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186-176
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-13 KUPARUK RIV UNIT 3Q-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-13 50-029-21664-00-00 186-176-0 W SPT 6114 1861760 1528 2847 2848 2847 2848 130 130 130 130 4YRTST P Josh Hunt 8/28/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-13 Inspection Date: Tubing OA Packer Depth 220 1800 1730 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240828162740 BBL Pumped:1.7 BBL Returned:1.5 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 99 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 14:21:39 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Tuesday, August 18, 2020 P.I. Supervisor -ZE �f (� ` Nzoz` SUBJECT: Mechanical Integrity Tests l ConocoPhillips Alaska, Inc. 3Q-13 FROM: Brian Bixby KUPARUK RIV UNIT 3Q-13 Petroleum Inspector Src: Inspector Reviewed By: P. 1. Suprv1:1 7p - NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-13 API Well Number 50-029-21664-00-00 Inspector Name: Brian Bixby Permit Number: 186-176-0 Inspection Date: 8/15/2020 Insp Num: mitBDB200816080535 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-13iType Ips W 'TVD 6114 Tubing 1967 1967 " 1967 1967 ' PTD 1861760 Type Test ''i SPT Test psi 1528 IA 980 2790 - 2710- 2690 BBL 1.7 BBL Returned: 1.7 Pumped. Ret p - OA 320 330 330 330 Interval 4vRTST IPIF P Notes: Tuesday, August 18, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg �rDATE: Friday,September 16,2016 P.I.Supervisor l Z c IV j kt, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-13 FROM: Brian Bixby KUPARUK RIV UNIT 3Q-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-13 API Well Number 50-029-21664-00-00 Inspector Name: Brian Bixby Permit Number: 186-176-0 Inspection Date: 9/15/2016 Insp Num: mitBDB160915164128 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-13 • Type Inj W"TVD 6114 Tubing 1276 1280• 1280 • 1280 - PTD 1861760 Type Testi SPT!Test psi 1528 - IA 630 2010 - 1940 - 1935 Interval IN1TAL - P/F P '/ OA 400 450 - 450 - 450 - Notes: --------- Friday,September 16,2016 Page 1 of 1 STATE OF ALASKA • ALGA OIL AND GAS CONSERVATION CO4SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other StimulateAlter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: C_onocoPhillips Alaska, Inc. Development 1,7 Exploratory r 186-1760 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service '" 50-029-21664-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL25512 KRU 3Q-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8190 feet Plugs(measured) None true vertical 6583 feet Junk(measured) None Effective Depth measured 7951 feet Packer(measured) 7566, 7569 true vertical 6403 feet (true vertical) 6114, 6117 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 115' 115' SURFACE 4288' 9 5/8 4325' 3714' PRODUCTION 8135' 7 8169' 6567' RECEIVED Perforation depth: Measured depth: 7743-7755, 7760-7784, 7790-7828 SEP 1 3 2016 True Vertical Depth: 6247-6256,6260-6278,6282-6311 G CC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7681 MD,6200 TVD Packers&SSSV(type,MD,and TVD) LOCKED OUT=BAKER'FVL' -LOCKED OUT 3/11/2000 @ 1790 MD and 1773 TVD PACKER=BAKER 7"26#F-1 PACKER @ 7566 MD and 6114 TVD PBR = BAKER 80/40 PBR @ 7569 MD and 6117 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): ��Yyt��uy p� r Treatment descriptions including volumes used and final pressure: SCANNE i MA 6 4 2l1{ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 156 1221 694 1050 185 Subsequent to operation 0 0 4514 550 1096 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development r Service P7 Stratigraphic r Copies of Logs and Surveys Run " 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG 17 GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-419 Contact Darrell Humphrey/Bob Christensen Email: n1139(c�conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature 1 Phone:659-7535 Date t o )A\ Q t - 1 v iv/ //G ' /0AM Form 10-404 Revised 5/2015 RBDMS (-L_- SEP 1 3 2016 Submit Original Only • 3Q-13 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/03/16 Well converted to injection service and brought online , ofi KUP PROD 3Q-13 • ConocoPhillips 1 Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) -,..,,,,,,,,,,,,71,1! 500292166400 KUPARUK RIVER UNIT PROD 44.68 3,100.00 8,190.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 30-13,8/1720166:1306 PM SSSV:NONE Last WO: 42.51 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,954.0 12/13/2015 Rev Reason:GLV C/O pproven 8/17/2016 HANGER;34 0 Ij,11 I Casing Strings • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 Welded Casing Description OD(in) ID On) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.765 37.0 4,325.3 3,713.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread Pr;! r aA"PRODUCTION 7 6.276 34.0 8,168.8 6,567.2 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(MB) Set Depth(ft..Set Depth(TVD)I...Wt(Iblft) (Grade (Top Connection TUBING-UPPER 31/2 2.992 34.0 7,585.0 6,128.7 9.30 L-80 EUE 813 WO 2015 CONDUCTOR;38.D-115.0-i Completion Details Nominal ID Top(ORB) Top(ND)(ftKB) Top Incl(") Item Des Corn (in) 34.0 34.0 0.19 HANGER CtW tubing hanger 3.500 GAS LIFT;2,690.8 I. 7,563.2 6,112.5 41.81 LOCATOR Baker GBH-22 locator sub 3.000 7,564.0 6,113.1 41.81 SEAL ASSY Baker GBH-22 Seal assembly W/7 f out 3.000 • Tubing Description String Ma...ID(in) Top(9KB) Set Depth(ft...Set Depth(TVD)(...•Wt(Iblft) Grade Top Connection TUBING-LOWER- 31/2 2.992 7,565.8 7,770.0 6,267.3 9.30 L-80 EUE 8rd WO 2015 OSTV Tubing Shut Off;3509.3 KT.', Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 7,565.8 6,114.4 41.80 PACKER Baker 7"26#F-1 Packer 4.600 7,569.1 6,116.8 41.77 PBR Baker 80/40 PBR 3.990 7,606.1 6,144.5 41.54 NIPPLE 3.5 X 2.813 X nipple 2.813 2.992 7,680.5 6,200.3 41.45 XO Enlarging 3.5"8rd X 5.5"H-40 Ported sub 7,681.2 6,200.7 41.45 Liner 5.5"X 14#H-40 Wear sox with 5 15/16"wear rings 5.000 SURFACE;37.0-4,325.3 • 7,725.6 6,234.0 41.43 Liner 5.5"X 14#H-40 Wear sox with 5 15/16"wear dogs Mule 5.000 GAS LIFT;4,323.6 shoe Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top)kKB) (kKB) (°) Des Com Run Date ID(in) E 7,745.0 6,248.6 41.43 WHIPSTOCK BAKER GEN II WHIPSTOCK 2 5/8"X 5.5" 12/30/3015 GAS LIFT; ,551.5 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shctelt Top(ftKB) Btm(ftKB) (ftKB) _ (ftKB) Zone Date t) Type Com 7,743.0 7,755.0 6,247.1 6,256.1 A-3,3Q-13 8/4/2000 4.0 APERF '21/8"Enerjet;180 deg GAS LIFT;6,401 9 phasing;'1/-90 legs f/low side. 7,760.0 7,784.0 6,259.8' 6,277.8 A-2,3Q-13 '3/26/2000 4.0 RPERF '2 1/8"EJ III DP;+/-90 deg orient 7,790.0 7,828.0 6,282.3' 6,310.8 A-1,3Q-13 3/26/2000 4.0 RPERF 2 1/8"EJ III DP;+/-90 deg orient GAS LIFT;7,062.6 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(9KB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn GAS LIFT;7,502.4 1 2,690.8 2,508.0 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/9/2016 2 4,323.7 3,712.4 Camco MMG 1 1/2 GAS LIFT 'DMY RK 0.000 0.0 8/8/2016 3 5,551.5 4,617.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/8/2016 4 6,401.9 5,252.2 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 5 7,062.6 5,741.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 LOCATOR;7,56321.1 II 6 7,502.4 6,067.3 Cance MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/12/2016 PACKER;7.5657 I Notes:General&Safety SEAL ASSY;7.564.0End Date Annotation PBR;7,569.1 ;1 0 2/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 11/22/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. 11/22/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close NIPPLE;7,606.1 411 XO Enlarging;7.680.5 lit-ib: Liner;7981.2 Liner;7,725.6 APERF;7,743.0-7,755.01..... SLOTS;7,743.0-10,546.04-•_ L1-02 SLOTTED LINER;7,742.2 - I -10,552.0 -4 4- RPERF;7,760.0-7,784.0--4 a" RPERF;7,790.0-7,828.0I - 1 PRODUCTION;34.0.8,168.8 1 L • • OF T � • AO' I//7y.s THE STATE Alaska Oil and Gas OALASKA Conservation Commission 333 West Seventh Avenue c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O \"� Main: 907.279.1433 -4Fax: 907.276.7542 www.aogcc.alaska.gov Darrell Humphrey ��® u ` (j1 NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-13 Permit to Drill Number: 186-176 Sundry Number: 316-419 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, 9k.-1,154, Cathy . Foerster Ay Chair DATED this of August, 2016. RBDMS AUG 1 6 2016 r 4 • RECEIVED ' • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 2016 F7/‘//Ce APPLICATION FOR SUNDRY APPROVALS �/q{, �^+�°� 4 20 AAC 25.280 AOGi,► 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate E Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing Other: PROD to WAG F.7 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 186-1760 3.Address: 6.API Number: Stratigraphic r Service .. P. O. Box 100360,Anchorage,Alaska 99510 50-029-21664-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No j' KRU 3Q-13 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25512 ' 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): 8190 ` 6583 ' 7951'' 6403' . 3000 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 115' 115' SURFACE 4288' 9 5/8 4325' 3714' PRODUCTION 8135' 7 8169' 6567' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7743-7755,7760-7784,7790-7828 ' 6247-6256,6260-6278,6282-6311 3 1/2 L-80 7681 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) LOCKED OUT=BAKER'FVL' -LOCKED OUT 3/11/2000 MD=1790 TVD=1773 PACKER=BAKER 7"26#F-1 PACKER ` MD=7566 TVD=6114 PBR =BAKER 80/40 PBR ' MD=7569 TVD=6117 12.Attachments: Proposal Summary g WellBore Schematic 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service h/'. 14.Estimated Date for 15. Well Status after proposed work: 09/10/16f-. Commencing Operations: OIL ' VVINJ WpgpL Suspended 16.Verbal Approval: Date: GAS r WAG lw . GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Phone:659-7535 Email: n1139@conocoohillios.com Title: NSK Production Engineering Specialist Signature l l Date: �. ,v- /c iii// Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Rug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: N 'leilL !tL Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No Subsequent Form Required: /G i 0 APPROVED BY Approved by: , COMMISSIONERS/ THE COMMISSION Date: 8_4_4, VT L B//5 f/ eitkiic- ,e'8if/�6 O RtGi A Li.— Suborn Form and Form 10-403 Revised 11/2015 p � alid for 12 months from the date of approval. ttachments in Duplicate RBDMS �_AUG 1 6 2016 • 3Q-13 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3Q-13 and its associated laterals L1, L1- 01, L1-02 (PTD# 186-176, 215-221, 215-223, 215-224) from Oil Production service to Water Alternating Gas Injection service as the production period for this well has been completed. Area of Review: Kuparuk well 3Q-13 and it's associated laterals was completed as an injector on 7/25/16 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 3Q-07, 3Q-09 and 3Q-11. The top of the C sand was found at 7729' and/6237'tvd The top of the A sand was found at 7739' and /6244' tvd Area Map with 1/4 mile radius around target injection zone(see attached): The map attached shows that with the exception of the offset producers 3Q-07 and 3M-13, there are no additional production/injection wells are located within a 1/4 mile radius of the 3Q-13, 3Q-13L1, 3Q-13L1-01, 3Q-13L1-02 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3Q-13 and it associated laterals is good and is classified as a"CTD horizontal tri-lateral"well. The injection tubing/casing annulus is isolated via a Baker 7" 26# F-1 packer located at 7565' and (6114' tvd). A State-witnessed MIT-IA will be performed once well 3Q-13 and it's associated laterals are converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (6450' -8169' and/5287' -6567' tvd) to insure injection zone conformance. The CBL interpretation was completed on the PTD's. The 16" Conductor was cemented with 1875# Polyset. The 9-5/8" Surface casing was cemented with 1200sx ASIII and 300sx Class G. The 7" Intermediate casing was cemented with 300sx Class G and 175sx AS1. ✓w+ , - L cd a5- rAr 4-62 — Pc • —R4• J— till./A° a O a O 0 8 L F `oF c o a ry A a� \\ O ry i e I iti i ti I- 1 a N 2, a N E a a a E 'n Ooa oL ab u 'W V' L9 l7 n O V U V N ii n E 8 G aM tYl n N 6 W 4 m E m a C a Y .. E E all O o „ o oL c oS b o73- •+ p 00 oN or wm f p ^� m o c m e oo 2 rO '' u0 m m F ti u u ' o_ ww o `o `o_ C.) N °• c w _ N o o ' O ' o E w w a s 2,_, s � o 0 co rc c Z a . c m - a) Ec 23 J — o E u m m — �o3 a) I J J si Z.1 O h N 0 0 ui n— 0 f0 � a) L t' a E - 0 0 0 E o m m o— 0 0 O a'^ Q N .b b b '2s aE 0 o d n w 34 m n- r O m H _ N 0 0 Q m o .Mi ry 3 m• m m m o d, m N 0 0 °1 N o ' c 0 c:T7,' a ~ aiOo m • • - a os� z o=a F \ a E a a a E as a co oa• - - — yi m m m 1. N oc O c 'a c C'1� To al O O Of O N O O O f2 f2 P. E: U U 0. • or - t; M w o - a o CO d a z E-5 'I Q) u•c o f u u u .\�' a) �1 •. > 5 a' o Es ��a)) € \. V G -6 o � i E Q u o `o 0 o^. 8b., 8 A" e e e a Za `o n N H .o I'c N f _ o y n ao m r O L7 o O Lu 2 m Z d m m 3 `¢ d d b$ I?: $ d ro Y 29Jul16 ConocoPhillips Alaska, Inc. Injection Swap Analysis N 3Q-13 et al 0 0.08 0.16 0.24 0.32 Miles 3Q 0 17 -1: T : •E ADL025512 3Q-13 / 3Q-13L1 PBI ADL0255'3 3Q-07 0111/ 3Q-13L1 3Q-13L1-01 3Q-13L1-02 3M-13 3Q-22 3Q-13 Open Interval 1/4 Mi. Radius 3Q-13 3Q-13L1 Open Interval 1/4 Mi. Radius 3Q-13L1 3Q-13L1PB1 Open Interval ❑ 1/4 Mi. Radius 3Q-13L1PB1 ADL025520 -�° 3Q-13L1-01 Open Interval 0 1/4 Mi. Radius 3Q-13L1-01 -025521 3Q-13L1-02 Open Interval 0 1/4 Mi. Radius 3Q-13L1-02 Well Within Radius * Well PadR6uk-,9 � ' � • 110.7' 09Aug16 • ConocoPhillips Alaska, Inc. Injection Swap Analysis N 3Q-13 et al 0 0.08 0.16 0.2, 0.32 Miles 3Q 0 17 18 T 7DL0255\ ih %g * 3Q-13 / r ,, � 3Q-13L1 PB1 ADL0255'3 3Q-07 il / i 19 3Q-13L1 3Q-13L1-01 3Q-13L1-02 3M-1'3 —3Q-13 Open Interval 0 1/4 Mi. Radius 3Q-13 3Q-13L1 Open Interval 1/4 Mi. Radius 3Q-13L1 —3Q-13L1 PB1 Open Interval ❑ 1/4 Mi. Radius 3Q-13L1PB1 ADL025520 —3Q-13L1-01 Open Interval 0 1/4 Mi. Radius 3Q-13L1-01 .025521 r .y; —3Q-13L1-02 Open Interval 0 1/4 Mi. Radius 3Q-13L1-02 —Well Within Radius *Well Pad Ai 0 KUP PROD • 3Q-13 ConocoPhillips r Well Attributes Max Angle&MD TD + Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cmocom,tmrc 500292166400 KUPARUK RIVER UNIT PROD 44.68 3,100.00 8,190.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-13,2/420169:27:12 AM SSSV:NONE Last WO: 42.51 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date i Last Tag:SLM 7,954.0 12/13/2015 Rev Reason:ADD LATERALS;GLV C/O lehallf 2/4/2016 HANGER;34.0 �c)�R.-: Ik Casing Strings " Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062. 38.0 115.0 115.0 62.50 H-40 Welded Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,. SURFACE 9 5/8 8.765 37.0 4,325.3 3,713.