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188-041
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-12 KUPARUK RIV UNIT 3O-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-12 50-029-21804-00-00 188-041-0 W SPT 6321 1880410 1580 2900 2900 2900 2900 80 80 80 80 4YRTST P Adam Earl 6/24/2025 MIT-IA 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 3O-12 Inspection Date: Tubing OA Packer Depth 605 2015 1955 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625083026 BBL Pumped:1.3 BBL Returned:1.1 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor b(kl'U'Z FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 30-12 KUPARUK RIV UNIT 30-12 See: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RN UNIT 30.12 API Well Number 50-029-21804-00-00 Inspector Name: Adam Earl Permit Number: 188-041-0 Inspection Date: 6/3/2021 Insp Num: mitAGE210607105219 Rei Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-12 -Type Inj w' -,TVD 6321 Tubing 2900 2800. 2800 " 2800 " PTD 1880410 Type Test SPT Test psi 1580 IA 670 2010 1950 1940 " BBL Pumped: I BBL Returned: I OA 100 100 Interval 4YRTST p/F P Notes: MIT IA - Tuesday, June 8, 2021 Pagc 1 ut I STATE OF ALASKA AL(A OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing Li Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 'erforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: WINJ to WAG III 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory 0 188-041 3.Address: P. 0. Box 100360,Anchorage,Alaska Stratigraphic❑ Service Q 6.API Number: 99510 50-029-21804-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 30-12 ADL025513 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,005 feet Plugs measured None feet true vertical 6,956 feet Junk measured None feet Effective Depth measured 6,875 feet Packer measured 6364 feet true vertical 6,827 feet true vertical 6321 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74 16 110 110 RECEIVED Surface 4,071 12 4,106 4100 Intermediate Production 6,924 7 6,957 6909 JAN 0 3 2018 Liner 517 6 6,876 6827 (�(� Perforation depth Measured depth 6611-6732 feet A®((��v1 C C True Vertical depth 6566-6686 feet Tubing(size,grade,measured and true vertical depth) 3.5 L-80 6363 6320 Packers and SSSV(type,measured and true vertical depth) TRDP-BAKER'FVLD' @ 1784 MD and 1784 TV 0 0 SSSV @ 1803 MD and 1804 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN J. 7 2018 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1427 418 3868 Subsequent to operation: 3868 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development 0 Service J Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil [] Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-568 Contact Name: Ethan Plunkett Authorized Name:Ethan Plunkett Contact Email: Ethan.T.PIunkett@conocophiiiips.com Authorized Title: Petroleum Engineer Authorized Signature: Date: t7j-O Z- Zo I$ Contact Phone: (907)263-4280 ,F1 yells' Form 10-404 Revised 4/2017 // FiEE,' 3 Lt,:,',:; - U i'J Submit Original Only • • ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 January 2, 2018 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 30-12 (PTD# 188-041). If you have any questions regarding this matter, please contact me at 907-263-4280. Sincerely, Ethan Plunkett Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed Schematic 1 • 30-12 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/30/17 Convert well from WINJ to WAG service. KUP INJ 30-12 ConocoPhillips O° Well Attributes Max Angle&MD TD Ala'Na.Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) mrbccvruxr. 500292180400 KUPARUK RIVER UNIT INJ 14.21 5,300.00 7,005.0 ... ° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 30-12,11/16/2015 6558:05 PM SSSV:TRDP 90 5/6/2015 Last WO: 11/22/2014 40.00 6/3/1988 Vertical schematic(actual) Annotation Depth)ftKB) End Date Annotation Last Mod By End Date _Last Tag:SLM 6.690.0 1/29/2015 Rev Reason:WAIVERED CANCELLED pproven 11/16/2015 HANGER;33.0 IVO Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ii CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 WELDED !] . Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ` I.. SURFACE 95/8 8.921 35.0 4,105.7 4,100.1 36.00 J-55 BTC W,Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...I Wt/Len(I...Grade Top Thread MOM r. s PRODUCTION 7 6.276 33.0 6,957.1 6,908.6 26.00 J-55 BTC . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...I Wt/Len(I...Grade Top Thread LINER 41/2 4.000 6,359.3 6,876.0 6,828.2 11.60 L-80 BTCM CONDUCTOR;36.0410.0 ` Liner Details Nominal ID Top)ftKB) Top(ND)(ftKB) Top Ind(°) Item Des Com (in) SAFETY VLV;1,803.8 fit j 6,359.3 In � 6,316.6 9.18 PACKER BAKER 2RH ZXP w/HD LINER TOP PACKER 5.020 IF 6,378.7 6,335.8 9.07 HANGER BAKER FLEX-LOCK LINER HANGER 4.220 A. 6,388.1 6,345.1 9.01 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT;2,496.6 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection • TUBING-WO 31/2 2.992 33.0 6,393.2 6,350.1 9.30 L-80 EUE 8rd • Completion Details Nominal ID GAS LIFT;3,717.0 Top(RKB) Top(ND)(ftKB) Top Incl E) Item Des Com lin) 33.0 33.0 0.14 HANGER McEVOY GEN IV TUBING HANGER 2.950 1,803.8 1,803.8 0.35 SAFETY VLV TRMAXX-CMT-5-SR SCSSSV 2.812 6,310.2 6,268.2 9.47 NIPPLE '"X'NIPPLE 2.813 6,362.5 6,319.8 9.16 LOCATOR 80-40 GBH-22 LOCATOR(bottom of locator space Out 7') 3.000 SURFACE;350-4,105.7 + 6,363.7 6,320.9 9.16 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.980 • GAS LIFT;4.603.0 it Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top)TVD) Top Incl Top(ftKB) (ftKB) 7) Des Corn Run Date ID(in) 6,625.0 6,579.5 7.93 WHIPSTOCK BAKER 3.5"x4.5"THRU-TUBING,ORIENTED S 2/3/2015 0.000 DEG ROHS. GAS LIFT;5,334.6 I Perforations&Slots Shot Dens Top)TVD) Btm(ND) )shotsft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 1) Type Com 6,611.0 6,621.0 6,565.6 6,575.5 C-1,30-12 3/27/1989 12.0 IPERF 60 deg.phasing;2 1/8" GAS LIFT;5,883.8 EnerJet[SQZ'D] 6,661.0 6,671.0 6,615.1 6,625.0 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, _. Powerjet HSD[OPEN] 6,661.0 6,671.0 6,615.1 6,625.0 A-3,30-12 '3/27/1989 12.0 (PERF 60 deg.phasing;2 1/8" GAS LIFT;6,250.3 EnerJet[OPEN] 6,676.0 6,695.0 6,630.0 6,648.8 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, Powerjet HSD[OPEN] 6,676.0 6,700.0 6,630.0 6,653.8 A-2,30-12 3/26/1989 12.0 (PERF 60 deg.phasing;2 1/8" NIPPLE;6,310.2 IEnerJet[SQZ.D] 6,695.0 6,700.0 6,648.8 6,653.8 A-1,30-12 2/1/2015 6.0 RPERF 60 deg phasing,2.5" Millenium II[OPEN] 6,712.0 6,732.0 6,665.7 6,685.5 A-1,30-12 6/26/1988 8.0 APERF 45 deg.phasing;41/2" HSD Csg Gun[SQZ'D] LOCATOR;6,362.5 Mandrel Inserts St SEAL ASSY;6,363.63 ah i7;::= i' onTop(TVD) Valve Latch Port Size TRO Run I N To (ftKB) (ftKB) Make Model OD)in) Sery Type Type Top( (in) (psi) Run Date Com 'I` 2,496.6 2,496.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/12/2015 2 3,717.0 3,712.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK � 0.000 0.0 10/13/2015 3 4,603.0 4,595.8 CAMCO MMG 1 1/2 GAS LIFT 'DMY RK ' 0.000 0.0 10/13/2015 • 4 5,334.6 5,308.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 (PERF;6,611.0-6,621.0-j. 5 5,883.8 5,848.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 6 6,250.3 6,209.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 OCR- WHIPSTOCK;6.625.0- WINDOW;6,628.0-6,636.0 Notes:General&Safety (PERF;6,661.0.6,677.0 End Date Annotation RPERF;6,661.0-6,671.0 - 3/20/2015 NOTE:ADD LATERALS Li(off main wellbore),L1-01 RPERF;6,676.0-6,695.0 IPERF;6,676.0-6.700,0 K' ' l'1 RPERF;6,695.0.6,700.0- - t..I APERF;6,712.0.6,732.0- Fl • :1 • • LINER;6,359.2-6,876.0 r. PRODUCTION;33.0.6,957.1 4 • pro /B8 - 4-I Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,January 03, 2018 11:05 AM To: 'Plunkett, Ethan T' Subject: RE: [EXTERNAL]RE:ConocoPhillips KRU 30-12 WAG vs.WINJa That will work- From: Plunkett, Ethan T[mailto:Ethan.T.Plunkett@conocophillips.com] Sent:Tuesday,January 02,2018 2:50 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Haggerty-Sherrod,Ann(Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: RE: [EXTERNAL]RE: ConocoPhillips KRU 30-12 WAG vs.WINJ Good morning Victoria, We conducted the WAG on the 30-12 last week to gas. I'm sending over the 10-404 but this will have the same sundry number as the previously submitted 10-403. 30-12 (188-041) 30-12L1 (215-003) 30-12L1-01 (215-047) Will this create an issue? SCOL Thanks, Ethan Ethan Plunkett I 3NIMROQ-Senior Drilisite Petroleum Engineer I ConocoPhillips Alaska I GKA Base I 0: (907)263-4280 C: (918)812-2284 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, December 20,2017 9:50 AM To: Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.com> Subject: RE: [EXTERNAL]RE:ConocoPhillips KRU 30-12 WAG vs.WINJ You may submit the 10-404 now to correct the status to WAG. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 1 . • S Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, December 20,2017 9:50 AM To: 'Plunkett, Ethan T' Subject: RE: [EXTERNAL]RE:ConocoPhillips KRU 30-12 WAG vs.WIN) 1 You may submit the 10-404 now to correct the status to WAG. u Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission SCOW* 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Plunkett, Ethan T[mailto:Ethan.T.Plunkett@conocophillips.com] Sent:Tuesday, December 19,2017 4:02 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE:ConocoPhillips KRU 30-12 WAG vs.WINJ Just to confirm:We will conduct the WIN)to WAG and then submit the 10-404 to WAG after the work has been completed? Thanks for the help, Ethan From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,December 19,2017 11:50 AM To: Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.com> Subject: [EXTERNAL]RE: ConocoPhillips KRU 30-12 WAG vs.WINJ Ethan, They are currently listed as WINJ. Please submit 10-404 for each of them listed as WAG. Thanx, Victoria PTD JAB- a41 • ,,TL From: Plunkett, Ethan T[mailto:Ethan.T.Plunkett@conocophillips.com] Sent: Monday, December 18, 2017 2:02 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:ConocoPhillips KRU 30-12 WAG vs.WINJ Good afternoon Victoria, I recently transitioned into Yemeli Gozon's vacated role under Michael Braun as petroleum engineer for Kuparuk drillsites 3N,31,3M,3R,30 and 3Q. We are working to find more lean gas injection wells on the north side of Kuparuk. I noticed for 30-12 that we have the 10-403 and 10-407 listed as WAG, but the filed 10-404 were mistakenly filed as WINJ. The wells in question are: 30-12 (188-041) 30-1211 (215-003) 30-1211-01 (215-047) My question is that are these wells considered WAG or WINJ in AOGCC's opinion? If they are considered WINJ, is it possible to file a 10-404 to WAG? Thanks for your help, Ethan Plunkett Ethan Plunkett 13NIMROQ-Senior Drillsite Petroleum Engineer 1 ConocoPhillips Alaska 1 GKA Base 1 0: (907)263-4280 C: (918)812-2284 2 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim Regg r SUBJECT: Mechanical Integrity Tests P.I.Supervisor Q� Ifo ('� l� CONOCOPHILLIPS ALASKA INC 30-12 FROM: Lou Laubenstein KUPARUK RIV UNIT 30-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .1 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-12 API Well Number 50-029-21804-00-00 Inspector Name: Lou Laubenstein Permit Number: 188-041-0 Inspection Date: 6/6/2017 Insp Num: mitLOL170607160037 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-12 - Type Inj ®TVD 6321 Tubing 2800 2800 - 2800 - 2800 . PTD 1880410 - Type Test SPT Test psi 1580 - IA 710 1910 - 1860 - 1850 - BBL Pumped: 1.2 - BBL Returned: 1.1 OA I 360 420 - 420 ' 420 - Interval 4YRTST P/F P Notes: S`pNNED SEP 0 5 2017 Thursday,June 15,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I DATE: Tuesday,November 03,2015 P.I.Supervisor --2L,.'G 11(271 it SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-12 FROM: Bob Noble KUPARUK RIV UNIT 30-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv, NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-12 API Well Number 50-029-21804-00-00 Inspector Name: Bob Noble Permit Number: 188-041-0 Inspection Date: 11/1/2015 Insp Num: mitRCN151101154041 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------ ---------- Well 30-12 - Type Inj W• TVD 6321 • i Tubing 1710 - 1710 . ! 1710 - 1710 PTD 1880410 " Type Test SPT Test psi 3100 _ IA 800 3400 - 3310 - 3305 Interval REQVAR PAF P „I OA 490 695 - 680 690 Notes: Required by variance to test to max.anticipated injection pressure. zS.4-7)17 SCANNED SEP 16 2016; Tuesday,November 03,2015 Page 1 of 1 STATE OF ALASKA • lIKLASKA OIL AND GAS CONSERVATION MMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Rall Tubing r Operations shutdown r Performed: Suspend r Perforate r Other StimulateAlter Casing r r Change Approved Program Rug for Redrill r Perforate New Pool rRepair Well r Re-enter Susp Well r Other: Prod to WINJFi 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 188-041 3.Address: 6.API Number: Stratigraphic r Service r P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21804-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025513 KRU 30-12 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7005 feet Plugs(measured) None true vertical 6956 feet Junk(measured) None Effective Depth measured 6875 feet Packer(measured) 6364 true vertical 6827 feet (true vertical) 6321 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 4071 12 4106 4100 LINER 517 5.96 6876 6827 PRODUCTION 6924 7 6957 6909 RECEIVED OCT 27 2015 Perforation depth: Measured depth: 6611-6732 �gNEL3p� True Vertical Depth: 6566-6686 � � AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80,6363 MD,6320 TVD Packers&SSSV(type, MD,and TVD) SEAL ASSY-80-40 GBH-22 SEAL ASSEMBLY @ 6364 MD and 6321 TVD TRDP-BAKER'FVLD'@ 1784 MD and 1784 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 _ 0 0 1050 0 Subsequent to operation 2777 338 640 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service 1 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ P WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-568 Contact Darrell Humphrey/Bob Christensen Email n1139@conocophillips.com Printed Name Robert D Christensen Title NSK Production Engineering Specialist Signature Phone:659-7535 Date /® /C— 2 lvrL /&,/27 1/2. - d* V47//3---- RBDMS4IT 2 7 2015 Form 10-404 Revised 5/2015 Submit Original Only a 30-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/12/15 BRUSH n' FLUSH TBG TO 6400' SLM, SET 2.81 XX PLUG &GAUGES @ 6310' RKB, SET 3 1/2 AVA STYLE CATCHER ON PLUG @ SAME, PULLED OV @ 6250' RKB, PULLED GLV @ 2496' RKB SET DV @ SAME, PULLED GLV's @ 3717', 4603', 5334' &5883' RKB. 10/13/15 SET DV's @ 3717', 4603', 5334', & 5883' RKB, LOAD TBG & IA W/INHIBITED SEAWATER W/DSL (U-TUBE) FREEZE PROTECT. SET DV @ 6250' RKB. MITIA(PASS). 10/14/15 PULLED AVA CATCHER &2.81"XX PLUG W/GAUGES @ 6310' RKB. 10/20/15 Well opened to water only injection service • KUP PROD11. 30-12 rConocoPhillips - Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Ilncl 7) MD(ftKB) Act Btm(ftKB) .,,,,,,,.:',,phi' xi. 500292180400 KUPARUK RIVER UNIT PROD 14.21 5,300.00 7,005.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-12,10/15/2015 325:02 PM SSSV:TRDP 90 5/6/2015 Last WO: 11/22/2014 40.00 6/3/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _......._.._ .........._...... ..__...... ._..._._._Last Tag:SLM 6,690.0 1/29/2015 Rev Reason:GLV C/O lehallf 10/15/2015 HANGER;33.0 I1,'- '�Y w Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread 1 CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 WELDED kr Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread SURFACE 95/8 8.921 35.0 4,105.7 4,100.1 36.00 J-55 BTC m,Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Thr 6"....,..1,PRODUCTION 7 6.276 33.0 6,957.1 6,908.6 26.00 J-55 BTC Casing Description OD(In) 'ID(in) Top(ftKB) Set Depth(61(8) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 4.000 6,359.3 6,876.0 6,828.2 11.60 L-80 BTCM CONDUCTOR;36.0410.0 ' Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Cam (in) SAFETY VLV;1,803.8 M 6,359.3 6,316.6 9.18 PACKER BAKER 2RH ZXP w/HD LINER TOP PACKER 5.020 6,378.7 6,335.8 9.07 HANGER BAKER FLEX-LOCK LINER HANGER 4.220 6,388.1 6,345.1 9.01 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT;2,496.6 Tubing Strings 1111 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING-WO 3 1/2 2.992 310 6,393.2 6,350.1 9.30 L-80 EUE Srd III Completion Details Nominal ID GAS LIFT;3,717.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) r 1 33.0 33.0 0.14 HANGER McEVOY GEN IV TUBING HANGER 2.950 1,803.8 1,803.8 0.35 SAFETY VLV TRMAXX-CMT-5-SR SCSSSV 2.812 6,310.2 6,268.2 9.47 NIPPLE "X'NIPPLE 2.813 6,362.5 6,319.8 9.16 LOCATOR 80-40 GBH-22 LOCATOR(bottom of locator space out 7') 3.000 SURFACE;35,0.4,105.7-+ 6,363.7 6,320.9 9.16 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.980 GAS LIFT;4,603.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°I Des Corn Run Date ID(in) 6.625 0 6.579.5 7.93 WHIPSTOCK BAKER 3.5"x 4.5"THRU-TUBING,ORIENTED 5 2/3/2015 0.000 DEG ROHS. GAS LIFT;5,334.6 Perforations&Slots Shot Den Top(ND) Btm(TVD) (shots/f Top(6158) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,611.0 6,621.0 6,565.6 6,575.5 C-1,30-12 3/27/1989 12.0 (PERF 60 deg.phasing;2 1/8" GAS LIFT;5,883.8 EnerJet[SQZ'D] 6,661.0 6,671.0 6,615.1 6,625.0 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, Powerjet HSD[OPEN] 6,661.0 6,671.0 6,615.1 6,625.0 A-3,30-12 3/27/1989 12.0 (PERF 60 deg.phasing;2 1/8" GAS LIFT;6,2502 ii i EnerJet[OPEN] 6,676.0 6,695.0 6,630.0 6,648.8 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, Powerjet HSD[OPEN] 6,676.0 6,700.0 6,630.0 6,653.8 A-2,30-12 3/26/1989 12.0 IPERF 60 deg.phasing;2 1/8" NIPPLE;6,3102 i EnerJet[SQZ'D] 6,695.0 6,700.0 6,648.8 6,653.8 A-1,30-12 2/1/2015 6.0 RPERF 60 deg phasing,2.5" Millenium II[OPEN] 6,712.0 6,732.0 6,665.7 6,685.5 A-1,30-12 6/26/1988 8.0 APERF 45 deg.phasing;41/2" HSD Csg Gun[SQTD] LOCATOR;6,3625Mandrel Inserts St SEAL 5557;6,363.6 'W 4" ah 1' on Top(ND) Valve Latch Part Size TRO Run N Top(ftKB) (61KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,496.6 2,496.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/12/2015 2 3,717.0 3,712.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 • 3 4,603.0 4,595.