ¡TypeTest i SPT ¡ Test psi 1500 OA I 420 I 420 i 420 420 ¡ ! I i I ¡ -- Interval OTHER PIF P Tubing: 2400 2400 i 2400 2400 I i I Notes MITIA: this well does not meet the AOGCC requirements for packer placement in an injection well. 0.4 bbls diesel pumped. ~-- :'---V {2,. ¡}; I Dr-, 1,0 .r>- ,1,;:,;c,?r,-,l" '~< fJ,;"VI'\P, ',,-J i . TV(.L~: ~;_!\.~./~..' ;; p~C:~\~'e-J f<-':;~G'f ZeL,- 11.14 '-J ;( 4fc¡' £/s;!C(, . I SÇ!tNNED ,JUN : B 2005 Wednesday, May 31,2006 Page 1 of I ~ .~",.~, " . MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2001940 MD 9161. TVD DATA SUBMITTAL COMPLIANCE REPORT 4/112003 Well Name/No. KUPARUK RIV UNIT 1A-04A Operator CONOCOPHILLIPS ALASKA INC 6659 ~ Completion Dat 2/2/2001 ' Completion Statu 1WINJ Current Status WAGIN APl No. 50-029-20621-01-00 UIC Y REQUIRED INFORMATION Mud Log N._~o Sample N._go Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Interval Log Log Run Name Scale Media No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments ED D ~ LIS Verification ED C C-.Vel~LIS Verification k J P~ SP/SCMT ~ ~) J~'~l 5 FINAL ;C~L/PSP2..%'J#,,~ t 5 FINAL Directional Survey FINAL Directional Survey FINAL Directional Survey FINAL Directional Survey FINAL 6465 9117 Open 6464 9069 Open 7995 9058 ch 6160 9058 CH 11/29/2001 ~4~0461 4/26/2002 =,,1'0~91 ~ v'o~;~ 2/12/2001 7995-9058 Color Print 2114/2001 6160-9058 Color Print 2123/2001 Dir Survey Digital Data 2/23/2001 Dir Survey Paper Copy 3/18/2001 Directional Survey Digital Data 3/18/2001 Directional Survey Paper Copy Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~'-~/"N----- Analysis R e.~.~.iv~.d ? Daily History Received? Formation Tops Comments: Permit to Drill 2001940 DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. KUPARUK RIV UNIT 1A-04A Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-20621-01-00 MD 9161 TVD Compliance Reviewed By: 6659 Completion Dat 2/2/2001 Completion Statu 1WINJ Current Status WAGIN UIC Y Date: STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS · :.: 1."OP6mtions performed: ' ' 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service_X · '. Operationshu~0WnL..i ...... :i ...=-stimulateL~. 'i . ;'.. ' .... '::" P!ugging.~'.:.... i ".Perforate- ":'. '. : -' '. -'. . ...' .... P~II tubing"~ '.:. :.!'.:'?i':.'-.;'.?...:.:..'.-'.-iit,~:casing... '~'-:.:. ': '.' ."::'." :;."" .'.R~ii:Well'-:': '.....'..i0~.1]'~:~x WIN~Jto~.;' .~ :..."..' . .. 6. Datum elevation (DF or KB feet) RKB g6 feet 7. Unit or Property name (asp's 540179, 5971107) 4. Location of well at surface 4260' FNL, 4966' FEL, Sec. 5, T11N, R10E, UM At top of productive interval 387' FSL, 502' FEL, Sec. 5, T11N, R10E, UM At effective depth (asp's 544733, 5970688) At total depth 4702' FNL, 415' FEL, Sec. 5, T11N, R10E, UM 9161 feet Plugs (measured) 6657 feet 12. Present well condition summary Total depth: measured true vertical Kuparuk Unit 8. Well number 1A-04A 9. Permit number / approval number 200-194 / 10. APl number 50-029-20621-01 11. Field / Pool Kuparuk Oil Pool Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 200 sx Permafrost 80' 80' SURF CASING 2894' 10-3/4" 120o sx Fondu & 250 sx ASII 2990' 2631'. PROD CASING 6398' 7" 1039 sx Class G & 42 bbls ASII 6494' 4931' CSG WINDOW 12' 5-1/2" '6506' 4939' CSG WINDOW 57' 4-1/2" 400 sx C~ass G '6345' 4834' Perforation depth: measured ~~!i!~!~![ i ii ii i' . R ! i i! .... I/ N 0 ; 003 ......................................................................................... ~as~u. a Gas Cons, C0mmisslo[, :,~,:~,~:::~::::,:::.:,,,,,.:,.:=:.~,,.:::::::,: ,~ :::::::::::::::::::::::::::::::::::::::::: .,,.:.,~ ,::: :~ .:~, ::~ ::::,::: ,:,::,.,,,~: ~::, .:: . : ,:. :,,, :: .:. :: . :,:::::,:, :,: ,:., ::,: :::, ,,,:~,: ::,:, ::::,:: :::, ::::::::::::::::::::::::::::::::::::::::::::::: ,:,.:.,,:..::::::,:! ::::::::::::::::::::::::::::::::::::::::::::::::::::: :,:m,::: ! !i~'~"i'~i?i~"~%"~'""~'ii"'"~{~"~',,'"=~?'~':'ii~{{iii'~!;;[[i~ "!'i'i= '~ii" '"T Y'"" i? i~i1~[~i~i~;i[~i[[~i~i~;~.~.~i~i~.i~.s.~;~j~.~[~[~iii~:~.[~ '~i~J~ ~i~,'",:'i~ i~ .......................................................................................................................................................... 13. Stimulation or cement squeeze summa~ 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Representative Daily Averaqe Production or Injection Data .... (~!.l-.B..bl . . Gas-Mcf Water-Bbl Casing P.r..e....s....s....u. re T..u....b..i.n.....q......P. ressure 17. I hereby certify that the fo~~ rue ~nd correct to the best of my knowledge. Signed ~ Title Production Engineedng Technician Robert O. Cfir~tensen Form 10-404 Rev 06/15/88 · . q hMS B F L JA[q S 2003 Questions? Call Jeff Spencer 659-7226 Prepared b~/ Robert Chdstensen 659-7535 SUBMIT IN DUPLICATE 1A-04A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary .11i11/20021C0mmenced WAG EOR..Injection '.. ', '1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 21, 2002 RE: MWD Formation Evaluation Logs 1A-04A, AK-MM-00317 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1A-04A: Digital Log Images 1 CD Rom RECEIVED ,~.~' ,2002 L--t..,: 2 6 ~askaOil &Gas Cons. Commissio~ ~chomge To whom it may concern, The originally sent digital data, 3-1/2" floppy with .pdf and .ptt files, for well lA-04 was exported using Grid North instead of True North. This caused the Inc's and Az's to be incorrect in the final digital data. The original hard copies sent to you were printed out correctly however, but replacements have also been included with this digital data. Please d~estroy th__.e original digital data and use the digital data included in this envelope. '----'-' /'~ ~ ~ /~ Victor Eppler Sperry Sun IIFR (907) 273-3564 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 March 12, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1A-04A (200-194) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 1A-04A. If you have any questions regarding this matter, please contact me at 265-6434 or Steve McKeever at 265-6826. Sincerely, J. Trantham Drilling Engineering Supervisor PAI Drilling JT/skad RECEIVED Mtll~ 1,.t~ 2001 Alaska 0il & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1~ Status of well Classification of Service Well O" D Gas D Suspended D Abandoned D Service r~ ~.-----,,.,.--.-~.. ~ i.c.c,,A T! _c~l. ~ water Injector 2. Name of Operator VL~-,j~D 7. Permit Number Phillips Alaska, Inc. ~,,~ ~ 200-194 3. Address .~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 - 50-029-20621-01 4. Location of well at surface ..--..;~ ............... ~. 9. Unit or Lease Name 1019' FSL, 312' FWL, Sec. 5, T11N, R10E, UM (ASP: 540183, 5971107) :~.;',i?_' [ Kuparuk River Unit At Top Producing Interval :' __..~-._..__.Z.__'_~2./_ i 10. Well Number 387' FSL, 502' FEL, Sec. 5, T11N, R10E, UM (ASP: 544647, 5970503) ; ,,' 'i':'i--:Fr'; ~ 1A-04A ~ - ... , ,~ At Total Depth ~'~ 11. Field and Pool :: 572' FSL, 417' FEL, Sec. 5, T11 N, R10E, UM (ASP: 544730, 5970689) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 26' feetI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date~ ..C"°niP" Susp.. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 22, 2000 December 26, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9161' MD / 6659' TVD 9062' MD / 6587' TVD YES r~ No [~]I N/A feet MD 1650' (approx) 22. Type Eiectrlc or Other Logs Run GR/Res/Neu Dens, USIT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 65.5# H-40 Surface 80' 24" 2oo sx Permafrost 10.75" 45.5# K-55 Surface 2990' 13.75" 12oo sx Fondu & 250 sx ASII 7" 26# K-55 Surface 6494' 8.75" lO39 sx Class G & 42 bbls ASll 4.5" 12.6# L-80 6345' 9158' 6" 4OO sx Class G 4.5" tie-back 12.6# L-80 6288' 6345' Baker bridge plug set at 6525' WLM 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD Interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 6345' 6288' 8848'-8861' MD 6434'-6443' TVD 4 spf 8870'-8916' MD 6449'-6482' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, pst 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A MAR ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit In duplicate 29. I ',~ 3,0. ~. -. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8534' 6211' Base Kuparuk C 8648' 6292' Top Kuparuk A 8837' 6427' Base Kuparuk A 8991' 6537' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS . Summary of Daily Operations, Directional Survey 32. I hereby cerlify that the following Is true and correct to the best of my knowledge. Questions? Steve McKeever 265-6826 James Trantham Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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. RECEIVIED Item 28: If no cores taken, indicate 'none". Form 10-407 ORIGINAL MAR 2001 Alaska Oil & Gas Cons. Commission Anchorage 1A-04A Operations Summary Rpt No 12/19/00 1 2/19/00 1 2/19/00 1 2/19/00 12/19/00 12/19/00 1 2/19/00 12/20/00 12/20/00 12/20/00 12/20/00 12/20/00 12/20/00 12/20/00 Comments Move rig from 1A-24 to 1A-04A=Accept rig @ 04:00 hrs. 12/19/2000. Pull BPV & VRP-Rig up to kill well. (500# on tbg.) PJSM on well kill=Test lines & manifold to 110# w/air. On load tbg. protectors & control line spool-lower tarps-test cellar alarm-on load 100 degree seawater-install plyboard for safety around cellar. Open well-start seawater down tbg. (tbg. 480-csg.40) pump @ 3 bpm-returns to flow tank. Pump 285 bbls.-Shut down-0 pressure on tbg. & csg. Set BPV-N/D tree-bleed control line-remove tree from cellar. Install blank plug in tbg. hanger-n/u adapter spool-n/u bope-test all bope (witness test waived by aogcc Chuck Cheave). Pull hanger-break circ. & attempt to pull loose from chemical cut while circ. @ 9.3 bpm & working tbg. Working tbg.