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ,' ' a u+.PRODUCTION 7 6.276 34.0 8,168.8 6,567.2 26.00 J-55 BTC PIPPIPTubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..f Set Depth(T)./D)(...Wt(lb/ft) Grade Top Connection TUBING-UPPER 31/2 2.992 34.0 7,585.0 6,128.7 9.30 L-80 EUE 8rd WO 2015 CONDUCTOR;38.0-115.0 Completion Details Nominal ID Top)ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (In) 34.0 34.0 0.19 HANGER C(W tubing hanger 3.500 GAS LIFT;2,6908 - 7,563.2 6,112.5 41.81 LOCATOR Baker GBH-22 locator sub 3.000 I 7,564.0 6,113.1 41.81 SEAL ASSY 'Baker GBH-22 Seal assembly W/711 out 3.000 Tubing Description String Ma...ID(in) Top)ftKB) Set Depth(N..Set Depth)TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-LOWER- 31/2 2.992 7,565.8 7,770.0 6,267.3 9.30 L-80 EUE 8rd WO 20)5 OSN Tubing Shut Off,3,509.3P; Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°I Item Des Corn (in) 7,565.8 6,114.4 41.80 PACKER Baker 7"26#F-1 Packer 4.600 7,569.1 6,116.8 41.77 PBR Baker80/40 PBR 3.990 7,606.1 6,144.5 41.54 NIPPLE 3.5 X 2.813 X nipple 2.813 III 7,680.5 6,200.3 41.45 XO Enlarging 3.5"8rd X 5.5"H-40 Ported sub 2.992 7,681.2 6,200.7 41.45 Liner 5.5"X 14#H-40 Wear sox with 5 15/16"wear rings 5 000 SURFACE;37.0-4,325.3 .4 7,725.6 6,234.0 41.43 Liner 5.5"X 14#H-40 Wear sox with 5 15/16"wear rings Mule 5.000 GAS LIFT;4,323.6 shoe 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) 1 I Des Corn Run Date ID(in) 7,745.0 6,248.6 41.43 WHIPSTOCK BAKER GEN II WHIPSTOCK 2 5/8"X 5.5" 12/30/3015 GAS LIFT;5,551.5 <-i Perforations&Slots Shot Den Top(TVD) Btm)TVD) (shots/f Top(ftKB) BM,(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,743.0 7,755.0 6,247.1 6,256.1 A-3,3Q-13 8/4/2000 4.0 APERF 21/8"Enerjet;180 deg GAS LIFT;6,401.9 phasing;+/-90 degs f/low side. 7,760.0 7,784.0 6,259.8 6,277.8 A-2,3Q-13 3/26/2000 4.0 RPERF 2 1/8"EJ III DP;+1-90 deg orient 7,790.0 7,828.0 6,282.3 6,310.8 A-1,30-13 3/26/2000 4.0 RPERF 2 1/8"EJ III DP;+/-90 GAS LIFT;7,062.61 deg orient Mandrel Inserts St aft on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GAS LIFT;7,502.4 .1 1 2,690.8 2,508.0 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,249.0 1/28/2016 2 4,323.7 3,712.4 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,247.0 1/28/2016 _. 3 5,551.5 4,617.7'Camco MMG 1 1/2 GAS LIFT 'OV RK 0.250 0.0 1/28/2016 ' 4 6,401.9 5,252.2 Camco MMG 1 1/2 GAS LIFT 'DMY RK 0.000 0.0 11/22/2015 5 7,062.6 5,741.3 Camco MMG 1 1/2'GAS LIFT 'DMY RK 0.000 0.0 11/22/2015 LOCATOR;7,563.2 mg 'Di 6 7,502.4 6,067.3 Camco MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 12/10/2015 Wii- PACKER;7,565.7 SEAL ASSY;7,564.0 4 . Notes:General&Safety PBR;7,569.1 _a II End Date Annotation 2/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 11/22/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. 11/22/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close NIPPLE,0606.1 - I 00 Enlarging;7,680.5 Liner;7,681.2 Liner;7,725.6 i. APERF;7,743.0.7,755.0 l SLOTS;7,743.0-10,546.0 -. I L1-02 SLOTTED LINER;7,742.2 -10,552.0 RPERF;7,760.0-7,784.0 -4 RPERF;7,790.0-7.828.0 [ I PRODUCTION;34.0-8.168.8 • Bettis, Patricia K (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, August 12, 2016 10:24 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3Q-13 (PTD 186-176): Sundry Application Attachments: 3Q-13 AOR Spreadsheet revised 8-11-16.xlsx; 3Q-13_AOR Map_ revised 08-11-16.pdf Patricia- here are the revisions to the AOR Map and the AOR detail page that include 3Q-22. Thanks Darrell Humphrey/ Bob Christensen Production Engineering Specialist Conocophillips Alaska Inc. n1139@conocophillips.com Office (907) 659-7535 Pager(907) 659-7000#924 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday, August 11, 2016 11:31 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]KRU 3Q-13 (PTD 186-176): Sundry Application Good morning Darrell, For the one-quarter mile area review, ConocoPhillips lists 30-13 mother bore and laterals, 30-07 and 3M-13. A review of AOGCC data shows 3Q-22 well within that quarter mile area. Please provide an updated map and well data (TOC, zonal isolation, mechanical integrity that includes KRU 3Q-22. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 0 r II • r4 C J r V co 47 N v C13 co _c IL(9 W ° Q Q. ., VI o p N a1 v O O NZ O F L C tin O w -1 Z 1- r F > CO IP 1111 a-- v a E , ¢9Y o ` o - =a w a 2 °- a°, _ ° o ° F-. ", 0 Q a a u + C -a v 0 - w co •in in co o G E L m J a C7 r '- + v, +, v, a .. O n a°i CD t oC c F 2 w Ts 0_ Q1 ,12 z Q N M M c @ v Q v Z K .'p C1 0 E ° _T 5 ~ CO a) s -0 = f.. a) Y CO (13D O 0 0 f0 G u "C CS W J J J y www m ° o Q Q Q C DO G, a Z Z Z W @ '° `^ ,� G LL ti LL (1) L f1 L1 CC y > CI) O o > Y +-' a E 4) Y C W a1 Q) O .° Urr C Z vE, o_ a) y -0 Cl.)C v +-, .� 0 -i a 1- > > c U U N. 4 0 C Ow N a 0. O to U - , w ca t° . w li °: o p (') ›c' p 0 N AA W^ co ,� ,_ (� *tet at Ga 0 r,r7-1 -5 z r-, x § , w O os . V d ° J J \ "7 to N i i W di---ii.."2--,1119 0 w n• . E ar a > 7 > E "+ d' 2 c 3 0w N Y Y zr CO CO �� CU t - u w IAo 11 V Y Y OD ro 4-, a C x 'v, a LLI ^J w M V in 0 > 0 N N r- V �7 o p O O f0 tV o O O O N n ��, D O c to O O c N O O O CO t0 111 .N O N. c, CN .- v N N N N N ° Si O O v N O O O ;' L1 in u) u) M 3 y Cont CO~ C a Ou C gm SE u ro V Y N , w C C Q g Q In r u7 io a) > a 1 9 N L" r, , Z r c +�_., E v H pp C'1 Z ` a L d .< .0 N -- w U M M E Z a) , Y COD EI4 ?.. ifk co F- a a Q • • RECEIVED E STATE OF ALASKA MAR 0 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other StimulateAlter Casing pr Change Approved Program r Plug for Redrill r Perforate New Pool rRepair Well r Re-enter Susp Well r Other:WAG to Prod>30 days(� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-176 3.Address: 6.API Number: Stratigraphic r Service ji P. O. Box 100360,Anchorage,Alaska 99510 50-029-21664-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25512 KRU 3Q-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8190 feet Plugs(measured) 3946 true vertical 6583 feet Junk(measured) None Effective Depth measured 7951 feet Packer(measured) 7564, 7566, 7569 true vertical 6403 feet (true vertical) 6113, 6114, 6117 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115' SURFACE 4288 9.625 4325 PRODUCTION 8135 7.656 8169 6567' Perforation depth: Measured depth: 7743-7828 satiate1! -: True Vertical Depth: 6247-6310 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7681 MD,6200 TVD Packers&SSSV(type,MD,and TVD) LOCKED OUT-BAKER'FVL' -LOCKED OUT 3/11/2000 @ 1790 MD and 1773 TVD SEAL ASSY-BAKER GBH-22 SEAL ASSEMBLY W/7 FT OUT @ 7564 MD and 6113 TVD PACKER-BAKER 7"26#F-1 PACKER @ 7566 MD and 6114 TVD PBR -BAKER 80/40 PBR @ 7569 MD and 6117 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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 0 2346 2228 _ 1250 2320 Subsequent to operation 309 1151 1125 1050 260 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations jr Exploratory r Development jd Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email: n1139@conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature 1 Phone:659-7535 Date ,2 , z,,, t / Form 10-404 Revised 5`/2015 v7-L_ 41g,f//6 RBDMS uV MAR 0 1 2016 Submit Original Only 3/11 i/G • • 3Q-13 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/01/16 Open well to production, pre produce for greater than 30 days tg KUP PROD 0 3Q-13 ConocoPh1 ips Well Attributes Max Angle&MD TD Alaska,(f1C. Wellbore API/UWI Field Name Wellbore Status ncl(°I MD(ftKB) Act Btm(ftKB) cnnoconvupc'<,)- 500292166400 KUPARUK RIVER UNIT PROD 44.68 3,100.00 8,190.0 ••• Comment •H2S(ppm) Date Annotation End Data KB-Grd(ft) Rig Release Date 30-13,2/4/20169:2712 Ann SSSV:NONE Last WO: 42.51 12/10/1986 Vertical schematic(actual) - '"'-Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _,,,,._,,,_-,.,,,,_,-.•,.,,,._,,,,,,,,,,,,,,,,,,,,,,,,,,,_,-.,_„_ _ Last Tag:SLM 7,954.0 12/13/2015 Rev Reason:ADD LATERALS;GLV C/O lehallf 2/4/2016 HANGER;34.0 I ill Casing Strings Casing Description OD(in) ID(in) Top(51(13) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 Welded Casing Description OD(in) 'ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread _ _ SURFACE 95/8 8.765 37.0 4,325.3 3,713.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread '' -'' ' - '" -' "'. l PRODUCTION 7 6.276 34.0 8,168.8 6,567.2 26.00'J-55 BTC Tubing Strings Tubing Description String Me...ID(in) Top(ft6e) Set Depth(ft..Set Depth(T60)(...Wt(Ib/ft) Grade Top Connection TUBING-UPPER 31/2 2.992 34.0 7,585.0 6,128.7 9.30 L-80 EUE 8rd W02015 CONDUCTOR;38.0-115.0- , Completion Details Nominal ID Top OMB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) • 34.0 34.0 0.19 HANGER CIW tubing hanger 3.500 GAS LIFT;2,690.8 ( c 7,563.2 6,112.5 41.81 LOCATOR Baker GBH-22 locator sub ' 3.000 7,564.0 6,113.1 41.81 SEAL ASSY Baker GBH-22 Seal assembly W/7 f out ' 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING-LOWER- 31/2 2.992 7,565.8 7,770.0 6,267.3 9.30 L-80 EUE 8rd WO2015 OSTV Tubing Shut Off;3,509.3 /r; i Completion Details -'" Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,565.8 6,114.4 41.80 PACKER 'Baker 7"26#F-1 Packer 4.600 • 7,569.1 6,116.8 41.77 PBR Baker 80/40 PBR 3.990 7,606.1 6,144.5 41.54 NIPPLE '3.5 X 2.813 X nipple ' 2.813 I 7,680.5 6,200.3 41.45 XO Enlarging '3.5"8rd X 5.5"H-40 Ported sub 2.992 7,681.2 6,200.7 41.45 Liner 5.5"X 14#H-40 Wearsox with 5 15/16"wear rings 5.000 SURFACE;37.D-4,325. t- - 7,725.6 6,234.0 41.43 Liner 5.5"X14#H-40 Wearsox with 515/16"wear rings Mule 5.000 GAS LIFT;4,323.6 shoe Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,745.0 6,248.6 41.43 WHIPSTOCK BAKER GEN II WHIPSTOCK 2 5/8"X 5.5" 12/30/3015 GAS LIFT;5,551.5 Perforations&Slots Shot Dens Top(ND) Btrn(TVD) (shots/f Top(ftKB) Bhn(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,743.0 7,755.0 6,247.1 6,256.1 A-3,30-13 8/4/2000 4.0 APERF 2 1/8"Enerjet;180 deg GAS LIFT;6,401.5 phasing;+1-90 degs f/low side. 7,760.0 7,784.0 6,259.8 6,277.8 A-2,30-13 3/26/2000 ' 4.0 RPERF 21/8"EJ III DP;+/-90 deg orient 7,790.0 7,828.0 6,282.3 6,310.8 A-1,3Q-13 3/26/2000 4.0 RPERF 2 1/8"EJ 10 DP;+/-90 deg orient GAS LIFT;7,062.6 1 Mandrel Inserts St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB( Make Modal OD(in) Sery Type Type (In) (psi) Run Date Com GAS LIFT;7,502.4 1� 2,690.8 2,508.0 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,249.0 1/28/2016 2 4,323.7 3,712.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,247.0 1/28/2016 3 5,551.5 4,617.7 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 1/28/2016 4 6,401.9 5,252.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 5 7,062.6 5,741.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 LOCATOR;7,563.2 •IE. 6 7,502.4 6,067.3 Camco MMG 11/2 GAS LIFT DMY RKP 0.000 0.0 12/10/2015 PACKER;7,585.7 Notes:General&Safety SEAL ASSY;7,564.0` PBR;7,569.1 's End Date Annotation 2/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 11/22/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. 11/22/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close i . NIPPLE;7,606.1 • XO Enlarging;7,680.5 Liner;7,681.2 -a1 Liner;7,755.0 _ APERF;7,743.0-7,755.0 SLOTS;7,743.0-10,546.0 -/l L7-02 SLOTTED LINER;7,742.2 -I .._- -10,552.0 RPERF;7,760.0-7,784.0 r RPERF;7,790.0-7,828.0 I 1 PRODUCTION;34.0-8,168.8 L • • 1 II II 1ru 1 to O II 1 ow , Or N UO 11 I I 2°1 I.I cco CO n' iv 11 I I M L I r m ZNI UN II 1I i2� i �_ Q CO o II II o 3 1i 't..6 _ I.- ,1� 11 II u c i n ' ,n ' 1 ID N oN II 11 In �Il 0 y � ' co r 11 I -o 2 1I c U o II 1 M y M i Qp p c7i _ d m F' c 11 I1 deo �I ;t_o II NQ goy II11MCV 11 � � m• V to o r:"6 11 11 II MU'No o - m n t - 1 ,I m /r `n N. d N 11 It 11 N M N O -. I1 11 ,I 111 47-Z)• co O c ao tt 0 II a > O. E 11 I1. 1i.. 2 c >n ty N p 11 0il ro co c.c °o m 11 \\ / N C \\ / Q 5 O CD O7 I l � VI / a co 0 0 y I\\ 1/ co coW o1 aa)Z.- b 8 \\ II D 2 CV "O C_ N 0 Q N \\ II w 2 0 E P z co a \\ II o CO CO _ \\ M #• E C Y°Jcsi � N n F \\ m CI Ca c 2 II ai U c`to M ai CO© c X m c II ° o (V N (V Z N Y (V N c ° II 0.- • . to �- r O0 ,- .,-- -i9 M M tc) M M d M in Q To • y 11 -' 11 • c €7 -T-1 O 1,- H I I _L :c..1.41:13, II G7 3 rI o „" / 0 A p>a II ce, //�� O O ) // \V X00 // 3.= hU> /i V/ i4ii \/-11—D//a w 0 ..-------i i n 1 rJ m V ..............-•----} - V/ ti 11 11 1111!!!! Ir, CI M o 4� O m M O _� � .� yo M� Ips a� w© ,n o p -or 4 a O,N H N t/f ID (OL �� Nr oipxl x- on rN Qr 1,.@ I,-LI iC6 C9 G • • 24,151 WELL LOG TRANSMITTAL#903005738 To: Alaska Oil and Gas Conservation Comm. January 22, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100IVED DATA LOGGED Anchorage, Alaska 99501 ZKiBENDER JAN' 26 AOGCC RE: Static Bottom Hole Pressure Record/Jewelry Log: 3Q-13 Run Date: 12/20/2015 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 3Q-13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21664-00 r Static Bottom Hole Pressure Record } !'U 1 Color Log 50-029-21664-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ii?Asig,-#.,4%) ,.E;,ya�Pl� • STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate Pull Tubing F Operations Shutdown Performed: Suspend E Perforate r Other Stimulate E Alter Casing E Change Approved Program E Plug for Redrill r Perforate New Pool E Repair Well r Re-enter Susp Well r Other: CTD Setup F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory r 186-176 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21664-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25512 KRU 3Q-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8190 feet Plugs(measured) None true vertical 6583 feet Junk(measured) None Effective Depth measured 7951 feet Packer(measured) 7566 true vertical 6403 feet (true vertical) 6114 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 4288 9 5/8 4325 3713 PRODUCTION 8134 7 8168 6567 ' 'kt 2;:',U1'; Perforation depth: Measured depth: 7743-7828 1 00 E ,. . RECEIVED 3 True Vertical Depth: 6247-6310 DEC 1 $ 2 015 Tubing(size,grade,MD,and ND) 3.5, L-80, 7681 MD,6200 ND AOGCC Packers&SSSV(type,MD,and TVD) PACKER-Baker, F-1@7566 MD,6114 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none 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 shut-in Subsequent to operation waiting fac hookup 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r', Development r Service F Stratigraphic E Copies of Logs and Surveys Run r 16.Well Status after work: Oil E Gas r WDSPL E Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ F WAG E GINJ E SUSP E SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-471 Contact Theresa Lee@263-4837 Email Theresa.M.Lee(a�conocophillips.com Printed Name Theresa Lee 1 Title Workover Engineer Signature /,,,///�f� <SJ nn_ Phone:263-4837 Date 1 �7 / 1 ) 'e J'" VTL 1 RBDMS DEC 212015 Form 10-404 Revised 5/2015 i j6, /14 V� Submit Original Only 0*--/- 3 KUP 4 3Q-13 . ConocoPhillips I Well Attribu Max Angl TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl 0) MD(ftK Act Btm(ftKB) C01osopha1w _ 500292166400 KUPARUK RIVER UNIT INJ 44.68 3,100.00 8,190.0 ... Comment H2S(ppm) Date Annotation End DateKB-Grd(ft) -Rig Release Date 35-13.12/17/20153'.27:59 PM SSSV:NONE Last WO: I 42.51 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,954.0 12/13/2015 Rev Reason:WORKOVER,PULLED PLUG, lehallf 12/17/2015 HANGER,34.0 1?,,i,'it GLV C/O Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 I-I-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.765 37.0 4,325.3 3,713.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ISM PRODUCTION 7 6.276 34.0 8,168.8 6,567.2 26.00 J-55 BTC IMPIIIP ^Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-UPPER 31/2 2.992 34.0 7,585.0 6,128.71 9.301 L-80 EUE 8rd WO 2015 e ;` Completion Details CONDUCTOR;SS 0-115 Is Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 34.0 34.0 0.19 HANGER CIW tubing hanger 3.500 GAS LIFT;2.690.8 g 7,563.2 6,112.5 41.81 LOCATOR Baker GBH-22 locator sub 3.000 7,564.0 6,113.1 41.81 SEAL ASSY Baker GBH-22 Seal assembly W/7 ft out 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TURING LOWER- 31/2 2.992 7,565.8 7,770.0 6,267.3 9.30 L-80 EUE 8rd WO N Tubing Shut Off,3,509.3 Completion Details OS TV Nominal ID Top(ftKB) Top(TVD)(ftKB) Top lode) Item Des Com (in) 7,565.8 6,114.4 41.80 PACKER Baker 7"268 F-1 Packer 4.600 7,569.1 6,116.8 41.77 PBR Baker 80/40 PBR 3.990 7,606.1 6,144.5 41.54 NIPPLE 3.5 X 2.813 X nipple 2.813 7,680.5 6,200.3 41.45 XO Enlarging 3.5"8rd X 5.5"H-40 Ported sub 2.992 7,681.2 6,200.7 41.45 Liner 5.5"X 14 N H-40 Wear sox with 5 15/16"wear rings 5.000 7,725.6 6,234.0 41.43 Liner 5.5"X 14 8 H-40 Wear sox with 5 15/16"wear rings Mule 5.000 SURFACE,37.0-4.3253 GAS LIFT;4.323.6 {:I. shoe Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com GAS LIFT;5,551.5 7,743.0 7,755.0 6,247.1 6,256.1 A-3,3Q-13 8/4/2000 4.0 APERF 2 1/8"Enerjet;180 deg phasing;+/-90 degs f/low side. 7,760.0 7,784.0 6,259.8 6,277.8 A-2,3Q-13 3/26/2000 4.0 RPERF 21/8"EJ III DP;+/-90 deg orient 7,790.0 7,828.0 6,282.3 6,310.8 A-1,3Q-13 3/26/2000 4.0 RPERF 21/8"EJ III DP;+/-90 GAS LIFT;6,401.9 deg orient Mandrel Inserts St ati N Top(ND) , Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn GAS LIFT,7062s 1 2,690.8 2,508.0 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 2 4,323.7 3,712.