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186-151
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-18 KUPARUK RIV UNIT 3K-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3K-18 50-029-21641-00-00 186-151-0 W SPT 6604 1861510 1651 2863 2855 2848 2846 21 24 24 24 4YRTST P Josh Hunt 6/18/2025 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 3K-18 Inspection Date: Tubing OA Packer Depth 430 2160 2040 2010IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250620081550 BBL Pumped:2.6 BBL Returned:2.4 Thursday, July 24, 2025 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:NSK DHD Field Supv Cc:Regg, James B (OGC) Subject:RE: 10-426 form for 3K-pad SI non-witnessed MIT-IA"s 5-8-25 Date:Wednesday, June 18, 2025 2:28:23 PM Attachments:image001.png Matt/Bruce, I made a minor revision, changing the report date to 05/08/25. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK DHD Field Supv <n2238@conocophillips.com> Sent: Thursday, May 8, 2025 6:41 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: 10-426 form for 3K-pad SI non-witnessed MIT-IA's 5-8-25 Morning, Please see the attached 10-426 form from the 3K-pad SI non-witnessed MIT-IA’s that was performed on 5-8-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor .58. 37' KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861020 Type Inj N Tubing 1275 1275 1275 1275 Type Test P Packer TVD 6420 BBL Pump 1.2 IA 450 2030 1975 1950 Interval 4 Test psi 1605 BBL Return 1.2 OA 25 30 25 25 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861040 Type Inj N Tubing 1450 1450 1450 1450 Type Test P Packer TVD 6431 BBL Pump 2.0 IA 700 2010 1930 1910 Interval 4 Test psi 1608 BBL Return 2.0 OA 150 150 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861250 Type Inj N Tubing 1350 1360 1360 1360 Type Test P Packer TVD 6564 BBL Pump 1.6 IA 300 2030 2010 2000 Interval 4 Test psi 1641 BBL Return 1.6 OA 10 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861510 Type Inj N Tubing 1200 1250 1250 1250 Type Test P Packer TVD 6606 BBL Pump 1.2 IA 140 1900 1880 1880 Interval 4 Test psi 1652 BBL Return 1.2 OA 10 10 11 11 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980810 Type Inj N Tubing 1340 1350 1350 1340 Type Test P Packer TVD 6548 BBL Pump 1.0 IA 700 2040 2030 2030 Interval 4 Test psi 1637 BBL Return 1.0 OA 320 480 480 480 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1970770 Type Inj N Tubing 1080 1210 1100 1090 Type Test P Packer TVD 6621 BBL Pump 1.2 IA 220 1940 1915 1910 Interval 4 Test psi 1655 BBL Return 1.2 OA 540 620 580 580 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980820 Type Inj N Tubing 1340 1475 1425 1400 Type Test P Packer TVD 6117 BBL Pump 1.0 IA 100 2110 2080 2070 Interval 4 Test psi1529BBL Return1.0OA25252525 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980770 Type Inj N Tubing 820 840 840 840 Type Test P Packer TVD 6275 BBL Pump 1.3 IA 200 1800 1790 1790 Interval 4 Test psi 1569 BBL Return 1.1 OA 25 40 40 40 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 3K-31 3K-34 Notes: 3K-25 3K-26 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 3K-07 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3K Pad Gschwind/Sheets 05/08/28 Notes: Notes: Notes: Notes: 3K-02 3K-04 3K-18 Form 10-426 (Revised 01/2017)2025-0508_MIT_KRU_3K-18 9 9 9 9 9 999 9 -5HJJ 3K-18 MEMORANDUM TO: Jim Regg 'Rje.-, -5 614oz,i • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday, October 19, 2017 12:41 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 3K-18 (PTD# 186-151) Chris, I wanted to follow-up on our recent notification of low OA pressure seen in 3K-18 (PTD#186-151). DHD performed a passing MITOA yesterday to confirm we have competent surface casing. As previously mentioned,we will continue operating 3K-18 as a normal well. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450SCANNED FER , %!' ,I From: NSK Well Integrity Supv CPF3 and WNS Sent:Wednesday,October 18,2017 8:07 AM To: 'Wallace,Chris D (DOA)'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: KRU 3K-18(PTD#186-151) Chris, KRU injection well 3K-18 (PTD#186-151)was found with low pressure on the OA. There isn't any noticeable point in the well's history where this pressure dropped suddenly, so it's entirely possible this is an artifact of thermal effects on the annulus. CPAI proposes performing an MITOA to ensure the surface casing has integrity, and if so we will continue to treat it as a normal well. If the MITOA fails, we'll notify you and inform you of our proposed path forward. Attached is a 90-day TIO plot. Please let me know if you have questions or disagree with the plan. Thanks, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 16,2017 TO: Jim Regg P.I.Supervisor �e1 51/q/17 SUBJECT: Mechanical Integrity Tests I / CONOCOPHILLIPS ALASKA INC 3K-18 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-18 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-18 API Well Number 50-029-21641-00-00 Inspector Name: Chuck Scheve Permit Number: 186-151-0 Inspection Date: 5/10/2017 Insp Num: mitCS170510161255 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-18 Type Inj W 'TVD 6604 ' Tubing 2800 2800 - 2800 - 2800 PTD 1861510 - Type Test SPT Test psi 1651 ' IA 650 2000 , 1910 . 1900 - BBL Pumped: 2.1 - BBL Returned: 2.2 - OA 10 12 12 - 12 Interval 4YRTST PAF P Notes: SCANNED .J U L 1 1 art. 1 Tuesday,May 16,2017 Page 1 of 1 MEMORANDUM TO: Jim Regg r--j P.I. Supervisor ~ ~ C~!) 6 `~ ~~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-18 KUPARUK RIV UNIT 3K-18 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 3K-18 Insp Num: mitCS090515162422 Rel Insp Num: API Well Number: 50-029-21641-00-00 Permit Number: 186-151-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-18 ITYhe Ind, N 'j'am 6604 jA 0 2260 / 2160 2160 P.T.D 1s61s1o " TypeTest SPT , Test psi 16sI OA 0 0 0 o I Interval aYttTST p~F P Tubing 9so Iooo Iooo Iooo Notes: Pretest pressures observed and found stable . Well demonstrated good mechanical integrity. Wednesday, May 20, 2009 Page 1 of 1 . . ~ ConocoPhillips Alaska JLIL 3 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 \) 1 1{)t)1 ,,~K\e.O þ...\) G SÇ~"Il"l \l6~ 1"5 \ Dear Mr. Maunder: Enck)sed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, " ) -\~~ 7 ('Lit/o?- Perry Kl . ConocoPhillips Well Integrity Supervisor . . JUL3 1 2007 o d ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11 " 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2,007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K-11 186-164 43' .- 605 21" - 7/10/2007 .- . 7.8 .,. -. . 7/16/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 ....."..-. d:d-~- 01/02/07 Schlumbel'gel' NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /. .', ,D Jþ.N {} ß 20\)7 (" ".v"i""",~rä"'t:le !..r.j.':jlí![~Î((':~;:'~".~· ~ ,. ..- ( i:r~, (-80 - tS-'¡ Field: II -. #J.......~...' ~-.. Kuparuk Well Job# Log Description Color CD Date BL 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 1 D-1 09 NIA INJECTION PROFilE 11127/06 1 1J-136 (REDO) 11534188 USIT 12110/06 1 1R-18 NIA SBHPIDD 12118106 1 1G-16 11551836 INJECTION PROFilE 12119106 1 1D-103 11548555 INJECTION PROFilE 12120106 1 3K-09A N/A SBHP SURVEY 12/22106 1 3K-26 N/A SBHP SURVEY 12/22106 1 3K.18 11551838 SBHP SURVEY 12123106 1 2N-326 11551840 SBHP SURVEY 12124106 1 3S-19 11548564 PRODUCTION PROFilE 12125/06 1 2M-10 11551841 PRODUCTION PROFilE 12125/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12126/06 1 2M-15 11551843 PRODUCTION PROFilE 12127/06 1 2M-22 11538773 PRODUCTION PROFilE 12128106 1 1J-184 11538775 PRODUCTION PROFILE 12130/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . TO: Jim Regg P.I. Supervisor ') Ke11 6/¡~/Ùç ~ta[e 01 AlaSKa Alaska Oil and Gas Conservation Comm. ) DATE: Wednesday, May 25,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-18 KUPARUK RIV UNIT 3K-18 \cêo( \ 6\ .l.' ....D.l.'... 'J "''-1'"11 "iI 11 U 1,.. FROM: Chuck Scheve Petroleum Inspector 8rc: Inspector Reviewed By: P.I. Supr<)ߣ- Comm Well Name: KUPARUK RlV UNIT 3K-18 Insp Num: mitCS050521154707 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21641-00-00 Permit Number: 186-151-0 Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-18 Type Inj. w ITVD 6605 I IA 100 2800 I 2750 2740 SPT I Test psi P.T. 1861510 TypeTest 1651.25 lOA 440 560 560 560 I Interval 4YRTST P/F P Tubing I 2200 2200 2200 2200 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNEC~ JUL Û r.¡ 2005 Wednesday, May 25,2005 Page I of I ) ) OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhilJips Alaska Inc. Kuparuk 1 KRUI 3K 05/21/05 Arend 1 Sauvageau - AES Chuck Scheve ,. \6 \ ~~ SC,ANNE.D MJ\Y 2, 6 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us Packer Depth Pretest Initial 15 Min. 30 Min. well 3K-02 I Type Inj I S I Tv.D·1 6421 I Tub~ng I 27501 27501 27501 2750 Interval I 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 / 550 I 550 / 550 well 3K-04 I Type Inj I S I T.V.D. 6431 I Tub~ng I 30001 30001 30001 3OOOllnterval 4 P.T.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 / 350 / 350 I 350 Well\3K-05 I Type Inj 1 S 1 T.V.D. 6341 I Tubing I 27501 27501 27501 2750 1 Interval I 4 P.T.