-attempt to pull same while pumping 9.3 bpm @ 3150#. Monitor well while wait on SWS. PJSM=Cut & slip drlg. line-check crown-o-matic. Pull to 80k-set slips-rig up sws-PJSM-make up pump in sub & packoff-run in hole with string shot-tie in-fire string shot from 7666 to 7654 to loosen corrosion from tbg.-poh w/string shot to sssv-pump down tbg. to get string shot thru sssv-poh & rig down Drain stack-land hanger-push down on tbg. to get Ids in-lay down landing jt. -set bpv. N/D bop-pick up stack-string 35~ of control line thru bop & connect to hanger port-n/u bope-pull bpv. Pull 80k on tbg. & set slips-r/u sws-PJSM-m/u pump in sub & packoff-rih w/chemical cutter-tie in & cut pipe @ 7663-poh & rig down sws. Pull hanger to floor. (Total 24 hrs. problem time) 12/21/00 R/U to pull tbg.-lay down hanger-cbu. 12/21/00 POH laying down 2 7/8" tbg. & jewelry-off load same. 12/21/00 Rig up & shell test Ipr-stack-choke & kill lines. 12/21/00 Rig up for dp-make up bit-scraper-pick up 9 sdc,s-bha & 75 jts. 3.5" dp & rih to 6790. 12/21/00 Circ. bottoms up x 2 @ 9 bpm. 12/21/00 POH for running wire line set bridge plug. 12/21/00 Rig up sws & run gauge ring junk basket to 6800'. 12/22/00 PJSM-Run Baker bridge plug on wireline-log in & set @ 6525 WLM-poh & rig down sws. 12/22/00 Test csg. 3000# for 30 rains. 12/22/00/'Make up milling assembly & whipstock-rih I stand dp-check mwd. 12/22/00 Run in hole slow with whipstock. 12/22/00 Make up top drive-cycle pumps for mwd-orient 41 deg. left-tag bridge plug @ 6513 dpm-set whipstock. 12/22/00 Pump spacer pill-displace seawater w/9.6# Isnd mud. 12/22/00 ' Mill window from 6494' to 6506'-Drill new hole from 6506' to 6524'. 12/22/00 Ream window-circ, sweep. 12/22/00 Formation integrity test-12.2#. 12/22/00 Pump pill-poh-lay down bha. 12/23/00 Lay down milling assembly. 12/23/00 Clean bop stack-lay down washing tool. 12/23/00 Change out saver sub on top drive. 12/23/00 Make up mwd drlg. assembly-upload same & rih. 12/23/00 Make up top drive-break circ.-cycle pumps for mwd-orient. 12/23/00 Slide thru window-ream from 6510 to 6524'. 12/23/00 Drlg. & surveys from 6524' to 6959'. 12/24/00 Drlg. & surveys from 6959' to 7901'. 12/25/00 Drlg. & surveys from 7901' to 8190'. (TVD 5961') Alaska 0il ~ Cas Cons.' Anchorage C°rnmism.on 1A-04A Operations Summary ("' 12/25/00 1 2/25/00 1 2/25/00 1 2/25/00 12/25/00 12/25/00 1 2/25/00 12/26/00 12/26/00 1 2/26/00 12/26/00 12/27/00 12/27/00 12/27/00 12/27/00 12/27/00 12/27/00 12/27/00 12/27/00 12/27/00 1 2/27/00 1 2/27/00 12/27/00 12/28/00 12/28/00 1 2/28/00 1 2/28/00 12/28/00 12/28/00 12/28/00 12/28/00 12/28/00 12/28/00 12/29/00 12/29/00 12/29/00 12/29/00 12/29/00 12/29/00 Pump sweeps-Circ, hole clean for wiper trip to shoe & FIT. w/10.5# mud. Wiper trip to shoe @ 6506'. (hole in good condition) Circ.-while changing air tube in drlg. nipple. Perform-F.I.T.=12.2# ok. Service top drive-crown-& crown-o-matic. RIH & break circ. slowly-keep ecd,s down. Drlg. & surveys from 8190' to 8493'. Continue directional drill 6 1/8" hole f/8493' to 9160' MD TD 6656' TVD. Add Drill & side to control torque. Circulate and condition hole. Pump sweeps rotate & reciprocate. Make short trip with 11 stands f/9160' up to 8000'. RIH hole in good condition. Circulate & condition hole f/4 1/2" Csg. Drop DP drift & POOH f/9160' to 6300' Monitor well @ 7" csg shoe. Pump dry job. Continue to POOH Service rig. Safety meeting slips trips & falls. Continue POOH L/D HWDP Down Icad MWD L/D Same. Flush and Lay down Motor. R/U to run 4 1/2" csg. PJSM Flear floor. P/U and run 90 jts of 4 1/2" 12.6# L-80 NSCT csg. As per/program. M/U Baker liner hanger and running tool. up wt 50k down wt 35k Circurate pipe volume 3 bpm @ 400 psi. RIH on 3 1/2" DP 90 sec per stand to 6411' Circulate Hole volume @ 7" Shoe. M/U cement head on a 3 1/2" joint DP L/D. Run liner in open hole F/6494' to 9130' M/U cement head circulate last single down tag bottom 9160' @ 1.5 bpm 900 psi. Condition mud and hole for cementing. Increasing rate till @ 3 bpm 1200 psi. With 4 1/2" casing on bottom @ 9160' circulate Reciprocate & condition mud for cementing. PJSM with Dowell and rig crew. Batch mix MudPUSH & Flush. Pump 5 bbls of Preflush Test lines to 5000 psi Followed by 15 bbl's @ 8.4 ppg Followed by 20 bbl's MudPUSH @ 13.0 ppg Followed by 400 sks class 'G' neat cement @ 15.8 ppg (83 bbl's) Followed by 2 bbl's water Drop dart switch to rig pumps. Kick out dart w Release f/liner hanger. Pressure up to 1000 psi pull out when pressure droped pumped 5 bbl's down DP push cement up away from PBR. Switch lines and reverse out cement @ 2 bpm cement to surface w/1100 strokes (DP volume +5 bbl's) continue to 1400 stks w/ Talk over options. Leak down hole. Pump long way to clear well bore of mud contaminated cement. Treat mud while circulating dump 100 bbl's contaminated mud to cutting tank. Monitor well O.K. Slack off on DP putting Baker seals back in seal bore. Test down tbg to 1000 psi. O.K. Test annulus leaking 700 psi injection shut down pumps holding 480 psi after 10 min. Break down cement head and lay down. POOH standing back DP. Lay down liner setting tool. Wash out BOPE. Slip and cut drilling line M/U Baker 7" test packer w/4.72" seal assy below. RIH on 3.5" DP to 3200' set packer. Test annulus to 1000 psi O.K. Continue RIH to 6324' Set packer test annulus to 1000 psi O.K. Sting into PBR @ 6345' test casing to 1000 psi O.K. Test annulus leaking off POOH L/D 79 jts Stand back L/D test packer. Weekly BOP test. RIH w/3.5" DP to 6297' Service rig Circulate & warm up hole. POOH L/D 3.5" DP. Drain stack Pull wear ring. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 1A-04A Operations Summary 12/29/00 Change out lifting and turning equipment. PJSM 12/29/00 P/U & run 4 1/2" 12.6# L-80 IBT completion Assy 1 2/30/O0 Continue running 4 1/2" 12.6# L-80 IBT tubing total of 202 joints W/Seal Stem & 7" X 4 1/2" S- 3 Straddle packer. RHC plug set 'DB' Nipple below packer. Run slowly using tubing plug. 12/30/00 Drop ball rod. Space out and land on FMC tubing hanger. RILDS 12/30/00 Set Packer w/3000 psi f/10 min O.K. 12/30/00 R/U Halliburton wireline unit RIH w/Sliding sleeve shifting tool. Work on opening sleeve POOH R/D. 12/30/00 R/U circulating lines to displace mud w/sea water. Unable to circulate down annulus or tubing, R/D lines. 12/30/00 R/U Halliburton wireline unit RIH W/sliding sleeve shifting tool. Open Baker 'CMU' @ 6237' POOH R/D 12/30/00 R/U Reverse circulaate and displace 10.5 ppg mud W/Seawater 350 bbl's. 12/30/00 Set Two way check. N/D BOPE. 12/31/00 Continue to N/D BOP's 12/31/00 N/U 4 1/16" 5M Tree. Test 300-5000 psi. Pull test plug. 12/31/00 Pump 80 bbl's diesel down annulus. Put tubing and annulus in communication & let diesel 'U' tube to balance. 12/31/00 R/U Halliburton wireline unit. RIH w/sliding sleeve shifting tool & close sliding sleeve @ 6237' POOH RIH w/fishing tool to recover ball rod POOH RIH w/RHC plug pulling tool. POOH R/D Wireline unit. 12/31/00 R/U lines Test tubing & liner to 3000 psi for 30 min O.K. Test 7" X 4 1/2" annulus to 3000 psi for 30 min O.K. 12/31/00 R/D circulating lines. Set BPV. Sercure well and cellar. 12/31/00 R/D move rig off well. Clean up around cellar and location. 12/31/00 Release rig @ 1900 hrs 12/31/00 RECEIVED Alaska Oil & Gas Cons. Cornrnissio~ Anchorage ( Page 1 or' ~- Well Service Report Iw,,n II Job S,:op,, , II Job Number I1A-04A 11DRILLING SUPPORT-CAPITAL 'Il°:z°'i°~ ~859'~ Io,,t,, Ilo~lyWork Ilu~i~ ~-mb,,r I 02/02/2001 DRILLING SUPPORT-CAPITAL: PERF 8848-8861 AND 2145 8870-8916 FT MD - 2.88" HSD @ 4 SPF Ilgey Per~on IIsuper,~isor II SWS-SPENCER II ODELL IlX~nal Inner Ann IlInit Outer Ann l[ 600 II ~oo Ilnn~ Outer Daily PERF 8848-8861 AND 8870-8916 FT MD - 2.88" HSD @ 4 SPF - 34J UJ Sununary iCHARGES, 60 DEG PHASING. [Perf] ~me IlL°g ~:utry I 07:00 IILEFT KCC FOR KIC I 07:30 IILE~ fac FOR ~A P~-C~L~D DSO FOR ACCESS I 07:4~ so s~PPOgT ~Q~n,M~Sr O~ ~OC~r~OS- C~~D c~msr- s~r~ ~ET~G - BEG~ RU 08:45 I[ST~D~G BY FOR SUPPORT EQU~ME~ ~V~I [ ~:30 ]]SUPPORT EQUIP~NT A~IVED ] 09:45 IIP~-A~ S~TY MEETING- A~'GUN ~1 'l 10:~ I1~ L~ TO 3~ PSI [ x0:~o II~ LU~ TO 3~ PSI I 10:20~ G~ ~1 - = ~~/AH-38/S~VE~GGT-C~EX JO~/S~ ~AD - ~sic~ o~orroM sos~ = 2~.7 ~ x 2.ss" 11,:~o IILoo A Tm ~ PASS ~OM 89~0 ~ I 11:15 LOG ~O POSITION - CCL DE~H = 8898.7 11.3 ~ ~TERV~ = 8910-8916 ~ MD. GOOD ~ICATION AT SU~ACE OF DETONATION. , 11:20 SHOT O~ ~1 W~H 2750 PSI APPROX OF STATIC P~SSU~ ~D 350 PSI OF ~LL~~ P~SSU~ = 31~ PSI AT PE~S. PROG~ STA~D ~SERVOIR P~SSU~ WAS 34~ PSI, BUT WHP DROPPED TO 2~ PSI SHORTLY ~R H~G 11:25 II~s~D EGGNOG, POO~ 12:10 IIAw SU~ACE-CON~~D ~L SaOTS ~D .... II ............. ' RECEIVED MAR 1 3 ~001, Alaska Oil & Gas Cons. Commission Anchorage Page 2 ct' 2 ( 12:30 IIA~ G~ ~2 12:45 ~H G~ ~ - S~ AS G~ gl EXCE~ LONGER G~. TOT~ TOOL = 35.7 ~ET X 2.88' M~ OD 13:30 IILO~ A Tm ~ PASS ROM 8950 ~ 13:35 LOG ~O POS~ION TO SHOOT GUN g2 - CCL DE~H AT 8882 ~ MD - CCL TO TOP SHOT = 7.4 ~ - ~RV~ = 8890-8910 ~ ~. GOOD ~DICATION AT SU~ACE OF DETONATION. - LOG O~ ~D POOH. 14:45 IIm~ OU~ ~3-EXAC~Y T~ S~ AS G~ 15:30 iLOG ~TO POSITION - CCL.DE~H 8862.6 ~ MD - CCL TO TOP SHOT = 7.4 ~ - ~ERVAL = 8870~8~0 ~. G~OD ~DICAT1ON OF DETONATION AT 'SU~ACE.- LOG O~ ~D POOH. 16:25I1~ su~c~-com~~D ~tm SHOTS ~D. I 16:40 ~H G~ ~ - S~ SIZ~ AS. ~ ~D ~3, BUT ONLY LO~R 13 ~,:2o I1~o~ ~ mm ~ ~ss ~om 89so ~ 17:30 LOG I~O POSITION TO SHOOT GUN ~ - CCL DE~H ~ 8833.6 ~ MD - CCL TO TOP SHOT = 14.4 ~ - ~TERV~: 8848-8861 ~ MD. GOOD ~DICATION OF DETONATION. LOG O~ - POOH. 20:00 CALLED DSO - LE~ PAD AND ~FO~ED HIM THAT THE OA H~ DROPPED FROM 5~ TO 0 PSI. Alaska Oil & Gas Cons. Commission Anchorage (' ( Page 1 of 2 Well Service Report Wen IlJob Scope IIJob Number 1A-04A IIDRILLING SUPPORT-CAPITAL '11o2o7o~859.