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 3 5,551.5 4,617.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 GAS LIFT 7,5024 4 6,401.9 5,252.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/22/2015 5 7,062.6 5,741.3 Camco MMG 1 1/2 GAS LIFT DMY RK ' 0.000 0.0 11/22/2015 6 7,502.4 6,067.3 Camco MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 12/10/2015 LOCATOR,7,563.2 Notes:General&Safety End Date Annotation 2/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PACKER;7,565.7 SEAL A551;7,564.0` i a' 11/22/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close P80,7'569.1 .. 11/22/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. NIPPLE,7,608.1 X0 Enlarging;7,680.5 l-A Liner,7,681.2 Liner;7,256 APERF;7,743.0-7,7755.0 RPERF;7,760.0-7,784.0--: RPERF;7,790.0-7,828.0---. I PRODUCTION,34.08,168. All l Operations Summary (with Timelog Depths) 3Q-13 Phiflips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ttKB)` 11/15/2015 11/15/2015 9.50 MIRU MOVE RURD P De-Mob equipment from 30-20 to 3Q 09:00 18:30 pad. 11/15/2015 11/16/2015 5.50 MIRU MOVE MOB P Move rig from 30 to 3Q.Continue 18:30 00:00 spotting equipment on 3Q.Prepare to spot rig over well. 11/16/2015 11/16/2015 7.50 MIRU MOVE MOB P Continue to MOB equipment on pad 00:00 07:30 and rig up.Rig accepted @ 07:30 HRs. 11/16/2015 11/16/2015 3.50 MIRU WELCTL RURD P Take on Mud. Install secondary valves 07:30 11:00 on well.hook up lines to well.. 11/16/2015 11/16/2015 1.00 MIRU WELCTL OTHR T Called out valve shop to service IA 11:00 12:00 valve as it was leaking. Made up secondary IA valve. 11/16/2015 11/16/2015 2.00 MIRU WELCTL MPSP P PJSM pick up and install lubricator.PT 12:00 14:00 to 2000 psi. Pul BPV.Tbg Pressure= 1250. IA pressure=1450 Laid down lubricator. 11/16/2015 11/16/2015 6.00 MIRU WELCTL KLWL P PJSM.Rig up lines to kill well. 14:00 20:00 Pressure test lines to 3,800 psi.Bled IA from 1,500 psi to 700 psi.Shut in and built back to 1,450 psi.Bled tubing from 1,050 psi to 500 psi.Shut in and built back to 1,000 psi. Circulate 1.5 time hole volume conventional with 12.3#mud at 1 BPM. ICP= 1300 psi.Blow down lines to tiger tank.Begin second circulation at 2.5 BPM. ICP=770 psi.Pumped 436 bbls total. 11/16/2015 11/16/2015 0.50 MIRU WELCTL OWFF P Flow check well for 30 mins.Well 20:00 20:30 static. 11/16/2015 11/16/2015 0.50 MIRU WHDBOP MPSP P Set BPV. 20:30 21:00 11/16/2015 11/16/2015 2.50 MIRU WHDBOP NUND P Nipple down and remove tree. 21:00 23:30 Inspected tubing hanger threads. Install BOP test dart. 11/16/2015 11/17/2015 0.50 MIRU WHDBOP NUND P Nipple up DSA. 23:30 00:00 11/17/2015 11/17/2015 2.50 MIRU WHDBOP NUND P Nipple up BOPE. Install bag close line. 00:00 02:30 Install riser. 11/17/2015 11/17/2015 1.50 MIRU WHDBOP RURD P Prepare cellar and wellhead for BOP 02:30 04:00 test.Rig up test joints. Flush mud lines.Make up test equipment. 11/17/2015 11/17/2015 8.50 MIRU WHDBOP BOPE P Test BOPE.To 250/3800 PSI.W/2 04:00 12:30 7/8&3.5 Test jts.Tested Waived By Chuck Scheve AOGCC. 11/17/2015 11/17/2015 1.00 MIRU WHDBOP RURD P Rig down test equipment. Suck out 12:30 13:30 Stack. Blow down lines. 11/17/2015 11/17/2015 0.50 MIRU WHDBOP MPSP P Pulled the Dart and HP BPV. Lay 13:30 14:00 down same. 11/17/2015 11/17/2015 1.50 COMPZN RPCOMP RURD P (SIMOPS monitor well static)...Rig up 14:00 15:30 Weatherford tubing equipment. Make -up the 3 1/2"landing pup joint assembly. Screw in Top Drive. BOLDS. 11/17/2015 11/17/2015 0.25 COMPZN RPCOMP PULL P Pull Tubing Hanger off seat at 60K. 15:30 15:45 Pull Tubing Hanger to the floor at 70K with no problems. Page 1/5 Report Printed: 12/18/2015 • • Operations Summary (with Timelog Depths) 3Q-13 `think Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity CodeTime P-T-X Operation (ftK8) End Depth(ttKB) 11/17/2015 11/17/2015 1.00 COMPZN RPCOMP CIRC P Circulate Well with 12.3 lb/gal WBM at 15:45 16:45 5.0 bpm/1,220 psi. SIMOPS rig up Schlumberger Spooling Unit. 11/17/2015 11/17/2015 0.25 COMPZN RPCOMP SFTY P PJSM. Discuss the hazards 16:45 17:00 associated to pulling and laying down the Completion. 11/17/2015 11/17/2015 1.00 COMPZN RPCOMP CIRC P Mixed and pumped 8 BBL's of 13.8# 7,621.0 7,621.0 17:00 18:00 Dry job. 11/17/2015 11/18/2015 6.00 COMPZN RPCOMP PULL P Single down the 2 7/8"Completion to 7,612.0 4,125.0 18:00 00:00 the SSSV while spooling Control Line. 31 SS Bands recovered.Continue to lay down completion 11/18/2015 11/18/2015 6.00 COMPZN RPCOMP PULL P Continue to lay down old completion. 4,125.0 0.0 00:00 06:00 Recovered 237 Jts 2 7/8"Tubing, SSSV,6 ea GLMs, 1 ea OEJ. Also recovered 31 SS Bands as expected. 11/18/2015 11/18/2015 2.50 COMPZN RPCOMP RURD P Clear and clean floor. Rig up rig 0.0 0.0 06:00 08:30 tongs. Install wear bushing. Change elevators. 11/18/2015 11/18/2015 2.00 COMPZN RPCOMP BHAH P Make-up BHA#1 as follows: Guide, 0.0 317.0 08:30 10:30 Overshot Bowl,2 ea Extensions,Top Sub,Bumper Sub,Oil Jar,9 ea 4 3/4" Drill Collars. 11/18/2015 11/18/2015 9.50 COMPZN RPCOMP PULD P Single in BHA#1 on 3 1/2"HT-38 Drill 317.0 7,571.0 10:30 20:00 Pipe from the Pipe Shed. 11/18/2015 11/18/2015 1.00 COMPZN RPCOMP CIRC P Circulated BU @ 4 BPM @ 1270 psi. 7,571.0 7,571.0 20:00 21:00 to condition mud. 11/18/2015 11/18/2015 0.25 COMPZN RPCOMP FISH P Slowed circulation down to 2BPM 7,571.0 7,603.0 21:00 21:15 engaged top of 7596 ft.RKB.Let jars bleed off.pulled up to 230K 75 over packer released.pulled up 10 ft and back down 15 packer free. 11/18/2015 11/18/2015 1.50 COMPZN RPCOMP CIRC P Circulated 1.5 times hole volume @ 7,651.0 7,651.0 21:15 22:45 4BPM @ 1254 PSI.saw minimal gas returns to surface. 11/18/2015 11/18/2015 0.25 COMPZN RPCOMP OWFF P Monitor well for flow 15 min's 7,651.0 7,651.0 22:45 23:00 11/18/2015 11/18/2015 0.25 COMPZN RPCOMP CIRC P Pumped 10 BBL dry job with 13.5 Mud 7,651.0 7,651.0 23:00 23:15 11/18/2015 11/19/2015 0.75 COMPZN RPCOMP TRIP P POOH with fish 7,651.0 6,850.0 23:15 00:00 11/19/2015 11/19/2015 3.50 COMPZN RPCOMP TRIP P Continue to POOH with fish. 6,850.0 317.0 00:00 03:30 11/19/2015 11/19/2015 2.50 COMPZN RPCOMP BHAH P Lay down DC's and fish.Clear floor. 317.0 0.0 03:30 06:00 (recovered the remaining completion, complete). 11/19/2015 11/19/2015 2.00 COMPZN WELLPR BHAH P Make-up BHA#2 as follows: 6 1/8" 0.0 134.0 06:00 08:00 Junk Mill,2 ea Boot Baskets,Bit Sub, Bumper sup,Oil Jar,3 ea 4 3/4"Drill Collars,Double Pin sub,7"Casing Scraper,Bit Sub,XO. 11/19/2015 11/19/2015 3.50 COMPZN WELLPR TRIP P Trip in with BHA#2 on 3 1/2"Drill Pipe 134.0 7,836.0 08:00 11:30 stands from the Derrick to 7,836-ft dpmd(Junk Mill depth at 7,836- ftdpmd...Casing Scraper depth at 7,707-ft dpmd). Page 2/5 Report Printed: 12/18/2015 - • • Operations Summary (with Timelog Depths) 0 , „ 3Q-13 ConocoPhitlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/19/2015 11/19/2015 0.50 COMPZN WELLPR CIRC T Attempted several times to break 7,836.0 7,836.0 11:30 12:00 circulations. No-Joy. Drill Pipe pressures up. (Suspect heavy mud settled out below the perforations). 11/19/2015 11/19/2015 0.25 COMPZN WELLPR TRIP T Trip back up to-7,400-ft dpmd. 7,836.0 7,400.0 12:00 12:15 11/19/2015 11/19/2015 0.75 COMPZN WELLPR WASH P Break circulations at 1.0 bpm. 7,400.0 7,836.0 12:15 13:00 Increase pump pressure up to 4.0 bpm/1,045 psi with full returns. Circulated down to 7836 ft @ 3.8 BPM @ 1010 psi.began building pressure once more to 1600 psi.Discovered that IBP was slowly closing. 11/19/2015 11/19/2015 6.00 COMPZN WELLPR RGRP T Set back one stand of drill pipe. 7,836.0 7,746.0 13:00 19:00 Trouble shoot the Inside BOP Valve on the Top Drive. (SIMOPS: continue to process Completion Tubing). 11/19/2015 11/19/2015 1.75 COMPZN WELLPR CIRC P Broke circulation at 5 BPM @ 1450 7,746.0 7,836.0 19:00 20:45 psi..Pumped 28 BBL150 Hi-Vis sweep. Recovered sand and scale back. 11/19/2015 11/19/2015 0.50 COMPZN WELLPR SFTY P Conducted a safety Stand down with 7,836.0 7,836.0 20:45 21:15 crew.Review monthly incidents and injuries with them. 11/19/2015 11/19/2015 0.25 COMPZN WELLPR CIRC P pumped 10 BBL 13.5 dry job. 7,836.0 7,836.0 21:15 21:30 11/19/2015 11/20/2015 2.50 COMPZN WELLPR TRIP P POOH with BHA#2 7,836.0 3,900.0 21:30 00:00 11/20/2015 11/20/2015 1.50 COMPZN WELLPR TRIP P Continue to POOH with BHA#2. 3,900.0 317.0 00:00 01:30 11/20/2015 11/20/2015 2.00 COMPZN WELLPR BHAH P Laid down BHA#2.Clear rig floor and 317.0 0.0 01:30 03:30 pipe shed of tools.Clean Rig floor. 11/20/2015 11/20/2015 0.50 COMPZN RPCOMP SVRG P Service and inspect Top drive 0.0 0.0 03:30 04:00 11/20/2015 11/20/2015 1.00 COMPZN RPCOMP RURD P RU Weatherford handling equipment. 0.0 0.0 04:00 05:00 11/20/2015 11/20/2015 2.00 COMPZN RPCOMP WAIT T Wait on replacement wear sox jt and 0.0 0.0 05:00 07:00 port sub.Do to damaged pin end. 11/20/2015 11/20/2015 0.50 COMPZN RPCOMP SFTY P PJSM. Discusses the hazards 0.0 0.0 07:00 07:30 associated with picking up the Lower completion. Review the final running order. 11/20/2015 11/20/2015 1.75 COMPZN RPCOMP PUTB P Pick-up the Lower Completion as 0.0 224.0 07:30 09:15 follows: Wearsox Joint w/Mule Shoe, Wearsox Joint, 5 1/2"x 3 1/2"Ported XO-Sub,2 Joints of 3 1/2"Tubing,"X"- Nipple Assembly(with PXX...plug and prong installed),Baker PBR Assembly,Baker 7"x 26 lb/ft F-1 Packer. Note...all connections below the Packer have been BAKERLOK'd. (Pick up the Baker Setting Tool). 11/20/2015 11/20/2015 0.50 COMPZN RPCOMP RURD P Rig down Weatherford tubing handling 224.0 224.0 09:15 09:45 equipment. Page 3/5 Report Printed: 12/18/2015 • • 0 Operations Summary (with Timelog Depths) a 3Q-13 c nitrps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P T-X Operation {WS) End Depth(ftK6)' 11/20/2015 11/20/2015 5.25 COMPZN RPCOMP RCST P Run the Lower Completion in on 3 1/2" 224.0 7,770.0 09:45 15:00 Drill Pipe stands from the Derrick. Up weight=165K. Down weight=90K. End of the Wearsox Mule Shoe at 7770-ft. Top of the Wearsox section at 7681-ft. Top of the Baker F-1 Packer at 7.565.75-ft. 11/20/2015 11/20/2015 0.75 COMPZN RPCOMP PACK P Drop the 1 7/16"packer setting ball. 7,770.0 7,770.0 15:00 15:45 Brining pump on at 1.0 bpm. Increase to 2 bpm. Ball on seat. Pressure up to 2,200 psi. Hold pressure for 3 minutes. Packer set. Shear setting tool free from packer. Record on chart. 11/20/2015 11/20/2015 0.25 COMPZN RPCOMP PRTS P Pressure test Casing,Packer and 7,770.0 7,770.0 15:45 16:00 PXX Plug at 1,500 psi x 10 minutes. Record on chart. 11/20/2015 11/20/2015 0.50 COMPZN RPCOMP COND P Prep to Displace Mud from wellbore 7,770.0 7,760.0 16:00 16:30 with Sea Water. Lay down the working joint. Monitor Well static. Stage Vac Trucks. Mix 100 bbl Deep- Clean Pill. 11/20/2015 11/20/2015 3.25 COMPZN RPCOMP COND P Off load and clean mud system for 7,760.0 7,660.0 16:30 19:45 fluid swap over to sea water. 11/20/2015 11/20/2015 3.25 COMPZN RPCOMP DISP P Circulated 100 BBL deep clean 7,660.0 7,660.0 19:45 23:00 sweep, 100 BBL Hi-Vis sweep. followed by 350 BBLs of sea water. 11/20/2015 11/20/2015 0.50 COMPZN RPCOMP OWFF P Monitor well for flow. 7,660.0 7,660.0 23:00 23:30 11/20/2015 11/21/2015 0.50 COMPZN RPCOMP PULD P POOH laying down drill pipe. 7,660.0 7,200.0 23:30 00:00 11/21/2015 11/21/2015 6.00 COMPZN RPCOMP PULD P Continue to lay down drill pipe. 7,200.0 190.0 00:00 06:00 11/21/2015 11/21/2015 0.25 COMPZN RPCOMP SFTY P BOP Drill. 190.0 190.0 06:00 06:15 11/21/2015 11/21/2015 0.25 COMPZN RPCOMP PULD P Finish laying down Drill Pipe 190.0 0.0 06:15 06:30 11/21/2015 11/21/2015 1.25 COMPZN RPCOMP RURD P Prep to run the Upper 3 1/2"Gas Lift 0.0 0.0 06:30 07:45 Completion. Pull Wear Bushing, Jet the Stack. Clear floor. Rig up Weatherford tubing equipment. 11/21/2015 11/21/2015 0.25 COMPZN RPCOMP SFTY P PJSM. Discuss the hazards with 0.0 0.0 07:45 08:00 picking up and running the upper completion. 11/21/2015 11/21/2015 6.50 COMPZN RPCOMP PUTB P Perform final jewelry inspection and 0.0 4,000.0 08:00 14:30 review running order. Pick-up the Baker Seal Assembly. Single in the 3 1/2"GL Completion as designed to the Baker Orbit Valve. 11/21/2015 11/21/2015 0.50 COMPZN RPCOMP SVRG P Inspect Top Drive 4,000.0 4,000.0 14:30 15:00 11/21/2015 11/21/2015 3.25 COMPZN RPCOMP RURD P Rig up Halliburton dual spooling unit 4,000.0 4,000.0 15:00 18:15 and equipment. Make-up Orbit Valve. Continue to rig up and tie in control lines. Service and test Orbit Valve. Valve placement will 3500 ft from surface. 11/21/2015 11/22/2015 5.75 COMPZN RPCOMP PUTB P Continue to RIH with upper completion 4,000.0 7,560.0 18:15 00:00 installing Cannon clamps on Control lines every jt. Page 4/5 Report Printed: 12/18/2015 • s , Operations Summary (with Timelog Depths) 3Q-13 ConocoPhiilips sr,�xs Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our{hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS); 11/22/2015 11/22/2015 0.50 COMPZN RPCOMP RURD P Ru Circulating line. 7,560.0 7,560.0 00:00 00:30 11/22/2015 11/22/2015 1.50 COMPZN RPCOMP HOSO P Circulate @ 1BPM engaged seals. 7,560.0 7,580.0 00:30 02:00 No GO locator sub.Space out tbg. Install hanger.Installed control lines in hanger. 11/22/2015 11/22/2015 1.50 COMPZN RPCOMP CRIH P Pumped 260 bbls of CI sea water at 3 7,560.0 7,560.0 02:00 03:30 BPM @ 240 PSI. 11/22/2015 11/22/2015 0.50 COMPZN RPCOMP THGR P Engaged seals in to PBR. Land 7,560.0 7,582.0 03:30 04:00 Hanger.RILDS 11/22/2015 11/22/2015 2.00 COMPZN RPCOMP PRTS P PT Tubing to 3500 psi for 15 min's.PT 7,582.0 7,582.0 04:00 06:00 IA to 3000 for 30 min's Chart recorded.Shear open the SOV. Pump both directions to confirm flow path. 11/22/2015 11/22/2015 0.75 COMPZN RPCOMP PRTS P Test Orbit Valve as follows: Closed 7,582.0 7,582.0 06:00 06:45 position,Pressure up on the tubing side to 3,500 paid x 5 minutes. Good. Bleed pressure to 0 psi. Pressure up on the backside to 3,000 psi.x 5 minutes. Good. Bleed pressure to 0 psi. Open the Orbit Valve. Circulate down the tubing,taking returns from the IA and confirm open. Good. All tests recorded on chart. Blow down lines. 11/22/2015 11/22/2015 0.50 COMPZN RPCOMP RURD P Lay down landing joint. Rig down 7,582.0 7,582.0 06:45 07:15 Weatherford tubing equipment. Rig down Halliburton spooling unit and equipment. 11/22/2015 11/22/2015 0.25 COMPZN WHDBOP MPSP P Set"HP"BPV. Pressure test from 7,582.0 7,582.0 07:15 07:30 below at 1,000 psi. Good. Record test on chart. 11/22/2015 11/22/2015 10.50 COMPZN WHDBOP SVRG P Perform scheduled Before Well 0.0 0.0 07:30 18:00 Maintenance. Replace Annular element. 11/22/2015 11/22/2015 2.50 COMPZN WHDBOP NUND P ND BOPE. 0.0 0.0 18:00 20:30 11/22/2015 11/23/2015 3.50 COMPZN WHDBOP NUND P NU adaptor and tree.Test to 250/ 0.0 0.0 20:30 00:00 5000 Build Orbit valve manifold 11/23/2015 11/23/2015 0.50 COMPZN WHDBOP MPSP P Pull BPV. 0.0 0.0 00:00 00:30 11/23/2015 11/23/2015 2.50 COMPZN WHDBOP FRZP P PJSM RU LRS.Freeze protect well 0.0 0.0 00:30 03:00 with 77 bbls of diesel to 2100 ft. .RD LRS.Equalize well. 11/23/2015 11/23/2015 0.50 COMPZN WHDBOP MPSP P Install Type H BPV. 0.0 0.0 03:00 03:30 11/23/2015 11/23/2015 1.50 DEMOB MOVE RURD P Install gauges.Prep tree and secure 0.0 0.0 03:30 05:00 well. 11/23/2015 11/23/2015 1.00 DEMOB MOVE RURD P Prep cellar Rig released.@ 06:00 hrs 05:00 06:00 Page 5/5 Report Printed: 12/18/2015 V OF Ty, $ w_..„0 4..,..,...