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 4 5,334.6 5,308.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 IPERF;6,611.0-6,621.0- 5 5,883.8 5,848.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 • • 6 6,250.3 6,209.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/13/2015 OCR- WHIPSTOCK;6,625.0- 1 WINDOW;6,628.0-6,636.0 Notes:General&Safety RPERF;fi,661.0-6,671.0 End Date Annotation IPERF;8,881.0-fi,671.0� 4/5/2008 NOTE:WAIVERED WELL,TBG X IA COMM MI CYCLES LIMITED TO MAXIMUM OF 12 WEEKS 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 RPERF;6,676.0$695.0 g IPERF;6,676.0-6,700.0 RX ' dQ J RPERF;6,695.0-6,700.0- i5 a APERF;6,712.0-6,732.0- .it l • . ''. • LINER;6,3592.6,876.0k t I PRODUCTION;33.0-6,957.1 ,t OF T�� • • THE STATE Alaska Oil and Gas -s A of Conservation CommissioLAsIKA n 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 �� www.aogcc.alaska.gov SCOW DEC 1 Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-12 Sundry Number: 315-568 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair 22015 DATED this /0/1/'- y of September, 2015 RBDMS4 SEP i Encl. RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMMI N SEP 1 6 015 APPLICATION FOR SUNDRY APPROVALS 09 5 9/leks 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations (— Fracture Stimulate r Pull Tubing r Operations shutdown 1.— Suspend Suspend r Perforate r Other Stimulate r Atter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Prod to WAG 57 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 17, 188-041 , 3.Address: Stratigraphic r Service r 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21804-00 ' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 7 KRU 30-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513 Kuparuk River Field/Kuparuk River Oil Pool• 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7005 6956 6875' 6827' None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110' 110' SURFACE 4071 12 4106' 4100' LINER 517 5.96 6876' 6827' PRODUCTION 6924 7 6957' 6909' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): ' 6611-6621,6661-6671,6676-6700,6712-6732 6565-6575,6615-6625,6630-6654,6666-6685 3.5 L-80 6363 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-"X'NIPPLE MD=6310 TVD=6268 • LOCATOR-80-40 GBH-22 LOCATOR(BOTTOM OF LOCATOR SF MD=6363 TVD=6320 , SEAL ASSY-80-40 GBH-22 SEAL ASSEMBLY MD=6364 TVD=6321 , WHIPSTOCK-BAKER 3.5"X 4.5"THRU-TUBING,ORIENTED 5 DE MD=6625 TVD=6579 , TRDP-BAKER'FVLD' MD=1784 TVD=1784 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17- 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/30/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG F F. GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey/Bob Christensen Email: n1139 anconocoohillios.com Printed Na Darrell Humphrey Title: NSK Production Engineering Specialist Signature - "LA y� Phone:659-7535 Date of, t 1.4 . /5 A Commission Use Only Sundry Number: �/ Conditions of approval: Notify Commission so that a representative may witness - Irj-'S(D o Plug Integrity r BOP Test I. Mechanical Integrity Test tg Location Clearance r p� c- nn Other: IA1C.v � 1t1 0 PYiS t 0 be I✓� G«,C G'`J CC" i ►1lo 6 2'J,17 .. ,./--,ft. h, fr f_557-G/ /T- /i4- re 1_4-1r-rc/ a F-ft _5'7''' b,7,'3,,,4 ,nj�c1ze..,, Spacing Exception Required? Yes❑ No Subsequent Form Required: 1 f — 4a4 APPROVED BY / Approved by: ' 11-e..4.3 cit."-- COMMISSIONER THE COMMISSION Date:g/g '! 5 Form 10-403 Revised 5/2015 AppUKVp \vHH o12 monthtrAtye d to of approval. DIA RBbn-Littp•rlaild 2015 11,110uptafe VVrG g/t7/!5- C.-')i".) 7//67,2_0/3' • • 30-12 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips requests to convert 30-12 ( PTD 188-041) and it's associated laterals 30-12L1 and 30-12L1- 01 (PTD 215-003,215-047) from oil production to WAG injection service. 30-12 was completed in May of 1988 as a WAG injector, sundry 314-543 10/9/14 approved it for workover as a WAG injector and the 2 laterals were approved for WAG injection 1/13/15. The laterals were completed 3/13/15 were brought on oil production 4/20/15 and have been on production since then. Sundry notifications were submitted 5/17/15 changing the status to oil and pre-produce for greater than 30 days. Converting well 30-12 and it's associated laterals to injection will provide support to the Kuparuk producers 30-08 and 30-13 in the A-Sand patterns. An AOR was completed on the PTD's. Quarter Mile Injection Review(for injection wells only) There are no wells within %4-mile of the 30-12L1 & 30-12L1-0lwell plans. 30-12 (mother bore) Injector • Completed with 7", 26#, J-55 casing on 6/03/1988. • Classified as a "Normal Well"with a recent Rig Work-Over • C-sand perforations: 6611'-6621' MD (behind scab liner and cemented). •A-sand perforations: 6636'-6640' MD, 6661'-6671' MD, 6676'-6700' MD and 6712'-6732' MD (behind scab liner and cemented). • During the Dec. 2014 work over, a variance was granted for setting the packer over 200' away from the uppermost A-sand perforation. Packer is located at 6359' MD. •The cement bond log shows adequate cement as per original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. The 16" Conductor was cemented with 175sx of AS I. The 9.265" Surface casing was cemented with 1500sx AS III, 300sx Class G, 150sx AS I. 7" Production casing was cemented with 360sx Class G, 175sx AS I. �t �czys�r Cort�¢�r� � t-e// d5 c7c 7o (7//,t2vea& Serv, 6P- N 0 resp t,es n I77/.) • • From PTD application 30-12L1 & 30-12L1-01 (approved 1/13/15 215-003, 215-047) 15.Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance,,'' 30-12L1 3,397' 30-12L1-01 3,397' — Distance to Nearest Well within Pool Late l Name 131stance•k;;•241001 30-12L1 1,445' 30-11 30-12L1-01 1,445' 30-11 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There are no wells within '/4-mile of the 30-12L1 & 30-12L1-0lwell plans. 30-12 (mother bore) Injector • Completed with 7", 26#, J-55 casing on 6/03/1988. • Classified as a "Normal Well"with a recent Rig Work-Over • C-sand perforations: 6611'-6621' MD (behind scab liner and cemented). • A-sand perforations: 6636'-6640' MD, 6661'-6671' MD, 6676'-6700' MD and 6712'- 6732' MD (behind scab liner and cemented). • Plan to re-perforate the A-sand perforations pre-rig before drilling the 30-12L1 & 30- 12L1-01 laterals. • During the Dec. 2014 work over, a variance was granted for setting the packer over 200' away from the uppermost A-sand perforation. Packer is located at 6359' MD. The cement bond log shows adequate cement as per original injection order. The proposed kick-off point for the CTD sidetrack is in the A-sand perfs and should not compromise existing conformance. • • • O`act o o� o MIIIIIIIMPaga1W'::",,,:t.k 30-09 30-121:11111117_,.. O • 3();\ Q(bti m ;, O rn �� 0, O .10 a Pi wf :i7e Vie, il 4. I ConocoPhillips Legend Alaska,Inc. * Well Surface Location Pad Mean Center Injection Swap Analysis 1/4 Mile Radius 30-12, 30-12L1, 30-12L1-01 30-12 N 30-12L1n 0 0.25 0s 30-12L1-01 /`\V Miles 1H-041mjSwap.mxd CSR 5/8/2015 KUP PROD • 30-12 ConocoPhillips OA Well Attributes Max Angle&MD TD Alaska,In.: Wellbore API/UWI Field Name Wellbore Status Incl 0) MD(ftKB) Act Btir(ftKB) canocoahtnpe 500292180400 KUPARUK RIVER UNIT PROD 14.21 5,300.00 7,005.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-12,9(14/2015 4 47'20 PM SSSV:TRDP Last WO: 11/22/2014 40.00 6/3/1988 Vertcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .. ......... _...__ .._._.. ....._...Last Tag:SLM 6,690.0 1/29/2015 Rev Reason'CEMENT QC smsmith 9/14/2015 HANGER;33.0 Ir_UI Casing Strings Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 WELDED 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I SURFACE 95/8 8.921 35.0 4,105.7 4,100.1 36.00 J-55 BTC , ..�,spry Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �V r .n.t.m PRODUCTION 7 6.276 33.0 6,957.1 6,908.6 26.00 J-55 BTC IIIIIICasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 4.000 6,359.3 6,876.0 6,828.2 11.60 L-80 BTCM CONDUCTOR;36.0-110.0 ' Liner Details ini Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SAFETYVLV;1.803.8 -!t' 6,359.3 6,316.6 9.18 PACKER BAKER 2RH ZXP w/HD LINER TOP PACKER 5.020 6,378.7 6,335.8 9.07 HANGER BAKER FLEX-LOCK LINER HANGER 4.220 6,388.1 6,345.1 9.01 SBE BAKER 80-40 SEAL BORE EXTENSION 4000 GAS LIFT;2,496.6 Tubing Strings Tubing Description String Ma...10(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Iblft) Grade Top Connection TUBING-WO 3 1/2 2.992 33.0 6,393.2 6.350.1 9.30 L-80 EUE 8rd Completion Details Nominal ID GAS LIFT;3717.0 - Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 33.0 33.0 0.14 HANGER McEVOY GEN IV TUBING HANGER 2.950 1,803.8 1,803.8 0.35 SAFETYVLV i TRMAXX-CMT-5-SRSCSSSV 2.812 6,310.2 6,268.2 9.47 NIPPLE "X'NIPPLE 2.813 I- 6,362.5 6,319.8 9.16 LOCATOR -80-40 GBH-22 LOCATOR(bottom of locator space out 7') 3.000 SURFACE;35.0-4,105.7-4. - 6,363.7 6,320.9 9.16 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.980 GAS LIFT;4,603.0-1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 6,625.0 6,579.5 7.93 WHIPSTOCK BAKER 3.510 4.5"THRU-TUBING,ORIENTED 5 2/3/2015 0.000 DEG ROHS. GAS LIFT;5,334.8 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,611.0 6,621.0 6,565.6 6,575.5 C-1,30-12 3/27/1989 12.0 IPERF l 60 deg.phasing;2 1/8" GAS LIFT;5,883.8 EnerJet 6,661.0 6,671.0 6,615.1 6,625.0 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, Powerjet HSD 6,661.0 6,671.0 6,615.1 6,625.0 A-3,30-12 3/27/1989 12.0 IPERF 60 deg.phasing;2 1/8" GAS LIFT;6,250.3 c EnerJet 6,676.0 6,695.0 6,630.0 6,648.8 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, Powerjet HSD 6,676.0 6,700.0 6,630.0 6,653.8 A-2,30-12 3/26/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet NIPPLE;6,310.2 1111 6,695.0 6,700.0 6,648.8 6,653.8 A-1,30-12 2/1/2015 6.0 RPERF 60 deg phasing,2.5" Millenium II iWii6,712.0 6,732.0 6,665.7 6,685.5 A-1,30-12 6/26/1988 8.0 APERF 45 deg.phasing;4 1/2" HSD Csg Gun LOCATOR;6,362.5 Mandrel Inserts ;�;,... St SEAL ASSY;6,363.6 �! ati )i; = ; on Top(ND) Valve Latch Port Size TRO Run 2; ; N Top MOB) (ftKB) Make Model OD(In) Sery Type Type (In) (psi) Run Date Com r 1 2,496.6 2,496.3 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,330.0 4/4/2015 2 3,717.0 3,712.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,313.0 4/4/2015 3 4,603.0 4,595.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,298.0 4/4/2015 • 4 5,334.6 5,308.7 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,282.0 4/4/2015 5 5,883.8 5,848.7 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,267.0 4/4/2015 6 6,250.3 6,209.1 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 4/3/2015 OCR- IPERF;6,611.0-6,621.0- j Notes:General&Safety End Date Annotation • 4/5/2008 NOTE. WAIVERED WELL,TBG X IA COMM MI CYCLES LIMITED TO MAXIMUM OF 12 WEEKS WHIPSTOCK;6,625.0- WINDOW;6,828.0-8,636.0 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 IPERF6,661.0-6,671.0 - RPERF;6,661.0-6,871.0 RPERF;6,676.0-6,695.0 IPERF;6,676.0-6,700.0�. RPERF;6,695.0-6,700.0- , . APERF;6,712.0-6,732.0-1 h a i' 1 ■. • LINER;6,359.2-6,876.0 if PRODUCTION;33.0-8,907.1 - w . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ivii3SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed' Suspend r Perforate r Other Stimulate #-- Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool (" Repair Well r Re-enter Susp Well ( ' Other:WAG to Prod (� 2.Operator Name: 4.Well Class Before Work 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development j"'" Exploratory r _ _ 188-041-00 3.Address: 6.API Number: Stratigraphic r Service J P. 0. Box 100360,Anchorage,Alaska 99510 50-029-21804-00 7 Property Designation(Lease Number) 8 Well Name and Number: ADL 25513 KRU 30-12 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7005 feet Plugs(measured) none true vertical 6956 feet Junk(measured) none Effective Depth measured 6875 feet Packer(measured) 6310, 6363, 6364, 6625 true vertical 6827 feet (true vertical) 6268,6320, 6321, 6579 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 0 0 SURFACE 4071 12 4106 4100 0 0 LINER 517 5 96 6876 6827 0 0 PRODUCTION 6924 7 6957 6909 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 6611-6621,6661-6671,6676-6700,6712-6732RECEIVED True Vertical Depth: 6565-6575,6615-6625,6630-6654,6666-6685 MAY 19 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 6393 MD, 6350 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-"X' NIPPLE @ 6310 MD and 6268 TVD AOGCC LOCATOR-80-40 GBH-22 LOCATOR(BOTTOM OF LOCATOR SPACE OUT 7')@ 6363 MD and 6320 TVD SEAL ASSY-80-40 GBH-22 SEAL ASSEMBLY @ 6364 MD and 6321 TVD WHIPSTOCK-BAKER 3.5"X 4.5"THRU-TUBING,ORIENTED 5 DEG ROHS.@ 6625 MD and 6579 TVD TRDP-BAKER'FVLD'@ 1804 MD and 1804 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCONE) f 2015 13. Representative Daily Average Production or Injection Data U 1 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 317 419 2746 1313 154 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Darrell Humphrey/Bob Christensen Email n1139@conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature ,1 Phone 659-7535 Date „�-td►"n� s', /7. 5 Form 10-404 Revised 5/2015 _ �. Sub i Original Only 1,11— s/z�/ /5 f, ,5 RBDMS MAY 2 9 2015 30-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/20/15 Pre produced WAG injector brought online, production to be for greater than 30 days 04/04/15 PULLED DV'S & SET GLV'S @ 5883', 5334', 4603', 3717', &2496' RKB; PULLED CATCHER &2.81" XX PLUG W/GAUGES @ 6310' RKB. JOB COMPLETE. SBHP OF 3597 PSI MEASURED. KUP INJ 30-12 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status Incl(.) MD(ftKB) Act Btm(ftKB) ,,,,,,4,,, ,,,,,, 500292180400 KUPARUK RIVER UNIT INJ + 14.21 5,300.00 7,005.0 ... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 30.12.41520151;17;35 PM SSSV:TRDP Last WO: 11/22/2014 40.00 6/3/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - -- - -----Last Tag:SLM 6,690.0 1292015 Rev Reason:GLV C/O hipshkf 4/5/2015 HANGER;33.0 I FII-JI Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread --- SURFACE 95/8 8.921 35.0 4,105.7 4,100.1 36.00 J-55 BTC -- - ras,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ''PRODUCTION 7 6.276 33.0 6,957.1 6,908.6 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR;36.0-110.0 I LINER 41/2 4.000 6,359.3 6,876.0 6,828.2 11.60 L-80 BTCM Liner Details Nom inal ID SAFETY VLV;1,803.8 Top(ftKB) Top(ND)(MB) Top Incl(') Item Des Com )ie) 6,359.3 6,316.6 9.18 PACKER BAKER 2RH ZXP w/HD LINER TOP PACKER 5.020 6,378.7 6,335.8 9.07 HANGER BAKER FLEX-LOCK LINER HANGER 4.220 6,388.1 6,345.1 9.01 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT:2,496.6 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Iblft) Grade Top Connection • TUBING-WO 3 12 2.992 33.0 6,393.2 6,350.1 9.30 L-80 EUE 8rd Completion Details GAS UFT;3,717.0 Nominal ID Top(ftKB) Top(ND))ftKB) Top Incl)3 Item Des Com _ (in) 33.0 33.0 0.14 HANGER McEVOY GEN IV TUBING HANGER 2.950 1,803.8' 1,803.8' 0.35 SAFETY VLV TRMAXX-CMT-5-SR SCSSSV 2.812 6,310.2 6,268.2 9.47 NIPPLE "X'NIPPLE ' 2.813 SURFACE;35.0.4,105.7-a s 6,362.5' 6,319.8' 9.16 LOCATOR 80-40 GBH-22 LOCATOR(bottom of locator space out 7') 3.000 GAS LIFT;4,603.0 6,363.7 6,320.9 9.16 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.980 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date 10(in) • 6,625.0 6,579.5 7.93 WHIPSTOCK BAKER 3.5"x 4.5"THRU-TUBING,ORIENTED 5 2/3/2015 0.000 GAS LIFT;5,334.6 DEG ROHS. Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotslf GAS LIFT;5,683.8 Top(ftKB) Btm(ftKB) (ttKB) (ftKB) Zone Date t) Type Com 6,611.0 . 6,621.0 6,565.6 6,575.5 327/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet 6,661.0 6,671.0 6,615.1 6,625.0 A-1,30-12 22/2015 6.0 RPERF '60 deg phasing, GAS LIFT;6,250.3 i Powerjet HSD 6,661.0 6,671.0 6,615.1 6,625.0 A-3,30-12 3/27/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet 6,676.0 6,695.0 6,630.0 6,648.8 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, NIPPLE;6,3102473 Powerjet HSD 6,676.0 6,700.0 6,630.0 6,653.8 326/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet iii 6,695.0 6,700.0 6,648.8 6,653.8 A-1,30-12 2/1/2015 6.0 RPERF 60 deg phasing,2.5" Millenium II LOCATOR;6,362.5 6,712.0 6,732.0' 6,665.7 6,685.5 A-1,30-12 6/26/1988 8.0 APERF '45 deg.phasing;41/2" HSD Csg Gun SEAL ASSY;6,363.6 I Mandrel Inserts a st � ati on Top(TVD) Valve Latch Port Size TRO Run N Top(CKB) (flKB) Make Model OD(in) Sery Type Type (ie) (psi) Run Date Com 2,496.6 2,496.3 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,330.0 4/4/2015 2 3,717.0 3,712.5 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,313.0 4/4/2015 3 4,603.0 4,595.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,298.0 4/4/2015 __ 4 5,334.6 5,308.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,282.0 4/4/2015 IPERF;6,611.0-6,621.0- _ 5 5,883.8 5,848.7 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,267.0 4/4/2015 6 6,250.3 6,209.1 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 4/3/2015 DCR- 1 Notes:General&Safety End Date Annotation 4/5/2008 NOTE:WAIVERED WELL,TBG X IA COMM MI CYCLES LIMITED TO MAXIMUM OF 12 WEEKS WHIPSTOCK:6,625.0 WINDOW;6.629.06.636.0 Ik. 3/20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 I_ _I IPERF;6,661.06,671.0 4 RPERF;6,661.0-6,671.01-. RPERF;6,676.0.6,695.0 s b. s� IPERF;6,676.0-6,700.0. It.II RPERF;6,695.48,700.0 :I A _ APERF;6,712.0-6,732.0- II, U I Li Li LINER;6,359.2-6,876.0 ' PRODUCTION;33.0-6,957.11 SLOTS;6.630.4-7,578.8 - LINER L1-01;6.620.2-9,101.01 STATE OF ALASKA AL-.__.A OIL AND GAS CONSERVATION COM. 310N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed: Abandon r Repair well r Plug Perforations r Perforate r Other r Aker Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188-041 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21804-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 KRU 30-12 9.Logs(List logs and submit electronic and printed data per 20AAC25 071). 