~ Date Ilx~ny Work Ill.it Number 02/17/2001 IIDmLL~G SUPPORT-CAPITAL: HPBD I o I[ II II DS-GALLEGOS II GOB R II Init Tbg Press [Inm Tbg P~e~ Ilx~t Inner Ann II~n~ Inner Ann Ilz~t Outer Ann II II II soo II 575 II 575 ' Daily PUMP HIGH PRESSURE BREAKDOWN - PERFS BROKE DOWN AT 5950 PSI Sunnnary - SAW GOOD DIVERSION (UP TO 2500 PSI) wrrH ROCK SALT - PLACED 13594 LBS 16/20 CARBOLITE BEHIND PIPE - MAX RATE 40 BPM AND MAX PRESSURE 7200 PSI - PUMPING 40 BPM AND 6200 PSI AT END OF JOB - DSO OPENED WELL UP TO INJECTION AFTER RIG DOWN - INITIAL RATE 3900 BPD AT 2580 PSI [HPBD] ITame IILog Egtry I 06:00 IIMIRU SCHLUMBERGER PUMPING EQUIPMENT 09:00 TGSM - MUSTER AREA BY END DUMP - DO NOT GET IN HURRY - LOOK OUT FOR EACH OTHER - DISCUSS RESPONSIBILITIF~S AND JOB PLAN 09:30 PRESSURE UP INJECTION LINE UPSTREAM OF WING VALVE TO 3550 PSI - PRESSURE UP ANNULUS TO 2050 PSI - PRIME UP PUMPS - PERFORM LOW PRESSURE PT TO 350 PSI - ALL OK - OPEN MASTER VALVE - SET TREESAVER - WARM UP PUMPS ,AND' LINES,- PT TO 8500 PSI - SMALL LEAK ON GREASE FITTING ON DOWELL MASTER VALVE - REPAIR FITTING - PT TO 8500 PSI - ALL OK 11:00 START PUMPING STAGE 1 - 200 BBL SLICK SEAWATER AT 40 BPM AND. 4120 PSI (PERFS BROKE DOWN AT 5950 PSI) - 50 BBLS SLICK SEAWATER WITH 1 PPA 16/20 CARBOLITE (2861 LBS) AT 25 BPM AND 3360 PSI - 225 BBLS SLICK SEAWATER - PUMPING 40 BPM AT 4025 PSI BEFORE SAND HIT PERFS - PUMPING 32 BPM AT 6500 PSI WITH LAST OF SAND ON PERFS - 40 BPM AT 5000 PSI WITH 25.BBLS LEFT IN FLUSH - 40 BPM AT 4850 PSI AT END OF FLUSH ' 11:15 SHUT DOWN PUMPS - ISIP=2265 - FG=0.79 - DECIDE TO DECREASE ROCK SALT ON NEXT STAGE TO 600 LBS AND 300 LBS (DESIGN WAS 1158 LBS AND 772 LBS) 11:30 START PUMPING STAGE 2 - 18 BBLS GEL DIESEL WITH 600 LBS ROCK SALT AT 8 BPM AND 2825 PSI - 10 BBLS GEL DIESEL SPACER AT 8 BPM RECEIVED Alaska Oil & Gas Cons. Commission Anchorage , Page 2 of 2 AND 3260 PSI- 12 BBLS GEL DIESEL WITH 300 LBS ROCK SALT AT 8 BPM AND 3100 PSI- 5 BBL GEL DIESEL SPACER- PUMP 150 BBLS SLICK SEAWATER AT 25 BPM AND 4020 PSI- PRESSURE BROKE BACK TO 3700 PSI - PUMP 50 BBL 1PPA 16/20 CARBOLITE SCOUR (2934 LBS) - FLUSH ~WITH 300 BBLS SLICK SEAWATER AT 40 BPM AND 4.100 PSI - PRESSURE WENT UPTO 5125 PSI WITH SAND ON PERFS BROKE BACKTO 4800 PSI- SAW 1500 PSI AND 800 PSI DIVERSION WITH ROCK SALT 11:50 SHUT DOWN PUMPS - 2670 PSI ISIP - FG=0.86 - DECIDE'TO DECREASE ROCK SALT ON NEXT STAGE TO 900 LBS AND 500 LBS - DESIGN WAS 1158 LBS AND 1158 LBS 12:05 START PUMPING 3RD STAGE - 20 BBLS GEL DIESEL AT 8 BPM AND 3000 PSI WITH 900 LBS ROCK SALT - 10 BBLS GEL DIESEL SPACER AT 8 BPM . , AND 3300 PSI - 13 BBLS GEL DIESEL WITH 500 LBS ROCK SALT AT 8 BPM AND 3140 PSI- 5 BBL GEL DIESEL SPACER- PUMP 150 BBLS SLICK SEAWATER AT 25 BPM AND 4100 PSI - SAW 900 PSI AND 2500 PSI ,. DIVERSION WITH ROCK SALT- PUMP 200 BBL 1PPA 16/20 CARBOLITE SCOUR (7799 LBS) AT 40 BPM - 6800 PSI HIGHEST PRESSURE - BROKE BACK TO 6200 PSI - FLUSH WITH 296 BBLS SLICK SEAWATER AT 40 BPM AND 6270 PSI 12:40 ]lsHtrr DOWN PUMPS- ISIP=3240 PSI- FG=0.95 - BLEED OFF IA TO 500 PSI I 2:5o RD 14:00 DSO ON SITE - SIWHP= 850 PSI - OPEN WELL UP TO INJECTION - INITIAL RATE 3900 BPD AT 2580 PSI · I 5:oo II mo SCmJm G MAR 1 3 200t Alaska oil & Gas Cons. Commission Anchorage 16-Mar-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 1A-04A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,395.90' MD 6,493.00' MD 9,161.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEFINITIVE Job No. AKMMO0317, Kuparuk River Unit Phillips Alaska Kuparuk fA, Slot 1A-04 1A-O4A Surveyed: 26 December, 2000 $ UR VEY REPORT 16 March, 2001 Your Ref: API500292062101 Surface Coordinates: 5971106.83 N, 540178.52 E (70° 19' 55.0788" N, 149° 40' 26.7587" W) Kelly Bushing: 95.90fl above Mean Sea Level QFII'LLING SERVICES; Survey Ref: svy9349 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 1A.O4A Your Ref: API500292062101 Job No. AKMMOO3fT, Surveyed: 26 December, 2000 DEFINITIVF Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6395.90 49.000 117.600 4771.17 4867.07 6493.00 49.971 116.134 4834.25 4930.15 6504.00 49.868 115.209 4841.33 4937.23 6683.49 48.190 100,110 4959.40 5055.30 6780.15 46.940 92,120 5024.68 5120.58 6876.45 48.000 82.600 5089.86 5185.76 6973.19 47.930 76,210 5154.67 5250.57 7070.20 47.550 68.690 5219.96 5315.86 7168.45 47.520 60.440 5286.35 5382.25 7264.88 49.930 51,270 5350.04 5445.94 7362.27 53.400 45,890 5410.46 5506.36 7457.77 56.860 38,980 5465.10 5561.00 7556.06 58.040 39.340 5517.98 5613.88 7653.18 57.330 38.490 5569.90 5665.80 7748.22 56.910 37.540 5621.50 5717.40 7845.46 56.600 35,090 5674.81 5770.71 7940.53 56.270 34,290 5727.37 5823.27 8037.30 53.530 30,030 5783.03 5878.93 8131.41 51.180 30,260 5840.50 5936.40 8230.50 50.390 29,620 5903.15 5999.05 8326.11 47.130 29,430 5966.17 6062.07 8424.01 44.310 27,900 6034.52 6130.42 8521.16 43.960 24.650 6104.25 6200.15 8618.47 44.480 25,390 6173.99 6269.89 8716.04 44.590 24,560 6243.54 6339.44 8812.91 44.320 24,710 6312.69 6408.59 8910.22 44.520 25,490 6382.19 6478.09 9007.39 44.250 23.650 6451.63 6547.53 9104.34 44.470 24.250 6520.95 6616.85 9161.00 44.470 24,250 6561.38 6657.28 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1686.62 S 3184.97 E 5969437.29 N 543372.48 E 1719.97 S 3250.82 E 5969404.29 N 543438.50 E 1723.62 S 3258.40 E 5969400.69 N 543446.11E 1764.72S 3386.77 E 5969360.27 N 543574.69 E 1772.36 S 3457.59 E 5969353.01N 543645.55 E 1769.05 S 3528.32 E 5969356.70 N 543716.26 E 1755.85 S 3598.88 E 5969370.28 N 543786.75 E 1734.25 S 3667.24 E -5969392.25 N 543855.00 E 1703.17 S 3732.59 E 5969423.68 N 543920.18 E 1662.49S 3792.38 E 5969464.68 N 543979.75 E 1611.93 S 3849.56 E 5969515.55 N 544036.66 E 1554.10 S 3902.30 E 5969573,66 N 544089.09 E 1489.86 S 3954.62 E 5969638.17 N 544141.06 E 1426.00 S 4006.18 E 5969702.31N 544192.28 E 1363.12 S 4055.33 E 5969765.45 N 544241.10 E 1297.60 S 4103.49 E 5969831.23 N 544288.90 E 1232.46S 4148.58 E 5969896.61N 544333.64 E 1165.50 S 4190.74 E 5969963.80 N 544375.45 E 1101.06S 4228.16 E 5970028.43 N 544412.52 E 1034.54S 4266.48 E 5970095.16 N 544450.48 E 971.99 S 4301.91 E 5970157.90 N 544485.57 E 910.51S 4335.54 E 5970219.56 N 544518.88 E 849.87 S 4365.49 E 5970280.36 N 544548.50 E 788.37 S 4394.19 E 5970342.01N 544576.87 E 726.34 S 4423.08 E 5970404.19 N 544605.43 E 664.67 S 4451.36 E 5970466.01N 544633.38 E 603.00 S 4480.25 E 5970527.84 N 544661.94 E 541.19 S 4508.51E 5970589.80 N 544689.87 E 479.24 S 4536.03 E 5970651.89 N 544717.05 E 443.05 S 4552.33 E 5970688.17 N 544733.16 E Dogleg Vertical Rate Section (°/'lOOff) 448.97 1.52 459.49 6.50 460.87 6.41 500.96 6.23 535.39 7.36 578.73 4.91 630.06 5.75 687.02 6.19 749.99 7.57 817.64 5.61 891.88 6.95 969.50 1.24 1052.14 1.04 1134.03 0.95 1213.74 2.13 1295.04 0.78 1374.25 4.58 1453.29 2.50 1527.52 0.94 1603.99 3.41 1675.54 3.09 1745.18 2.36 1812.02 0.75 1878.85 0.61 1946.22 0.30 2012.94 0.60 2080.03 1.35 2146.85 0.49 2213.37 0.00 2252.35 Phillips Alaska Kuparuk lA Comment Tie-on Survey Top of Whipstock (window point) Bottom of Whipstock PROJECTED SURVEY f6 March, 200f - 4:25 Page 2 of 4 DrillQuest 2.00.06 Sperry-Sun Drilling .Services Survey Report for 1A-O4A Your Ref: API500292062101 Job No. AKMMO0317, Surveyed: 26 December, 2000 Kuparuk River Unit Phillips Alaska Kuparuk I'A All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 35.060° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9161.00ft., The Bottom Hole Displacement is 4573.84ft., in the Direction of 95.559° (True). ' Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 6395.90 4867.07 1686.62 S 3184.97 E 6493.00 4930.15 1719.97 S 3250.82 E 6504.00 4937.23 1723.62 S 3258.40 E 9161.00 6657.28 443.05 S 4552.33 E Comment Tie-on Survey Top of Whipstock (window point) Bottom of Whipstock PROJECTED SURVEY Survey tool program for f A-O4A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 9161.00 6657.28 Survey Tool Description MWD Magnetic (1A-04A) '/6 March, 2001 - 4:25 Page 3 of 4 DrillQuest 2.00.06 Sperry-Sun Drilling Services North Reference Sheet for fA-04 Kuparuk River Unit Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot Grid Coordinates of Well: 5971106.83 N, 540178.52 E Geographical Coordinates of Well: 70° 19' 55.0788" N, 149° 40' 26.7587" W Grid Convergence at Surface is 0.307°. Magnetic Declination at Surface is 26.270° (19 December, 2000) Phillips Alaska Kuparuk lA Grid -North True North Magnetic North 25.9.63°1 Magnetic Model: IGBGCF00 Date:. 19-Dec-00 Declination: 26.270 Inclination/Dip: 80~684 HorizontalComponent:. 929'6 nT Northerly Component! 8336' nT · Easterly Component: 4115 nT Vertical Component: 56667 nT Total- Field Str.ength: 5.7425 nT ~,~.. Hole Direction Grid North is 0.307° East of True. North . (Grid - Convergence) Magnetic North is 26.270~' East of True NOrth (Magnetic..Declination) Magnetic North-is 25.963° East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Subtract 0.307 degrees To convert a Magnetic Direction to a True-Direction, Add 26.270 degr..e, es To convert a Magnetic DireCtion to-a Grid Direction, Add 25~963 degrees 16 March, 2001.4:25 Page 4 of 4 DrillQuest 2.00.06 Scklumlierger NO. 948 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print ' 1A~24 SBHP-PRESSURE STOPS 010126 1 2Z-29 LEAK DETECTION LOG 010129 1 3K-07 INJECTION PROFILE 010130 1 1A-04A 21048 SCMT 010123 I .~' 2/6/01 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Schlumberger NO.960 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1F-20 PRODUCTION PROFILE 010201 I v 1A-04A 21061 SCMT 010128 I 2/8/01 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 29-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1A-04A Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,395.90' MD 6,493.00' MD 9,161.