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 / 940 / 940 I 940 Well\3K-07 I Type Inj I S I TV.D. 6565 I Tub~ng I 29501 29501 29501 2950 I Interval I 4 P.T.D. 1861250 Type Test P Test psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 / 340 / 340 1 340 well 3K-12 I Type Inj I S I T.V.D. 6644 I Tubing I 28501 28501 28501 2850 I Interval I 0 P.T.D. 1861650 Type Test P Test psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 I 480 / 480 I 480 Well\3K-13 I Type Inj I S I T.V.D. 6376 I Tubing I 28501 28501 28501 2850 Interval I 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 I 600 / 600 I 600 well 3K-15 I Type Inj I S I TV.D. 6448 I Tubing I 28501 28501 28501 2850 Interval I 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 I 450 I 450 I 450 well 3K-18 I Type Inj I S I TV.D. 6605 1 Tub~ng I 22001 22001 22001 2200 I Interval I 4 P.T.D. 1861510 Type Test P Test psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 I 560 I 560 / 560 well 3K-19 I Type Inj I S I T.V.D. 6331 1 Tubing I 27501 27501 27501 275Ollnterval 4 P.T.D. 2011080 Type Test P T est psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 / 620 / 620 I 620 We1l13K-25 I Type Inj I N I T.v.D·1 6552 I Tub~ng I 27~1 2751 2751 275 lnterval 1 4 P.T.D. 1980810 Type Test P Test psi 1638 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 / 600 / 600 we1l13K-26 \ Type Inj I S I T.V.D·I 6656 I Tubing I 27501 27501 27501 2750 \ Interval 1 4 P.T.D. 1970770 Type Test P Test psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 720 1 780 I 780 1 780 well 3K-30 I Type Inj I S I T.V.D. 6580 I Tubing I 28501 28501 28501 2850 1 Interval I 4 P.T.D. 1971130 Type Test P T est psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 I 460 I 450 I 450 well 3K-31 Type Inj I S I TV.D. 6117 1 Tub~ng I 285~1 28501 28501 2850 1 Interval I 4 P.T.D. 1980820 Type Test P Test psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 I 600 Well!3K-34 I Type Inj ~ S I TV.D. 6285 I Tub~ng I 28501 28501 28501 2850 ¡Interval I 4 P .T.D. 1980770 Type Test P T est psi 1571 Casing 300 2140 2140 2140 P/F P Notes: OA: 400 I 650 I 650 I 650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey Test during Workover D = Differential Temperature Test 0= Other (describe in notes) MIT Report Form 5/24/2005 Revised: 05/19/02 MIT KRU 3K 05-21-05.xls MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE 1. Operation Performed: ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate Plugging Perforate 3~ · Alter casing Repair well Other__ Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 959' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1508' FSL, 1428' FEL, Sec. 1, T12N, At effective depth 1238' FSL, 1212' FEL, Sec. 1, T12N, At total depth 1190' FSL, 1149' FEL, Sec. 1, T12N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 9 8 4 3' true vertical 691 1' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 69' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3K-18 9. Permit number/approval number #86-151 10. APl number so-029-21641 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9705' true vertical 6812' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 8 0' 1 6" 1540# POLESET 1 1 5' 1 1 5' 5278' 9 5/8" 1510SXAS III& 531 5' 3894' 375 Sx Class G 9790' 7" 400SxClassG& 9790' 6873' 175 Sx AS I measured 9509', 9514', 9517', 9519', 9545', 9547', 9553', 9558', 9561', 9563', 9570-80'MD true vertical 6675', 6679', 6681', 6682', 6700', 6701', 6706', 6709', 6711', 6712', 6717-24'TVD HRP~ 9405' Tubing (size, grade, and measured depth) 2 7/8" ,L-80, TBG W/ TAIL @ 9432' Packers and SSSV (type and measured depth) SSSV: TRDP-1A-SSA~ 1816', Packer: 13. Stimulation or cement squeeze summary 14. Reperforated the A2 and A3 Sand intervals. Intervals treated (measured) 9544'-9570' MD-RKB and 9496'-9526' MD-RKB Treatment description including volumes used and final pressure 2 1/8" Enerjet, 13.5 grams Representative Daily Average Production or Inje~ion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0- -0- 1975 360 930 Subsequent to operation 0- -0- 2050 400 980 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Water Injector :~ 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 Rev 09/12/90 Service Date SUBMIT IN DUPLICATE WELL SERVICE REPORT ARCO Alaska, Inc-~ .~ SuDsidiary of Atlantic Rictlfielcl Compa WELL CONTRACTOR ~ / ~_~-~_ REMARKS (3 JPBDT JFIELD - DISTRICT- STATE IOP~~RT TIME IDAYS j DATE -- l-"J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER ~ (~:3~ ,,~ DRESSER-ATLAS ' DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol I~.. ~o~3t~ ~-~--_.C~. Supervision Pre-Job Safety Meeting AFE ..TOTAL FIELD ESTIMATE IIsigned ..j STATE Of ALASKA ~" ....... ~/-~,. / ALASKA ul'L AND GAS CONSERVATION CO,vIMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-151 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21641 4. Location of well at surface 9. Unit Or Lease Name 959' FSL, 315' FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1508' FSL, 1428' FEL, Sec. 1, T12N, R9E, UM 3K-18 At Total Depth 11. Field and Pool 1205' FSL, 1149' FEL, Sec. 1, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 69'I ADL 25629, ALK 2562 ,_ 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 08/29/86 09/07/86 01/27/87'I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9843'MD 6911 'TVD 9705'MD 6812'TVD YES [~ NO []I 1816' feet MD 1700' (Approx) 22. Type Electric or Other Logs Run DIL/SP/SFL, GR, FDC/CNL, Cal, CBL/Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 1540# Pol eset · 9-5/8" 36.0# JE-SR2 Surf 5315' 12-1/4" 1510 sx AS Ill & 375 sx Class G 7" 26.0# J-55 Surf 9790' 8-1/2" 400 sx Class G & 175 sx AS I . I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-'7/8" 9432 ' 9405 ' 9509 'MD 6675 'TVD 9558 'MD 6709 'TVD 9514'MD 6679'TVD . 9561 'MD 6711'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 9517'MD 6681'TVD 9563'MD 6712'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9519'MD 6682'TVD 9570'-9580'MD 6717'-6724'TVD 5313'-5352'(plug) 150 sx Class G 9545'MD 6700'TVD Perforated w/1 spf, 0° phasing See attached AddenJum, dated 01/29/87~ ' 9547 'MD 6701 'TVD 9553'MD 6706'TVD for Fracture dat . 27. N/A ' PRODUCTION TEST Date First Production Method of Operation '(Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL cHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (co/r) ' ' Flow Tubing Casing pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief descr ption of lithology, porosity, fractures,'apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Drilled RR 09/09/86. Tubing ran 12/10/86, Perforated well 12/20/86, Submit in duplica~ Form 10-407 Rev. 7-1-80 WC2:046 :DAN I CONTINUED ON REVERSE SIDE GEOLOGIC MARKEI~S " ' ~' '~:ORMATION TESTS ~' ~'x - . ::~ ~/. , . . : ... \~ 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 9268' 6510' N/A Base Kuparuk C 9322' 6547' Top Kuparuk A 9466' 6646' Base Kuparuk A 9649' 6772' 31. LIST OF ATTACHMENTS Addendum (dated 01/29/87), 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer ,.~9_<~? Signed &~( ~ .~t~ ~_~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc;). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 10/24/86 1/27/87 3K-18 Rn GR/JB to 9710'. Rn CBL & gyro. Frac Kuparuk "A" sand perfs 9509' 9514' 9517' 9519' 9545', 9547', 9553', 9558', 9561', 9563' & 9570' thru 9580' perf procedure dated 1/19/87 as follows: Stage #1: 100 bbls gelled diesel @ 20 BPM, 7050-5000 psi Stage #2: 54 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 5000-5050 psi Stage #3: 440 bbls gelled diesel @ 20 BPM, 5050-5130 psi Stage #4: 33 bbls gelled diesel 2 ppg 20/40 mesh @ 20 BPM, 5130-5095 psi Stage #5: 34 bbls gelled diesel 3 ppg 20/40 mesh @ 20 BPM, 5095-5376 psi Stage #6: 47 bbls gelled diesel 4 ppg 20/40 mesh @ 20 BPM, 5376-5480 psi Stage #7: 49 bbls gelled diesel 5 ppg 20/40 mesh @ 20 BPM, 5480-5700 psi Stage #8: 64 bbls gelled diesel 6 ppg 20/40 mesh @ 20 BPM, 5700-5681 psi Stage #9: 20 bbls gelled diesel 7+ ppg 20/40 mesh, 12-15 BPM, 5700-7400 psi Drop 8 ppg stage to go to flush. Stage #10:55 bbls gelled diesel @ 15 BPM, 5500 psi. Fluid to Recover: 852# gelled diesel Sand in Csg: 1025# Avg Pressure: 5700 psi Sand in Zone: 2200# of 100 mesh & 42,537# of 20/40 mesh 'Drilling~p~e~r-~is°r ~ / Date November 18, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60082 Well: 3K-18 Field: Kuparuk Alaska Survey Date: October 25, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARE:O ALASKA, F, JF ARLtK ALASKA fi;PE:RRY-'.:?;LIN t.4EI...L ?.i:t...IF,:VEY]'NG COMPANY I NC. C'OMPUTAT I ON DATE OCTOBER 28~ 1986 _ .. VtER-I"tCA/... StE(Z:]"ION (::AI..RULATED ALONG (::L TRL E ~E1BS'SE A COLIRSE ULI _IR.:,E MEASI...IRED VERT I C:AL VERT !.:CAL I NC:L INA]" I F~N D I REC:T I ON I"l E F:' '[' H [) [.':.: P 'l' H D E P T H D E I']i I'"I ]' N .1'-I E 0 R E E L--; ........ DATE OF .=,LRVEY OC:TODER.::.' ~' ,,_, ].'?:~:':- BOSS GYROSCOPIIL':. SURVEY dOB NUMBER .AK-BO-.~,0082 I<IELI_Y Bt.J:.'};HIIqG [i:l...[:-'V, ::---. ,'_":,':,,, C.'~)I i., OF'ERATCIR-SEL. L. E R :'_:i: DOG-LEG TOTAL. :SEVER I TV RECTANGULAR F:OORD I NATES; DEJG/1 O0 NC RTH/SCd...ITH () ("} ,, () () ..... 6':). 00 ("~ 0 iq 0. 0 E 0.00 0.00 0.0 10() '-7/9. '.:.,"F' :30 9'F¢ (] =:~: · a._, S :':: 9 E 0.9:':~ ('~. 7:2: S ("~. ":' 2 0 0 1 c.). ,.-./.. .......... 9 F-: 1 :':: ~"~. 9 ::: () =,.:~ ''", ,'-'..:, 2 4 . :3. 0 E 0. (]. 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TR JE .~ UB-oEA COLIRSE MEASlJRED VERT I CAL VERT I CAL I NCL I NAT I ON l) E P T H D E F' '1" H I: E F' T H l.'.t F G DATE OF :SURVEY OC:TOBEF;.: 25.-, BOSS AYROSCOPIC: SURVE::Y JOB NUP'IBER Ai<-BO-6008:2 KE]_/_Y BLI:-~;FJ I NG [::[LEV. -:: 6'? ,. 0 F'E R A'T OR--:.::;E L L_ E:F: C:OLIRSE DOG-LEG TOTAL. D I REF:T I ON '._=;EVER I TY :' .... ! -' REUTANUL LAR COORD I NATES Ivi I N I:1 [-.--: i.':.~ R [:." E S I'.l E G / 10 () N 0 R T H / '.:-; 0 I_1T H E A S T / W E E; '1" :30 ()C, 2!: 4 C:, :2:. :1. 4 :2:10C:, ':-24 72. 18 :3:200 25 :'2: '7.4,:') 330 C) .'2: /:, (} 2 . /:-., /:, :::.: 4 C) 0 266'7. J. 9 ::350(') :;77:}::c~. 64 2/_-,,:.':, 1.64 ::!: (':., () c~2'7'F'::i',. i :1. 2724. 11 :':~ 7 C) (') .':, c, =~ A ~"'; ':3' ..:. 7,:, 7,._J =: '~';, .... ...:, o::-., c~ :.'.38 0 0 '.-.' 9">2. 1:2: ,. ........... 12 ..... .-, c),-,-'. 97 :2:918.97 :::~'?(-)(') z. :. c, 7 4 C:, C:,,:.::, :305:3. ,:':, 7 :;2: '::"',!ii: 4.6 '7 4 J. 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'~'~;-_T'.:T;~z-:'"~/:%"' "i~i ............ 2112.62 .~l A, (")(') 4 (")7 9..=, (] 4 0 1 0 =' '~ ' 55'?. ............. ,0 49 .,.6 S 39 6C) E :::; ................................ ~:..~, 49 '":"-"E~ 1. '~"-' ................. . .~.,._ Yo S 2:1 14 57Cx') 4144.72 4075 72 49 z. o 1 Ct. 17 c; 2207 ";'":' .... ~ d~~i · . .-- . . ~ z 4.. 5:300 4:2; O' ':~' ?;4. ............ .4.:~ ....... 1 Z i=i'YcF2[ ..... .......... , --',-~' z. 4 '.:::':34 4 ~"~ 4, 'ii> .................. ('~ '- '-'"" ........ ~::;'po<) 4z. / I ::2:'7 42C)5. ::!:7 S ... 12: :27 2/z...., E!: J. S :2 :::: ('~ /-, J. 4. ARO] ALASKA, 3 K - 1 .B ALo. ASKA NC. ' ........................... V E F:;,' 1- .1; C A L MEAStJRED D E F' T H E;I='E R R Y-- S t_llq W I.'< I._ I_. '..=; U R V E Y I N G iS: elm P A N Y A N C.: H CI R A I:) E[ A L A L:; K A DATE OF SI lRVEY OCTOBEr: · UMF L TAT I ON DATE OCTOBER 2,C:, 1986 BOSS GYROSC:OF'IC SURVEY I '" "" q'-' /_', 0(.),...,: dOB NLMBER AK-BO- I<EI....I_Y BLISHING EL.EV. :=: 6'!;',,-'-.?0 F 'i',. 0 P E R A T m..-.~ R - S iii:.: L L.. E R S 'SECT':ION C:AL_C:LiI~A'TE~i-"nL. ON,:~ C: L ,'::, :=; LI F.~ E: · :; ~UB,: ;=.~EA C:OUR:=;E F:FIUR:=;E DOG-LEO TOTAL TRIJE ~' ~' _ ..... VER T I E:AL VERTICAL !_N_!~i_L_ !N._~.i? 1.'j?.,i, D !,R~C: T..~ ~;JN .E!EVE:R I TY RECTANGULAR COORD INA TES DEF"I"FI DEF'I"H DEC:; M I N i.]E;GRF:E'.S DE)S/'l. 0(') NORTH / :,E;OLITH EAST/WE:ST ......... 6.1 O0 4404.9 j. 4:3:7.