10.Field/Pool(s): GR/CCL Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7005 feet Plugs(measured) none true vertical 6956 feet Junk(measured) none Effective Depth measured 6875 feet Packer(measured) 6359 true vertical 6827 feet (true vertical) 6317 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 4071 9.625 4106 4100 LINER 517 4.5 6876 6827 PRODUCTION 6924 7 6957 6909 E0 NN D scow a p P 0 2 2015 Perforation depth: Measured depth: perfs cemented off CTrue Vertical Depth: pens cemented off • r, C C Tubing(size,grade,MD,and ND) 3.5, L-80,6393 MD,6350 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 2RH ZXP PACKER @ 6359 MD and 6317 ND SSSV-TRMAXX-CMT-5-SR SCSSSV @ 1804 MD and 1804 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r7 Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG P, GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-004 Contact Ron Phillips @ 265-6312 Email Ron.L.Phillips@conocophillips.com Printed Name Ron Phillips ,, Title CTD Engineer Signature 7- Phillip �� 1 " Phone:265-6312 Date n/I,s ✓ it2 1 41/6/) J/ J) 7 RBDMSJ APR - 7 2015 y/3/,— Form 10-404 Revised 10/2012 Submit Original Only KUP INJ 30-12 ConocoPhillips °- Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cvro[riaompc 500292180400 KUPARUK RIVER UNIT INJ 14.21 5,300.00 7,005.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30.12,3/25/201512.00:48 PM SSSV:TRDP Last WO: 11/22/2014 40.00 6/3/1988 Vertical schematic(actual) - Annotation Depth(MB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,690.0 1/29/2015 Rev Reason:ADD LATERALS L1,L1-01 smsmith 3/20/2015 HANGER 330 Ik1/11 Casing Strings _, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..,Grade Top Thread CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H-40 WELDED - Casing Description OD(in) 'ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 4,105.7 4,100.1 36.00 J-55 BTC '--"" u6duA FRAN4M1 a.,Casing Description OD(in) -ID (in) Top(ftKB) Set Depth Set Depth(,90)...WULenJ-55 Top Thread ''-""� '�"A�"`~PRODUCTION 7, 6.276 33.0 6,957.1 6,908.6 26.00 J-55 BTC - Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g,..Grade Top Thread CONDUCTOR;36.0.110.0 i LINER 41/2 4.000 6,359.3 6,876.0 6,828.2 11.60 L-80 BTCM Liner Details Nominal ID SAFETY VLV;1,803.8 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 6,359.3 6,316.6 9.18 PACKER BAKER 2RH ZXP w/HD LINER TOP PACKER 5.020 GAS LIFT;2,496.8 6,378.7 6,335.8 9.07 HANGER BAKER FLEX-LOCK LINER HANGER 4.220 6,3881 6,345.1 9.01 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description I String Ma...I ID(in) 'Top(ftKB) I Set Depth(ft...I Set Depth(TVD)(...I Wt(lb/ft) 'Grade 'Top Connection TUBING-WO 3 1/2 2.992 33.0 6,393 2 6,350.1 9.30 L-80 EUE Brd CI Completion Details GAS LIFT;3,717.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 33.0 33.0• 0.14 HANGER McEVOY GEN IV TUBING HANGER 2.950 1,803.8 1,803.8- 0.35 SAFETY VLV TRMAXX-CMT-5-SR SCSSSV 2.812 6,310.2 6,268.2 9.47 NIPPLE "X'NIPPLE 2.813 SURFACE;35.0.4,105.7 6,362.5 6,319.8 9.16 LOCATOR 80-40 GBH-22 LOCATOR(bottom of locator space out 7') 3.000 GAS LIFT;4,603.0-1r - 6,363.7 6,320.9 I 9.16 SEAL ASSY 80-40 GBH-22 SEAL ASSEMBLY 2.980 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 6,625.0 6,579.5 7.93 WHIPSTOCK BAKER 3.5"x 4.5"THRU-TUBING,ORIENTED 5 2/3/2015 0.000 GAS LIFT;5,334.6 DEG ROHS. Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotsff GAS LIFT;5,883.8 Top(ftKB) Btm(ftKB) (8KB) (ftKB) Zone Date t) Type Com 6,611.0 6,621.0 6,565.6 6,575.5 3/27/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet 6,661.0 6,671.0 6,615.1 6,625.0 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, GAS LIFT;6,250.3 Powerjet HSD 6,661.0 6,671.0 6,615.1 6,625.0 A-3,30-12 3/27/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet 6,676.0 6,695.0 6,630.0 6,648.8 A-1,30-12 2/2/2015 6.0 RPERF 60 deg phasing, NIPPLE,6,310.z Paweriet HSD 6,676.0 6,700.0 6,630.0 6,653.8 3/26/1989 12.0 (PERF 60 deg.phasing;2 1/8" EnerJet 6,695.0 6,700.0 6,648.8 6,653.8 A-1,30-12 2/1/2015 6.0 RPERF 60 deg phasing,2.5" Mi)lenium II LOCATOR;6,362.5 6,712.0 6,732.0 6,665.7 6,685.5 A-1,30-12 6/26/1988 8.0 APERF 45 deg.phasing;4 1/2" HSD Csg Gun SEAL ASSY;6,363.6 Ma nd re I Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (8KB) Make Model 00(In) Sere Type Type (in) (psi) Run Date Com 1 2,496.6 2,496.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/1/2014 2 3,717.0 3,712.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/1/2014 3 4,603.0 4,595.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/1/2014 4 5,334.6 5,308.7 CAMCO MMG 1 1/2'GAS LIFT DMY RK 0.000 0.0 12/1/2014 !PERF;6,611.0-6,621.0 _ 5 5,883.8 5,848.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/1/2014 6• 6,250.3 6,209.1 CAMCO MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 1/20/2015 DCR- Notes:General&Safety End Date Annotation 4/5/2008 NOTE: WAIVERED WELL,TBG X IA COMM MI CYCLES LIMITED TO MAXIMUM OF 12 WEEKS WHIPSTOCK;6,625.0 WINDOW;6,628.0-6,636.0 6' W20/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 'PERF;6,661.0-6,671.0 RPERF;6,661.0-8,671.0 RPERF;6,676.0-6,695.0, (PERF;6,676.0-6,700.0 RPERF;6,695.0-6,700.0 APERF;6,712.0-6,732.0 I ! 4I I LINER;6,3592-6,876.0 PRODUCTION;33.0-6,957.1 .1.1L- SLOTS;6,630.4-7,578.8 (- LINER L1-01;6,6202-9,101.01 30-12 PRE-RIG WELL WORK DATE SUMMARY 1/20/2015 GAUGED TBG WITH 2.60" CENT; TAGGED @ 6570'SLM. SET CATCHER. PULLED SOV&SET DV @ 6250' RKB. MIT IA 2500 PSI, GOOD. PULLED CATCHER. COMPLETE. 1/22/2015 RIH TAG @ 6637' CTMD, START JETTING DOWN AT 10 FT MIN AT 1.8 BPM, MADE IT TO 6658' CTMD. HARD TAG MADE NO HOLE, CAME OUT OF HOLE RESTART IN MORNING ****JOB IN PROGRESS**** 1/23/2015 RIH WITH 2.80" 3 BLADE JUNK MILL, TAG @ 6677'CTMD MILLED FOR 3 HRS MADE NO HOLE, POOH CHANGE OUT MILLS, RIH WITH 2.80" DIAMOND PARABOLIC TAG @ 6682', MADE IT TO 6687'CALLED TOWN FOR PLAN FORWARD. ****RESTART IN THE MORNING**** 1/24/2015 THREE VENTURI RUNS, GETTING BACK METAL CHUNKS, RUBBER ELEMENTS, WOOD SCREWS, SET SCREWS, MISC. PIECES OF METAL PICS IN WELLVIEW ****JOB IN PROGRESS**** 1/25/2015 TWO VENTURI RUNS, CAME BACK WITH FULL BASKETS BOTH TIMES, ESTIMATED 15 LBS OF METAL, 3'OF HOLE,TAG @ 6689' CTMD WELL READY FOR SLICK LINE 1/29/2015 TAGGED @ 6690' SLM, EST. 6705' RKB. DRIFTED TBG WITH WHIPSTOCK DUMMY TO BOTTOM. IN PROGRESS. 2/1/2015 LOG GR/CCL CORRELATION PASS AND FOUND TOP OF FILL AT 6710'. PERFORATE INTERVAL 6695'-6700' USING 2.5" HSC LOADED 6 SPF, PHASED 60 DEG, 11.1 GR MILLENIUM II HMX CHARGES. LOG CORRELATED TO SLB CEMENT BOND LOG DATED 17 JUN 1988 AT K1 AND HRZ MARKERS. JOB IN PROGRESS. 2/2/2015 PERFORATED FROM 6676'-6695'AND FROM 6661'-6671'WITH 2.5" POWERJET HSD 6 SPF 60 DEG PHASING CHARGES. JOB IN PROGRESS. 2/3/2015 PUMP 270 BBLS DIESEL DOWN TBG TO ESTABLISH AN INJECTION RATE OF 3.5 BPM AT 2900 PSI (JOB COMPLETE) 2/3/2015 SET BAKER 3.5"x4.5"THRU-TUBING WHIPSTOCK. TOP OF WHIPSTOCK AT 6625' RKB. SET 5 DEG ROHS. CCL TO TOP OF WHIPSTOCK= 15'. CCL STOP DEPTH 6610'. TWO PIP TAGS INSTALLED IN WHIPSTOCK AT 7632.35' RKB. JOB COMPLETE 2/9/2015 MEASURED BHP @ 6620' RKB; PERFORMED CLOSURE TESTED SSSV( PASS) ASSIST VLV CREW IN SETTING 2-WAY CHECK FOR DHD/RIG. JOB COMPLETE. 2/9/2015 (PRE-CTD): (WC): POSITIVE TREE VALVE TESTS: MV(PASSED), SSV(PASSED), SV(PASSED) DDT'S MV(PASSED), SSV(PASSED), SV(PASSED) STATE OF ALASKA AL A OIL AND GAS CONSERVATION COM, .SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed. Abandon r Repair w ell rJ Rug Perforations r Perforate Other Scab Liner Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188-041 3.Address: 6 API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21804-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 _ KRU 30-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CCL/GR Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7005 feet Plugs(measured) none true vertical 6956 feet Junk(measured) none Effective Depth measured 6875 feet Packer(measured) 6359 true vertical 6827 feet (true vertical) 6316 Casing Length Size MD ND Burst Collapse CONDUCTOR 74 16 110 110 SURFACE 4071 9.625 4106 4100 LINER 517 4.5 6876 6827 PRODUCTION 6924 7 6957 6909 RECEIVED JAN 022015 Perforation depth: Measured depth. perfs cemented off SCANNED I LL •6 y► LU.,„ q cGCC True Vertical Depth. A Tubing(size,grade,MD,and TVD) 3.5, L-80, 6393 MD,6350 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 2RH ZXP LINER TOP PACKER @ 6359 MD and 6316 TVD SSSV-TRMAXX SSSV @ 1804 MD and 1804 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured). 6861'MD Treatment descriptions including volumes used and final pressure: 18 bbls Class G 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation _ shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service P Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 314-543 Contact Diana Guzman Email Diana.Guzmant conocophillips.com Printed Name Diana Guzman( _ Title Sr. Wells Engineer Signature���[�,"w ( v i zA ve..au Phone:265-6318 Date It/Si /Iy Ir iVJ{l��''���� y'Tl- //9/�1 SS- Form 10-404 Revised 10/2012 Sub ' riginal Only RSDMS JAN - 4 2015 30-12 PRE-RIG WELL WORK DATE SUMMARY 10/12/2014 (PRE RWO) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, MIT- OA PASSED TO 1800 PSI, MIT-IA PASSED TO 3000 PSI, FUNCTION TESTED T LDS (ALL GOOD). 10/18/2014 TAG FILL @ 6688' SLM & MEASURE BHP @ 6696' RKB (3953 PSI) 10/27/2014 PULLED DV @ 6388' RKB. LRS ON LOCATION BULL HEADING SW DOWN IA&TBG. READY FOR BPV. 11/16/2014 (SEC) : T/I/O = BPV/1275/2. IA FL @ surface. OA FL near surface. No wellhouse, scaffold, flowline or SSV panel. Time Log & Summary ConocoPhillips Wellview Web Reporting Report Well Name: 30-12 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/23/2014 1:30:00 AM Rig Release: 12/2/2014 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/22/2014 24 hr summary Move rig from 1A pad to 30-12 00:00 08:30 8.50 MIRU MOVE MOB T Load auxiliary equipment out to 30 pad. Wait on authorization to move rig during phase conditions. Blower and grader in front of rig. Scratching slight grade at 1 A entrance. 08:30 00:00 15.50 MIRU MOVE MOB P Begin moving rig to 3 0-pad. Estimated travel time 12-14 hours. Rig on location 11/23/2014 Move onto 30 pad. Hang tree in cellar. Spot rig over well. Rig accepted at 01:30. Berm up cellar,spot auxillar equipment. Hook up hardline, take on KWF. R/U and lubricate BPV. Kill well with 11.8 ppg KWF. Monitor well, slight vac. Set BPV. N/D tree, N/U BOPE and test. Rig accepted at 01:30 00:00 01:00 1.00 MIRU MOVE MOB P Hang tree in cellar. 01:00 01:30 0.50 MIRU MOVE MOB P Spot rig over well. Rig accepted at 01:30. 01:30 03:15 1.75 MIRU MOVE RURD P Berm up cellar, spot auxiliary equipment. 03:15 04:15 1.00 MIRU MOVE RURD P Load KWF. R/U lines to kill well. 04:15 04:45 0.50 MIRU MOVE SFTY P Pre-Spud Meeting 04:45 06:00 1.25 MIRU MOVE RURD P Continue taking on KWF-hook up hardline 06:00 08:30 2.50 MIRU WELCTt MPSP P R/U lubricator, test to 2500 psi and pull BPV. 08:30 09:30 1.00 MIRU WELCTt SFTY P Pre-spud meeting&PJSM-killing well using 11.8 KWF reconditioned flo-pro with 2%friction reducer. Current well pressures: SITP 1475 psi, IA 1200, OA=0 09:30 12:00 2.50 MIRU WELCTt KLWL P Test hard line to 2500 psi-bleed gas cap off well. Proceed with well kill. Attempt to bleed of gas cap- stablize @ 990 psi. Begin kill pumping down tubing @ 3bpm. ICP- 1590 psi/IA 1250 psi. FCP-840 psi/IA 90 psi Good 11.8 KWF to surface. Strap tanks. Pumped 291 bbls/returns 279 bbls 12:00 12:45 0.75 MIRU WELCTt OWFF P Monitor well for 30 minutes-good -well on light vac, then static. Blow down all hard lines. 12:45 16:15 3.50 MIRU WHDBO RURD P PJSM-dry rod BPV, ND tree and lines. Inspect hngr threads-good. Page 1 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 19:15 3.00 MIRU WHDBO NUND P NUBOPE 19:15 20:30 1.25 MIRU WHDBO RURD P R/U to test BOPE's. Shell test- Blind ram doors leaking. Tighten blind ram doors. Shell test-no leaks observed. 20:30 23:30 3.00 MIRU WHDBO BOPE T Test BOPE's 250/4000 psi except annular 250/3500 psi. Test waived by Chuck Sheave via email 11/22 1. Blind rams, Kill 13, Lower TD, 3-1/2"IF Dart, Choke 4, 11, 12.- LPR doors leaking. Tighten. LPR doors still leaking. Suck out stack, change out door seal. Fill stack. 23:30 00:00 0.50 MIRU WHDBO BOPE P Test BOPE's 250/4000 psi except annular 250/3500 psi. Test waived by Chuck Sheave via email 11/22 1. Blind rams; Kill 13, Lower TD; 3-1/2"IF Dart;Choke 4, 11, 12- Pass 11/24/2014 Continue testing BOPE's. Pull BPV. M/U landing joing, BOLDS. Attempt to pull decompletion free from seals. Unable to pull seals free. Circulate hole volume at 6 bpm 1300 psi. Spot and R/U E-Line. RIH with 1-11/16"RCT cutter and coorelate. Cut tubing at 6,415'. POOH with E-Line, hang up at SSSV. Stage rig pumps up to 6 bpm to open SSSV and allow E-line to pass. Stand back E-Line. Pull hanger to the floor with 74K. R/U Camco, pump SSSV open. L/D Hanger. Circulate hole volume 5 bpm 1100 psi. 00:00 06:30 6.50 0 0 MIRU WHDBO BOPE P Cont.Test BOPE's 250/4000 psi except annular 250/3500 psi. Test waived by Chuck S.via email 11/22 2. Blinds; Kill HCR; Upper TD; 3-1/2" IF TIW; Chokes 3,7, 9,10-pass 3. Blinds; Man. Kill; Upper TD; 3-1/2" TIW; Chokes 2, 5, 8-pass 4. LPR with 2-7/8 TJ; 3-1/2"8rd FOSV-pass 5.Annular with 2-7/8"TJ; Man. Kill- pass 6. UPR with 2-7/8"TJ; Man Kill; chokes 1, 2, 5,6-pass 7. UPR with 2-7/8"TJ; Man Kill; Choke HCR-pass 8. UPR with 2-7/8"TJ; Man Kill; Man Choke-low pass, high fail. Re-grease man. choke-pass 9. LPR with 3-1/2"TJ-low pass, High test hose leak. Tighten test hose-pass 10.Annular with 3-1/2"TJ-pass 11. LPR with 4-1/2"TJ 12.Annular with 4 1/2"TJ 06:30 07:30 1.00 0 0 MIRU WHDBO BOPE P Draw down test-lay down TJ. Suck out stack&pull BPV. Page 2 of 10 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 07:30 09:00 1.50 0 0 COMPZ RPCOM PULL P BOLDS-P/U on tubing-hanger broke over @ 60K, P/U to 125K- 80%pull on pipe. No luck pulling from seals. Dispatch E-line. Continue working string. Pump hole volume while working string down tubing 6 bpm @ 1300psi. 09:00 09:30 0.50 0 0 COMPZ RPCOM RURD P Stop pumping, no flow check,well static,blow down TD. Set pipe in slips @ 85 K(15K over string weight). Set up rig floor for E-line operations. 09:30 12:00 2.50 0 0 COMPZ RPCOM ELNE T Wait on Eline. Eline called out @ 08:30 hrs Arrived @ 12:00 hrs 12:00 15:15 3.25 0 0 COMPZ RPCOM ELNE P PJSM-Spot Eline and R/U E-line. 15:15 21:45 6.50 0 0 COMPZ RPCOM ELNE P RIH with 1 11/16"RCT cutter 6414'. WL hung up @ sssv. Pumped it open @ 6 BPM. Eline thru valve. RD Eline 21:45 22:30 0.75 0 0 COMPZ RPCOM PULL P Pulled hanger to floor. Up wt=74 K. Missing valve to control line on hanger. 22:30 23:30 1.00 0 0 COMPZ RPCOM RURD P PJSM with Camco. RU spooler 23:30 00:00 0.50 0 0 COMPZ RPCOM CIRC P Ciculate Hole Volume @ 5BPM @ 1100 psi 11/25/2014 Circulate and condition the hole. POOH with 2-7/8"completion(recovered all 30 SS bands)to 2950'. RIH with storm packer,set at 100', and PT to 1500 psi(good test). ND BOPE. ND tubing spool with Hydratight (casing grew 1"). Spear 7"casing, pull 10K and casing stretched an additional 3.25"(total casing growth 4.25"). Land casing in slips, cut off excess casing, and install new pack-off. NU new tubing spool and test voids to 250/3000 psi(good test). NU BOPE and shell test BOPE to 250/4000 psi(good test). Retrieve storm packer and POOH with 2-7/8"completion. 00:00 01:00 1.00 0 0 COMPZ RPCOM CIRC P Continue circulating hole volume at 6 bpm 1100 psi. R/D circ equipment 01:00 02:00 1.00 0 0 COMPZ RPCOM CIRC P Monitor the well. Well out of balance. Establish circulation and pump tubing volume. 02:00 02:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor well for flow,well static. 02:30 05:30 3.00 6,414 4,605 COMPZ RPCOM PULL P PJSM POOH with 2-7/8" decompletion 05:30 07:00 1.50 4,605 4,605 COMPZ RPCOM RURD P Lay down SSSV-kick out camco equipment.All 30 SS bands recovered from well. 07:00 09:00 2.00 4,605 2,950 COMPZ RPCOM PULL P Continue TOOH with decompletion to 2950'to set storm packer. 09:00 10:30 1.50 2,950 3,050 COMPZ WELLPF MPSP P Pick up BHA#1 Strom packer RIH to 100 ft.set packer. PT to 1500 psi. for 20 min's. 10:30 11:00 0.50 3,050 0 COMPZ WELLPF OWFF P Monitor the well for flow for 30 minutes. Well static. 11:00 12:00 1.00 0 0 COMPZ WELLPF NUND P ND BOPE stack 12:00 15:00 3.00 0 0 COMPZ WELLPF NUND P PJSM. Install PESI growth system ND tbg spool. Csg growth prior to stretching= 1". RD PESI. Pulled pack off seals. Page 3 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 1.00 0 0 COMPZ WELLPF CUTP P Made up BHA#2 Spear assembly. engaged casing pulled 10 K over string wt of 57 K. Total growth= 4.25" Landed slips released spear and laid it down. 16:00 19:30 3.50 0 0 COMPZ WELLPF CUTP P Cut off excess casing. install new pack off&NU new tbg spool. Test voids to 250/3000 psi(good test). 19:30 21:00 1.50 0 0 COMPZ WELLPF NUND P NU BOPE 21:00 22:00 1.00 0 0 COMPZ WHDBO BOPE P Shell test BOPE to 250/4000 psi 22:00 22:15 0.25 0 0 COMPZ WELLPF RURD P Pull BOPE test plug and install wear ring. 22:15 22:45 0.50 0 100 COMPZ WELLPF MPSP P PJSM. RIH with BHA#3-storm packer retrieving tool. Release storm packer. 22:45 23:15 0.50 100 100 COMPZ WELLPF OWFF P Observe the well for flow for 30 minutes. Well static. 23:15 23:30 0.25 3,050 2,950 COMPZ WELLPF MPSP P POOH with storm packer and lay down storm packer with retrieving tool-BHA#3. 23:30 00:00 0.50 2,950 2,780 COMPZ RPCOM PULL P Continue to POOH with 2-7/8" completion at midnight 2780'. 11/26/2014 Continue to POOH with 2-7/8"completion from 2780'to surface. Cut joint= 15.88'with good cut. Install test plug and PT to 1500 psi for 5 minutes(good test). Change out upper rams from 2-7/8"solid body rams to 3-1/2"solid body rams. Shell test upper 3-1/2"pipe rams to 250/4000 psi. RIH with BHA#4-overshot assembly to 6398'. Circulate and condition the hole. SO to engage tubing stub with overshot and start jarring at 50K over up to 75K over. Fish is free. Reverse circulate three DP volumes. TOOH with BHA#4- overshot assembly and fish from 6405'to surface. We did not recover the seal assembly fish. 00:00 03:30 3.50 2,780 0 COMPZ RPCOM PULL P Continue to POOH with 2-7/8" completion from 2780'to surface. Cut joint 15.88'with good cut. 03:30 04:15 0.75 0 0 COMPZ RPCOM RURD P Clean and clear the floor. Pull wear ring. 04:15 05:00 0.75 0 0 COMPZ WHDBO BOPE P Install test plug and PT to 1500 psi for 5 minutes(good test). Blow down stack. 