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187-026
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, November 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3M-06 KUPARUK RIV UNIT 3M-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/26/2025 3M-06 50-029-21707-00-00 187-026-0 W SPT 6105 1870260 1526 1650 1660 1660 1660 180 200 200 200 4YRTST P Bob Noble 11/2/2025 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 3M-06 Inspection Date: Tubing OA Packer Depth 450 2310 2235 2235IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN251103153644 BBL Pumped:2.3 BBL Returned:2.3 Wednesday, November 26, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska 00 and Gas Conservation Commission TO:Jim Regg�� 7�Z�1 �4ti2c DATE: Tuesday, July 21, 2020 isor l `� P.I. Supervisor SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3M-06 FROM: Austin McLeod KUPARUK Rry UNr13M-06 Petroleum Inspector Packer Depth Pretest Initial Sre: Inspector Reviewed By: n P.L Sup" J/�c_ NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3M-06 API Well Number 50-029-21707-00-00 Inspector Name: Austin McLeod Permit Number: 187-026-0 Inspection Date: 7/18/2020 IDsp Num: mitSAM200719090639 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3M-06 Type Inj W TVDPJ�� 1875 - 1875 - 1875 - 1875 PTD 1870260 Type Test SPT Test psi 460 2600. 2465 - 2450BBL Pumped: z.3 BBL Returned:pA Iso - 400 aoo - aoo .Interval 4YRTST P/ri Notes: MFT -IA Tuesday, July 21, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,June 28,2017 P.I.Supervisor 4,e 7(7(r 7 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3M-06 FROM: Chuck Scheve KUPARUK RIV UNIT 3M-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 34- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3M-06 API Well Number 50-029-21707-00-00 Inspector Name: Chuck Scheve Permit Number: 187-026-0 Inspection Date: 6/24/2017 Insp Num: mitCS170625093040 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3M-06 'IType Inj W -TVD 6105 Tubing 1325 ( 1325 1325 " 1325 PTD 1870260 "Type Test SPT LTest psi 1526 IA 400 ' 2220 - 2090 " 2070 - 7 BBL Pumped: 3.4 'BBL Returned: 2.4 OA 120 140 140 140 Interval INITAL P/F P ,, Notes: Initial MITIA post conversion per Sundry 317-234,...- SCANNED AUG 2 2 2017, Wednesday,June 28,2017 Page 1 of 1 . ,. . • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION 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 Stimulate 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>30 days f 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 187-0260 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-029-21707-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25521 KRU 3M-06 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 7460 feet Plugs(measured) None true vertical 6471 feet Junk(measured) None Effective Depth measured 7331 feet Packer(measured) 7011 true vertical 6366 feet (true vertical) 6106 Casing Length Size MD Burst Collapse CONDUCTOR 77' 16 115' 115' SURFACE 3490' 9 5/8 3527' 3400' PRODUCTION 7394' 7 7429' 6445' RECEIVED SCANNED *IAN 3 1 201? JUL 2 0 2016 Perforation depth: Measured depth: 7132-7142, 7155-7180, 7186-7190 True Vertical Depth: 6204-6212,6223-6243,6248-6251 AOGGC Tubing(size,grade,MD,and TVD) 2 7/8 ,J-55, 7041 MD,6131 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV=CAMCO TRDP-IA-SSA SAFETY VALVE @ 1800 MD and 1800 TVD PACKER=CAMCO HRP-1-SP PACKER @ 7011 MD and 6106 TVD NIPPLE=CAMCO D NIPPLE NO GO @ 7030 MD and 6121 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-8bl Casing Pressure Tubing Pressure Prior to well operation 0 0 1046 1000 2856 Subsequent to operation 16 1 4568 350 151 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic f Copies of Logs and Surveys Run r 16.Well Status after work: Oil F 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(C conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature 1:).1..rvelkPhone:659-7535 Date A'S i- S 1 3 f f 1 L RBDMS Lk, "" 2 2 2016 Form 10-404 Revised 5/2015 Submit Original Only • • 3M-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/14/16 Open Well- Return to Service- Produce > 30 days for resevoir pressure management • KUP INJ 3M-06 _ Well Attributes Max Angle&MD TD ConocoPhillips g A itik;-1 in,. [olroOORWYps I Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) 500292170700 KUPARUK RIVER UNIT INJ }I 41.12 5,800.00 7,465.0 ••• M, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 3M-06,10115/201311.07.55 AM SSSV:TRDP Last WO: 39.71 4/23/1987 Vesicalschemaac(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,247.0 6/10/2013 Rev Reason:WELL REVIEW osborl 10/15/2013 I Casing Strings HANGER;32.9 IICasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread l■ CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED II Casing Description OD(in) ID(in) Top(ft6B) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .3 SURFACE 95/8 8.921 37.0 3,526.5 3,399.9 36.00 J-55 BTC Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt./Len(i...Grade Top Thread PRODUCTION 7 6.276 35.0 7,428.9 6,445.2 26.00 J-55 BTC Tubing Strings ■ 'Tubing Description String Ma...ID(in) Top(069) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection T� .. �TUBING 2 7/8 2.441 32.9 7,041.9 6,131.3 6.50 J-55 EUE8rdABMOD I CONDUCTOR;38.0-115.0-i . Completion Details Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Mel(1 Item Des Com (in) I 32.9 32.9 0.12 HANGER VETCO GREY TUBING HANGER 2.875 6 1,799.6 1,799. 0.32 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 SAFETY VLV;1,799.6 i, 6,994.4 6,093.0 36.46 SBR CAMCO OEJ SBR 2.312 7,010.9 6,106.3 36.42 PACKER CAMCO HRP-1-SP PACKER 2.347 7,029.6 6,121.4 36.36 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT;2,327.2 7,041.2 6,130.7 36.33 SOS CAMCO SHEAR OUT SUB 2.441 Perforations&Slots Shot Den Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (R613) (ftKB) Zone Date t) Type Com 7,132.0 7,142.0 6,204.0 6,212.1 A-2,3M-O6 7/6/1987 1.0 IPERF 180 deg.phasing,4" Csg Gun SURFACE;37.00,526.5 7,155.0 7,180.0 6,222.6 6,242.9 A-1,3M-06 7/6/1987 1.0 IPERF 180 deg.phasing,4" Csg Gun GAS LIFT;3,954.3 11 7,186.0 7,190.0 6,247.8 6,251.0 A-1,3M-06 7/6/1987 1.0 IPERF 180 deg.phasing,4" Csg Gun Mandrel Inserts GAS LIFT;4.903.8 Stati C °^ Top(ND) Valve Latch Port Size TRO Run o No Top(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 2,327.2 2,326.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAS LIFT;5,331.0 2 3,954.3 3,735.6 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 3 4,903.8 4,476.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 4 5,331.0 4,805.1 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAS LIFT;6728.1 _ 5 5,728.1 5,105.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 6 6,188.6 5,454.9 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 7 6,552.8 5,740.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 8 6,948.8 6,056.3 OTIS LB 1 1/2 GAS LIFT DMY T-2 0.000 0.0 7/8/1987 GAS LIFT;6,188.6 Notes:General&Safety I End Date Annotation 7/27/2010 NOTE'Vow Schematic w/Alaska Schematic9.0 GAS LIFT;6,552.8II III GAS LIFT;6948.8 SBR;6.994.4 PACKER;7,010.9 I NIPPLE;7,029.6 SOS;7,041.2 - (PERF;7,132.0-7,142.0--- IPERF;7,155.0-7,180.0- I (PERF;7,186.0-7,190.0 I I PRODUCTION;35.0-7,428.9 yOF TAti ID III �.e'\\��I 7.�s THE STATE Alaska Oil and Gas 4�►-i-��1, of/® L A S KA Conservation Commission rift== -_- 333 West Seventh Avenue �, !- * , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Hilaire Yemeli-Gozon 1�� 2 i. Petroleum Engineer E '' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool,KRU 3M-06 Permit to Drill Number: 187-026 Sundry Number: 317-234 Dear Mr. Yemeli-Gozon: 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, °1-46- ?gg-4-4-1, Cathy . Foerster Chair DATED this 1( ay of June, 2017. RBDMS \,u JUN 1 6 2017 • • ;. ' ,. `- LIVE STATE OF ALASKA JIJ 0 8 Z017 ALASKA OIL AND GAS CONSERVATION COMMISSION OTS 4 /1 4-r 1 7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon Li Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Redrill p Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Li Other PROS 'b INT D 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development V 187-026 3.Address: Stratigraphic ❑ Service I ; 6.API Number: $ 50-029-21707-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3M-06 Will planned perforations require a spacing exception? Yes ❑ No Q/ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25521 k 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): B7+.&& (71(ps83' (i ar //e4 ;errl17,33I , €1445"— 6366 lig. 3000 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 77" 16" 115' 115' 1640 670 Surface 3,490' 9-7/8" 3,527' 3,714' 3520 2020 Intermediate Production 7,394' 7" 7,429' 6,567' 4980 4320 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7132-7142,7155-7180, 6204-6212,6223-6243,6248- 2.875" J-55 7041' 7186-7190 t 6251 , Packers and SSSV Type: Packer-Camco HRP-1-SP Packer Packers and SSSV MD(ft)and TVD(ft): MD=7011 ,TVD=6106 and Camco TRDP-1A-SSA safety VLV MD=1800 TVD=18001 12.Attachments: Proposal Summary ❑ Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program CI BOP Sketch El Exploratory El Stratigraphic❑ Development[ Service d 14.Estimated Date for 6/15/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG QQ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown Li Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Hilaire Yemeli-Gozon Contact Name: Hilaire Yemeli-Gozon Authorized Title: Petroleum Engineer Contact Email: hilaire.yemeli-gozon@COP.com (� � Authorized Signature: ( , �j0 Date: 0 610(/��(J ZaIt2 Contact Phone: (907)265-1478 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Ski- 2341 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ F. b 't-t!dq Other Post Initial Injection MIT Req'd? Yes No ❑ RBDMS p' JUN 1 6 2017 Spacing Exception Required? Yes ❑ No j Subsequent Form Required: /v — 4 D / _ (��I APPROVED BY 7 Approved by:aS6 / / COMMISSIONER THE COMMISSION Date:C –/' /7 IITZ /11/ 17,043 6/1// 6;0'4'7 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ORIGINAL ,t 1101. ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 RECEIVE® May 26, 2017 JUN 0 8 2017 AOGCC Commissioner AOGCC State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3M-06 from Oil Production to Water Alternating Gas Injection service. 3M-06 was drilled as an injector and had been injecting from May 5th, 1988 to January 14, 2016 when it was shut-in and back operations started 7/14/2016 for reservoir pressure management ahead of of se i •rifling. Enclosed you will find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3M-06 (PTD# 187-026) If you have any questions regarding this matter, please contact me at 907-265-1478. Sincerely, Hilaire Yemeli-Gozon Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary AOR Detail Area Map Well Schematic 1 • 3M-06 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3M-06 (PTD# 187-026) from oil production service to water injection service. Area of Review KRU Well 3M-06 is waiting to be converted to dedicated water injection to provide injection into the reservoir to increase the ultimate recovery of oil. 3M-06 is anticipated to support 3M- 05 and 3M-14 T- " - . : . , . . i ., .. VD The top of the A sand was found at 7,126' MD/6,199'TVD Area map with % mile radius around target injection zone (see attached) The map attached shows that except for the offset producers 3M-16, 3M-13 and 3M-05,there are no additional production/injection wells located within a 1/4 mile radius of the 3M-06 penetration of the Kuparuk interval Mechanical Condition of the Well to be Converted The mechanical condition of Kuparuk well 3M-06 is good and is classified as a "single casing" well. The injection tubing/casing annulus is isolated via Camco HRP-1-SP Packer located at 7,011' MD (6,106' TVD) A State-witnessed MIT-IA will be performed once well 3M-06 is converted to water injection, online, and stabilized CBL and interpretation of the cement quality The intermediate casing CBL indicates sufficient formation bond (5,300'-7,312' MD/4,825'— 6,341'TVD) The CBL interpretation was completed on the PTD's. • The 16" conductor was cemented with 198 sx CS 11. • The 9-5/8" surface casing was cemented with 1100 sx AS 111 & 350 sx Class G. • The 7" production casing was cemented with 300 sx Class G & 175 sx AS I. • • f6 lD OQ ,� LL II N Cr) I.~L N N 0 ~ O II = L No ~ o 0. ~ 0 •- oN O 0O ~ a a O ~a_ 2 a c i ,--1 -, -0 n ua � o0o v cn f-- N N I-CC Ln a H I- oo — o o 2 C 0 U o ccoo _ O`1-1 N v d d U CL Q Q I\- CtC z D_ W '���., N ei + o C a v a °. 3 Q c '' U cm N x N cxic U y 0 h Q ,N O — N a O - x rB M _ O - x co O 'o C _ OC a Owl \ N U - O .o _ N . N U co N O W N U m Cu N a) 1. fE ti4 N o in U .4 C N to OD N oo cn C C7 Q NC n oN cn °C° U a) a! E C _: cNi N N 0a Cu X y Dl e-I-I Op U ,„ N cn C 6� `-1 O U co N n _ Ln U a N U N C m 0 cNi' N U N _ U I� U N _ U n - U •- o�S .-I Cu co - U •� 02$ I` x ci - U •� QS ^ x .