~:5'["i~-~ ............... ~4'i~; ......... il .:~i ....... Ei "4:'i' [50' E ...... 0" 2i'~ ................ ::5("3~('%-'~'-'"~ ................... ~'~-~:.)'~;';"0:3 E 6:::00 4469. ':):::.. _ 4.40C) . '::¢:R.... 49 :34 '::'...., 42. lC) E 0 . ....... :3C)9A. '92._ . 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O0 -478.2C) S 404. 18 E 17L::. 77 ::.:.; :'}l: . :3;.':, ' i 7/.b" '0(;) .......... ....... 1700 ARCO AL. AS;KA ~ :3 K- 1o KUPARUK E;PERRY-SLIN WELL SURVE;YING CC)MPANY ANE:HORAGE ALASKA INC. COMPUTATION DATE OCTOBER 28, 1986 DATE OF SLIRVEY OCTOBER '25-, ,_lOB NUMBER AK-BJ-6)Oo~; A L A 53 I< A KELLY BLISHING EL_lEV. OF'E R A T OR--:E;E L. [.. E F;,':~; tN~~TED VALLIES FOR EVEN 100 FEET OF SUB-SEA DEPTH I"RLIE ME A Lz:;I_tR£:. J.-.I VE:R]' ! CAE ""' E F' ]" F'I D E F:' T H SUB'SEA TOTAL V E R T I r:': A t_ f:;,' E C 1- A N G !J I... ~'-":~ F';: (:: 00 F;,' D l N A 'r E'.E; M D-- T V D V E R 1' I C A I .... . . DEI::'-H-I IqOR TFI / Ei;L31..I'T H [:-.; A S"f' / W E L::;'F D I F'FEF;,:ENC:E CORRECT I ON .~. 144 1 ::',6':9. 2 :.5: () .l 196'.9, 24. 59 :2069 -::'/-]. 8 2 ]. ;' ':; ';;:' 7 '7.':'. 226.'?. 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C) 1 S 676 ?, 00 ,..':, 700.00 ~ '.:.:' 2: '.-:>, 2'.:.? :B/_:.,61. 1 :!.::: E 251C:. 8S: .,'.'['7.4-4 :B '736, () 4 E "'.' 5"_-""7 .... .~. ..... 7'i;) 46.9 :}.", 810.2!:4 E 26 ():7-.':. ? 7 46. 1 .................................................................. :3884 5~] E ' -:' /- P; ,' b O0 46 0:':: :B957, :32 E .'.]'6'.:.~4. ::::0 44,80 4 ():29 '-' ,..:,.,.: E" '-'7'"F' 80 43 9':;, 41 ()2,, 38 E 2'784.44. 45./?,4 41 '75, 'P'.:.~ Ii.:- 28:.:]:0.2'P 45.85 424. 7, 'P 5 E :2:875.21 44. '!? .1. THE NEAR[i::.:.';T 2() F:'OOT MD (FRCd'I I::;:ADIL.IS OF CL.IRVA'f'LIR~) F:'OIN]"S ARCO 'ALASKA, INC:. :'-": K- 18 KIJF'ARLfl< :~i;F'E:.RRY-.'.'31...IN WELl... SURVEY I NG COMF'ANY A N C H 0 R A (.:i E A L.. A ~.:_'; K A COMF'UTATION DATE OCTOBER 28, 1.986 ,..lOB NUMBER AK-Bt-i-60082 _. MEASURE.r_;~ "'"EF'TH 926:3 '.:.)322 9466 ?64 ? ? 700 ?705 ?84:3 I<Et..LY BL.I:3HINC-i E'I....EV, : .... .:!:,'::.,., ,h,:~ i ,. 0 p E R A 1- 0 R --::-.; E L., i..,. E R :F.'; T R U E ':: SUB' S E A T 0 T A L. V I::.i-~ I I L..~..,LVERT I CAL. REC'r'ANC. iI...Ii.._AR COORD I NA'I'E:!ii; ;[)EPTH -f]EF'TH hlORTH/S(:)I..ITH EAS'r' / WE:.'.:.;T MARKER ,': ':'" .40 47o I.._ o c ~..::, :: . ._,,.., r_ TOP k:LtF'ARUK C :,.,, 10. Zh.:.: .....~,44~ .......... ;:~' ............................. :' ''"' q' '",'; '~0~"5'''''~'';''''' '=' '. , c,. 46 47~':',' 9(] S 4086 5? E BASE I-:,LIFARJi-:, C (:,...,4 7 46 /:.,4'~''-' . ...... ' ' 'i '" ,'_"',,'.':,46 1':¢ 6577. 19 '-'""=' ~4 ?;9 "'-' "t" -' '" .... 4,:,..:,._,... S 4 :[ .... 18 E T U I- k. L F A R Ltl-:., A ,..':, 7"z ::,. 36 :.' -~,-;.,--.,"- :::,;z(:, ,, ...,..:.,, ,:, :, ..................... ";!i.'!~]~?J:] '-:~'iF:.? ':¢: ./1:2.~:i(:;i. 2-~:; ............. ,.'3, 80 :::]. 62 6 '7 ::3'!.') ,'32 4':::"::;',:::. '"'":~ ....... / .._ S 42'7::ii: ';;)2 E '..:.'i;UR VE Y DE'F' TH 68 ;I. 2.2.t 674:_::,, 2:1. 4-?61.3':".:' :iii; 4-276. J. '.-::' E F:'L. UG BAC:K TD ""'""' ................ ~' "' :':'Z ::'"" t~ ' ~'.,:,'.911. 6842..:,.: ...... (J._:, .!-.._:,C) 4.::,..:,o. 6'7 E :3K- 18 STRATI GRAF'HIC oLIMMAiRY DERIVED USING D IL DEPTHS AND SPERRY SUN 'SURVEY DATA BKB BKB oUB-oEA VERT I CAL. 'TOF' KI._IF'AF(I._IK C 9268 ~151 (), 4:3 6441,48 4'7:}.': .I., :36::.:.: ]:'.4 A L:; E: I-::]_.IF'ARL.I}::.' C '.-.-/322 6547: 46 6478.4,'_'-:, 'T(.]I::' I< i._t F:' A IR LI I< A 'i?4C-,./:, 6,'.':,,-.~,'..~,, 1'? 657'7. 1 ':.:; 4',.:.':',:.E:...5, BASE KLIPARLIK A '.:.>64'.~ 6772 :F.:/_-, /-7C)::: :.:.:6 4':-/:L::l ':":":' - . # .... . . P L. UG B A C K 'TD '.:) 705 681 ":2, :21 674:3, :2 ! 4 TOTAL. DEPTH DRILLER '784:3 6911. :3:3 6842.3:3 50:34. :30S 1 ) F'FROM LINE:AR EXTRAF'("iLiAT'ICIN BEI....EIW DEEF'E:F.;T' :..=.:TATION. 2 ) COMPI I'l'ER F'I-RI-u]F:AM - ._,!,- ERR SUN THREE D I MENc, I ONAL RAD I Lit-'.; OF CL!RVATURE. DATA C:ALCLIL. ATION AND INTERPOLATION BY RADIUS OF E:URVAIlt'JRE ..... DATE: OF SURVEY OCT'ODER 25, .l':.;'86 C 0 MF'U T A'T I i:.'iN D~t TEE 0_, rUDER ",,' 986 ,'- · ..~, 1 ._lOB NUMBER At... BJ-6¢.Ooz I-:::ELL::!~:::i::.,B:IJ~BING EI..EV. = 67.00 FT. ..................... KUPqC _;" TRUF NP~]:: I O0 I 2'300, O0 -SCCC. :CC I ~000. O0 ""x , xx. ',, I 4.000. OC : 50C. 20 45CC -~ 6000..00 5CRLE ; - i iNCh lC iSCO, CC ,,' LSOO. C KuPqq:JR qecc qLRSKq. 3K-18 8C~OBffq 25. qR-8~-SC082 tNE. [986 : ,: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Al~,ska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 959' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1508' FSL, 1428' FEL, Sec. 1, T12N, R9E, UM At effective depth 1278' FSL, 1212' FEL, Sec. 1, T12N, R9E, UM At total depth 1205' FSL, 1149' FEL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 69 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-18 ~. 4/~ ~ c~ ~_ 9. Permit number/approval number 8-529 10. APl number ~0-029-21641 11. Field/Pool Kuparuk River Oil Pool 9843' MD feet Plugs (measured) 6911' TVD feet None feet Effective depth' measured 9705' MD feet Junk (measured) true vertical 6812' TVD feet None Casing Length Size Cemented Measured depth Structural Conductor 80' 1 6" 1540# Poleset 115' Surface 5278'. 9-5/8" 1510 Sx AS III & 5315' Intermediate 375 Sx Class G Production 9790' 7" 400 Sx Class G & 9790' Liner & 175 Sx ASI Perforation depth: measure 9509', .9514', 9517', 9519', 9545', 9561', 9563', 9570',-9580' MD True vertical depth 115' 3894' 6873' 9547., 9553', 9558', true vertical 6675', 6679', 6681', 6682', 6700', 6711', 6712', 6717'-6724' TVD Tubing (size, grade, and measured depth) 2-7/8", L-80, tbg w/tail @ 9432' Packers and SSSV (type and measured depth) HRP pkr @ 9405'~& TRDP-1A-SSA SSSV @ 1816' 6701', 6706', 6709', 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ~fasl~ [Iii & Gas Cons. ~" .~.~, ~chorage 14. Prior to well operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 419 144 0 1110 Tubing Pressure 100 Subsequent to operation 1300 400 2350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S'~ ned /~4:~.~/~1 ~ ~. ~f,~~ Form 10-404 I~ev 06/15/88 Title Date ~)~"-~.,, ~) ~I' ,~ SUBMIT IN DUPLICATE ARCO Alaska, Inr'-' ~ Subsidiary of Atlantic Ricl~field Compan~ WELL SERVICE REPORT WELL )PBDT CONTRACTOR REMARKS J FIELD - DISTRICT- STATE II( u P, qRu~( OPER~T-ION AT REPORT TIME _J_ /v'~ 4,t P L F_ o '~ o o ff l I R bL Om ~ ~ O. O,v v£~ $ /~,,u JDATE o'~3o 'P.T. o~'o~ 'P.,I~ ., IIOO H. R~, ~o ! s~+ D I-7: oo I.oJ Weather Report IF s~ ' I'~ ~LV Z~~ !~, C~v~~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knote ~ ARCO Alaska, Inc.~_~ Subsidiary of Atlantic Richfield Company WELL CONTRACTOR FIELD- DISTRICT- STATE OPERATION A~' REPORT ~'IME WELL SERVICE REPORT J I - REMARKS r-'-J CHECK THIS BLOCK If SUMMARY CONTINUED ON BACK Weather]TemP.Report OF Chill Fact°r i VisibilitY°F miles Iwind Vel' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. Operation Shutdown__ Stimulate Plugging Perforate Pull tubing Alter casing , Repair well Pull tubing , Other .... 6. Datum elevation (DF or KB) 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 959' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1508' FSL, 1428' FEL, Sec. 1, T12N, R9E, UM At effective depth 1278' FSL, 1212' FEL, Sec. 1, T12N, R9E, UM At total depth 1205' FSL, 1149' FEL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical RKB 69 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-18 £ 4/~' t,'_ c~o ~_ 9. Permit number/approval number 8-529 10. APl number so-029-21641 11. Field/Pool Kuparuk River Oil Pool 9843' MD feet Plugs (measured) 6911' TVD feet None X,, feet Effective depth: measured true vertical 9705' MD feet Junk (measured) 6812' TVD feet. None Casing Length Structural Conductor 80' Surface 5 2 7 8'. Intermediate Production 9 7 9 O' Liner Perforation depth: measure Size Cemented Measured depth True vertical depth I 6" 1540# Poleset 9-5/8" 1510 Sx AS III & 375 Sx Class G 7" 400 Sx Class G & & 175 Sx ASI 9509', 9514', 9517', 9519', 9561', 9563', 9570',-9580' 115' 115' 5315' 3894' 9790' 6873' 9545', 9547', 9553', MD 9558', true vertical 6711', 6712', 6717'-6724' TVD Tubing (size, grade, and measured depth) 2-7/8", L-80, tbg w/tail @ 9432' Packers and SSSV (type and measured depth) HRP pkr @ 9405''& TRDP-1A-SSA SSSV @ 1816' 13. Stimulation or cement squeeze summary Intervals treated (measured) 6675', 6679', 6681', 6682', 6700', 6701', 6706', 6709', Treatment description including volumes used and final pressure .0il & 6as Cons. - -',~,~ ~mch0rage Prior to well operation Subsequent to operation Re0resentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 419 144 0 1110 Tubing Pressure lO0 1300 4OO 235O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil ~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 I~ev 06/15/88 Title Date .~'""~ ~. '~' ~ SUBMIT IN DUPLICATE ARCOAlaska, Inc ..... · Subsidiary of Atlantic Rict~field Company WELL l PBDT JFiELD- DISTRICT - STATE CONTRACTOR WELL SERVICE REPORT REMARKS o'~oo . ~ I R LL 0'1-~5 OPER~.~T-ION AT REPORT TIME J-- Arena.4 pL E, r'ff IDAYS ~ lDATE __ ~7,~. ~ ~ 9 4, ~ R ~ ~.o/vv~/~s/o~u ~s~- ~,-.- ¢I~O~' 0730 I'"l: oo ID, U +o ~LW, ~2.. s~z, CHECK THIS BLOCK IF SUMMARY CONTINUED ON 'BACK J Signed, knotJJ ~~_.~/~' ~~ ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL iPBDT CONTRACTOR REMARKS IFIELD- DISTRICT-STATE ~,,~,o,~ r~ t< IOPERATiON A~T REPORT ~'IME WELL SERVICE REPORT DAYS ~'-~ .~' l-! CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weether Temp. [ Chill Factor [ Visibility JWindVel.Report oF oF milee ADDENDUM WELL: lO/24/86 1/27/87 6/26/87 3K-18 Rn GR/JB to 9710'. Rn CBL & gyr°. Frac Kuparuk "A" sand perfs 9509', 9514', 9517', 9519', 9545', 9547', 9553', 9558', 9561', 9563' & 9570' thru 9580' perf procedure dated 1/19/87 as follows: Stage #1: 100 bbls gelled diesel @ 20 BPM, 7050-5000 psi Stage #2: 54 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 5000-5050 psi Stage #3: 440 bbls gelled diesel @ 20 BPM, 5050-5130 psi Stage #4: 33 bbls gelled diesel 2 ppg 20/40 mesh @ 20 BPM, 5130-5095 psi Stage #5: 34 bbls gelled diesel 3 ppg 20/40 mesh @ 20 BPM, 5095-5376 psi Stage #6: 47 bbls gelled diesel 4 ppg 20/40 mesh @ 20 BPM, 5376-5480 psi Stage #7: 49 bbls gelled diesel 5 ppg 20/40 mesh @ 20 BPM, 5480-5700 psi Stage #8: 64 bbls gelled diesel 6 ppg 20/40 mesh @ 20 BPM, 5700-5681 psi Stage #9: 20 bbls gelled diesel 7+ ppg 20/40 mesh, 12-15 BPM, 5700-7400 psi Drop 8 ppg stage to go to flush. Stage #10:55 bbls gelled diesel @ 15 BPM, 5500 psi. Fluid to Recover: 852# gelled diesel Sand in Csg: 1025# Avg Pressure: 5700 psi Sand in Zone: 2200# of 100 mesh & 42,537# of 20/40 mesh RU CTU, RIH, wsh f/9000'-9705'. Rec pipe f/TD to 9432', CBU. Displ CTU & rathole w/cln diesel, POH, displ'g well w/cln diesel. Turn well over to Production. Drilling Supervisor DEC 1 9:19S8 Alaska Oil & {~2s Con::. Commission '7'- 2 Date ARCO Alaska,/nc. Date: September 7, 1988 RETURN TO: Transmittal #: 7285 ARCO Alaska,/nc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed Copy of this transmittal. 