05:00 08:00 3.00 0 0 COMPZ WHDBO BOPE P PJSM. Change out upper rams from 2-7/8"solid body rams to 3-1/2"solid body rams. 08:00 09:30 1.50 0 COMPZ WHDBO BOPE P Shell test upper 3-1/2"pipe rams to 250/4000 psi. Pull test plug and set wear ring. 09:30 17:00 7.50 0 6,398 COMPZ RPCOM PULD P Make up&RIH with BHA#4- Overshot assembly. Pick up drill pipe. Up wt= 120 K. Dn wt. = 118K. 17:00 18:00 1.00 6,398 6,398 COMPZ RPCOM CIRC P Condition mud in hole. Circulated 400 BBL's @ 6 BPM @ 1250 psi. Page 4 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:30 1.50 6,398 6,405 COMPZ RPCOM JAR P SO to engage tubing stub with overshot, PU= 124K, and SO= 115K. Tag top of fish at 6405' , rotate down over fish at 20 RPM,set down 20K, and begin jarring. Start jarring at 50K over up to 75K over. Fish is free, PU 30', pump at 3 BPM =700, SO,and pump pressure increased to 1200 psi. PU to reverse circulate. 19:30 20:00 0.50 6,405 6,405 COMPZ RPCOM CIRC P Reverse circulate three DP volumes (150 bbls)at 8 BPM= 1800 psi. Had sand come over the shakers. Blow down top drive. SIMOPS: Perform post jarring derrick inspection. 20:00 20:30 0.50 6,405 6,405 COMPZ RPCOM OWFF P Observe the well for flow for 30 minutes,well static. 20:30 21:00 0.50 6,405 6,405 COMPZ RPCOM RURD P RU DP air slips 21:00 00:00 3.00 6,405 0 COMPZ RPCOM TRIP P TOOH with BHA#4-overshot assembly and fish from 6405'to surface. Did not recover the seal assembly fish. 11/27/2014 Lay down overshot assembly. Wait for new grapple and extra extension to be delivered. TIH with 5-3/4" overshot assembly to top of fish at 6405',swallowed over fish to 6411'and set grapple with 20K over. Hit jars at 50 K over and pulling up to 75 K over. Hit jars 4 times, fish pulled free pulled up to 6765', SO to 6420' started taking weight. TOOH with fish dragging 10-15K over and swabbing;filling hole every stand down the drill pipe. Recovered seal assembly, PBR and packer assembly. TIH with cleanout mill assembly to 6634', broke circulation, observed entrained packer gas in returns, and shut down the pumps. Circulate out the entrained packer gas thru the choke and thru the degasser. Observe the well for flow for 30 minutes,well static. 00:00 00:30 0.50 0 0 COMPZ RPCOM PULD P Lay down BHA#4-overshot assembly. Grapple has some scale packed off in the wicker threads but show signs of engaging the tubing stub. 00:30 02:30 2.00 0 0 COMPZ RPCOM OTHR T Wait for new grapple and extra extension to be delivered. SIMOPS: Service the top drive and blocks. 02:30 02:45 0.25 0 0 COMPZ RPCOM RURD P Load and strap tools. 02:45 03:00 0.25 0 28 COMPZ RPCOM PULD P PU and MU BHA#5-5-3/4"overshot assembly. 03:00 06:30 3.50 28 6,411 COMPZ RPCOM TRIP P TIH with BHA#5 to top of fish at 6405',swallowed over fish to 6411. 06:30 07:00 0.50 6,411 6,420 COMPZ RPCOM FISH P Set grapple with 20K over. Hit jars @ 50 K over&pulling up to 75 K over. Hit jars 4 times pulled free pulled up to 6765'dropped back down to 6420 ft.taking weight. 07:00 17:00 10.00 6,420 0 COMPZ RPCOM TRIP P POOH with BHA#5. Dragging 10-15K over and swabbing. Filling hole every stand thru drill pipe. Recovered packer assembly. Page 5 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 69 COMPZ WELLPF PULD P Pick up BHA#6-cleanout mill assembly. 18:00 21:00 3.00 69 6,442 COMPZ WELLPF TRIP P TIH with BHA#6 to 6442'. 21:00 21:30 0.50 6,442 6,634 COMPZ WELLPF PULD P Continue to RIH with BHA#6 singling in from the pipe shed to 6634'. PU = 126K&SO= 120K. 21:30 23:30 2.00 6,634 6,634 COMPZ WELLPF CIRC P Break circulation at 8 BPM=2100 psi, observed entrained packer gas in returns, shut down the pumps. Circulate out the entrained packer gas at 1 BPM =850 psi thru the choke at 230 psi thru the degasser. 23:30 00:00 0.50 6,634 6,634 COMPZ WELLPF OWFF P Observe the well for flow for 30 minutes, well static. 11/28/2014 Circulate and condition the well; circulated 224 bbls and returns were clean. Continue to single in the hole with cleanout mill assembly tagged fill at 6680'and cleanout fill to 6876'. Drop ball and open pump out sub. TOOH with cleanout mill assembly and lay down cleanout assembly. RU HES, RIH with perforation gun, and perforate from 6636'to 6640'. Stand back E-Line. MU and TIH with 4-1/2"liner assembly filling the DP every 5 stands(depth at midnight=3912'). 00:00 00:30 0.50 6,634 6,634 COMPZ WELLPF CIRC P Circulate and condition the well at 8 BPM =2000 psi. Observed sand coming over the shakers, circulated 224 bbls and returns were clean. 00:30 03:30 3.00 6,634 6,876 COMPZ WELLPF WASH P Continue to single in the hole with BHA#6-cleanout mill assembly circulating at 8 BPM =2130 psi, rotating at 65 RPM. Tag fill at 6680' and cleanout fill to 6693'were torque spiked to 3800 ft-lbs(Fish lost in 6/3/99: 53" DAP tool also centralizers and blades from E-line spinner). Mill thru fish and continue to cleanout fill (getting frac sand over the shakers)to 6876'. 03:30 04:30 1.00 6,876 6,876 COMPZ WELLPF CIRC P Pump 20 bbls sweep and circulate it out at 10 BPM =2800 psi until clean returns(293 bbls). Drop ball and open pump out sub(sheared at 2574 psi). 04:30 05:00 0.50 6,876 6,876 COMPZ WELLPF OWFF P Observe the well for flow for 30 minutes,well static. SIMOPS: Blown down top drive and drop 2-1/8"drift with tag wire. 05:00 09:00 4.00 6,876 252 COMPZ WELLPF TRIP P TOOH with BHA#6-cleanout mill assembly. 09:00 11:30 2.50 252 0 COMPZ WELLPF PULD P Lay down drill collars and BHA#6. Clear rig of fishing tools 11:30 12:00 0.50 0 0 COMPZ WELLPF ELNE P Load and install Dutch riser. Prep for E-line. 12:00 17:00 5.00 0 0 COMPZ WELLPF ELNE P PJSM RU HES to run GR , 3 3/8" 60° phasing Millennium 6 Spf HMX Super DP perforation gun. Perf from 6636'to 6640 ft. Lay down HES pull Dutch riser. Page 6 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 0 0 COMPZ RPCOM RURD P RU liner running equipment. Load cement head and centralizers. 18:00 20:15 2.25 0 524 COMPZ RPCOM PULD P PU and MU shoe track, 3 joints of 4-1/2"liner,window kickoff joint, 5 joints of 4-1/2"liner, SBE, and liner hanger/packer assembly. 20:15 20:30 0.25 524 524 COMPZ RPCOM RURD P Change over floor to DP running equipment. 20:30 00:00 3.50 524 3,912 COMPZ RPCOM TRIP P TIH with 4-1/2"liner assembly filling the DP every 5 stands. Depth at midnight=3912'. 11/29/2014 Continue to TIH with 4-1/2"liner assembly filling the DP every 5 stands from 3912'to 6865'. RU HES E-line, RIH with CCL/GR, correlate liner on depth(4'correction 6,), and RD E-line. Circulate and condition the mud. RU Schlumberger and cement liner(cement in place at 12:45 hours). Pressured up to 3171 psi to set liner hanger and set down on hanger with 60K. RD Schlumberger. Released from liner top, hanger did not appear to be in place after rotation. No shear action and able to circulate. Circulate out mud flush and cement. Tagged liner top at 6359', it fell 14'to 6876'(liner shoe). Set liner top packer. Wait on cement. Pressure test the 4-1/2" liner, liner top packer, and 7"casing to 250/3000 psi for 30 minutes. TOOH with liner setting tool(depth at midnight=3676'). 00:00 04:00 4.00 3,912 6,865 COMPZ RPCOM TRIP P Continue to TIH with 4-1/2"liner assembly filling the DP every 5 stands from 3912'to 6865'. PU space out pups and a single DP joint to space out for good working height for E-line. 04:00 07:00 3.00 6,865 6,865 COMPZ RPCOM ELNE P PJSM. RU HES E-line. RIH with CCL and GR. Correlate liner on depth. POOH with E-line. RD E-line. 07:00 09:00 2.00 6,865 6,861 COMPZ RPCOM RURD P Ru cement head and lines lifted string 4 ft to place it on depth with eline 09:00 10:00 1.00 6,861 6,861 COMPZ RPCOM CIRC P Est circulation @ 4 BPM @ 970 psi. to condition mud. 10:00 13:30 3.50 6,861 6,861 COMPZ CEMEN.CMNT P PJSM RU Schlumberger to cement liner. Pumped 5 BBLs mud flush 13.5#@ 1.5 BPM @ 740 psi. PT lines to 4000 psi. Pump 10 m ore BBL's of mud flush @ 2.5 BPM @ 760 psi. =15.3 total. MIX&pump 19.3 G cmt with 2#'s per BBL cement. Dropped plug displaced with 5 BBI's fresh , 48.3 bbls. set plug & pressured up to 3171 psi. CMT in place @ 12:45 hrs. held pressure set hanger. Sat down on hanger with 60 K. Bled off pressure. RD Schlumberger. 13:30 14:15 0.75 6,861 6,861 COMPZ RPCOM CIRC P Released from liner top. Hanger did not appear to be in place after rotation. No shear action.Able to circulate. Circulate mud flush&cmt. out with 205 bbls. 14:15 15:30 1.25 6,359 6,244 COMPZ RPCOM PACK P RD cmt head. pick up work jt Tagged liner top @ 6359 ft It fell 14 ft to PBTD @ 6876 ft tail of liner. Set packer. pulled up to 6244' Page 7 of 10 Time Logs Date From To " Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:30 3.00 6,244 6,244 COMPZ CEMEN'WOC P Wait on cement and orders. Had rig complete slip/cut while waiting. Liner depth ok. 18:30 19:00 0.50 6,244 6,244 COMPZ RPCOM RURD P RU to pressure test. 19:00 21:15 2.25 6,244 6,244 COMPZ RPCOM PRTS P Pressure test the 4-1/2"liner, liner top packer,and 7"casing to 250/3000 psi for 30 minutes. 21:15 21:30 0.25 6,244 6,244 COMPZ RPCOM RURD P RD testing equipment 21:30 22:00 0.50 6,244 6,244 COMPZ RPCOM OWFF P Observe the well for flow for 30 minutes,well static 22:00 00:00 2.00 6,244 3,676 COMPZ RPCOM TRIP P TOOH with liner setting tool(depth at midnight=3676'). 11/30/2014 Continue TOOH with liner setting tool from 3676'to surface. TIH with 2-7/8"mule shoe joint cleanout assembly; no-go inside the liner tie back sleeve at 6370'with the mule shoe at 6403'. PU, break circulation, and pump 60 bbls hi-vis mud sweep followed by 35 bbls hi-vis seawater sweep followed by clean seawater. TOOH with 5 stands,well is out of balance.Attempt to balance the well out without success. Clean the residual mud out of the pits and take on clean sea water. TIH with 5 stands and pump 31 bbls hi-vis seawater sweep followed by clean seawater until returns are clean. TOOH with cleanout assembly from 6402'to surface with DP. 00:00 01:30 1.50 3,676 0 COMPZ RPCOM TRIP P Continue TOOH with liner setting tool from 3676'to surface. 01:30 02:30 1.00 0 0 COMPZ WELLPF PULD P Lay down liner setting tool. PU and MU BHA#7-2-7/8"mule shoe joint to cleanout liner hanger/packer and SBE. 02:30 05:30 3.00 0 6,403 COMPZ WELLPF TRIP P TIH with BHA#7 and no-go inside the liner tie back sleeve at 6370'with the mule shoe at 6403' 05:30 08:00 2.50 6,403 6,402 COMPZ WELLPF DISP P PU and break circulation at 2 BPM= 730 psi. Circulate and condition the mud. Pump 60 bbls hi-vis mud sweep followed by 35 bbls hi-vis seawater sweep followed by clean seawater. 08:00 08:30 0.50 6,402 5,827 COMPZ WELLPF TRIP P POOH with 5 stands well is out of balance 08:30 11:00 2.50 5,827 5,827 COMPZ WELLPF CIRC T Circulated hole volume once more to clean up fluid&balance well. still out of balance built sweep. &pump 20 BBLs. Inspected trip tank still had mud in it. isolated Trip tank to clean. Sweep back to surface. Still had some mud in the system . 11:00 11:30 0.50 5,827 5,827 COMPZ WELLPF OWFF T Flow check for 30 min's.well still out of balance. 11:30 18:00 6.50 5,827 5,827 COMPZ WELLPF COND T Clean pits and take on clean sea water. 18:00 18:30 0.50 5,827 6,402 COMPZ WELLPF TRIP T TIH from 5824'to 6402' 18:30 19:30 1.00 6,402 6,402 COMPZ WELLPF OTHR T Wait for truck with 290 bbls of new clean seawater to arrive. 19:30 20:15 0.75 6,402 6,402 COMPZ WELLPF COND T Load pits with new clean seawater. Strap the pits Page 8 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 21:30 1.25 6,402 6,402 COMPZ WELLPF CIRC T PJSM. Pump 31 bbls hi-vis sweep followed by clean seawater until returns are clean(243 bbls)at 8 BPM=2300 psi. Blow down top drive and kill tank line. 21:30 22:00 0.50 6,402 6,402 COMPZ WELLPF OWFF T Observer the well for flow for 30 minutes,well static. 22:00 00:00 2.00 6,402 33 COMPZ WELLPF TRIP P TOOH with BHA#7 from 6402'to surface with DP. 12/01/2014 Lay down cleanout assembly and washout the BOPE stack. RIH with 3-1/2"tubing completion per tally. At a depth of 5784', lost manual slip die in the hole but still had free movement up and down. Continue to RIH with completion. Engage seal assembly into the SBE,space out, and MU tubing hanger. Circulate well to CI seawater, land tubing hanger,and RILDS.. PT the tubing to 3500 psi, PT the IA to 3000 psi, install BPV/blanking plug and pressure up on the IA to 1000 psi to test BPV from below. Change upper rams to 2-7/8"solid body rams. 00:00 00:15 0.25 33 0 COMPZ WELLPF PULD P Lay down BHA#7-2-7/8"mule shoe joint cleanout assembly. 00:15 00:30 0.25 0 0 COMPZ WELLPF RURD P Pull wear ring and set test plug in prep to washout the BOPE stack. 00:30 00:45 0.25 0 0 COMPZ WELLPF PULD P PU and MU BOPE wash tool. 00:45 01:15 0.50 0 0 COMPZ WELLPF WWWH P Washout the BOPE stack. 01:15 01:30 0.25 0 0 COMPZ WELLPF PULD P Lay down BOPE wash tool 01:30 03:30 2.00 0 0 COMPZ WELLPF RURD P Blow down top drive. Pull test plug. RD DP running equipment. RU 3-1/2"tubing running equipment. 03:30 17:00 13.50 0 6,365 COMPZ RPCOM PUTB P PU 3-1/2"tubing per running order. installed SSSV with Zip tie band 3 Per jt SS band every 10/11 jt above&below coupling, (At 13:30 hrs,tubing depth of 5784', lost manual slip die in the hole. (Dimensions: 1"H X 1-1/4"W X 2-3/4"L)Checked free movement with string up wt=84K pulled up 10 ft no issues. no issues in down movement. continue to RIH with completion. Up weight=93 K down weight=90 K Installed 11 stainless steel bands and 169 plastic zip ties. 17:00 17:30 0.50 6,365 6,365 COMPZ RPCOM HOSO P No Go on liner top.space out well Picked up hanger. 17:30 18:30 1.00 6,365 6,365 COMPZ RPCOM CRIH P Spot 172 bbls of 5%Conqor 303 treated sea water.displaced with 50 bbls of sea water. 18:30 19:30 1.00 6,365 0 COMPZ RPCOM THGR P Land tubing hanger and RILDS. 19:30 20:15 0.75 0 0 COMPZ RPCOM RURD P RU testing equipment. Page 9 of 10 Time Logs Date From To Dur S. Depth`E. Depth Phase Code Subcode T Comment 20:15 22:00 1.75 0 0 COMPZ RPCOM PRTS P Pressure test the tubing to 3500 psi for 15 minutes(good test). Bleed the tubing to 2000 psi and PT the IA to 3000 psi for 30 minutes(good test). Pressure up on the IA and shear the SOV(sheared at 2619 psi) 22:00 22:15 0.25 0 0 COMPZ RPCOM RURD P RD testing equipment. Pull landing joint. 22:15 22:30 0.25 0 0 COMPZ WHDBO MPSP P Set BPV and blanking plug. Pressure up on the IA to 1000 psi to PT the BPV from below for 5 minutes (good test). 22:30 23:00 0.50 0 0 COMPZ WHDBO RURD P RD SLB pooler and control line sheave. 23:00 00:00 1.00 0 0 COMPZ WHDBO NUND P Change out upper pipe rams to 2-7/8"solid body rams. 12/02/2014 Continue to change out upper pipe rams to 2-7/8"solid body rams. Open lower pipe rams inspect and cleanout. ND the BOPE and set back on stump. NU tubing head adapter and NU 3-1/8"tree. PT the tubing head adapter and tree to 250/5000 psi. Pull blanking plug and BPV. Open and function test SCSSSV. RU LRS and freeze protect well with 70 bbls of diesel at 2 BPM =700 psi down the IA. RD LRS. Let diesel to equalize T x IA. Final well pressures: TBG= 0 psi, IA=0 psi, OA=0 psi. Installed BPV and secured well. *Rig released @ 12:00 hours* 00:00 05:30 5.50 0 0 COMPZ WHDBO NUND P Continue to change out upper pipe rams to 2-7/8"solid body rams. Open lower pipe rams inspect and cleanout. ND the BOPE and set back on stump. NU tubing head adapter and NU 3-1/8"tree. 05:30 06:30 1.00 0 0 COMPZ WHDBO PRTS P PT the tubing head adapter and tree to 250/5000 psi. Pull blanking plug and BPV. Open and function test SCSSSV. 06:30 09:00 2.50 0 0 COMPZ WHDBO FRZP P PJSM: RU LRS and freeze protect well with 70 bbls of diesel at 2 BPM =700 psi down the IA. RD LRS 09:00 12:00 3.00 0 0 COMPZ WHDBO FRZP P Let well equalize out diesel push for freeze protect. Final well pressures. TBG= O psi, IA=0 psi, OA=0 psi, RD hoses. Installed BPV and secured well. *Rig released @ 12:00 hours* Page 10 of 10 /--, Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file. may be scanned during the rescan activity or are viewable by direct inspection of the file. jÝYOBL Well History File Identifier Organization (done) ~~o-Sided 1111111111111111111 o ResCdn Needed 11\ 11111\11111111\\ RESCAN DIGITAL DATA OVERSIZED (Scannable) o Color items: o Diskettes. No. o Maps: o Grayscale items o Other, NofType o Other items scannable by large scanner o Poor Ouality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds o Other TOTAL PAGES: NOTES: ORGANIZED EY BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE /sl Project Proofing 1I11111111111111111 111111111\111111111 1:-S-t~~r:<:1 l~~_~__~__.__ - --- PROOFED BY BEVERL y BREN VINCENT SHERYL MARIA LOWELL DATE /SI Scanned (done) \\\\\111\ \111\ 1\111 P AG E S . {a1ìllelî7'r\t:Di-s-camTTTT9i ~C'ì SC¡'.NNED 6Y BEVERLY BREN VINCEG(,jAR;;O. LOWEll DAn R/.?- '1 /0 Z3J ~ ------- ReScanned (done) 1111111111111111111 RE SCANrJED 6Y. BEVERL Y BREN V1NCUJT SHERYl Mi-RIA LOwELL OA1 E IS' --~---- General Notes or Comments about tt,IS file Ouallty Ct1eckecJ (ciont'ì 1111111111\11111111 PAGES Hr~ "~CJl ~>(..)f'ne<1 ",\>,1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 19,2013 TO: Jim Regg P.I.Supervisor �6Z (G(7A h SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA INC 30-12 FROM: Jeff Turkington KUPARUK RIV UNIT 30-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv:3:a2- NON-CONFIDENTIAL Comm Well Name KUPARUK R1V UNIT 30-12 API Well Number 50-029-21804-00-00 Inspector Name: Jeff Turkington Permit Number: 188-041-0 Inspection Date: 6/16/2013 Insp Num: mitJAT130616205820 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-12 " ',,Type Inj W.i,TVD 6404 - IA 5o5 3400 1262 3222 - PTD 1880410— a � Type Test SPT ITest psi 3000 OA 500 " 500 500 500 Interval ''REQ\AR I,P/F P 1Tubing 2754 ; 2754 2754 2754 Notes: A10 2B.027.5.0 bbl diesel to fill. SCANNED FEB 2 0 2014 Wednesday,June 19,2013 Page 1 of 1 lS5O410 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, July 30, 2012 8:38 AM To: Regg, James B (DOA) F- 4 7(3b)(1--- Cc: Wallace, Chris D (DOA) Subject: RE: KRU Monthly injector report for June Jim, Initial DHD Diagnostics on 30 -10 and 30 -12 were completed over the weekend. Passing MITOAs were achieved on both wells. The IC -pack off seals were re- energized and IC -POTs were performed. 