-i U = C7 U ° _ (7 N ro = 0 N U H U cn m C O cc v 0000 cc °n O - UO °� �j aai 0 o _ O Ln cc ▪ U 2 W O 2 - O N I, J co -- .-1 C E a) 2 d u N y Q N a) CO m m 01 ° 00 Co O O- Q K Q U r, ,...LO_ N• U N d cr) y= U = d CC C C C C 'Q y ca. O a) o O O 3 " U .'� 0' i i+ 0 L,0 3 O u 0 a)U Cuy CU CII ,,F- N O 7 CC N o 0.1o v L a a CL Q 0_ o C m d E m U C -J -J 4- E U CO U U O O a) I- 0 aa) Li) 0 0 N O E LID N N. r U V N cvj 0 0 0 o• f N 01 CD '▪ U LO N V a o T O LA in IN IN O -0 O D lD .-I N I- w c 0 R g N _ m ci vQ- O O LO N O n°. 00 m N 1°- O CO H 00 � C C H 3 U ._ 7 N 'O N 0- 0• -) w Lf1 m 1.0 J C9 ci • ..-4w Q 2 2 m m m Lb o CO OO N N N N N _ e-I N--1 c-I CL (N N Q1 N N CN Q O 9 0 O O O N N N 0 NN N m O 9 O. o^o 00 N. H ea co e, 411 • LFLb25522 ADLQ25512 :3R1 1G. :1-1:5 77 _.---- _ T13NR9E 11.1435 Ti3 i 8E ADL025523 ADLU25521 -- Well Trajectory „ ConocoPhillips s Well Qpen Interval Alaska,Inc. 1 Quarter Mile Open Interval Radi:laAk 3M-06 Wells within Open Interval Rados D.2 Q.A r----1 Injection Swap Analysis 1 OPAI Leases ! boles KUP PROD ` 3M-06 ConocoPhillips ='r Well Attributes Max Angle&MD TD Alaska,Inc. t_'° Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftK8) Act Btm(flK8) ConaceP ya1m 500292170700 KUPARUK RIVER UNIT PROD 41.12 5,800.00 7,465.0 --- Comment H2S(ppm) Date Annotation End Date KB-Gra(ft) Rig Release Date 3M-06,211 01201 7 1:36:12 PM SSSV:TRDP 2,900 11/27/2016 Last WO: _ 39.71 4/23/1987 Vertical schematic(actual) Annotation Depth OMB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,223.0 12/24/2016 Rev Reason:H2S pproven 2/10/2017 itiHANGER;32.9 4 �LI Casing Strings Ir Casing Description OD(in) ID(in) Top(ftK8) Set Depth(ftK8) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED I' iil= Casing Description OD(in) ID(in) Top MKS) Set Depth(ftK8) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 37.0 3,526.5 3,399.9 36.00 J-55 BTC tCasing Description OD(in) ID(in) Top(ftK8) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,428.9 6,445.2 26.00 J-55 BTC 11111111111111111111 ow .1oc Tubing Strings MPti._Tubing Description String Ma...ID(in) Top(ftK8) Set Depth(ft..Set Depth(NO)(...Wt(lb/ft) Grade Top Connection TUBING 27/8 2.441 32.9 7,041.9 6,131.3 6.50 J-55 EUE8rdABMOD CONDUCTOR;38.0-115.0 Completion Details Nominal ID Tap(ftK8) Top(ND)(MB) Top Incl(°) Item Des Com (in) 32.9 32.9 0.12 HANGER VETCO GREY TUBING HANGER 2.875 1,799.6 1,799.6 0.32 SAFETYVLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 FRAC SLEEVE;1,799 0 6,994.4 6,093.0 36.46 SBR CAMCO OEJ SBR 2.312 SAFETY VLV;1,799.6 ill 7,010.9 6,106.3 36.42 PACKER CAMCO HRP-1-SP PACKER 2.347 7,029.6 6,121.4 36.36 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,041.2 6,130.7 36.33 SOS CAMCO SHEAR OUT SUB 2.441 II GAS LIFT;2,327.2 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftK8) (ftK8) (3 Des Com Run Date ID(in) 1,799.0 1,799.0 0.32 FRAC 2.33"ISO SLEEVE(OAL 97"/ID 1.80") 1/1/1799 1.800 SLEEVE Perforations&Slots Shot Dens SURFACE;37.0-3,528.5 Top(ND) Bim(TVD) (shotsff Top(ftK8) Blot(flK8) (MB) (ftK8) Zone Dale t) Type Com 7,132.0 7,142.0 6,204.0 6,212.1 A-2,3M-06 7)6/1987 1.0 (PERF 180 deg.phasing,4" GAS LIFT;3,954.3II 7,155.0 7,180.0 6,222.6 6,242.9 A-1,3M-06 7/611987 Csg Gun 1.0 (PERF 180 deg.phasing,4" I Csg Gun GAS LIFT;4,903.8 I 7,186.0 7,190.0 6,247.8 6,251.0 A-1,3M-06 7/6/1987 1.0 IPERF 180 deg.phasing,4" Csg Gun Mandrel Inserts GAS LIFT;5,331.0III St ati 011 Top(ND) Valve Latch Port Size TRO Run N Top(ftK8) (flK8) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1 2,327.2 2,326.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAB LIFT;5,126.1III 2 3,954.3 3,735.6 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 I 3 4,903.8 4,476.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 4 5,331.0 4,805.1 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAS LIFT;6,188.6 i 5 5,728.1 5,105.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 I 6 6,188.6 5,454.9 CAMCO KBMG 7 6,552.8 5,740.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 718!1987 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAS LIFT;6s52.9 8 6,948.8 6,056.3 OTIS LB 11/2 GAS LIFT DMY T-2 - 0.000 0.0 7/8/1987 T Notes:General&Safety End Date Annotation GAS LIFT;8,948.6 ■ 7/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 - . SBR;8,994A .a. PACKER;7,010.9 NIPPLE;7,029.8 SOS;7,0412 (PERF;7,132.0-7,142.0 (PERF;7,155.0-7,180.0 (PERF;7,186.0-7,190.0 I PRODUCTION;35.0-7,428.9 ` • • 0 REcEiv, :. i.:', JUN 07 Z0 STATE OF ALASKA AOG e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS T� 20 AAC 25.280 1.Type of Request: Abandon IJ Plug Perforations Li Fracture StimulateL I Repair Well LI Operations shutdown Li Suspend ❑ Perforate❑ Other Stimulate❑ Pull Tubing❑ Change Approved Program El Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Atter Casing❑ Other: PROD to WINJ Q 2.Operator Name: 4.Current Well Class: 5..—rmit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 187-026 3.Address: Stratigraphic ❑ Service Q API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21707-00 7.If perforating: 8.W. Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? El Yes No 0 KRU 3M-06 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25521 Kuparuk R.,er 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): 8,190' 6,583' 7951' 6403' 3000 None I None Casing Length Size MD TVD Burst Collapse Structural �� Conductor 77' 16" 115' `,-�Y i 115' 1640 670 Surface 3,490' 9-5/8' 3,527' , \ 3,714' 3520 2020 Production 7,394' 7" 7,429' 1 6567' 4980 4320 Liner i IP Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7132-7142,7155-7180,7186-7190 6204-6212,6223-6243,6248-6251 2.875" • J-55 7,041' Packers and SSSV Type: hackers and SSSV MD(ft)and TVD(ft): PACKER-CAMCO HRP-1-SP PACKER MD=7011 TVD=6106 SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE MD=1800 TVD=1800 12.Attachments: Proposal Summary Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program P Sketch n. Exploratory ❑. Stratigraptr] Developmet ❑. Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:6/15/2017 OIL 0 WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG Q GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein wil Io..e deviated from without prior written approval. Authorized Name: Hilaire Yemeli-Gozon , / Contact Name:Hilaire Yemeli-Gozon Authorized Title: + P troleum Engi .-r �� 0 /7 i Contact Email:Hilaire.Yemeli-Gozon(c�conocophillips.com r�I/Vn/ /v"Vlf `l 12 Contact Phone:907)265-1478 Authorized Signature: Date: �/ COMMISSION U E ONLY Conditions of approval: Notify Commission so that a representative may witnes Sundry Number: s `..7 2 3 L( Plug Integrity El BOP Test ❑ Mechanical Integrity Test El Location Clearance El Other: Post Initial Injection MIT Req'd? No 0 Spacing Exception Required? No❑ .ubsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: SAL JRI Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 RECEIVED May 26, 2017 JUN 0 7 2017 AOGCC Commissioner �^ �� State of Alaska, Oil & Gas Conservation Commission AOGCC 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3M-06 from Oil Production to Water Alternating Gas Injection service. 3M-06 was drilled as an injector and had been injecting from May 5th, 1988 to January 14, 2016 when it was shut-in and flow back operations started 7/14/2016 for reservoir pressure management ahead of offset CTD drilling. Enclosed you will find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3M-06 (PTD# 187-026) If you have any questions regarding this matter, please contact me at 907-265-1478. Sincerely, Hilaire Yemeli-Gozon Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary AOR Detail Area Map Well Schematic 1 • • 3M-06 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3M-06 (PTD# 187-026) from oil production service to water injection service. Area of Review KRU Well 3M-06 is waiting to be converted to dedicated water injection to provide injection into the reservoir to increase the ultimate recovery of oil. 3M-06 is anticipated to support 3M- 05 and 3M-14 The top of the C sand was found at 7,126' MD/6,199' TVD The top of the A sand was found at 7,126' MD/6,199'TVD Area map with % mile radius around target injection zone (see attached) The map attached shows that except for the offset producers 3M-16, 3M-13 and 3M-05, there are no additional production/injection wells located within a 1/4 mile radius of the 3M-06 penetration of the Kuparuk interval Mechanical Condition of the Well to be Converted The mechanical condition of Kuparuk well 3M-06 is good and is classified as a "single casing" well. The injection tubing/casing annulus is isolated via Camco HRP-1-SP Packer located at 7,011' MD (6,106' TVD) A State-witnessed MIT-IA will be performed once well 3M-06 is converted to water injection, online, and stabilized CBL and interpretation of the cement quality The intermediate casing CBL indicates sufficient formation bond (5,300'-7,312' MD/4,825'— 6,341'TVD) The CBL interpretation was completed on the PTD's. • The 16" conductor was cemented with 198 sx CS 11. • The 9-5/8" surface casing was cemented with 1100 sx AS 111 & 350 sx Class G. • The 7" production casing was cemented with 300 sx Class G & 175 sx AS I. • • Q J II N H N N Q — O 1- O II '= o — . -o O O O a a O a C II o -a Q H N O QJ \ N d N d O c aJ aJ \ Ln rn Lr a v c - a a U a 3• Q c o Ln U vi I� x In U n O0 -O Q ") O -a _� ^ o - x 0 - x CO a+ cul N U N O O V1 U CO c6 N 0 00 to U CO CO N O — N a) ., on O N cOco U c Ln o0 . o N N N x bA . Vl •- N x ns E C Ol eNI n 00 CO U C Q) N o (0 N N •c 61 ,moi 00 U cvlo N CD a) E n N C U n @ O U 6 Ln CO — f]a 0 _ _ Ln v o 0 Ln 0ca CO o .N 0 U Ln 0cn - U U Li) ,_ U O H U r,, o6 r1 U co - U •,n o2S ^ x c-I - U .7 40 ^ x ,--I VI �o N -1 U = (.7 U -1 U = 0 ,1 U = 0 To C O cc v 00 CC CU O .- O o2S aJ O o _ OU n w c 4- U 2 K V co - 1, I- O a) `� N 't s-I y La _ O v n Y a) U N 0 Q 00 Ln - v rn m 0 01 0 COooco 0 O- Q cc Q U I� ,� Q N• U N d p�j +-' `� U 2 CL Ln C C C C C c L wO wO aJ O 0. U >• r 0 i U O u 0 N O O O 0 v) vii r . '� 'O i `�- '>7 c w O N a O_ d O_ d O 4+ T C m o aJc_ J J 03 03 03 w E U U U o L a - o CU I- o o v ,u '7 0 'ED) o I- u o v o 0 0 0 I-- cu to N v U Q H O _ 0 LU IoaC U lDN-I lNfN 1C IN N N c CI 02 N Q LU 000 0 O o ao CO N N 0. _ 0 ▪ O 00 CO Cr) C C C D UU Q -D 0 O -0 0 1- 2 2 -c NN a Q. J- LN Ln CO li ,U'I Z m m m Lo 0 0o O .-I .--1 N-i F. N N N Q O O O 0 O 0 Ln O enn O O O O I- co 00 oco a s-i ,-. .-. • • ADL025522 AOL025512 Ulm 3.41-13 3M 3M-06 __ ._. T13NR9E Ti E AOLQ25523 AD L025521 Well Trajectory N ConocoPhillips Well Open Intergyral Alaska,lr1C. niQuarter Mile Open Interval RadLis M-06 Wells within Oper Interval Radius0 4 Injection Swap Analysis I I CP,AI Leases Miles 5118:2017 • ` KUP PROD • 3M-06 ConocoPhillips '' Well Attributes Max Angle&'AMI) tp Alaska.Inc Wellbore API/UWI Field Name Wellbore Status ntl(°) MD(ftKB) Act Btm(ftKB) ,z,r,,. "<"L 500292170700 KUPARUK RIVER UNIT PROD 41.12 5,800.00 7,465.0 ••• Cammenl H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-06,2/10/20171:36'12 PM SSSV:TRDP 2,900 11/27/2016 Last WO: 39.71 4/23/1987 Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 7,223.0 12/24/2016 Rev Reason:H2S pproven 2/10/2017 HANGER;32.9 ii.I Casing:.Stltr�gs .. �, li Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..,Grade Top Thread I 71 CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED 1 I C g D scr pt on OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(IVO)...WULen p..Grade Top Thread SURFACE 9 5/8 8 921 37 0 3,526.5 3,399 9 36.00 J 55 BTC II # C g D scr pt on OD(in) ID(n) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I 'Grade Top Thread PRODUCTION 7 6 276 35 0 7 428.9 6,445 2 26.00 J-55 BTC �IF , T bang Descr pl nn String Ma ID(n) Top(ftKB) Set Depth(fl Set Depth(TVD)( Wt(Ib/Ft) Gratle Top Connection TUBING 2 7/8I 2 4411 32 0I 7 041 91 6 11 3I 6 50 J 55 I EUEBrdABMOD CONDUCTOR,38.0-115.0 ' Corn on©e$alla Y �A!rr Nominal lD , Top(ftKB) Top(ND)(ftKB) Top'nein Item Des Com (in) 32.9 32.9 0.12 HANGER VETCO GREY TUBING HANGER 2.875 1,799.6 1,799.6 0.32 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 FRAC SLEEVE;1 ass o1 6,994.4 6,093.0 36.46 SBR CAMCO OEJ SBR 2.312 SAFETY VLV;1,799.6 7,010.9 6,106.3 36.42 PACKER CAMCO HRP-1-SP PACKER 2.347 7,029.6- 6,121.4 36.36 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,041 2 6,130.7 36 33 SOS CAMCO SHEAR OUT SUB 2.441 GAs LFT;2 327_z Other in Hole(Wireline retrievable plugs,valvee Pumps,fish,etc.) Top(TVD) Tap Incl Top(ftKB) (ftKB) I (°) Des Com Run Date ID(in) 1,799.0 1,799.0 Ij 0.32 FRAC 2.33"ISO SLEEVE(OAL 97"/ID 1.80") 1/1/1799 1.800 SLEEVE Perforations&Mots Shot ... Dens SURFACE;37.0-3,52fi.5� Top(ND) BEn(TVD) (chots/f I Top(ftKB) Btm(ftKB) (ftKB) (6KB) Zone Date t) Type Cern 7,132.0 7,142.0 6,204.0 6,212.1 A-2,3M-Oft 7/611987 1.0 IPERF 180 deg.phasing,4" GAs LIFT:3554 3 Csg Gun 7,155.0 7,180.0 6,222.6 6,242.9 A-1,3M-06 7/6/1987 1.0 IPERF 180 deg.phasing,4" Csg Gun GAS LIFT;4,9038 7,186.0 7,190.0 6,247.8 6,251.0 A-1,3M-06 7/6/1987 1.0 IPERF 180 deg.phasing,4" Csg Gun Mandrel Inserts GAS LIFT;5,331.0 at atm a on N Top(ftKB) Top(TVD) Valve Latch Port Size TRO Run (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com 1 2,327.2 2,326.4 CAMCO KBMG ' 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAS UFT;57281 2' 3,954.3 3,735.6 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 I 3 4,903.8 4,476.