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ALASIIA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Tranthan Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kupamk River'l A-04A Phillips Alaska, Inc. Permit No: 200-194 Sur. Loc. 1019'FSL, 312'FWL, See. 05, TI IN, R10E, UM 'Btmhole Loc. 369'FSL, 426'FEL, Sec. 05, T1 IN, R10E, UM Dear Mr. Tranthan: Enclosed is the approved application for permit to redrill 'the above referenced well. ., 'The permit to redrill does not exemPt.you from obtaining additional permits required by law frOm other governmental agencies, and does not aUthorize conducting drilling operations until 'all Other required permitting, determinations are made. The blowoUt'prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; · and the mechanical integritY (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20/LAC 25.030(g).(3). Sufficient notice (approximately 24 hours) of the MI test 'before operation, and of the BOPE test prior to drilling new hole must be given so that a.' representative of the Commission may witness the tests..Notice maybe given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, J. 'M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this ~ day of November,,2000 dlf/Enclosures cc' Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. " STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL la. Type of woflc Drill r~l Redrill O I lb. Type of well. Exploratory O StratigraphicTestO Development Oil l--I Re-ent~j O Deepen OI Service ~] Development Gas r-~ single zone [~ Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 100 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25647 ALK 465 Kuparuk River Pool 4. Location of well at surface '~' ~ ~./ 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1019' FSL, 312' FWL, Sec. 5, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive Interval 8. Well number Number 187' FSL, 554' FEL, Sec. 5, T11N, R10E, UM 1A-04A #U-630610 At total depth 9. Approximate spud date Amount 369' FSL, 426' FEL, Sec. 5, T11N, R10E, UM December 1, 2000 $200,000 12. Distance to nearest property line ~ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) 426' @ TD feetI None feet 2560 9020' MD / 6651 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) iKickoff depth: 6504 MD Maximum hole angle 47.7° Maximum surface 2607 psig At total depth (TVD) 3300 psig 18. Casing program Setting Depth size Spoclflcatlons Top Bottom Quantity of Cement Hole Casin~l Wei~lht Grade coupIin~l Length MD TVD MD TVD Iinclude sta~le data) 6.125' 4.5" 12.6~ 'L-80 NSCT 2670' 6350' 4838' 9020' 6651' 79 bbls Class G ,.-..., '-- ~-~.-. i V !:::: I./ 19. To be completed for Redrill, Re-ent~J, and Deepen Operations. Present wall condition summaxy NO Total Depth: measured 8844' feet V~ Plugs (measured) true vertical 6299' feet ~ Oil & Gas Cons. Commissior Effective Depth: measured 8733' feet Junk (measured) Vann Gun @ 8473' true vertical 6379' feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 200 sx Permafrost 80' 80' Surface 2990' 10.75" 1200 sx Fondu & 250 sx AS II 2990' 2632' Production 8824' 7" 1039 sx Class G & 42 bbls ASII 8824' 6789' Liner ~" ""~ ::"'i, ' ~ .... ~ ' ' Perforation depth: measured Current Perforations to be Abandoned.~!'-,.,Jr 'i', '"~'~ ~.ii~ "'~'"'"" "'~ )~'"'~, i":' '"" true vertical 20. Attachments Filing fee r~ Property Plat D BOP Sketch D Dive,er Sketch r~ Drilling program r~ Drag,aid program [] nme vs depth plot DRefractlon analysis r'~ Seabed report D 20 AAC 25.050 requirements D 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Ques#ons? Call Brian Noel265-697,. Signed ~~.-~1~''~~~-~-~=~-- Titie:D#/lin~lEngin,#ngSupen4,or Date ~' James Trantham { ' Prel3ared hv Shemn AIlsut)-Drelf,: ~,, Commission Use Onl} Perm, Number I APlnumber I .'koproval date Ieee cover letter ~ - f:l 5/' 50- c3.~'*/- 2.Z:)~7--/" ,:3 / Ifor other requirements Cond,~onsofopproval Sempies required I--I Yes E] .o .ud~o~required O Yes El .o Hydrogen sumde measures ~ Yes C] .o Di~onal s~rveyrequ~red [21 Yes I--I .o Requlred working pressure for BOPE O2M; O 3M; D 5M; D lOM;O ~, .~)(~, by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12/1/85 ° Submit in triplicate REDRILL PLAN SUMMARY Well 1A-04 A Type of well (producer/injector): Surface Location: Target: Top A4 TD: MD: 9020' TVD: 6651' Rig: Estimated Start Date: Operation Days to Complete: Injector 1019' FSL, 312' FWL, Sec 5, T11N, R10E, UM 187' FSL, 554' FEL, Sec 5, T11 N, R10E, UM 369' FSL, 426' FEL, Sec 5, T11 N, R10E, UM Nordic Rig 3 12/5/00 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate % Solids Milling Initial Drilling Final Drilling 9.6-10 8-15 25-30 50-65 5-10 8-13 <12 8.5-9.0 6-11 9.6-10 8-15 16-24 45-55 3-8 7-12 <12 8.5-9.0 6-11 10.5 10-17 18-28 45-60 3-8 7-12 <10 8.5-9.0 8-12 Drillin_= Fluid System: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: RECEIVED NOV Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Casin.q/Tubin_~ Pro;ram: Hole size Cs_c~l'b; Len;th Too (MD/TVD) Btm (MD/TVD) 6-1/8" 2820' 6350'/4838' 9020'/6651' Liner 4-1/2", 12.6#, L-80, NSCT Tubing 4-1/2", 12.6#, L-80, BTC ABMod 6350' 30'/30' 6350'/4838' Cement Calculations: Casing to be cemented: 4-1/2" in 6-1/8" open hole Volume = 79 bbls, Class G Cement Based on: Open hole volume + 60%, 150' liner lap, and 150' of cement above liner top. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated~/surface pressure (MASP) while drilling the sidetrack is calculated using a reservoir pressure of 330(73:)'STat a target mid-point of 6300' TVD. Gas gradient is anticipated to be 0.11 psi/ft. Using this data, the MASP is calculated to be: MASP=((3300/6300)-0.11 )*6300 MASP=2607 psi Therefore PAl will test the BOP equipment to 3500 psi. Drilling Hazards: Lost Circulation: The suspect lost circulation zones throughout the Kuparuk field are the K-10 and K-5 intervals. The sidetrack 1A-04A, will exit the 7" casing between the K-10 and K-5 intervals. The cement bond Icg run August 1981 shows 50% bond at the planned window depth. It is believed the above intervals will handle the expected maximum mud weight of 10.5 ppg to be used for this sidetrack. The original well was drilled with mud weight ranging from 9.7-10.6 ppg. Solids control and dilution will be used to maintain mud weight and lost circulation material will be onsite. Overpressured Intervals: Other Hazards: The kick-off point in 1A-04A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 6504' MD / 4937' TVD 51 ° (in sidetrack portion) No Hazards 52° (in original portion) Lo_crqinq Proqram: Open Hole Logs: Cased Hole Logs: GR / Resistivity / Density-Neutron Cement Bond Log Notes: All drill solids generated from the 1A-04A sidetrack will be hauled to an approved Prudhoe Bay class II well for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted GKA disposal well. KRU 1A-04 A GENERAL SIDETRACK PROCEDURE P&A WORK (Pre-Rig): /~ 1. MIRU slickline unit. RIH and pull 1" CV from mandrels #9 and #10 at 8033' and 8101' MD RKB and run 1" DV in each mandrel. Pull CV from mandrel #11 at 8260' MD RKB and leave open pocket. . MIRU CTU. RIH with cement retainer on CTU and set retainer at +/- 8015' MD RKB (in first full joint of 2-7/8" tubing below Otis 'RH' packer). Squeeze 45 bbls of 15.8 ppg Class G cement below retainer (11 bbl for the tubing and annular volume between the packers + 34 bbls into perfs). Bleed annulus pressure to 0 psi. Pressure test tubing above cement retainer to 2500 psi for 30 min (chart test). Slowly bleed tubing pressure to 0 psi and monitor pressure for build-up. RU slickline unit. RIH and pull 1" DV from mandrel #8 at 7944' MD RKB, leaving an open pocket. RU E-line unit. RIH and cut tubing at +/-7965' MD RKB (middle of first full joint of 3-1/2" tubing above Otis 'RH' packer). Set BPV and VR plug. Remove well house and scaffolding. RIG WORK: 1. MIRU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Verify well is dead. Circulate well to 9.6 ppg milling fluid through tubing cut at 7,965' MD. 3. Set BPV. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. 5. PU 7" Casing Scraper on DP and run through Bridge Plug setting depth. 6. RU E-line Unit. RIH and set Bridge Plug at +/- 6,520' MD. 7. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, Etc and RIH. Orient and set whipstock w/MWD. Shear off whipstock bolt and test wellbore to 3000 psi, testing bridge plug and cement plug to ensure isolation from perforations. Mill window in 7" casing and 20' formation. Perform FIT test to 12.2 ppg (max expected ECD=I 1.9 ppg at window for 10.5 ppg LSND mud and cuttings). POOH and LD milling assembly. Note: If unable to obtain adequate FIT, squeeze window with cement, redrill and test again. 8. RIH w/6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, perform FIT test, kick-off and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH and lay down drilling assembly. Note: Mud should be weighted up +/- 200' MD above estimated top of Kuparuk. 9. Run 4-1/2" liner to TD w/150' of overlap above top of milled window. 10. Cement liner in place, set liner hanger and liner top packer, circulate out excess cement and POOH laying down 3-1/2" DP. 11. Pressure test casing and liner lap to 3000 psi for 30 min (Chart Test for State). KRU 1A-04 A GENERAL SIDETRACK PROCEDURE 12. RIH w/4-1/2" completion assembly and sting into Seal Bore Extension below liner top packer. Space out. Displace well to sea water and land tubing. Test tubing and annulus to 3000 psi. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 14. Clean out well to PBTD w/coiled tubing. E-line perforate through tubing. BDN 11/20/00 KRU 1A-04A Injector Proposed Completion PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail. These depths need to be converted to Nordic RKB. 4-1/2" liner top @ +/- 6350' MD Top of Whipstock & KOP at +/-6500' MD G. 4-1/2" 5M FMC tubing hanger with 4-1/2" L-80 BTC ABMod pin down F. 4-1/2", 12.6#, L-80 BTC ABMod tubing to surface E. 4-1/2" Camco 'DB' landing nipple with 3.875" ID No-Go profile set at +/-500' MD D. 4-1/2", 12.6#, L-80 ABMod tubing to 'DB' landing nipple C. 4-1/2" Baker 'CMU' sliding sleeve w/3.812" Camco 'DB' No-Go profile. Sleeve run in closed position B. 1 joint - 4-1/2", 12.6#, L-80 BTC ABMod tubing A. Baker 4-1/2" seal assembly w/10' of seals and special Iocator to locate in SBE Liner Top: - Baker 12' Seal Bore Extension with 4.75" ID. - Baker 4-1/2" x 7" 'ZXP' Liner Top Isolation Packer. - Baker 4-1/2" x 7" 'HMC' Hydraulic Liner Hanger with 4-1/2" NSCT pin down. Window in 7" Bridge Plug at +/-6520' MD Abandoned D,C,B Sand Perfs 4-1/2" Camco 'DB' landing nipple with 3.75" ID No-Go profile Abandoned A-Sand Peds C Sand Future Perfs 4-1/2" Camco 'A' seating nipple with 3.75" ID polish bore 4-1/2" L-80 NSCT liner @ A Sand +/-9020' MD 7",26#, K-55 casing@8824'MD BDN 10/20/00, v. 1 ICreeted by rix~ FOR: NOEL Dote plotted: 21-Nov-20QO Pqot ~eference re 4A Vereion Ceerdrnotee ore in feet reference slot ~4A. True Vertic`"l Depths or,. reference RI<B (Nordic 4800- 4950 7 Window 5100 5250 5400 5550 5700 5850 6000 6150 6500 6450 Phillips Alaska, Inc. Struotum: Pad lA Well: 4A Field: Kuparuk River Unit Looaflon: North Slope, Alaska East (feet) -> 2600 2800 ~000 5200 3400 3600 5800 4000 4200 4400 4600 4800 5000 I I I I I [ I I I I I I I I I I I I I I I I I TD LOCATION: 56g' F'SL, 426' FEL SEC. 5, T11N, R10E Tie-in Survey /~D 50.00 Top of Window/Interpolated Point -Casing Pt ~1 14 KOP/Base °f Whipst°ck I TARGET LOCATION: I "' M|ll Bury Depth/Begin Drop/Turn 187' FSL, 554' F£L Target-A4 Sand [ ~/ ~ Top Kuparuk A4 48.47 - ' SEC. 5, T11N, RIOE ~ Top Kuparuk A 46.26 DES: 6.00 deg per 100 fi/~/-oP~c4T°P Kuporuk B 44.59 Jk/e Top. Kuparuk D 43.11 705' FNL, 1712' FEL Bose HRZ/Top U.Kolublk. SEC. 8, T11N, RIOE 45.36 ~ 44.26 ~T E~O To~ 45.79 Dp of Window/Interpolated Point - EOC ~ KOP/Bose of Whipsto~ C Top HRZ 7 Window ~epth/Beg,n Drop/Turn Base HRZ/Top U.Kalublk TANGENT ANGLE 47.72 DEG K- 1/Top L.Kalublk Top Kuparuk D Top C4 35.06 AZIMUTH 1856' (TO TARGET) ***Plone of Proposol*** Top Kuparuk B Target-A4 Sand Top Kuparuk A Top Kuparuk A4 400 600 8O0 lO00 0 12oo ~-~ 1400 I v 1600 1800 2000 6600 6750 TD-Caslng Pt 0 150 500 450 600 750 gOO 1050 1200 1550 1500 1650 1800 1950 21 O0 2250 2400 2550 Vertical Section (feet) -> Azlmuth 55.06 with reference 0.00 N, 0.00 W from slot #4A ICreated by rixse ]i'O:~: Date plotted: 21-Nov-2000 ~ot ~efererme i, 4A Verak:. ~A. Coor~nate~ ore in feet reference ,lot ~4A. True Vertical Depth,, ar-, reference RKB (Nordic Phillips Alaska, Inc. Struoture: Pad lA Well: 4A field: Kuporuk River Unlf Location: North Slope, Alaska Point Tie-in Survey Top of Window/InterpNJ KOP/Bose of WhipstocNJ Mill Bury Depth/BegiNJ EOC Top HRZ Bose HRZ/Top U.KolubNJ K- 1/Top L.Kolubik Top Kuporuk D Top C4 Top Kuporuk B Top Kuparuk A Top Kuporuk A4 Target-A4 Sand TD-Casing Pt PROFILF COMMENT MD 'lnc Dir TVD - 6496.00 50.00 116.10 4932.10 6504.00 50.00 116.14 49.37.24 6517.00 51.41 114.55 4945.48 653`5.00 5,5.15 112.21 4955.27 7495.67 47.72 5~.06 5623.86 7756.97 47.72 `55.06 5801.00 8076.5`3 47.72 `55.06 6016.00 8257.06 47.72 ,55.06 6124.00 8360.4,5 47.72 `55.06 6207.00 8599.07 47.72 55.06 6235.00 8532.84 47.72 `55.06 6325.00 8682.96 47.72 55.06 6424.00 8717.15 47.72 55.06 6447.00 8720.12 47.72 `55.06 6449.00 9020.12 47.72 `55.06 6650.85 DATA North -1720.25 -1722.9`5 -1727.22 -1732.22 -1572.94 -1415.50 -1219.99 - 1122.78 -1048.07 -1024.67 -94,3.66 -852.75 -832.05 -830.25 -648.59 East 3253.29 ,3258.80 ,3267.9O ,3279.52 `3892.10 4004.01 41`39.8,3 42O8.06 4260.50 4276.92 4,3,33.78 4,597.58 4412.11 4413.38 4540.88 V. Sect 460.96 461.91 465.65 466.22 948.51 114`3 ..30 1`379.75 1498.49 1589.76 1618.`35 1717.32 1828.58 1855.68 1855.88 2O77.82 Deg/'~'-) 0.00 0.40 15.20 15.20 6.00 0.00 0.00 0.00~ 0.00 0.00 0.00 0.00 0.00 0.00 Crated by r~m FOR-* NOF, L Dote plott~: 21-Nov-2000 Plot Reference b 4A Version ~3. Coordrnetes om in feet refe~ Mot ~r4A. True Vertlcel Depths ~ertee RKB (Nord~ I Phillips Alaska, Inc. .Sfruoture: Pad lA Well: 4A Field: Kuparuk River Unlf Location: North Slope, Alaeka 200 200 400 600 ~ 800 · ~- 1000 0 1200 I V 1400 1600 1800 2000 2200 East (feet) -> 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 I I I I I I I I I I I I t t I t I I I I I I I I I I I I I I I ! I I I I I I I I I ~6500 700 -~oo / /6500 o1 aa ' ./6:~oo ,/' /! ~',~4100 ~',,,~,_§..1_00 / " .V' 5900 5100 ~,~5500 '~00 0 i i i i i i i i I i i i i i i i i i i i i i i i ii i i i i i i i i i i i i i i 2000 2200 2400 2600 2800 5000 5200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 East (feet) -> 200 2OO 4OO 1000 "~ 1200 1400 1600 1800 2OOO 22O0 V Ic~ ~ ~ FOR: NOEL Dot~ plattad: 21-Nou-2000 330 320 Phillips Alaska, Inc. Structure: Pad lA Well: ,LA Field: Kuparuk River Unit Location : North Slope, Alaska TRUE NORTH 350 0 10 340 20 3O 4O 310 5O 3O0 6O 290 7O 28O 8O 27O 9O 26O lO0 25O 110 240 120 25O 130 220 140 210 I 150 200 160 190 80 170 All depths shown (]re Meosured depths on Reference Well Normal Plone Travelling Cylinder - Feet q)JON enJ± s~ q~JoN eoueae~eB ggBI - e4JeL3 :p.LoJeqds 'l~ auoz - e4SeLe :adX)UO.L)Oe?OJd 3 O0'g~g N O0'6IOI cae sa)eu~paoo3 LeOOL 3OL$ 90L'gBlO~ 3 'gOL'9OIIL6~ N cae se3eubpdoo3 PbJ9 3OLS gog'gg O~ 6~'~6~'~ 6~ OZU s~ uo~3eooL 3o[s gIL'§g 0~. 6~I~'gLI'~ 6I OLU uo paa3ua3 s~ aan3ona3s 9SS'9S ~ OSI~'gLS'~I 9I OLU uo paa3ua3 s~ pLa~J O00g-AON-I~ : pes~AeJ )sel O00~-AON-O~ : pe)eeao O00~-AON-i~ : pe%u~Jd : asue3~l S6g~oad : ~aa ano g#uo~saeAW : ~ea anoA 031NI seqfnH aetna ~q S3IINIVmt~33Nll NOIIISOd 9NIOrll3NI 9N IISI1 lVSOdOt~d ~)lS~ LV ' ado LS q3JON :[.LUff JOA.L~) ~lna~dn)l YHf 3,OLS Vl~ P~d · ouI '~lS~LV sd.~LL.~qd Phillips Alaska, Inc. Pad 1A,4A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I NAT E S 6496.00 50.00 116.10 4932.10 1720.23 S 3253.29 E 6500.00 50.00 116.12 4934.67 1721.58 S 3256.05 E 6504.00 50.00 116.14 4937.24 1722.93 S 3258.80 E 6517.00 51.41 114.35 4945.48 1727.22 S 3267.90 E 6533.00 53.15 112.21 4955.27 1732.22 S 3279.52 E 6600.00 51.14 107.80 4996.39 1750.33 S 3329.20 E 6700.00 48.47 100.76 5060.97 1769.23 S 3403.11 E 6800.00 46.26 93.17 5128.76 1778.22 S 3476.02 E 6900.00 44.59 85.08 5198.99 1777.21 S 3547.12 E 7000.00 43.53 76.58 5270.92 1766.19 S 3615.65 E PROPOSAL LISTING Page 1 Your ref : 4AVersion#3 Last revised : 21-Nov-2000 Dogleg Vert Deg/lOOft Sect 0.00 460.96 0.40 461.44 0.40 461.91 15.20 463.63 15.20 466.22 6.00 479.93 6.00 506.92 6.00 541.44 6.00 583.13 6.00 631.51 Ti e- i n Survey Top of Window/Interpolated Point KOP/Base of Whipstock Mill Bury Depth/Begin Drop/Turn 7100.00 43.11 67.85 5343.74 1745.30 S 3680.85 E 6.00 686.07 7200.00 43.36 59.09 5416.67 1714.76 S 3742.01 E 6.00 746.20 7300.00 44.26 50.52 5488.90 1674.90 S 3798.45 E 6.00 811.25 7400.00 45.79 42.31 5559.63 1626.17 S 3849.56 E 6.00 880.50 7493.67 47.72 35.06 5623.86 1572.94 S 3892.10 E 6.00 948.51 EOC 7500.00 47.72 35.06 5628.11 1569.11S 3894.79 E 0.00 953.19 7756.97 47.72 35.06 5801.00 1413.50 S 4004.01 E 0.00 1143.30 Top HRZ 8000.00 47.72 35.06 5964.51 1266.33 S 4107.30 E 0.00 1323.10 8076.53 47.72 35.06 6016.00 1219.99 S 4139.83 E 0.00 1379.73 Base HRZ/Top U.Kalubik 8237.06 47.72 35.06 6124.00 1122.78 S 4208.06 E 0.00 1498.49 K-l/Top L.Kalubik 8360.43 47.72 35.06 6207.00 1048.07 S 4260.50 E 0.00 1589.76 Top Kuparuk D 8399.07 47.72 35.06 6233.00 1024.67 S 4276.92 E 0.00 1618.35 Top C4 8500.00 47.72 35.06 6300.90 963.55 S 4319.82 E 0.00 1693.02 8532.84 47.72 35.06 6323.00 943.66 S 4333.78 E 0.00 1717.32 Top Kuparuk B 8682.96 47.72 35.06 6424.00 852.75 S 4397.58 E 0.00 1828.38 Top Kuparuk A 8717.15 47.72 35.06 6447.00 832.05 S 4412.11 E 0.00 1853.68 Top KuparukA4 8720.12 47.72 35.06 6449.00 830.25 S 4413.38 E 0.00 1855.88 1A-O4A-A4 Target 11-14-00 9000.00 47.72 35.06 6637.30 660.77 S 4532.33 E 0.00 2062.94 9020.12 47.72 35.06 6650.83 648.59 S 4540.88 E 0.00 2077.82 TD-Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #4A and TVD from RKB (Nordic 3) (96.00 Ft above mean sea level). Bottom hole distance is 4586.97 on azimuth 98.13 degrees from wellhead. Total Dogleg for wellpath is 62.08 degrees. Vertical section is from N 0.00 W 0.00 on azimuth 35.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska. Inc. Pad 1A,4A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 4AVersion#3 Last revised : 21-Nov-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 6496.00 4932.10 1720.23 S 3253.29 E Tie-in Survey 6504.00 4937.24 6517.00 4945.48 6533.00 4955.27 7493.67 5623.86 7756.97 5801.00 8076.53 6016.00 8237.06 6124.00 8360.43 6207.00 8399.07 6233.00 8532.84 6323.00 8682.96 6424.00 8717.15 6447.00 8720.12 6449.00 9020.12 6650.83 1722.93 1727.22 1732 22 1572 94 1413 50 1219 99 1122 78 1048 07 1024 67 943.66 852.75 832.05 830.25 648.59 S 3258.80 E Top of Window/Interpolated Point S 3267.90 E KOP/Base of Whipstock S 3279.52 E Mill Bury Depth/Begin Drop/Turn S 3892.10 E EOC S 4004.01E Top HRZ S 4139.83 E Base HRZ/Top U.Kalubik S 4208.06 E K-l/Top L.Kalubik S 4260.50 E Top Kuparuk D S 4276.92 E Top C4 S 4333.78 E Top Kuparuk B S 4397.58 E Top Kuparuk A S 4412.11 E Top KuparukA4 S 4413.38 E 1A-O4A-A4 Target 11-14-00 S 4540.88 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coord$. Casing n/a 4932.10 1720.23S 3253.29E 6504.00 4937.24 1722.93S 3258.80E 7" Window n/a 4932.10 1720.23S 3253.29E 9020.12 6650.83 648.59S 4540.88E 4-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1A-O4A-A4 Target 11- 544600.000,5970300.000,0.0000 6449.00 830.25S 4413.38E 14-Nov-2000 Phillips Alaska, Inc. Pad lA 4A slot ~4A Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: 4AVersion#3 Our ref : prop4295 License : Date printed : 21-Nov-2000 Date created: 20-Nov-2000 Last revised: 21-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nTO 19 45.173,w149 40 35.713 Slot location is n70 19 55.195,w149 40 26.603 Slot Grid coordinates are N 5971106.703, E 540182.706 Slot local coordinates are 1019.00 N 312.