\��� `�9 THE STATE Alaska Oil and Gas �1 of/\ T /\ SJ(T /�, Conservation Commission �"' 11111-1 `1-1 ti 333 West Seventh Avenue Anchora e, Alaska 99501-3572 vii °''' ,�*h,,� � GOVERNOR BILL WALKER9 Main 907 279 1 433 RLAS� Fax 907 276 7542 www aogcc.alaska.gov ZTheresa Lee 1 460 17 Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 SCANNEO Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-13 Sundry Number: 315-471 Dear Ms. Lee: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ale14 Cathy P. oerster Chair DATED this .5 day of August, 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /,l" `` APPLICATION FOR SUNDRY APPROVALS AS 8 (.. 20 MC 25.280 ' °(3 C 1.Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other. _CTD Set Up 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Exploratory ❑ Development L 186-176 • 3.Address: Stratigraphic ❑ Service d 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21664-00' 7. If perforating: 8.Well Name and Number. KRU 3Q-13 What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Leas/Number): 10.Field/Pool(s): I 11112) ADL 26520 ,5/) r- Field/KuparuK . 1\ k,k CVl 0 i l 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): - 8190 . 6583 - 7951 - 6403 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16 115 15 Surface 4288 9 5/8 4325 3713 Intermediate Production 8134 7 8168 6567 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7743-7828` 6247-6310 2-7/8" L-80 7661 Packers and SSSV Type. Baker FVL SSSV,Camco HRP-1-SP Packer Packers and SSSV MD(ft)and TVD(ft): 1790, 1773&7630,6162 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work. i46 Detailed Operations Program ❑✓ BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 1 1 Service CZ 14.Estimated Date for 5-Aug-15 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 . GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Theresa Lee 1– A—ef3 L-€,€.__. Email Theresa.M.Lee(a�conocophillips.com Printed Name Title Workover Engineer °VI '" (° -(° --., 482:44— Signature Pho Date �L 4 1 is_ • COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 - 1("3/1f I Plug Integrity 0 BOP Test e Mechanical Integrity Test Er Location Clearance 0 Other: aOp 1---r5i-- 1-0 38GU1-25r (A-ip5p ,5 345G' p5, /1,-, v-, v 1 a e" h r e-v:',--) trr fir 5 t- ¢o Z S‘.7 C2 5 , tate W, f-vzf 55rd /tn1T- IA is fii,-e-a 4 ftrr - /-4 / fi� tC1 i `�, 1LCt��- s ZSpacing Exception Required? Yes 0 NoSubsequent Form Required: Mr 40 APPROVED BY Approved by: agii44--,��_ COMMISSIONER THE COMMISSION Date: $ --5--- /3 v-ri✓ 87- /5 �`/," OA) Submit Form and �____ ... ......._..__ 1.i.....� A��.�....J......1:....�:....:......1:.1 i...A9.r.wwLl.w L.w...�I.w.Iw ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 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 an Application for Sundry Approval to workover the Kuparuk afed Well 3Q-13 (PTD# 186-176). 3Q-13 was originally drilled in 1986 and perforated in Al, A2, A3 sands. The weII was hydraulically fractured and pre-produced for 9 months before it was converted to injection. 3Q-13 is currently injecting at an average of 2,200 BWPD with reservoir pressure of 4,080 psi. This well has had no RWO since drilled and has passed all 4 mechanical integrity tests (MIT) on IA and OA in 2004, 2008, 2009 and 2012. 3Q-13 is currently in service as a miscible gas injector and designated as a normal well with no known well integrity issues. The CTD set up will allow for an A sand tri-lateral redevelopment to support 3Q-22, 3Q-07 and 3M-13. The proposed workover will pull the 2 7/8" completion string and packer then install a new 3 1/2" completion with a 5 1/2" tubing tail and FHL packer. We plan to inspect the exterior of the tubing for corrosion to determine a good setting depth for the new FHL packer within 200' of the top perforation. Estimated setting depth would be just above the current lowest GLM at 7,562'. This Sundry application is intended to document the proposed work on the Injection well 3Q-13 and to request approval to workover the well. If you have any questions or require any further information, please contact me at 263-4837. Regards, I 41 Theresa Lee Workover Engineer CPAI Drilling and Wells Theresa.M.Lee@conocophillips.com ORIGINAL 3Q-13 Kuparuk Producer Rig Workover (PTD #: 186-176) Current Status 3Q-13 is online injecting and is planned to be shut in on August 4, 2015. Scope of Work The proposed workover will Pull the 2 7/8" completion string and packer then install a new 3 1/2" completion with a 5 1/2" tubing tail and FHL packer. General Well info MPSP: 3,450 psi using 0.1 psi/ft gas gradient and SBHP from March 6, 2014 Reservoir pressure/TVD: 4,080 psi at 7,815' MD (6,301' TVD) SBHP taken on March 6, 2014 Wellhead type/pressure rating: CIW Gen IV 5K BOP configuration: Annular/ Pipe Rams/ Blind Rams/Mud Cross/ Pipe Rams MIT Results: MIT-OA passed to 1,810 psi on April 10, 2015 MIT-TxIA passed to 3,000 psi on April 10, 2015 Well Type: Injector Estimated Start Date: August 6, 2015 Production Engineer: Jason Long 265-6039/Jason.W.Long@conocophillips.com Workover Engineer: Theresa Lee 263-4837/Theresa.M.Lee@conocophillips.com Pre-Riq Work 1. SL: Pull valve from GLM#6 and leave open. Obtain new BHP. 2. Ops: Set BPV within 24 hours of rig arrival. Procedure: 1. MIRU. 2. Pull BPV. Reverse circulate KWF. Obtain SITP and SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV and blanking plug, PT to 1,000 psi from below if possible, ND tree, NU BOPE and test. 4. Pull blanking plug and BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 2 7/8"tubing. a. If OEJ will not pull free from the slick stick, RU E-line: Fire a string shot and cut the tubing at 7,586' RKB (middle of the first full joint above the OEJ). RDMO E-line. 6. RIH w/overshot dressed for 2 7/8"tubing on 3 1/2" drillpipe, latch onto tubing stub and jar OEJ and packer free. POOH laying down drillpipe. 7. RIH in with new 3 1/2"tubing, FHL packer and 5 1/2"tail pipe. 8. RU DSL to space 5 1/2"tail pipe KOJ on depth prior to setting packer. 9. Set XX plug, pressure up tubing to 2,600 psi to set the FHL packer. PT the IA to 3,000 psi. Shear the PBR. Space out 7'from fully located, mark the pipe. POOH two stands. ORIGINAL 10. Swap well over to seawater. Spot corrosion inhibited seawater into the IA. 11. Space out w/pups, MU hanger. MU control line to hanger. Land the hanger, RILDS. 13. PT the tubing to 3,000 psi, bleed tubing to 2,500 psi. PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 14. Pull the landing joint, install BPV. PT BPV to 1,000 psi from below. 15. ND BOPE. 16. NU tree. Pull BPV and install tree test plug. Test tree. Pull test plug. 17. Freeze protect well w/diesel. 18. Set BPV. 19. RDMO. Pre-Rig Work 1. Pull 'H' BPV. 2. RU Slickline: a. RIH and pull XX plug from the 2.813"X nipple. b. RIH and pull the SOV. Run Gas Lift Design for CTD. 3. Reset the well houses and flow lines. 4. Turn well over to Operations and CTD. ORIGINAL KUP INJ 30-13 ConocoPhillips ; Well Attributes Max Angle&MD TD • Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl I') MD(ftKB) Act Btm(ftKB) ctxwriam' Him • 500292166400 KUPARUK RIVER UNIT INJ 44.68 3,100.00 8,190.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30T3.3/11/2014330.44 PM SSSV:LOCKED OUT 3/11/2000 Last WO: 42.51 12/10/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,951.0 3/6/2014 Rev Reason'TAG hipshkf 3/11/2014 Casing Strings HANGER,34 0 1116 I I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1;1 I CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.765 37.0 4,325.3 3,713.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread • PRODUCTION 7 6.276 34.0 8,168.8 6,567.2 26.00 J-55 BTC PPP .. ,.. ,..e....Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth)TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.441 34.0 7,660.8 6,185.5 6.50 L-80 EUEBrdABMOD CONDUCTOR;38.0.115.0 Completion Details Nominal ID Top(MB) Top(TVD)(ftKB) Top Incl I") Item Des Corn (In) 34.0 34.0 0.19 HANGER C.I.W.2 7/8"Tubing Hanger 2 7/8"8rd Top/Bim 2.875 1,790.2 1,773.3 23.11 SAFETY VLV Baker'FVL'SSSV 4.563 OD,2.310 ID(LOCKED OUT 6,162.6 41.51 PACKER 2.310 3/1112000) SAFETY VLV;1,790.2 71,'67934120.1280 ,612.8 6,149.5 41,53 PBR CAMCO'OEJ'4.750 OD,2.312 ID 2.312 7,630.3 CAMCO 2 7/8 x 7 HRP-I-SP Packer 5.937 OD,2.347 2.347 ID 7,648.2 6,176.0 41.49 NIPPLE CAMCO 27/8 D-Nipple 2.2501D 2.250 GAS UFT;2.751.8 7.G60.1 6.185.0 41.48 SOS CAMCO27/8 Shear Oct Sub 2.992 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Bier(ftKB) (ftKB) (ftKB) Zone Date II Type Com 7,743.0 7,755.0 6,247.1 6,256.1 A-3,30-13 8/4/2000 4.0 APERF 2 1/8"Enerjet;180 deg phasing;+/-90 degs f/low side. SURFACE;37.0-4.325.3 • 7,760.0 7,784.0 6,259.8 6,277.8 A-2,30-13 3/26/2000 4.0 RPERF 2 1/8"EJ III DP;o/-90 deg orient 7,790.0 7,828.0 6,282.3 6,310.8 A-1,30-13 3/26/2000 4.0 RPERF 2 1/8"EJ III DP;+1-90 GAS LIFT;5,006.4 deg orient Mandrel Inserts I St 0-ti on Top(TVD) Value Latch Port Size TRO Run GAS LIFT;6,276.2111 N Top(ftKB) (ftKB) Make Model OD ON Sery Type Type (In) (psi) Run Date Com P 2,751.8 2,553.2 Merla TMPD 1 GAS LIFT -DMY BK-2 0.000 0.0 1/18/1987 I 2 5,006.4 4,213.2 Merla TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 1/18/1987 3 6,276.2 5,159.1 Merla TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 1/18/1987 GAS LIFT;6726.4 4 6,726.4 5,492.0 Merla TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 1/18/1987 5 7,144.4 5,802.0 Merla TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 1/18/1987 6 7,562.1 6,111.7 OTIS 2.875x1. 11/2 GAS LIFT DMY T-2 0.000 0.0 2/22/1987 5 • GAS LIFT;7,144.4 • Notes:General&Safety • • End Date Annotation I2/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT;7,562.1 I II I I PAR:7.612.8 MM • Q r PACKER;7,630.3 NEI. a" NIPPLE;7,648.2 £i I ` APERF;7,743.0.7,755.0 RPERF;7.760.0.7,784.0 - RPERF;7,790.0.7528.0 I II ORIGINAL PRODUCTION;34.0.8,168.8 I ConocoPhilli'p L 3Q-13 31/2" x 51/2" CTD setup 4 Baker Orbit Valve @ -3,500' Casing-9-5/8" 36#, J-55 to 4,325' — Casing-7"26#, J-55 to 8,168' Tubing-31/2" 9.3#, L-80, 8rd EUE-Mod to 7,660,' Camco 3 1/2"x 1 1/2" MMG GLM's "` /-- Baker 20' PBR @ -7,553' ' 1, ' FHL Packer @ -7,560' o I f— 2.813"X-Nipple @ 7,675' o -3 '/2"x 5'/" Crossover with ports @ 7,690' • Liner-2 Jts 5'/2" 14#, H-40, 7,690'to 7,770' -411.4 r1:3 0 .."•..., ® 6" OD Wearsox every-3'on CTD Laterals KOP 7,745' ► �~ lower joint of 5'/" liner ' ' IT A-3 Perfs 7,743'to 7,755' - --: gi A-2 Perfs 7,760'to 7,784'—► 3 A-1 Perfs 7,790'to 7,828' -► ORIGINAL .. IDate: October 28,2014 I Drawn By: Theresa Lee CAMERON CONOCOPHILLIPS KUPARUK RIVER UNIT WELL 3Q-13 EXISTING EQUIPMENT (CC CIW KRU GEN 4 WELLHEAD SYSTEM 2-7/8" COMPLETION 3-1/8"5K TREE /� `r / IPO + �V®\ O JO • 2 9/16" 5000 Tre- 11111(jCio°11.1 1. J Oi I III / 0 0 BO. CIW(KRU Gen 4) • Tubing Head Adapter PN 640952-03 11111111^ „ CIW Type FBB(KRU Gen 4) 7-1/16 5K STDD Btm x 2 9/16" 5K STDD To• �• 'Mj. Tubing Hanger PN 640949-03 Prep for Secondary Seal on Tubing Hanger. ���_ (_ res 7 x 2-7/8" EUE Box BTM x 2-7/8"" EUE Prep for(1) Control Line Box Top. 2"Type H BPV Profile. CIW Type N (KRU Gen 4) E Prepped for(1) Control Line Tubing Spool PN 640933-01 11111 r: IAI 11" 3M Flange Btm x 7-1/16 5M Flange Top. Bottom prep for.9-1/2 C-Bore x 7" Csg �• S i■. CIW Type X Secondary Pack-Off Type Secondary NX Bushing : m. 9-1/2 C-Bore x 7" CSG I CIW Type WF(KRU Gen 4) ■� I �.��� CIW Type FR Slips f�� W ` 10 x 7"with Separate Type WC Casing Head PN 641230-01 "ELI IFFF-�Wo Primary Seal Assembly 11-3/4" Butt Btm x 11" 3M Flange Top. ! - , Slips PN 156173-01-01-09 WC PN 156165-01-01-09 11-3/4" Casing 7" Casing L I 2-7/8"Tubing Image Project Well History File Cover Page XHVZE This page identifies thOse items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) /~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: [] Diskettes, No. [] Maps: Grayscale items: Poor Quality Originals: Other: ~ [] Other, No/Type TOTAL PAGES: ~)~ NOTES: RGANIZED BY: BREN VINCENT SHERYL MARIA LOWELL [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: ~:7'~(at the time of scanning) SCANNED BY: BEVERLY BREN VINCE~ARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: ~~,,_... ~ ,,_f~~ PAG ES: Quality Checked (done) RevlNOTScanned.wl~l ~ • COI'IOC~~~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission , ~ ~ ~ 333 West 7 Avenue, Suite 100 '~(~ Anchorage, AK 99501 - . u ,, ~,~~.~ ~; ~ ~~~~~~ ~~ 13 <.. ~. r .,.:r.a _ _ ' I ~ _ ~ dj N r~ Dear Mr. Maunder: - Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~` and l Oth 2009. The atta.ched spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 ~.. ~~ ~~. e n~ .,_~ ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement ~ Cement top off date v~ ~~ v~~ u.~~.( Corrosion inhibitor r a~a Corrosion inhibitor/ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10l2009 3G-13 3G-15 50103201370000 50103201390000 1901160 1901210 17" 18" n/a Na 17" 18" n/a n/a 2.97 2.97 8/10/2009 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'S" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 3H-09 50103200790000 50103200860000 1870790 1871120 17" 17" n/a n/a 17" 17" n/a n/a 2.97 5.52 8/8l2009 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 5010320088000Q 1871290 2'7" n!a 2'7" n/a 8.92 8/9/2009 3H-15 3H-16A 50103200820000 50103200960100 1871030 2000220 19" 15' n/a 2.75 19" - 17" Na 7/30/2009 3.4 1.7 8/9/2009 8!9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 3H-25 3H-26 3H-28A 50103200970000 50103202030000 50103202080000 50103202360100 1880110 1990400 1940290 1960370 27'6" 30" SF SF 4.25 n/a n/a n/a 27" 30" 9" 18" 7/30/2009 n/a n/a n/a 8.5 7.65 2.12 5.1 8/9/2009 8/9/2009 8/9/2009 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 3Q-02 3Q-04 3Q-07 3Q-12 3Q-13 50029222200000 50029216880000 50029222190000 50029216820000 50029216770000 50029216640000 1911250 1870040 1911240 1861940 1861890 1861760 15'7" 41' 4'10" 6" 7" 44'6" 2.00 4.75 1.50 n/a n/a 5.00 17" 21" 16" 6" 7" 21" 7/30/2009 7/30/2009 7/30/2009 n/a n/a 7/30/2009 4.25 5.52 4.25 1.7 2.97 8.92 8/8l2009 8/8l2009 8/8/2009 8/9/2009 8/8/2009 8/8/2009 ~ 3Q-15 3Q-16 50029216660000 50029216670000 1861780 1861790 49'S" 46' 4.50 S.25 20" 30" 7/30/2009 7/30/2009 9.35 8.5 8/8/2009 8/8/2009 MEMORANDUM To~ Jim Regg ~ P.I. Supervisor ~~~~ t~~~G FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October O 1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-13 KUPARUK RIV UNIT 3Q-13 Src: Inspector NON-CONFIDENTIAL Reviewed By j P.I. Suprv `~~ Comm Well Name: KUPARUK RN UNIT 3Q-13 API Well Number: 50-029-21664-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080927182554 permit Number: 186-176-0 / Inspection Date: 9/25/2008 Rel Insp Num: Packer Depth. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-13 Type Inj. ~ G 'j'am 6162 IA ~ 950 1800 ~~ 1720 1700 p T ~ 1861760 TypeTest ~ SPT I TCSt pSl 1800 i ~~ QA ~ 230 230 230 230 ~ Interval 4YRTST p~F P Tubing I 3340 3340 3340 i 3340 Notes: Wednesday, October O1, 2008 Page l of 1 MEMO RAND UM State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp Petroleum Inspector DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-I3 KUPARUK RIV UNIT 3Q-I3 TO: Jim Regg 0 (J{ , D P.I. Supervisor f"Iert 'V 24 f Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3Q-13 API Well Number: 50-029-21664-00-00 Inspector Name: John Crisp Insp Num: miUCrO408IOl804II Permit Number: 186-176-0 Inspection Date: 8/812004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-I3 Type Inj. S TVD 6582 IA 750 3050 2850 2820 P.T. 1861760 TypeTest SPT Test psi 1540.5 OA 150 150 150 150 Interval 4YRTST P/F P Tubing 2150 2150 2150 2150 Notes: It took 10 bbl's to achieve test pressure. After initial stabilization of200 psi the IA lost only 20 psi. MIT passed test. Wednesday, August 11,2004 Pagel of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: ! PI3illips Alaska, Inc. Development__ 3. Address Po O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2282' FNL, 2037' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 716' FNL, 1734' FEL, Sec. 20, T13N, RgE, UM At effective depth 6. Datum elevation (DF or KB feet) RKB 60 feet Exploratory_ 7. Unit or Property name Stratigmphic __ se~vice___x Kuparuk Unit 8. Well number (asp's 516300, 6025789) 3Q-13 ~,t total depth 1003' FNL, 3662' FEL, Sec. 20, T13N, R9E, UM 12. Present well condition summary -l'otal depth: measured ~ue vertical 9. Permit number / approval number 186-176 / 10. APl number 50-029-21664 11. Field / Pool Kuparuk Oil Pool 8190 feet Plugs (measured) 6583 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth CONDUCTOR 115' 16" 1875~ F'o~e set 1 15' SUR. CASING 4265' 9-5/8" 12oo sx AS m & 300 sx C~ass G 4325' PROD. CASING 8109' 7' 300 sx Class G & 175 sx AS I 8169' True vertical Depth 115' 3713' 6567' 13. Stimulation or cement squeeze summary 14. Prior to well operation Subsequent to operation 15. Affachments Copies of Logs and Surveys run__ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jo[fA. Spencer Representative Daily Average Production or Injection Data . . ..O.!.F.B.