3F-13 3K 18 3B-13 '3Q-15 3N-08A 1E-12 '~ 3K-14 '31-03 1Y-06 1Y-07 Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Please acknowledge receipt and return 8 - 2 7- 8 8 Casing 8 - 2 7 - 8 8 Tubing 8 - 2 6 - 8 8 Casing 8 - 2 7- 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Casing 8- 2 6- 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Casing 8 - 2 6 - 8 8 Both Sands 8 - 2 6 - 8 8 Sand 'A' Receipt Acknowledged: D&M State of Alaska · : . Chevron Unocal Mobil SAPC ARCO Aleska, Inc. Post Office Be,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 7, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are. two Applications for Sundry Approvals. One is a request to add additional perfs in the A Sand (A5 Sand) and the other is a request to convert a production well to a water injector. Well ' Action 1F-12 Perf A5 Sand ~3K-18 Conversion Anticipated Start Date July, 1988 July, 1988 If you have any questions, please call me at 265-6508. Sincerely, Senior Operations Engineer JME:cp:O092 Attachments cc: File KOE1.4~9 ARCO Alaska, Inc. is a Subsidiary of AllantlcRIchfleldCompany : STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIVi,$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown :} Re-enter suspended well :-q Alter casing Il T~me extension Change approved program Plugging "~ Stimulate .? Pull tubing Amend order ,r Perforate [' Other 2 Name o.f.,Op~rator, ARCO AlasKa, znc 3 Address PO Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 959' FSL, 315' FWL, Sec. 35, T13N, RgE, UM At top of productive ~nterval 1508' FSL, 1428' FEL, Sec. 1, T12N, R9E, UM /~i'2~f~e'ct~Ld,epj.~12' FEL, Sec. 1, T12N, RgE, UM At total depth 1205' FSL~ 1149' FEL, Sec, 1, T12N, RgE, UlVl R~,BD~t~m elevation (DF or KB) 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-18 pS. Pe.r~nit, p.~ml;)gq erml 'g F~O-J.::).L 0 ~0-.~21~l~ber 10. Pool Kuparuk River 0il Pool feet 11. Present well condition summary Total depth' measured 9843' MD feet true vertical 6911' TVD feet Plugs (measured) None Effective depth: measured 9705' MD feet true vertical 6812' TVD feet Junk (measured) None X X xIx~Xe('RlexIJ~l~ e Production 9790' xxxL2R~rxxxxx Perforation depth: measured Casing Length Size Cemented Measured depth True Vertical depth Structural 80' 16" 1540# Poleset 115' 115' Conductor Surface 5278' 9-5/8" 1510 SX ASIII & 5315' 3894' 375 SX Class G 7" 400 SX Class G & 9790' 6873' & 175 SX ASI 9509', 9514', 9517', 9519', 9545', 9547', 9553', 9558', 9561', 9563', 9570'-9580" MD true vertical 6675' 6679' 6681' 6682' 6700' 6711' 6712' 6717'-6724' TVD Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail @ 9432' Packers and SSSV (type and measured depth) HRP Dkr 0 9405' & TRDP-1A-SSA SSSV @ 1816' 12.Attach'ments Description summary of proposal ~! Detailed operations program Convert from oil producer to water injector. 13. Estimated date for commencing operation July 15, 1988 14. If proposal was verbally approved Name of approver ~ Date approved e~ cer~ that the foregoin~ is t~ and correct to the best of my knowledge l .,h Signed~ ~ Title Sr. Operations Engineer Commission U~o Only Date 6/29/88 Conditions of approval Approved by Form 10-403 Rev 12-1-85 Approval No. O~--~._..~__h. ~ Notify commission so representative may witness r-'., Plug integrity E} BOP Test ID Location clearance ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned by order oJ C'0mm'issi0rier- ~ the commission Date ~.--/~.-~ Submit in triplicate Well 3K-18 Application for Sundry Approval 1. Propose conversion from production to water injection. 2. No BOP equipment will be required. 3. The estimated static BHP is 2200 psi at 6200' TVD-SS. 4. No workover fluids will be required. STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMN .,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate ~ Pull tubing Alter Casing1,~ Other [~ COMPLETE 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 959' FSL, 315' FWL, Sec.35, T13N, R9E, UM At top of productive interval 1508' FSL, 1428' FEL, Sec. 1, T12N, RgE, UM At. effective depth 1278' FSL, 1212 FEL, Sec. 1, T12N, RgE, UM At total depth 1205' FSL, 11/+9', FEL, Sec. 1, T12N, R9E, UM 11. Present well condition summary Total depth: measured true vertical 9843 ' MD 6911 ' TVD feet feet Plugs (measured) 5. Datum elevation (DF or KB) RKB {;~) ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-18 8. Approval number 422 9. APl number 50-- 029-21641 10, Poe ol 'l(uparuk River Oil Pool, 5313' - 5352' w/150 sx Class G Effective depth: measured 9705 'ND true vertical 6812 ' TVD feet feet Junk (measured) None Casing Length Conductor 80' Surface 5278' Size 16" 9-5/8" Production 9790' 7" Cemented 1540# Pol eset 1510 sx AS III & 375 sx Class G 400 sx Class G & 175 sx AS I Measured depth 115'MD 5315'MD 9790 'MD True Vertical depth 115" TVD 3894 ' TVD 6873 ' TVD Perforation depth: measured None 12. true vertical None Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail @ 9432' Packers and SSSV (type and measured depth) HEP pkr ~ 9405~& TRDP-1A-SSA SSSV @ 1816' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure N/A 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 (Completion Well Hi story w/Addendum, dated 11/15/86) Daily Report of Well Operations 2~ Copies of Logs and Surveys Run ~ Gyro Title Associate Engineer Date (DANI) SW0/150 Submit in Duplicate Feet ADDENDUM WELL: 9~09~86 10124186 3K-18 Arctic Pak w/175 sx AS I & 60 bbls Arctic Pak; tst OK. Rn GR/JB to 9710'. Rn CBL & gyro. j A'~;,~ 1Bg7 Naska Oil & ¢~as'Eqns. commission RECEIVED FEB 0 2 1987 Alaska 0ii & (~as Cons, Commission Anchorage ///lC- / Date ~ ~s ' the "Flflll R~pe~' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Flail R~" sl~ould be submitted also when o~erations Ire suspended for an indefinite or appreciable length of time On workovers when an official teat is not required upon Gompletlon, repo~t completion and represefltltlvl test data in blocks provided. The "Final Repe~t" form may be used for reporting the entire operation if space il availaPle. Dlatrlct ICounty or Parish I Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no. ITitle AFE AK1509 Nordic 1 Operator I A.R.Co. W.t. ARCO Alaska, Inc. Spudded or W,O. begun Date Complete 12/lo/86 Date and depth as of 8:00 a.m. 12/~1/86 Complete record for each day reported North Slope Borough Accounting cost center code State Alaska Well no. 3K-18 ADL 25629 Completion AP1 50-029-21641 rTotal number of wells (active or inactive) on this [cost center prior to plugging and 56,24% labandonment of this well IH°ur I Prior status if a W.O, 12/9/87 / 2330 hrs. 7" @ 9790' 9705' PBTD, Rn'g 2-7/8" CA 9.9 ppg Brine Accept rig @ 2330 hfs, 12/9/86. w/ 2-7/8" CA. ND tree, NU & Cst BOPE. RIH 7" @ 9790' 9705' PBTD, RR 6.8 ppg diesel Rn 294 its, 2-7/8", 6.5#, L-80 EUE 8RDAB-Mod tbs w/SSSV @ 1816', HRP Pkr @ 9405', TT @ 9432'. Shear out OEJ, cst ann to 2500 psi. Tat SSSV; OK. ND BOPE, NU &tst tree to 250/5000 psi. Displ well w/diesel. RR @ 1800 hfs, 12/10/86. Old TO New TD Released rig Date 12/10/86 Classifications (oil, ga/, etc.) Oil Producing method Flowing Potential test data IpS Depth 1800 hfs.I {Kind of rig jType completion (single, dual, etc,) Single Official reservoir name(s) Kuparuk Sands 9705' PBTD Rotary W~ll no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per d~y " ' Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effe~ilve date corrected ,,. The above iS correct For form preparation and distribution, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE December 31, 1986 TRANSMITTAL #5865 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Final Prints: (1 blueline copy unless otherwise specified) 3K-18 2" DIL 9'7-86 1000-9836 .'5" FDC Porosity 9-7-86 8900-9810 Cyberlook 9-7-86 9150-9750 2" FDC Porosity 9-7-86 8900-9810 5" DIL 9-7-86 1000-9836 ~5" FDC Raw 9-7-86 8900-9810 2" FDC Raw 9-7-86 8900-9810 3K-7 ~5" FDC Raw 9-22-86 4582-8468 -- 5" FDC Porosity 9-22-86 4582-8468 --'2" DIL 9-22-86 1000-8494 --- 5" DIL 9-22-86 1000-8494 --~ 2" FDC Porosity 4582-8468 ~- 2" FDC Raw 9-22-86 4582-8468 ---Cyberlook 9-22-86 7800-8400 Receipt Acknowledged: DISTRIBUTION: NSK lState of. ARCO Ala-ka. In(:. ,s · Subsidiary of AtlanticRichfieldCompanY STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION COb,,.~ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Ak¢ Receipt ~ . of the fOllowing material which was transmitted via is hereby acknowledged: .QUANTITY .f-- A"E P-vA DESCRIPTION go~o Copy sent to sender YES ~ NO...__ '. ~, ARCO Alaska, Inc, Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 . RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE10-02-86 TRANSMITTAL #5785 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Tapes plus Listings': Schl: One copy of each 2T-7 08-26-86 Run #1 3K-18 09-07-86 Run #1 0097.0-6982.0 ..-/t~'~ 3/c~-- 5--d/:)~--/'; - c/~--~' ~'oO',.7. 0993 0-9880 ~~3 /~/-- ~-~/:%P--/3-" f 9~3 -- ~'c~',=?~ Receipt AcknoWledged: S.t~'{e of E IVED hlaska 011 & Gas Cons. Commission Anchorage Date: ARCO Alllkl. Inc. il a Subsidiary of AllanlicRichfielclComl3lny STATE OF ALASKA .... ALASKA ~L AND GAS CONSERVATION COMMIS....ON 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 ' 5. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 959' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1621' FSL, 1576' FEL, Sec. 1, T12N, R9E, UM (Approx.) At e~f2~tiv~SdLe, pth215' FEL, Sec. 1, T12N, R9E, UM (Approx.) At tg~z14¢el~, 1145' FEE, Sec. 1, T12N, RgE, UM (Approx.) 