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Pad 1A,4A Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 1 Your ref : 4AVersion#3 Last revised : 21-Nov-2000 Measured Inclin Azimuth True Vert R E C TAN G U L A R G R I D C 0 0 R D S G E 0 G RA Depth Degrees Degrees Depth C 0 0 R D I NAT E S Easting Northing C O0 R D I 6496.00 50.00 116.10 4932.10 1720.23S 3253.29E 543444.78 5969403.96 n70 19 38.27 6500.00 50.00 116.12 4934.67 1721.58S 3256.05E 543447.54 5969402.62 n70 19 38.25 6504.00 50.00 116.14 4937.24 1722.93S 3258.80E 543450.29 5969401.29 n70 19 38.24 6517.00 51.41 114.35 4945.48 1727.22S 3267.90E 543459.41 5969397.05 n70 19 38.20 6533.00 53.15 112.21 4955.27 1732.22S 3279.52E 543471.06 5969392.11 n70 19 38.15 6600.00 51.14 107.80 4996.39 1750.33S 3329.20E 543520.83 5969374.27 n70 19 37.97 6700.00 48.47 100.76 5060.97 1769.23S 3403.11E 543594.83 5969355.76 n70 19 37.79 6800.00 46.26 93.17 5128.76 1778.22S 3476.02E 543667.78 5969347.15 n7O 19 37.70 6900.00 44.59 85.08 5198.99 1777.21S 3547.12E 543738.88 5969348.55 n70 19 37.71 7000.00 43.53 76.58 5270.92 1766.19S 3615.65E 543807.34 5969359.92 n70 19 37.81 7100.00 43.11 67.85 5343.74 1745.30S 3680.85E 543872.42 5969381.16 n70 19 38.02 7200.00 43.36 59.09 5416.67 1714.76S 3742.01E 543933.41 5969412.02 nTO 19 38.32 7300.00 44.26 50.52 5488.90 1674.90S 3798.45E 543989.63 5969452.17 n70 19 38.71 7400.00 45.79 42.31 5559.63 1626.17S 3849.56E 544040.48 5969501.17 n70 19 39.19 7493.67 47.72 35.06 5623.86 1572.94S 3892.10E 544082.73 5969554.62 n70 19 39.71 7500.00 47.72 35.06 5628.11 1569.11S 3894.79E 544085.40 5969558.47 n70 19 39.75 7756.97 47.72 35.06 5801.00 1413.50S 4004.01E 544193.78 5969714.64 n70 19 41.28 8000.00 47.72 35.06 5964.51 1266.33S 4107.30E 544296.28 5969862.34 nTO 19 42.73 8076.53 47.72 35.06 6016.00 1219.99S 4139.83E 544328.56 5969908.86 n70 19 43.18 8237.06 47.72 35.06 6124.00 1122.78S 4208.06E 544396.26 5970006.42 n70 1944.14 8360.43 47.72 35.06 6207.00 1048.07S 4260.50E 544448.29 5970081.39 n70 19 44.87 8399.07 47.72 35.06 6233.00 1024.67S 4276.92E 544464.59 5970104.88 n70 19 45.10 8500.00 47.72 35.06 6300.90 963.55S 4319.82E 544507.16 5970166.22 n70 19 45.70 8532.84 47.72 35.06 6323.00 943.66S 4333.78E 544521.01 5970186.18 n70 19 45.90 8682.96 47.72 35.06 6424.00 852.75S 4397.58E 544584.33 5970277.42 nTO 19 46.79 8717.15 47.72 35.06 6447.00 832.05S 4412.11E 544598.75 5970298.19 n70 19 47.00 8720.12 47.72 35.06 6449.00 830.25S 4413.38E 544600.00 5970300.00 n70 19 47.01 9000.00 47.72 35.06 6637.30 660.77S 4532.33E 544718.04 5970470.10 n70 19 48.68 9020.12 47.72 35.06 6650.83 648.59S 4540.88E 544726.53 5970482.32 n70 19 48.80 PHIC NATES w149 38 51.64 w149 38 51.56 w149 38 51.48 w149 38 51.21 w149 38 50.87 w149 38 49.42 w149 38 47.26 w149 38 45.13 w149 38 43.06 w149 38 41.06 w149 38 39.15 w149 38 37.37 w149 38 35.72 w149 38 34.23 w149 38 32.99 w149 38 32.91 w149 38 29.72 w149 38 26.70 w149 38 25.75 w149 38 23.75 w149 38 22.22 w149 38 21.74 w149 38 20.49 w149 38 20.08 w149 38 18.22 w149 38 17.79 w149 38 17.75 w149 38 14.28 w149 38 14.03 All data in feet unless otherwise stated, Calculation uses minimum curvature method. Coordinates from slot~4A and TVD from RKB (Nordic 3) (96.00 Ft above mean sea level). Bottom hole distance is 4586.97 on azimuth 98.13 degrees from wellhead. Total Dogleg for wellpath is 62.08 degrees. Vertical section is from N 0.00 W 0.00 on azimuth 35.06 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska. Inc. Pad 1A,4A Kuparuk River Unit,North Slope. A1 aska PROPOSAL LISTING Page 2 Your ref : 4A Version#3 Last revised : 21-Nov-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 6496.00 4932.10 1720.23S 3253.29E Tie-in Survey 6504.00 4937.24 1722.93S 3258.80E Top of Window/Interpolated Point 6517.00 4945.48 1727.22S 3267.90E KOP/Base of Whipstock 6533.00 4955.27 1732.22S 3279.52E Mill Bury Depth/Begin Drop/Turn 7493.67 5623.86 1572.94S 3892.10E EOC 7756.97 5801.00 1413.50S 4004.01E Top HRZ 8076.53 6016.00 1219.99S 4139.83E Base HRZ/Top U.Kalubik 8237.06 6124.00 1122.78S 4208.06E K-l/Top L.Kalubik 8360.43 6207.00 1048.07S 4260.50E Top Kuparuk D 8399.07 6233.00 1024.67S 4276.92E Top C4 8532.84 6323.00 943.66S 4333.78E Top Kuparuk B 8682.96 6424.00 852.75S 4397.58E Top Kuparuk A 8717.15 6447.00 832.05S 4412.11E Top Kuparuk A4 8720.12 6449.00 830.25S 4413.38E 1A-O4A-A4 Target 11-14-00 9020.12 6650.83 648.59S 4540.88E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 4932.10 1720.23S 3253.29E 6504.00 4937.24 1722.93S 3258.80E 7" Window n/a 4932.10 1720.23S 3253.29E 9020.12 6650.83 648.59S 4540.88E 4-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Phillips Alaska. Inc. Pad 1A,4A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECT COOR 6496.00 50.00 116.10 4932.10 1720.23 6500.00 50.00 116.12 4934.67 1721.58 6504.00 50.00 116.14 4937.24 1722.93 6517.00 51.41 114.35 4945.48 1727.22 6533.00 53.15 112.21 4955.27 1732.22 6600.00 51.14 107.80 4996.39 1750.33 6700.00 48.47 100.76 5060.97 1769.23 6800.00 46.26 93.17 5128.76 1778.22 6900.00 44.59 85.08 5198.99 1777.21 7000.00 43.53 76.58 5270.92 1766.19 PROPOSAL LISTING Page 1 Your ref : 4AVersion#3 Last revised : 21-Nov-2000 A N G U L A R Vert Ellipse Semi Axes Minor D I N A T E S Sect Major Minor Vert. Azi. S 3253.29 E 460.96 82.09 26.01 23.22 297.69 S 3256.05 E 461.44 82.13 26.02 23.23 297.69 S 3258.80 E 461.91 82.18 26.04 23.25 297.69 S 3267.90 E 463.63 82.32 26.08 23.30 297.68 S 3279.52 E 466.22 82.51 26.13 23.37 297.67 S 3329.20 E 479.93 83.39 26.37 23.65 297.55 S 3403.11 E 506.92 84.87 26.79 24.05 297.18 S 3476.02 E 541.44 86.50 27.37 24.45 296.56 S 3547.12 E 583.13 88.16 28.17 24.84 295.70 S 3615.65 E 631.51 89.78 29.22 25.22 294.63 7100.00 43.11 67.85 5343.74 1745.30 S 3680.85 E 686.07 91.28 30.55 25.61 293.39 7200.00 43.36 59.09 5416.67 1714.76 S 3742.01 E 746.20 92.61 32.12 26.00 292.00 7300.00 44.26 50.52 5488.90 1674.90 S 3798.45 E 811.25 93.74 33.88 26.40 290.51 7400.00 45.79 42.31 5559.63 1626.17 S 3849.56 E 880.50 94.65 35.78 26.83 288.96 7493.67 47.72 35.06 5623.86 1572.94 S 3892.10 E 948.51 95.33 37.61 27.25 287.48 7500.00 47.72 35.06 5628.11 1569.11 S 3894.79 E 953.19 95.37 37.74 27.28 287.38 7756.97 47.72 35.06 5801.00 1413.50 S 4004.01 E 1143.30 97.86 43.11 28.48 282.81 8000.00 47.72 35.06 5964.51 1266.33 S 4107.30 E 1323.10 100.21 48.19 29.62 278.49 8076.53 47.72 35.06 6016.00 1219.99 S 4139.83 E 1379.73 101.35 49.67 30.00 276.91 8237.06 47.72 35.06 6124.00 1122.78 S 4208.06 E 1498.49 103.75 52.77 30.79 273.60 8360.43 47.72 35.06 6207.00 1048.07 S 4260.50 E 1589.76 105.58 55.15 31.40 271.06 8399.07 47.72 35.06 6233.00 1024.67 S 4276.92 E 1618.35 106.16 55.90 31.59 270.26 8500.00 47.72 35.06 6300.90 963.55 S 4319.82 E 1693.02 107.66 57.85 32.09 268.18 8532.84 47.72 35.06 6323.00 943.66 S 4333.78 E 1717.32 108.30 58.39 32.26 267.49 8682.96 47.72 35.06 6424.00 852.75 S 4397.58 E 1828.38 111.19 60.85 33.02 264.33 8717.15 47.72 35.06 6447.00 832.05 S 4412.11 E 1853.68 111.85 61.42 33.19 263.61 8720.12 47.72 35.06 6449.00 830.25 S 4413.38 E 1855.88 111.91 61.47 33.21 263.55 9000.00 47.72 35.06 6637.30 660.77 S 4532.33 E 2062.94 118.16 65.42 34.65 257.94 9020.12 47.72 35.06 6650.83 648.59 S 4540.88 E 2077.82 118.64 65.68 34.76 257.56 All data is in feet unless otherwise stated. Coordinates from slot ~A and TVD from RKB (Nordic 3) (96,00 Ft above mean sea level). Bottom hole distance is 4586.97 on azimuth 98.13 degrees from wellhead. Vertical section is from N 0.00 W 0.00 on azimuth 35.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1A,4A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 4AVersion#3 Last revised : 21-Nov-2000 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6496 ARCO (H.A. Gyro) User specified 82.09 26.01 23.22 6496 9020 ARCO (H.A. Mag) User specified 118.64 65.68 34.76 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments i n wel 1 path MD TVD Rectangul ar Coords. Comment 6496.00 4932.10 1720.23 S 3253.29 E Tie-in Survey 6504.00 4937.24 1722.93 S 3258.80 E Top of Window/Interpolated Point 6517.00 4945.48 1727.22 S 3267.90 E KOP/Base of Whipstock 6533.00 4955.27 1732.22 S 3279.52 E Mill Bury Depth/Begin Drop/Turn 7493.67 5623.86 1572.94 S 3892.10 E EOC 7756.97 5801.00 1413.50 S 4004.01 E Top HRZ 8076.53 6016.00 1219.99 S 4139.83 E Base HRZ/Top U.Kalubik 8237.06 6124.00 1122.78 S 4208.06 E K-l/Top L.Kalubik 8360.43 6207.00 1048.07 S 4260.50 E Top Kuparuk D 8399.07 6233.00 1024.67 S 4276.92 E Top C4 8532.84 6323.00 943.66 S 4333.78 E Top Kuparuk B 8682.96 6424.00 852.75 S 4397.58 E Top Kuparuk A 8717.15 6447.00 832.05 S 4412.11 E Top KuparukA4 8720.12 6449.00 830.25 S 4413.38 E 1A-O4A-A4 Target 11-14-00 9020.12 6650.83 648.59 S 4540.88 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 4932.10 1720.23S 3253.29E 6504.00 4937.24 1722.93S 3258.80E 7" Window n/a 4932.10 1720.23S 3253.29E 9020.12 6650.83 648.59S 4540.88E 4-1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1A-O4A-A4 Target 11- 544600.000,5970300.000,0.0000 6449.00 830.25S 4413.38E 14-Nov-2000 Phillips Alaska, Inc. Pad lA 4A slot #4A Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 4AVersion#3 Our ref : prop4295 License : Date printed : 21-Nov-2000 Date created : 20-Nov-2000 Last revised : 21-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 40 35.713 Slot location is n70 19 55.195,w149 40 26.603 Slot Grid coordinates are N 5971106.703, E 540182.706 Slot local coordinates are 1019.00 N 312.