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 4 5,331.0 4,805.1 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAS LIFT;5,1685 5 5,728.1 5,105.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 6 6,188.6 5,454.9 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 7 6,552.8 5,740.4 CAMCO KBMG 1 GAS LIFT DMY BK-2 0.000 0.0 7/8/1987 GAS LIFT;6,552.8 8 6,948.8 6 056.3 OTIS LB 1 1/2 GAS LIFT DMY T-2 0.000 0.0 7/8/1987 Notes;General&Safety I End Date1 Annotation 7/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6 948.8 I I .11 SBR;6,994.4 Y, m. PACKER;7,010.9 >t_ NIPPLE;7,029 6 SOS,7,0412 IPERF;7,132 0-7,142.0- IPERF;7,155.0-7,180.0 IPERF;7,196.0-7,190.0�� PRODUCTION,35.0-7,428.9 L • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,June 8, 2017 9:51 AM To: Hilaire.Yemeli-Gozon@conocophillips.com Subject: KRU 3M-06 (PTD 187026): Sundry Application Good morning Hilaire, Please resubmit the Sundry Application (Form 10-403)for KRU 3M-06. The form received from ConocoPhillips was altered to the point of being too small to read. Please do not alter in any way, shape or size,the forms found on the AOGCC website at: http://doa.alaska.gov/ogc/forms/forms.html Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 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 III/ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 25,2013 TO: Jim Regg r P.I.Supervisor i--- ell I°(11 I:3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-06 FROM: Jeff Jones KUPARUK RIV UNIT 3M-06 Petroleum Inspector Src: Inspector Reviewed 13; ._ P.I.Suprv---igg--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3M-06 API Well Number 50-029-21707-00-00 Inspector Name: JeffJones Permit Number: 187-026-0 Inspection Date: 9/21/2013 Insp Num: m0.1130924210143 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6105 . Well! 3M-06 . Type Inj w 1TVD 1 1 IA 1 530 1790 - 1700 -1 1685 - 1111 — PTD 1870260 -1Type Test SIT Test psil 1526 . OA ! 200 1 330 - 1 340 340 - _1 Interval `1YRTST 1P/F P - Tubing 525 L 2525 1 2 - [ 525 2 ' 2525 I Notes: 1 well inspected,no exceptions noted. SCANNED DEC 1 0 2613 Wednesday,September 25,2013 Page 1 of 1 ME1~®IZAIeTDLTM TO: Jim Regg > ~•(l ~t~o P.I. Supervisor ~ ~`~~~ FROM: $ob Noble Petroleum Inspector State ®f Alaska . Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-06 KUPARUK RIV UNIT 3M-06 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~bP` Comm Well Name: KUPARUK RN UNIT 3M-06 Insp Num: mitRCN080707181234 Rel Insp Num: API Well Number: 50-029-z 1707-00-0o Permit Number: 187-026-0 Inspector Name' Bob Noble Inspection Date: 7/6/2008 Packer Depth , Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-06 Type Inj. ~' 'r`1D 6105 IA I 950 2280 ~ 2200 ~ 2190 p.T ls~oz6o TypeTest SPT Test psi z2so ~ pA ' a6o 600 600 600 Interval 4YRTST p~F P r/ Tubing i 2790 ! 2790 z79o z79o ~ Notes: A'`G ~ , ~~~ ~1''U4'SG~'~1'~ ~~ ~nP ~ ~i ~~1N~~ AU ~ ~ ~ 208 Tuesday, July 08, 2008 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, August 04, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-06 KUPARUK RIV UNIT 3M-O6 TO: JimRegg ~ . I P.I. Supervisor "Lt[~ ~I'l 04- Src: Inspector Reviewed By:,r- P.I. Suprv ..j¡;re.- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3M-06 API Well Number: 50-029-21707-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS04080320 I 407 Permit Number: 187-026-0 Inspection Date: 8/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-O6 Type Inj. S TVD 6470 IA 500 2220 2170 2150 P.T. 1870260 TypeTest SPT Test psi 1526.25 OA 0 0 0 0 Interval 4YRTST PIF P Tubing 2900 2900 2900 2900 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, August 04, 2004 Page I oft MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE 2, Name of Operator ARCO Alaska. Inc. 3. Address ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown. Stimulate m Plugging Perforate pull tubing . Alter casing . Repair well Pull tubing Other P..O. B0.x..' 100360, Anchorage, AK 4. Location of well at surface 1181' FNL, 1694' FEL, Sec. 25, T13N, R8E, UM At top. of productive interval 595' FNL, 1015' FWL, Sec. 30, T13N, R9E, UM At effective depth 552' FNL, 1127' FWL, Sec. 30, T13N, R9E, UM At total depth 525' FNL, 1197' FWL~ Sec: 30, T13N~ R9E, UM 12. Present well condition summary - Total Depth: 5. Type of Well: Development X Exploratory _ I Stratigraphic .._ . . measured 7 4 6 0' feet Plugs (measured) true vertical 6470' feet ~ ..... Datum elevation (DF or KB) 63' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-06 9. Permit number/approval number 1~-202 10. APl number 5o-029-21707 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 3 31 ' feet Junk (measured) true vertical 6366 feet ;i~. -: Casing Length Size Cemented Structural Conductor 8 0' 1 6" 198 Sx CS II Surface 348 9' 9 5/8" 1100 Sx AS III & Intermediate 350 Sx Class "G" Production 7423' 7" 300 Sx Class "G" & Liner 175 Sx AS I Perforation depth: measured 7132'-7142', 7155'-7180', 7186'-7190' MD true vertical 6204'-6212', 6223'-6243', 6248'-6251' TVD Measureddepth Trueverticaldepth 115' 115' 3526' 3399~. 7423' 644~ Tubing (size, grade, and measured depth) 2 7/8", 6.5 Ib/ft, EUE, IPC 7040' MD Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA1798'~ Packer: Camco HRP-1-SP 7009' MD 13. Stimulation or cement squeeze summary NOV o 7 ]988 Intervals treated (measured) Treatment description including volumes used and final pressure ~J~l~t~l~,;-,' Representative Daily AVe;age Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (producing) 890 1 295 - 0 1 1 25 ,, ,Subsequent, to operation (injecting) - 0 - - 0 - ' ''~ .4800 850 15. Attachments 16. Status Of well classification as: Copies of Logs and Surveys run.-. Water Injector X . Daily Report of Well Operations X Oil _ Gas Suspended 17. I hereby certify that the foregoing is true 'and correct to the best of my knowledge. FOrm '10-404 l~ev 06/15/88 /' 190 1700 Service SUBMIT I~ DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Compa~h, WELL SERVICE REPORT WELL JPBDT ')NTP~CTOR . __ · REMARKS OPERATION AT REPORT TIME IDAYS 1 DATE NOV o 7 1988, ['-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather lTemp' I Chill Fact°r I'VlSlblllty 1WIndReport OF OF miles Vel. ISigned REMARKS CONTINUED: DESCRIPTION DAILY ACCUM, TOTAL CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE WELL ARCO Alaska, InIi<> Subsidiary of Atlantic Richfield Compal!II~~' PBDT '75~1 ~)NTRACTOR REMARKS .-~ c, ~. IZ.W I ~.~[~ tFIELD - DISTRICT · STATE PERATION AT REPORT TIME WELL SERVICE REPORT ~ o~/l~m p~-~ ~s. ~ ~ ~L~ ~. ~5 ~ b~ 5~00 ~oo ~oo ~ lO0 z ~oo z I ~o 77 7_4~5 [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. Factor .o. 0.~c.. 0~t'"' 7"~' mllel REMARKS CONTINUED: ACCUM. DESCRIPTION DAILY TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER C~ ~ q ~ B. J. HUGHES Roustabouts - Diesel [=~ 0 ~ ~ . ~ ~ ~' ~'/~ .8 Methanol Supervision L., ~,$. 5 45'7 Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE t ~::)~ ~ ~ ARCO Ala~lnc. 0CPFUrmslte3 Morn,ng Heport Date / ~ ~ Time ~o Drillsite -.~ Status Production Well Status Gas Lift Status Shut-In Well P.T. or TP Choke Temp Last H2S CSG Pressure PSI Gas Inj. Rate # SI [one PSI Bean OF WC% 3PM 7" 10" Temp VleterTotal MSCFD Hrs Reason Total Status I Injection Well Status Shut-In Well Gl, PW Iniect. Pressure PSI Temp Choke 3SG Pressure PSI Meter Injection Rate # or SW '.one Allowable Actual OF Bean 7" 10" Total I. BBLS/Day MMSCFD Hrs. Reason i~ /~o I~O ~ 3~ ~go ~ ~1~ Total I ~ G~ SWI Total I · ~( ~, 5" PWI Total Drillsite Coil Temperature °F Coil Pressure PSI . Bath Blanket Heater Prod Test PrOd ' Test Temp. Gas PSi Run Tim~e Out /~o 2o,$' ?Zo /3,5" ~. f'y' Zt.o Z'./ Chemicals Type Oal~2 Tank: Meoh/Diese.[. I Level Temp. Comments Operater's Signature J,/~///,~""/A Headers Production Water Iniection Gas Injection . Gas Lift Drain Pressure ,,~ ~ ~o /,_~5"'0 1-8: ..... Temperature 9-16: A~RCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 22, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and. Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. The wells are listed below. Well Action Anticipated Start Date 2A-2 Conversion ~~02'Conversion 3M-7 Conversion 3M-12 Conversion 3M-21 Conversion March, 1988 April, 1988 April, 1988 April, 1988 April, 1988 2D-9 Fracture March, 1988 2G-11 Perforate, Fracture March, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:pg:0165 Attachments cc: File KOE1.4-9 RECEIVED AI~ska Oil & Gas Cons. Commiss[ot] Anchorage //'"'~ STATE OF ALASKA /~ ALAS,,~ OIL AND GAS CONSERVATION COM,,.,~SSION 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 ARCO Alaska, Inc 3. Address PO Box 100360. Anchorage: AK 99510 4. Location of well at surface 1181' FN~, .169.4~ F[L, Sec.25, T13N, R8E, UM At top of proouct~ve interva~ 595' FNL, 1015' FWL, Sec. 30, T13N, R9E, UM At effective depth 552' FNL, 1127' FWL, Sec.30, T13N, RgE, UM At total depth 525' FNL. 1197' FWL: Sec.30: T13N_. RgE: IIM 11. Present well condition summary Total depth: measured 7460' MD feet true vertical 6470' TVD feet 5. Datum elevation (DF or KB) RKB 63 6. Unit or Property name Kunaruk Rivmv, [Init 7. Well number 3M-6 ~~ 8. Permit number Permit #87-26 9. APl number 5o- 029-2170700 10. Pool Kunam~k River' fill Pnnl ! Plugs (measured) None feet Effective depth: measured 7331' MD feet true vertical 6366' TVD feet Casing Structural Conductor Surface xxk~t~[00x~d~ Production xx~k~xxxxx Perforation depth: Length 80' 3489' Junk (measured) None measured Size Cemented 16" 198 SX CSII 9-5/8" 1100 SX ASI I I & 350 SX Class G 7423' 7" 300 SX Class G 7423' MD & 175 SX ASI. 7132'-7142', 7155'-7180', 7186'-7190' MD, Measured depth True Vertical depth 115' MD 115' TVD 3526' MD 3399' TVD true vertical 6204'-6212' 6223'-6243' 6248'-6251' TVD Tubing (size, grade and measured depth) 2-7/8", 6.5 lb/ft, EUE, IPC, 7040' MD ~;aSc~r:s and SSSV, tvDe and measured depth) Camco TRBP-1A-SSA @ 1798' MD. 6440' TVD RECEIVED, Alaska Oil & Gas Cons. C0mmiss/0~ Packer: Camco HRP-1-SP 0 7009' ~ch0mge 12.Attachments Description summary of proposal ~ Detailed operations program [] Convert well to w~i;er injection. 13. Estimated date for commencing operation April, 1988 14. If proposal was verbally approved Su]3scquent ~Vork B, eported on _ ~ Form No../-O-z..~Dated-/-]/-]-/-~r~ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Sr. Operations Engineer BOP sketch [] Date 3/10/88 Commission Use Only Conditions of approval Approved by Notify commission so representative maywitness [ Approval No. d~..._j~,~L [] Plug integrity [] BOP Test [] Location clearanceI '~ Mech~.~cal ,,-.~..~.. ,~ T~st Approved Copy ORIGINAL SIGNED BY LONNtE C. SMITH Form 10-403 Rev 12~-85 Returned.._ Commissioner by order of ~ the commission Date 3'3/' Submit in triplicate ~ff/ Kuparuk Well 3M-6 Well 3M-6, which is currently an oil producer, will be converted to a water injector. No down hole wireline work is required. Surface facility modifica- tions such as pipe spool replacement, turbine meter installation and miscella- neous instrumentation changes are required. The well will be shut-in for approximately 48 hours when the facility modifica- tions are being made. During this 48 hour shut-in period, wellhead pressure and fluid level measurements will be taken to calculate bottom hole static pressure. KSH:tc:0119 RECEIVEI) MAR 2 z, !fi~8 Oil & Gas Cons. Commission Anchorage ~ ,STATEOF AiLASKA f""~- ' ALAS.~,A ~IL AND GAS CONS~ERVATtON ~MMJSStO~ ~d~ WELL COM I "OR P ION R ORT AND LO · , .:...~ , Well Classification of :Service 1. Status .of Well ~ - OIL [~ ,GAS [] SUSP~EN~DED [] A~BA~NDC~N'ED .i-T] SERVICE 2. Name of OPerator 7. Permit Number ARCO Alaska, Inc. .~.,:; '~'~,, . ~_87-26 3. Address 'CC !~ 8;APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 ,:~ r~ 80='; 029-21707 ,' ; ........ 4. Location of well at surface t, :, ;~ ' g. Ui~it or Lease Name 1181' FNL, 169/+' FEL, Sec.25, T13N, R8E, UN Kuparuk River Unit; At Top Producing Interval 1:0. Well' Number 595' FNL, 1015' FWL~ Sec.30, T13N, RgE, UN 3N-6 At Total Depth 11. Field and Pool 525' FNL, 1197' FWL, Sec.30, T13N, RgE, UM Kuparuk River Field 5. Elevation in feet ,(~ndicate KB, DF, etc.) 6..Lease Designation and Serial No. Kuparuk Ri vet 0~ 1 Pool RKB 6/+' ABL 25521 ALK 2557 , ' I 12. Date Spudded t3..:Date T.D. Reached 14. Da~e Com~., Sum. or Aband. 15. Water Depth, if offshore 1~. No. Of Completions 0/+/17/87 0/+/22/87 10/16/87' . N/A feet MSL 1 17. TOtal Depth (MD+TVD) 18.:Plug.Back,Depth (MD+TMD), ,'9. Directional Survey . ! 