30 -12 passed both the negative and positive pressure ICC = POTs, while 30 -10 passed the negative and failed the drawdown POT. However, the OA drawdown tests for both wells failed. The wells were shut in and freeze protected yesterday and will remain so pending further diagnostics to include but not limited to MITIAs and repeat OA DD'I s with IA pressure having been bled off. The proper paperwork and /or permissions will be asked for prior to bringing the wells back on -line. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc scow Desk Phone (907) 659 -7224 ! SAY 0 2 2013 Pager (907) 659 -7000 pgr 909 dd�nn From: Regg, James B (DOA) [mailto:jim.regg(aalaska.gov] Sent: Thursday, July 19, 2012 10:18 AM To: NSK Problem Well Supv Cc: Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: KRU Monthly injector report for June 3F -04 (PTD 1852280): report IA pressure bleed on 6/16 /2012 (took 2 days to bleed off IA pressure from 1300 to 800psi ?); what was the cause of pressure increase on 6/20 to 1500 psi followed by decline on 6/24 from 1500 to 800psi, and subsequent repressure of the IA to 1250psi as of 6/30? 30 -10 (PTD 1880590): T1O pressures plot indicates OA pressure is tracking IA pressure: this should be investigated 30 -12 (PTD 1880410): same issue as 30 -10 3S -18 (PTD 2022060): Huff & Puff well; please add daily production volume to the tabular data for future submittals; otherwise it is not obvious if well is producing or S1 when not injecting Jim Regg AOGCC 333 W. 7th Ave, Suite 1()0 Anchorage, AK 99501 907 -793 -1236 From: NSK Problem Well Supv [mailto:n1617 _ c. ..co.hilli.s.com] Sent: Sunday, July 08, 2012 9:33 PM To: Regg, James B (DOA); Schwartz, Gu (DOA) Subject: KRU Monthly injector repo or June 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 30, 2011 NED Commissioner Dan Seamount tin Crms. Cornmfssion Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: 3 0 - 1 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, e , MJ Lo land ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) p rY i Kuparuk Field Date 6130111 2F,2M,2N,2T,2X,2Z,3B,30 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2F -19 50029227280000 1962010 8" N/A 23" N/A 13 6/25/2011 2M -09A 50103201770100 1960900 SF N/A 18" N/A 3.5 6/26/2011 2M -14 50103201730000 1920630 SF N/A 19" N/A 3.5 6/26/2011 2M -17 50103201500000 1910180 SF N/A 19" N/A 3.5 6/26/2011 2M -26 50103201720000 1920550 SF N/A 21" N/A 3.5 6/26/2011 2N -316 50103203420000 2000900 SF N/A 18" N/A 4 6/27/2011 2N -318A 50103203430100 2090220 10" N/A 27" N/A 7 6/27/2011 2T-40 50103205280000 2060400 2' N/A 2' N/A 6 6/26/2011 2T -202 50103202540000 1980370 6" N/A 20" N/A 9 6/26/2011 2X -07 50029209910000 1831130 SF N/A 21" N/A 2 6/25/2011 2X -08 50029209920000 1831140 SF N/A 21" N/A 2.5 6/25/2011 2Z -02 50029209600000 1830800 18" N/A 18" N/A 2.6 6/24/2011 3B -01 50029213180000 1850560 SF 1.50 17" 5/23/2011 6 6/22/2011 C ") 30-12 50029218040000 1880410 SF N/A 22" N/A 1.7 6122/2011 I 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 22, 2011 TO: Jim Regg - ' P.I. Supervisor \ 23 f 9 '/( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30 -12 FROM: Bob Noble KUPARUK RIV UNIT 30 -12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry n NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 30 -12 API Well Number: 50- 029 - 21804 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN110621143333 Permit Number: 188-041 -0 Inspection Date: 6/21/2011 Rel lnsp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 30-12 ' Inj. lil TVD 6404 ' IA 944 3800 ' 3735 3710 - P. T.D� 1880410 'ITypeTest S Test psi 3800 - OA 640 890 900 900 Interval REQ _ P/F P " Tubing' 3000 3000 3000 3000 1 Notes: This IA took 5.4 bbls to pump it up. A3:o . z. 0 z7 - ,'.;p i:0 t2 :I. :I' el `!-I Wednesday, June 22, 2011 Page 1 of 1 • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, June 22, 2011 9:24 AM 19 _ To: NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: RE: 30 -12 MITIA results nothing attached would like an explanation about why it took 17+ barrels of fluid (that I can account for) to fill the IA for MITs. Is there gas being bled from IA? If so, has it been sampled? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 � n. �t 3 Lt ��i Anchorage, AK 99501 {`1 U 1� 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Wednesday, June 22, 2011 7:05 AM To: Brooks, Phoebe L (DOA); Regg, James B (DOA) Cc: Loveland, MJ Subject: 30 -12 MITIA results To All, Attached are the results of 30 -12 State Witnessed (Bob Noble) MIT's. If you have any questions please let me know. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659 -7224 6/22/2011 MEMORANDUM ~ TO: Jim Regg ~~~3 ~ f ~~ ~ P.I. Supervisor ~ FROM: Chuck Scheve Petroleum Inspector ~ tate of Alaska Alaska Oii and Gas Conservation Commission DATE: Thursday, July 23, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-] 2 KUPARLTK RIV LJNIT 30-12 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RN iJNIT 30-12 API Well Number: 50-029-21804-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS090626192249 Permit Number: 188-041-0 - Inspection Date 6/26/2009 Rel Insp Num: MITOP000002699 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~7~/e~l 30-12 Type Inj. W 7'~ 6404 ~ IA 1480 3720 " 3640 3640 ~ P.T.D lssoaio TypeTest SPT Test psi lboi y pA sao iooo iooo iooo IntePVai RequiredbyVariance P~ Pass y Tubing 3100 3100 3100 3100 NOtes: Well has known Tubing x IA comunication when on gas injection. / ~ Z~.C~Z7 ,- N~ i~ . ~~e~. ~r~S~L~ ~ 5 ti~1~~u,~ c,~,~`~,~~~' ~1~ec~,.~ ~r~s~w~ ~, ~;''~!. ,. ~ " ` t ; ; !~ '.~ :' ~ ~ U '~ uw.'.. f t, ~ Thursday, July 23, 2009 Page 1 of 1 ~ LJ MEMORANDUM 'ro: Jim Regg ~~'~~ `Z~~Z~~~, P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector I~ LJ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July O1, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPffiLLIPS ALASKA INC 30-12 KUPARiJK RIV UNIT 30-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv.~ Comm Well Name: KUPARUK RIV iJNIT 30-12 API Well Number: 50-029-21804-00-00 Inspector Name: Chack Scheve Insp Num: mitCS090626192733 Permit Number: 188-041-0 .- Inspection Date: 6/26/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. we~~ 30-12 Type Inj. W T'~ 6404 jA 1000 1040 1040 1040 P.T.D lasoaio TypeTest SPT ~ Test psi 16oi ,~ pA sao isoo .~ v6o i~6o Interval ~Qvnx p~ P ~ Tubing 3~0o sioo 3ioo 3ioo NOtes• MITOA. Well has known Tubing x IA comunication when on gas injection. ' ~ ~r~Z7 ~ (~!'~-~ D~~ tm ~i,c~+~-~enP~ ~~ C'~C~e~ S , f;`3i "srs,~r` `~. l.~ l' G i ~ L~ ~ f' . .> . ~,~ x- . . Wednesday, July O1, 2009 Page 1 of 1 30-12 (PTD 188-041, AIO 2B.02~larification Page 1 of 1 Re , James B DOA 99 ~ From: Regg, James B (DOA) Sent: Friday, April 04, 2008 2:56 PM '''~~~ Gj ~ (~~ © v To: 'NSK Well Integrity Proj' Subject: RE: 30-12 (PTD 188-041, AIO 28.027) Clarification Intent is to test to max injection pressure which would be 3800 psi gas injection pressure. Testing to max injection pressure has been a requirement in the few instances where gas injection has been allowed to continue in a well with mechanical integrity concerns. If the IA is going to be considered a competent barrier for well integrity purposes (essentially what is being done by the admin approval), it should be able to handle the injection pressure, or some other mechanics! requirement would be imposed to limit the pressure. As a general guide for future admin approval applications, if the downhole equipment being exposed to maximum injection pressure does represent a concern, please make sure to include appropriate detail sa #hat can be considered in our decision. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~1 AF'R ~ ~ 2008 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] _... Sent: Thursday, April 03, 2008 2:07 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: 30-12 (PTD 188-041, AIO 26.027) Clarification Jim, One of the conditions required by A102B.027 is an MITIA every 2 years to the maximum anticipated injection pressure. As a general rule ConocoPhillips does not normally MIT 7" inner annuli above 3500 psi due to hydrostatic head and maximum dP & collapse ratings on packers and jewelry. So before modifying the documentation for 30-12 to require an MITIA above our normal maximum test pressure, I wanted to gain clarification with the Commission as to whether the test pressure requirement was intended to include maximum MI injection pressure (3800 psi) or whether the maximum water injection pressure (3000 psi) was the intent of the requirement. During normal operations the IA will not exceed 2000 psi. Please advise. Thank you. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 4/4/2008 30-12 (PTD188-041) Page l..s~ • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, January 08, 2008 10:13 AM i 4~~0 To: 'NSK Well Integrity Proj' ~~~ Subject: RE: 30-12 (PTD188-041)Shorten MI Cycle Update We will need an Admin Approval request from CPAI no later than first week of March for this well to continue WAG ops on a shortened cycle. Jim Regg AOGCC 333 w.7th Avenue, suite 100 ~;~~~~ J~;N ~ ~ 20d~ Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, December 25, 2007 8:57 AM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 30-12 (PTD188-041)Shorten MI Cycle Update Jim, The this is an interim update for the shortened MI Cycle test for 30-12 (PTD 188-041). The well was Wagged to water on September 3; 2007 after showing signs of TxIA communication to MI. The tubing packoffs were tested, reenergized and rehydrated with hydraulic fluid in October. ' 30-12 was wagged back to MI on Dec 12, 2007, and the IA pressure has stayed fairly stable at -1250 psi. If the lA pressure trends remain stabilized and norms! the well will continue on MI injection until MidfLate February then e wagged to water. Attached is the ourrent 3 month TIO plot. Let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone X907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 05, 2007 3:33 PM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 30-12 (PTD188-041) 1 /8/2008 30-12 (PTD188-041) • Perry, MJ - • Page 2 ofd Sounds like a good plan, except do a shortened Mi cycle after reenergizing the pack-offs before pursuing an AA and add well to monthly report. The TIO data you provided indicates the IA pressure takes 2-3 months to show an increase after swapping to MI. This test may provide performance info that would be important to have for any AA that we would consider. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, September 04, 2007 2:46 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 30-12 (PTD188-041) Jim, Tom, 30-12 (PTD 188-041) was wagged to water yesterday do to a noted steady increase in IA pressure. Some of the increased pressure is clearly thermal, however the trend indicates a slow TxIA leak. The well had been on MI since March 31, 2007. It is our belief that we can repair the communication source by reenergizing the tubing packoffs after the well has been on water for a few days. The slow TxIA communication is attributed to the well head seats drying out after the well has been on MI service for several months. The well has exhibited similar behavior before as can be see in the attached 18 month T/I/O plot. The current T/IiO after wag to water is 2356/1550/700. It is ConocoPhillips intention to gain approval from the Commission to continue MI injection in this well after the seals are reenergized on either a shortened MI cycle (i.e. inject MI for ~3 month followed by water for 3 months) or with a periodic seal reenergize PM cycle or both. ConocoPhillips will follow up with an AA request if that is appropriate next step Attached is a 3 month T/I/O plot, an 18 month T/I/O plot and a Well schematic. Please let me know if this plan is acceptable or if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907} 659-7043 Cell Phone (907} 448-3114 1 /8/2008 TII:O Plot - 30-12 ~aao ~, 2a0a ~. 1ao0 fi ~~ i ~~ o -{-H-~- 25-Sep-07 a$-Oct-07 ~1-Oct-07 a3-Slav-0~ 16-Slav-a~' 29-Nair-U~ ~1-ueo-ur Date 00 15a 10u Y a u ~a 0 30-12 (PTDI88-041) Page 1 of3 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, September 05, 2007 3:33 PM To: 'NSK Well Integrity Proj' Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: 30-12 (PTD188-041) ~(r1 Q('5/01 Perry, MJ- Sounds like a good plan, except do a shortened MI cycle after reenergizing the pack-offs Þªfofe pursuing an AA and add well to monthly report. The TIO data you provided indicates the IA pressure takes 2-3 months to show an increase after swapping to MI. This test may provide performance info that would be important to . have for any AA that we would consider. Jim Regg AOGCC 333 w'7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 5CANNED SEP 1 1 2007 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, September 04,20072:46 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 30-12 (PTD188-041) Jim, Tom, . 30-12 (PTD 188-041) was wagged to water yesterday do to a noted steady increase in IA pressure. Some of the increased pressure is clearly thermal, however the trend indicates a slow TxlA leak. The well had been on MI since March 31, 2007. It is our belief that we can repair the communication source by reenergizing the tubing packoffs after the well has been on water for a few days. The slow TxlA communication is attributed to the well head seals drying out after the well has been on MI service for several months. The well has exhibited similar behavior before as can be see in the attached 18 month TIIIO plot. The current TIIIO after wag to water is 2356/1550/700. It is ConocoPhillips intention to gain approval from the Commission to continue MI injection in this well after the seals are reenergized on either a shortened MI cycle (i.e. inject MI for -3 month followed by water for 3 months) or with a periodic seal reenergize PM cycle or both. ConocoPhillips will follow up with an AA request if that is appropriate next step Attached is a 3 month TIIIO plot, an 18 month TIIIO plot and a Well schematic. 9/5/2007 2 ) 2 . . KRU 30-12 API: 500292180400 Well Type: INJ Anale @ TS: 8 dea @ 6591 sssv SSSV Type: TRDP Orig Completion: 6/3/1988 Angle @. TD: 8 deg @. 7005 (1784-1785, Annular Fluid: Last W/O: Rey Reason: TAG FILL OD:2.875) Reference Loa: Ref Log Date: Last Update: 12/4/2004 Last Tag: 6717 TO: 7005 ftKB Last Taa Date: 11/11/2004 Max Hole Angle: 14 deg @. 5300 i:~å$tñå¡1š"'w', Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 9.625 0 4106 4100 36.00 J-55 PROD. CASING 7.000 0 6957 6908 26.00 J-55 Size 1 Top I Bottom I TVD I Wt I Grade I Thread 2.875 I 0 I 6522 1 6477 I 6.50 1 ~ Interval TVD Zone Status Ft SPF Date Type Comment 6611 - 6621 6566 - 6576 C-1,UNIT B 10 12 3/27/1989 IPERF 60 deg. phasing; 2 1/8" EnerJet 6661 - 6671 6615 - 6625 A-3 10 12 3/27/1989 IPERF 60 deg. phasing; 2 1/8" Ener Jet 6676 - 6700 6630 - 6654 A-3,A-2 24 12 3/26/1989 IPERF 60 deg. phasing; 2 1/8" EnerJet 6712 - 6732 6666 - 6685 A-1 20 8 6/26/1988 APERF 45 deg. phasing; 4 1/2" HSD CSg Gun St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2568 2568 MMH FMHO DMY 1.0 BK 0.000 0 8/6/1989 2 4160 4154 MMH FMHO DMY 1.0 BK 0.000 0 6/26/1988 3 5070 5052 MMH FMHO DMY 1.0 BK 0.000 0 8/6/1989 4 5526 5496 MMH FMHO DMY 1.0 BK 0.000 0 6/26/1988 5 5793 5759 MMH FMHO DMY 1.0 BK 0.000 0 6/26/1988 6 6122 6083 MMH FMHO DMY 1.0 BK 0.000 0 6/26/1988 7 6388 6345 Merla TGPD DMY 1.5 TG 0.000 0 8/6/1989 Depth TVD Tvpe Description ID 1784 1784 SSSV Baker 'FVLD' 2.310 6434 6390 PBR Baker 2.376 6448 6404 PKR Baker 'HB' 2.376 6487 6443 NIP Cameo 'D' Nipple NO GO 2.250 PBR 6521 6477 SOS Baker 2.441 (6434-6435, 6522 6477 TTL 2.441 OD:2.875) 1 Depth I Description Comment 6687 FISH Fish left in hole, 53" DAP tool, 1 3/8" fishing neck @ 6687' WLM; PKR also centralizer portion & blades from full bore E-line spinner 6/3/99 (6448-6449, OD:6.151) Date 1 Note 6/27/19881 NOTE on HandOyer Form: 1 1/2" Brass Ball may be in 1 1/2" GLM @ 6388' NIP (6487-6488, OD:2.875) TUBING (0-6522, OD:2.875, ID:2.441) Perf - - - = (6611-6621) = - Perf = I: = - I- = (6661-6671) = I: - = I- = - - - - - - - =1= = Perf - I- - (6676-6700) - ~ - - - Perf - - (6712-6732) - - - - MEMORANDUM TO: Jim Regg P.I. Supervisor 1'/. ,\ttf G1?tID~ FROM: John Crisp Petroleum Inspector Well Name: KUPARUK RIV UNIT 30-12 Insp Num: mitJCr060613132559 Rei Insp Num State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-12 KUPARUK RIV UNIT 30-12 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-21804-00-00 Permit Number: 188-041-0 Packer Depth Pretest w;ïi-T 3~-12--- iT!p'~-inj'lmG I TVD__..~ -'-640~_____ T--iAr- 1450 P.T. _JI88041~JTyp~!_~~~~ I Tes~J~~~_1601 I _<2g_____~80 Interval 4YRTST PIF P Tubing I 3600 Notes 8.5 bbl's pumped for test. Wednesday, June 14.2006 ) \ tgl6 ... oÝ' I Reviewed By: P.I. Suprv .J~ Comm Inspector Name: John Crisp Inspection Date: 6110/2006 Initial 15 Min. 30 Min. 45 Min. 60 Min. 2040 2000 2000 1-- 640 640 640 ------t------ ----+--.. .----. .--- 3600 3600 3600 I ---~._--_._"._.._- SCANNED JUN 2 ~7 2005 Page I of I ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~...~Ú.........'""",,,,"""'..'";",.,...'.i:".-....,..",:Ð."