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 1000 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-9340'>,,27,Pad lA GMS <O-7675'>,,5,Pad lA MSS <1511-2663'>,,7,Pad lA PGMS <0-8500'> PGMS <0-8276'> PGMS <0-7948'> PGMS <0-7380'> GMS <0-9432'> PGMS <0-9034'> PGMS <0-8000'> PGMS <0-7144'> PGMS <0-8285'> PGMS <0-8865'> PGMS <0-7495'> GMS <0-9732'> ,7A,Pad lA ,26,Pad lA ,19,Pad lA ,18,Pad lA ,lO,Pad lA ,20,Pad lA ,22,Pad lA ,13,Pad lA ,14,Pad lA ,12,Pad lA ,23,Pad lA ,11,Pad lA PGMS <O-10025'>,,28,Pad lA GMS <O-9159'>,,6,Pad lA PGMS <0-8115'>,,25,Pad lA GMS <0-8880'>,,3,Pad lA Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 1-Nov-2000 )3977.8( 6496.0 6496.0 9-May-1991 )4409.6( 6496.0 6496.0 1-Nov-2000 )4183.4( 6496.0 6496.0 1-Nov-2000 )4103.3( 6496.0 6496.0 1-Nov-2000 )4719.8( 6496.0 6496.0 1-Nov-2000 )4816.2( 6496.0 8100.0 1-Nov-2000 )2743.8( 9020.1 9020.1 7-May-1991 )4609.7( 6496.0 6496.0 1-Nov-2000 )1749.2( 9020.1 9020.1 1-Nov-2000 )812.1( 8076.5 8076.5 1-Nov-2000 )4299.0( 6496.0 6496.0 1-Nov-2000 )926.1( 9020.1 9020.1 1-Nov-2000 )4560.7( 6496.0 6496.0 1-Nov-2000 )5068.8( 6496.0 6496.0 7-May-1991 )1419.4( 6496.0 6496.0 1-Nov-2000 )2787.1( 6496.0 6496.0 lO-May-1991 )2871.8( 6496.0 6496.0 1-Nov-2000 )1728.4( 6496.0 6496.0 7-May-1991 )3709.1( 9020.1 9020.1 GMS <0- 8150 '>., 2, Pad 1~ PGMS <0-7120'>,, 9, Pad lA GMS <0-7830'>,, 1, Pad lA GMS <O-6300'>,,WS12.Pad lA PGMS <O-8560'>,,17,Pad lA PGMS <0- 9210'>., 15, Pad lA MSS <4451 - 7622'>,,16,Pad lA GMS <0- 7411' >,, 16A. Pad lA 24 Version #3,,24,Pad lA GMS <0-8844'>,, 4, Pad lA GMS <0-8840' >Depth Shifted, ,4, Pad lA 7-May-1991 )4954.4( 1-Nov-2000 )2157.3( 7-May-1991 )4873.7( 1-Nov-2000 )3229.8( 1-Nov-2000 )4870.0( 1-Nov-2000 )4945.1( 1-Nov-2000 )3990.6( lO-May-1991 )3990.6( 16-Nov-2000 )3324.5( 10-May-1991 )0.0( 21-Nov-2000 )0.0( 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 7208.3 7100.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 7208.3 7100.0 Phillips Alaska, Inc. Pad 1A,4A Kuparuk River Unit,North Slope. Alaska Reference wellpath M.D. T.V.D. CLEARANCE LISTING Page 2 Your ref : 4A Version#3 Last revised : 21-Nov-2000 Object wellpath : PGMS <0-8000'>,.22,Pad lA Horiz Min'm Ellipse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 7396.0 5556.8 1628.3S 3847.6E 7642.1 6353.5 1387.4S 3225.9E 291.2 1038.9 )969.2( 7496.0 5625.4 1571.5S 3893.1E 7703.9 6393.1 1406.4S 3269.5E 284.8 1002.7 )931.2( 7596.0 5692.7 1511.0S 3935.6E 7756.8 6426.9 1423.1S 3306.6E 278.0 970.7* )895.9( 7696.0 5760.0 1450.4S 3978.1E 7805.2 6457.8 1438.8S 3340.5E 271.0 945.3* )865.8( 7796.0 5827.3 1389.9S 4020.6E 7851.2 6487.2 1454.5S 3372.1E 264.3 927.5* )841.7( 7896.0 5894.5 1329.3S 4063.1E 7891.6 6513.0 1469.0S 3399.5E 258.1 917.9' )824.5( 7996.0 5961.8 1268.8S 4105.6E 7941.3 6544.9 1487.2S 3433.0E 252.0 916.6' )814.6( 8096.0 6029.1 1208.2S 4148.1E 7991.0 6576.8 1505.4S 3466.6E 246.4 923.5 )812.2( 8196.0 6096.4 1147.6S 4190.6E 8000.0 6582.6 1508.6S 3472.6E 243.3 939.3 )819.3( 8296.0 6163.7 1087.1S 4233.1E 8000.0 6582.6 1508.6S 3472.6E 241.0 965.2 )837.5( 8396.0 6230.9 8496.0 6298.2 8596.0 6365.5 1026.5S 4275.6E 8000.0 6582.6 1508.6S 3472.6E 239.0 1000.4 )866.4( 966.0S 4318.1E 8000.0 6582.6 1508.6S 3472.6E 237.3 1044.1 )904.9( 905.4S 4360.6E 8000.0 6582.6 1508.6S 3472.6E 235.8 1095.2 )952.2( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~A and TVD from RKB (Nordic 3) (96.00 Ft above mean sea level). Vertical section is from N 0.00 W 0.00 on azimuth 35.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ,, Phillips Alaska, Inc. Pad 1A,4A Kuparuk River Unit,North Slope, Alaska M,D, 8796.O 8896.0 8996.0 CLEARANCE LISTING Page 3 Your ref : 4AVersion#3 Last revised : 21-Nov-2000 Reference wellpath Object wellpath : PGMS <O-8285'>,,14,Pad lA Horiz Min'm Ellipse T.V.D. Rect Coordinates M.D.T.V.D. Rect Coordinates Bearing Dist Sep'n 6500.0 784.3S 4445.6E 8285.0 6929.7 131.9S 3657.1E 309.6 1110.0 )973.3( 6567.3 723.7S 4488.1E 8285.0 6929.7 131.9S 3657.1E 305.5 1082.7 )946.5( 6634.6 663.2S 4530.6E 8285.0 6929.7 131.9S 3657.1E 301.3 1064.2 )928.9( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~4A and TVD from RKB (Nordic 3) (g6.00 Ft above mean sea level), Vertical section is from N 0.00 W 0.00 on azimuth 35.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1A,4A Kuparuk River Unit,North Slope. Alaska Reference wellpath CLEARANCE LISTING Page 4 Your ref: 4AVersion#3 Last revised : 21-Nov-2000 Object wellpath: GMS <O-8844'>,,4,Pad lA Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 6496.0 4932.1 1720.2S 3253.3E 6500.0 4932.1 1720.2S 3253.3E 270.0 0.0 )0.0( 6596.0 4993.9 1749.4S 3326.2E 6599.7 4996.2 1754.1S 3321.7E 223.6 7.0 )0.0( 6696.0 5058.3 1768.7S 3400.2E 6698.5 5060.3 1787.7S 3388.9E 210.6 22.2 )0.0( 6796.0 5126.0 1778.1S 3473.1E 6796.6 5125.9 1818.8S 3454.9E 204.1 44.6 )O.O( 6896.0 5196.1 1777.4S 3544.3E 6891.0 5191.9 1846.8S 3516.4E 201.9 74.9 )0.0( 6996.0 5268.0 1766.8S 3613.0E 6982.9 5259.0 1873.8S 3573.1E 200.5 114.6 )0.0( 7096.0 5340.8 1746.3S 3678.3E 7067.6 5323.3 1898.4S 3622.3E 200.2 163.0 )0.0( 7196.0 5413.8 1716.2S 3739.6E 7142.5 5382.2 1921.3S 3662.6E 200.6 221.4 )0.0( 7296.0 5486.0 1676.7S 3796.3E 7206.6 5432.7 1942.8S 3695.7E 200.7 289.5 )38.4( 7396.0 5556.8 1628.3S 3847.6E 7270.1 5482.5 1965.1S 3728.0E 199.6 365.1 )104.9( 7496.0 5625.4 1571.5S 3893.1E 7324.1 5524.9 1984.4S 3755.4E 198.4 446.6 )183.5( 7596.0 5692.7 1511.0S 3935.6E 7367.8 5559.4 2000.3S 3777.0E 198.0 531.4 )267.2( 7696.0 5760.0 1450.4S 3978.1E 7415.8 5597.7 2018.2S 3799.8E 197.4 616.9 )350.9( 7796.0 5827.3 .1389.9S 4020.6E 7464.8 5636.8 2036.7S 3822.8E 197.0 702.7 )434.7( 7896.0 5894.5 1329.3S 4063.1E 7510.8 5673.6 2054.1S 3844.3E 196.8 788.7 )519.2( 7996.0 5961.8 1268.8S 4105.6E 7553.3 5707.6 2070.5S 3863.6E 196.8 875.2 )604.5( 8096.0 6029.1 1208.2S 4148.1E 7594.2 5740.7 2086.7S 3881.6E 196.9 962.3 )690.4( 8196.0 6096.4 1147.6S 4190.6E 7645.4 5782.2 2107.1S 3903.5E 196.7 1049.6 )775.5( 8296.0 6163.7 1087.1S 4233.1E 7699.5 5826.3 2128.2S 3926.5E 196.4 1136.6 )860.1( 8396.0 6230.9 1026.5S 4275.6E 7734.6 5855.1 2142.0S 3941.1E 196.7 1223.7 )946.4( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~A and TVD from RKB (Nordic 3) (96.00 Ft above mean sea level). Vertical section is from N 0.00 W 0.00 on azimuth 35.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1A,4A Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 5 Your ref: 4A Version #3 Last revised : 21-Nov-2000 Reference wellpath Object wellpath : GMS <0-8840'>Depth Shifted,.4,Pad lA M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 6496.0 4932.1 6596.0 4993.9 6696.0 5058.3 6796.0 5126.0 6896.0 5196.1 1720.2S 3253.3E 6496.0 4932.1 1720.2S 3253.3E 270.0 0.0 )0.0( 1749.4S 3326.2E 6595.7 4996.2 1754.1S 3321.7E 223.6 7.0 )0.0( 1768.7S 3400.2E 6694.5 5060.3 1787.7S 3388.9E 210.6 22.2 )0.0( 1778.1S 3473.1E 6792.6 5125.9 1818.8S 3454.9E 204.1 44.6 )0.0( 1777.4S 3544.3E 6887.0 5191.9 1846.8S 3516.4E 201.9 74.9 )0.0( 6996.0 5268.0 7096.0 5340.8 7196.0 5413.8 7296.0 5486.0 7396.0 5556.8 1766.8S 3613.0E 6978.9 5259.0 1873.8S 3573.1E 200.5 114.6 )0.0( 1746.3S 3678.3E 7063.6 5323.3 1898.4S 3622.3E 200.2 163.0 )0.0( 1716.2S 3739.6E 7138.5 5382.1 1921.3S 3662.6E 200.6 221.4 )44.8( 1676.7S 3796.3E 7202.6 5432.7 1942.9S 3695.7E 200.7 289.5 )110.9( 1628.3S 3847.6E 7266.1 5482.5 1965.1S 3728.0E 199.6 365.1 )184.8( 7496.0 5625.4 1571.5S 3893.1E 7320.1 5524.9 1984.4S 3755.4E 198.4 446.7 )265.7( 7596.0 5692.7 1511.0S 3935.6E 7363.8 5559.4 2000.3S 3777.0E 198.0 531.4 )350.3( 7696.0 5760.0 1450.4S 3978.1E 7411.8 5597.7 2018.2S 3799.8E 197.4 616.9 )435.0( 7796.0 5827.3 1389.9S 4020.6E 7460.8 5636.8 2036.7S 3822.8E 197.0 702.7 )519.7( 7896.0 5894.5 1329.3S 4063.1E 7506.8 5673.6 2054.1S 3844.3E 196.8 788.7 )604.8( 7996.0 5961.8 8096.0 6029.1 8196.0 6096.4 8296.0 6163.7 1268.8S 4105.6E 7549.3 5707.6 2070.5S 3863.6E 196.8 875.2 )690.6( 1208.2S 4148.1E 7590.2 5740.7 2086.7S 3881.6E 196.9 962.3 )777.0( 1147.6S 4190.6E 7641.4 5782.2 2107.1S 3903.5E 196.7 1049.6 )862.8( 1087.1S 4233.1E 7695.5 5826.3 2128.3S 3926.5E 196.4 1136.6 )948.2( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot//4A and TVD from RKB (Nordic 3) (96.00 Ft above mean sea level). Vertical section is from N 0.00 W 0.00 on azimuth 35.06 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad lA 4A slot ~4A Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 4A Version #3 Our ref : prop4295 License : Date printed : 21-Nov-2000 Date created : 20-Nov-2000 Last revised : 21-Nov-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 40 35.713 Slot location is n70 19 55.195,w149 40 26.603 Slot Grid coordinates are N 5971106.703, E 540182.706 Slot local coordinates are 1019.00 N 312.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath GMS <O-8250'>,,4,Pad lB GMS <O-8153'>,,2,Pad lB GMS <O-7950'>,,3,Pad lB GMS <O-8550'>,,B-9-GI,Pad lB GMS <O-9200'>,,B-lO-GI,Pad lB GMS <O-10723'>,,B-11-GI,Pad lB GMS <O-3190'>,,WS-1,Pad lB GMS <0-3789'>,,WS-7,Pad lB GMS <O-3500'>,,WS-8,Pad lB GMS <O-3835'>,,WS-9,Pad lB GMS <O-3832'>,,WS-lO,Pad lB GMS <0-3800'>,,WS-ll,Pad lB GMS <0-4016'>,,CPF-1A,Pad lB GMS <O-6814'>,,5,Pad lB GMS <O-8810'>,,6,Pad lB GMS <O-9625'>,,7,Pad lB PMSS <2500-2796'>,,WS-4,Pad lB GMS <O-4018'>,,WS-4,Pad lB GMS <O-4018'>,,WS-2,Pad lB GMS <O-3992'>,,WS-3,Pad lB GMS <0-3951'>,,WS-5,Pad lB PMSS <0-7450'>, 15,Pad lB PMSS <0-7450'>, 16,Pad lB PMSS <0-9986'>, 14,Pad lB PGMS <0-8780'>, 12,Pad lB PGMS <0-7500'>, 17,Pad lB GMS <0-8585'>, 1,Pad lB Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 21-May-1991 5698.3 7720.0 7720 21-May-1991 2011.2 9020.1 9020 21-May-1991 6617.6 8500.0 8956 21-May-1991 4988.4 9020.1 9020 21-May-1991 6272.5 9020.1 9020 21-May-1991 6757.3 7680.0 8600 21-May-1991 6560.6 8560.0 8560 21-May-1991 5678.5 7516.0 7516 21-May-1991 5895.8 8532.8 8532 21-May-1991 5577.5 9020.1 9020. 21-May-lggl 4632.2 7436.0 7436. 21-May-lggl 4698.5 8500.0 8500. 21-May-1991 7343.5 7350.0 7350. 