20. Depth where SSSV set I 21. Thick<ness of Permafrost 7/+60'ND, 6/+70'TVD 7331 'MD, 6366'TVD YES E~ NO []I 1798' feet MD! 1600~ (approx) , 22~ Type ,E[ect, ric or O~her Logs RUn DIL/SP/GR/SFL~ FDC/CNL~ Cyberlook, Cal, CBT, GCT 23. .CASING., ..L.I.N,ER. AND CE-.M.ENTING RECORD,.. SETTING DEPTH MD AMOUNT PULLED CASING SIZE WT. P-ER FT. GRADE TOP BOTTOM HOL~ SIZE CEMENTING RECORD,_ ~ ,~ . 'lb" 62:5# H-/+O Surf 115' '2M' 198 sx CS II , 9-5/8" 36.0# J-55 Surf 3526' 12-1/M' 1100 sx AS III & 350 s~ Class G 7" 26.0# J-55 Surf 7423' 8-1/2" 300 sx Class G & 175 s~ AS I , 24. Perforations open to P~oduction (MD+TVD of ~Tep and Bottom and 25. TUBING RECORD interval, size and .number) SJZE DEPTH SET (MD) PACKER SET (MD) Perforated w/1 spf, 120° phasing 'Z-7/8',' 7040' 7009' 7132.'-71/+2'ND 620/+'-6212'TVD , 7155,,7i'80,HD 6223,-6243':TvD .~ . .: ~ 26. ACID, FRAcTuRE;cEMENT SQ4JEEZE, ETC. 7186 ' -7190'ND 62/+8 ~ -6251 ~TVD DEPTH tNT'ERVAL (M~)) AMoUI~IT & KIND OF MATERIAL USED See al;t;ach.ed Adderdum~ dat;ed 10/21/87~, ~. ~ ~ fo~ Tract;ute data. _ Date First Production ii Method of Operation (Flowing, gas lift, etc.) I Date-of Test 'Hours ,'r, es:ted PRODuCT].ON .FOR. OJL-B:BL GAS,MCF WATER~BB,~L~ CHOKE SIZE { GAS-O1L RATIO TESTpER~OD i~''' ': . ~ .Flow Tubing Casing,pressure ' CALCULATED :6i.L-BBL' GAs:MCF' WATER,BBLOIL~RA~/ITy-A'pt (c°rr) Press. 24-HOUR RATE I~ ,, · 28. CORE :DATA , Brief descript, ion of Hthelogy, porosity, fractures, apparent dills and p;esence of 0il, gas or water. Submit core chips. RECEITED NOV 1 . · , Alaska 011 & Gas Cons. Commbslor~ Anchorage *Not;e: Drilled RR /+/23/87. Perforated well & ran t;ubJn9 7/7/87, Fract;ured well 10/16/87, . , .... '' ' ' '' :Form 1.0-407 Rev. 7-1-80 CONT:I:NU.ED ON REVERSE SIDE Submit, ., in duplicate~ 29. ~' ' 301~ {' ~ GEOLOGIC MARKERS FORMATION TESTS ~.'. . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7126t 6199t N/A Base Kuparuk C 7126~ 6199~ Top Kuparuk A 7126~ 6199~ Base Kuparuk A 7228~ 6282t . :. 31. LIST OF ATTACHMENTS Addendum (dated 10/21/87) 32. I hereby certify that the foregoing is true and correct to the best of my'knowledge Signed (~~_~/~_,L~_~_., Title Associate Engineer' Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service WellS: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 2'3: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~107 ADDENDUM WELL: 5/01/87 10/16/87 3M-6 RU Schl, rn GR/JB to 7318' WLM. Rn CBT f/7312'-5300'. Rn GCT gyro f/7280'-surf. Frac Kuparuk A-1 and A-2 zone perfs 7132'-7142', 7155'-7180' & 7186'-7190' in ten stages per revised procedure dated 10/7/87 as follows: Stage 1: 100 bbls gelled diesel @ 10-20 BPM, 4950-4300 psi Stage 2: 460 bbls gelled diesel @ 20 BPM, 5450-3850 psi Stage 3: 20 bbls gelled diesel 2 ppg 12/20 sand @ 20 BPM, 3800 psi Stage 4: 30 bbls gelled diesel 4 ppg 12/20 sand @ 20 BPM, 3800-3920 psi Stage 5: 40 bbls gelled diesel 6 ppg 12/20 sand @ 20 BPM, 3750-3680 psi Stage 6: 40 bbls gelled diesel 7 ppg 12/20 sand @ 20 BPM, 3710-3650 psi Stage 7: 40 bbls gelled diesel 8 ppg 12/20 sand @ 20 BPM, 3670-3700 psi Stage 8: 30 bbls gelled diesel 9 ppg 12/20 sand @ 20 BPM, 3760-3820 psi Stage 9: 24 bbls gelled diesel 10 ppg 12/20 sand @ 20 BPM, 3990-4040 psi Stage 10:40 bbls gelled diesel flush @ 20 BPM, 4080-7900 psi Calculated 42.7 bbls flush. Screened out w/40 bbls pmp'd. Shut down. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 755 bbls 45,567# 3433# 3836 psi Drilling gupervis6r NOV 6 Alaska 011 & Ga8 Cons. AnchoraGe / Date HICROFI M, SUB.SURFACE DIRECTIONAL SURVEY ~] UIDANCE ~'~ONTINUOUS [-~ OOL Company ARCO ALASKA, INC. Well Name 3M-6(].181' FNL~l. 69..4' FEL~SEC Field/Location KUPARUK~. NORTH SLOPE,. ALASKA I .25)T1 3NmR8E.UM) Job Reference No. 72305 SARBER RECEIVED Date JUL 2 9 !~87 30-APR-87 Alaska Oil & Gas Cons. Commission Computed By; Anchora.oe K R U N E L L ri i · $CHbU#BERGBR ~ GC? DZRECTZONA~ SURVEY CU.~TOMER bISTING ARCO AbABKA, INCe~ 3Meb KUPARUK NORTH 8bOPE,AbASKA SURVEY DATEr 30-APR-8? £NGINEERI G, SARBER METHODS OF COMPUTA?ION TOOb bOCA?IONI ?ANGEN?IAb- Averaged deviation and azimuth INT£ReObA?IONI bINEAR VER?ICAb 8ECTIONI HOR~Z. DIS?. PROJECTED ONtO A TARGE~ A~MU~H Or NORTH ?~ DEG 40 M~N gA&~ ARCO ALASKA, XN¢. 3#-6 KUPARUK NORTH SLOPEFALASKA CO#POTATION DATES 17-MA¥-87 PAGE- KE:LL'¥ DATE OF' 8URVEI[: 30~AFIq-17 BUSHZNG ELEVATICONI 64.4)0 ~NG~NEERI G,~ SARB~R INTERPOLATED VALUES FOR EVEN 100 FEET or MEASURED DEPTH TRUE lqEi~iSURED VERTZCAL VEl EPTH 0~00 100,,00 200,,00 700. 90O 1000,00 999 94 11,00,00 1099 94 1300,00 1199 94 1300,00 1299 94 140~*00 1399 94 150 ,00 1499 93 1600,00 I599~93 1700.00 1699,93 t800,00 1799,92 1900,00 1899.92 o0 t999, o0 2099: O0 2199 O0 2299, O0 2398, O0 2495, O0 2592 O0 2686~ 2872 O0 '2961 O0 3048 o0 3134 O0 3218 O0 O0 3456 o, 3535 oo .00 95 -0,34 0~34 0',15 $ 0,32 # 0,35 $ 64 S9 # 95 t35,95 9 ~ $ 46 24 N -0,9} 0~60 $ ~ 0 22 S 66 12 . 008 94 235,94 0 ~, $ '6 5~" :1.,? ~:t* 0," $ 1.3t W 1.5t ' l* St" 94 535,94 0 14 S 17 33 N -2,78 0,92 1,41 8 2,55 699 94 635,94 0 7 S 82 58 ~ -2,84 0136 1.63 1.79 799 94 735,94 0 14 s 22 17 N -3,24 899 94 835,94 0 6 $ 66 58 N -3,31 6~ 2~06 ~ 2,96 N 3,61 8' 55~12 w 94 93,5,94 0 12 S 33 38 ~ -3,63 0~81 2~'13 S 3,28 N 3,91- $ S7 ! # 94 1035,94 0 4 N 22 38 W -3,61 0,52 2,26 94 1135,94 0 1.2 s 14 20 , :3,86 92 1835,92 0 29 ~ 50 55 E 5~,04 2135'85 2 48 N 64 5 E s 4,~63. : 4 a 0,4 E 20,69 N. 77 E 2431,66 14 2 N 82 8 E 48°78 3;02 48,09 E 48,~0. ~ 80 12 E 2528.05 16 48 N 81 53 E 75.34 I 37 '99 2622,99 19 24 N 8.2 38 E 106.60 16,,09 N 105,49 85 2716,85 21 29 N 82 I E 141,03 3,~3 20, q9 N 139,67 E 141,2! N 81 32 g 78 2~08,78 25 0 N 76 41E 180,33 4,01 28.03 N ~78,30 94 2984,94 30 33 N 77 24 E 274 78 2;~0 50 51 N ~14 3154 14 34 3 N 81 30 g 96 3392 96 38 40 N 82 19 g 562 22' 92 66 N 554,84 g 5~2052 N 80 i000 300 O0 "O0 000 tOO 3~00 3500 $00 700 800 9O0 CO#PUTATXON DATE1 17-MAY-B7 AbASKA~ :INC. DA~E Or ~g Y ~R NORTH 6~OPE,AbASKA ENGZNgER l . ZN~ERPObATED V~bUES FOR EVKN ~00 FEET Or NEA&URED DEPTH ~RUE SUB ~EA COURSE VERTZCAb DOGbEG REC~ANGUbAR CQORDZNATE8 DEPTH DEPTH DEPTH D~ NZN DEG. N~N FEET DES/JO0 FEET FE, E~ ' FEE~ 4100.00 3849,52 )?es.sa 38 25 N 82 la g 87L.39 i,l' 32, 4200.00 3927.77 3863,77 38 35 N 82 2~ E 933054 ~00,00 4:~61.,78 4097.78 3g 30 N 80 9 E ~120,94 2 0.~t 4600.00 42~'9,15 4175,~5 39 1~ N 79 10 E 1~84,2':8 4700,00 4~I6,.82 4252,82 38 52 N 7e 2~ g ~247,28 0,46 1 4800~00 4394,80 4330,80 38 36 N 77 47 E 1309.87 4900.00 4473.08 4400,08 3e ~4 a 77 4 g 1372.08 0.93 21,27 N I SSoG3 r ? ,ooo.oo ,? ,?,,, ,,,,.,, o , "'""'" ,,oo.oo ,,,.,? ,o.,, "?? '?' ,,,.o?. t ,I., 5~00.00 4705.3g 464[.39 40 29 N 76 39 E 156~.75 ~8 249,4? N t4~ ,~ 49 ~e 5400.00 4857.23~ 4793'23 40 4) N 75 38 E 169~.79 0 5 9S, 2 N 66'.2 5700000 5084.05 5020005 40 54 N 77 8 E 1887.72 3 42 346017 N 1855,88 E 5900.00 5234.75 5~70e75 4~ 4 N 78 37 g 2019.1'9 0 72 37~.44 N 1984,90 E 6000,00 53.~0,29 5246,2~ 4~ 53 N 77 49E 2o84.71 o 3o 384,8? N 204~ 04 6200.00 5386,3? 53~2.37 39 57 N 76 4~ E 2t49'.59 1 52 399.1~ N 2~2 25 E 5477.33 36 40 N 75 I E 2275.88 6300,00 5541,33 6600,00 5777.63 57i3'63 37 29 N 72 37 E 2460.03 0 5 N 2 670:0,00 5657.~14 5793'14 37 10 N 7~ 49 E 2520,30 0 6 4~ ; N '4 E 6900.00 60~7,03 5953.03 36 40 N 70 8 E 2639.34 68 ~ t ~ N · : 8 E 7200,00 625g,01 6195,OX 35 35 N 68 45 E 2814.~2 0 ~ 60., '4 N 49 ' 7200;00 6340,30 6276,30 35 36 N 69 X $ 287X*?X 0 O0 62, 4 N SO4 7400,00 642~,60 6357,60 ~5 36 N 69 1 E 2929,~2 0 O0 64 ,~ 9 N 858 42 E 29 ?460.00 6470,37 6406.37 35 36 N 69 t ; 2963.57 0 O0 655.90 N 289X 04 CO#PUTATION DATEI 17-MA¥-87 PAGE: ARCO ALASKA, INC.~ DATE OF SURVEY 30-APR..9? 3N-6 KELLY BUSHING EbEVAT.~ON~ 64000 IrT KUPARUK NORTH SLOPB;AUASKA ENGZNEERI G.o~ BARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH NEASURED VERT,CALTRUE SUB-SEAvERTICAL DEV!AT~oNzOURSEA~I#UTH VERTICAL DOGLEG. RECTANGULAR COORDINATES HORZ~.: DEPARTURE ~ECTZO, SEVERITY NORTH/SOUTH EA~T/,E$T D,~T~. DEPTH DEPTH DEPTH DKG NZN DEG ,IN FEET DEG/IO0 FEET FEET FEET CO#gUTATION DATE~ 1'/-MAY-e7 PAGE 4 ARCO ALASKA~ %NC, DATE OF SURVEY 30~AIPR-,8"; )N,,6 KELLY BU,SH'J;NG. ELEVATION~ 64,00 FT KUPARUK NORTH SLOPE,ALASKA ENGINEERI. G,, SARBER INTERPOLATED VALUES FOR EVEN 200 FEET OF' SUBoZSEA DEPTH SUB-SEA.... COURSE VERTXCAL DOGLEG RECTANGULAR COORDINATE6 HORI~,'.~ DEPAR'~:u.U. RE TRUE ' VERTicaL UTH SEVERITY A~ZI4U~ NEAIURED VERTICAL DEVIATXON AZl# SECTION NORTH/SOUTH EAST/#EtT DIST.~ rn o.oo o.r .,:oo i,l o !!'" o.oo o.,, ,,.o, .. oo oo ,~ ,~ ,~ o.oo o oo o.oo 0,1;1 ~ 0,00 0 0 7,,.0, 764.oog ~, o' ,*'1 ~o6~.o6 ~o64.oo ~ooo oo ~ '~ 2 39 03,80 X~64,0o ' ~,94 4,66 ~0 ,,..oo oo : ~:~ t664.00 O0 ~ 3 1~ [ :2:8~ 4.64 ~ 2.53 48 5,04 1764'00 O0 ~ 26 ~ 25 ~.95 I 4'.89 48 :,..oooo I~ ~ * [ ,.,o. I t 41,'27 i76.34 ,: I 27,.19 N 174 41 ~ 176,5~ :... 4. ,:6,,oo ::o( I~ I ~ ::,,.oo :2o(I ~ ,:[ 74:60 406 43 ~ J-O( ~ 4 488,~$ 8 , 4 481. 35 488.52 ' 567.87 560~ 45 568.18 ARCO ALASKA, INCo KUPARUK NORTH SLOPE~,ALASKA COHPUTATZON DATES 17-#A¥-67 DA?E OF SURVEYS KELLY BUSHING EL£VATZONI ENGXNEERS P&GE 5 30q,,APR-B7 64..00 FT Ge, S&RBER XNTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTXCAL DOGLEG RECTANGULAR COORDXNATE3 HORXZ, DEPARTURE HEASURED VERTZC&L VERTXCAL DEVXATtON AZI#U?H SECTXON SEVERITY NORTH/SOUTH DEPTH DEPTH DEPTH DEG NXN DEG #XN FEET DEG/XO0 FEET FEET FEET DEG #XN 4246037 3964 O0 3900 00' 38 38 N 82 20 E 962,41 0 21 148 43 N 951 61E 963 3! N 81 8 E 4374030 4064 O0 4000 O0 36 32 N 81 57 E 1042,05 010 N 1030 84 E t043 4.632,06 4264 O0 4200 O0 39 6 N 78 59 E 1204,55 0 37 186 49N 119 13 E 1205 64 N 8:_6 E 5408,95 4864 O0 4000 O0 40 43 "75 34 E ~697,63 0 5' 296 67 # 167 94 E 93 a 1755 §~,~ ~ 4964,00 4900 O0 40 54 N 74 34 E 17,83 0 54 3~8 45 5064 O0 5000 O0 40 53 N 75 48 E 1870 3 40 342 01 E 1870 57 " 7! 27 E 67 1924 359 64 376 79 .800 O0 40 N ~7 3 E 2 83 ~ 2044 "?' 2' E N 55 E O0 ~9 75 19 58 . ~ N 49 E 94 4 , 434 O0 ~:~!:t~ ~5~648005564i00' ~&O0 37 N 4.42 E ' 60 6 ~ ~ ~ 6708 6, 5864.00 5800 ~;" ~ 63 6833,83 5964 6064 6958.~ 708~; 6164 ~,~2.~16 6464 7'~60.00 6470 O0 o, oo 6t0 OOoo O0 6400 37 6406 O0 36 6 N 70 39 28 0,63 525 oo ,, 16 "[ oo ,.., , , . O0 35 36 k 69 I E 2959007 0,00 654 37 35 36 N 69 ~ E 296~'57 OeO0 655 2616 83 ~ 2685 62 N 75 2891 49 E 2746 E 2889 76 E 2959 04 E 2964 23 N 7820 E 99 $ 77 51 ~ 77 ARCO AbA6KAf, XNCe' UPARUK NORTH &bOPEeAbA6KA COMPUTATION DATEI 17-MA¥087 PAGE 6 DATE OF SURVEYI 30~APR-87 KELbY BUSHING EbEVATIONI 64000 FT £NGINE~RI Go SARBER #ARKER ZNTERPOLATED VALUES FOR CHOSEN HORIZON& SURFACE LOCATXON ' A --PTH ORIGINs 1181FNL, 1694 FEb. SZC. 25.~TI3N. RSE, UN MEASURED KBTVD RECTANGUbAR COORDZNA?gS~ · BELON FROM 8UBoSEA NORTH/SOUTH EAST/#EST'- 116000 619809 585093~~ 2709037 TOP. KUPARUK ¢ ~t ~:00 6198,9~ 6134,98 ;~.BASE*KUPARUK C 61~40~8 585,93 ~ f--~OP KUPARUK A O0 6198,9 585,93 ~ 2?00,.37 6134,98 2?09,5? L~eASE KUPARUK A ~ : 6365'5~ 629.01 PBTD 460,00 6470,3 655,90 a ARCO ALASKAA INC, iH-6 UPARUK NORTH SLOPE,ALASKA CO#PUTATION DATES 17-#A¥-87 PAGE '7 . DATE: OF ~URVEYI 30?AFROS? KELLY BUSHING ELEVATION: 64,00 FT ENGINEERS G,~SARBER #ARKER TOP KUPARUK C ~.~..~ASE KUPARUK C Q::,OP KUPARUK A -,eASt KUPARUK A PBTD TD MEASURED DEPTH BELOW KB ORIGIN8 I181. FNLp TVD FROM KB SUB-SEA &URFACE LOCATION AT 1694 FEb,.SEC. 25, Tt3N. RSE, UN RECTANGUbA~ COORDTNA~ES NORTH/SOUTH EAST/#EST 7126.00 6198,98 6134,91 585.93 ~.00 6198.99 6134.98 585.93 ~!~.00 6262.~? 6217.77 .44 ,.oo ,00 6365050 6301,50 6 9, 000 6470037 6406,37 6~5 O1 090 2 6 ,93 E 2820,90 lC 2891,04 E FINAL NELL LOCATION AT TDI TRUE SUBoSEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7460,00 6470.3? 640603? HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2964,51 N 77 13 E SCHLUMBEROER O I REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC. WELL BM-8 F I ELD KUPARUK COUNTRY USA RUN ! DATE LOOOEO 30 - APR - 87 REFERENCE 7230S WELL' 3M-,6 (~,181,,,FNL, 1694' FEL, SEC 25, TI3N, R8E, UM) HORIZONTAL PROJECTION N~RTH 2500 REF 72305 SCRLE = l / 500 IN/FT ~000 I l~O0 ! 000 SO0 -EiO0 - ! 000 SOUTH -1500 WES? 500 1000 I~O0 - .REC'EIVED JUL 2 Alaska Oil & Gas Cons. Commissio,~ ~chor~e WELL' 3M-6 (ll-81'.,.FNL; 1694' FEL, SEC 25, T13N, R8E, UN) VERTICAL PROJECTION 258. -BOO 0 0 500 1000 ISO0 2000 2SO0 9000 ~SO0 ?8. PROJECTION ON VERTICAL PLANE 78. - 268. SCALEO IN VERTICAl. DEPTHS HORIZ SCALE = 1/S00 IN/FT Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 26, 1987 Transmittal ~ 6041 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 acknovledge receipt and. return'one, signed copy of this transmittal. , 2U-13 Static Well Pressure Survey tCt Sand 8-27-87 3H-8 Kuparuk Well Pressure Report tA~ Sand 7-10-87 ~3H-? Kuparuk Well Pressure Report ; 8-13-87 ~3~-~ Kuparuk. We11 Pressure Report ~A~ Sand 8-12-87 ~3H-5 Kuparuk Well Pressure Report ~At Sand 8-12-87 · '""-3H-4 Kuparuk Well Pressure Report 8-11-87 100554H Receipt Acknowledged: DISTRIBUTION: BPAE Chevron Hobil SAPC Unocal State of A~aska ( D & H' ARCO Allskl, Inc. Il · Subsldilry ol All· .nllcRIchlleldComp.ny STATE OF ALASKA ~ OIL AND GAS CONSERVATION cO,v,..,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other IX CONPLETE 2. Name of Operator ARCO A]aska~ Inco 3. Address P.0. Box 100360 Anchorage~ AK 99510-0360 4. Location of well at surface 1181' FNL, 1694" FEL~ 5ec.25~ T13N~ R8E~ UN At top of productive interval 595' FNL~ 1015' FWL, 5ec.30~ T13N~ RgE, UN At effective depth 552' FNL~ 1127' FWL~ $ec.30~ T13N~ RgE~ UN At total depth 525' FNL~ 1197' FWL~.Sec.30~ T!3N~ R9E~ UN 11. Present well condition summary Total depth: measured 7460'MD true vertical 6470 'TVD Effective depth: measured 7331 ,ND true vertical 6366'TVD 5. Datum elevation (DF or KB) RKB 64t 6. Unit or Property name Kuparuk River Untt 7. Well number 3t4-6 8. Approval number 7-32~ 9. APl number 50-- 029-21707 10. Pool Kuparuk River 0il Pool feet Plugs (measured) None feet feet Junk (measured) None feet Feet Casing Length Size Cemented Measured depth Conductor 80' 16" 198 sx CS II 115'ND Surface 3489' 9-5/8" 1100 sx AS I II &. 