..:~~l ~~,9?xf RepairWell 0 Pull Tubing 0 Operat. ShutdownO Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 59' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Stimulate 0 Waiver 0 Other 0 Time Extension 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Re-enter Suspended Well 0 .3, ~ermit to Drill Number: ~ Exploratory 0 L~"IO 201-019 . Service 0 6. API Number: 50-029-21804-00 9. Well Name and Number: 30-12 10. Field/Pool(s): Kuparuk Oil Pool measured 7005' feet true vertical 6956' feet measured feet true vertical 6276' feet Length Size MD 110' 16" 110' 4047' 9-5/8" 4106' 6898' 7" 6957' Plugs (measured) Junk (measured) Burst TVD Collapse 110' 4100' 6908' Measured depth: 6611-21,6661-71,6676-6700,6712-32 true vertical depth: 6566-76, 6615-25, 6630-54, 6666-85 NOV 2 2004 Tubing (size, grade, and measured depth) 2-7/8", J-55, 6522' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' pkr= 6448' sssv= SSSV sssv= 1784' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A SCANNED NOV 2 9 2004 13. Treatment descriptions including volumes used and final pressure: Prior to well operation , Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1200 1200 15. Well Class after proposed work: Exploratory 0 Development D 16. Well Status after proposed work: OilO GasD WAGD WDSPL 0 CasinQ Pressure 1300 1300 TubinQ Pressure 2340 2340 Service 0 WINJ0 GINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Brad Gathman/MJ Loveland @ 659-7224 :rint~Nam~ L07~ ~~:ne igna U~~nn 10~~ 04~004 0 rÚG\'N A L Problem Wells Supervisor 907 -659-7224 Date ;IS}I 0 1I1rl9 RBDMS BFL NOV 2 9 2004 Submit Original Only 30-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/21/2004 Bradenhead weld, Initial T/I/O= 0/0/0 Purge N2 across IA and OA while making 3 welding passed around BH as per procedure. QC post weld was good. 11/24/2004 MITOA (post BH weld) -passed. T /1/0=0/0/0. Pressured up OA to 1800 psi with diesel, started MITOA, T/I/0=0/100/1800, 15 minute reading- T/I/0=0/100/1740, 30 minute reading- T/I/0=0/100/1720. Bled OA, final T/I/0=0/50/180 (;h ) ) (~7.. os'?' (~'7-0z.C:; / <¡¡0-(~G;, 11?1l -o'f( [~rl- {(2 Page 1 of 2 y ConocoPhillips TranSluittal #383 Detail Date: 9/29/2004 To (External !)al.ty): Email: Howard_Okland@admin.state.ak.us ,I Frou1 (I) AI Contact): Email: Sandra.D.Lemke@conocophillips.com First Sandra Name: Last Lemke Name: Phone 265-6947 Number: Company: ConocoPhillips Alaska Address: 700 G Street, AT01486 City: Anchorage State: Ak Zip Code: 99510 First Name: Howard Last Name: Oakland Phone Number: Company: Address: City: ' State: Zip Code: Sent Via: hand delivery Transn1Íttal Info: Tracking #: SCANNED .Jl\N 0 () 2005 Justification: per 9/26/2004 request from Helen Warman, AOGCC Librarian Quantity 1 1 1 1 1 1 . Data Detail: Description Core Analysis report-KRU 30-12; Core Labs CL BP-3-1281; 8/9/1988 Core Analysis KRU 3M-09; 7/21/1987; Core Labs Core Analysis Report; KR U 3H-09; 2/22/1988; Core Labs Core Analysis Report; KRU 3K-09; Core Labs; 1/19/1987 Core Analysis Report; KRU 3M-16; Core Labs 8/19/1987 Type paper / paper / paper / paper I paper ¡ paper / Core Analysis Report- KRU 2T-09; Core Labs; 9/30/1988 http://www.ak.ppco.com/transmi ttal/print.asp ?transno=3 83 9/29/2004 ') Attachments: Filename: None Received By~/; h j J /' Sign~~~. .JtIM~ Approver: Signature: h up:/ /www.ak.ppco.com/transm i ttal/pri n t.as p ?transno=3 83 Filesize: N/ A ). Date: 9f.~ r( Date: Page 2of2 Q/?Q/?OO4 Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Page 1 of2 /---..... MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor (J)"\ Chair DATE: June 28, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder r m ^.~ PAl P.I. Supervisor W IV \. 30 'r)( -OJ multiple FROM: John H. Spaulding (t C;' KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL 4 P 4 P 4 P 4 P 4 P Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle v= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details M.I.T.'s performed: § Attachments: none Number of Failures: º Total Time during tests: 4 hrs cc: none M IT report form 5/12/00 L.G. mit(1) kru 30 6-28-02js.xls 7/16/2002 --- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Philli Alaska, Inc. 3. Address P. O. Box 100360 Anchora a, AK 99510-0360 4. Location of well at surface 1017' FNl, 3266' FEl, Sec. 22, T13N, A9E , UM At top of productive . interval 1234' FNl, 1863' FWL, Sec. 22, T13N, A9E, UM At effective depth Development _ Exploratory _ Stratigraphic _ ServiceJ (asp's 525648,6021801) At total depth 1254' FNl,3466' FEl, Sec. 22, T13N, A9E , UM 12. Present well condition summary Total depth: measured true vertical (asp's 525449,6021563) 7005 feet 6956 feet Plugs (measured) Effective depth: measured true vertical Casing Length Size CONDUCTOR 110' 16" SUR. CASING 4047' 9-5/8" PROD. CASING 6898' 711 feet Junk (measured) feet Cemented 175 sxAS I 1500 sx AS IU & 300 sx Class G w. 360 sx Class G Perforation depth: measured true vertical Tubing (size, grade, and' measured depth) 6. Datum elevation (DF or KB feet) AKB 59 feet 7. Unit or Property name Ku aruk Unit 8. Well number 30-12 9. Pennit number I approval number 188-041/ 10. API number 50-029-21804 11. Reid I Pool Ku aruk Oil Pool Measured Depth 110' 4106' 69571 True vertical Depth 110' 4100' 6908' Packers & SSSV (type & measured depth) Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations -" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed V 4 s ~ TiUe Production Engineering Supervisor Jeff A 51 ncer r- I=nrm 10.404 RAV nñl15/RR . SUBMIT IN DUPLICATE 6ö -- .-..... o ~/î 1/' /" < STATE OF IUSKA AlßSKA OIL AND GAS CONSERVATION COMMh:>d1ON REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 1. Operations Performed: Operation Shutdown _ Stimulate_ Pull tubing Alter casing Repair well 5. Type of Well: Development Exploratory Stratigraphic Service Plugging _ Perforate_ Other -1L 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1019' FNL, 2011' FWL, SEC.22, T13N, R9E, UM At top of productive interval 1234' FNL, 1863' FWL, SEC.22, T13N, R9E, UM At effective depth 1249' FNL, 1827' FWL, SEC.22, T13N, R9E, UM At total depth 1256' FNL 1811' FWL SEC.22, T13N R9E, UM 12. Present well condition summary Total Depth: measured true vertical feet x 7. Unit or Property name Kuparuk River Unit 8. Well number 9. Permit number/approval number 10. API number 11. Field/Pool Kuparuk River Field Ku aruk River Oil Pool 7005' 6956' feet feet Plugs (measured) Effective depth: measured true vertical 6875' feet Junk (measured) 6827' feet Casing Structural Conductor Surface Intermediate Length Size Cemented Measured depth True vertical depth Production Liner 7" 175 SX AS 1 1500 SX AS III & 300 SX CLASS G TOP JOB w/150 SX AS 1 360SXCLASS G 6957' 110' 4106' 110 4101' 80' 4071' 1 6" 9-5/8" 6924' 6908' Perforation depth: measured 6712'-6732', 6678'-6702, true vertical 6666'-6686', 6632'-6656', 6662'-6672' , 6616'-6626', 6611'-6621'. t \) 6566'-657~ E€£ \ \ ~ ~ ~ R 0 5 '99"3 . Wi. ~SS\O 0'\ & Gas cons. Carom A\aska i, a Eì Tubing (size, grade, and measured depth) 2-7/8 J-55 @ 6522' Packers and SSSV (type and measured depth) HB PKR 6448' FVLD SSSV 1784' 13. Stimulation or cement squeeze summary CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL 0 f\J ~ (24 /99, Intervals treated (measured) Treatment description including volumes used and final pressure 14. ReDresentative Daily AveraQe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 518 188 o 1194 146 1348 Subse uent to 0 ration 0 0 2823 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Water Injector _L Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service ~ œd C.~. ~~ Form 10-404 Rev 09/12/90 Title Petroleum En ineer Date 3 4 q3 SUBMIT IN DUPLICATE ~"" ARca Alaska, Inc./---' Post Office L-. _~ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 -. ~~ ~~ April 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject Kuparuk River Field Water Injection Surveys In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the First Quarter, 1990. The data is provided in the form of separate zone surveys or as spinner logs listed in Attachment 1. Injection rates determined by separate zone surveys are also listed in Attachment 1. The blue line and sepia copies of the spinner logs are also included. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, ~~¡{ ~~ ( S. E. Schmidt Operations Engineer SES:LLP REC!E\\JfJ) tit A '1 ,,990 eomm\SS\Qt\ &1AL'~ 011 &. Gal ~ona. ~ ~. Attach ment ARca Alaska. inc. is a Subsidiary of AI!3m¡cRich!ieldComp~ny I REQE\V£U tAÄ'( 1 1990 Alaslla 011 & Gas cons. commissIon Anchorage { C 1450 00266000 . 00267000 3C-02 02921414 01/09/86 03/01/90 SEP ZONE FOLLOWUP A&C SS A 1200 00270000 C 600 00280000 00290000 ..____3F-12 02921493 07/05/86 11/15/89 SPINNER FOLLOWUP A&C SS A 3900 00300000 ;/' C 6400 00310000 00320000 ~3F-16 02921502 05/10/89 11/24/89 SPINNER FOLLOWUP A&C SS A 400 00330000 C 6600 00340000 00350000 /730-12 02921804 08/24/89 03/09/90 SPINNER INITIAL A&C SS A 450 00360000 C 1450 00370000 ~, ~ ARCO Alaska, Inc. ~~ ~". Date: August 11, 1989 Transmittal #: 7536 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-17 30-12 3H-11 3H-16 3H-18 3H-13 Kuparuk Well Pres sue Report Sub-Surface Pressure Survey Kuparuk Fluid level Report Kuparuk Fluid level Report Kuparuk Fluid level Report Kuparuk Fluid level Report 1-23-89 1-12-89 8-07-89 8-07-89 8-07-89 8-07-89 Sand 'A' #71605 Casing Casing Casing Casing Receipt ACknowledged: I.~' 2" '~' (( (" i . I 1: I" ì ,) ./, ",/ < . < "1 ~ -- t ,', , I ~~:~ Date: ------------ "-. /\ "v' It '1 (J' "I n, (" ·..·1-: ("'111{' ,. PI [1' ì' ,',. I { -....,. ,...) \1... I.. h·J ,. .J '.·t' ~ And~1)1 é1~lH DISTRIBUTION: BP Chevron Unocal Mobil State of Alaska D&M ........!. /.-.... ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk A TO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~~ ~~ Transmittal #: 7470 :,':'~ ~ ~..~ ß l '0' .¿" :.1..:...) Q'( a. "]a''''''a 0:1· .. . .. ....\ ¡ & Gas Cor.s. ('-m~is~: '\.' --.... dl.l ~d.J,; Ancj~orage Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. "" 3 0 -1 8 Sub-Surface Pressure Survey , 3 A - 0 3 Kuparuk Fluid Level Report --.. 3 A - 08 Kuparuk Fluid Level Report ~30-11 Kuparuk Fluid Level Report '-30 -1 3 Kuparuk Fluid Level Report ~ 0 -1 7 Kuparuk Fluid Level Report ~ B-1 4 Kuparuk Fluid Level Report 3 0 - 0 8 Kuparuk Fluid Level Report ~~. D - '" 3 H -1 0 Kuparuk Fluid Level Report ;¡.. ,...- ...... c n .0. I> Kuparuk Fluid Level Report ~3A-08 Kuparuk Fluid Level Report "'- 3 0 -1 2 Kuparuk Fluid Level Report ~ 30 -1 8 Kuparuk Fluid Level Report 2 B-1 4 Kuparuk Fluid Level Report "1 R - 0 2 Kuparuk Fluid Level Report 3 F - 1 6 Kuparuk Fluid Level Report "" 3F-16 Kuparuk Fluid Level Report '1 R - 0 2 Kuparuk Fluid Level Report ~ 1 Y - 06 Kuparuk Fluid Level Report " 2 T - 0 7 Kuparuk Fluid Level Report ~1 E - 2 5 Kuparuk Well Presure Report Receipt Acknowledged: 2-15-89 4-23-89 4-23-89 4-22-89 4-22-89 4-22-89 4-24-89 4-24-89 4-24-89 4-24-89 4-29-89 4-29-89 4-29-89 4-30-89 4-29-89 5-03-89 5-04-89 5-03-89 5-08-89 5-07-89 11-07-88 --------.------------------ DISTRIBUTION: D&M I rliiiíJU SAPC ~~~tQ Chevron Date: Mobil #64613 Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada ------------ Unocal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program _ Pull tubing Variance Perforate Other ..x. 5. Type of Well: 6. Datum elevation (OF or KB) Development ..x. Exploratory Stratigraphic Service 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1019' FNL, 2011' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1234' FNL, 1863' FWL, Sec. 22, T13N, R9E, UM At effective depth 1249' FNL, 1827' FWL, Sec.22, T13N, R9E, UM At total depth 1256' FNL 1811' FWL Sec. 22 T13N R9E UM 12. Present well condition summary Total Depth: measured true vertical measured 6712'-6732', 6678'-6702', true vertical 6666'-6686', 6632'-6656', Tubing (size. grade. and measured depth 2 7/8" J-55, 6.5# @ 6522' Packers and SSSV (type and measured depth) HB Packer 6448' FLVD SSSV 13. Attachments Description summary of proposal _ Convert well from oil roducer to water in·ector. 14. Estimated date for commencing operation - 1- 16. If proposal was verbally approved ~- ....... 2. Name of Operator Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 4071 ' 6924' .-.. N A¥)% '1C/7 !/,,(,t. r: "'-j 7. Unit or Property name Kuparuk River Unit 8. Well number -12 9. 4 11. Field/Pool Kuparuk River Field Ku aruk River Oil Pool 7005' feet Plugs (measured) 6956' feet 6875' feet Junk (measured) 6827' feet None Size Cemented Measured depth True vertical depth 1 6" 9 5/8" 175 Sx AS I 1 1 0' 1 1 0' 1 500 Sx AS III & 4 1 0 6 ' 4 1 0 1 ' 300 Sx Class G Top Job w/150 Sx AS I 360 Sx Class G 6957' 6908' 7" 6662'-6672', 6611'-6621' 6616'-6626', 6566'-6576' \oIf",;J ,,';' 1 ... t I :~~.l¿~j"~,~i vii C{ , (l-~.;: ¿ Hi H0..~ -;';i2 ¡\!lcr;·~-~:~ d8L~ 1784' Detailed operation program _ BOP sketch _ 15. Status of well classification as: Oil ..L ' Gas Suspended _ Name of approver Date approved Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title 'v").~ ~ FOR COMMISSI N USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test ^ Subsequent form require Date ) r :APproval N°'9 ~/ð <=f 10- iApproved Copy - Returned J-- ~o #, IJAIGmAL SrGNED BY LONNIE C. SMITH Commissioner r¡ "o.-,,"-~ f; Attachment to Application for Sundry Approval Kuparuk River Unit Wells 30-5,10,12,17 Conversion to Water Injection Service Wells 30-5,10,12, and 17 are currently oil producers, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to convert these four wells to water injection service. A Wireline BOPE will be used during the portions of the conversion procedure which require wireline work. Expected static bottom-hole pressures for each well are listed below. No workover fluid will be used during the conversion procedure. MIT's, as required by the State, will be performed on these wells prior to conversion, and the MIT form will be forwarded to the State upon completion. WELL Expected SBHP 30-5 2800 psi 30-10 2300 psi 30-12 2450 psi 30-17 2500 psi ~. 't .' 1 ....1 ..,-. . 4 3 2 , ,. ~ooo PSI ,.. WELLHEAD CONNECTOR FLANGE 2. ~OOO PSI WIRELIN[ RAMS (VAR&ABl[ SIZE) 3. ~OOO PSI 4 1/6" LUBRICATOR 4. ~OOO PSI 4 1/6" F'LOYt' TUBE PACK-orr HJRElJNE BOP EQUJPMENT ARCO Alaska, Inc. Is a Subsidiary of AllantlcRlchfieldCompany RECEIVED FEB - 6 19B9 A\aska OU & Gas Cons. Commission Anchorage ;4 ~\ ~ f ,"~) \. C ~~ ~t4 (..~ - r:¡ .. J>9 I ""). .:-'\. . ..~..,.._ a'," -- ~ ....~.J'~ ð ,,_ '_Y-- _>___"u.·~ ,.~_.,..,_~...--."" 6\ Ls "" 'r' \, <:..... ~. ARCO ALASKA, INC. P. O. BOX 100360 ANCHORAGE, AK. 99510 .../7trTN: ABV-100 " ~.../t\/ \~ f' \d ,j ~ ~ DATE:~~ RECEI1rE>Dfiy: -\ - ./.1fI ".;..~ . ....', ~ ~." , ."".~... .' .. . ., '.' -t, Al /f~. t.t· '1'; UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COpy OF THIS FORM TO: (at one foot intervals}ß~ .¡ ~ ,'\ '+ ",J ' ¡' l t') \)~ t ¡ ,. ",\ ~J Q <fm r .\ q NAME: KRU 30-12 NUMBER OF BOXES: , j.¡¡i- r ,0.. ç J " $v~ G s ~ q " l,~ v f "~-'" .~ I 1("" _ l \f-.J b¿j·~ (, ~ (~ / n qq (} V I . five DATE: February 6, 1989 AIRBILL #: nla AFT#: nla CHARGE CODE# TRANSMITTAL ~~ ~~ --- SENT BY: TERESA GORUP 6549' - 6559' 6562' - 6588' 6592' - 6746' 6750 - 6767' State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Ak. 99501 AUn: John Boyle OPERATOR: Arco SAMPLE TYPE: core chips SAMPLES SENT: SAMPLE / I ARCO Alaska, Inc. I I Post Office Box 100360 ; Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .At- ~, STATE OF ALASKA ALASKA ÒIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ ~ 1. Status of Well Classification of Service Well ~~ OIL ø GAS 0 SUSPENDED 0 ABANDONED 0 SERVICE 0 2. Name of Operator 7. Permit Number ARrO Al.1c:;.k.1 In,.. 88-41 3. Address , 8. API Number D n Q,,~ 1nn-:>.c.n AI( aac:.1f'\_f'\-:>rf'\ 50- 029-21804 4. Location of well at surfac~ ';:}' :J 9. Unit or Lease Name 1019' F~L, 2011' FWL, Sec.22, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1234' FNL, 1863 ' FWL, Sec.22, T13N, R9E, UM 30-12 At Total Depth 11 . Field and Pool 1256' FNL, 1811 ' FWL, Sec.22, T13N, R9E, UM Kuparuk River Fi e1 d 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Oil Pool RKB 59' ADL 25513 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date COITJP., Susp. or Aband. 115. Water Depth, if offshore 116. No. of com~letions OS/23/88 06/02/88 {;7/t~ 1ft' ~0188* {rf L' N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MDtTVD) 19. Directional Survey 10. Depth where SSSV set 21. Thickness of Permafrost 7005 'MD/6956 'TVD 6875'MD/6827'/TVD YES{2 NoD 1784' feet MD 1700' ( aoorox) 22. Type Electric or Other Logs Run LSS/GR/DIL. LDT/CNL/GR/CAL D I LlGRISP ISFI ForI rNI rAI r.R rRTr,c:r 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 h" h1 r:..it I-I-Ú.n <::....+ 11 n, " I. " 1'7r:: ,"v AC I q-C;/R" ':). e:; nit I-r:..r:.. <::....+ I. 1 n c. , 1 ,,_ 1 11." 1 r::nn '" ~ A <:: I I I II. '2 nn ,,~ " ~. _ r --.- ,- . - - - ~ T_ . .1.. /1 r::n AC I 7" ?e:; nit I-r:..r:.. <::....+ 0_1 /"" . r -' c.ac:.ï' '2c.n '" v r, '" '"" r II. 1 Ie: _ ~ AC 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) Perforated w/8 spf, 45° Phasing 2-7/8" 6522' 6448' 6712'-6732'MD/6666'-6686'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Adde dum, dated 10/26/88, for Fracture data 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD. F low Tubing Casing Pressure CALCULATED 01 L-BBL GAS-MCF WATER-BBL OIL GRAVITY·API (corr) Press. 24-HOUR RATE. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached core description. ECE1'VED ~ A ~\~ j(fJ ~('. Î"" J -..¡.¡ " .¡,... NOTE: Drilled RR 6/3/88. Perforated well and ran tubing 6/26/88. Jilaska Oil & Gas COns.. Commission Fractured well 9/30/88. ¿ ~!i9;' ~ : Anchorage Form 10-407 Rev. 7-1-80 WC5/082 CONTINUED ON REVERSE SIDE Submit in duplicate r ;/ I"i'", ."'..- .!.~, ":'::¡'!~ .;"\'.: . . ---( 1 29. ..,- 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested. pressure data. all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6586' 6541' N/A Base Kuparuk, C 6619' 6573' Top Kuparuk A 6651 ' 6605' Base Kuparuk A 6761' 6714' 31. LIST OF A TT ACHMENTS Addendums (dated 08/10/88 & 10/26/88)~ Core Descriotion 32. I hereby certify that the foregoing is true and Correct to the best of my knowledge I s¡gnedf 5 ~~y Area Drilling Engineer ///23/ B 9 Title Date // 1 -- 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 iniection, 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: I ndicate whether from ground level (G L) or other elevation (DF, KB, etco). 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 I njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA, INC. CORE DESCRIPTION CORE #1 6549' -6560' CORE #2 6562'-6588.4' CORE #3 6592'-6616' 6616'-6623.8' 6623.8'-6651.7' CORE#4 6652'-6713.8' CORE#5 6713.8'-6746.8' CORE #6 6749.8'-6766' 6766'-6767.5' rr· KRU 30-12 SEC. 22, TI3N, R9E, UMIAT Shale, dark grey to black, very hard, silty, some siderite cemented zones. Shale and siltstone, dark grey, some siderite cemented beds and lenses. Siltstone, dark grey, some siderite cemented beds and lenses. Sandstone, very fine to coarse, bioturbated, glauconitic, pebbly near the base. Patchy siderite cemen 1. Wavy and lenticular bedded very fine-grained sandstone interbedded with dark grey siltstone and shale. Oil stained sandstone near top of interval. Interbedded very fine-grained sandstone, siltstone and shale. Sandstone oil stained. Siltstone and shale medium to dark grey. Lenticular to wavy bedding. Sandstone quartzose with fair to good porosity; well indurated. Same as above, sparse ankerite cement. Same as above, sparse ankerite cement. Shale, dark grey, some siltstone lenses, thinly laminated, very hard. 