~ ..... ~.s.-.M...d.' .w...a..te.r:.B~..! ............. g.a..s!qg.p.r, es.~u.r.e ......... .T.u.b.!n.g..P..m...~..U..~... Questions? Call Jeff Spencer 659-7226 Prepared by Robert Ch#stensen 659-7535 Form 10-404 Rev 06/15/88' SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X 4. Location of well at surface 2283' FNL, 2037' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 716' FNL, 1734' FEL, Sec. 20, T13N, R9E, UM At effective depth (asp's 516297, 6025791) (asp's 514808, 6022075) At total depth 1003' FNL, 1629' FVVL, Sec. 20, T13N, RgE, UM (asp's 514705, 6021788) 12. Present well condition summary Total depth: measured true vertical 81 90 feet Plugs (measured) 6583 feet Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 4265' PROD CASING 8109' 7879 feet Junk (measured) 6349 feet Size Cemented 16" 1875# Poleset 9-5/8" 1200 SxAS III & 300 G 7" 300 Sx G & 175 Sx AS I Perforate _X Other__ 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-13i 9. Permit number / approval number 186-176 10. APl number 50-029-21664 11. Field / Pool Kuparuk Oil Pool Tagged Fill (8/24/00) @ 7879' MD. Measured Depth True vertical Depth 115' 115' 4325' 3713' 8169' 6567' Perforation depth: measured 7743 - 7755'; 7760 - 7784'; 7790 - 7828' true vertical 6247 - 6256'; 6260 - 6278'; 6282 - 6311' Tubing (size, grade, and measured depth) 2.875", 6.5#, L-80, Tubing @ 7661' MD. Packers & SSSV (type & measured depth) Camco 'HRP-I-SP' Packer @ 7630' MD. Baker 'FVL' - Locked Out 3/11/00 @ 1790' MD. RECEIVED MAR 2 7 2001 Alaska 0ii & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl . Representative Da y Avera,qe Production or Injection Data Gas-Mc{ Water-Bbl 2000 5000 CasingPressure TubingPre~ure - 2800 3700 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~/~ // Title: Form 10-404 Rev 06/15/88 · 16. Status of well classification as: Suspended __ Service __.(WAG).__ Prepare{~ by John Peirce 265-6471 SUBMIT IN DUPLICATE 3Q-13i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT & PERFORATING OPERATIONS 2/6/00: RIH & tagged fill at 7875' MD. 2/14/00: MIRU & PT equipment. Pumped a Fullbore High Pressure Breakdown treatment through the open perforations at: 7746'; 7748'; 7750'; 7762'; 7764'; 7770 - 7772'; 7794'; 7796'; 7798'; 7800 - 7802'; 7804'; 7806'; 7814 - 7815'; 7817'. (All perfs listed @ 1 spf) Pumped: a) 300 bbls Slickwater @ 27 bpm, followed by b) 50 bbls Scour slurry w/1 ppa proppant @ 26 bpm & 7800 psi, followed by c) 400 bbls HPBD stage @ 27 - 29 bpm / 7800 - 8800 psi, followed by d) 100 bbls Scour slurry w/1 ppa proppant, followed by e) 500 bbls HPBD stage @ 29 bpm / 8600 psi, followed by f) Shutdown. ISIP @ 2400. Placed a total of 5,861 lbs of Scour sand into the formation. Rigged down. 3/26/00: MIRU & PT equipment. RIH w/perforating guns & shot 62' of perforations as follows: Added / Reperforated: 7760-7784' MD 7790- 7828' MD Used 2-1/8" Enerjet carriers & shot the perfs at 2 spf. POOH w/guns. Rigged down. 814100: MIRU & PT equipment. RIH w/perforating guns & shot 12' of perforations as follows: Added / Reperforated: 7743- 7755' MD Used 2-1/8" Enerjet carriers & shot the perfs at 4 spf. POOH w/guns. Rigged down. 8/24/00: RIH & tagged fill at 7879' MD. Returned the well to injection & obtained a valid injection rate. STATE OF ALASKA ALAS._.,, OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 995]0 4. Location of well at surface 2283' FNL, 2038' FEL, Sec.17, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 60' 6. Unit or Property name KiJnarlJl< Rivc, r 7.' Well number 3Q-13 Feet At top of productive interval 781' FNL, 1880' FWL, Sec. 20, T13N, R9E, UN At effective depth 958' FNL, 1821' FWL, Sec.20, T13N, R9E, UM At total depth 1026' FNL, 1800' FWL, Sec. 20, T13N, R9E, UN 8. Approval number #7-808 9. APl number 50-- 029-21664 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth' measured 8190' ND feet true vertical 6603' TVD feet Plugs (measured)NOne Effective depth: measured 8083' MD feet true vertical 6523' TVD feet Junk (measured) None Casing Structural Conductor Surface xxxl~~e Production xxxlxi;~:~:XX XX Perforation depth: Length Size 80' 16" 4288' 9-5/8" 8135' 7" measured Cemented Measured depth 6onductor Report not received 115' MD 1200 SX AS III 4325' MD & 300 SX Class G 300 SX Class G 8169' MD See Attached Listing true vertical See Attached Listing True Vertical depth 115' TVD 3728' TVD 6587' TVD ~bing(size, grade and measured depth) 2.875", L-80, tbg with Tail ~ 7661' Packers and SSSV(type and measured depth) SSSV' Baker FV[ 1790', Packer: Camco HRP-I-SP ~ 7630' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 800 BOPD 1100 MCFPD - BWPD 1200 psig 180 psig Subsequent tooperation 2700 BWPD ],000 Dsig 17F)fl .n~ig 14. Attachments Converted from oil producer to water injector Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/~(..~,'~ ~ /z~/'?/v'~._~,¢~.4.~~ Title Form 10-40;4 Rev. 12,7-85 ' Sr. Operations Engineer Date 2/26/88 Submit in Duplicate We1 1 Completion or Recompletion Report end Log 3Q-13 (cont'd) Item #24: Perforations MD 7746 7748 7750 7762 7764 7770 7771 7772 7794 7796 7798 7800 7801 7802 7804 7806 7814 7815' 7817' 7823'-7826' Perforated w/1 spf TVD 6249' 6250' 6252' 6261' 6262' 6267' 6267' 6268' 6285' 6286' 6288' 6289 6290 6291 6292 6294 6300 6300 6302 6306 1 , ! I I I I ! '-6309' SW02/26 05/12/87 ,RCOAlaska, Inc, ,? Subsidiary of Atlantic Richfield Company .L IPBDT ' "TRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME IDAYS I DATE IT. (,,gAs ,',Jcn'* t,,81T"~e...c_..se.,~ DY CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather]TemP.Report OF Chill Fact°r ] Visibility IWindVel' fSigned°F miles knots ARCO Alaska, Inc ~ Post Office x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate on Kuparuk wells. The listed below. are multiple wel 1 s were Commission Applications for both conversions Well Action 2A-3 Conversion 2A-6 Conversion 2A-7 Conversion Anticipated Sta 3K-15 Conversion Sundry Approvals and fractures as 3N-4 Conversion 3N-5 Conversion 3N-11 Conversion rt Date 3Q-5 Conversion 3Q-12 Conversion ~~. ~ Conversion If you have any questions, please call October 19, 1987 October 19, 1987 October 19, 1987 October 15, 1987 Sincerely, October 15, 1987 October 15, 1987 October 15, 1987 October 15, 1987 October 15, 1987 October 15, 1987 me at 265-6840. lwood Senior Operations Engineer GBS:pg:0117 Attachments cc: File KOE1.4-9 RECEIVED OCT 1 6 1881 Alaska 0ii & Gas Cons. Commission Anchorage .. ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALA._..A OIL AND GAS CONSERVATION COl~ .... ISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend [] Operation Shutdown lq Re-enter suspended well [] Alter casing F~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 2283' FNL, 2038' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 781' FNL, 1880' FWL, Sec. 20, T13N, R9E, UM At effective depth 958' FNL, 1821' FWL, Sec. 20, T13N, R9E, UM At total depth 1026' FNL, 1800' FWL, Sec. 20, T13N, R9E, UM 11. Present well condition summary Total depth: measured 8190' feet true vertical 6603' feet 5. Datum elevation (DF or KB) RKB 60 6, Unit or Property name Kuparuk River Unit 7. Well number 3Q-13 8. Permit number 86-176 9. APl number 50-- 029-21664 Plugs (measured) feet 10. Pool Kuparuk River Oil Pool None Effective depth: measured 8083' feet true vertical 6523' feet Junk (measured) Casing Length Structural Conductor 80' Surface 4288' Intermediate Production 8135' Liner Perforation depth: measured Size Cemented Measured depth 16"Conductor Report not rec'd 115' 9-5/8" 1200 Sx A.S. III 4325' 300 Sx Class "G" 7" 300 Sx Class "G" 8169' See Attached true vertical See Attached Tubing (size, grade and measured depth) 2.875", L-80, tbg w/tail Packers and SSSV (type and measured depth) True Vertical depth 115' 3728' 6587' @ 7661' SSSV' Baker FVL 1790', Packer' Camco HRP-1-SP @ 7630', 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch ~ Convert to water injection. 13. Estimated date for commencing operation October 15, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to ~e best of my knowledge Signed /~~ /'~ ;S/'")/.-~,~..,¢..~/~)itle ~¥~ ~-~t~--~tl¢,"~ L ' ~ Date Commission Use Only Notify commission so representative may witness ,pprova,,o. Conditions of approval ~ ~lu~ into~rity ~ BO~ Tost ~ kocation cloarancoI ' ..... . ' . ~,~'~"~,,~.,~ ~,-~-,,,..,~';::~:'~ /'~ ....~'~ ............... by order of .... I Approved by '~, ,¢~<,,~; * ~;!¢ Commissioner the commission Date Form 10-403 Rev 12-1-85~',~ ~c,,,;. ~ .......... Submit in triplicate ' :' STATE OF ALASKA - ~ ALASKA OIL AND GAS CONSERVATION C,~MMISSION t/~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Welt Classification of Service Well OIL I~. GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-176 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21664 4. Location of well at surface 9. Unit or Lease Name 2283' FNL, 2037' FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 716' FNL, 1734' FWL, Sec.20, T13N, R9E, UM 3Q-13 At Total Depth 11. Field and Pool 1003' FNL, 1629' FWL, Sec.20, T13N, R9E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) t 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 60'I ADL 25512 ALK 2553 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/0/+/86 12/09/86 04/26/87*I N/A feet MSLI 1 , 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Dep'hwhereSSSVset I 21.Thickness of Permafrost 8190'MD, 6582'TVD 8083'MD, 6502'TVD YES ~ NO [] 1790' feet MD 1600' (approx.) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 1875# Pol eset 9-5/8" 36.0# J-55 Surf 4325' 12-1/4" 1200 sx AS Ill & 300 sx Class G , 7" 26.0# J-55 Surf 8169' 8-1/2" 300 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7661 ' 7630 ' · See attached 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached adde~dum~ dated 5/5/87 for fracture data 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD · Flow Tubing Casing PressUre CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. ; 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ., 'l r". :~ "~ i.~';,.-:', ,:..~ ,[:~.': ,!'..'.'? * NOTE: Drilled RR 12/10/86. Tubing run 01/18/87. Perforated well 03/07/87. hi?- -',, ,' WC2.b9: UAN I Form 10-407 Submit in duplicate CONTINUED ON REVERSE SIDE Rev. 7-1-80 GEOLOGIC MARKERS'' ' ,. 'iF-~RMATiON 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 7727' 6234' N/A Base Kuparuk C 7739' 6243' Top Kuparuk A 7739' 6243' Base Kuparuk A 7864' 6337' 31. LIST OF ATTACHMENTS Addendums (dated 2/17/87, 3/19/87, and 5/5/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~~/~ Title Associate Engineer Date ~-~J~"~7 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Wel 1 Completion or Recompletion Report and 3Q-13 (cont'd) Log Item #24: Perfora Perforations MD 7746 7748 7750 7762 7764 7770 7771 7772 7794 7796 7798 7800 7801 7802 7804 7806 7814 7815 7817 7823 -7826' ted w/1 spf TVD 6249 6250 6252 6261 6262 6267 6267 6268 6285 6286 6288 6289 6290 6291 6292 6294 6300 6300 6302 6306 -6309' SW02/26 05/12/87 ADDENDUM WELL: 1/06/87 1/09/87 3Q-13 Rn CBL & gyro. Re-rn CBL to 8079' WLM TD. Rn GR/JB f/PBTD to surf. Dr~.llzng Superv~.sor ~/~ ~/~ Date ADDENDUM WELL: 3/07/87 3Q-13 RU Schl, tst lubr. RIH w/2 perf guns, & temp tl & Measurement While Perf'g tl & per @ 1SPF, 0° phasing @ 7814' 7815' 7817' 7823'-7826' & 7794' 7796' 7798' 7800' 7801' 7802' 7804' & 7806' SI well, POOH TIH , ~ , · · w/gun #3, perf 7746' 7748' 7750' 7762' 7764' 7770' 7771' & 7772'· Press before shooting had inc'd to 3140 psi. Flow well to tanks. $I f/PBU, press inc'd to 3130 psi. POOH, RD Schl. 'D ~ill-ing Su~erviso% ADDENDUM WELL: 3Q-13 1/06/87 Rn CBL & gyro. 1/o9/87 4/26/87 Re-rn CBL to 8079' WLM TD. Rn GR/JB f/PBTD to surf. Frac Kuparuk "A" sand perfs 7746' 7748' 7750' 7762' 7764' 7770' 7771' 7772' 7794' 7796' 7798' 7800' 7801' 7802' 7804' 7806' 7714' 7715' 7717' 7723' 7724', 7725', & 7726' in 12 stages per frac procedure dated 4/21/87 as follows: Stage 1: 40 bbls 140° diesel w/5% Musol @ 5 BPM, 4350 - 3930 psi · Stage 2: 100 bbls gel diesel @ 12 - 21BPM, 6440 - 4670 psi Stage 3: 180 bbls gel diesel @ 20 BPM, 5120 - 4730 psi Stage 4: 11 bbls gel diesel 1 ppg/lO0 mesh @ 21BPM, 4730 psi .Stage 5: 359 bbls gel diesel @ 20.5 BPM, 4730 - 4650 psi Stage 6: 36 bbls gel diesel @ 3 ppg 20/40 @ 20.5 BPM, 4650 - 4700 psi Stage 7: 34 bbls gel diesel 4 ppg 20/40 @ 20.5 BPM, 4700 - 4670 psi Stage 8: 20 bbls gel diesel 5 ppg 20/40 @ 19.5 BPM, 4670 - 4740 psi Stage 9: 31 bbls gel diesel 6 ppg 20/40 @ 20 BPM, 4740 - 4990 psi Stage 10:15 bbls gel diesel 7 ppg 20/40 @ 20 BPM, 4990 - 4900 psi Stage 11:14 bbls gel diesel 8 ppg 20/40 @ 20 BPM, 4900 - 4910 psi Stage 12:46 bbls gel diesel flush @ 20 BPM, 4910 - 5310 psi Fluid to Recover: Sand in Zone Avg Press: Sand in Csg: 886# 400# 100 mesh & 33,720# 20/40 4750 psi 280# 20/40 Turn well over to Production, 4/26/87. Drilling Supervisor January 16, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70002 Well: 3Q-13 Field: Kuparuk North Slope, Alaska Survey Date: January 5, 1987 Mr. Ruedrich: P'lease find enclosed the "Original" and one (1) copy of our Boss GyroScopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures [ ,ECEIYED FEB- 9 1957 Alaska Oi~ & Gas Cons. Oommiss?~: Anchorage .tlCHORAGE FILE COPy ,NC. NL Sperry-Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ANCHORAGE ALASKA ARCO ALASKA, INC, :3 Q-15: I.:::UI::'A R U K A I._ ~'-"-~ E:KA C:OMF'UTATION DATE ,JANLIF:~F:;Y' l i.? .., .1. ':T.;E:7 ,. DATE OF ~:;URVEY ,JANLIARY - ,) ,j _1_ :; :;: ... ~:,: - '-'°'" . '"" I "' - :' ~:' ' BUo,., GYROE;COF'IC .=,L. RV~Y .... 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() ..................................... 2'il;' 1. 'i;;, .1. ::ii: ::ii: ()"::' .... 7 ....I .::.. :3 1 E:'7 ,, '1 6 · "*~ -'% I::;' · .::,..= .... 4, 4() ........................................ :.i:: ::ii: 2 i. ~!! () .ii: ::ii: :iii: :iii:. ,:,'-., () :? 4 55, <':, :1. ............................ · .2" ....m .,:L .~ ,,., ..- "" £ :' 'Zo 9 .= ..... 44 .... ,, =-~ ,~,--] · .2, ".2' ._1.2, ,, ........ :'::I '?' '? :':: ,, ./::, () . :iii: '7 'i;> O , 5 "' <::' c::i "7 ... ~ ...~ ..... ,u ..I.. ..................................... 3 ?:'2!: 4,2 4. 056 · 61 4 :{. :2 :ii!: ,, fi!; zl. 416: ::!!: ~ :iii: 4 .q '211:i 4... ":' :1. I NC~ ANE:I-]FIRAGE ALASKA ' DATE OF S.IRVEY ,_IANUARY 05, 1987 . .. Bu.=,.=, GYROSE:OF'IE: .=,L.IRVE'~ CAMPUTATIAN DA'rE ' -""-' '-' ' ' ,.J A N I J A R Y ]. ;:":., VERT I F:AL_ :-qEC"I' I ON CALC:ULATEB;:;: :AL. ONG""E' . ]"RI IE '::11B-:~EA r~'l ~_-': A :;ii: I...I J::;~ I:..~ .~"l V I::-.-; I:;: '1" ;I; C A L... .I;;;i E] F-:' T H 1 '? 8'7 . (', B Iq U H B E R A i.::]-... B [..-.i-'7 0 A 0'2 I<EL_L.Y Bl..!:i~;l-II ?,,l(!i I;!;iI..,E;V ~ ..... ;:~': ........ ~:.'i("). C>O F::"I", ......... r", F' E R r:.-'~ 'T' ] R..... F'i ]: ;:: I. I:[ I:.;; E VERTI CAI... DEPTH C OI...IR'.E;E COURSE L] L-.f G-/._ E G TO'T'AL.. I NE:I.... I NA'I" I ]1',.I i'"l I R E;C"F I (]l',.I SEVE-R I TY F;:IEC TANr}I...II~.. AF:; C ;') -. F:iI] ;I; I',,h:':'~'i"l:?.'S D liii; ,.'