3526'MD 350 sx Class G Production 7423' 7" 300 sx Class G & 7423~MD 175 sx AS I True Vertical depth 115~TVD 3399 ~TVD 6~0 ~ TVD 12. Perforation depth: meaSured 7132 ' -7142 'ND, 7155'-7180'MD~ 7186'-7190'ND true vertical 620~'-6212'TVD~ 6223~-62~3'TVD~ 62~8'-6251'TVD Tubing (size, grade and measured depth) 2-7/8", J-55 tubing w/tail @ 7040' Packers and SSSV (type and measured depth) HRP-1-SP pkr ~ 7009' & TRDP-1A-SSA SSSV ~ 1798' RECEIVED JUL29 Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure Alaska. 0il & Gas Cons, Commission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Inte.ction Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Comp] etion We] l History w/Addendum, dated 5/16/87) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [~ Gyro 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~- Signed & ~/~.~ .~J~)J.A~ Title Associate Engineer Date Form 10-404 Rev. 12-1-85~' ~ (Dani) SW02/SZ~ Submit in Duplicate ARCO 0il and Gas comPany Dally 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 8old. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting Dlstr,ct ICounty or Parish I State Alaska North Slope BOrough Field ~Lease or Unit ADL 25521 Kuparuk River 'Title Auth. or W.O. no. AFF. AK2068 I Completion Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 7/07/87 Date and depth as of 8:00 a.m. 7/08/87 Complete record for each day reported cost center code Alaska Well no. 3~-6 AP1 50-029-21707 W.I. rl'otal number of wells (active or inao{ive) on this Icost center' prior to plugging and 56.24% Jabandonment of this well IHour I Prior Stettll If · W.O. 7/06/87 / 1815 hrs. I 7" @ 7423' 7331' PBTD, Rn'g compl string 10.0 ppg Nat1 Accept ri& @ 1815 hfs, 7/06/87. ~ tree. NU & tat BOPE. RU la.,, perf 7132'~7142', 7186'-~190', 7155'-7180' @ 1SPF, 120° phasing. ~ake GR/JB tn to 7100'. RD WL. RIH w/2-7/8" compl. 7" @ 7423' 7331' PBTD, RR .6:9 ppg Dieseel En 212 Its, 2-7/8", 6.5#, J-55 SUE 8RDAB Mod tbs w/SSSV @ 1798', HRP-I-SP PAr @ 7009', TT @ 7040'. Tat tbs/ann to 2500 psi; OK. bid BOPE, NU & tat tree to 250/5000 psi. PR@ 1200 hfs, 7/07/87. RECEIVED JUL 2 9 1987 Naska 0il a Gas Cons. Commission Anchorage Old TD Released rig 1200 hrs. Classifications (olli gas, etC.) 0:[1 Producing method Flowing New TO Date 7/07/87 PO Depth 7331' PBTD Kind of rig Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) KUparuk Sands Potential test data Well no. Date Reservoir Producing Interval OII or gas Test time Production OII °n test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signatul~'l ~/...~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, PageS 86 and 87. Drilling Supervisor WELL: 51o1/87 3M-6 RU Schl, rn GR/JB co 7318' WLM. Rn GCT gyro f/7280'-surf' CBT f/7312'-5300'' RECEIVED JUL 2 9 1~¢7 Naska 0il & Gas Cons. Commission Anchoraoe ARCO Alaska, Inc, ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: COnductor As-Built Location Plat- 3M Pad (Wells 1-22) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure Alaska 0il & Gas Cons. 6ommisslort Anchorage ARCO Alaska, Inc. is a Subsidiary of AflanticRtchfleldCompanY SIMPSON LAGOC44 Vi;IHITY MAP SCALE Imm E. MILES' ' ALL WELLS LOCATED IN SEC. 25, TI3N, R8E, UMIAT MERIDIAN. ASPs 'X' LATITUDE SOS,ET' S06,Z89.40 SOS,tOO.OS ,641.02 506,$08.76 ~Ol~ ,~,&3.8"; ~;o6,, ~lT.~4r~,' NOTES: I. ALL COORDINATES ARE A.8-O. , ZOHE 4. I HEREBY CER'TiFY THAT I Aid PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 3/8/87 Z.ALL DISTANCES SHOWN ARE TRUE. $.ELEVATiONS ARE B.RM.S.L. 4.REF. FIELD BOOK LOT-$ o POt` T.It; LeT-It R?; LST.$,PSI - S$; S.O.G.ELEVATIONS FROM ,.R. BELL & ASSOCIATES. ,.,o,,ZO.T,~ ,os,,,=s ,,,~ o, ,, c~.~ 1'~ ~ I~ IdONU~NTS PER LND & ASSOCIATES. J U L o ~ ~5B7 ;t.F.N.L. 1296' IT41' Z$.I' t6.6' JtT~: 1732 23._8', tS.e' ItSO, IT~t ~.S, tS.O: I:~ZT' I?i$ 25.4 2e.O; ,~o4: ~To~ I I t I 1604 lice: 1084 II~S IGTS ~.1, ~S.&, iME', le3e, ,.o,o ,ez6 996** 1617: ~1.4: Ze.4: 073 ,eD? ,,., OS~*, 1598 ti.l: 26.4~ 0ET, 1586 tO.O, 86.~ 904, IS/l 881 1569 80.0 ~6.S 858' 1559 RO.O* 26.6 ~35 ' l~' ZO.~' ZS.q' j~' /7~/' Z~.O' Z~.Z / ~)' /7~' ~.o' ze,~ · ARCO Alaska Inc. D.S. 3M WELL CONDUCTOR AS-BUILT & ASS( , DWN BY: GLL CHK BY: AJR ARCO Alaska, InC./.-*--~ pos o.ic I , oo3eo Anchorage,'~ .~ka 99510-0360 Telephone 907 276 1215 Date: May 26, 1987 Transmittal #5984 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. '~3M-9 OH LIS Tape 5-2-87 72291 ~ 3M-8 / Re-Formated Field Tape 4-15-87 · OH LIS Tape 4-21-87 72283 72274 ka Oil & G~s Cons. CommissMn ~ Anchoraoe Receipt Acknowledged: Date: DISTRIBUTION: 'State M. Stanford ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska, In ~'i' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date:- May 12, 1987 RETURN TO: ARCO Alaska, Inc.' Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal # 5976 Transmitted her&~ith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-7 3K-9A 3K-8 3K-17 lA-10 3Q-16 %A-2 3Q-15 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-837~ CET 11-15-86 7940-9400 CET' 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC. ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRichfleldCompany ~ STATE OF ALASKA ,~t~_. ALA~,,,~~ OIL AND GAS CONSERVATION CO,v,,,,,oSION ,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 5. Datum elevation (DF or KB) ARCO ATaska, I nc RKB 63' fe~ 6. Unit or Property name 3. Ad61re~_. ... Box 100360 Anchorage, AK 9951 0-0360 Kuparuk River Uni 1: 4. Location of well at surface 1181' FNL, 1693' FEL~ Sec.25~ T13N~ R8E~ UN At top of productive interval ... 618' FNL, 1116' FWL~ SeC.30~ T13N~ RgE, UN (approx.) At effective dePth 519' FNL, 1-127' FWL~ Sec.30, T13N~ RgE~ UN (approx.) At total depth 490' FNL, 11-97' FWL~ Sec.30~,... T13.N.~ RgE, UN 11. Present well condition summary Total depth: 7. Well number 3N-6 8. Permit number 87-26 9. APl number 50_029-217o7 10. Pool Ku'pa ru k River ,, measured 7460'NB feet Plugs (measured) None true vertical 6471'TVD feet Pool Effective depth: measured 7331 ' ND true vertical 6367'TVD Casing Length Size Conductor 80 ' I 6" Surface 3489' 9-5/8" Producti on 7423 ' 7" feet Junk (measured) None feet Cemented Measured depth True Vertical depth 198 sx CS II 115'MD 115'TVD 1100 sx AS II I & 3526'ND 3401'TVD 350 sx Class G 300 sx Class G 7423'MD 6441'TVD Perforation depth: measured None true vertical N o n e Tubing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None RECEIVED AlaSka 0i~ & Gas Cons. C0mmissi0~ Anchorage 12.Attachments WELL HISTOEY Description summary of proposal [] Detailed Operations program [] BOP sketch [] 13. Estimated date for commencing operation .(,,~,~;/U, 1987 14. If ~3roposal 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 ,_/' ~. Title As socia1:e Engineer Signed _ J . ~t~3l, ,,. . . Commission Use Only (Dani) $A2/52 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel Date .Approved by Form 10-403 Rev 12'1-85 ~mis$ioner by order of ~,-- ~ .,~ .v'3~ the commission Date ~ "'[~ ~ (~""-"'~¢~)Z~ Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instruction.:. Prepare and submit the "Initial Report,' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ' Alaska Field North Slope Borough IState Alaska IWell no. 3M-6 I County. parish or borough Lease or Unit Kuparuk River ADL 25521 Auth. or W.O. no. [Title AFE AK2068 [ Drill Doyon #9 API 50-029-21707 Operator ARCO Alaska, Inc. Spudded or W;O. begun [Date IHour SpUdded 4 / 17/87 0600 hfs. Complete record for each day reported IARCO W.I. Prior itatu, if a W.O. 56.24% Date and depth al of 8:~ a.m, 4/17/87 thru 4/20/87 4/21/87 4/22/87 16" @ 115' & 9-5/8" @ 3526' 4632', (4517'), RIH w/new bit Wt. 8.8, PV 7, YP 4, PR 9.0, WL 11.2, Sol 3 Accept rig @ 0200 h;s, 4/17/87. NU & cst 20" diverter. Spud well @ 0600 hfs, 4/17/87. Drl & surv 12%" hole to 3557', short trip, CBU, POH. RU & rn 89 its, 9-5/8", 36#, J-55 BTC cs$ w/FC @ 3444', FS @ 3526'. Cmt w/Il00 sx AS III & 350 ex C1 "~'. Bump plug, tst csg to 2000 psi. ND diverter, NO & tst BOPE. RIH, DO FC, tst csg to 2000 psi. DO FS + new hole. Perform LOT to 12.5 ppg EMW. Drl 8%" hole to 4632', POH, chg out bit & RIH. 476', 1959', 2449', 3199', 3672', 4300', 0.4°, S36.5W, 476 TVD, - 1.28 VS, -1.39, -1.03 1.10, Nll.7E, 1958.90 TVD, 4.03 VS, -7.33, 5.58 12.5°, N81.2E, 2445.97 TFD, 46.46 rS, 9.12, 45.56 31.9°, N78.2E, 3133.92 TVD, 334.49 VS, 62.39, 328.64 38.4°, N81.4E, 3514.72 TVD, 613.95 VS, 100.77, 605.96 38.8°, NSl.7E, 4006.20 T%q), 1004.40 rS, 158.38, 992.62 9-5/8" @ 3526' 6925', (2293'), Drl$ Wt. 9.2, PV 9, YP 3, PH 9.0, WL 8.2, Sol 6 Drl & surv to 6925'. 4835', 38.6°, N75.6E, 4423.73TVD, 1338.74 rS, 224.18N, 1320.43E 6349', 38.4°, N74.6E, 5583.39TVD, 2310.77 rS, 459.00N, 2264.73E 9-5/8" @ 3526' 7465', (535'), Drlg Wt. 10.1, PV 14, YP 10, PH 9.5, WL 5.2, Sol 11 Drl & surv to 7337', short trip, CBU, POE. RU Schl, log 8~" open hole w/DIL/SFL f/7326'-1000', CNL/FDC f/7300'-4450', Cyberlok f/7280'-6900', CAL f/7300'-3520', RD Schl. Drl f/7337'-7460'. 6917', 36.8O, N68.4E, 6033.41TVD, 2654.63 rS, 568.97, 2593.38 7337', 35.6°, N67.2E, 6372.33 TVD, 2898.22 rS, 662.70, 2873.05 RECEIVED MAY 1 i 1.qg7 Naska 0il & Gas Cons. Commission Anchorage Theabove is correct FOrforn~' preparation ...... .... and distr~utt°n,nrn~-n fl ,4 ,41.*,]~.*t,. ¥ seeProcedure, Manual, Section 10. Drilling, Pages 86 and 87. ITitle 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 PI.ugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ' I Accounting District ]County or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25521 Auth. or W.O. no. ITitle AFE AK2068 I Drill Doyon #9 Operator [A.~.Co. W.I. ARCO Alaska, Inc. - 56.24g Spudded or w.O. begun IDate Spudded I 4/17/87 Complete record for each day reported Date and depth as of 8:00 a.m. 4/23/87 coat canter code Alaska IWell no. 3M-6 AP1 50-029-21707 l ~)tal number of wells (activ® or In&c~ive) on this cst center prior to plugging and bendonment of this well I our I Pdor -.titus If · ~t'.O. 0600 I 7" @ 7423' 7465' TD, 7331' PBTD, RR 10.1 ppg Brine · C&C, POOH, LD DP. P.n 169 ]ts, 7", 26#, J-55 BTC + mkr ~t w/FC @ 7333', FS @ 7423'. Cmt w/100 sx 50/50 Pozz w/4[ D-20, .5~ D-65 & .2~ D-46 & 200 sx C1 "G" w/3[ lC1, .9~ D-127, .3[ D-13 & .2Z D-46. Displ w/280 bbls 10.0 ppg brine. ND BOPB, I40 tbs spool, tst to 3000 psi. RR @ 0100 hfs, 4/23/87. RECEIVED MAY ! ~ kq~7 Alaska 0~! & G;~s Cons. C0mmissior~ Anch0ra.~e Old TD Released rig 0100 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD J PB Depth 7465' TD 7331' PBTD Date IKind of rig 4/23/87 Rotary [Type completion (single, dual, etc.) S ingle Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct I ~S-"~--/~ I)rillins Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc...' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 310, 1987 Transmittal # 5968 Return t.o: ARCO Alaska, linc. Attn: Kuparuk Records Clerk ATO-III9 P. O' Box: 100360 Anchorage, AK 99510-O360 Transmitt'eci herewith are ,the fol. lowi~g item~. and return one signed copy of this OPEH HOLE FIHAL PRIHTSt 3N- 1,0 2" FDC Porosity 4-5-87 3389-711.9 Cyber look 4- 5-87 3389- 7144 5" FDC Porosity 4-5-87 3389-71i9 2" FDC Ray Data 4-5-87 3389-7119 '2" D[L &-5-87 3389-71~ 5" D[L 4-5-87 3389-71~4 2" FDC Porosity 4-21-87 4450-7300 Cyberlook 4-,2I-8-7 6900-7280 2" DIL 4-21-87 100O-7326 5" FDC Haw Data 4-21-87 44~0-7300 5" FDCPorosity 4-21-87 4450-7300 2" FDC Haw Data 4-21-87 4450-7300 5' DIL 4-21-87 1000-7326 Alaska 0il & Gas Cons. Comml~,,~lo[1 Ar'.chora3.~ Receipt Acknowledged: .......................... DISTRIBUTION: NSK Drilling Rat. hmell D & H ,~State of Alaska {* sepia) ':' Vault {.film) Date: ARCO Alaska, Inc. is a Subs,diary of AtlanticRichfieldCompnm~r ~~~~ - at~ ,~'ME -UM ..~ ,St., -,-o: c. v~~ ~~~ O~T~: ~ Chai~n ~ ~ RtENO.: · D.BDF.31 THRU': FROM: osT~ ~ Inspector TELEPHONE NO.: SUBJECT: of Alaska. 1987 ~ Teet The B02 test began at 8=2.0 a.m. and was Attachment . . ALASRA OZ~L & C/.S CO~:S~:R%',LT:IOH Gas De:et:ors. - . . · , ACC~TOR SYST~ Fu~l Charge ~ressure, ~~_~ pslg . ~u:p ~nc:. c2es. ~:es. 200 pstS, ~ :~~, sec. / .. ~pe: g~2~ / res: ~:essure Lower Ke~ / res: ~:essure ~~ ,, ~o. :~~ ~ ~ ....... ~us:a~e Chokes / ~vgra:~cz!