69 ' RKB 6. Unit or Property name Ku_D~rvk River Unit 7. Well number 3K-18 8. Permit number 86-151 9. APl number 50-- 029-21641 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 9843 ' MD feet 6895 ' TVD feet 9705 'MD 6798 ' TVD feet feet ProduCtion Length Size 80 ' 16" 5278' 9-5/8" 9790 ' 7" Plugs (measured) 5313' - 5352' w/150 sx Class G Junk(measured) None Cemented Measured depth 1540# Poleset 115'MD 1510 sx AS III & 375 sx Class G 5315'MD 400 sx Class G & 9790'MD 175 sx AS I True Vertical depth 115 'TVD 3897'TVD 6857 ' TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None ECEI¥ D SEP 2 5 198 0il & Gas Cons. Corem:ssi; Anchora~r'~ 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch Well History, Addendum (dated 9-16-86) 13. Estimated date for commencing operation November, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ ~ Title Associate Engineer ~/ Commission Use Only (DAM) SA/119 Conditions of approval Notify commission so representative may witness I Approval ~ Plug integrity ~ BOP Test [] Location clearance I Date NO. Dy order of /) .),, ~yJ I I ~ ~ Commissioner the comm'ss'on Date ~';~ '~ ?l Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily instructions: Preoare 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 Kuparuk River Auth. or W.O. no. AFE AK1509 ICounty, parish or borough North Slope Borough IL .... or unit ADL 25629 ITitle Drill State Doyon 9 Operator API 50-029-21641 ARCO w.I. Pr or status Alaska Well no. 3K-18 56.24% if a W,O. ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date 8/29/86 IH°ur Date and depth as of 8:00 a.m, 8/29/86 8/30/86 thru 9/02/86 9/03/86 9/04/86 Complete record for each day reported 0630 hrs. 16" @ 115' 115' (0') MU BHA Move rig 3K-17 to 3K-18. Nipples up diverter. MU 12¼" BHA. 16" @ 115' 5331', .(5216'), POOH Spud well @ 0630 hrs, 8/29/86. Drl to 427', DD & surv 12¼" hole to 5300', short trip, C&C, POOH. TIH, drl to 5320', circ, POOH. RU & rn 133 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 5234', FS @ 5315'. Cmt w/1510 sx AS III &.375 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter, NU & tst BOPE. TIH w/8½" BHA, DO cmt & flt equip + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Att to drl, POOH to ck bit. 373', .4°, S32.2W, 373.60 TVD, 0.39 VS, 1.10S, 0.69W 1107', 1486', 1897', 2908', 3570', 4797', 5245', 25.4°, S41.7E, 1080.70TVD, 167.68VS, 134.87S, 100.22E 36.2°, S39.7E, 1403.04TVD, 365.92VS, 286.37S, 228.06E 45.1°, S41,1E, 1709.20TVD, 639.47VS, 496.26S, 403.52E 52.0°, S32.7E, 2359.11TVD, 1409.98VS, 1121.26S, 857.86E 51.5°, S38.0E, 2780.33TVD, 1919.43VS, 1529.60S, 1164.04E 51.0°, S38.8E, 3574.70TVD, 2852.79VS, 2275.95S, 1727.07E 52.3°, S35.0E, 3852.66TVD, 3203.43VS, 2556.86S, 1937.98E 9-5/8" @ 5315' 5352', (21'), TIH w/rev jet bskt Wt. 8.6, PV 4, YP 1, PH 9.5, WL 17.6, Sol 2 RIH w/turbine & att to drl, POOH. PU junk mill/JB, TIH, mill on junk, POOH. TIH w/bit & JB, drl on junk, POOH. PU rev jet bskt & TIH. 9-5/8" @ 5315' 5352', (0'), POOH Wt. 8.6, PV 3, YP 1, PH 9.5, WL 17.2, Sol 2 TIH w/mill, mill over junk, POOH; no rec'y of cone. TIH w/DP, pmp 150 sx Cl "G" w/2% S-1 & .2% D-46. WOC. TIH, tag cmt @ 5028', drl cmt to 5313', lost pmp press, POOH, lk'g f/wshout. SEP 2 5 Gas GoDs, Alaska O~t & The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. J ~/~.-~_'~/~ .{cIDateI Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If !esting, coring, or perforating, show formation name in describing work performed Number all drill stem tests sequentially. Attach description of al cores Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers aha following setting of oil string until completion District ICounty or Parish [State Alaska North Slope Borough Alaska Field Lease or Unit IWell no. Kuparuk River ADL 25629 J 3K-18 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 9/05/86 9/06/86 thru 9/08/86 9-5/8" @ 5315' 6801', (1449'), Drlg Wt. 9.0, PV 8, YP 5, PH 9.5, WL 13.2, Sol 5 RIH w/new BHA, drl sidetrack f/5313'-5384', POOH, PU turbine, TIH & drl to 6801'. 5692', 49.4°, S40.4E, 4130.81TVD, 3553.50 VS, 2828.15S, 2159.32E 6324', 50.0°, S41.3E, 4540.00 TVD, 4035.13 VS, 3196.15S, 2470.03E 6795', 50.9°, S45.0E, 4839.91TVD, 4397.79 VS, 3461.06S, 2718.36E 9-5/8" @ 5315' 9843', (3042'), POH f/logs Wt. 10.0, PV 22, YP 8, PH 9.5, WL 4.0, $ol 12 Drl & surv 8~" hole to 9843', 20 std short trip, C&C, POH. RU Schl; unable to get below 7718'. Make wiper trip, CBU & spot diesel pill, POH. 9/09/86 7301', 7804', 8304', 8803', 9296', 9745', 48.5°, S46.4E, 5167.16 TVD, 4781.96 V$, 3730.56S, 2994.53E 49.2°, S50.4E, 5502.19 TVD, 5152.94 VS, 3984.83S, 3268.24E 47.4°, S44.7E, 5834.79 TVD, 5523.12 VS, 4236.68S, 3543.58E 46.9°, S45.5E, 6174.15 TVD, 5887.68 VS, 4494.91S, 3802.71E 46.7°, S47.5E, 6511.63 TVD, 6244.95 VS, 4742.28S, 4063.38E 44.5°, S44E, 6825.76 TVD, 6564.24 VS, 4966.08S, 4293.12E 9-5/8" @ 5315' 9843', (0'), Rn'g 7" Wt. 10.0, PV 20, YP 8, PH 9.5, WL 4.2, Sol 12 POOH. RU Schl, log DIL/SP/SFL f/9844'-5315', GR f/9844'-1000' , FDC/CNL f/9844'-8900', CAL f/9844'-5315', RD Schl. Make cond'g trip, POOH. RU & rn 7" csg. The above is correct Signat~~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IOate . JTitle Drilling Supervisor ARCO Oil and Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable nas been assigned or well is Plugged. Abandoned or Sold "Final Report" should be submitted aisc when operations are suspended tor an indefinite or appreciable length of time. On workovers when an official test is qot reouired upon completion, report completion and representative test data n blocks provided. The "Final Report" form may be used for reportmg the entire operabon f space is avmlable. DistrictAlaska County or Parish Field ILease or Unit I Kuparuk River Auth. or W.O. no. Title AFE AKI509 I Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. oegun Spudded Date and depth as of 8:00 a.m 9/10/86 North Slope Borough ADL 25629 Accounting cost center code State Alaska Drill JWell no. 3K-18 API 50-029-21641 A.R.Co. W.I. Date 56. 24% 8/29/86 Complete record for each aay reported I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our ' I Prior status if a W.O. I 0630 hrs. 7" @ 9790' 9843' TD, 9705' PBTD, RR 10.0 Brine Fin rn'g 238 jts, 7", 26#, J-55 BTC tbg w/FS @ 9790', FC @ 9705'. Cmt w/100 sx 50/50 w/4% D-20 & .2% D-46 & 300 sx C1 "G" w/3% KCl, .9% D-127, .3% D-13 & .2% D-46. Displ w/lO.0 ppg brine, bump plug. ND BOPE, instl pack-off & tbg head. Tst flange to 3000 psi. RR @ 1800 hrs, 9/9/86° SEP 2 5 Gas Cons. Old TD Rel eased rig 1800 hrs. Classifications (oil, gas, etc,) 011 INew TD PB Depth 9843' TD 9705' PBTD JDate K nd of r g 9/9/86 Rotary Type completion (single, dual etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day . Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected .,. The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. J ~4/(~,,~ ~Date JTitle Drilling Supervisor ADDENDUM WELL: 3K-18 9/09/86 Arctic Pak w/175 sx AS I & 60 bbls Arctic Pak; tst OK. Drilling Supervisor Date MEM ORAIUDUM , Staf - of Alaska TO: ALASKA O~ AND GAS CONSERVATION COMMIboiON Chai.~~6C. V./ ~h' rton DAIE: September 5, 1986 F~tE NO.: D.JFB.12 THRU: Lonnie C. Smith TELEPHONE NO,: Commissioner FROM: John F- Boyle ~J~ ~ Petroleum Engineer Asst SUBJECT: BOP Test ARCO KRU 3K-18 Permit No. 86-151 Kuparuk River Field Monday, Sep.tember !,. !986: I traveled this date from Nordic Rig '#1' sUbjeCt 0f"~nother report, to Doyon Rig #9 to witness a BOP test. There was one failure. On. the upper set of pipe rams the bonnet seal leaked. This was .repaired, and tested satisfactorily. Ail other tests were performed with no problems. I filled out an AOGCC BOP inspection report 'which is attached. In s~ary, I witnessed the BOP test on Doyon Rig #9. Attachment 02-001 A ( Rev 10-84) . .~' :- ~ ' STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report General Housekeeping, - Operator ~ ~ ~_ Location: Sec / Drilling Contractor Location, General Rig Reserve Pit Well Sig~__ Rig. Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Visual Audio' . 'i~:i/iAnnular PreVenter ~ -"30'~ 01II I :I' Choke Line Valve~\~/Jt V "Ve !1 Check Valve~.%z ..~ ' ,:~. ,,~,.- ti Test Results: Failures -'~___.___.-~ Representative ~ ^~u.~c Di~.~N Q.,?~e Casing Set RePresentative ACCUMULATOR SYSTEM Full Charge Pre,ssure Pressure After ClosurJ~ psig psig Pump incr. clos. pres. 200 psig,. ~,min~sec. Full Charge Pressure Attained:__ ~ min~sec. Controls: Master ~ ~ Remote O~ Blinds switch cover _.Kelly ~nd Floor Safety Valves Upper Kelly2 ©'~' Lower Kelly'.'O .. Ball Type Inside BOP O Choke Manifold No. Valves Test Pressure Test Pressure Test PressUre Test Pressure.. ~00' D~ JO0% Test PresSure No. flanges Adjustable Chokes . Hvdrauicall¥ operated choke Test Time ~ hrs. · Repair or ReplaCement of failed equipment to be made within ----- days and Inspector/ Commission office notified. O' -0 Distribution "orig. - AO&GCC cc - Operator cc - Supervisor August 7, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3K- 18 ARCO Alaska, Inc. Permit b~o. 86-151 Sur. Loc. 959'.FSL, 315'FWL, Sec.35, T13N, R9E, UM. Btmhole Loc. l146'FSL, l172'FEL, Sec. 1, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~_~,~ trg~ours, Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery .... STATE OF ALASKA .... ALASKA ,,.. ~,_ AND GAS CONSERVATION CC .~VIISSION " .....PERMIT TO DRILL ,,,/'l ~ 20 AAC 25.005 la. Type of work Drill l~ R~drill OI lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69' , PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0il Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25629 ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.O25) 959'FSL, 315'FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 1621'FSL, 1576'FEL, Sec.1, T12N, R9E, UM 3K-18 #8088-26-27 At total depth 9. Approximate spud date Amount 1146'FSL, 1172'FEL, Sec.1, T12N, RgE, UM 08/24/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 9861 'MD 959' ¢ surface feet 3K-17 25'¢ surface feet 2560 f6842'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 400 feet Maximum hole angles0 0 Maximum surface 2299 psig At total depth O'VD) 3420 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) l'7--1/hllC~-r-,/RIl ~.~-. ¢14~ I_Rr-, RTl~ RlC~I '~R! "~r-,I r-,'7'~1 ! '~OC) I, I 'lr-.tfl e~ A~ I I I HF-F6W ~75 sx Cla~ 6 blend ~-1/2" 7" 26.0~ J-S5 BTC 9827~ ~6~ ~ 9861~ 68~2~ 2OO sx Clas~ G~m~n~mum HF-E6W TOC 5(~0~ abov~ top of KuDaruk 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 Struotur~l Conductor lntorme0iate ProductionAUG .'- 6 1986 Liner Perforation depth: measured AIBB~ 0il & Gas 00ns. t rue ve rt ica I ADohorage 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Timevs depth plot.