.!i M I IxlD E (} R E E :i:i; .1E) Iii!; Cji ./]. ()C) N (;)I::; ~1' H / i::: f['l I. I "1" I'"l E ;~:'l '.!ii; "J"/" i,~.l t:i:' :.'".'i;-'r V E F,' T I C ~"'.'~ I .... :i']; liiiJ C 'T' I 0 N I'"tOR I ZE~NT'AL. D I :']:F:'LACEMErNT = Zl.::.:~ 13, ~:i 0 FEi;E"I" A'T' :.-] OI..I'T'H 21 E[EG. 58 M I N, WES"I" A'T' H!'] .~::: 8 :t ANCHORA~] E ALA'.:;KA DF~'I'E ~_-~F' '.~.;I..IF~VEY ,J(~NUAF;:Y O.~i., 1':.9::~7 · . ,...IFiNI..I,':.'.~F~:'f' t :,'.::., t '.:.>:.::','? _ :"i}:.:; I,,11.11¥11~::~I:i':1::;~ F'~t::'-..I:.'~,"~-..'TF)('~F~-'? ........... .................... . .... ~ I ..: ,., l':::Fi:l.._l Y F.:'~I il:: I'i I I',t(i:i lii:.'l _1:::..~ ,, ~:-,i'.'t ,, 0,3 F'"I", !i'~!.!:!iJi'~:_~!.:: ('_~..i['.!:_.:!.!!:;:i.: ;..?!!7: !.i':i~.t;!.ij..! ::,:.l!il ....... INTERF'OLATED ..... ~Fq[ I IF'"":-.:, FOR. EVEI',I :l. O0(-I F'EET F~F: PlE:.(-ISLIRED DI:.:.F'TH I"H ........... V E I:;,' T ]: I.':: (-'/I .... I::;: E C T' ~.:7~ N (31...I I... F-i I::;~ I~:: 0 i:')t::i' i0 '1: N F.', "1-E: :.:.'i; H I)".-' "1" 'v' i71 V E_' i :;~ "1" i' 1% (.'.'~, I... I')li.:' F::"I" H I'q(3 F;,"l" H./:..j:Ol... 'l"l..i Iii:: ~"~ :ii:"l" .,'" I,,Jl:i!: :i!j:"!" I:) :f I:::'I:::'Ii:i:I::;:E't',I(:::E. 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O ~"~ (': ':::' ' "'" ' ::.::'":' '":' ' '"",'.' ..... ,_', :', 4 .. ..... ::ii~:2 5!t, ~i~2 '.~i; 1 '-' .... .:.,/.:,..:, ,1. .-.,..,., ,.::~ ..:,~::: .-:, .:::,.~:: :::: ,:::....., · , ..... ~. 7 kl 1 ':;F)::'N '7'7 ..... .. . .,::...::, ',:.:: ~".~ i")(") ,:!:, .".I. ::~ 9 ,, t:"; :'::i ~.!:, ::~: 7' '? ,, ti::; 7; :Tii:',!ii: :!ii', :;ii:., ,'.!:, 7 :ii.:; 1. t.::; 7 F~, '70 ~,..J :L ~5 ~.~:, O ,, ,:':1. 7' :::il :!!!; 4 ,. 7 ,::) ',iii', 1 ':.';'F~"'::' .....Zl. 4 ,':' t=;'?':::' 4,q. -,':I.()00 ,. ,::::'.'2 '.!ii;1 ,'_'::, .t. zl. ::ii:,':l. kl 1 ,'" ~"~"7 ':": -' . .... · .. ':::"J ':.:' .,:: .................... ..... ,, ... ~,:::, '"fi ?' ,, ,"1'::.'.' A L.. A :-.2; K A ANCHORAGE AL. ASKA C:OMF'I.J]'ATION DATE DATE OF F:URVEY ,.IANUARY 05, 1987 ...... I':::[.:.':t....L..Y BI...i:F:H.'[r',.IEi liii:l....li.:.':V. = 60. C)O I::::i". ........... ........ .... 0 F:' [:i: I::;; r'".'~ "1" 0 I::;; ..-. I'."1C t.':) I...I ]' F;: ]: N ' " '" .:: ..... F'.F; EVEN :l FEEl' ... TERFULATE. IJ VAI II 'Fl.-JR O0 CJF: :~;I...IB--L-.-;EA DEPTH D [!i: f::' "1" FI --- 60. ("~() (). ()0 0,, ()('-) C). C)9 N :t. (:' 0',, i:5'i5 I ' i')!i.-:i :20,:} ,, ()() 2 ,, C)'7 ':::,: ')(*'.', C) ;'] '":' '::;'":: ..... ~ ...... .,,:... . .. ............. 4. (.'.)0 ,, ()0 :}.':. 7',:i: N !5;()0.0() 4.91 lxl /:., 0 (). () () /.:,. ():'2: Iq 7 ()(),, ,'::: C:, ' i!),,' :iii: 0 F'I :3 ()':}. ()() '7 ,, 4 ,'.!:, N '200 ,, ,:} 0 7 ,, :ii!:9 l'.J !1. 00() 0O' "; .... . . ,:.,. 42 Iq 11 (:)0. (:~(") 8.74 r....I 12()(). ()0 5.77 iq :l. :':!: ci ('i ',: ('ii'"i !:ii: ,, 14.()C), (:!() J. 6 ,, 85 1 '=' ... ..... () (). () () :38. !:::; :L 'Ti; () ,, O. 2. :3. :'.'::, 02 E 2 :iii: 'ii:.: 7:3 Iii!' 4:3 Ii!i: :iii: 1 [ii: 44 E 52 .?.z E' O'i;.' E g ./.:, [...~: 66 E 0 ,, ()1 ,:::1 ,, :"i(", 0 ,, ()1 () ,, ~.': J ,::) ,, 0:2 (} ,, ,:} :1. (). 0:2: 0,. ()() (). ()::ii: (). 01 (). ()4 0 ,, () ,, 04 :') ,, ,:":, C: ,, C: 4 ' ,'}., ,'} () 0 ,, (') 4 C:,, i":, ........... () ,, 05 ()~ () () C~. 05 (). 0() () ,, ()7 () ,, 4 4 ,, 4 I{~1 ' ...... ,, :L '")':::' ... ,, :: ...., t,,,I 0 ,, "*: 7 · .... 7.7.5 N :1.. 7/ :L ';' :1.:3 W 4 '='"'" ARC:r_') F./L.A::;I.CA., I NC;:,, I "' '~'""., ., ,_,7 DF:tTE I:]F SLIRVEY ,_~NLIARY C._, :i.c':'=' F':r"iP1F'LITAT I ~qN D~'fE I:i F:' fi!; F;,' F."t 'T' C)F;~ '"'-I"i I.-: (';.~ L.I i. i::;..' . . I NTERF'OLATEI] VALUEE; FIZIR E'VIEN 10(:) FLEET OF L:.;UB-::;E:F4 DEF'I'H ..... · = = ....... i'"'i-~:'i ......... ::ii!;'.:iT1 31 .,...'"'~- ..1 i""l ~"). ., -...' 71..I. '? ,, :l. ~."-J. .... . I.'fi::'l,, ,r:", ,'"," ,'¢ ,:!:, ,, .,;..':' ..::,...., 21 ;",C:, ,.'".~,:') ::!!~O,'~1. '::"":' :!:!; :t/'~. ;i.,..." ..... ,' ...1 "." .':. '::' ,:"~ ":','"~ .'::,':' · ,,.., , ...... ~ .,' j:., , . . . .,- ,..., ~, · .... , .. . ,. ,. ~.. -"N "~' ,,' · ", ';::"7'~':,,:"~ ,'"',C) ..:, ,, ,.", .::, ,' '.!!!; '1. ""' ":" .':,,'7 W .I. "'"'"::' ,":',!::"; :;:!:;!', ~ ,"1. ......... ,i ...... , ~..' .-' ,~ .... -...,... ,L ..... ,, .~. 2 :":~ O O ,, O O 4. 5 ::9, 67. :iii; 2 C, 4. ,, C:, C) W t. 33,, '7 i ::i:: :i.., C:,'.'i:, 2400,,00 !:";:': :: O6, '.B :;2/I.:1. C)7W t,'.!:,,'.'.-:., ;'.:,6. :.~;:;::: '":'::"' '::'.'= (3(') (":,(-~, 61/.1. :1. J.'::: .... :'":?':::' ':"'=' W ';::'O 1 :1 :;;ir 34. .,':l ,':':., ............2/:', (":, i":, , (":,.. (-.',. ,...::,":::'...., .:::,'"" ::ii', 22 ,, (":, .... !:=;(.d :;2 :'.ii'. C:.-: ,, !=; .... ("~ .'ii: '7 ,. :iii:',:i: :2'70 :::, ,..] C:, 7' ¢i:i~ 4. ,, 5 i;:.' :i:!; ::ii: 6,'.:-:, ,, 3',iii: t.,.,t 2 '77' ,, ',!F~ C:, .? ':;.... !!:~ D :;;!:',!:!:C~ C), C:,C;, :;!!: '7' :1. ,, ::!!;:E', S 4. :1. :l. ,, i ,'.'~. l,.J ::ii: t '7 ,, ,'.!:,O :Ti.::'i;:.' ,, ~, ,, ,, . ..' ,~. , ,~ ... ,,.::~ ,..I ::.:.-:0, F) 0,, O(") i 0:':: 4 ""'"" ..... , ,, ..:,,=, :i;i; .':i.?:;:'!!~ ,, :dL.' W .-,,'-,,:=' '7 ...... :,,:,....,., :1. :;.3:;;i: :;;il,:::.', ::.:.': 100 ,, OO ;l. 1.1. :.=.:,, ';:?/.-'. :':i: '.= i ',!!!~ ,, .1. 4 W ,.1- .1. '7,,/-,',.:' 3 .'1 ,, ';;:: :1. :'.:'!: ::;i: C:, C) ,, C)':'~ 'I J. ?.':':i. ("):1. ~!:.'; '":'::' .... ':.fl-!=.'~;., ' .... ., ' '" ......... · ...,.... 4 ,, ~::::'::' I.,J :1. ::ii: 1 .':::..::: ,'",":,' :'::~:=~,:")(':, ,:':,,:":,17'7'7 .... 1 !iii; .::".:.':"-':t- .... q. 1,4 :;:::,'::i, :'":':":, .................. "'¥ , . ':::i' 4. E:7 ,, :,'::, 1 ..... I I',1 t NTERF, OLATEFI V(:.~L. LIES FL-U:.? EVIEN lOC, F:'EE"r OF SUB-'._:;EA DIEF'TH DF~TE OF '.:;;I._IF;:VEi:Y ,_.I(':~NLIF::~F;;Y ('-).~!;, i;.'.:l_-iI',] F'I..I'I" f'~ T Ii]iN D ~:'~ T E ...... :/.~'?',i~.ii-i?,,f-:,:'~.;" :1' :;?'i .... !1.-(:.;?.-5i'5'- .................................................... ,..lOB F. II..IN:01::!.'Fi' r"":l.:'::i.. }:-:~0---L.:70C, 02 1<tS.'~.:l._l..'Y' E;U:i:i;H]:F.!I3 E:I...F:'!'V, :::: 6,0.0,:)F::"T', .... 0 F:' F.:.'. F;t f::~ "F 0 F:.: ...-i".'1 l:::: C:i I. I ]' F::~ [ii: 4 1. ,:5i.'::, ,, 0 0 4 2 60, 0 0 4 :"-.'~ 6, O, 0 (': 4. 4. 60, O0 4 5 ,fi:, 0 ,, 0 (.'.'.~ ,":1. ,5 ,:50 ,, ()() 4 7,'.'.:, 0 ,, 0 0 4 L:i~,5, (), ()0 4. 9 6 0 ,, 0 0 I';."' ~ ;' '"' :.,O,.: ~.~, ()0 !516, 0 ,, 0 () !:.5 :;ii: ,.5 0 ,. ()0 5:36 0 ,, 0 0 i::: 9 ('~,:"i, c:, O 177 :iii: .... '~::' ............ ,, ,:" ..... :.:ii; ~iii~:2 ()., 4 ::;ir 1,4 4 ':.'.:'0 () ,. (.:' () :I. ~.:.'!'.,'.'!:, :2 ,, '.-5':;;!: :!!i; ::::: F:i 9 ,, ::i!~'7 1.4 4 ]. ,::)C,., 0 ,:') 15:,' 4 '7 ,, :1. 'ii:.' :ii!, :3'i;;' ',ii:',,, :2 '7 4 2 ()() ,. () O 2('.:,.. !:iii 2 ',, .,.'::, .... 9 :iii; '.:.':' 37 ,, "",;:. ,:,'"' 4:3(':,(),, ,:'~,c>.. :2 :[ :1. 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'.::; F:' F': F::~t:;."Y'-.-.:F:I...tI\I [..J [ii: l... i .... :!i!: i,. ll::;: V l~]: "¢ ]' I',IG CL-.IP'iF:'(:,~hlY jL:.';:)J".iF:i' 9 ANC:HORAGE ALASKA ",il I "" /' DATE.. I']F '.~!~I_IF,,vE-~ ,..IANI_I~Y. ~,)._,"'=, 1'.:'./87 = C:OHPUTATTON D~TE .... IANI...IARY '1. :21-, .1. Q:~',7 ,..lOB I",.IUt'"iBI~'R '?'i'ti:.'i'7]~:i.'.:f.'. .... '7()C.~C)2 ... ............. t< E L_ L '"," B L!'.i.:.': H i11 i",i C liii L_ I:':i ',,...' ,.,.. = ... (.'.:., !~!..,, ,.5)() F::' '1: ....... '~ . ~"~ F::' [::' '::~ ~'."'~ "1" r"t F:.' ...- M C (3 I...J ]' j:~ I::il ..:~2.__:L ............ : .... ~ ......... : ................................ ,,.,,,_~..:., ,-:.~ . INTERPOLATED VAL_.UE:!::; F:OR EVEN :L()O F'I.:.EE'I" (iF SUB-SE;A DEF'"I'H "l"l-"lliii7 CAI....f.'.:UL..A'T'ION PRCff';:EI]URES L.ILz.;E: A L..INE;AF:~ I hI"I"I~!:F::.:F:'(}I.A'T'T(]N BET'WE:.EI',I "J'HI'}" I',IE:AF:;:Ei;ST 20 F'OO'T' ME) (F::'ROM RADIU'.!!i; (iF:' CUF:;,'VA'T'UF';:I!:i:) POINTS ?.'i; l::' ti:!; F:;: F;; 'r".---'.31...ll,.l t.,..ii!:i;l..I .... :!i;;I...ll::::'v'E':'Y' INF.! C()I"IF:'ANY' I:::'('.~(}IE 1 C) A N C H 0 R A El E A L A S K A DATE ~'"~F' ...... SLIRVEY IANIIARY 0.=;., 1':"':'7...,_, F: 0 MI::'I..I'f'A T II]IN Ti A T E ............................................................................................................................... ,..I('~NLIAF4~Y'' ].2, ].5;':!!i:7 .... lO.F:) I".ll...IJ"'l'_f::~li;;;t::;; I'::: ~: L.. [... "," .B.' I...I 53 H [ PIG 13:J I... I:i': L.;. .:= 6 ('_'), (-':, C:, I::' "J", ..... (') ~::" [ii' J;:;,' ("./"1" ('1 j:;(] ..~-J"'J (:.' (::~ I...I :[ }:;: !~:' ..................................... · ~'"'T', ........................... ' ..... ." INTERPOL. ATED VAI ...... lIES F:'OR SF'ECIAI... ::'-':I_IRVEi;Y F'OIN'FS 1'"'1A F:;: I< IE 6 2:34.4 1 624 :."3.4 0 ("-, 2 4 3 ,, 4 () ,":.,.7 :'::: "7 ,, :J. 4 6 501 ,, 9 ('-., .... ' ...... ' 44. ,17 '" ",,:L ,, I -2eeC. CC -LOSC. 2C / .,'7 ? .. :- · /; : / : --2CC2. 35 - -,! } :2:2. [, -L RECEIVED --c..23. }C. · . · FEB - 9 1987 Alaska Oil & Gas Cons. Commission Anchorage -! BECEIVED FEB- 9 1987 Alaska Oil & Gas Cons. Commission Anchorage .6000,00 [ -- i ARCO Alaska, lnc Post Office- _,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 9, 1987 Transmittal # 5909 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL Finals: 3Q-13 1-9-87 6162-8074 3Q-14 1-9-87 6416-8392 3Q-11 1-9-87 5158-7127 3Q-9 1-8-87 7113-7760 3Q-12 1-9-87 5127-7284 3Q-10 1-8-87 5418-8240 Receipt Acknowledged' DISTRIBUTION' BPAE Chevron (+ sepia) Unocal (+ sepia) NSK L. Johnston Mobil (+ sepia) SAPC (+ sepia) Drilling State of Alaska (+ sepia) ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCornpany STATE OF ALASKA ALAS~ _..-OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS · Operations performed: Operation shutdown ,~. Stimulate [] Plugging [] COHPLETE Alter Casing [] Other I~ Perforate [] Pull tubing [] 2. Nam~e ~of Operator ~Cu Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 2283' FNL, 2037' FEL, Sec.17, T13N, RgE, UH At top of productive interval 716' FNL, 1734' FWL, Sec. 20, T13N, RgE, UN At effective depth 937' FNL, 1653' FWL, 5ec.20, T13N, R9E, UN At total depth 1003' FNL, 1629' FWL, Sec.20, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 60 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 30-13 8. Approval number 7-21 9. APl number 50-- 029-21664 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8190'MD 6582 ' TVD 8083 ' MD 6502 ' TVD Casing Length Size Conductor 80 ' 1 6" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 1875# Pol eset 115'HD True Vertical depth 115'TVD Surface 4288 ' 9-5/8" Producti on 8135 ' 7" 1200 sx AS III & 4325'MD 3713'TVD 300 sx Class G 300 sx Class G & 8169'MD 6566'TVD 175 sx AS I Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ¢ 7661' Packers and SSSV (type and measured depth) HRP-I-SP pkr (~ 7630' & FVL S55V (~ 1790' 12. Stimulation or cement squeeze summary N/A Interva s treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Wel 1 Hi s__~ry) Daily Report of Well Operations LA Copies of Logs and Surveys Run ~ GYRO 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ /-- Signed --orm 10-404 Rev. 12-1-85 Title Associate Engineer (DANI) SW02/O01 Date -2-z 7 Submit in Duplicat~ ,.;O Oil and Gas Company Daily Well History-Final Report .nstructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting Ihe entire operation if space is available. District Field Alaska ICounty or Parish Lease or Unit Title North Slope Borough Accounting State cost center code Alaska Kuparuk River ADL 25512 JWell no. 3Q-13 Auth, or W.O. no. AFE AK1673 Nordic #1 Operator ARcO Alaska, Inc. Spudded or W.O. begun Complete 1/16/87 1/17/87 thru 1/19/87 Completion API 50-029-21665 A.R.Co. W.I. 56.24% Date 1/16/87 Date and depth as of 8:00 a.m. Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our J Prior status if a W.O. I 0515 hrs. 7" @ 8169' 8083' PBTD, NU BOPE 10.0 ppg Brine Accept rig @ 0515 hrs, 1/16/87. ND tree, NU BOPE. 7" @ 8169' 8083' PBTD, RR 6.8 ppg Diesel NU & tst BOPE to 3000 psi. Rn 237 its, 2-7/8", 6.5#, L-80 EUE 8RD AB-Mod tbg w/SSSV @ 1790', TT @ 7661'. Set pkr, tst tbg to 2500 psi & SSSV @ 1000 psi. ND BOPE. NU & tst tree to 250/5000 psi. Displ well w/diesel. Pkr set 500' high. Displ diesel w/brine. ND tree, pull 2-7/8" tbg, pull & chg out pkr. Re-rn 2-7/8" tbg, set pkr @ 7630' & tst to 2500 psi. Tst tbg & ann to 2500 psi. Tst SSSV @ 1000 psi. ND BOPE, NU & tst tree to 250/5000 psi. Displ well w/diesel. RR @ 1645 hrs, 1/18/87. Old TD J New TD J PB Depth Released rig J Date J Kind of rig 1645 hrs. J 1/18/87 Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc,) Single 8083' PBTD Rotary Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 20, 1987 Transmittal # 5892 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals: (1 blueline unless otherwise specified) 3Q-15 2" & 5" FDC Porosity 11-25-86 5900-7402 2" & 5" FDC Raw 11-25-86 5900-7402 ~~ 2" ~ 5" DIL 11-25-86 3850-7428 --------------" Cybe~look 11-25~86 6950-7400 3Q-13 2" & 5" FDC Porosity 12-9-86 6500-8146 2" & 5" FDC Raw 12-9-86 6500-8146 O ~ 2'~& 5" DIL 12-9-86 4323-8172 ~ Cyberlook 12-9-86 7500-8100 3Q-14 2" & 5" FDC Raw 12-3-86 6850-8472 2" & 5" FDC Porosity 12-3-86 6850-8472 2" & 5" DIL 12-3-86 1000-8498 Cy. berlook 12-3-86 6900-8400 · Receipt Acknowledged: DISTRIBUTION: NSK Drilling L. Johnston (vendor Pkg) Gas Cons. Oommission ka Oil & Anchorage Date: Rathmell D&M Vault (film) ARCO Alaska, Inc, is a Subsidiary of AllanlicRichlleldCompany STATE OF ALASKA ALASK,-. .)IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown/~ Re-enter suspended well -- Alter casing -- Time extension ;- Change approved program ~ Plugging ~ Stimulate :- Pull tubing- Amend order- Perforate- Other - 2. Name of Operator APPrl &l~[,~ Trot, 3. Address P. O. Box lO03Rfl Anrhnrag¢; aK 99~!0-03_~0 4. Location of well at surface 2283' FNL, 2038' FEL, Sec.17, T13N, RgE, UM At top of productive interval 781' FNL, 1880' FWL, Sec.20, T13N, R9E, UM (approx.) At effective depth 958' FNL, 1821' FWL, Sec.20, T13N, RgE, UM (approx.) At total depth 1026' FNL, 1800' FWL, Sec.20, T13N, RgE, UM (approx.) 5. Datum elevation (DF or KB) RKB 60 6. Unit or Property name feet K~J,naruk River Ilnit 7. Well number 3Q-13 8. Permit number 86-176 9. APl number 50-- 029-21664 10. Pool Kbparuk River 0il Pool 11. Present well condition summary Total depth: measured 8190 'MD feet true vertical 6603 'TVD feet 8083 'MD Effective depth: measured 6523 'TVD feet true vertical feet Casing Length Size Conductor 80' 16" Surface 4288' 9-5/8" Producti on 8135' 7" Plugs (measured) None Junk (measured) None Cemented Measured depth Conductor Report 115'MD not received 1200 sx AS III & 4325'MD 300 sx Class G 300 sx Class G 8169'MD True Vertical depth 115' TVD 3728'TVD 6587'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured dep[~(:~rle 12.Attachments Description summary of proposal Well Hi story 13. Estimated date for commencing operation January, 1987 Detailed operations program BOP sketch --' 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~~ ~./,~ Title Associate Engineer Commission Use Only Date (DAM) SA/191 Conditions of approval Notify commission so representative may witness -- Plug integrity Approved by Form 10-403 Rev 12~-{-85 J Approval No. / BOP Test - Location clearance ~'-- '"'~,,.-.~ ,:-- / -/~ ~;~,, by order of Commissioner the commission Date /"-/',~---~"'/ Submit in triplicate I State North Slope Borough Alaska Field ':: Lease or Unit Well no. Kuparuk. River ADL 25512 3Q-13 Auth. or W.O. no; ~Title AFE AK1673 I Drill Doy°n 9 API 50-029-21664 Operator_ ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDat, IHour SpUdded 12/4/86 2200 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 12/05/86 IARCO W,I. Prior status if a W.O. 1'2/06/86 thru 12/08/86 12/09/86 16" @ 1 1248', Wt. 9.5 Accept 12/4/86 15' (1133'), Drlg , PV 14, YP 30, PH 8.0, WL 16.4, Sol 8 rig @ 2000 hrs, 12/4/86. NU diverter. . Drl to 1248'. Spud well @ 2200 hrs, 9-5/8" @ 4325' 7027', (5779'), Drlg Wt. 9.2, PV 5, YP 4, PH 9.5, WL 10.8, Sol 6 Drl & surv 12¼" hole to 4340', short trip, C&C, POH. RU & rn 109 jts, 9-5/8", J-55 36#, BTC csg w/FC @ 4238', FS @ 4325'. Cmt w/1200 sx AS III & 300 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. RIH, DO cmt & flt equip + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 7027'. 