/~ o~era:ed choke / hfs. April 14, 1987 Mr. J. B. Kewin Regional Drilling ~tneer ARCO Alaska, Inc. P.. O.. Box !00360 · Alas'~,-, 99510-0360 . · Telecopy: (907) 276-7542 ?tte, ~,~par~ River l~i~ 3M-6 Rev. ~O Alas~ka, Inc. Pe~c No. 87-26 Sur. Loc. llSt'FKL, B~ole 'Loc. Dear ~r. Kevtn :. Enclosed is the approved revised-application for permit to drill the above referenced well. ' Se provisions of the cover letter, dated ~l~¢eh 10, 1987, ace~anytng the ort~~I .approved per~i~ ~ ~ effect for ~ht8 revision. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE.- COMMISSION dlf EnclosUre ~a'rCment of Fish & Game, ~bi~ac Section w/o encl. ~parC~n~ ~ Environmental Conservation w/o encl Doug L..Lowe~ ' · ~ STATE OF ALASKA ALASKA ~_.~. AND GAS CONSERVATION CC. ,,ylISSION PERMIT TO DRILL la. Type of work Drill Re-Entry 2. Name of Operator ARCO Alaska, Inc. 20 AAC 25.005 Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Deepenq Service [] Developement Gas [] Single Zone~i~' Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool p3 ~dd~,ess ;u. aox 100360 Anchorage· AK 99510-0360 4. Location of well at surface ll81'FNL, 1693'FEL, $ec.25, T13N, R8E, UM At top of productive interval 618'FNL, 1116'FWL, Sec.30, T13N, RgE, UM At total depth 610'FNL, 1286'FWL, $ec.30, T13N, RgE, UM 12. Distance to nearest property line 610'~ Total Depth feet Kickoff depth?. 1 46 13. Distance to nearest well 3M-7 16' ~ 600'TVD feet 16. To be completed for deviated wells feet Maximum hole angle 41 0 18. Casing program size Hole Casing 24" I 6" 12-1/4' 9-5/8" 8-1/2" 7" Specifications Weight i Grade I C°upling I L~;g, th I I I I HF-E~W I 26.0#1J-55/ BTC 17403' I I RKB 63' PAD 26' · feet 6. Property Designation ADL 25521 -ALK 2557 7. Unit or property Name Kuparuk R~ver Unit 8. Well nurpber 3N-6 9. Approximate spud date 04/13/87 14. Number of acres in property 2560 Kuparuk River F~eld Kuparuk River 0il Pod 11. Type Bond (see 20 AAC 25.025) Statewide Number #8088-26-27 Amount $500,000 15. Proposed depth(MDandTVD) 7437'MD (6364'TVD) feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2 01 I psig At total depth (TVD) Setting Depth Top Bottom 35' I 35' I 115' I 115' I i Toc 5'p0, abov 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet ~08 7 pslg Quantity of cement (include stage data) ±200 ef 1225 sx AS III & 350 sx Class G blend 200 sx Class G(minimu~) e top of Kuparuk Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth T,~ib'~::-s~:.,j'ect we]] was originally approved 03/10/87 (APl No. 50-029-21707, Permit No. 87~26) i~¢'!tCc-~:~i..'-:due to Geo logica] data obtained~rom surrounding wells the~g~n~ h~*~'~bee-n'-changed as stated above. Any questions regarding ~h;s ch , , ~ e~d~ected t°'Har'.0'ld. Engel at 263-~882. , ... , , . -. -. .. . .. - -' - Alaska 0il · ,. -, ~ · ' ~, An~orag0 20. ~ttachmonts Fili~0 foo ~ ~roporty plat ~ BO~ Skotch ~ Divortor Skotch ~ Drillin~ pro, ram ~rillin~ fluid pr~ ~ lime vs d~ptn plot ~ ~ffaction analysis D Soa~e0 roport ~ 20 ~C 2fi.050 roquiromont~ 21. I horoby c~ify ~at tho ~or~n~ truo and corroct to tho host of my knowlod~o / / /,~ ~ - Regional Drtll~ng Engineer Signed ( /~~~.f~~ Title //'- d ~// ' ' ~ Commission Use Only Permit Nur~ber -- I APl number I Approval date I See cover letter ~ 7-,,~G I 50--<~ ~ - ~--[~ ~ I''" 0 4 / 14 Z 8 7 I for other requirements Conditions of approval Samples required [] Yes ~;~,.No Mud I°g required ~ Y~ '~No Hydrogen sulfide measures [] Ye~s '~No ~)i[ectibn~l survey required ~ Yes [] No Required working.p4,~re~h31r~L~ ~I~'-2M;.,~I~, 3M; [] SM; [] 10M; r-1'15M Other: ,.,' '~' ~ by order of . Approved by /t~.Z -~~ Commissioner the commission Fnrm ~n.ztnl n~v"-.t~l~fi ~ '"---.-'! ~'"'~'" '" Subr~it i( tril~licate KUPARUK RIVER UNIT 20' DIVERTER SCHEHATIC DESCRIPTION 1. 16" COI~UCTOR 2. Fl'lC SLIP-ON WELD STARTIN6 HEAD 3. FHC DIVERTER ASSEI"IBLY WITH TWO 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLIN6 SPOOL W/10" OUTLETS S. 10" HCR BALL VALVES Vt/I0" DIVERTER LINES, A SIN6LE VALVE OPENS AUT01"IATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REHOTELY CON'I~0LLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALA .SI~.; INC., REQUESTS API~OV~., OF THIS DIVI~TEI~ ~~ ~ A VAi~IANCE FR0r~ 20AAC2~;:O3~(b) "~-. 2:' '*.':- '""r ~.. ;" 2 rIAINTENANCE ~, OPERAT, ION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPEI:~J,Y. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN iNFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. C~EN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. I~O NOT SHUT IN WELL UNDER ANY CIRCUt'ISTANCES 36 11-3-86 I' II i ii 6 II I DIA(~;J~ #1 50CX3 PSI ~ BOP ..STACX: ~. 16" - a:xx) F,8! TAI~ ~I'AI~rZNI3 ~ 2. II · - 30(X) I:~! CASXNI3 ~ 3. II · ~ F~X X 13-~8" - ~XX) F~! ~P~ 5. 13~,.,%/6" - ~ i:~! C~%U..ZNI3 ~ W,/C3.,K3(E ~ KXLL LZI',F.8 6. 13-5/8" 5000 F~X ~ RNa W,,~XF:~ ~ C:N TC~.. '7. 13-,6/8'- ~ I~% ~ CAPACITy TEST wX X¢ FLUID. Z. ~ T',¢a?~TCI~ ~ XS 3CXX3 1:'SX WXTN 3. ~ TZI~ ~. ¢3,113~' ~ t,NZT'~ 8D4,LTAI~r, CL~Y 4. Z$ 45 ~; ~°TIME NJ3 I:SIX) F~X I~MII~X~NI3 5 ii i 13-~/8' ~ STAO<: TEST 510C~4001 REV.; MAY I 5o 1965 DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up Density 9.6-9.8 8.7-9.2 PV 15-30 5-15 yp 20-40 8-12 Viscosity 50-100 35-40 Initial Gel 5-15 2-4 10 Minute Gel 15-30 4-8 Filtrate AP1 20 10-20 pM 9-10 9.5-10.5 % Solids 10± 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-1Z 9.5-10.5 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-freezin$ 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. LWI~/ih GENERAL DRILLING PROCEDUSJ~ KUPAKUK RIVER FIELD DEVELOPMENT WELLS 10. II. 12. 1~. 14. i~. 1~. 17. 18. 19. 20. 21. 22. I. Move in rig. 2. Install Tankco diverter system. 3. Drill 12~" hole to 9-5/8" surface casin$ point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow ouc preventer. Test casin$ to 2000 psiS. 6. Drill ou= cement and lO' new hole. Perfona leakoff Drill 8~"' ho~e co lo{{in~ point accordin~ Co directional plan. 8. Run open hole loss. Continue drilli~ 8%" hole =o provide 100' be~een plu~ back coca~ depth and bocc~ of Kupa~k sands. ~n ~d cedric 7" casin~. Pressure cesC Co 3500 D~queeze ~ccic Pack and ce~nc in 7" x 9-5/8" ~ulus. Nipple d~ bl~ out preventer ~d ~scall ca~ora~ ~l tree. Secure well a~ release rig. ~ cased hole logs. ~ve ~ ~r~vez rig. N~pple up bl~ ~t Pick up 7" casing scraper ~d tub~, trip ~ hole ~o plug back cocal depth. Circulate hole ~Ch clean brine ~d trip ~t of hole t~g back. Perforate and ~n co~leciou aaae~ly, aec ~d ces~ pacer. Nipple d~ bl~ out preventer and ~s~all ~ ~ree. C~nge oyez ~o diesel. Flow well co ca~s. Shut in. .?~ Se~re well ~d release =i~. ---~ Fracture so--laCe. '~Y~'~'~ ' I I ii i i i i i ~ i i ~E STIR ~ STIR _. STI. } cL F TYPICAL MUD SYSTEM SCHEMATIC LWE4 / ih ARCO Alaska, Inc. Post Office BoX~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive AnchOrage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-18) Dear Mr. Chatterton: Enclosed is an as-built locatiomp]at for the subject wells. you have any questions, please call me' at 263-4944. Sincerely, Gruber Associate Engineer If JG/db GRU1/31 Enclosure RECEIVED MAR- i 1987 Alaska 0il & Gas Cons. Commission Anchor~ge ARCO Alaska, Inc. is a Subsidiary o! AllanticRichfieldCompany ALL WELLS LOCATED IN SEC. 25, OL, IKTOIC liT. SIMPSON LAGOON VICINITy MAP SCALE 1"=2MILES NOTES '. I. ALL COORDINATES ARE A.S.P. , ZONE 4. 2.ALL DISTANCES SHOWN ARE TRUE. 3.ELEVATIONS ARE B.P.M.S.L. 4.REF. FIELD BOOK L87-3o Pgs. 7-1~.; L87-1, R7; LBT-3,PSI-53; 5.0.G. ELEVATIONS FROM F.R. BELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BASED ON SM CONTROL MONUMENTS PER LHD & ASSOCIATES. ASPs 'X' 4,016,202.17 6,016,225.10 6,016,248.21 6~016,271 . 24 6,016,294.28 6,016,317.42 6,016,:540.48 6,016,$65.49 6 016,386'92 6 016,456.13 6 016,479,2.2 66 016~50Z.26 i016,625.61 016,548.6Z 016,571.45 66016,594.75 016,61 7.99 6 016,641.02 506, I~. 6.99 506,136.45 506,145.9! 606,155.51 506,165.01 506,174.6~, 506,184.13 $06,193.52 506,203.14 506,232.02 506,241.62 506,251.07 506,260.75 506,270.30 506,27 9.77 506,289.40 $06,299.05 5 06,308.76 LATITUDE LONGITUDE 70027'19.790'' 49o~ 20.665 20.91 $ .?'21 · 7' 2 I. 366 ?'23.868 700Z7'24.094 14~56'54.647 Dist. F.N.L. 1296' 1273' 1250', 1227 IZ04', IIBI 11Se 1135 1112' 1042 1019 996 975 950 904 881 858' Dist. KE.L. 1741 1732 1722 1713 170:5 1694 IB84 1675 1665 1636 1626 1617 1607 1598 1588, 1678 1569 1559 O.G Pad Elev. 23.1' 2,$.6' Z3.$, 26.9, 23.4 2,6.8 2,3.4', 2.6.81, 23.3, 2,6 7 2,3.2t 26~6' 2,3. I , 26.6* 23.0, 26.4' 2, 1.7, 26.51 2 1.5 26.5 21.2 26.3 21. I'. 26.4'. 20 9' 26.4' '' 26.5', 20.9 20.9' 26.5 2,0.8' 26.6' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 3/8/8'/ ARCO Alaska Inc. D.S.$M WELL CONDUCTOR AS-BUILT l/arch 1'0, 1987 1~. J. B. Kewi.n Regional Drillin~ Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage., Alaska 99510-0360 Re- Kuparu_k River Unit 3H-6 AKCO Alaska, Inc. Permit No. 87-26- Sur. Loc. Btmhole Loc, · TelecoP7:. ' (907) 276 7542 ! '1 F 1181 FNL, 1693 EL Sec, 25, T13N, ~K, UM. 132T'~, 201~'~, ~C. 30, TI3N, R~' bM. Dear Mr. Kewin: Enclosed is the approved ~~ca-tiOn for permit to drill the above referenced well. T~ne permit Co drill does noC indemnify you from the probable need to o~tatn additional 'perm£ts required by law from other . governmental agencies prior to commencing operations at the we£~ site. To aid us in scheduling field work, please notify this office 24 hours prior to commene~ installation of the blowout preven~ion equipment so ~hat a representative 'of the C~sston may be present to wi=ness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify =his office 24 hours prior to con~encing equipment.installation .so that the Commission may witness testing b6fore drilling below t~e shoe of the' conductor pipe. V t 1' o s / Chairman of Alaska 0il and Gas Conservation Commission BY ORDER'OF THE COMMISSION dlf Enclosure cC: Department of Fish & Game, Habitat Section w/o encl. Department of EnvirOnmental Conservation w/o encL, " /'"% STATE OF ALASKA ALASKA C~.'~ AND GAS CONSERVATION COk,_~.~ ISSlON PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill~' Redrill~l lb. Type of welI. Exploratoryl-] StratigraphicTestr--I Development Oil J;~' Re-Entry Deepen Service [] Developement Gas [] Single Zone'l~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF Or KB) 1~. Field and Pool ARCO Alaska, Inc. RKB 63', PAD 26' feet Kuparuk River Field ,~ddr. ess 6~,PD~.op:~t~2D1esig~nLaKtio2n557 Kuparuk River 0il Poe p3;u. ~ox 100360 Anchorage, AK 99510-0360 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see20 AAC 25.025) 11'81'FNL, 1693'FEL, Sec.25, T13N, R8E, UN Kuparuk River Unil: St;at:ewide 131~'t~ ~(~)1. ,of 1~o2d~F~.i~[ intf~rval 8. Well nurpber Number , ;,ec.30, T13N, RDE, UN 3N-6 #8088-26-27 At total depth 9. Approximate spud date Amount 1327'FNL, 2014~FWL, Sec.30, T13N, RDE, UN 03/22/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 31,1-5 7854 'ND 1811'~ Surface feet 25' @ Surface feet 2560 (6351'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depthTM 2 feet Maximum hole angle 47 0 Maximum surface 2011 pslg At total depth ('rVD) 31 06 pslg 18. Casing program ... Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TYD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' *200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 3528' 35' 35' 3563' 3398' 890 sx AS III & HF-EI:W 290 sx Class G blend 8-1/2''r 7" 26.0# J-55 BTC 7820' 34' 34' 7854' 6351' 200 sx Class G(mtnir, un HF-E W TOC 5)0' above 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 Conductor RECEIVED Surface Intermediate MAR- 4 1987 Production Liner Alaska u. e u~s Cuns, Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~' Property plat [] BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid progr~j:l::~l~ Time vs depth plot [] Refraction analysi' 's [] Seabed report [] 20 AAC 25.050 requirements/~ 21. I hereby certi~ tha/t the foregoin.a_is true and correct to the best of my knowledge ' o ,-. Signed / -/~~4Z4./ ~,~,~_.~/ Ti t le .... Regional Drilling Engineer D e V - ~' ~'/ ~'"' "~ Commission Use Only (HARRY) PD2/013 Permit Numbe/r ~_ ~ I APl number I Approval date I See cover letter / - 2- (,, J 50-- o ~-~, - 9- I 70 7 I 0 3 / 10/87 .J for other requirements Conditions of approval samples required [] Yes ,~No Mud log requ~e.cl [] Yes ~. No Hydrogen sulfide measures [] Yes ~ No Dij'ection' al survey required ~i~,Yes [] Nd Required working pr_~ssure f.or DOPE_ r-12M; I~ 3_M; [] 5M; [] 10M; [] 15M Other: /~t'"~ /~~'~:~---'--~ by order of Approved by L ~'~-~/'- ~ ...... ,~'~'~,~ Commissioner the commission Dat _c~/~_~_~~/'~l~ ~'~ , Sul3f cate ARCO iALASKA. I~NC. '. PAD 3M. WELL NO, 6 PROPOSED KUP. A~UK. F.