~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I here. by certify that the foregoing is true and correct to the best of my knowledge Signe ~ ~' Title Regional Drilling Engineer Date ~ 0 I Commission Use Only ( HRE ) PD/PD~05 I I ] See cover letter ~ormit ~um~er ~:~l~l 50-- ~'~-~ ~ I 08/07/86 for other requirements Conditions of approval Samples required ~ Yes ~ ~o Mud ~o~ required ~ Yes ~ ~o Hydrooen sulfi~o measures D Yos ~ ~o Directional survey required ~ Yes D ~o Other: by order of Approved by ~ ~., ~/. ~~~~ Commissioner the commission Dat Form 10-401 Rev.'T2:~-l-~,~ Sub~¢ n triplicate STATE OF ALASKA ALASKA L~iL AND GAS CONSERVATION CO,vIMISSlON PERMIT TO DRILL 20 AAC 25.005 . ,, la. Type of Work Drill ~ R~drill ©1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69' , PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25629 ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 959'FSL, 315'FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit Statewide At top of productive interval 8: Well nu .mber Number 1621'FSL, 1576'FEL, Sec.1, T12N, ROE, UM 3K-18 #8088-26-27 At total depth 9. Approximate spud date Amount l146'FSL, l172'FEL, SEC.1, T12N, ROE, UM 08/24/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth IMD and TVD) property line 9861 'MD 959' ~ surface feet 3K-17 25'(~ surface feet 2560 (6842'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 400 feet Maximum hole angle 50 0 Maximum surface 2299 psig At total depth (TVD) 3420 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 0"" ~" ~'~ 5//' u_,,n ~"~1'~ 801 3:' ~5! 11:' .4c, '""'"' ef ~ · · v v~ . .. , ~ ..v ~ ~ ,.. , , ,.., .,- ~.- v v HF-FI~W _'575 _~x class 6 blend 8-1/2" 7" 26.0# J-55 BTC 9827' 134' 34' 9861' 6R42' 200 .~x £1a.~.~ ¢,(minimHml HF-ERW TOC 5(!0' abov to~ of KuDaruk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface IntermediateAUG ,- 6 1986 Production Liner Alaska Oil & Gas Cons. COITIiirjjSSj02 Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch '~ Diverter Sketch ,~r Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analysis ~ Seabed report [] 20 AAC 25,050 requirements, 21. I here. by certify that the foregoing is true and correct to the best of my knowledge Signe ~ Title Regional Drilling Engineer Date ~ () I Commission Use Only (HRE) PD/PD305 Permit Num~_lS1APl 50-- -21641 [ P6°~10d¢~8 Ap I See cover letter numSe2r9 6 for other requirements Gonditions of approval Samples required ~ Yes '~ No Mud log required E3 Yes ,l~. No Hydrogen sulfide measures [] Yes [] No [~i.rectional survey required ~,L. Yes ~ No Required worki~ssure~for~~M;,,c~3M; Fi 5M; [] 10M; [] i5M Other: ~/~ /~~~ by order of Approved by~,~ '~../, L ~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Sub~ n triplicate PAD'-'~K;::L-~LL~ NO:i~ '1 8 PROPOSED K_I~_.'A_~U_K-/~.-:_F_! EL..P_,?L_ N_OR_rH.L._S_¢O_P[.,_ AL ASKA. EAST/laN UHI.P,$TOCK~ !NC. I v.' oo o .-o . 9 1 $ BUILD 3 DEe ..... P-ER-I O0.-.FT- ................................................... 21 27' 39 45 BASE PERt~AFROST TVD-1721 Tt'lD-,1859 DEPm-53-.t. EOC TVD'1869 THD'2077 DEP'690 I'1'1 --I 6000. 7000. TOP UGNU SNDS TVD-2?04 TND-3383 DEP"1695 TOP ~ SAK SN.DS TVD-3404 TMD-4479 DEP-2538 K? 1 2 TVD-3684 TIID."'4917' DEP-2876 / 9 5/8' CSG PT T V-D~-.T~52~--DEP-~I t-6 ........ AVERAGE ANGLE 50 DEG 18 MI N RECEIVED ,AUG - 6 1986 Alaska .Oil & Gas Cons, Commission K-5' TVD-5779 TND-8197 DEP-5399 T/ ZONE D TVD-6~24 TMD'9050 DEP-6056 T/ ZONE C TVD-6422 TMD-9204 DEP-6174 T/ ZONE A TVD-6589 TMD-9465. DEP-6375' TARGET CNTR TVD-6652 T~D-9564 DEP-6451 B/ KUP SNDS TVD-6714 T~D-9661DEP-6525 TD (LOG PT) TVD-6842 T~D-9861 DEP-6679 I ........ I-'' .......... ............ i ..... i I Anchorage 0 1 000 2000 3000 4000 5000 6000 ?000 VERTICAL SECTION . . . i EAST. HAN W~PSTO~. INC. . . . _ .. 000' 0 1000. 20._00. ' ~0 4000 I ,,. ,1 I J _ · i 1QQQ · ........ ~__ ......... 2000 ---I. ~.~. c) . 3:_. 3000_ . 4000. - . 5000 5000 · ~ .. TARGET CENTER TVD-66~2 TI. ID-95~4~ DEP-64~ SOUTH 4919 EAST 417'3 320' Fg, L · I ~21)' FEL TD L~'FIOI¢~ 11~' F~Lo 1172' FEL SEC. 1'. T1211, Rg~ SEC. I. T12tl. ~ -RECEI-VED .... AUG '--6--1986' · . Alaska Oil & Gas Cons. Commissio,~ - Anchorage ....... 6451 ' (TO TARGET) : ~' RECE '1!' '.' 5.00_ ...... · ............... : ............... . .......... ' ......... ' ...... ' \ '1500 "/"I........ I ~0~3~ ala~lin.Oil & ! ' I Anchorage · · \ ~ - ,0 '- 100- . 200 300' .,.400--: - ..~-500:: ! --' 600~::--i:.;:-i..- ! - ' ' ~ .... - ..... .. -~ ~:'2-:,'.' '"' ."-x-~ 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. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKER,5 ST CLF. ANER TYPICAL HUD SYSTEH SCHEMATIC LWK4 / ih RECEIVED AUG- 6 A{acka Oil & Gas Cons. Commksio:, Anchcrac3e · Density PV YP Viscosity Initial Gel 10 Minute Gel Filtrate API pH % Solids DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 50-100 5-15 15-30 2O 9-10 10_+ Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 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. LWK5/ih RECEIVED AUG- 6 1o,988 CorIliI1,tz~o. Alaska Oil & Gas Cons. ~""~ ~ Anchom~e KUPRRUK R I VER UN I T 20" D I VERTER SCHEMRT I C lc_ DESCRIPTION 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI ORILLING SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES N/10" DIVERTER LINES, A SINQLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE RENOTELY CONTROLLED TO ACHIEVE DONNNINO DIVERSION. $. 20" 2000 PSI ANNULAR PREVENTER. 6 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 03S (b) HRINTENRNCE & OPERATION RECEIVED 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER ANO VERIFY THAT VALVE OPENS PROPERLY. Z. CLOSE RNNULAR PREVENTER AND BLOW A I R THROUGH DI VERTER L I NES EVERY 12 H(X.~S. 3. CLOSE A~AR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBDRE FLUIDS OR GAS IS DETECTEO. OPEN APPROPRIATE VALVE TO ACHIEVE DONNNINO DIVERSION. DO NOT SHUT IN NELL UNDER ANY C I RCUMSTANCES. AUG- 6 188G Alaska 0ii & Gas Cons. Comm!ssion Anchorage S100840~2 RI( i 7 ' > > DIAGPAM ~! 5. l~8' - ~ ~I ~I~I~ ~ W/~ ~ KI~ LI~ 6. 1~8' - ~ ~I ~ ~ W/PI~ ~ ~ ii 4 A~CLI~TC~ CAPACITY TEST I. (I-ECl( ~ FILL AO3JVM. ATCR RF. SE]a~OIR TO LEVEL WITH ~IC FLUID. ~ 9'H~T A~TOR PRI[S,.qI. RI[ IS ~ ~I WI~ 3. ~ TI~, ~ ~ ~ ~TS SIXThlY 4. ~ ~ ~ ~, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ t STACK,TEST I. FILL 843:1 STA(]( AN3 CHOKE lvlANIFOLD WITH ARCTIC DIESS.. (3-[0( THAT ALL LOCK D(]IM~ ~ IN ~).LJ-EAD FLI.LY I:~-TRACTED. SF. AT TEST PLUG IN WITH 1~4JNqINI3 JT AID ~ IN LOCXDOM4 3. Q.CeE ~ PRSVEN11~ Ahl3 ~ KILL Ah~ C1-KI<E Lib[ VALVES ADJACENT TO B(::P STA(:X. ALL OTi-ER 4. i:~ UP TO ~ PS:[ AhO I-K)LD I='CR IO MIN. IN- C~ ~ TO 301:30 PS): Ah~ I-KI.D FC~ lO MIN. BLEED ~SBU4~ TO O PS):. 5. ~ AI~tQJ.AR ~ AhD ~ KILL Ahl3 C:HO<E Lib[ VALVES. (:LOSE TCP PII:~ RAMS AN3 ~ VALVES O4 KZLL AhO (]~]<E LIhF. S. 6. TEST TO 250 PSI AhD 3000 PSI A~ IN STEP 4. 7. CONTINL~ TESTING ALL VALVES, LIhESo AhD C]-K:KES WITH A 2SO PSI LON AhO 34300 PSI HIGH. TEST AS IN STEP 4. DO NOT ~q~al[ TE.qT ANY Q4CI(E THAT ~3T A FULL CLOSING P(~ITI'VE SEAL ~ F1JIk~-TIQN TEST 0"i1~,~ T'I"~T gO ~ FI3.LY CLO~E. 8. CPEN TCP PIPE RAI~ N~D CLOSE ~OTTO~I PIPE RNaS. TEST BOTT(]~I PIPE RNVlS TO 250 PSI N~ ~ PSI. 9. CPEN 80TTCM PIPE RNaS, SAO< ~UT RLI~ING JT 10. CLOSE BLIP) RANIS ~ TEST TO 250 PSI AI~ 5000 PSI. II. CPEN BLIND RNaS A~ RETRIEVE *TEST PLUG. MAKE SURE ~ANIFCI. D A~D LI~E$ ARE FULL CF FLUID. SET ALL VALVES IN CRILLING POSITIC~. 12.' TEST STANDPIPE VALVES, KELLY, KELLY COO<S, CRILL PIPE SAFETY VALVE, AJ~ I~I~E BCP TO 2.50 PSI AJ~D 3CX)O PSI. 13. R~OJtD TEST I~FCIllVlATICl4 (214 BLOWOUT PI:~m/F. NTER TEST FCI4M, SION, AhD SF. N3 TO ~ILLING 14. PF_Rff~ ClJvlaLETE BCI~ TEST AF99~ NIPPLING LI3 V?~B<LY THEREAFTER FIJ4C~ICI4ALLY CI:~RATE BCI=~ DAILY RECEIVED AUG- , i~JOO, Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Nay 7, 1986 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 - 3K Pad {Wells 1 - 18) Dear l,lr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i ii I / i I .... ~.1 ...... il III I _ - ~-I..OCATED IM PROTR&CTED -~--~ 27~, ?..& . p uRvIY ~ · 3 LOCATED IN PROTRACTED ~OCATEO IN PROTRAOTEO SECTION ~5~ T. I~ N.~ R. 9 E.~ U.M. SECTION ~5~ T. I~ N.~ R. 9 E.~U.M. X ' S~,~.ll L~G. 149045'~.9~7. X ' 5~,~S.69 L~. 14~' ~L, 318' ~ ~-~.2 P~- M.6 ~2~' ~, 326' ~ ~-~.8 X - 5~,~.19 LaG. 149'45'~.93~ X - SZe,~S.73 ~. ~49'45'~.9774' I~' ~, 318' ~ ~- ~.S P~- ~.6 11~' ~, 316' ~ ~- ~.0 P~- ~.S X - 5~,~.07 L~G. 149'45'~.~50 X - S~.~.M ~. 149'45'~.~' 13~' ~,317' ~ ~-~.8 P~.5 1~' ~, 316' ~ ~- ~.0 P~- ~.5 6 - Y - 6,~,~3.M ~T. ~'~'01.5~1' 15 - Y - 6,~,0~.63 ~T. 70'25'~.8451' 1~' ~0 317' ~ ~- ~.~ P~- ~.6 10~' ~L, 316' ~ ~- ~.0 P~ 7 - Y - 6,~,~8.M ~T. 700~'01.~' 16 - Y - 6.~,~3.M ~T. 70'~'~.5~' X - 6~,~5.~ * LaG. 149'45'~.~' X - 5~,~5.71 L~G. 149'45'~.9~6' 1~~ ~L, 3~7' ~ ~ - ~.0 P~ - ~.S ~' FSL, 31S' ~ a - ~.0 P~ 8 - Y - 6,~,253.70 ~T. 70'26'01.0~ 17 - Y - 6,~7.978.81 ~T. 70'25'~.3651' X - S~,~S.~ LaG. 149'46'~.9~' X - S~,~5.77 LaG. 1259' ~L, 317' ~ ~- ~.0 P~- ~.5 ~S' FSL, 315' ~ ~- ~.0 P~ e - Y - 6,~,2~.6S ~T. 70'~'~.8124' 18 - Y - 6,~7,963.69 UT. X - S~,~S.9Z L~G. 149'45'~.~' X - 5~.~5.73 LaG. ~2~' FSL, 327' ~ ~ - ~.1 P~ - ~.5 959' FSL, 315' ~ ~ - ~.0 P~ . . NOTES . . .... I. ALL COORDINATES ARE A.S.E~ZONE4. ~ALL DISTANCES SHOWN ARE TRUE. " ~.HORIZONTAL POSITIONS BASED ON ~K CONTROL MONUMENTS PER L~O ~ ASSOC. 4. VERTICAL POSITIONS BASED ON ~K TBM NO. 4 & TBM No. 5 PER LHD & ASSr, 5.O.6, ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-~O?O rev.~ I I I I II I . . CER~FICA~ OF SURVE~R: I HEREBY C~T~ THAT I AM PROPERLY ~i*~ REGISTERED AND LICENSED ~ PRACTIC[ LAND -- SURVEYING IN ~E STATE OF ALASKA ~O THAT ~ ' -- - THI~ PLAT REPRESENTS & LOCATION SURVEY ~.-.. MADE BY ME OR UN~R MY SUPERVISION, AND ~ :- .. :: SURVEYED FOR: J~ ARCO Alosko, Inc. '.; -x '"' ~ & DATE 2 MAY leas ~f KUPARUK PROJECT '; "~ D.~w.~ DRILL SITE 3K CONDUCTOR i ~,~o ~.E.....o~ AS-BUILT LOCATIONS ~ - ...... . ,~..m ~,m ' )IDWG. NO. NSK 86-31 ~ Arct~ ~u/eva~, Sure 201, A~ho~ge, A/aska 99503 llS~LE NOT TO SCALE ~ il~e ~. , I I I I I II I CHECK LIST FOR NEW W~L PERMITS ITEM APPROVE DATE (1) Fee ~/'/~-~----- ~-7~ ~ 1. / (2) Loc ~-~f~hru"t ~- 7-Y L ( 8) (3) Admin (4) Casg ~~.~ g- 7-~'C (14 tl~ru 22) (23 thTM 28) (6) OTHER 7V,~, (29 thru 31) (6) Add: Company ~ YES Is the permit fee attached .......................................... ~ 2. Is well to be. located in a defined pool ............................. · Is well located proper distance from property line .................. 