461', 1.1°, N51.9E, 460.98 TVD, - 3.75VS, 2.73N, 3.43E 1318', 3.8°, S25.7W, 1317.85 TVD, - 6.20 VS, 1.39N, 14.43E 1794', 21.8°, S24.6W, 1780.25 TVD, 99.71VS, 96.16S, 27.29W 3813', 42.8°, S25.2W, 3350.97 TVD, 1348.52 VS, 1242.10S, 530.92W 4280', 42.2°, S26.5W, 3695.28 TVD, 1663.42 VS, 1531.76S, 655.98W 4785', 42.7°, S22.2W, 4067.90 TVD, 2004.05 VS, 1848.12S, 782.84W 6454', 42.1°, S15.6W, 5311.34 TVD, 3115.20 VS, 2911.84S, 1108.57W 9-5/8" @ 4325' 8190', (1163'), Drlg Wt. 10.0, PV 14, YP 8, PH 9.5, WL 4.8, Sol 11 Drl & surv 8½" hole to 8190', short trip to 4300'. 7015', 42.0, S17.4W, 5728.12TVD, 3490.32VS, 3272.11S, 1215.29W 7580', 42.2, S15.8W, 6147.34TVD, 3868.51VS, 3635.11S, 1323.51W 8190', 41.2, S18.3W, 6602.79TVD, 4273.83VS, 4023.07S, 1442.49W The above is correct For form prepi~rat~n an'~'distrib~, see Procedure'~,,Manual, Section 10, Drilling, Pages 86 and 87. Date . · JTitle Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Reporl" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Spudded or W.O. begun Spudded Accounting cost center code District County or Parish State Alaska Alaska North Slope Borough Field Lease or Unit I Well no. Kuparuk River ADL 25512 [ 3Q-13 Auth. or W.O. no. T t e AFE AK1673 Drill Doyon 9 API 50-029-21664 Operator A.R.Co. W.I. rrotal number of wells (active or inactive) on this~ Icost center prior to plugging and I .&ECO AlasEa, Thc. 56.24Z Jabandonment of this well Date IHour I Prlor status if a W.O. 12/4/86 ! 2200 hrs. I Complete record for each day reported 12/lo/86 Date and depth as of 8:00 a.m. 12/11/86 9-5/8" @ 4325' 8190', (0'), RIH W/7" csg Wt. 10.1, PV 15, YP 9, PH 9.0, WL 4.4, Sol 11 Short trip, CUC, POH f/logs. RU Schl, rn DIL/GR/SP/SFL/CAL f/8180'-4325', cont w/GR to 1000'. Rn FDC/CNL f/8180'-7200' & 6800'-6500', RD Schl. RU & RIH w/7" csg. 7" @ 8169' 8190' TD, 8083' PBTD, RR 10.0 ppg NaC1/NaBr Rn 196 + 1 mkr jr, 7", 26#, J-55 BTC csg w/FC @ 8084', FS @ 8169'. Cmt w/100 sx 50/50 Pozz & 200 sx C1 "G". Displ w/brine, bump plug. ND BOPE, instl &tst packoff. RR @ 1800 hrs, 12/10/86. Old TD New TD Released rig Date 1800 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 8190' TD PB Depth IK nd of rg 12/10/86 I Type completion (single, dual, etc.) S±ngle Official reservoir name(s) Kuparuk Sands 8083' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production O[I on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The ~,b~e is correct For form prepar i~o and distribution,(''-'~ see Procedures M~nual, Section 10, Tit', Drilling, Pages 86 and 87. Drilling Supervisor ARCO AlasKa, inc. ~ ~ Post Office ~ 100360 Anchorage. AiasKa ,o9,510-0360 Teiephone 907 276 1215 RETURN TO: ARCO ~_LASKA, INC. ATT~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 ~nchoraoe AK 99510-0360 Transmitted herewith are the following items. retu~n one signed copy of this transmittal. DATE December 23, 1986 TR3~NSMiTTAL # 5860 Please acknowledge receipt and 3Q-14 OH LIS /ape + Listing ~72100 12-3-86 3Q-!3 OH LIS Tape + Listing #72114 12-9-86 30-12 OH LIS Tape + Listing J'~ ,. ~.'/~z~ 12-14-86 Receiot Acknowledged'.' Distribution: Wethere!! State of Alaska .. ARCO &lask~. Inc. ~s a Sub$:(3zer¥ of Al ertl cR c~f · ~Compem? ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3Q Pad (Wells 1-16) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/dmr GRU1/44 Enclosure If ARCO Alaska, Inc, is a Subsidiary of AtlanlicRichfi,,IdCompany 8 9 17 16 VICINITY ~ $CAi. E s I" · 2 Mil. El ALL WELLS LOCATED IN SEC. 17, TISN, R9E, UMIAT MERIDIAN. 6,025,875.2:5 6,025,867.50 6,025,861.28 6,025,855.29 6,025,849.:56 6,025,843.37 6,025,837.44 6,025,851.45 6,025, 815.50 6,025, 807.25 6,025,801. :51 6,025, 795.53 6,025, 789.:51 6,025, ?85.4? 6,025, 77'7.44 6,025, 771.55 515, 959.92 515, 984.20 516,008.42 516,0~2 516,056.99 516,081.28 516,105.64 516,129.72 516,202.58 516,226.82 516,251.42 516, 275. 516,299.52 516, ;325.80 516,372 .$1 LATITUDE 70o 2 8' 54.75B" 70° 2 8' 54.'/'01" 70° 28' 54.639" 7O° 28' 54.5,80" ?O0 2e' 54.52 ~" ?O0 28' 54.462" 7O0 2e' 54.40~" ?O0 2e' 54. 7O0 28' 54. 165" ?O0 28' 54. ?O0 2e' 54.044" 7O° 28' 5:5.987" 7O0 26' 55.925" ?O0 aB' ~55.8~?" ~70o 28' 53.600" ?O0 28' 53.749" NOT[S: I. ALL C(X)RI~AT~$ AI~ A.S.R, ZONE 4. 2.AL.L DIgTANCLr~ ~ AI~ TRI,~. :5.ELEVATIONS ~ B.P. 4.1~F. FIELD BOOK LI4-1&, liable 21-22. 5.0. G. ELEVATIONS FROM F. R. B~LL & 6.HORIZONTAl. POglTION~ BASED ON ~Q C(~~ !'r~[..~ ~l, fT'S PER LHD 149°52' ~0.5~2" 149o 5E 09.798'' 149° 52' 09 149° 52'08. :576" 149e 52'07.6 58" ~4~ 52'06.944" 14~ ~' 06.220" ~4~' ~.'o5. ~.o" 14~e ~'~ .665" 14~ 52'01.94~" I~ 52'01.2~" I~'~. 52~" 14~ 51' ~, 614 14~ 51' 58. DI$t. EN.L. 2199' 2205' 2211' 2217' 222:5' 2229' 223~' 2241' 2259' 2285' 227'1' 227'?' 228:5' 22e~' 2301' 2~2' 2:504' 22eo' 2255' 2231' 22o7' 21~4' 2110' 2085' 2062' 2037' 2o~' 19~5' I?.1 17'.1 17.1 17.2 17.2 17'.:5 17.3 17.4 17.5 17.$ 17'.5 17.5 17.5 17.5 21.? 21.? 21 .S 21.0 22,0 22.0 22.0 21.9 21.9 21.8 21.9 21,0 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ANO LICENSED TO PRAC- TICE LANO SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY Mi[ OR UNDER MY SUP[RVISION, AND THAT ALL DIMENSIONS ANO OTHER DETAILS ARE CORRECT AS OF 11/2/86. d~, '. *************************** · w.,,,f;;,~....'..: .~. :...,:. · · · · % '~'~':........ ARCO Alaska Inc. D.S.$Q W~LL CONDUCTOR ASlKIILT ~ BY' AJR J CNK ~Y, JWT , DATE, II/lO/N [ NSK 6. 317-d3 November 4, 1986 Telecopy: (907) 276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inco P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: 3Q-i3 ARCO Alaska, Inc. Permit No. 86-176 Sur. Loc. 2283'FNL, 2038'FEL, Sec. 17, T13N, R9E, UM. Btm~-hole Loc. 1042'F~, !786'FWL, Sec. 20, T13N, R9E, U~.~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The'permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other goverp~enta! agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Con~nission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~qhere a diverter system is required, please also notify this office~4 hours prior to commencing equipment installation so that the Comanission may witness testing bezor~ drilling below the shoe of the conductor pipe ..~-'-5~) tr.~-~o~s. C, V. Chatterton Chai~an of Alaska Oil and Gas Conservation Co~ission BY O~ER OF THE CO~-R~%ISSiON jo Enclosure cc: Department of Fish & Game, Habitat Section. w/o encl. Department of Enviro,n~ental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C~ IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~. Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test Q Development Oil Re-Entry ~ DeepenI~I Service [] Developement Gas ~ Single Zone ,~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 60' , PAD 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0il Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2283'FNL, 2038'FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .tuber Number 781'FNL, 1880'FWL, Sec.20~ T13N, R9E, UM 3Q-13 #8088-26-27 At total depth 9. Approximate spud date Amount 1042'FNL, 1786'FWL, Sec.20, T13N, R9E, UM 11/24/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) proPerty line 81 87 'MD 20:B8' ~ surface feet 3Q-14 25' @ surfacefeetl 2560 (6572'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth1 200 feet Maximum hole angle43 0 Maximum surface 221 7 psig At total depth (-rVD) 3250 psig 18. Casing program Setting Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 17-1/~"9-.5/fl" 7% G. ¢)¢ .t-SR RT(' &?R7' ~' ~' ~9' ~T&n, !200 HF-ERW 300 .~x Cln.~.% C, hl~_nrI 8-1/2" 7" i26.0# J-55 BTC 8153' 34' 34' 8187' 6.572' 200 sx Class Gfminimum HF-ERW TOC 5C0' abov( top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented ,¢ Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate OCT 2 9 1986 Production Liner Alaska 0il & Gas Cons. Perforation depth: measured Anchorage true vertical 20. Attachments Filin~ fee ~ Property plat ~ BOP Sketch "~ Diverter Sketch ,~. Drilling program Drilling fluid program .~. Timevs depth plot ~ Refraction analysis _~ Seabed report ~ 20AAC25.050 requirements 21. I hereby cer/t~y that the foregp~.og is true and correct to the best of my knowledge , / %" F., ~ Title Regional Drilling Engineer S,gned ,/ ~ ?,/.~/~.~.,~'r,,~¢,t,/ Date i~"' ¢' U / ~" '~ Commission Use Only ( HRE ) PD/009 Permit Number I APl number I Approval date I See cover letter ,~ (¢-'~ ~/.F~. [ 50-- O~;~ -...~ ..,/ (,_~ ~, ~[- ~ I 1 1 / 0~ / 86I for other requirements Conditions of approval Samples required [] Yes ".~,No Mud Icg required ~ Yes "',~.~.No Hydrogen sulfide measures Q Yes [] No D. ir,,ectional,survey required ~,,~Yes ~ No" Required workingpr~cc.~sure~or~ ~,~M~, ~!~f, 3M; ¢q,'5M; [] 10M; C 15M Other: //"'7// //'/~ /~/~ ~ by order of Approved by ( ~" ./, k.~~'' _~~ Commissioner the commission Date Form 10-401R6~:--I¢1-85 triplicate T/ ZONE A i TVD-6325 1'~=7851 DI~_P=4064 ....... TARGET CNTR ---TYD~B3T~ THD=T§i 9 i~11--- a,~?,aOil& GasCons. ,,,~mmission B./ KUP SNDt~ TVD=6425 THD=798?'DEP=4157 .Rn,..,horage I'D (LOG PT) TVD=6572 Tt'ID=8187 :DEP-4293 ZOO0 i i , , I" 0 .1 000 2000 ;~000 4000 $000 .... ~ ............. VERTt CAt.--- SECT ION .... : J d ~ooo: - .... ~ .... Oll-~s Cons. TD LOC~Tt'I~. 1042' FILL. ITNI~' FIdl. SEC. 20. T13N. ROE : S t9 DEl3 49 I'IIN W 411:1' (TO T. ARGET) . - _ . - I -I -t -- t · t / \ ' : / ~1590 ...... ¥ / ,, "~1- 8.~ ...... / -- r /~ ........ ~- ..... ~ ........ t ........ l' ~ ...... L ........................... r ~--: ................ ~ ~ / - t , ..... ~~' t- / .... I ~ ~ 1 ..... : 2300 2200 21 O0 2000 ,1 900. 1 800 1 700 . -[ -- 4-- _ . , -~Oo f - · . _ 27 OCL KUPARUK R I VER UN I T 20" ID I VERTER SCHEMAT I C 8 DE SC R I PT I ON 1, 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. $. 20" 2000 PSI DRILLINg SPOOL N/lO' OUTLETS. 7. 10" HCR BALL VALVES N/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. . ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 035 (b) MA I NTENANCE & OPERAT I ON 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLON A I R THROUGH D I VERTER L I NES EVERY !2 HOURS. S ~.~~,ss~ ~ ~T SHUT IN HEL~ , ~~~ ~,- UNDER ANY CIRCUMSTANCES. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF HELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNNIND DIVERSION. SI 0084002 RI( 6 5 4 2 I iL_ DIAGRAM #1 13-5/8" ~O00 PSI RSRRA BOP STACK I. 16" - 2000 PSI TAhi<~ STARTING HEAD 2. 11" - 5000 PSI CASING HEAD 5. I1" - 5000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 15--5/8' - 5000 PSI DRILLING SPOOL W/CHOKE /~ KILL LIr~ES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE RAMS ON TOP, BLIhD R/~ ON BOTTC~. '7. 1 3-5/8" - 5000 PSI Ah~ AC~LATOR CAPACITY TEST i. CHECK A~ FILL ACCUIV~TDR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACC~TOR PRESSURE IS 5000 PSI WITH 1500 PSI DOWNST~ OF THE REGULATOR. 5. CENSERVE TINE. THEN CLOSE ALL UNITS SINIJLTAh~OUSLY AhD RECORD THE TINE AhD PRESSURE RE~INING AFTER ALL UNITS ARE CLOSED WITH CHARGING Pl~ OFF. 4. RECORD ON NADC REPORT, THE ACCEPT~ LC~ LIMIT IS 45 SEC~ CLOSING TINE AhD I PO0 PSI RE~INING PRESSURE. 13-5/8" BOP STACK TEST I. FILL BOP STACK AhD Q-K]KE MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK D(TA~ SCREY~ IN I~EJ_U-EAD ARE FULLY RETRACTED. SEAT TEST PLUG IN Y~E]_U-EAD WITH RUNNING JT AbE) RUN IN LOCK~ SCREWS. 5. CLOSE A~AR PREVENTER A~ MANUAL KILL AhD CHOKE LIh~ VALVES ADJACENT TO BOP STACK, ALL OTHER VALVES AhD CHOKES ~ BE OPEN. 4. PRESSL~ UP TO 250 PSI AhD HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI AbE) HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN Ah~ PREVENTER AbE) MANUAL KILL AhD CHOKE LIhE VALVES. CLOSE TOP PIPE RAIV~ AhD HCR VALVES ON KILL AhD CHOKE LI~ES. 6. TEST TO 250 PSI A~ 5000 PSI AS IN STEP 4. '7. CONTINUE TESTING ALL VALVES, LIh~S, AhD CHOKES WITH A 250 PSI LO~ AhD 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS T A FULL (~.OSING POSITIVE SEAL CHOKE. O~Y NCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AI~ CLOSE BOTTC~ PIPE TEST BOTTOM PIPE RA~ TO 250 PSI AND 5000 PSI. 9. OPEN BOTTOM PIPE RAMS, BACK OUT RUbbING JT AhD PULL OUT OF HOLE. I0. CLOSE BLINO RA~S ANO TEST TO 250 PSI AhD 5000 PSI. II. OPEN BLIhD RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AbE) LI~S ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAhDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, ANO INSIDE BOP TO 250 PSI AhD 5000 PSI. 15. RECORD TEST I~ORf4~TION ON BLOWOUT PREVENTER TEST FOR~, SIGN, AhD SEhD TO DRILLING SUPERVISOR. 14. PERFORlVl CGVPLETE BOPE TEST AFTER NIPPLING UP AhD WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15, 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS- DEC~SSER l' STIR ~e--~. STIR i~UD ~LEANER STIR TYPICAL I'IUD SYSTEM $CHEI"IATIC LWK4/ih CHECK LIST FOR NEW WFT.I, PFZRMITS ITEl4 ~OVE DATE (2 '~ 8) (3) Adnzin 1. Is the permit fee attached .......................................... (4) Casg ~/~ 3/ (14 thrh' 22) 2. 3. 4. 5. 6 7 (9 th~ 13).~1" ' 10. d i3~ ~ 12. 13. (5) BOPE (~3 thTM 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. ~/n For (6) OTHER /F,/-/, 29. (29 thru 31) 30. 31. Company A~ [ 0 ~~ .F-~t... Lease & YES Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distm~ce from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is w~llbore plat included .... Is operator the only affected party .................... Can permit be approved before fifteen-day wait ......... Does operator have a bond in force .................................. Is a conservation order needed ' Is administrative approval needed .................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cemmlt cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are d~ta presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ Additional requirements ............................................. Geology: Engineering: rev: 07/18/86 . 6.011 POOL 'f~ Ol OO INITIAL CLASS STATUS GEO. AREA ~O UNIT NO. ON/OF~ SHORE Well No. NO , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' No special'effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING ,¥P OlO.d02 V~F!OAT!ON LISTING PaGE 1 ERVICE NaME :~DIT AT5:8,5/12/15 RiGiN : 55L NAqE :7211~ QNTiNU~TION ~ :01 R:¥1GUS REEL : OMMENTS :LIS TAP=, ARCg KUP~RUK. 3Q-13, $oi 50-029-21664 -';:: TAP"',_ H=~,D~R_ ~ ...... -,--,- i~RVIC~_ NAME ''-gIT,~ )ATE :86/12/15 ]RIGi~ :F$'IA 'APE N~ME : ]ONTINU~T!ON ~ :Ol ;RE¥1OUS TAPE : )OMMENTS :LIS T~PE~ ;-'~'~ FILE HEADER :;:~',~ :~LE NAME :EDIT .001 ~ERViCE NAME : iERSION ~ : )~T E : '~X!MUM LENGTH : 102a :iLE TYPE )REVIOUS FILE INFORMATION RECORDS -, .... qNEM CONTEN'TS UNIT TYPE CATE SIZE COOE CN : ARCO ALASK&, iNC. 000 000 018 065 JN : 3Q'-13 000 0,00 006 065 :N : KUP.aRUK 000 000 008 065 ~ANG: 9E 000 000 002 065 TOWN: 13N O,OO 000 004 065 SECT: 17 000 DO0 002 065 COUN: NOR'TH SLOPE 000 000 012 065 STAT: ~LASKa 000 000 006 065 CTRY: US.a 000 000 003 06.5 MNEM C8NTENTS UNIT TYPc- CATE SIZE CCDE V? OlO.H02 VSRiF!CaTION LISTING PAgE 2 ~5 NUMBER AT &KCC: 721i~ UN ~1, D4TE LOGGED: 09-DEC-a5 ,DP: RICK KRUWELL &SING : 9.625" @ 4325' - BIT SIZE : 8.5" TD 8190' 'YPE FLUID : WEIGHTED POLYMER 'ENSITY = I0.1 LB/G RM : 3.53 @ 68 'DF 'iSC"SITY~ : 40 S RMF = 3.~8 @ 68 DF 'H = 9.5 RMC : 2.35 ~ 68 OF 'LUZD LOSS = 4.6 C3 RM ~T BHT = 1.73 ~ 146 OF [ATRZX S&NDSTDNE .-,--,--, .... THIS DATA H~S NOT BEEN DE~'TH SHi~T= OV RLAYS FiEL~ PRINTS-,:-,--~-,.-,- V2 OIO.H02 VERIFiC~Ti,ON LiSTInG ?'aG2 3 SCHLUI.16ERGER LOC-S !NCLUO$S WITH T'~qiS MAGNETIC TAPE: ~;: DUAL INDUCTZGN SPHERICALLY FgCUS~C LOG (CZL) ~,~ "' O.