[ELD,: NORTH S~0PE,. ALASKA T~/D=2~,I,3 Tt~-,2345 DEP,' 2g K-t2' TYD~3198 :TI~D-~92 DEP"41) EOC (9 $,~8' C~O PT) " AVERAGE ANGL~] 46 DEG 31 1'lIN , "I'-~50~ ' I~0' '41750~ 1700' 65C '- · i' ' ' 1_550 · i - ~ ;. : ........ t :, · , ; i I i i ~ i i , , i . · ~ . ....... · . , -~ i .... I .... :~ol :. 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' ~.~ ..... :'W ...... 4 .......... : ............ ~.~i~ .................. ~ ................ ~ ....... ~ ........ ::_ :_:_~:-~-~:~-~ ::::_::. :.- ..~..:: :-~:,.,, : :: :: ~:~:: :: :::.: ::: :.: :_:_: ::.:. :: ::_:... .... ~ ..... ~F:~:-. :: ......... :.: -~ ~t~ ..... i ....... ~,~.,-~ .... ~,' .............. : .... ._~. ._~_~._i ..... t ........... ~ ' - J ' '~'~1 .......... ~ ...... ~''~ .... ~ ' ''l ............. , :-t::-: :':I: :'-: 1 "-: :':::-::-':::: i:: ' ~.:-~c:: :' 'I-: -: ':: :'I::-' :-:~~,4;~:2::-::::.":-::::: ...... j .... ~... : .......... : ..... ~ :: ...... ~~ .: ....... i ............ ~~~ .......... .... ~ ~ / ~''. ..... ~ ................................. ..... I .... .~-.. ~ ........ : ..- -::-~,~ ......... ~,~ .... J .................... ~ ~ .... : ..... '-~ .... t t' : ...... J '~.'~ --~ ............ ~ ~ ..... i ............ ~ ............ ~'-- i:~ ......... ::~ .... ~ ~ -. '-::' iz '~u · ~:'1~00 ...... ~ ~: ...... I-:-:"-:-': ..... : :: :"7:~7-' :':--:":-- : :~ ....... ~:~'-- : ........... ~ ......... : ............... I ........... ~ ................. '~ .-'. .... : ...... .........~..: 'J : : : :-J : ...... I ......... SI ............. ~" ........ ~ ......................... ~ ~........ :.. . ~.: ....... ~~ ..... ~ ....... ~ ...................... I-- ..- ........... .- %~ ...... j' :j '~ .: ...: ~ , ~.,, ~ ~,:-, _.:~ -..,:. ~ -: .... ~-:~;_:::-:-.: :.. ,- ......... ~ : ~ ~ ..................... ~ ---: ....... ~: ........ , :4' ..... 1 .... [. . : - -~ .... ~ .......... ~-~ ................. : ....... -I ..... ~'~ ................ :~---~ .... : ;-:- ~ , t ~ ............. ~ ...... : .. :'J~:: "' · : ..... ........... , .... ~-, · ,, : ~_ ~ ~ - iii I iii iii iJ iiii ii/il i/iiil ilill i iii il lli ii KUPARUK RIVER UNIT 20' DIVERTER $CHEHATIC L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTIN$ HEAD 5. FMC DIVERTER ASSEMBLY WITH T~O 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 1 O" HCR BALL VALVES W/1 O" DIVERTER LINES, A SINGLE VALVE OPENS AUTOffiATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REOUESTS APPROVAL OF THISDIVERTER SYSl~E-'PI AS A VARIANCE FROI'I 20AAC25.035(b) I'IAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE D(TWlqWIND o,v~,~,o,. R E C E IV E D MAR -' 4 1987 DO NOT SHUT I N,,~EL_.L ~, ~ uo,,~, Commission Anchor~e UNDER ANY CIRCUHSTANCE$ JG 11-3-86 6 4 AGRAM #l 13-5/8' 5000 PSI RSRRA BOP STACK 4. 13-5/8· - ~X30 PSI PIPE RNaB 5. 1~-5/8~ - ,~300 PSI Dt~ILLIN~ 830(1. ~/CHCI(E N~D KILL LII~.S A~TOR CN3ACITY TEST I. CHECK ~ FILL ~TOR RI~ERVOIR TO ~ LEVEL WI]I't ~IC FLUID. ~. ~ THAT ACC~ TGR ~ 18 3(X:IO PSI WITH 4. RE~ ON ~ ~o THE ~.~LE L~ LIMIT IS 45 ~E:~ Cl..06INI3 TM N~ 1200 PSI RB4~ININ~ 13--.~/8" BI33 STACK TEST I. FlU. BOP SI'ACK .q43 ~ MM~FOI..D WITH .~l~'~IC 2. CHECK THAT ALL LOCK BC~N ~ IN ~ FLU.¥ REI'RACI~. ~,~T TEST PU~3 IN ~ WITH EIJ~NI~ JT ~ ~ IN L(X3CDCaN ~. LINE VN.V~ ~ TO ~ 8TACK, ~ OTHE~ 4. ~ UP TO 250,~N~D H~LD FCR 10 ~ IN- ~ ~ TO ~ PSI ~D H~LD F(3~ I0 MIN. BLEED ~ TO 0 PSI. LIllE V~L~. CL08E TCP PIPE ~ N~D ~ VN. VES ON KILL ~ (3~CI(E LI _N~. 6. TEST TO ~ PSI N~D ~PS! AS IN STEP 4. ?. coNrINJE 1T~q'IN~ ~ VN.VE~o LI~,~° ~ CHCI(ES WITH A 2~3 PSI L~/~ ~ 3000 PSI HIGH. ~ AS IN ~ TOP PIPE ENa8 ~ CL08~ BOl'rO4 PIPE TEST BOTTCM PIPE P, NV8 TO 25(3 PSI N~D 3(330 PSI. CLOSE BLIN3 RNaB AN3 TEST TO ~ PSI N~) 3000 PSI. M~IIFClJ3 ~ LII~.S N~E FULL CIr NSN-F~EEZII~3 FLUID. SET ALL VALVE~ IN DRILLIN~ PC~ITICN. TEST ST~PIPE V~LVESo KELLY, KELLY C0C1($o DRILL. PIPE SNrETY VALVE, ~ INSIDE 50P TO 250 P~I 3000 PSI. FCI~I~ $I(~N, N~D SE~D TO D~ILLIN~ 8JPERVlSCR. ~rcEKLY TI~ FUNCTION~.LY CPERATE BCPE DAILY. 8~ 9. I0. II. 12. 13. 14. 510084001 REV. 2 MAY 15, 1985 Density DRILLING FLUID PROGRAM SPud to Drill out 9-5/8" Surface Casing t. 0 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 caging leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .I1 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 boris 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 PROCEDUR~ 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. II. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus, 12. Nipple down blow out preventer and install, temporary X--s tree. 13. Secure well and release rig. li. Run cased hole logs. 15. Move in workover rig. Nipple up blow .out preventer. 16. Pick up 7" casing scraper and tubing, crap in hole to plus back total depth. Circula~e hole with clean brine and trip out o£ hole s~andin8 tubing back. 17. Perforate and run completion assembly, set and test pecker. 18. Nipple down blow ou= 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 SHAKER~ --I I,, I'uo I CL~NER RECEIVED ~AR- ~ J987 Alaska O# ~ (~s Cons. Commisslor~ Anchorage '1 STIR STIR STIR I'IUD CENTRIFUGE CLEANER TYPICAL tlUD SYSTEtl SCHEHATIC LWK4/ih (2) . q-10- ? ..... (2 hru 8) (3) Adm/n ~ tf-( ~-;] ahd (6) ~ (29 '~t~~l) (6) rev: 01/28/87 6.011 1. Is the pennit fee attached ........................................... ~ 2. Is well .to be located in a defined P°°l ............................. 3. Is well located proper distance frc~ property line .................. 4. Is well located proper distance from other wells ................ .... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included .. ......... ' ..... 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ........... , .......... i ~9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force ....... ........................... Is a conservation order needed ...................................... Is a~strative approval-needed ............................. · ...... Is the lease mmber apPropriate ..................................... Does the well have a unique name and n;~her .......................... Is' ~ductor string prided o®.e®® o®......o®...e.®®®..®.®..-.-.® --®. Will surfa~ ~ing protect ~esh ~ter zones ....................... IS enoch ce~m/t used to c~rculate on conductor and surface ..., ...... Will cement tie in surface and intermadiate or production string~ ... Will cement cover all ~ productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well ~ be kicked off Is old w~l~re ab~t p~~e incluc~d on 10-403 ............ Is adequate wellbore separation proposed ............................ 23 IS a diverter system requ~ed - /~ . .o,. e . .e .......... me ..... · · ® · · · -®e e~- · · · · 26. ~ ~ b~ ~~t ~S~ ra~ - Test to ~ ps~ .. ~ 27. ~ ~ ~ ~*old ~ly w/~I ~-53 f~ 84) .................. 28. ~ ~ ~~ of ~S ~ p~le ................................. For exploratory and Stratigraphic wells: 29. Are data presented on po~ overpressure zones? ................. 30, ~ seismic anal~ data ~en~d on shall~ ~ z~ .... .. ....... 31. If ~ off~ ~., ~ ~ resul~ of seabed cxxx~~ ~ented ,i i i i i i i P(X)L CIA_SS STA.'I'dS ARFA- (1)-~ '~/~ /' ~-F~ 1 Is the permit fee attached (2) ~ ~ 7-&~ 2. ~ll~lo~ted~a~d h ~11 l~ted p~ ~~ce ~ o~ mlh ........ ~ ~ci~t ~~ted a~ge ~~ble 6.~ ~11 to be ~ted ~ is ~l~ore p~t ~cl~d ................ 7. ~ op~tor ~ ~y ~fected p~ ............ · a · leeeeeeee eeeeeeeeeeeeeeeeeeee eeeee. 13) ..... 10 ~ ~~ o~ n~d 9~ . ac~ . ..................................... F ~ ~7 11 Is a~s~a~ a~r~-~~d (10 ~ 13) .. 12f ~ ~m l~e ~~ ~~ate . . :::::::::::::::::::::::::::::::: (I4 ~ 22) 14. ~ c~~~r s~ p~~d ........................................ ~: ~. Will ~~e ~~ protect ~e~ 16. ~ ~~ c~t ~ed to c~~te 17. ~11 c~t ~e ~ ~ace ~ ~t~te or pro~~ s~s ... 18. Will c~t c~ ~1 ~ p~~~ 19. Will all ~~ gi~ a~te s~e~ 20. ~ ~s ~11 m be ~ off 21. ~ old ~~re ~~t p~~e ~l~d ~ ~ a~te ~~o~ s~a~ pr~sed ................ (23 ~ 28) ~. ~ a ~~~ ~s.t~ r~~ .... 26. ~ ~~ ~~ci~t ~~ ra~ -Test to,,, 27. ~ ~ ~ ~old ~ly w/~ ~-53 =s.m o= ................................. (6) ~ For explora~and Stra~c ,.,ells: 29. Are data ~emted ,ma ~ ca~azpres~ zca~m.s? ................. 30. Are seismic analysis data presented on shall~ gas zcmes .... : ....... ---~ 31. If an offshore loc., are ~ results of seabed conditi~ms presented7, ........ 32. Addi~~ z~ts ............................................. rev: 01/28/87 6. 011 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 roadability 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. MICROFILMED LIS TAPE VERIFICATION LISTING .VP 010.H02 VERIFICATION LISTING PAGE I ,,-,, REEL HEADER-,--,-'"'" ~ERVICE NAME :EDIT )ATE :87/05/ 6 ]RIGIN : ~EEL NAME :72283 SONTINUATION # :Ol ~REVIOUS REEL SOMMENTS :LIS TAPEr ARCO ALASKA, INC. 3M-6, API 50-02g-21707 6, TAPE HEADER '"'",,--,, SERVICE NAME :EDIT DATE :87/05/ 6 3RIGIN :FSIA TAPE NAME : CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :LIS TAPEr ARCO ALASKA~ INC. 3M-6, API 50-029-21707 ** FILE HEADER FILE NAME :EDIT .OOI SERVICE NAME : VERSION # : DATE: MAXIMUM LENGTH : 1024 FiLE TYPE PREVIOUS FILE : INFORMATION RECORDS MNEM CONTENTS UNIT TYPE CATE SIZE CODE .. CN : ARCO ALASKAs INC. 000 000 018 065 WN : 3M-6 000 000 004 065 F,N : KUPARUK 000 000 008 065 RANG: RBE 000 000 003 065 TOWN: T13N 000 000 004 065 SECT: S25 000 000 003 065 CO'UN: NORTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 006 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE PRES: E 000 000 001 065 ** COMMENTS '"'"~-.- ,VP OlO.H02 VERIFICATION LISTING PAGE 2 : SCHL~JMBERGER -,- : ALASKA COMPUTING CENTER 'OMPANY : ARCO ALASKA9 INC. IELL : 3M-6 :IELD = KUPARUK 'OUNTY = NORTH SLOPE BOROUGH ;TATE : ALASKA lOB NUMBER AT AKCC: 72283 :'UN #19 DATE LOGGED: 21 APR 87 .DP: JIM KOHRING ;ASING ~YPE FLUID )ENSITY fiSCOSITY ~H :LUID LOSS 9.625" @ 3525' - BIT SIZE = 8.5" TO 7334' WEIGHTED POLYMER 10.! LB/G RM : 5.19 @ 67 DF 42.0 S RMF = 4.24 @ 67 DF 9.5 RMC = 3.53 @ 67 OF 4.2 C3 RM AT BHT = 2.649 @ 138 DF 4AXIMUM RECORDED TEMPERATURE = 138 DF 4ATRIX SANDSTONE .VP 010oH02 VERIFICATION LISTING PAGE 3 --,-.'.--,-',"'"'"'"'" THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS '~'~"'"'".,-..,--,-~-,- SCHLUMBERGER LOGS INCLUDED NITH THIS MAGNETIC TAPE: DUALINDUCTION SPHERICALLY FOCUSED LOG (OIL) DATA AVAILABLE: 7326° TO 3525' FORMATION DENSITY COMPENSATED LOG (FDN) COMPENSATED NEUTRON LOG (FDN) DATA AVAILABLE: 7300' TO 6896' .DATA AVAILABLE: 4751° TD 4447' GAMMA RAY IN CASING (CHL) DATA AVAILABLE: 3569' TO 985' ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR COOE ENTRY 2 1 66 0 4 8 4 73 60 9 4 65 .lin 16' 0 1 66 0 )ATUM SPECIFICATION BL'DCKS ~NEM SERVICE .SERVICE UNIT API API API API FILE SIZE SPt REPR ID ORDER ~ LOG TYPE CLASS MOD NO, CODE PROCESS (OCTAL) .VP 010.H02 VERiFiCATION LISTING PAGE 4 )EPT ;FLU DIL :LD DIL :LM DIL ;P DIL ;R DIL ~ENS DIL ;R FON IHOB FDN )RHO FDN )PHI FDN ;~'AlI FDN tP H I F DN IRAT FDN ~NRA FDN ~CNL FDN :~NL FDN CHL FENS CHL FT O0 OHMM O0 OHMM O0 OHMM O0 MV O0 GAPI O0 LB O0 GAPI O0 G/C3 O0 G/C3 O0 PU O0 IN' O0 PU O0 O0 O0 CPS O0 CPS O0 LB O0 GAPI O0 LB O0 000 O0 0 0 4 1 220 01 0 0 4 1 120 46 0 0 4 1 120 44 0 0 4 1 010 01 0 0 4 1 310 01 0 0 4 1 635 21 0 0 4 1 310 01 0 0 4 1 350 02 0 0 4 1 356 01 0 0 4 1 890 O0 0 0 4 1 280 01 0 0 4 1 890 O0 0 0 4 1 420 01 0 0 4 1 000 O0 0 0 4 1 330 31 0 0 4 1 330 30 0 0 4 1 635 21 0 0 4 1 310 01 0 0 4 1 635 21 0 0 4 I 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 0000'0000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 DATA 7348.0000 SFL'U 3.3723 ILO 2.8171 ILM 2.9832 -23.6719 'GR 98.0000 TENS ' 2005.0000 GR 98.0000 2.4355 DRHO ' 0.1045 DPHI 12.9972 CALI 9.4141 39.5508 NRAT 3.3770 RNRA 3.5781 ,NCNL 1781,.0000 497,5000 TENS 2005,0000 GR -999,2500 TENS -999,2500 3EPT 5P OB HI NL 7300.0000 SFLU 3.0355 ILD 2.6720 ILM 2.6974 -24.1719 GR 98.000'0 TENS 4292.0000 GR 98.0000 2,4766 DRHO 0,1162 DPHI 10,5114 CALl 9.5000 37.3535 NRAT 3.2617 RNRA 3.2930 NCNL 1764.0000 535.5000 TENS 4292.0000 GR -999.2500 TENS -999..2500 PT 7200,0000 SFLU 10,1257 ILD 8,1950 ILM 8,1464 -26.0625 GR 83.3750 TENS 4034.0000 GR. 83.3750 OB 2,40.04 DRHO 0,0391 DPHI 15,1278 CALl 8,9141 HI 33.7402 NRAT 3.0156 RNRA 3.2969 NCN'L 2336.0000 NL 708.5000 TENS 4034.0000 GR -999.2500 TENS -999.2500 DEPT 7100.0000 SFLU 1.7633 ILD 1,9025 ILM 1.8738 SP -23 6875 GR 119.3125 TENS 4252.0000 GR 119.3125 R,HOB 2~4395 DRHO 0,0244 DPHI 12,7604 CALI 8,7266 NPHI 49.1699 NRAT 3.8437 RNRA 4.0977 NCNL 1877.0000 FCNL 457.7500 TENS 4252.0000 GR -999.2500 TENS -999.2500 DEPT 7000.0000 SFLU 4.5529 ILO 4.3952 ILM 4.1909 SP -32.5938 GR 169.'8750 TENS 4100.0000 GR 169.8750 RHOB 2,4668 DRHO 0,0503 DPHI 11,1032 CALI 8,8828 NPHI 43.9453 NRAT 3.5723 RNRA 3.6191 NCNL 1776.0000 FCNL 490.5000 TENS 4100.0000 GR -999.2500 TENS -999.2500 .VP 010.H02 VERIFICATION LISTING PAGE 5 )EPT 6900.0000 SFLU ;P -38.6875 GR ~HOB 2.3555 DRHO IPHI 48.8281 NRAT :CNL 442.5000 TENS )EPT tHOB ~PHI :CNL )EPT ;P ~HOB ~PHI =CNL )EPT SP ~HOB ~PHI FCNL ~EPT ~H 0 B ~PHI FCNL DE PT RH 0 B ~t,'P H I FC N L OEPT SP RHOB. PHI C NL 3,2781 ILO 2.7073 ILM 2.7431 124.7500 TENS 3974.0000 GR 124.7500 0.0313 DPHI 17.8504 CALI 8.9453 3.8457 RNRA 3.9297 NCNL 1739.0000 3974.0000 GR -999.2500 TENS -999.2500 6800.0000 SFLU 3.1614 ILD 2.5235 ILH 2.5838 -43.6563 GR 204.7500 TENS 4148.0000 GR -999.2500 -999.2500 DRHO -999.2500 DPHI -999.2500 CALl -999.2500 -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 GR -999.2500 TENS -999,2500 6700.0000 SFLU 3.7592 ILO 3.4424 ILM 3.5045 -50.2500 GR 173.62'50 TENS 3840.0000 GR -999.2500 -9'99.2500 ORHO -999.2500 DPHI -999.2500 CALI -999.2500 -999,2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 GR -999.2500 TENS -999.2500 6600.0000 SFLU 3.7210 ILO 3.5270 ILM 3.5633 -53.1250, GR 140.625'0 TENS 3864,0000 GR -999.2500 -999.2500 DRHO , -999.2500 DPHI -999.2500 CALI -999..2500 -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.250.0 -999.2500 TENS -999.2500 GR -999,2500 TENS -999.2500 6500.0000 SFLU 3.3002 ILD 3,3132 ILM 3.3486 -58.,1250 GR 130.3750 TENS 3634.0000 GR -999.2500 -9.99,25.00 DRHO -999.2500 DPHI -999.2500 CALl -999,25.00 -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999,2500 -999,2500 TENS -999.2500 GR -999.2500 TENS -999,,2500 6400.0000 : SFLU 3.5628 ILD 3.1667 ILM 3.1005 -59.6563 GR 123 6875 TENS 3640.0000 GR -999.2500 -999.2500 DRHO -999~2500 DPHI -999.2500 CALI -999.2500 -999.2500 NRAT -999,2500 R'NRA -999,2500 NCNL -999.2500 -999.2500 TENS -999.2500 GR -999.2500 TENS -999,2500 6300.0000 SFLU 3.9252 ILD 3.7490 ILM 3.7531 -63.3125, GR 10.7.937'5 TENS 3684.0000 GR -999.2500 -999.2500 DRHO -999,2500 DPHi -999.2500 CAL! -999,2500 -999oZ5.00 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 GR -999.2500 TENS -999.2500 DEPT 6200.0000 SFLU 4.5635 ILD 4.5781 ILM '4.4544 SP -63,3750 GR 93,1250 TENS 3484.0000 GR -999,2500 RHOB -999.2500 DRHO -999.2500 DPHI -999.2500 CALI .