21-May-1991 5314.6 9020.1 9020. 21-May-1991 7108.0 7720.0 7720. 21-May-1991 7403.5 7840.0 8796. 21-May-1991 7267.9 7556.0 8776. 21-May-1991 7267.9 7556.0 8776. 21-May-1991 7635.1 8300.0 8596. 21-May-1991 7329.6 9020.1 9020. 21-May-1991 6806.3 7760.0 7760. 14-Apr-1994 4818.6 9020.1 9020. 24-Mar-1994 4549.1 9020.1 9020. 20-Mar-1994 3789.2 9020.1 9020. 23-Jun-1993 7661.9 7680.0 8480. 7-Jun-1994 6388.2 9020.1 9020. 21-May-1991 4208.1 7350.0 7350. PMSS <O-7900'>,,13,Pad(ID PMSS <O-7824'>,,18,Pad lB GMS <0-3835'>,,WS-6,Pad lB PMSS <O-8945'>,,19,Pad lB PMSS <6344 - 9710'>,,SA,Pad lB PGMS <O-9340'>.,27,Pad lA GMS <O-7675'>,,5,Pad lA MSS <1511-2663'>,,7,Pad lA PGMS <O-8500'>,,7A,Pad lA PGMS PGMS PGMS GMS PGMS PGMS PGMS PGMS PGMS PGMS GMS PGMS GMS PGMS GMS <0-8276'> <0-7948'> <0-7380'> <0-9432'> <0-9034'> <0-8000'> <0-7144'> <0-8285'> <0-8865'> <0-7495'> ,26.Pad lA ,19,Pad lA ,18,Pad lA ,lO,Pad lA ,20,Pad lA ,22,Pad lA ,13.Pad lA ,14,Pad lA ,12,Pad lA ,23,Pad lA <0-9732'> ,11,Pad lA <O-lO025'>,,28,Pad lA <O-9159'>,,6,Pad lA <O-8115'>,,25,Pad lA <O-8880'>,,3,Pad lA GMS <0-8150'>,,2,Pad lA PGMS <O-7120'>,,9,Pad lA GMS <O-7830'>,,1,Pad lA GMS <O-6300'>,,WS12,Pad lA PGMS <0-8560'>,,17,Pad lA PGMS <O-9210'>,,15,Pad lA MSS <4451 - 7622'>,,16,Pad lA GMS <O-7411'>,,16A,Pad lA GMS <O-8844'>,,4,Pad lA GMS <O-8840'>Depth Shifted,,4,Pad lA 22-Apr-1994 29-Apr-1994 21-May-1991 9-May-1994 30-Ju1-1997 1-Nov-2000 9-May-1991 1-Nov-2000 1-Nov-2000 1-Nov-2000 1-Nov-2000 1-Nov-2000 7-May-1991 1-Nov-2000 1-Nov-2000 1-Nov-2000 1-Nov-2000 1-Nov-2000 1-Nov-2000 7-May-1991 1-Nov-2000 lO-May-1991 1-Nov-2000 7-May-1991 7-May-1991 1-Nov-2000 7-May-1991 1-Nov-2000 1-Nov-2000 1-Nov-2000 1-Nov-2000 lO-May-1991 lO-May-1991 21-Nov-2000 2392.8 5920.7 6295.0 5571.3 7450.3 4075.9 4523.6 4227.2 4179.4 4772.5 4846.5 2908.9 4682.7 1951.1 916.1 4330.4 1061.1 4595.5 5104.2 1627.4 2919.7 3058.2 1867.9 3855.6 4986.9 2248.5 4907.3 3281 1 4901 3 4973 6 4046 1 4046 1 O0 O0 8836.0 (" 8976.0 9020.1 7358.3 7780.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 9020.1 6496.0 9020.1 7960.0 6496.0 9020.1 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6500.0 6500.0 8836.0 8976.0 9020.1 7358.3 8740.0 6496.0 6496.0 6496.0 6496.0 6496 0 8100 0 9020 1 6496 0 9020 1 7960 0 6496.0 9020.1 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 9020.1 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6496.0 6500.0 6500.0 PHILLII ' Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 November 22, 2000 Alaska Oil and Gas Conservation Commission 3001 Pomupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: W/.est'~/v~ 1A-04A 1019' FSL, 312' FWL, Sec. 5, T11 N, R10E 187' FSL, 554' FEL, Sec. 5, T11 N, R10E 369' FSL, 426' FEL, Sec. 5, T11 N, R10E Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill a development well West Sak 1A-04A. The'well will be drilled and completed using Nordic Rig 3. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuffings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite lA,. or hauled to an approved Prudhoe or GKA Class II disposal well. Also note that Phillips Alaska does not anticipate the presence of H=S in the formations to be encountered in this well. However, there will be H=S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report " (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mark Longdon, Geologist 263-4506 Please note that the anticipated spud date for this well is December 1, 2000. Should you have any questions or require further information, please contact Brian Noel at 265-6979, or James Trantham at 265-6434. Sincerely, James Trantham Drilling Engineering Supervisor RECEIVED NOV 2 2, ?nnrl 0il & Gas Cons. Commission WELL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION APPR DATE WELL NAME/,'~--4:;~/'/~ PROGRAM: exp dev redrll serv v' wellbore seg ann. disposal para req 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... . 5. 6. 7. 8. 9. 10. 11. 12. 13. N ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. D~TE 26. t ~/~l-oo' 27. - ' 28. 29. UNIT# ~:)///~z~ ~) ON/OFF SHORE 30. 31. 32. 33. 34. Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can.be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... N ' : . N .sr c.n i. u Ow ohy ogen.um e a,u e ..... Data presented on potential overpressure zones ........ Seismic analysis of shallow gas zones .............~/~ ~ N Seabed condition suwey (if off-shore) ......... '. ~l ~" y N Contain name/phone for weekly progress repo~s [expl~mto~ only] Y N Y N Y N GEOLOGY APPR Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ....... ..:.,.;~ ..... BOPE press rating appropriate; test to ,-z~~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) Will contain waste in a suitable receiving zonei ....... ~,PPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface;' (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/.Annular · /J'~ '~/0~ -~ COMMISSION: Comments/Instructions: I§ I§ Z c:Vnsoffice\wordian\diana\checklist (rev. 11101//00) 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 {he roadability of the Well History file and to . simpl, ify finding information, informati~3n 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. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Nov 13 14:53:04 2001 Reel Header Service name ............. LISTPE Date ..................... 01/11/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/11/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kurparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MWD RUN 2 AK-MM-00317 A. WEAVER D. HIEM 1A-04A 500292062101 Phillips Alaska, Inc. Sperry-Sun Drilling Services 13-NOV-01 5 liN 10E 1019 312 .00 95.90 66.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 6493.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER- MUELLER TUBE DETECTORS), ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 5. CTN DATA WERE REPROCESSED USING A FORMATION WATER CHLORIDE VALUE OF 15,150 PPM, BASED ON A PHONE CONVERSATION WITH WAYNE CAMPAIGN ON 11/13/01. THE FIELD DATA WERE PROCESSED USING A VALUE OF 50,000 PPM. 6. DEPTH SHIFTING/CORRECTION WAS WAIVED PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 03/02/01. 7. MWD RUN 2 REPRESENTS WELL 1A-04Ai WITH API# 50-029-20621-01. THIS WELL REACHED A TOTAL DEPTH OF 9161'MD/6657.28'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 9.6 - 9.7 PPG MUD SALINITY: 15,000 PPM CHLORIDES FORMATION WATER SALINITY: 15,150 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NCNT 6465.0 9069.5 FCNT 6465.0 9069.5 NPHI 6465.0 9069.5 PEF 6465.0 9085.0 GR 6465.5 9117.0 RPD 6469.0 9124.0 RPM 6469.0 9124.0 RPS 6469.0 9124.0 RPX 6469.0 9124.0 DRHO 6494.0 9085.0 RHOB 6494.0 9085.0 ROP 6504.5 9161.0 FET 6504.5 9124.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 6465.0 9161.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 P E F MWD BARN 4 1 68 12 16 20 24 28 32 36 40 44 48 52 4 5 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 6465 9161 ROP MWD FT/H 0.39 1149.96 GR MWD API 35.82 601.3 RPX MWD OHMM 0.59 1633.87 RPS MWD OHMM 0.79 949.64 RPM MWD OHMM 0.77 2000 RPD MWD OHMM 0.09 2000 FET MWD HOUR 0.28 8.39 NPHI MWD PU-S 20.05 56.46 FCNT MWD CNTS 112.65 914.63 NCNT MWD CNTS 14156.7 37836.2 RHOB MWD G/CM 1.51 3.24 DRHO MWD G/CM -0.65 0.45 PEF MWD BARN 2.22 16.75 Mean 7813 64.5558 157.999 4.02933 3.86937 19.6271 10.0629 1.12601 37.3792 292.709 21831 2.40618 0.0936813 4.28739 Nsam 5393 5314 5304 5311 5311 5311 5311 5240 5210 5210 5210 5183 5183 5241 First Reading 6465 6504.5 6465.5 6469 6469 6469 6469 6504.5 6465 6465 6465 6494 6494 6465 Last Reading 9161 9161 9117 9124 9124 9124 9124 9124 9069.5 9069.5 9069.5 9085 9085 9085 First Reading For Entire File .......... 6465 Last Reading For Entire File ........... 9161 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF GR RPD RPM RPS RPX DRHO RHOB ROP FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 6465.0 6465.0 6465.0 6465.0 6465.5 6469.0 6469.0 6469.0 6469.0 6494.0 6494.0 6504.5 6504.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): STOP DEPTH 9069.5 9069.5 9069.5 9085.0 9117.0 9124.0 9124.0 9124.0 9124.0 9085.0 9085.0 9161.0 9124.0 26-DEC-00 Insite 4.15 Memory 9161.0 6493.0 9161.0 44.0 58.0 TOOL NUMBER PB01750GR4 PB01750GR4 PB01750GR4 PB01750GR4 6.125 6493.0 Water Based 10.50 50.0 9.8 1200 3.4 2.300 1.100 1.900 2.800 65.0 143.0 65.0 65.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 LoGGinG Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD020 FT/H 4 1 GR MWD020 API 4 1 RPX MWD020 OHMM 4 1 RPS MWD020 OHMM 4 1 RPM MWD020 OHMM 4 1 RPD MWD020 OHMM 4 1 FET MWD020 HOUR 4 1 NPHI MWD020 PU-S 4 1 FCNT MWD020 CNTS 4 1 NCNT MWD020 CNTS 4 1 RHOB MWD020 G/CM 4 1 DRHO MWD020 G/CM 4 1 PEF MWD020 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Service Unit Min Max DEPT FT 6465 9161 ROP MWD020 FT/H 0.39 1149.96 GR MWD020 API 35.82 601.3 RPX MWD020 OHMM 0.59 1633.87 RPS MWD020 OHMM 0.79 949.64 RPM MWD020 OHMM 0.77 2000 RPD MWD020 OHMM 0.09 2000 FET MWD020 HOUR 0.28 8.39 NPHI MWD020 PU-S 20.05 56.46 FCNT MWD020 CNTS 112.65 .914.63 NCNT MWD020 CNTS 14156.7 37836.2 RHOB MWD020 G/CM 1.51 3.24 DRHO MWD020 G/CM -0.65 0.45 PEF MWD020 BARN 2.22 16.75 Mean Nsam 7813 5393 64.5558 5314 157.999 5304 4.02933 5311 3.86937 5311 19.6271 5311 10.0629 5311 1.12601 5240 37.3792 5210 292.709 5210 21831 5210 2.40618 5183 0.0936813 5183 4.28739 5241 First Reading 6465 6504.5 6465.5 6469 6469 6469 6469 6504.5 6465 6465 6465 6494 6494 6465 Last Reading 9161 9161 9117 9124 9124 9124 9124 9124 9069.5 9069.5 9069.5 9085 9085 9085 First Reading For Entire File .......... 6465 Last Reading For Entire File ........... 9161 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/11/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/11/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