~T~ AVAZ~' AELE: 81~2' TC 432~' ~;~ :'JRMATiON DENSITY CO~qPENSATED LGG (FDN) ~:~ .,. C~MPENSATED NEUTRON LDG (FDN) ~',~ D~TA AVAILABLE: 8146' TO 4324' :',~ GAMiqA R~Y !N CASING (GR.CSG) ~:= DATA AVAILABLE: ~324' TO 992' ~',~ DAT.& FSRM&T RECCRD ;;'-~;= !NTRY BLOCKS TYPE SIZE REPR CBDE ~NTRY 2 1 56 0 4 1 66 1 8 4 73 60 9 4 ~5 .lin 16 1 66 I 0 t 6 ~ 0 DATUM SPECIFICATION BLOCKS qNEM SERVICE SERVICE UNI'T APl AP1 API API FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOO NO. C~DE (OCTAL) )EPT FT O0 000 O0 0 0 4 ! 68 OOOO0000000000 ~FLU OiL DHMM O0 220 01 0 0 4 i 68 00000000000000 [LO DIL OHM~ O0 120 46 0 0 4 1 6:B, 0~0000000000080 [LM DiL OHMM O0 120 44 0 0 4 1 68 00000000000000 ~P DIL MV O0 010 Oi 0 0 4 1 68 00000000000000 .VP 010.H02 VERIFiCATIJN LISTING PAG: 4 ;R glL GAPI O0 'EN3 DiL L5 O0 iR FDN GAPi O0 ;aL1 F~N IN O0 :HgB ~gN G/C3 O0 )RHC FDN G/C3 O0 JRAT FDN O0 :NRA FDN O0 ~PHi FDN PU O0 )PHI ~DN PU O0 iCNL FDN CPS O0 :CNL ~DN CPS O0 'ENS FDN L5 O0 ;R CSG GAPZ O0 'ENS CSG La O0 31 63 28 35 35 O0 $9 33 33 63 31 63 )EPT 8213.0000 SFLU ~P -15.5000 GR :ALi 9.0547 RHGB ~NRA 3.2353 NPHi :CNL E87.0000 TENS )EPT 8200.0000 SFLU ;P -16.5000 GR ;ALI 9.0547 RHO5 ~NRA 3.2363 NPHI :CNL 587.0000 TENS )EPT 8100.0000 SFLU ~P -25.4531 GR :ALI 9.0781 RHO5 ~NRA 3.4863 NPHI :CNL 53,2.0000 TENS )EPT ~000.0000 SFLU ~P -24.0000 GR :ALI 8.5703 RHOB ~NRA 3.0098 N:PHI :CNL 717.5000 TENS DEPT 7900. 0000 SFLU SP -31.9844 G'R :ALI 8.7813 Rd08 ~NRA 3.3125 NPHI =CNL 597. 0000 TENS DEPT 7~00.0000 SFLU SP -45.0000 GR :ALI 8.5073 RH06 RNRA 2.9746 NPHI =CNL 949.5000 TENS . 123. 2. 35. 1185. . 123. 2. 35. 2830. 104. 2. 39. 4504. .. 100. 2. 33. 4412. 102. 2. 39. 4468. 36. 62, 2- 30. 4104. 0395 1875 4570 1562 0000 0364 1875 4~70 1562 0000 3239 5000 4688 6484 0000 2234 5000 4590 3,496 0000 4633 2500 4434 3555 0000 0039 1875 3320 5176 0000 O! 21 O1 O1 02 O1 Cl O0 O0 O0 31 3O 21 Oi 21 ILO TENS DRHO DPHI GR ILO TENS DRH'O DPHI GR ILD TENS DRHO DPHI GR tLD TENS DPHI GR ILD TENS DRHD C:PHi GR !LD TENS DRHO DPHI GR ! 68 JO000000000000 1 58 00000000300030 i 68 00000000000000 I 68 O0000000OO00OC 1 68 00000000000000 1 58 O00CO000000000 1 68 00000000000300 1 68 00000000000000 i 58 OOO00000000000 i 68 00300000000000 1 68 O000000000OO00 1 6~ O000000000000C i 68 O0000000OO0000 1 68 O000000000000O 1 68 00000000000000 2.7197 ILM !185.0000 GR 0.2285 NRAT 11.6699 NCNL -999.2500 TENS 2.7197 ILM 2830.0000 GR 0.2285 NRAT 11.6.599 NCNL -999.2500 TENS 2.5790 ILM 4504.0000 GR 0.0757 NRA'T 10.9375 NCNL -999.2500 TENS .2.9044 ILM 4412.0000 GR 0.0303 NRAT 11.4746 NCNL -999.2500 TENS 3.1519 ILM 4468.0000 GR 0.0713 NRA'T 12.4023 NCNL -999.2500 T=NS 26.1481 ILM 4104.0000 GR 0.0352 NRAT 19.2383 NCNL I999.2500 TENS 2.8278 123.1875 3.1055 1900.0000 -999.2500 2.6271 123.1875 3.1055 1900.0000 -999.2500 2.8320 104.5000 3.3535 1855.0000 -999.2500 3.009,8 100.5000 2.9687 2150.0000 -999.2500 3.2932 102.2500 3.3145 1978.0000 -999.2500 27.5487 62.1875 2.7754 2826.0000 -999.2500 VO OIO.H02 VERIFIC,a, TION LISTING OAGE 5 'EPT 7700.0000 S~LU P -36.0000 GR ALZ 9.8572 R~38, NRA 3.3457 NPHZ :CNL 381.5000 TENS 'EPT 7600.0000 SFLU P -33.4063 GR ,ALI 9.4219 RHO5 iNRA 3.7949 NPHi CNL 421. 7500 T=NS~ EPT 7500.0000 SFLU P -39.0000 GR ALI 9.9453 RHOB NRA 3.7109 NPHi CNL 480,5000 TENS ~EPT 7400.0000 SFLU ;P -43.0000 GR :ALI 9.0078 RHOB :NRA 3.7539 NPHi :CNL 485,0000 TENS )EPT 7300,0000 SFLU ;P -47,5000 GR 'ALI 9,4219 RHOB ~NRA 3,8555 NPHZ :CNL 448,7500 TENS )EPT 7200.0000 SFLU ;P -54.7188 GR :ALI 10.0347 RH03 ~NRA 3,4160 NPHI :CNL 536,5000 TENS )EPT 7100.0000 SFLU ;P -54.0313 GR :ALI -999.2500 RHO5 INRA -999,2500 NPHi :CNL -999.2500 TENS )EFT 7000,0000 SFLU ~P -57,0000 GR ;aL! -999,.2500 RH06 ~NRA -999.2500 NPHI :CNL -999,2500 TENS )EPT 6900,0000 SFLU ;P -~7,0000 GR :ALI -999,2500 RHO5 ~NRA -999,,2500 NPHI :CNL -999.2500 TENS 2.0948 ILD 123.7500 TENS 2.3586 ORHO 33.6~26 DPhI 4324.0000 GR 2.3883 ILD 111,5623 TENS 2,3813 DRH5 48,2910 DPHI ~184,0000 GR 2,7195 ILO 127,1250 TENS 2,4199 DRHO 43,6523 OPHI 4024,0000 GR 4.3738 iLD 184.6250 TENS 2.4004 ORHO 44.9707 DPHI 4084.0000 GR 4,5631 ILD 246,6250 TENS 2.3418 DRHD 46,1914 DPHI 3870.0000 GR 4.5139 !LD 166,8750 TENS 2..4199 DRHD 38,9160 DPHI 3934,0000 GR 4.3178 ILD 135,0000 TENS -999,2500 DRHO -999.2:300 DPHi -999.2500 GR 5.3210 ILD 92.8750 TENS -999.2300 DRHO -999.2300 DPHi -999.2500 GR 3,3391 ILO 154,0000 'TENS -999,2500 DRHO -999,2500 DPHZ -999.2500 GR 2.9907 ILM 4324.00'00 GR -0.0068 NRAT 5.4199 NCNL -999.2500 TENS 1,9919 iLM 418&.0000 GR 0.04~4 NRAT 17.4303 NCNL -999.2300 TENS 2.5319 ILM 4024.0000 GR 0.0498 NRAT 13,8184 NCNL -999,2500 T~NS 3.7384 ILM 4084.0000 G2 0.0444 NRA'T 15.0391 NCNL -999.2300 TENS 3,4561 ILM 3870,0000 GR 0,0322 .NRAT 18,5547 NCNL -999.23'00 TENS 3.9247 ILM 39,34.0000 GR 0.0,400 NR2. T 13,8672 NCNL -999,2500 TENS 3.9313 iLM 3964.0000 GA -999.2500 NRAT -999.2300 NCNL -999.2500 TENS 4.9835 ILM 4090,0000 GR -999.2500 NRA'T -999.2500 NCNL -999.2500 'TENS 2,9437 iLM 412.4,0000 GR -999,2300 NRAT -999,2500 NCNL -999.2500 'TENS 2.3817 123.7300 3.0898 2950,0000 -999.2500 1.9903 111.5625 3.8533 1601.0000 -999.2500 2,5.570 127,1250 3,6406 1784.0000 -999.2500 3.8103 164,6250 3,6367 1821,0000 -999,2300 3,5157 248,6230 3,7.402 1731,0000 -999,2500 3.9598 166,8750 3,3926 1833.0000 -999,2500 ~.0045 -999,2500 -999.2500 -999.2500 -999,2500 5.1248 -999.2500 -999.2300 -999.2500 '-999.2500 3,0030 -999,2500 -999.2500 -'999,2500 -999.2500 VP 010.H02 VERIFIC~.TION LISTING PAGE 6 EOT 5800.0000 SFLU P -45.~588 GR 'ALi -999.2500 RHDS INRA -999.2500 NPHI :CNL -999.2500 TENS EPT 6700,0000 SFLU P -49,3.750 GR ALi 8,1'797 RHO5 INRA 3.0469 NRHI :CNL 518,0000 TENS $EPT 5500.0000 SFLU ;F -54.3750 GR ;ALI 8,7734 RHO5 (NRA 3,5977 NFHi :CNL 538.0000 TENS )EPT 6500,0000 SFLU ~P -58,0000 GR :AL1 8,6408 RHG5 ~NRA 2,9336 NPHi :CNL 719,0000 TENS )EPT 6400,0000 SFLU ~P -57,0000 GR ;ALI -9'99,2500 RH08 ~NRA -999,2500 NPHi :CNL -999,2500 TENS )EPT 6300,0000 SFLU ~P -58,2500 GR ]ALI -999,2500 RH05 ~NRA -999,2500 NPHI :CNL -999,2500 'TENS ]EP'T 5200,0000 SFLU 5P -61.5000 GR ]ALI -999,2500 RHOB ~NRA -999,2500 NPHi =CNL -999,2500 TENS' DEOT .6100,0000 SFLU SP -64.0000 GR $.~LI .-999.2500 RHOB RNRA -999,2500 NPHZ ~CNL -999,2500 TENS DEPT 6000.0000 SFLU SP -67,7500 GR SAL! -999,2500 R:HO6 RNRA -999,.2500 NPHI =CNL -999,2500 TENS 2,2832 ILD ~5.6250 'TENS -999.2500 DRHS -999.2500 DPHI -999,2500 GR 1,8288 ILD 97,9373 TENS 2,3867 DRHO 40.0391 DPHZ 3824,0000 GR 1,5499 ILD ii1,0625 TENS 2,3594 DRHO 40,3320 DPH! 3940,0000 GR 3,8399 ILD 118,4375 TENS 2.4492 DRHg 33,0078 OPHI 3944,0000 GR 4,0244 iLD 100,0000 TENS -999,2:500 ORHO -9991,2500 OPH! · -999,2500 GR 3,1288 ILD 84,8125 TENS -999,2500 DRHO -999,2500 DPHI -999..2500 GR 3.1797 ILO 121,2500 TENS -999,2500 DRHD -999,2500 DPHI -999,2500 GR ~,2052 ILD 89.2500 TENS -999.2500 DRH'O -99'9.2500 DPHi -999,2500 GR 2,3038 IL9 110.5000 'TENS -999,2500 DRHO -999,2500 DPHI -9'99,2500 GR 2.4619 iLM 4050.0000 GR -999,2S00 NRAT -999.2500 NCNL -9'99,2500 TENS 1,8596 iLM 3824.0000 GR 0.1313 NR~T 15.9180 NCNL -999,2500 T~NS 1.7257 ILM 3940.0000 GR 0,0386 NRAT 17,4805 NCNL -999.2500 TENS 3,7184 !LM 3944,0000 GR 0,0503 NRAT 12,1094 NCNL -999.2500 TENS 4,0729 ILM 3864,00O0 GR -999,2500 NR&T -999,2300 NCNL -999,25.00 TENS 4,1101 ILM 3824,0000 GR -999,2500 NRA'T -999,2500 NCNL -'999.2500 TENS 3,4006 !LM 3770.0000 GR -999,2~00 NR~T ,-999.2500 NCNL -999,2500 TENS 4,6928 ILM 3784.0000 GR -999,2500 NRAT -999,2,500 NCNL -999.2500 TENS 2,3187 ILM 3434,0000 GR -999,2500 NRAT -999,2.500 NCNL -999,2S00 TEN.S 2.6042 -999.2500 -999.2500 -999.2500 -999.2500 1.8740 97.9375 3.3008 1883.0000 -999.2500 1,7919 II1,0625 3,3652 1936.0000 -999,2500 3,7066 118,4375 2,9512 2110,0000 -999,2500 4.0365 -999,2500 -999.2500 '-999,2500 -999,2500 4.4444 -999.2500 -999.2500 -999.2~00 3,3840 -999.2500 -999.2500 -999.2500 -999.2500 5.3209 -999.2500 -999,2500 -999.2500 -999.2500 2.3028 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERiFICATiON LISTING P~GE 7 )EPT ;ID :AL1 ~NR~ :CNL DEPT ;P ;ALi ]NRA 'CNL )EOT ~P :AL1 ~NRA :CNL DF:PT .;ALI ~N RA :CNL DEPT 'ALI RNRA ~CNL DEPT SP SALI RNRA FCNL DEPT SP CALl RNR.A FCNL DE PT SP CALl R N R & F C N L DEPT SP CALl RNRA FCNL 5900.0000 SFLU -70.7500 GR -999.2500 RMOB -999.2500 NPHI -999,2500 TENS 5800,0000 SFLU -71.2500 GR -999,2500 RHOB -999,2500 NPhl -999.2500 TENS 5703.0000 SFLU -76.5000 GR -9'99,2500 RHO6 -99'9,2500 NPHi -999.2500 TENS 5600.0000 SFLU -75,9375 GR -999.2500 RHOB -999,2500 NPHI -999.2500 'TENS 5500.0000 SFLU -76.9375 GR -999.2500 RHOF5 -999.2500 NPHI -999,2500 TENS 5400,0000 SFLU -75,7500 GR -999,2500 RHOB -999,2500 NPHI -999,2500 TENS 5300,0000 SFLU -'7.5,7500 GR -999,2500 RHOB -999.2500 NPHi -999,2500 TENS 5200.0000 SFLU -74.7500 GR -99'9.2500 RHOB -999.2500 NPHi -999,2500 TENS 5100,0000 SFLU -78,2500 GR -999,2500 RH08 -999,2500 NPHI -999.2500 TENS 2.ii06 ILD 110,0000 TENS -999,2500 ORHO -999,2500 DPHI -999.2500 GR 2,5570 ILO 89.8125 TENS -999.2500 ORHO -99'9,2500 DPHI -999,2500 GR 2,8027 ILO 108.8750 TENS -999.2500 DRMC -999.2500 DPHI -999.2500 GR 2.6495 ILD 97.5625 TENS -9'99.2500 DRHO -999.2500 CPHI -999.2500 GR 2, .5784 ILO 96,3125 T~=NS -999,2500 DRHO -999,2500 DPHI -999.2500 GR 2,5393 ILO 102.0625 TEN.S -999,2500 DRMO -999,2500 DPHi -9'9'9.2500 GR 2.301! ILO 98,2500 TENS -999,2500 DRHO -999,2500 DPHi -999°2500 GR 1,0390 ILO 76.3125 TENS -999.2500 DRHO -999,2500 DPHI -999,2500 GR 2,6129 !LO 86,3125 TENS -999,2500 CRHO -999,2500 OPHI -999,2300 GR 2.2179 ILM 3404,0000 GR -999.2500 NRAT -999.2300 NCNL -99'9,2300 TENS 2,7240 ILM 3404,0000 GR -999.2500 NRAT -999,2500 NCNL -999,2500 TENS 2.9175 ILM 3364,00C, 0 GR -999,2500 NRAT -999,2500 NCNL -999,2500 TENS 2.7837 ILM 3364.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2.500 T~NS 2,7114 ILM 3434,0000 GR -999,2500 NRAT -999,2500 NCNL -999.2500 TENS 2,55.20 ILM 3200.0000 GR -999.2500 NRAT -999,2500 NCNL -999,2500 TENS' 2.4838 iLM 3050,0000 GR -999.2500 NRAT -999,2500 NCNL -999,2500 TENS 0,6026 ILM 296,0,0000 GR -999,2500 NRAT -999,2500 NCNL '-999,2500 'TENS 2,8388 iLM' 2924,0000 GR -999,2500 NRAT -999,2500 NCNL -999,2500 TENS 2.2085 -999.2500 -999.2500 -999.2500 -999.2500 2.6552 -999.2500 -999.2500 -999.2500 -999.2500 2.B913 -999.2500 -999.2500 -999.2500 -999.2500 2.7808 -9'99.2500 -999.2500 -999,2500 -999.2500 2,7180 -999,2.500 -999.2500 -999.2500 -999.2500 2,5187 -999,2500 -999.2500 -999,2500 -999.2500 2.4152 -999.2500 -99'9.2500 -999.2500 -999.2500 0,7458 -999,2500 -999,2500 -999,2500 -999.2500 2.8017 '-999,2500 -999,2500 -999,2500 -999.2500 VP OlO.H02 VERIFICATION LISTiNg 'PAI35 ~ EFT 5000.0000 SFLU P -85.0000 GR aLI -999.2500 RHOB NRa -999.2500 NPdI CNL -999.2500 TENS EPT 4900.0000 SFLU P -79.7500 GR ALI -999.2500 RmOB NRA -999.2500 NPHI :CNL -999.2500 TENS ,EPT 4800.0000 S~LU ,P -80.0625 GR :siLl -999.2500 RHOB :NRA -999.2500 N.~HI :CNL -999.2500 TENS )EOT 4700.0000 SFLU ;P -80.5625 GR 'ALI -9'99.2500 RHOB INRA -999,2500 NPHI :CNL -9'99,2500 TENS )EPT 4600.0000 SFLU ;P '-84.0625 GR ;ALI -999.2500 RH'08 ~NRA -999,2500 NPHI :CNL -999,2500 TENS ;P -87,4375 GR ;ALI -999,2500 RHO8 ~NRA -999.2500 NPHI :CNL -999.2500 T~NS )EPT 4400.0000 SFLU ;P -82.7500 GR ;ALI -'999.2500 RH'OB ~NR~. -999,2500 NPHI :CNL -999.2500 'TENS )EPT 4300,0000 SFLU ;P -999,2500 GR ;ALi -999,2500 RH08 ~NRA -999.2500 NPHI :CNL -999,2500 TENS )EPT 4200,0000 SFLU ;P -999,2500 GR 'AL! -999,2500 RH'O8 ~NRA -999.2500 NPHI :CNL -999,2500 TENS 3.0618 IL3 82.7~00 TENS -999.2~00 9RH3 -99'9.2500 DP~Z -999.2500 GR 3.0~27 ILO 97.7500 TENS -999.2500 DRHO -999.2500 DmHi -999.2500 GR 2.9494 ILD 93,0625 TENS -999.2500 ORHO -999.2500 DPHI -999.2500 GR 2,6773 ILD 97.0625 TENS -9'99.2500 DRH9 -999,2500 DPHI -999.2500 GR 3,2466 ILD 92,6250 'TENS -99'9,2500 DRH'2 -999.2500 DPHI -999,2500 GR 2,7841 'ILD 105,0000 'TENS -999,2500 ORHO -999.2500 OPHI -999.2500 GR 2,5795 ILD 75,3125 TENS -999. 2500 DRHO -999,2500 DPHI -999.2500 GR -999.2500 ILO -999.2500 TENS -999,2500 ORHO -9'99.12500 DPHI -999,2500 GR -999,2500 ILO -999.2500 TENS -999,2500 DRHC -9'99,.2500 DPHI -99.9,2500 GR 3.2802 ILM 2554.0000 GR -999.2500 NRAT -999,2500 NCNL -999.2500 TENS 3.307'9 ILM 2924,0000 G~ -999,2500 NRAT -999.2500 NCNL -999.2500 TENS 3.3951 iLM 2810.0000 GR -'999.2500 NRAT -999.2500 NCNL -999.2500 TENS 2,903~ ILM 2704.0000 GR -9'99,2500 NRAT -999,2500 NCNL -999,2500 TENS 3.4789 ILM 2660,0000 GR -999.2500 NRAT -999,2500 NCNL -999,2500 TENS 2,9784 ILM 2564,0000 GR -999,2500 NRAT -999°2500 NCNL -999,2500 TENS 2,9457 iLM 2594,0000 GR -999,2500 NRA'T -999,2500 NCNL -999.2500 TEN.S -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.,2~00 NCNL 66.9375 TENS -999.2500 ILM -999,2500 GR -999,2500 NRAT -999.2500 NCNL 51.3750 TENS 3.1983 -999.~'~500 -999.2500 -9'99.2500 -999.2500 3.2218 -999.2500 -999.2500 -999.2500 -999.2500 3.2984 -999.2500 -999.2500 -999.2500 -999.2500 2.8069 -999.2500 -999.2500 -999.2500 -99'9.2500 3,3938 -999.2500 -999,2500 -999,2500 -999,2500 2.8489 -999,2500 -999,2500 -999,2500 -999,2500 2,7258 -999,2500 -999,2500 -999,2500 -99'9,2500 -999.2500 -999,2500 -999,2500 -999,2500 2544.0000 -999.2500 -999.2500 -999.2500 -999.2500 2494.0000 V~ 010. .H02 VERiFZC~TION LISTING PA",~E 9 2PT 4100.0000 SFLU P -999.2500 GR AL1 -999,2500 RH05 NRA -999.2500 NPHI CNL -999.2500 TENS )EPT 4000,0000 SFLU ;P -999.2500 GR 'ALZ -999,2500 RHDB ~NRA -999.2500 NPHI :CNL -999,2500 T~NS }EPT 3900.0000 SFLU iP -999.2500 GR :ALI -999.2500 RH06 ~NRA -999,2500 NPHI :CNL -999,2500 TENS 3EPT 3800,0000 SFLU ~P -999.2500 GR :ALI -999.2500 RHOB ~NRA -999.2500 NPHI =CNL -999,2500 TENS DEPT 3700,0000 SFLO SP -999,2:500 GR 2ALI -999,2500 RHO6 RNRA -999.2500 NPHI ~CNL -999.2500 TENS DEPT 3600,0000 SFLU SP -999,2500 GR CALI -999,2500 RHDB RNRA -999,2500 NPH'Z FCNL -999,2500 TENS DEPT 3500,0000 SFLU SP .-999,2500 GR CALI -999,2500 RHOB RNRA -999,2500 NPHI FCNL -999,2500 TENS DEPT 3400.0000 SFLU SP -999,2.500 GR CALI -999,2500 RHOB RNRA -999,2500 NPHI FCNL -999,2500 TENS DEPT 3300,0000 SFLU SP -999.2500 GR CALI -999,2500 RHOB RNR~ -999.2500 NPH'I ~CNL '-999,2500 TENS -9~99,2500 iLO -999,2500 TENS -999,2500 CRHO -999.2500 DPHZ -999,2500 GR -999.2500 ILD -999.2500 TENS -9:99.2500 DRHO -999.2500 DPHI -999,2500 GR -999.2500 ILO .-999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 GR -999,2500 ILD -999.2500 TENS -999,2300 DRHO -999,2500 DPHI -999.2500 GR -999,2500 ILD -999,2500 TENS -999,2500 DRHO -999,2500 DPHI -999,2500 GR '-999,2500 ILO -999,2500 TENS -999.2500 DRHO -999,2500 DPHI -999.2300 GR -999,2500 iLO -999.2500 'TENS -999,2500 DRH9 -999,2500 DPHI -999.2500 GR .-999,2500 ILD -'9'99,2500 TENS -999.2500 DRHO -999,2500 DPHI -999,2500 GR -999,2500 ILD -9'99,2500 TENS -999,2500 DRHO -999.2500 OPHI -999.2300 GR -999.2500 ILM -999,2300 GR -999.2500 NRAT -999,2300 NCNL 58.3938 TENS -999,2500 ILM -9919,2500 GR -999,2500 NRAT -999.2500 NCNL 66,8125 TENS -999,2500 ILM -999,2500 GR -99'9,2300 NRAT -999,2500 NCNL 55.3438 TENS -999,2300 ILM -999,2300 GR -999,2500 NRAT -999,2500 NCNL 58.6563 TENS -999.2300 ILM -999.2500 GR -999.2300 NRAT -999.2500 NCNL 66.3750 TENS -999.2500 ILM -999.2500 GR -999,2300 NRAT -999.2500 NCNL 38.5313 TENS -999.2500 ILM -999.2500 GR -999.2500 NRA'T '-999.2500 NCNL 47,3123 TEN.S -999,2500 ILM -9'99,2300 GR -999,2500 NRAT -999,2500 NCNL 29,6563 TENS -999,2500 ILM -999,2500 GR -999,2500 NRAT -999,2500 NCNL 37.9!375 T~NS -999.2500 -999.2500 -999.2500 -999.2300 2514.0000 -999.2500 -999.2500 -999.2500 -999.2500 2524.0000 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2384.0000 -999,2500 -999,2500 -999,2500 -999.2500 2334.0000 -999.2500 -999,2500 -999.2500 -999,2500 2264.0000 -999.2500 -999.2500 -999.2500 -999.2500 2304.0000 -999.2500 -99'9,2500 -999.2500 -999,2500 2314,0000 -999.2500 -999.2300 -999.2500 -999.2500 2120o0000 VP OlO.H02 VERiFICAT!GN LISTING PAGE 10 EPT 3200.0000 SFLU P -999.2500 GR AL1 -999.2~00 R~C3 NRA -'999.2500 NPHi CNL -999.2500 TENS EPT 3100.0000 SFLU o -999.2500 GR ALI -999.2500 R~3~ NRA -999.2500 NPH! 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