'T .- ADDENDUM -------- WELL: 30-12 7/24/88 R/U hot oil. Test to 4000 psi. Pump 21 bbls diesel w/ 5% Musol at 1~ bpm, 2400 psi. Pump 22 bbls cln diesel at 2 bpm, 2900 psi. Pump 22 bbls hot diesel @ 2 bpm, 2900 psi. Displace to 1 bbl above top of perfs. 7/26/88 Arctic Pak well wi 175 sx ASI. ~ðCo ~ ¡j {)J~rP Dg"te ,. WELL: 9/28/88 thru 9/29/88 'f ADDENDUM -------- 30-12 Data frac well as follows: RU hot oil unit. Pmp 21 bbls diesel w/5% Musol, followed by 44.5 bbls cln diesel @ 2 BPM, 3100 psi. RU Howco tree saver. RU DA WL. Pressure tree saver & WL lubr to 7200 psi. Att to GIH w/temp/CCL downhole pressure recorder;'would not pass thru tree saver. Chg tIs, drop off CCL & temp tl, pmp down hole pressure tl thru lubr w/Howco. GIH, spot tIs @ 6610'. Stage 1: Start pmp'g slick diesel @ 17 BPM, 6900 psi w/final rate of 7100 psi. Total of 200 bbls pmp'd. Stage 2: Pmp diesel w/8 gal/1000 gal My-T-Oil II @ 20 BPM, 6500 psi. Total of 150 bbls pmp'd @ final rate of 5130 psi. Stage 3: Pmp 50 bbls 8 gal/1000 gal My-T-Oil II @ 20 BPM, 5100 final rate @ 20 BPM. Stage 4: Pmp 200 bbls 16 gal/1000 gal My-T-Oil II. Pmp 1st 30 bbls @ 10 BPM, 3850 psi. Slow rate to 3 BPM, 3620 psi for next 14 bbls, and inc pmp rate to 20 BPM, 5350 psi. Switch to slick diesel, displ tbg @ 20 BPM, 5300-5730 psi (total 44 bbls slick diesel). Stage 5: Pmp 200 bbls 8 gal/1000 My-T-Oil II w/40#/1000 gal silica flour as follows: Pmp 44 bbls @ 10 BPM, 3950 psi. Inc rate to 20 BPM, 5010 psi w/final pressure to 5060 psi. Witch to slick diesel (44 bbls). Displ @ 20 BPM, 5140-5250 psi. Stage 6: Pmp 200 bbls 16 gal/1000 gal My-T-Oil II w/40#/1000 gal silica flour as follows: Pmp 44 bbls @ 10 BPM, 3920 psi. Inc pmp rate to 20 BPM, 5400 psi f/next 156 bbls. Witch to slick diesel. Displ @ 20 BPM, 5450 - 5350 psi (44 bbls). Release w/rams. POOH w/DA WL & pressure recorder. Hung up in SSSV. Cycle SSSV several times. Bleed dn tbg pressure. Wrk thru SSSV, POOH. RD tree saver; lost pieces of tree saver cups. RU WL lube PU temp tl/CCL, GIH, log 5 passes from 6520'-6842', POOH. RD DS. Secure well. ~ ...-, ì --. ADDENDUM -------- WELL: 30-12 9/30/88 Frac Kuparuk "A" sand perfs 6710'-6730' in 10 stages perf procedure dated 9/30/88. Stage 1: Pmp 150 bbls gelled diesel @ 20 BPM, 6870-5650 psi. Stage 2: Pmp 625 bbls gelled diesel @ 20 BPM, 7000'-4600 psi. Stage 3: Pmp 45 bbls gelled diesel, 2 ppg, 1620, 20 BPM, 4590-4470 psi. Stage 4: Pmp 50 bbls gelled diesel, 4 ppg, 20 BPM, 4470-4450 psi. Stage 5: Pmp 60 bbls gelled diesel, 6 ppg, 20 BPM, 4450-4300 psi. Stage 6: Pmp 65 bbls gelled diesel, 8 ppg, 20 BPM, 4300-4650 psi. Stage 7: Pmp 70 bbls gelled diesel, 10 ppg, 20 BPM, 4650-5340 psi. Stage 8: Pmp 40 bbls gelled diesel, 10 - 11.7 ppg, 20 BPM, 5340-6200 psi. (Go to flush before final stage ramped to 12 ppg.) Stage 10: Pmp 43 bbls gelled diesel, 6 - 15 BPM, 3400-6200 psi. Lost prime bypassing tub rate dropped and unable to obtain rate of 20 BPM again. (Note: All proppant 16/20 carbolite) ~Jl/ ~£ Drilling Superviso 10 h.~ / 'fig , Date I~ I -.. 11) ll'¿' ¡(IT) ~ ~AGE 1 OTIS ENGINEERING 5708 OLD WEST YELLOWSTONE~ MILLS (307) 472-1164 SUB-SURFACE PRESSURE SURVE¥ka co. ARCO ALASKA EFF DEPTH CASING LINER DATE 890109 ELEVATION MAX TEMP PERF TUBING UNITS ENGLISH RUN 01 FIELD KUPARUK WELL 3012 WELL STAT FLOWING TOOL HUNG 6487 RKB CASING PRESS ON BOTTOM 1200 01/09 TUBING PRESS OFF BOTTOM 0900 01/12 ELEMENT RANGE o - 4132 ZERO POINT ZONE SHUT-IN 1830 01/09 PICK-UP ON-PROD CAL SER NO. 71605 MPP PURPOSE FLOW/BUILD UP/FLOW SURVEY DATA co. ARCO ALASKA RUN 01 FIELD KUPARUK WELL 3012 TIME P-T DP-DT DTIME TIME P-T DP-DT DTIME ø 0:30 2557.40 1lI.00 1lI.1lI0 8:00 1732.48 -824.92 7.5Ø =ltJÄl- Ø:35 2371 .00 -186.40 .08 8:30 1745.31 -812.Ø9 8.0Ø S ttH P 0:40 2220. 13 -337.27 .17 9:00 1769.27 -788.13 8.50 ç,o", 0:45 2138.77 -418.63 .25 9:30 1779.84 -777.56 9.00 p~"" 0:50 21Ø9.68 -447.72 .34 1Ø:00 1784.43 -772.97 9.5Ø Ø:55 2Ø75.Ø1 -482.39 .42 1Ø:3Ø 1791.71 -765.69 11l1.ØØ 1 :øø 2Ø43.45 -513.95 .50 11:ØØ 1787.65 -769.75 10.5Ø 1 : Ø5 2Ø15.61 -541.79 .58 11:30 1785.86 -771.54 1 1 . IlIØ 1 : 1Ø 2ØØ1.8Ø -555.6Ø .67 12:ØØ 1782.22 -775.18 11.50 1:15 1988.40 -569.0Ø .75 12:30 1781.25 -776.15 12.0Ø 1 : 2Ø 198Ø.99 -576.41 .83 13:3Ø 1772.73 -784.67 13.ØØ 1:25 1956.Ø5 -601 .35 .92 14:30 1766.67 -790.73 14.0Ø 1 : 30 1943.68 -613.72 1.ØØ 15:3Ø 1755.27 -8Ø2. 13 15.ØØ 1 : 45 1922.27 -635. 13 1 .25 16:3Ø 1748.8Ø -808.60 16.Ø0 2:ØØ 1816.78 -740.62 1 .50 17:3Ø 1741.11 -816.29 17.00 2: 15 1779.32 -778.Ø8 1 . 75 18:30 1 737 . 12 -82Ø.28 18.ØØ 2:3Ø 1761.Ø2 -796.38 2.ØØ 19:3Ø 1727.98 -829.42 19.00 2:45 1735.1Ø -822.30 2.25 2Ø:30 1722.34 -835.06 2Ø.0Ø 3:ØØ 1741.31 -816.Ø9 2.5Ø 21:30 1717.11 -84Ø.29 2 1 . øø 3: 15 17Ø7.57 -849.83 2.75 22:30 1712.5Ø -844.9Ø 22.ØØ 3:3Ø 1699.57 -857.83 3.00 23:30 1659.51 -897.89 23.0/z) 4:ØØ 1687.28 -870.12 3.50 0:30 1610.44 -946.96 24.ØØ 4:30 1669.43 -887.97 4.00 1 : 30 1512.19 -1045.21 25.Ø0 5:ØØ 1663.94 -893.46 4.50 2:30 1463.76 -1093.64 26.00 5:30 1661.53 -895.87 5.ØØ 3:30 1485.70 -1071.70 27.ØØ 6:00 1646.57 -91Ø.83 5.5Ø 4:30 1537.27 -1020. 13 28.ØØ 6:30 1654.66 -902.74 6.00 5:30 1588.Ø2 -969.38 29.ØØ 7:00 1647.73 -909.67 6.5Ø 5:45 1594.44 -962.96 29.25 7:3Ø 1720.26 -837.14 7.00 0:ØØ 0.00 Ø.0Ø 0.0Ø COMPLETE WELL NAME: KUPARUK 30-12 BEGINNING SURFACE PRESSURE BY PRESSURE GAUGE WAS 2Ø0 PSI BEGINNING SURFACE PRESSURE BY ELEMENT WAS 234.4 ENDING SURFACE PRESSURE BY PRESSURE GAUGE WAS 4ØØ PSI ENDING SURFACE PRESSURE BY ELEMENT WAS 404.7 BEGINNING FLOW PERIOD AND BUILD UP WERE TO STAIRSTEPPED TO READ ~ . . ~. .- - ... - 1 P{;i3E - ,-- OT I S END I NEE~-:;~ I NG 5708 OLD WEST YELLOWSTONE 1"11 LL~3 . ~JY ( 3Ø'7 ) 472--1164 $ u l~_-::.êll n E AG~~.__E:.f3.£~_ê.§!JE~~_ê.. U F: \.~~[ ØØ/09 Ø0/23 09 I 2Ø WELL 3012 TOOL HUNG 648 ON BOTTOM 12: OFF BOTTOM Ø9: ZERO POINT SHUT-IN 11 ON-PROD MPP KUPARUk FLOWING o - 4132 71605 -·V RUN 02 FIELD WELL STAT CASING pnESS TUBING PRESS ELEMENT RANGE ZONE PICK-UP CAL SER NO ALASKA 090989 160 ENGLIS~ CD. AF:CO EFF DEPTH CASING LINER DATE ELE\,IA T I ON M?'~X TEMP PE!:':F TUBING UNITS PUF~~PO~3E DTIME 11.50 12.50 1 ~::: . 50 14.50 15.50 16.50 1 7 . 5'0 18.50 19.50 20.50 21 . 50 22.5Ø 2~~:: . S0 24.50 :~5 .50 26.50 27.50 28.SØ ~:~~~ . 5Ø 30.00 :;~ l·J E L. L.. :~:; 0 1 DP--DT 756 . 9~:5 764. 12 770.B7 776.79 782.51 788 . 8~) 79~'::; . ~.::;:.~ 79'-7.66 804.76 808 . ¿¡ 1 809.36 814.46 818 . ::~;2 821 . 76 82::::;.96 827 . 19 832.29 832.4:.2 83~=j . 45 83~5.. 51 fiJ}.B~~J~.Y._J2f.fr.B. ~:::UPAF:Uk TIME P-T 23:00 2474.81 Ø::Ø02481.98 1:00 2488.73 2:0Ø 2494.65 3 : øø 2500. ::::7 4 :: øø 2~)Ø6. 71 5:00 2511.18 6:Ø0 2517.52 7:0Ø 2522.62 8:00 2526.47 9:: 0Ø 2527. :~2 1 ø : 00 2532. ~'::'2 11 : 0Ø 2536. 18 12:00 2539.62 13:0Ø 2541.82 14:Ø0 2545.05 15:0Ø 2550.15 16: Ø0 2~.55Ø. 28 17: øø 2553. ~~; 1 17:30 2553.37 F:UN 02 FIELD DTIME 0..ØØ ..03 .28 7r.: . ._\...J -¡ ¡:;:" " j' \_t .7B 1 .30 1 . :34 1 '-'-7 .0, 1 .89 2. 17 2.50 3.5Ø 4.5Ø 5.5Ø t,.50 ';7 . 5Ø B.5Ø l::¡ . ~5 e~ 10.50 ~'::;0··-·12 DF'-'DT 0.Ø0 217.59 220.72 3:38.92 347.02 445..08 4~;2 . ~'::'7 528 . 1 9 5:33 . L~2 559.87 ~.;68 . 80 589.51 6~'::;2 .. 84 662.96 679.84 696.72 713.19 724.91 7::::;6.0Ø 748.55 ~:::UPAF:Ut: CD. ?~¡:;:[:O ALt=:ìSKA T I ME F'- T 11 : 30 1 7 1 7 . Est.) 11 : 32 19~~5. 45 11 : 47 1 9::::;8 . 58 11:51 2056.78 12:15 2064.88 12:17 2162..94 12:48 2170.23 12: 50 2246. 0~) 13:22 2251.28 13:23 2277.73 13: 40 2286. bt.¡ 14:00 23Ø7.37 15:0Ø 235Ø.70 16:0Ø 2380.82 1 7 : øø 23971. 7~?! 18:Ø0 2414..58 19:ØØ 2431..05 20:ØØ 2442.77 21 : øø 245:3.86 22:00 2466.41 COMPLETE WELL NAME FILE #02t:::U3012 ínl' 1,1 ¡ill 'I" 'I i:, -...... ¡ ¡I ¡ !ii dH ¡ii¡ I!.: li: ¡Ii! ¡ U! !:T i ¡ ¡ rf t ,:; ;¡ ¡ j tt j : ¡ I I j , ; .' I II ¡' '¡ d; ¡ ¡: :¡ !, ! ¡ :, ; !¡ '" ¡ , , : ¡¡ 1: ¡:if it; iit ,it: :--± -l t . ~ t-- .11 ! : ! ,! ir dd .'" ..,. t tl t" .¡;, .... '''. it n:¡ ~¡ H ,; f' . ft ¡ It ¡f ¡ ¡ d ~ ! ¡ ¡ r¡ d ¡ j \ i it t I! ¡I fit!; ¡ 11 ¡ t ! !, n, i, .,; ; .." ,i, , t¡ t ¡'j 'I I, ,if I 'I I f I ¡ ,,¡ it,,!, ,,¡ ¡ . , , ' ill, ¡I III "I, \ :1' ¡I!! it;; . .. t (i I : ¡ ,: ;;; ¡ ,¡i, t" ¡ r": ¡ 1 I If! -!IIi I! 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' ,j' ¡ ; ¡ i t t · t t ¡ t i ¡ j' . f ! i! ! i Ii q ,J ¡ t i t it 1. nl tit ¡ 1: ¡ f ¡:: t :;::,:::: .... :::: H d¡ i"rf t if:¡f "ii", 'i! ¡ d t+ + 1f·h¡;-¡¡ T ";1 ;.......1 d.. .... ..._ .... tit ¡ U r ¡ II ! t ¡ ¡ I¡ ¡ II ! ¡¡ ¡ ¡¡¡¡I HI :ìil: 111 ; t £ HF ~rp1Jtit¡_:; ¡i] l ~~·.:l; ;,..,...; .... :::: :::: ¡:::: 1 ¡ 't ¡ ¡ I t ¡ If, ff'f ¡'1 !irf!! tIt ¡Ht I+-dlnt!;;: ;)I."r ,:¡: .'+_ ....¡.... t 1111 I!l! UII !Ii 'HI tJlilil ¡WI 1111 IT ¡Ulli ¡¡ !!! ¡Ii Iii i H¡¡!JIillil Hf in¡ ¡¡fJ h¡l)! 1i1¡!J.i{ Hn ::::::: ::;:: ..:: I! III; HJ¡¡'II!i!¡I!¡I!! fìl ¡¡¡'UIII¡lj,! ¡í¡ 1H HJlli!t!¡ It WI! i1Lt.LUJlJ~;; ! ;ft;, !i.) n,¡ttUì! :,n It i¡!u..~¡¡: 1:;; t.:,:,: i,:::,::::,: "'.. .... ::::1:::: ¡¡f1Lq :tH Hftt In Ifi ~11Ì:¡ H Ht ,'.tH~¡;m1Û1 ,it t\.UJllJJ~ Pit :n: ;¡Ü p-HHn rt1 tt- -trDnir tin i:;: !J::¡:::: q.. "H ::::i:::: utJ~.:f~t~¡UH~h·t$ht:tjl It U,'P,'t-U 'U',' ~,~,. Il d·t ~Hi JJt1,IH'tt¡lHi [~t,l, ~ftl,t' ·U,1" "f.1rH1~ H, .,i,lltiIT ,F1t lµ¡Ji~¡ATt ~ti ~.iH ~¡¡iL ¡:n U ¡ :,.¡I;: ¡ .¡:;, . :,,:-. i, :., .:::::::: 1400.0 1ttt4·r:.++ttttµ. :tt:t t+++:fH' tlhHt~+¡+·hH-+...rhp "+r~HHttt...¡~tTti tÞ.tl1'.±.itF-t=M, j:++:~tti:trtt¡:t¡¡rrt¡:¡::.¡:;:-:í:...;:.... :::: I 0.0 4.0 8.0 12.0 16.0 20.0 24.0 28.0 32.0 BAKERSFIELD, CA (805) 589-2768 10 x 10 TO 112 INCH 6 x 9 INCHES 2800.0 .. [' r -- r n- -T r' n t i , J ¡Tn '1l ¡ ¡ í "iT TT¡T I I r /1 I I II ¡ ¡ t ¡ \ ¡ ~ r .} I I \ :1 I ¡ I - . 2400.0 i ¡ I ¡ I ¡ t l ¡ t i ! I ~ l ¡.. - 2200.0 ...., I I .. ! I I 2000.0 1800.0 1600.0 ! ¡ '¡ ¡ 1 :! t I' I j ¡ i ~ J' i'ì j j Ii I +~¡ ) ¡I I :ij: i11 ~hHL .I It rt :td IN f- -!- .tj/t'-ÎtJH¡¡· I¡ lj! ¡ ,¡,I¡.1 11 It tI¡1 .Lt'. ¡ t ¡¡¡iHn ¡¡i¡ It t ¡tU~tfÍ¡f¡ In 't ARca ALASKA KUPARUK 30-12 n~ /fìC1-1~/RQ t HI; ¡ ¡; ¡ ¡ ) ¡ ~: it : ' ; : tt:¡-t¡ :;; i It FTI F #01Ktl:1012 2600.0 2400.0 2200..0 2000.0 ( 1800.0 1600.0 0.0 " 1". ,~ ~ ":""'~_~" ,"',., :- ~ , ...~-_.. I", -",,\,' _..__ BA_~~~SFIELD, CA (805) 589-2768 10 x 10 TO 'h INCH --- 6 x 9 INCHES P·::: :::!":.: ::::: ~..:.¡:.:.. ~---. - - _. ...- - -<--- -- . . . . . ., . . . ¡. .. .., .. ,,! . ". -.' ....,... .' .... j ..... '-..... .....- ---...---- "'" .,..,.;. . ., .' .. . . . I' . . t'...:L; H"': ¡ . \. . . t· !:::. ._-~~ - ¡::: ¡ . ¡ ..¡ "!~' -¡.. I : I . i . 1-. r ! I ~l ·····H-I: ... ' ... . ,. . ................. ,. . 4.0 8.0 12.0 18..0 20.0 24.0 28.0 32.0 ARC a ALASKA 09/09-23/89 KUPARKU 30-12 FILE #02KU3012 Date 17-JUNE-88 ComDuted By: KRUWELL Loaaed By: WARNER Job Reference No. 72850 Company ARCO ALASKA, INC. Well Name 30-12 (1019' FNL, 2011' FWL, SEC 22, T13N, R9E. UM) Field/Location KUPARUK. NORTH SLOPE. ALA_SKA )D {''l/tTb @] UIDANCE @]ONTINUOUS mOOL SU8·SURI'ACB DIRBCTIONAL SURV.Y -- ¡, ~ ~ METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: 1- *******************. * * * * ******************** * * . SCHLUMBERGER * * * ******************.. " GCT DIRECTIONAL SURVEY CUSTOMER LISTING ) FOR ARca ALASKA, INC, 3 0-12 KUPARUK NORTH 5LOPE,ALA5KA SURVEY DATE: l1-JUN-S8 ENGINEER I D. WARNER TANGENTIAL- Averaged deviation and azimuth IJINEAR HORIZ. D15T, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 28 DEG 26 MIN WEST COMPUTATION DATE: 13-JUL-88 PAGE 1 AR8Q ALASKA, INC, DATE Of' SURVEY: 17-JUN-88 3 -12 KELLY BUSHINC ELEVATION, 59,00 rT KUPARUK NORTH SLOPE,ALASKA ENGINEER I D,' WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH MEASURED TRUE sua-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, D~PARTURE VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DlST, A 1MUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FEET FEET DEe; MIN o 00 o 00 -59.00 0 0 N 0 0 E 0.00 0,00 0,00 N 0,00 E 0,00 N 0 0 E ~OO:OO 100:00 41 00 o 25 S 76 38 W 0.20 0.23 o 07 S 0,30 W 0,)1 5 ,¡ 20 W 00 00 200,00 141:00 o 30 S 74 28 W 0.77 0.08 0:29 S 1,09 w '·ð~ 5 1 9 W 300:00 299,99 240,99 o 36 S 71 17 W ~.4S 0,18 0,55 s 2,02 w S 't 36 W 400,00 399.98 340,98 o 37 S 68 29 W 28 0,05 o 94 :; 3,06 W '20 S 153 w 500,00 499.98 440.98 o 33 5 63 20 w 3'A2 0,07 1'39 5 3.99 W 4'23 S 70 51W 600.00 599.97 540.97 o 30 S 68 50 ~ )' 8 0,16 1:80 S 4 83 W 5'16 !~~ ~5 ~ ) 700,00 699,97 640,97 o 21 5 86 22 W 4'31 O,l~ 1.91 S 5'S1 W 5'84 800.00 799,97 740,97 o 20 S 72 17 w 4'69 o 2 2.03 5 6:10 W 6'43 S 'I 3~ II 900,00 899,97 840,97 o 34 5 '5 32 w 5:26 0:32 2.25 5 6.89 w 7:25 S, 54 W 1°00,00 899 96 940.96 o 37 5 66 51 W 6,10 0.07 2 65 S 7.9~ w 8,35 S 71 30 W toO 00 1 99:95 1040,95 o 41 S 71 10 w 6.94 0.13 3:03 s a 9 w 9 47 S 'å 18 W 1200:00 1199,95 1140,95 o 4~ 5 63 24 w '.90 0,31 3.51 S 10:~O w 10:69 s, 50 W 1300,00 1299,94 1240,94 o 3 5 61 17 W 8"A 0,01 3,98 5 10 * w ì~·g~ S 70 2 W 1400.00 1399.94 1340,94 o 34 5 51 52 W 9 5 O'à4 4'Så S 11:7 w S" 4 W 1500,00 1499.93 1440,93 o 31 5 53 1 W 10:44 o 7 ~'~3 5 12.5~ W ]'51 S 6 48 W 1600,00 1599 93 1540.93 o 33 S 41 1 W 1~.33 0'17 S 13 2 w 14:41 8 66 3) W 1100,00 1699'92 1640.92 o 27 5 25 30 W 1 19 0'19 6'47 S 13:65 w 5 11 S 64 3'7 W 1800.00 1799:92 1740.92 o 20 S 4 6 E 12:89 0'65 7'15 5 13,86 w 15: 0 S 6i 42 W 1900,00 1899.92 1840,92 o 44 N 88 0 [ 12,85 0:70 ':44 5 13,24 W 15,19 8 ,. 40 W ~ooo,oo 1999.91 1940.91 o 48 N 78 54 E 11,96 0.21 7,18 S 11,86 \r; 1~.87 & 58 48 w 100 00 2099,90 2040,90 1 6 N 72 50 E o 96 0,73 6,90 S 10,26 w 1 37 S 56 4 W 2200:00 2199,87 2140,87 1 14 N 59 19 E 9'22 o 15 5,96 5 8.36 W 10:27 S 51 30 w 2300,00 2299.84 2240.84 1 36 N 64 39 E 7:28 o'so 4,86 S 6,30 W ',96 S 5 20 W 2400.00 2399.79 2340,79 2 6 N 70 56 E 4.71 0'57 3.62 S 3.2~ w 4,84 S 4 33 W 2500,00 2499.70 2440,70 3 6 N 73 10 E 1,67 1'36 2.34 S 0.8 E 2,48 S 1 14 E 2600,00 2599.50 2540,50 3 55 ~ 73 42 E -2.76 0:89 0.56 5 6 83 E 6 85 S 8t 20 " ~'00,OO 2699,22 2640,22 4 37 N 72 4 E -8.~0 0,61 1,66 N 13:95 E 14:05 =, 11 *00 00 2798.87 2739.87 5 1 N 72 27 E -14. 1 0,54 4,26 N 21,98 E ~2,39 t, 2 00:00 2898,46 2839.46 5 13 N 74 8 E -20,S4 0,15 6,81 N 30,57 E 1,32 N '7 2 E 3000.00 2998,05 2939,05 5 11 N 75 40 E "~6.83 0,46 9,18 N 39,39 E 40,45 H 76 53 E 3100,00 3097.64 3038,64 5 6 N 75 21 E · 2,85 0,35 11,37 N 48,01 E 49.34 N '76 40 E 3200.00 3197.24 3138.24 5 7 N 76 54 E -38.92 O,~3 13.55 N 56.71 E 58,31 N '76 33 ! 3300,00 3296,85 3237.85 4 59 N 77 58 E ·44.69 g't! 15,45 N 65,3~ E 61'11 N '76 41 E 3400.00 3396.5~ 3337.51 4 15 N 79 53 ~ -49.91 11,04 N 13 J E 'J 2 N 'I 55 E roo.oo 3496 1 3437.~9 4 32 N 85 24 E -54.66 0'49 18,13 N :~: 1 E 8 : 31 H' 25 [ 600.00 3595:89 3536, 9 4 29 N 87 9 E ·58.82 0'48 18.62 N 96'~6 E 91.08 t ~I u E 700 00 3695.58 3636.58 4 26 N 87 24 E -62,83 0'30 18,95 N E 98 79 [ 3800:00 3795.29 3736.29 4 19 N 88 22 E -66.74 0'27 19,23 N 104:65 E 10~:41 N '7 35 E 3900,00 3895,00 3836,00 4 11 N 88 38 E -70.46 0:68 19,44 N 112,09 E 11 .76 N 8 9 E ~ COMPUTATION DATE: 13-JU¡"·S8 PAGE 2 ARCa ALASKA, INC. DATE OF SURVEY: 1?·JUN-88 3 0-12 KELLY BUSHING ELEVATION, 59,00 rT KUPARUK ENGINEERS D. WARNER NORTH 5LOPE,ALASKA INTERPOLATED VALUES FOR EVEN 100 FEET Of MEASURED DEPTH TRUE SUa-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORtZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/wEST DlST. A¡IMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEf~T DEG/l00 FEET FEET fEET D G MIN 4000,00 3994,76 3935.76 4 1 5 87 7 E -73,78 0,57 19,40 N 119'i1 E 120,68 N eO 44 E 4~OO,OO 4094.50 4035,50 4 17 5 82 59 E -76.65 0,38 18.76 N 126 3 E 127,72 N 8t33 E 4 00 00 4194.21 4~35,~1 4 20 5 79 51 E .79.30 0,71 17.69 N 133:88 E 135,04 N 8 ~8 E 4300:00 4293.92 4 34 2 4 17 5 77 33 E -81.48 0,13 16.18 N 141.23 E 14i'16 N 8 1 E 4400,00 4393.64 43 4:64 4 22 S 75 24 E -83.50 0,70 14.49 N 148.61 E 14 2 N 8! 25 E 4500.00 4493.34 4434.34 4 46 S 3~ 9 E .82.98 4,70 10,46 N 154 9 E 155:32 N 8 8 E 4600,00 4592.79 4533.79 7 31 S 30 W -74.51 4.15 o 35 N 155:85 E 155.85 N 852 II' 4'00,00 4691.54 4632.54 10 33 S 23 45 W -59,34 4,55 14:67 s 151.72 E 151,43 S ~f 28 ) 4800,00 4789.41 47~O.41 2 38 S 36 24 W -38,87 3,08 32,30 5 141.29 E 14 93 S , ~ 4900,00 4886,74 48 7,74 13 35 S 49 32 W -16.85 1.36 48.18 S 125.48 E 134:63 S 68 45 E 5000,00 4983.89 4924,89 13 48 S 50 13 w 5.13 0.30 63,87 5 107,20 E 123,79 S 5X 12 E 5~OO,OO 5080,96 5021,96 13 58 S 49 48 W 27,47 0,32 79,31 5 88.80 E 11 . 06 S 4 13 E 5 00 00 5177,97 511 .97 14 6 S 49 5S W 50,09 0,17 94 98 S 70,23 E 118:å2 s ~6 28 E 5300:00 5274.94 5215.94 14 12 S 50 9 w 72.82 O.~9 1~0:69 s 51,50 E 122 9 S 4 56 E 5400,00 5372,02 5313.02 12 26 5 51 59 W 94 98 4 5 1 5 89 S 33.02 E 130:14 S 14 41 ~ 5500,00 5470,32 5411,32 9 46 S 62 58 W 110:85 0:38 135:61 s 17,65 E 13~.75 87 24 5600,00 5568.85 5509,85 9 49 S 63 1~ W 124.89 O,!7 143.32 5 2 39 E 14 34 S i 57 E 5700,00 5667,39 5608.39 9 50 S 63 2 w 138.89 o 6 150,99 5 ~2:84 w 151:54 s 51 W 5800,00 5765.90 5706,90 9 57 S 63 39 W 152,94 0:15 158,65 5 8 ~o w 16~'à4 S to 4W 5900,00 5864,38 5805,38 10 9 S 63 52 W 167.17 0,25 166.36 5 43: 4 w 17 , 4 8 4 45 W 6000,00 5962,77 5903.77 10 23 5 64 0 W 181,69 0,30 174,20 5 59,86 W 184.20 S 11 57 II 6100.00 6061,10 6002,10 10 35 5 63 56 W 196.48 0,33 182.17 S 76,20 W 19'7,47 I 2 4A = 6200,00 6159,38 6100.38 10 33 S 64 28 W 211.47 0,50 190,24 S 92 80 W ~t~·~6 6300.00 6257.84 6198.84 9 31 5 65 16 W 225,55 0,82 197,65 5 108:66 w 2 8'71 s ¡ 48 W 6400,00 6356,52 6297.52 8 56 S 65 43 W 238.47 1,36 204,39 S 123,35 W S Ii 6 II 6500,00 6455.43 6396.43 8 10 5 67 21 w 250,07 0,79 210.~6 5 136.89 w ~2~:~~ I 41 = 6600,00 6554,45 6495.45 7 58 S 67 48 W 260,86 0,54 215 9 S 149.88 W 6700,00 6653,51 6594.51 7 48 5 66 39 W 271,57 0,23 220:86 s 162,46 w 2'74:17 S 16 20 6800,00 6752,60 6693.60 7 39 S 67 8 W 282,09 O,7~ 226,16 5 174.76 w 285.8~ ~ ¡ ~~ .. 