4] Is well located proper distance from other wells ' 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 perm%'t be approved before fifteen-day wait ...................... Lease & Well No. NO Does operator have a bond in force .................................. Is a conservation order needed ............................. ......... administrative approval needed IS eeeeeeeeeeeeeeeeeeeeeeeeeee.eeeeeee Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. Is conductor string provided ..., ..................................... ing Will surface cas protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separationproposed ........... - ................. Isa diverter system required. ...................................... ~ Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached.~ Does BOPEhave sufficient pressure rating - Test to ,~~ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (May 84).; ................ Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. Engige~ring: rev: 07/18/86 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl No special'effort has been made to chronologically organize this category of information, LIS T~P~. V~RiFiC~TION LiSTI~ .VP OlO.HO2 VERIFICATION LISTING PAGE 1 REEL HEADER ~:~ ;ERVICE NAME :EDIT )ATE :25/09/13 JR!GIN : ~E~L NAME :149570 ]ONT!NUaTiON ~ :01 ~REVIOUS REEL : ]~MMENTS :LIER~RY 'T~PE '$~ TA~ HEADER N:::: ~ERVICE NAME :EOIT 3ATE :8~/09/13 ~RZGZN :FSI~ F~PE NAME : ;ONTINUATZON m :01 PREVIOUS TAPE : 'OMMENTS :LIBRARY T~PE: · ,-~"'"-,- FILE Hr'AD =IL~E NAME : S~E'RVICE N~ME D~TE : MAXIMUM LENGTH : 102~ FiLE TYP~ PREVIOUS FiLE MNEM CCJN'T ENTS UNIT TYPE CATE SiZE C~OE CN : ARCO ALASKA, INC. 000 000 0'18 065 WN : 3K-18 000 000 006 065 FN : KUPARUK 000 000 008 065 ~ANG: 9E 000 000 002 065 TOWN: 13N 000 000 004 055 S6CT: 35 000 OOO 002 065 COUN: NORTH SL~P'~ 000 OOO 012 055 STAT: ~L~SK~ 000 000 006 065 ~NE~ CONTENTS UNiT TYP~ CAT~ SIZE CCDE .VP OIO.H02 VERImiC4TIDN LISTING P4GE 2 '- SCH' "' ..... ,-' &LASKA CgM,CUTi. NG CENTER ~:~ 'OMP,~NY : ARCO AL~:SK~. ZNC ~ E L L = 3 K- 18 :iELD : KUPARUK 'OUNTY = NORTH SLOPE ~ ~OROUGH ~'TATE = AL,&SKA JCB NUM~EER AT ACC: 71700 ;,UN ,~ONE, OAT:F LOGGr-D: 07 SEP 85 .DP: T H~LSTE~D 'ASING = 9.525" ~ 5317' - BiT SIZE : 8.5" TC 9843' FYPE FLUID : WEIGHTED E.Z. MUD ],ENSITY : 10.0 LE/G RM : ~+.2'90 @ 65 DF IISCOSI'TY : 44.0 S RMF : 3.440:9 65 OF >~ = ~.5 RNC = 2.580 ~ 65 DF :LUiD LOSS = 4.~ C3 RM AT 5HT = 1.907 2 155 DF ~IATRZ X SANDSTONE ,,..,.-,-., .... THIS O~TA H.~S NOT SmmN OEP'TH SHI~T'ED VERLAY rZmLD PRINTS =~:-,--, .... .VP OlO.H02 VERIFIgATiON LZSTiN8 PaGE 3 ~:: SC~LUMS'~ER., LOGS Z~C~-~UO:D~` WITH THIS MAGN~TTC~ TAP~: ~:: .,-"" DUAL INDUCTI-JN SPhERiCALLY :OCUSED, LOc~ (OTL)~ ~:~ =:~ DATA AVAILABLE: 9836' TO 5317' * .,- FORMATI~N D~NSITY C~MP~NSAT~D LOG (FDN) "' ~:: C~MP~NSATED NEUTRON LOG (FDN) ~ '~: DATA AVAILABLE: '9810' T~ 8900' ~'~ ::: GAMMA RAY IN CASING (GR.CNL) ~:: '" ~ A T _ ' ~: .. .~, .~, AVAILAB:L~: 5317' TO 1000 · ,..,. DATA FORMAT RECORD-,-"-'~'.,. ENTRY BLOCKS TYPE SiZE REPR 'CODE ::NTRY' 2 I 66 0 ¢ I 66 1 :'~ 4 73 60 9 4 65 o I I N 1~ 1 66 1 0 1 66 0 DAT"'~~ ~ ~ u,, SPECIFIrA'TI~N ~LOCKS MNEM SERVICE SERVICE UNIT A°i ~Pi AP1 AP1 FILE SIZE SPL REP~ PROCESS ID OROER ~ LOG TYPE CLASS M~D NO. CODE (OCTAL) gEPT FT O0 000 O0 0 0 4 1 68 OOOO0000000000 SFLU DIL OHMM O0 220 O1 0 0 4 I 68 O00000000OO000 !LD DIL OHMM O0 lgO 46 0 0 4 I 68 00000000000000 ILM DIL CHMM O0 120 44 0 0 4 1 68 00000000000000 SP DIL MY' O0 010 OI 0 0 4 1 68 00000000000000 GR DIL GAPI O0 310 O1 0 0 4 1 68 00000000000000 .VP OiO..HOZ VERIFICATION LISTING PAGE 4 iR FDN GAPi O0 ;AL1 FDN IN O0 SNOB ~F'DN G/C3 O0 )RHO ~DN G/C3 O0 ~RAT FDN O0 ~NRA FDN O0 qPHI FDN PU O0 qCNL FDN CPS O0 :CNL FDN CPS O0 $R CNL GAPI O0 310 280 350 356 420 000 330 3:30 310 O1 O1 O2 Oi 01 O0 O0 31 3O Ol DEPT 9880,5000 SFLU Se -32,2813 GR qMeB 2.4941 DRHO ~PHi 721.0938 NCNL DEPT 9800.0000 SFLU $P -38.3125 GR RHOB 2.45'70 DR~O NPHI 33.6426 NCNL 3EPT 9700.0000 SFLU SP -37.8750 GR RHOB 2.3066 DRHO NPHI 41,4551 NCNL DEPT 9600.0000 SFLU SP -29.8875 GR RHOB 2.3730 DRHO NPHI 32.1777 NCNL DEPT 9500.0000 SFLU SP -65,8125 GR RHD8 2.2715 DRHC NPHI 27.~1~ NCNL DEPT 9~00.0000 SFLU SP -28.7344 GR RHO;5 2.4453 DRHO NPHI 31.2500 NCNL DEPT 9300.0000 S=LU SP -26.'9687 GR RHGB 2.4666 ORHO NP~I 34,6191 NCNL O~PT 9200.0000 SFLU SP -33.8437 GR RHOB 2.8594 DRHO N~HZ 2~.3691 NCNL 3,2335 91,1250 0,0962 1948.0000 3,8586 90.3125 0.0742 2004.0000 3.2893 95.9375 0.0537 t681.0000 6,0327 83,3750 0,0049 2240.0090 35.8989 37.5000 0.0127 2696.0000 5,6188 $1.6875 0.0425 2272,0000 2.6655 108.7500 0.0381 2418.0000 3.2083 131.3'750 0.3232 1960.0000 ILD GR, NRAT FC NL ILD GR NR&T :FC NL ILO GR NR AT FCNL iLD GR NRAT FCNL ILD GR NR.AT FCNL iLD GR NR,~T FCNL ILD GR NRAT FCNL IL'~ NR~T FCNL 2.8,309 95.5625 40.5625 584.5000 3,2608 90.3125 3.1074 599,5000 2.7212 95,9375 3.4863 455,0000 5,2913 83.3750 2.9315 695.0000 24.4934 37,5000 2,5977 990.0000 5.2~09 81.6875 2.8926 747.0000 2.6900 105.7500 3.1445 749.0000 2.8570 131.3750 2.7715 729.0000 i 88 00000000000000 1 68 00000000000000 1 58 00000000000000 1 68 00000000000000 1 58 00000000000000 1 68 00000000000000 i. 58 00000000000000 1 68 00000000000000 i 68 00000000000000 1 65 00000000000000 iLM 2.8773 CALI 9.0938 RNRA 3.3320 GR -999.2500 ILM 3.4037 CALI 10.0859 RNRA 3.3418 GR -999.2500 ILM 2,8171 CA:LI 9,4922 RNR~ 3,6934 GR -999.2500 ILM 5.6048 CALl 9.0547 RNRA 3.2165 GR -999.2500 ILM 35.299'7 CALI 8.8203 RNR; 2.7227 GR -999.2500 ILM 5.2990 CALi 9,3516 RNRA 3.0410 GR -999.2500 ILM 2.7978 C~Li 9.8984 RNRA 3,2265 GR -999,2500 iLM 3.0338 CALi 10.2187 RNR~a 2,6875 GR -999.2500 .VP OiO,H02 VERIFICATION LISTING P,aG5 5 }:EPT 9100.0000 SFLU SP -23.2031 GR qHDB 2.3438 DRH~ NPHI 39.4043 NCNL DEPT 9000,0000 SFLU SP -20,1875 GR RHOB 2,2637 ORHO WPHI 47.8027 NCNL JEPT 8900,0000 SFLU SP -25.8594 GR RHCB 2.3008 DRHO NPHI 46.2891 NCNL D~PT $$00.0000 SFLU SP -22.8281 GR RHO~ -999,2500 DRHO NFHi -999,2500 NCNL DSmT $700,0000 S~LU SP -25,1094 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNL DEPT 8600,0000 S~LU SP '-20.9687 GR RHO$ -999,2500 DRHC NPHi -999,2500 NCNL OEPT 9500.0000 SFLU SP -13,2422 GR RHO~ -999,2500 DRHO NPHi -999,2500 NCNL OEPT 8400,0000 SFLU SP -i9,6094 GR RHDB -999.2500 DRHO NPH=~ -999. 2500 NCNL DSPT 8300,0000 SFLU SP -16.5938 GR RHO6 -999,2500 DRHG NPH~ -999.2500 NCNL OEPT 8200.0000 SFLU SP -15.7188 GR ~HOB -999.2500 DRHO NPHI -999.2500 NCNL S~PT 8100.0000 SFLd SP -15.4609 GR ~OB -999.2500 CRH!2 NPHI -999.2500 NCNL 2.2577 iLD IZl,O000 GR 0.0103 NRAT 1637.0000 FCNL 1.7112 iLD 109.5875 GR 0,0068 NRAT 1553.0000 FCNL 2.0867 ILD 119,2500 GR 0,0161 NR.&T 1639,0000 FCNL 2.7202 ILD 131,3750 GR -999.2500 NRAT -999,2500 FCN:L 2.7884 ILD 173,7500 GR -999,2500 NRAT -999.2500 FCNL 3,5790 iLD 256.0000 GR -999.2500 NRAT -999.2~00 FCNL 1,9576 iLD 146.2500 GR -999,2500 NRAT -999,2500 FCNL 3,0606 ILO 167,5250 GR -999,2500 NRAT -999.2500 FCNL 2.03.83 iLD 103,7500 SR -999.2500 NR.&T -999.2500 ~CNL 3.7795 ILD 96.3125 GR -999.2500 NRAT -999.2500 PCNL 2.6129 ILD 98. 1250 GR - 9 )9.2500 NR,~ T -9~9. 2500 FCNL 1.7633 ILM 121.0000 CALl 3,4707 RNRA ~52,0000 GR 1.7100 ILM 109,6875 CALI 3.8516 RNRA 374,5000 GR 2,0559 ILM 11:9,2500 CALI 3,7656 RNRA 390.0000 GR 2,4087 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 2.5848 iLM -999.2500 CALi -999.2500 RNRA .-999.2500 GR 2.6830 ILM -999,2500 CALI -'999.2500 RNRA -999,2500 GR 2.0229 iLM -999,2500 CALl -999,2500 RNRA -999,2500 GR 2.5194 iLM -999.2500 CALI -999.2500 RNRA -999.2500 GR -9'99.2500 CALI -999,2500 RNRA -999.2500 GR 3.2029 ILM -999.2500 CALI -999.2500 RNRA -999.2309 GR 2.3851 ZLM -999.2300 CALl -9'59.2500 RNR~ -999.2500 GR 1.7793 10.6953 3.621i -999.2500 1.7833 9.7500 4.1445 -999.2500 2,0969 9.6719 4,1992 -999,2500 2.4663 -999,2500 -999.2500 -999.2500 2.6340 -999.2500 -999.2500 -999.2500 2.8209 -999.2500 -999.2500 -999.2500 2.1041 -999.2500 -999.2500 -999.2500 2.6327 -999.2500 -999.2500 -999.2500 1.8658 .-999.2500 -999.2500 -999.2500 3.3152 -999.2500 -999.2500 -999.2500 2.3796 -999.2500 --999.2530 -999.2500 LVP OlO.HO2 VERiFICATiCN LISTING 3EPT 8000.0000 SFLU SP -16.9531 GR RHOB -999.2500 9RHO NPHI -999.2500 NCNL 3EPT 7900.0000 SFLU SP -22.2031 GR RH05 -999,2500 DRHO HPHI -999.2500 NCNL DSPT 7800,00.00 S¢LU SP -23.1'719 GR RHOB -999.2500 DRH; NPHI -999.2500 NCNL DEPT 7700.0000 SFLU SP -28.4688 GR RH05 -999.2500 DRHQ NPHi -999.2500 NCNL DEPT 7600.0000 SFLU SP -19.7969 RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 7500.0000 SFLU SP -28.7031 GR RHO6 -999,2500 DRHO NPHI -999.2500 NCNL 3EPT 7400.0000 SFLU SP -21.5406 GR RH08 -999.2500 DRHO NPHi -999.2500 NCNL DEPT 7300.0000 SFLU SP -22.2655 G'R RH05 -999.2500 DRHO NPHi -999.2500 NCNL DEPT 7200.0000 SFLU SP -23.9531 GR RhOB -999.2500 DRHO NPHI -999.2500 NCNL OEPT 7100.0000 SFLU SP -25.4531 GR RHD5 -999.2500 DRHJ NP~I -999.2500 NCNL DEPT 7000.0000 SnLU SP -32.0525 GR RH08 -999.2500 DRHO 1.8370 ILD 92.1875 GR -999.2500 NRAT -999.2500 FCNL 2.1996 iLO 125 187= GR -999.2500 NRAT -999.2.500 FCNL 2.9503 ILD 116.0625 GR -999.2500 NRAT -999.2500 FCNL 3,3172 ILD 128.0000 GR -999.2500 NRAT -999.2500 FCNL 2.6222 ILC 105.7500 GR -999.2500 NRAT -999.2500 FCNL 3.3 Z 28 I L D 123.2500 GR -999. 2500 NRAT -999.2500 ~CNL 2.7127 iLD 123.8750 GR -999.2500 NRAT -999.2500 FCNL 3.8754 iLO 109.5000 GR -999.2500 NRAT -999.2500 ~CNL 2.~504 ILD 92.8750 GR -999.2500 NRAT -999.2500 FCNL 2.7177 ILD 106.6250 GR -999.2500 NRAT -999.2500 FCNL 2.9081 ILO 110.1250 GR -999.2500 NRAT 1.7458 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2,2151 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3.0198 ! LM -999.2500 CALi -9'99. 2500 RNRA -999.2500 GR 3.1.832 iLM -999.2500 CALI -999.2500 RNRA -999.2500 GR 2.4939 iLM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3.2a2! !LM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.8822 ILM -999.2500 CALi --999.2500 RNRA -999.2500 GR 3.7004 ILM -9'99.2500 CALI -999.2500 RNRA ,-999.2500 GR 2.7903 ILM -999.2500 CALI -999.2500 RNR.& -'9'99.2500 GR 2.7537 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 2.9042 ILM -999.2500 CALl -999.2500 RNRA 1.8004 -999,2500 -999.2500 -999.2500 2.2331 -999.2500 -999.2500 -999.2500 3.049~ -999.2500 -999.2500 -999.2500 3.2311 -999.2500 -999.2500 -999.2500 2.4855 -999.2500 -999.2500 -999.2500 3.2989 -999.2500 -999.2500 -999.2500 2.8890 -999.2500 -999.2500 -999.2300 3.7198 -999.2500 -999.2500 -999.2500 2.8075 -999.2500 -999.2500 -999.2500 2,7536 -999.2500 -999.2500 -999.2500 2.9360 -999.2500 -999.2500 ~VP OIO.HO2 VE~IriCATI~N~~ ~ LISTING PA~'~ '~ ? ~PHI DEPT ~P qPHI DEPT ~PHi DEPT 5P WPHi DEPT SP RHOB 3:PT~. SP ~HDB NPHI DEPT SP RI-JOB NPN! DEPT SP RHOB NPMi OEPT SP RmOB NPHI DEPT SP NPHI DEPT SP -999.250 0 NCNL 6900.0000 SFLU -30,2031 GR -999.2500 ORhO ,-999.2300 NCNL 6800.0000 SFLU -29.828! GR -999.2500 DRHO -999.2500 NCNL 6700.0000 SFLU -29.4531 GR -999.2500 DRHO -999.2500 NCNL 6600.0000 SFLU -25.5155 GR -999.2500 DRHC -999.2500 NCNL 6500.0000 SFLU -35.6875 GR -999.2500 DRHO -999,2500 NCNL 6~00.0000 SFLU -28.8906 GR -999.2500 DRHO -999.2500 NCNL 5300.0000 SFLd -28.0781 GR -999.2500 ORHO -999.2500 NCNL 6200.0000 SFLU -29.1250 GR -999.2500 9RH8 -99'9.2500 NCNL 6100.0000 SFLU -24.3750 GR -999.2500 DRH3 -999.2500 NCNL 6000.0000 S~LU -23.0000 GR -999.2500 DRHO -999.2500 NCNL 5900.0000 SFLU -40.7813 GR -99'9. 