-999.2500 NPHI -999,2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 TENS -999.2500 GR -999.2500 TENS -999,2500 DEPT .6100,0000 SFLU 4.5706 ILO 3.8253 ILM 4.0511 SP -90.5000 GR 76.5625 TENS 3530.0000 GR -999.2500 RHOB -999.2500 DRHO -999.2500 DPHI -999,2500 CALI -999.2500 NPHI -999,2500 NRAT -999,2500 RNRA -999,2500 NCNL -999,2500 FCNL -999.2500 TENS -999.2500 GR -999.2500 TENS '999,2500 .VP 010.H02 VERIFICATION LISTING PAGE 6 tEPT 6000.0000 SFLU ;P -54.8437 GR ~H08 -999.2500 DRHO IPHI -999.2500 NRAT :CNL -999.2500 TENS )EPT 5900.0000 SFLU ;P -58.5000 GR ~HOB -999.2500 DRHO IPHI -999.2500 NRAT :CNL -999.2500 TENS )EPT 5800.0000 SFLU ~.P -47.6250 GR ~HOB -999.2500 DRHO tPHI -999.2500 NRAT =CNL -999.2500 TENS )EPT 5700.0000 SFLU ~P -56.6563 GR {HOB -999.2500. DRHO ~PHI -999.2500 NRAT ~CNL -999.2500 TENS ~,EpT 56.00.0000 SFLU SP -50.2500 GR ~H:OB -999.2500 DRHO ~,PHI -999,2500 NRAT FCNL -999,2500 'TENS DEPT 5500,0000 SFLU -59.5625 GR ~flOB -999,2500 DRHO ~PHI -999.2500 NRAT F<CNL -999.2500 TENS 3.6652 ILD 91.6875 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 3.3898 ILD 99.3125 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 2.8455 ILD 114.7500 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 3.6267 ILD 104o1~75 TENS -999.2 O0 DPHI -999.2500 RNRA -999.2500 GR 2.4055 ILD 113.3750 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 3'1211 ILD 113.9375 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR DEPT 5400,0000 SFLU 3,4660 ILO S.P -64,9375 GR 117,9375 TENS RHOB -999,2500 DRHO -999,2500 DPHI ~PHI -999,2500 NRAT -999.2500 RNRA FCNL -999.2500 TENS -999.2500 GR 3.8421 ILM 3.8535 3500.0000 GR -999.2500 -999.2500 CALI -999.2500 -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 3.4338 ILM 3.4122 3284.0000 GR -999.2500 -999.2500 CALI -999.2500 -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 2.9738 ILM 2.9432 3324.0000 GR -999.2500 -999.2500 CALI -999.2500 -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 3.6220 ILM 3.6277 3330.0000 GR -999.2500 -999.2500 CALI -999.2500 -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 2.5227 ILM 2.5005 3324.0000 GR -999.2500 -999.2500 CALI -999.2500 -999.2500 -NCNL -999.2500 -999-2500 TENS -999.2500 3.1223 ILM 3.0969 3150.0000 GR -999.2500 -999.2500 CALI -999.2500 -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 3.5426 ILM 3.4521 3110.0000 GR -999.2500 -999.2500 CALI -999.2500 -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 DEPT 5300,0000 SFLU 2,2999 ILO 2.6567 ILM 2,5161 SP -59,5313 GR 132.1250 TENS 3214.0000 GR -999.2500 RHOB -999.2500 DRHO -999.2500 DPHI -999.2500 CALI -999.2500 NPHI -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 TENS -999.2500 GR -999.2500 TENS -999.2500 DEPT' 5200.0000 SFLU 1.9011 ILD 2.1009 ILM 2.0874 SP -58.4063 GR 99.7500 TENS 3224.0000 GR -999.2500 RHOB -999.2500 DRHO -999.2500 DPHI -999.2500 CALI -999.2500 NPHI -999.2500 NRAT -999.2500 R'NRA -999.2500 NCNL -999.2500 FCNL -999.2500 TENS -999.2500 GR -999.2500 TENS -999.2500 .VP 010.H02 VERIFICATION LISTING PAGE 7 )EPT 5100.0000 SFLU iP -65.4375 GR {HOB -999.2500 DRHO 4PHI -999.2500 NRAT =CNL -999.2500 TENS )EPT 5000.0000 SFLU ;P -68.5000 GR ~HOB -999.2500 DRHD ~PHI -999.2500 NRAT :CNL -999.2500 TENS )EPT 4900.0000 SFLU ~P -70.4375 GR ~HOB -999.2500 DRHO ~PHI -999.2500 NRAT ;CNL -999.2500 TENS )EPT 4800.0000 SFLU 5P -71.8750 GR ~HOB -999. 2500 DRHO ~PHI -999.2500 NRAT FCNL -999.2500 TENS ,, ~EPT 4700.0000 SFLU SP -36.1875 GR ~MO8 2.3594 DRHO ~:PHI 38.4277 NRAT FCNL 585.5000 TENS ,, DEPT 4600.0000 SFLU SP -41. 2813 GR RHOB 2.3613 DRHO NPH[ 35-6445 NRAT FCNL 592.5000 TENS DEPT 4500.0000 SFLU SP -43.6875 GR RHOB 2,3359 DRHO NPHI 40.5762 NRAT FCNL 588.0000 TENS DEPT 4400.0000 SFLU SP -47.0938 GR RHOB -999.2500 ORHO NPHI -999.2500 NRAT FCNL -999.2500 TENS DEPT 4300.0000 SFLU SP -51.3125 GR RHOB -999.2500 DRHO NPHI -999.2500 NRAT FCNL ,-999.2500 TENS 2.4095 ILD 98.3125 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 3,1045 ILD 97.6875 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 2.9381 ILD 107.4375 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 2.9544 93.6250 TENS -999.2500 OPHI -999.2500 RNRA -999.2500 GR 3.4355 ILO 98.8125 TENS 0,0186 DPHI 3.3145. RNRA 2970.0000 GR 3.6744 ILO. 90.0625 TENS 0.0142 OPHI 3.1914 RNRA 2834.0000 GR 3.2311 ILD 98.0625 TENS 0.0786 DPHI 3.4160 RNRA 2680.0000 GR 4.4092 ILO I02.0000 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR 3.8429 ILD 94,7500 TENS -999.2500 DPHI -999,2500 RNRA -999.2500 GR 2.5152 3080.0000 -999.2500 -999.2500 -999.2500 3.3178 3004.0000 -999.2500 -999.2500 -999.2500 3.1986 3014.0000 -999.2500 -999.2500 -999.2500 3.2599 2990.0000 -999.2500 -999.2500 -999,2500 3.6385 2970.0.000 17.6136 3.5410 -999,2500 4.1183 2834.000'0 17.4953 3,5137 -999.2500 3.5959 2680.0000 19.0341 .3.5977 -999.2500 4.2079 Z704.0000 -999.2500 -999.2500 -999.2500 4.2014 2624.0000 -999.2500 -999.2500 -999.2500 ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS ILM GR CALI NCNL TENS 2.4851 -999.2500 -999.2500 -999.2500 -999.2500 3.2580 -999.2500 -999.2500 -999.2500 -999.2500 3.1448 -999.2500 -999.2500 -999.2500 -999.2500 3.0824 -999.2500 -999.2500 -999.2500 -999.2500 3.5348 98.8125 9.4375 2074.0000 -999.2500 3.9860 90.0625 9.7500 2082.0000 -999,2500 3.5254 98.0625 9,2266 2116,0000 -999.2500 3.9905 -999.2500 -999.2500 -999.2500 -999.2500 4.0883 -999.2500 -999.2500 -999.2500 -999.2500 .VP 010.H02 VERIFICATION LISTING PAGE 8 )EPT 4200.0000 SFLU 3.1261 ILD ;P -52.6563 GR 95.5625 TENS ~HOB -999.2500 DRHO -999.2500 DPHI dPHI -999.2500 NRAT -999.2500 RNRA :CNL -999.2500 TENS -999.2500 GR )EPT 4100.0000 SFLU 3.4095 ILD ~P -53 6~75 GR 103.2500 TENS ~HOB -999~2~0~ DRHO -999.2500 DPHI ~PHI -999.2500 NRAT -999.2500 RNRA :CNL -999.2500 TENS -999.2500 GR )EPT 4000.0000 SFLU 4.6430 ILD ~P -58.1562 GR 104.8125 TENS ~HOB -999.2500 DRHO -999.2500 DPHI ~PHI -999-2500 NRAT -999.2500 RNRA FCNL -999.2500 TENS -999.2500 GR ~EPT 3900.0000 SFLU 4.7870 ILD 5P -60.0625 GR 100.0625 TENS ~HOB -999.2500 DRHO -999.2500 DPHI ~PHI -999.2500 NRAT -999.2500 RNRA FCNL -999.2500 TENS -999.2500 GR 3.6413 ILM 2604.0000 GR -999.2500 CALI -999.2500 NCNL -999.2500 TENS 3.8584 ILM 2584.0000 GR -999.2500 CALI -999.2500 NCNL -9991.2500 TENS 4.9857 ILM 2590.0000 GR -999.2500 CALI -999.2500 NCNL -999.2500 TENS 4.9680 ILM 2440.0000 GR -999,2500 CALI -999.2500 NCNL -999'.2500 TENS DEPT 3800,0000 SFLU 3,4660 ILD 3,4162 ILM SP -63'6250 GR 95.6875 TENS 2314,0000 GR ~H'OB -9'99-2500 DRHO -999,2500 DPHI -999,250.0 CALI NiPHI -999.2500 NR'AT -999.2500 RN:RA -999.2500 NCNL FCNL -999.2500 TENS -999'2500 GR -999.2500 TENS D~PT 3700.0000 SFLU 3,0323 ILD 3.2009 ILM $?P -64.6250 GR 109.1250 TENS 2284.0000 GR RHOB -999.2500 DRHO "-999.2500 DPHI -999.2500 CALI NPHI -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL FCNL -999.2500 TENS -999.2500 GR -999.2500 TENS 3.4420 -999.2500 -999.2500 -999.2500 -999.2500 3,6919 -999.2500 -999.2500 -999.2500 -999.2500 '4.8646 -999.2500 -999.2500 -999.2500 -999.2500 4.8558 -999.2500 -999.2500 -999.2500 -999.2500 3.1941 '999.2500 -999.2500 -999.2500 -999,2500 3.0364 -999.2500 -999.2500 -999.250*0 -999.2500 DEPT 3600.0000 SFLU 4.0952 ILO 4.4033 ILM 4.1390 SP -71.6250 GR 99.7500 TENS 2180.0000 GR -999.2500 RHOB -999.2500 DRHO -999-'2500 DPHI -999,2500 CALI -999,2500 NPHI -99.9.2500 NR'AT -999,2500 RNRA -99'9.250'0 N.CNL -999,2500 FCNL. -999,2500 TENS -999.2500 GR 88.5000 TENS 2164.0000 DEPT 3500.0000 SFLU -999-2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 TENS -999.2500 GR -999.2500 RHOB -999.2500 DRHO -999.2500 DPHI -999,2500 CALI -999..250.0 NPHI -999.2500 NRAT -999,2500 RNRA -999,2500 NCNL -999.2500 FCNL -999.2500 TENS -999.2500 GR 56,8750 TENS 2310.0000 DEPT 3400.0000 SFLU '-999.2500 ILD -999.2500 ILM -999.2500 SiP -999,2500 GR -999.2500 TENS -999.2500 GR -999.2500 RHOB -999,2500 DRHO -999.2500 OPHI -999.2500 CALI -999.2500 NPHI -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 TENS -999.2500 GR 42.3750 TENS 2214.0000 .VP 010.H02 VERIFICATION LISTING PAGE 9 ~EPT ;P ',HOB IPHI :CNL iEPT ,'HOB iPHI :£NL )EPT ;P tHOB IPHI :CNL )EPT ~HOB ~PHI =CNL )EPT ~,~'p J, NOB JP. HI :CNL !~'E PT ~'HOB ~PHI :CNL )EPT iP OB HI NL )EPT. ~P ~HO B ~PHI ~CNL gEPT SP RHOB NPHI FCNL 3300.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NRAT -999.2500 TENS 3200.0000 SFLU -'999.2500 GR -999.2500 DRHO -999.2500 NRAT -999.2500 TENS 3100.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NRAT -999.2500 TENS 3000.0000 SFLU -999.2500 GR -999.2500 DRHD -999.2500 NRAT -999.2500 TENS 2900.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NRAT -999.2500 TENS 2BO~.O000 SFLU -99 .2500 GR -999.2500 DRHO -999.2500 NRAT -999.2500 TENS 2700.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NRAT -999.2500 TENS 2600.0000 -999.2500 -999.2500 -999.2500 -999.2500 SFLU GR DRHO NRAT TENS SFLU GR DRHO NRAT TENS 2500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILO -999.2500 TENS -999.2500 OPHI -999.2500 RNRA -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 OPHI -999.2500 RNRA -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 OPHI -999.2500 RNRA -999.2500 GR -999.2500 ILO -999.2500 TENS -99'9.2500 DPHI -999.2500 RNRA -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DPHI -999.2500 RNRA -999.250'0 GR -999.2500 ILD -999.2500 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DPHI -999.2500 RNRA -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DPHI ,999.2500 RNRA -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 OPHI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 GR -999.2500 CALI -999.2500 NCNL 44.5000 TENS -999.2500 ILM -999.2500 GR -999.2500 CALI -999.2500 NCNL 51.71B8 TENS -999.2500 ILM -999.2500 GR -999.2500 CALI -999.2500 NCNL 56.5313 TENS -999.2500 ILM -999.2500 GR -999.2500 CALI -999.2500 NCNL 68.1250 TENS -999.2500 ILM -999.2500 GR -999.2500 CALI -999.2500 NCNL 50.7500 TENS -999.2500 ILM -999.2500 GR -999.2500 CALI -999.2500 NCNL 28.7344 TENS -999.2500 ILM -999.2500 GR -999.2500 CALI -999.'2500 NCNL 52.6563 TENS -999.2500 ILM -999.2500 GR -999.2500 CALI -999.2500 NCNL 42-2813 TENS -999.2500 ILM -999.2500 GR -999.2500 CALl -999.2500 NCNL 35.8437 TENS -999.2500 -999.2500 -999.2500 -999.2500 2160.0000 -999.2500 -999.2500 -999.2500 -999.2500 2190.0000 -999.2500 -999.2500 -999.2500 -999.2500 2104.0000 -999'2500 -999.2500 -999.2500 -999.2500 1995.0000 -999.2500 -999.2500 -999.2500 -999.2500 1945.0000 -999.2500 -999.2500 -999.2500 -999.2500 1955.0000 -999.2500 -999.2500 -999.2500 -999.2500 1875.0000 -999.2500 -999.2500 -999.2500 -999.2500 1BI5.0000 -999.2500 -999.2500 -999.2500 -999.2500 1790.0000 .VP OlO.H02 VERIFICATION LISTING PAGE 10 ~EPT ;P :HOB IPHI :CNL )EPT ;P tHOB IPHI :CNL )EPT ;P ~HOB ~PHI :CNL )EPT ;P ~HOB ~PHI :C NL )EPT ~HOB ~PHI =CNL ~:E P T SP ~HOB NPHI ~C NL DEPT SP RHOB NPHI FCNL DEPT SP RHOB NPHI FCNL DEPT SP RHOB NPHI FCNL 2400.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 -999.2500 GR -999.2500 TENS -999.2500 GR -999.2500 -999.2500 DRHO -999.2500 DPHI -999.2500 CALl -999.2500 -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 -999.2500 TENS -999.2500 GR 39.2187 TENS 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