2500 FCNL 2.8629 ILD 105.8750 G2 -999.2500 NRAT -999.2500 FCNL 2.8532 ILO 100.3750 GR -999.2500 NRAT -999.2500 FCNL 2.9607 ILO 105.3750 GR -999.2500 NRAT -999.2500 FCNL 2.5245 ILO 90.0625 GR -999.2500 NRAT -999.2500 FCNL 3.3416 ILO 95.4375 GR -999.2500 NRAT -999.2500 FCNL 2.9239 ILD 108.18'75 GR -'999.2500 NRAT -999.2500 FCNL 3.0606 ILO 116.9375 GR -999.2500 NRAT -999.2500 FCNL 3.0911 ILD 106.3750 SR -999.2500 NRAT -999.2~00 FCNL 3.1255 ILO 103.5625 GR -999.2500 NRAT -999.2500 FCNL 2.6941 ILD 7~.3125 GR -999.2500 NRAT -9'99.2500 FCNL 3..08¢6 99.0625 GR -999.2500 GR 2.8141 iLM -999.2500 CALI 999 2500 ~4R -999.2500 GR 2.9330 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 2.9139 iLM -999.2500 CALl --999.2500 RNRA -999.2500 GR 2.6056 ILM -999.2500 CALl -999.2500 RNRA -999.2300 GR 3.9500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.6953 iLM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3.1864 ILM -999.2500 CALl -999.2500 RNR& -999.2300 GR 3.2983 ILM -999.2500 CALl -999.2500 RNRA -9:99.2500 GR 3.2360 ILM -999.2500 CALi -999.2500 RNRA -999.2300 GR 2.8555 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.1337 iLM -999.2500 CALI -999.2500 2.8171 -99'9.2500 -999.2500 -999.2.500 2.91'91 -999.2500 -999.2500 -999.2500 2.9215 -999.2500 -999.2500 -999.2500 2.6399 -999.Z500 -999.Z500 -999.2500 3.8366 -999.2500 -999.2500 -999.2500 2.7191 -999.2500 -999.2500 -999.2500 3.1317 -999.2500 -999.2500 -999.2500 3.2528 -999 · 25 O0 -999.2500 -999.2500 3.1840 -999.2500 -999.2500 -999.2500 2.7956 -999.2500 -999.2500 -999.2500 3.1217 -999.2500 .VP 010.H02 VERIFICATION LISTING PAGE 8 q HD ~,, -999.2500 DRHO ~PHI -999.2500 NCNL 3EPT 5800.0000 SFLU SP -41.4375 GR RHO5 -999.2500 DRHO ~PHZ -999.2500 NCNL DEFT 5700.0000 SFLU SP -27.3594 GR RH05 -999.2500 ORHO XPHI -999.2500 NCNL 3EPT 5600.0000 S~LU SP -27.9219 GR RHO~ --999.2500 DRHO NPHI '-999.2.500 NCNL DEFT 5500.0000 SFLU SP -32.8750 GR RHO6 -999.2500 ORHO NPHI -999.2500 NCNL DEFT 5400.0000 SFLU SP -22.5156 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEFT 5300.0000 SFLU SP 11.5469 GR RHOB -999.2500 9RHQ NPHI -999.2500 NCNL DEPT 52001.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRmO NPHI -999.2500 NCNL DEFT 5100.0000 SFLO SP -999.2300 GR RHO5 -999.2500 DRHD NPHI -999.2500 NCNL DEPT 5000.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO NmHi -999.2500 NC~L OEPT 4900.0000 SFLU SP -999.2500 GR RHOB -999.2.500 DR~S NP~'I -999.2300 NCNL -999.2500 NRAT -999.2500 FCNL 2.3099 ILD 96.2500 GR -'999.2500 NRAT -999.2500 FCNL 1.6256 iLO 9~.!875 GR -999.2500 NR4T -999.2500 FCNL 1.9676 83.1875 GR -999.2500 NRAT -999.2500 FCNL 2.6~53 ILO a3.5000 GR -999.2500 NRAT -999. 2500 FCNL 2.9167 ILQ 77.8750 GR -999.2500 NRAT -999.2500 FCNL 2000.0000 iLO 56.0623 GR -999.2:500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 iLO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 -999.2500 -999.2500 N2AT -999.2500 FCNL -999.2500 RNRa -999.2500 GR 1.2525 !LM -999.2500 C~Li -999.2500 RNRA -999.2500 GR 2.2056 ILM -999.2500 CALl -999.2500 RNa& -999.2300 GR 3.0482 !LM -999.2300 CALl -999.2500 RNR4 -999.2500 GR 3.3289 iLM -999.2300 C4LI -999.2500 RNRA -999.2500 GR 3.1990 ILM -999.2500 CALl · -999.2500 RNRA -999.2500 GR 11.6596 ILM -999.21500 CALI -999.2500 RNR~ -999.2500 GR -999. 2500 !LM -'999. 2500 CALl -999.2500 RNRA ,-999.2500 GR -999.2500 ILM -999.2.500 C~LI -999.2500 RN~A -999.2500 GR -999.2500 ILM -999.2500 C~Li -999.2500 RN~ -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 ~NR4 -999.2500 GR -999.2500 -999.2500 1.1804 .-999.2500 -999.2500 -999.2500 2.1592 -999.2500 .-999.2500 -999.2500 3.0244 -999.2500 -999.2500 -999.2500 3.1849 -999.2500 -999.2500 -999.2500 3.1391 -999.2500 -999.2500 -999.2500 2000.0000 -999.2500 .-999.2500 60.4375 -999.2500 -999.2500 -999.2500 37.4688 -999.2500 -999.2500 -999.2500 46.0938 -999.2500 -999. 2500 -999.2500 56.4375 -999.2500 -999.2500 -999.2500 58.5938 OEPT 4800.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 VP 010 HO~ V~RiF!C&TICN L~$TiNG ~ iP -999.2500 GR ~:~0'5 -999.2500 DRH~3 ~PHI -999.2300 NCNL )EPT 4700.0000 SFLU gp -999.2500 GR ~H3S -999.2500 gRffi3 ~PM! -999.2500 NCNL )EPT 4600.0000 SFLU gP -999.2300 GR ~HO~, -999.2500 DRHO JPHI -999.2500 NCNL )EPT ~300.0000 SFLU DP -999.2500 GR IHOB -999.2900 DRH3 ~PHI -:999.2500 NCNL )EPT 4400.0000 SFLU . ~p -999.2500 GR ~MGB -999.2500 D'RH~ ~PHI -999.2500 NC~L )EPT 4300,0000 SFLU ~P -999.2500 GR ~H05 -999.2500 3RH~ qPHI '-999.2500 NCNL 3EPT z, 200.0000 SFLU SP -999,2300 GR ~HO~ -999.2500 DRHO ~PHI -999,2500 NCNL 3E~T 4100.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO ~PHI .-999.2500 NCNL DEPT 4000.0000 SFLU SP -999.2500 GR RhOB -999.2300 DRHD NPMI -9'99,2300 NCNL 3;mT,., .~'~900. 0000 SFLU SP -99'9.2500 SR RHu~~' -999.2500 nRH~:.,. ,.~ NPHZ -999.2500 NCNL DEPT 3800.0000 SFLU SP -999.2500 GR ~H05 -999.2500 DRHO NPHI -999.2500 NCNL -99'9.25.00 GR -999,2500 NRAT -999.2500 FCNL -999.2500 -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 iLD -999.2500 SR -9~9.2500 NRAT -999.2500 FCNL -999,2500 iLO -999.2500 GR -999.2500 NRAT .-999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NR4T -999.2500 FCNL -999.2500 iLD -999.2500 GR -999.2500 NR&T -999.2500 ~CNL -999.2500 ILD -999.2500 GR -999.2500 NR4T -999.2500 FCNL -999,21500 iLD -999.2500 GR -9'99,2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2300 GR -999.2500 NR'AT -999.2300 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999..2500 ILD -~9.2500 GR -999.Z500 NRAT -99'9.2500 FCNL -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILM -999,2500 CALl -999,2500 RNRA -999,2500 GR -999,2500 iLM -999-2500 CALl -99,9.2500 RNRA -999.2500 GR -999.2500 !LM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 iLM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 iLM -999,2500 CALl -999,2300 RNRA -999,2500 GR -999.2500 ILM -999.2500 CALl --999.2500 RNRA -999.2500 GR -999,2500 !LM -999,2500 CALi -999,2500 RNRA -999,2500 GR -999.2500 ILM -999.2500 C~LI -99'9,2500 RNRA -999.2500 GR -999.2500 -999.2500 48.5313 -999,2500 -999.2500 -999,2500 39,1875 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 41.8125 -999.2500 -999.2500 -999.2500 29.92.19 -999.2500 -999.2500 -999.2500 52.5938 -999.2500 -999.2500 -999.2500 49.6250 -999.2500 -999,2500 -999.2500 26.3750 -999.2500 -999.2500 -999.2500 30.9531 -999.2500 -999.2500 -999.2500 44.9375 -999.2500 -999.2500 -999.2500 52.46~8 LVP 010.H02 VERiFIC4TION LISTING PAGE i0 OEFT SP NPHi 3EPT SP NPHI DEPT SP NPHI OEPT SP RH08 NPH! DEPT SP RHOB S? RHO5 NPHI DE PT SP NPHi- D:PT SP NPHI DEPT SP RHO& NPHI 05PT SP RHO5 NPHI DEPT SP NPHI 3700.0000 SFLU -999,2500 GR -999.2500 ORHO -999.2500 NCNL 3600.0000 SFLU -999.2500 GR -999,2500 DRH9 -999,2500 NCNL 3500.0000 SFLU -999,2500 GR -999.2500 DRHO -999.2500 NCNL 3400,0000 SFLU -999,2500 GR -999,2500 DRHO -999.2500 NCNL 3300,0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 NCNL 3200,0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 NCNL 3100,0000 SFLU -999,2500 GR -999,2500 DRHO -999.2500 NCNL 3000,0000 SFLU -999,2500 GR -999,2500 ORHS -999.2500 NCNL 2900,0000 SFLU -999.2500 GR -999.2500 DRH3 -999,2500 NCNL 2800,0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 NCNL 2700.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL -999,2500 ILO -999,2500 GR -999.2500 NRAT -999,2500 FCNL -999.2500 iLD '-999,2500 GR -9'99,2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO --999.2500 GR .-999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999,2500 GR -999.2500 NR&'T -999,2500 FCNL .-999,2500 iLO -999.2500 GR -999.2500 NRAT -999,2500 FCNL -999,2500 IL~ -999,2500 GR -999,2500 NRAT -999,2500 FCNL -999.2500 iLO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999,£500 ILO -999,2500 GR -999.2500 NRAT -999,2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2300 FCNL -999.2500 iLD -999,2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILM -999.2500 CALI -999.2500 RNR4 -999.2500 GR -999..2500 ILM -999.2500 CALi -999,2500 RNRA -999.2500 GR -999,2500 iLM -999.2500 CALl -99.9.2500 RNRA -999,2500 GR -999,2500 ILM -999.2300 CALI -999.2500 RNRA '-999.2500 GR -999.2500 ILM -999.2500 C&LI -999.2500 RNRA -999.2500 GR -999,2500 iLM -9'99.2500 C4Li -999.2500 RNRA -999,2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999,2500 ILM -999,2500 CA~Li -999.2500 RNRA -999.2:500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 iLM -999.2500 CALI -999.2500 RNR4 -999.2500 Gq -999.2500 iLM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 -999.2500 -999.2500 50.0625 -999.2500 -999.2500 -999,2500 26.0938 -999,2500 -999,2500 -999,2500 .31,8563 -999.2500 -999.2500 -999,2500 41.1250 -999.2500 -999.2500 -999.2500 52.9687 -999. 2500 -999,2500 -999.2500 54,3750 -999.2500 -999,2500 -999,2500 38.2500 -999.2500 -999.2500 -999.2500 39.6250 -999.2500 -999.2500 -999.2500 43.~688 -99'9.2500 -999.2500 -999.2500 39.5625 -999.2500 -999.2500 -999.2500 39.5000 .VP OlO,H02 VERIFICATION LISTING PAGE I1 )EPT ;P ~H05 ~PH l )E PT ;P ~HOB iPHi )EPT ;P ~PHZ )EFT ;P ~HOB )EPT ~P ~H05 )EPT ~P ~PHI 3EFT ~P :~HOB '~PHi DEPT Se EH06 NPHI SP RHO6 NPHi DEPT SP EH05 NPHI O E PT SP RHOB 2600,0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 NCNL 2500,0000 SFLU -999,2500 G2 -999.2500 DRHO -999.2500 NCNL 2400,0000 SFLU -999,2500 GR -999,2500 DR~O -'9'99.2500 NCNL 2300,0000 SFLU -9:99.2500 Gq -999.2500 ORHO -999,2500 NCNL 2200,0000 SFLU -999,2500 GR -999,2500 DRH9 -999,2500 NCNL 2100.0000 SFLU -999,2500 G2 -999,2500 DRHO -999.2500 NCNL 2000,0000 SFLU -999,2500 GR -999.2500 DRHO -999.2500 NCNL 1900,0000 SFLU -999,2500 GR -999,2500 ORHO -999,250'0 NCNL 1800.0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 NCNL 1700.0000 SFLU -999,2500 GR 999.:2500 DRH~ -999.2500 NCNL 1500,0000 SFLO -999,2500 GR -999,2500 ORH3 -999,2500 ILD -999,2500 GR -999,2500 NRAT -999.2500 FCNL -999.2500 !LD -999,2500 GR -999,2500 NEAT -9'99,2500 FCNL -999.2500 iLD -999.2500 GR -999.2500 NEAT -999.2500 ~CNL -999,2500 iLD -999.2500 GR -999,2500 NR&T -999,2500 FCNL -'999.2500 ILO -99'9.2500 GR -999,2500 NRAT -9~9.2500 FCNL -999,2500 iLD -999,2500 GR -999,2500 NR&T -9~9,2500 . 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