6900,00 6851,71 6792,71 7 39 5 67 8 W 292.49 0,0 231,34 S 181,05 W 297.4 W 7000.00 6950,82 6891.82 7 39 S 67 8 W 302,89 0.00 236,52 S 199,33 ~ 309,31 S 28 7 w 7005.00 6955.77 6896.77 7 39 5 67 8 W 303.41 0,00 236.77 S 199.94 W 309.90 a 10 w , COMPUTATIQN DATE; 13-JUI"..88 PAGE J AReD ALASKA, INC, DATE OF SURVEY: 17·\1UN-88 3 0-12 KELLY BUSHING ELEVATION: 59,00 rT - KUpARUK ENGINEERI D, WARNER NORTH SLOPE,ALA5KA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SU8·SEA COURSE VERTICAL, DOGLEG RECTANGULAR COORDINATES HORtZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/toO FEET FEET FEET DEG MIN o 00 o 00 -59,00 0 0 N 0 o E 0.00 0,00 0,00 N 0,00 E 0,00 N 0 o E 1000:00 999'96 940,96 o 17 S 66 51 W 6 §o 0,07 2,65 5 7 92 W 1~:n s 'A 30 W 2000,00 1~99:91 1940.91 o 8 N 78 54 E 11: 6 0,21 7.18 S 1~:86 w S 5 48 W 3000,00 2 98 05 2939.05 5 11 N 75 40 E "26.83 0,46 9 18 N 3 39 E 4 45 N '8 53 ! 4000,00 3994:76 3935.76 4 1 S 87 7 E -73.78 0.57 19:40 N 119:11 E 120:68 N 8· 44 E' 5000,00 4983.89 4924.89 13 48 S 50 13 W 5 13 0,30 63 87 5 107,20 E 124,79 S 59 12 ! 6000,00 5962.77 5903.77 10 23 S 64 0 w 181:69 0.30 ~74:20 5 59 86 W 184,20 S 18 5' W ~ooo.oo 6950,82 6891.82 7 39 S 67 8 W 02.89 0,00 36 52 5 199:33 w 309,31 5 48 7 i 005,00 6955.77 6896.77 7 39 S 67 8 W 303,41 0.00 236:77 5 199.94 W 309,90 S 4 10 ) , ) ARca ALASKA, INC, 3 0-12 KUPARUK NORTH SLOPE,ALASKA DATE Of' SURVEY: KEL~Y BUSHING ELEVATIONI ENGINEERI PAGE 4 1,-"UN..88 59,00 " D. WARNER INTERPOLATED VALUES FOR EVEN 100 TRUE SUB..SEA MEASURED VERTICAL VERTICAL DEPT~ DEPTH DEPTH o 00 59'00 l59:00 '35;'81 4~9'O~ 559:02 659,03 '759.03 859,03 959 04 1059:04 1159,05 1259 06 1359:06 1459,07 1559,07 1659.07 1759,08 1859.08 1959.09 2059 10 2159:12 2259 14 2359:19 2459,26 2559.41 2659.65 2759.99 2860,37 1960,79 061,20 161 60 3262:00 3362 36 3462:68 1563,00 663.31 763 61 3863:89 o 00 59'00 159:00 259 00 359:00 459,00 559,00 659,00 759,00 859,00 959 00 1059:00 1159.00 1259,00 1359,00 1459.00 1559.00 1659,00 1759.00 1859,00 1959,00 2059,00 2159.00 2259.00 2359,00 2459,00 2559.00 2659.00 2759,00 2859,00 2959,00 3059,00 3159.00 3259,00 3359,00 3459.00 3559,00 3659,00 3759.00 3859,00 -59.00 o 00 100:00 200.00 300.00 400.00 500.00 600.00 700,00 800.00 900.00 1000,00 1100,00 1200.00 1300.00 1400.00 1500,00 1600.00 1700,00 1800.00 1900,00 2000,00 2100,00 2200,00 2300.00 2400,00 2500.00 2600.00 2700,00 2800.00 2900.00 3000,00 3100,00 3200,00 3300.00 3400.00 3500.00 3600,00 3700.00 3800.00 COMPUTATION DATE: 13-JUL-S8 COURSE DEVIATION AZIMUTH PEG MIN PEG MIN o 0 N 0 0 E o 18 S 76 30 W o 28 5 73 43 W o 34 S 73 43 W o 38 S 69 29 w o 36 S 62 25 w o 31 S 63 20 W o 22 S 88 24 W o 20 S 76 31 w o 29 S 15 22 w o 39 S 67 13 w o 38 S 70 23 W o 42 S 65 4 W o 31 S 60 56 W o 34 S 57 40 W o 31 S 49 55 w o 33 S 47 22 W o 27 5 25 37 W o 24 S 15 47 W o 26 5 65 35 E o 48 N 76 33 E o 56 N 83 16 E 1 14 N 61 17 E 1 19 N 62 0 E 1 59 N 68 38 E 2 20 N 72 34 E 3 42 N 73 35 E 4 19 N 72 29 E 4 52 N 71 52 E 5 9 N 73 46 E 5 14 N 75 13 E 5 4 N 75 47 E 5 10 N 75 51 E 5 1 N 77 44 E 4 35 N 79 2 E 4 36 N 82 37 E 4 30 N 86 40 E 4 31 N 87 50 E 4 24 N 88 9 E 4 16 N 88 19 E VERTICAL SECTION FEET 0.00 0.03 0.53 1.14 1.94 2,78 3,59 4.18 4.53 5,01 5.74 6.59 7,49 8,40 9 21 10:10 10.95 11.87 12.&3 13,00 12.34 11,42 9,99 8,13 5.81 3,05 -0.86 -5.83 -11.72 -18.03 -24.39 -30,51 -36,62 -42,52 -48,03 -52.98 -57.28 -61.37 -65.34 -69.12 FEET Of SUB-SEA DEPTH DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/100 FEET FEET FEET DEG MIN 0,00 0,00 N 0,00 E 0,00 N 0 0 E 0.32 0,01 S 0.05 W 0,05 s,4 ) W 0,05 0,19 S 0,7.5 W 0,78 S 75 42 W 0.29 0,43 5 1.bl W 1.67 S 7S8 W 0.07 0,78 S 2,64 W 2,75 S 73 33 W 0,14 1.20 5 3,62 W 3,81 S 71 44 W 0,23 1,65 S 4.49 W 4.79 S 69 50 0,21 1.91 S 5.25 W 5.59 S 70 2 ~ 0.23 1.97 5 5.88 W 6,20 S 71 30 W 0,21 2.16 S 6.52 W 6.87 S 71 39 W 0.09 2.41 8 7.50 w 7,90 S '1 47 W 0.16 2,88 S 8,52 w 9,00 S 1 18 W 0,23 3,29 5 9.65 W 10,19 S 71 9 W 0.12 3,80 5 10,62 W 11.28 S 70 20 W 0,12 4,27 S 11,45 W 12.22 8 69 33 W 0.24 4.88 S 12.21 W 13,15 S 68 13 w 0,19 5,45 S 12.94 W 14,04 S 67 9 w 0,33 6.18 5 13.51 W 14,86 S 65 24 W 0,13 6.88 S 13.81 w 15.43 S 63 ,30 w 0.80 7.39 S 13.66 W 15.53 5 61 34 W 0,21 7.31 5 12,42 W 14.41 S 59 32 W 0,28 7.04 S 10,97 W 13.03 S 57 17 w 0,38 6,42 5 9.13 w 11.16 S S4 53 W 0,57 5.32 S 7.24 W 8.98 S 53 41 w 0,53 4.13 5 4.58 W 6.17 S 41 57 W 0.76 2,90 S 1.04 W 3,08 S 19 42 W 00.6496 01'1302 SN 140·2955 EE 140·4957 SN 7862 42°1 ~ ) . , . . ~ 0.39 3,20 N 18,69 E 18,97 N 80 17 E 0,18 5.82 N 27.12 E 27.74 N 71 53 E 0.23 8.28 N 35.92 E 36.87 N 77 1! 0,22 10.50 N 44,68 E 45.90 N 76 46 ! 0,20 12.74 N 53.37 E 54,87 N 76 34 E 0,11 14.75 N 62.06 E 63.79 N 16 3' E 0,56 16,49 N 70.41 E 72.32 N 76 49 E 0,60 17,82 N 78.35 E 80.35 N 77 10 E 0,43 18,45 N 86.23 E 88.18 N,7 55 E o 29 18,84 N 94.10 E 95.97 N 18 40 E 0:08 19.15 N 101.87 E 103,66 N,9 21 E 0.09 19,36 N 109,41 E 111.11 N 19 51 E COMPUTATION DATE: 13-JUt/-S8 PAGE 5 ARCa ALASKA, INC. DATE OF SURVEY: 17-JUN-S8 3 0·12 KELLY BUSHING ELEVATION. 59.00 rT KUPARUK NORTH SLOPE,ALASKA ENGINEER' D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET or sua-SEA DEPTH MEASURED TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/lOO FEET FEET FEET DEG NtH 3964.15 3959.00 3900.00 4 0 5 89 29 E .72.63 '0 26 19.47 N 116,60 E 118.2~ N 80 31 E 4064,41 4059,00 4000,00 4 12 S 84 22 E -75.66 O'4~ 19,05 N 123.71 E 125'1 N 81 14£ 4~64,70 4159,00 4100,00 4 24 S 82 3 E -78.39 0'0 18,09 N 131.22 E 132 6 N 8 8 £ 4 64 98 4259.00 4200,00 4 17 5 78 6 E -80,74 O'2A 16,74 N 138 67 E 139:68 N 8! 7 E 4365:26 4359.00 4300,00 4 21 S 77 11 E -82.92 0'1 15.11 N 146:04 E 146,82 N 8 5 E 4465,56 4459,00 4400.00 4 26 S SO 16 E -83.98 S'2A 12'56 N 153.19 E 153,70 N 85 r po 4565,97 4559,00 4500.00 6 20 S 0 3~ W -78,26 4:4 4'43 N 156,~9 E 156.25 N 88 2 ) 4~66.96 4659,00 4600,00 9 24 5 17 4 w -65,00 4.33 9'35 S 153,·8 E 154,07 586 ~ L" 4 68 86 4759,00 4700,00 12 11 5 32 Sl w -45.53 2.61 26:78 5 145,08 E 147.53 S 79 3 E 4871:46 4859.00 4800.00 13 27 S 46 51 w -23,12 3.04 44.37 5 130,50 E 137.84 S 71 13 E 4974,37 4959.00 4900,00 13 45 5 50 22 W o 54 0,22 59,97 5 111,90 E 126.96 S 6A 48 ! 5077,37 5059,00 5000.00 13 56 5 49 53 W 22:39 0,37 75.80 5 92,97 E 119,95 S 5 48 E 5~80.44 5159.00 5100,00 14 5 5 49 53 w 45.66 0,14 91.91 S 73 87 E 117.92 S 38 47 E 5 8356 5259.00 5200,00 14 11 S 50 3 W 69.07 0,23 108,10 5 54:60 E 12~,11 S 26 4'7 E 5386:66 5359,00 5300,00 13 5 5 5~ 11 W 92 31 4.08 124,08 S 35,29 E 12 00 S 15 if E 5488,51 5459,00 5400.00 9 44 S 6 51 W 109:24 0,49 134,73 S 19.39 E 136:11 S 8 E 5590,00 5559,00 5500,00 9 50 S 63 12 w 123.49 0,14 142,55 S 392 E 142.60 S 1 34 E 5691,48 5659,00 5600,00 9 50 S 63 22 W 137,70 0,06 150,34 5 1~:54 W 150,79 S 4 23 W ¡'~2.99 5,59,00 5700.00 9 56 S 63 38 W 151.95 O,~7 158,11 S 2 ~1 W }óO,42 5 9 13 W 8 4,54 5 59,00 5800,00 10 8 5 63 51 W 166.38 O. 5 165,94 5 42: 8 w 71,41 S 14 1 W 599~.17 5959,00 5900.00 10 22 S 64 0 W 181,13 0,27 173,90 S 59,24 W 183,7~ 5 18 48 W 609 86 6059,00 6000,00 10 34 S 63 56 w 196.!6 0,33 182,00 S 75.85 W ~97 1 5 22 ]7 W 6199:6~ 6159,00 6100.00 10 33 5 64 28 W 211 2 0,50 190,20 S 92 74 w 11:61 S 2S 59 W 630~ t 6259,00 6200.00 9 31 5 65 16 W 225:70 0.77 197.73 5 108:84 W 225,71 S 28 49 W 640 :51 6359,00 6300,00 8 54 5 65 46 W 238.78 1,41 204,55 5 123.71 W 239,05 S 31 9 w 6503,60 6459,00 6400,00 8 9 5 67 28 W 250,47 0,81 210,46 S 137.36 W 251,32 S 34 7 w 6604,60 6559,00 6500,00 7 57 5 67 40 W 261.35 0,59 ~15.73 5 150,48 W 263,02 S 3 5] } 6705,55 6659,00 6600,00 7 48 S 66 36 W 272.16 0,28 21 16 S 163.~5 W 274,82 S )6 25 ~. 7005,00 6955,77 6896.77 7 39 5 67 8 W 303,41 0,00 236:77 5 199, 4 W 309,90 S 40 10 w SURFACE LOCATION 2011 FWL~ SEC~AJ26T1]Nf R9E,UM RECTANGULAK CO RDINATES NORTH/SOUTHEAST/WEST 214.76 S 148,08 W 216.49 S 152,31 W 218.23 S 56 34 W 224,135 170:00 W ) 230,04 S 183,98 W 236,77 899,94 W ' ORIGIN= 1019 TVD FROM KB SUa-SEA 6540.58 6481.58 6573.26 6514.26 6604.96 6545.96 6713.95 6654,95 6826.93 6767.93 6955.77 6896.77 FNL, MEASURED DEPTH BELOW KB 658&.00 &619,00 6651.00 6761.00 6875,00 7005,00 TOP KUPARUK C BASE KlJPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD MARKER INTERPOLATED VALUES FOR CHOSEN HORIZONS PAGE 6 17-JUN-S8 59,00 rT D, WARNtR DATE OF SURVEY: KELLY BUSHING ELEVATION. ENGINEER. ARCa ALASKA, INC, 3 0-12 KUpARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 13-JUL-S8 COMPUTATION DATE: 13·~UL.88 ARca ALASKA, INC, 3 0-12 KUPARUK NORTH 5LOPE,ALASKA DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER' PAGE 7 17-JUN-S8 59.00 FT . D, WARN~R ******.*.*.* STRATIGRAPHIC SUMMARY ************ MARKER MEASURED DEPTH BELOW KB 6586,00 6619,00 6651,00 6761,00 6875,00 7005,00 ORIGIN. 1019 FNL, TVD FROM KB SUB-SEA 6540,58 6481.58 6573.26 6514.26 6604.96 6545.96 b713.95 6654 95 6826.93 6767:93 6955.77 6896,77 TOP KUPARUK C BASE KUPARUK C TOP KUPARUI< A BASE KUPARUK A PBTD TD FINAL WELL LOCATION AT TD: TRUE SUB-SEA HORIZONTAL DEPARTURE MEASURED VERTICAL VERTICAL DISTANCE AZIMUTH DEPTH DEPTH DEPTH FEET DEG MIN 7005,00 6955.77 6896,77 309.90 5 40 10 W SURFACE LOCATION AT 2011 FWL~ SEC~. 226T13NI R9E,UM RECTANGULAK CO RDINATES NORTH/SOUTHtAST/WEST 214.76 S 148,08 W 216.49 5 52.31 W 218 23 5 56 34 W 224:13 s 170:00 W 230,04 S 183.98 W ) 236,77 S 199,94 W SCHLUMBERGER DIRECTION~L SURVEY COMPANY ARCO ALASKA, INC. WELL 3 0-12 FIELD KUPARUK COUNTRY USA RUN 1 DATE LOGGED 17 - JUN - 88 . . REFERENCE 72850 ---- ~. WELL 30-12 (101~' FNL, 2011' FWL, SEC 22, T13N, R9E, UM) HORIZONTAL PROJECTION tØTH 300 SWTH -500 200 REF 72850 SCALE = 1/100 IN/FT ... -:1 = -j-:. = :::t:]=Lt~· ::f:!-t+t +i-+: fTT+! '! ~: :~f: =t+~.r ttt-t- *ti=:t·~~·..µ·..t~ #:t-i~ :·t-t·+=t- -~~':'-<-' ++~~- ... -4 - 'f ...... ...~..¡'L,...... ·.....l=r ..~T....~· +t-t..+. Tt-t-r' ::i:"""""'''' +.,...+-.,.. ..'1.-r-t....... =4...t..·.-+· ................... ...................... .-............-..- ...........,........ .4-+-+-+. .- _. -4- -Ii .. i't'tt t+-:;.. :::: : 1 ~; : i ~ : m ~;:; ~+; ;';;;'::: r "~'-~":: .t:..~- trt~ ...~: :J: -t.-t-.J" ·=ti·t'-~·- r¡--r~' =t=t:·t-+· .....-rt-t.. "1".,-+-+ -+-~''T..,.. -t-++..... -r-,.......,. f..1"·....·....· ..,.........;....... ....................... +4-4-.... ..............-...- '=t=,=iî= =i~=t~t= 11=+£ ::ti1t+1Tt i¡t}-4=t+t.= 1#i- tit1~-trt± ftlI1trt :~:tt:- if~= 1tj:-.l_.t~t:t lìl~~ ~t~dtifR~ =W! !t!;rft@W BEtti ~~t -Eš= ~i :~G~= -tttt $ã ~H:!~ ~ :1:tf +J~:tl-î~tt ~m Eli: ::i:i ·1rii 1fT! ~gi ~~+ lffi :~:: ~~r :;~; ~;: -i11~~ ~ft¡:~~+tf¥$fffff! :~jl¡f1i i~_'JEi~ Ifff ..~~- -~~ :Æ~ fi ~~*I~:WI:{:W:! :~lf ~-*~ ~~iî:mf :g:fE- 4f4~m$~ tm= fJîø+f~ WäWwWooW=müWäWWWW =!~~l~:n: =tl!t :g1! ElI ¥~W1iä!mfmmtiJff;1f= tt=tt - = :1~¡~ $¡~: :1~:ß: iff :~i~j¥ ~Þ: ~!w;mf .j;; tmfmfxi iff=[ß- T: ~~t ~r£ l ~tm ~tttr :tin:n-itøR~S i~1;m- fm~B1~ M -;~;-t 100 o -100 -200 -300 -400 ~;'; ~I~ :~~t :$1ffflfft!f;t+tfff ~m iãl :gg ~$tf tf~~t~:fif$ W in ,~t ; :~!:I: -!i:tf ~= ~tii lt~ it$ ftff fiH mf:ffi! !f:ff w~p* ~¡J - .. '" - ...t·~tt·¡- ..t'.l=tt- _.+..+"t'~. .-Ì-.+++.. titi: +~'-r~-' ·+..H-~-· ..4...i..¡,,·t·- _.¡"'¡.,4.+ ..¡...~...¡-¡.. .'¡...¡".¡".L ...¡..-t...¡...l- ..4...L..L.f-. +..¡..+..¡... ·..L.i--Ì-·~" ~:: = ~ :tff~= ::t-l~:: :1$fÌ: ~tFt! +r.ft =f$Þ~ t..~! $ftf. ·ttff l~i1t: mt~tit :r±:t~ ~t1:f.t =tf.t.í -400 -300 -200 -100 0 100 200 300 400 WEST EAST ""-" -- WELL. 30-12 (1019' FNL, 2011 I FWL, SEC 22, T13N, R9E, UM) VERTICAL PROJECTION 28. -200 -100 0 0 100 200 300 ..00 500 SOO ..'~j:: ':. =ttit:: 'il:±±: ~i1:it: rt:tµ: " ;.::::. : ·+:i= wi= ~t t.ttt .:ttt:t ..~~~~:: ti:±i:. -t:t..tt 208. .. t ...... '::tl+:l- "+'j"+'l ::µ:+T lt~tt: .......H-.1 ..1..1...+..... . ...-t.. -++4...... ................... ·_~·........¡-·t·.. .....-.-..... -............-.¡.. !-++....-.;... ...¡....¡....¡..+. ~i~:4~iiii-~r¡i.~I.ä ii1tri-fii;;. iiiUr lØl :llU-UH~nf -t~ì1m¡im4.1n s~m$t¡~¥~#~~:;· =if ~ij!~~lt¡~! :¡tH !H¡~ Ttn ttl¥ =¥ijf :j:n~ !f:fm!i¡5 tifäWf illr =Øø_WffiDømm~gøwgw ~!U£t~l ~nt ~¡t1:l¡!: :ttB~ 1m:: mi 4Êg EI !~l iii~ff =yffi. i1i **-u m~ø_mäøüwøWä~;m~ :I===:====IIII=I~ ~itt: ::1:1=::1:: ::j:::L!::l:: .ttt:t:: j:::i=tl:: ·=tl:=t=t:· ~Ft=ft 1- ¡ : -~ i+-!-~=~ttt=+= '::~=H+rtti: ·:l~=:t. : r-r.:t ~_·t+*.. t-1# § "+Tl· ..T+-· .+. "+...!"+'r- ..·t"¡-rt·.. P:::~"·H..· .................. -...."1'" ~ .................... -.-.--..... jt-.'t-. ......t"....-.t'". ....;.......+. -·t-.....·-·.. .................... r '+ri- ·..ti- ·..t..· ..H·+t- ·-t·+rt..· ++++. .++++ I; ¡: " : : :: : +++ ++++ H+++ ..µ.+..+. ++i+ -ri-+--+... +++t· en ::~~tt ~it ~tif! *!mt 1T~ +4. i :, _:1$:= æ ~r±±:~~. = ~ ~ ~:~~:~~tf;1g<=t!¥!!"lm~!!!€E!!!Ç ~ ~ -. . ... ..·t.. '+'h·..t.. ::+i·..~..·t-. .....+.+-1- "H'''¡'''~-' =ffi-::H-t-.µ-:::!::ii:~ +.+.t'"+ +....++ ++++- ++++ ..t4-f"+" ++-+-.¡_. ±t.t.+ La. - -+-i- +. ::r*tt+· ...... ::+:H+· +'d+ ++++ ! . : ~ : +-++ +tH- +-f ;; . I ,. H+·f-+-H·++· ++++ ...t-t4-f..· ++-t+- ~ LtJ ...1.. +-' +1'+-+ t·· ..-I,-t· +++.t-H-.+4-¡ . t·+t-..t· +-H'+ ..++++- +-t-+-+. ..+t..++- ...............!-+ ..·t-+..t'"~- " ex emr . ': n hI II If I j. I: : I . : :.: ... I 1 :! . .. : I ! i ! I !: :: : -t PROJECTION ON VERTICAL PLANE 208.- 28. SCFt..ED J N VERTJ CFt.. DEPTHS HORIZ SCALE = 1/100 IN/FT -- _::: ~ J Date 17-JUNE-88 ComDuted By: KRUWELL Loaoed By: WARNER Job Reference No. 72850 Company ARCO ALASKA, INC. Well Name 30-12 (10191 FNL. 20111 FWL, SEC 22. T13N. R9E.. UM) Field/Location KUPARUK. NORTH SLOPE. ALASKA 10 il'2. {OÙ @] UIDANCE @]ONTINUOUS [!] OOl SU8·SURFAC& DIR&CTIONAL SURV&Y J/~µ ...... ý¥~~ oýi .~ é~-"" -- METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATIONS VERTICAL SECTION: ******************** * * * * ******************** * * * SCHLUMBERGER * . * ******************** GCT DIRECTIONAL SURVEY CUSTOMER LISTING ) FOR ARca ALASKA, INC. 3 0-12 KUPARUK NORTH SLOPE,ALASKA } SURVEY DATE: 17-JUN-S8 ENGINEER: D. WARNER TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DI5T. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 28 DEG 26 MIN wEST I " COMPUTATION DATE: 13·JUL-88 PAGE ,1 ARgO ALASKA, INC. DATE Of' SURVEY: 11-JUN..Eie 3 -12 KELLY BUSHING ELEVATION, 59.0,1) FT KUPARUK NORTHSLOPE,ALASKA ENGINEERC D.' WA~NER INTERPOLATED VALUES FOR EVEN 100 FEET or MEASURED DEPTH MEASURED TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DlST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FEET FEET DEe; MIN o 00 o 00 -59.00 0 0 N 0 o E 0.00 0,00 0,00 N 0,00 E 0,00 ~ 7¡ o E ~OO:OO 100:00 41 00 o 25 S 76 38 W 0,20 0,23 0,07 S 0,30 W 0,31 20 W 00 00 200,00 141:00 o 30 S 74 28 W 0.77 0,08 0,29 S 1,09 w '·U s , 9 W 300:00 299.99 240,99 o 36 5 71 17 w ~t45 0,18 0,55 5 2,02 w S ,. 36 W 400,00 399.98 340,98 o 37 5 68 29 W ,28 0,05 0,94 5 3,06 w '20 S '253 w 500,00 499.98 440,98 o 33 S 63 20 w J:A~ 0.07 1,39 5 3,99 W 4'23 8 70 51 '.' 600,00 599.97 540,97 ° 30 S 68 50 w 0,16 1.80 5 4.83 W 5'16 I 6~35 ) 700,00 699,97 640.97 o 21 5 86 22 W 4.~1 O,l~ 1.91 5 5,51 W S'84 '7 5~ \If 800,00 799,97 140.97 o 20 S 72 17 w 4,69 o 2 2.03 S 6,10 W 6'43 S 'I 3 w 900,00 899.97 840,97 ° 34 5 7S 32 W 5,26 0:32 2,25 5 6,89 W 7:25 S, 54 W 1°00,00 399 96 940.96 o 37 5 66 51 W 6.10 0,07 2,65 S 7,9~ W 8.35 S n 30 W 100 00 1 99:95 1040,95 o 41 S 71 10 w 6.94 0.13 3,03 S a 9 w 9 47 S 18 W 1200:00 1199,95 1140,95 o 4~ S 63 24 w 7,90 0,31 3.51 S 10:10 w 10:69 s 50 W 1300,00 1299,94 1240,94 o 3 S 61 17 W 8.7A 0,01 3,98 5 10.9* w ti·Z~ s 70 2 W 1400,00 1399.94 1340.94 o 34 5 51 52 W 9.5 0'A4 4.5å S 11 7 W S ~, 4 W 1500,00 1499,93 1440,93 o 31 S 53 1 W 10.44 o '7 g'~3 S 12:5~ w 3'51 S 48 W 1600,00 1599,93 1540.93 o 33 S 41 1 W 1~.33 0'17 S 13 2 w 14:41 s 66 3) W 1100,00 1699,92 1640.92 o 27 5 25 )0 ·W 1 19 0'19 6'47 S 13:65 w 1~'lå s 64 " W 1800,00 1799,92 1140,92 o 20 S 4 6 E 12:89 0'65 7'15 5 13.86 w S 6i 42 W 1900.00 1899.92 1840,92 o 44 N 88 o E 12.85 0:70 7:44 5 13.24 w 15:19 8 6 40 W 2000,00 1999,91 1940.91 o 48 N 78 54 E 11.96 0.21 7.18 S 11.86 W 13.87 S 58 48 W 2100.00 2099,90 2040,90 1 6 N 72 50 E 0.96 0.73 6,90 S 10,26 w 12.37 S 56 4 W 2200.00 2199,87 2140.87 1 14 N 59 19 E 9.22 0,15 5,96 5 8.36 W 10,27 5 5~ 30 W 2300,00 2299.84 2240,84 ~ 3~ N 64 39 E 7.28 0,50 4.86 S 6.30 W 7,96 S 5 20 W 2400.00 2399.79 2340,79 N 70 56 E 4.71 0.57 3,62 5 3.2~ w 4.84 S 4~ 33 W 2500,00 2499,70 2440.70 3 6 -N 73 10 E 1.67 1.36 2.34 5 0,8 E 2.48 S 1 14" 2600,00 2599.50 2540.50 3 55 ,.. 73 42 E -2.76 0,89 0,56 5 6 83 E 6 85 S ai 20 2'00,00 2699.22 2640,22 4 37 N 72 4 E -8.~0 0,61 1,66 N 13:95 E 14:05 =, 11 t. 21°°·00 2798.81 2139.87 5 1 N 72 27 E -14. 1 0,54 4,26 N 21,98 E ~2,3~ E 2 00,00 2898,46 2839.46 5 13 N 74 8 E -20.54 0,15 6,81 N 30,57 E 1.3 N 7 2 E 3000.00 2998.05 2939,05 5 11 N 75 40 E .~6.83 0,46 9 18 N 39,39 E 40,45 N ;t 53 E 3100,00 3097.64 3038.64 5 6 N 75 21 E . 2,85 0.35 11:37 N 48,01 E 49.34 N 40 E 3200.00 3~97.24 3138.24 5 7 N 76 54 E -38,92 8:11 13.55 N 56.71 E 51,31 N " 33 ! 1300,00 3 96 85 3237.85 4 59 N 77 58 E .44.69 1~,45 N 65,3~ E 61'11 N '76 41 E 3400,00 3396:5~ 3337.51 4 35 N 79 53 E -49.91 1 04 N 73 ~ E 'I 2 N ~! 55 £ 1500.00 3496 1 3437,~9 4 32 N 85 24 E -54.66 8'19 18:13 N 81: 1 E 8 :31 N 25 t 600.00 3595:89 3536, 9 4 29 N 87 8 E ·58.82 0'48 18.62 N 89 ~ E 9 ,08 N ~I ~~ E '00 00 3695,58 3636,58 4 26 N 87 24 E -62.83 0'30 18,95 N 96' 6 E 9 79 N ! 3800:00 3795.29 3736.29 4 19 N 88 22 E -66.74 0'27 19,23 N 104:65 E tO~:41 N ¡o 35 E 3900,00 3895,00 3836,00 4 11 N 88 38 E -70,46 0:68 19,44 N 112,09 £ 1 ,76 N 9 E COMPUTATION DATE: 13-JU¡"·S8 PAGE .2 ,. ARCa ALASKA, INC. DATE OF SURVEY: 1 ,.ùUN.8'8 3 0-12 KELLY BUSHING ELEVATION' 59,00 rT KUPARUK NORTH SLOPE,ALASKA ENGINEERI D. WARNE~ INTERPOLATED VALUES FOR EVEN 100 FEET or MEASURED DEPTH TRUE sua-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, D~PARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/~EST DIST. A ¡MUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEf~T DEG/l00 FEET FEET FEET DEG MIN 4000,00 3894,16 3935.76 4 1 5 81 1 E -13.78 0.57 19.40 N 119,11 E 120,68 N 80 44 E 4~OO,OO 4 94 50 4035,50 4 17 5 82 59 E -76.65 0.38 18.16 N 126.33 E 127.72 M 8t 33 t: 4 00 00 4~94:21 :~3~'i~ 4 20 S 79 51 E -79.30 0.71 7 69 N 13f.88 E 135.04 N 8· ~8 ! 4300:00 4 93 92 4334:64 4 17 5 77 33 E -81.48 0.13 16:18 N 14 23 E 14i'16 N 8 7 I: 4400,00 4393:64 4 22 5 75 24 E -8 .50 0.70 14.49 N 148:61 E 14. 2 M 8i 25 E 4500.00 4493.34 4434.34 4 46 S 3~ 9 E -82.98 4.70 10,46 N 154 9 E 155:32 N 8 8". 4600,00 4592.79 4533.79 7 31 5 30 W -74,51 4.15 o 35 N 155:85 E 155.85 N 8 52 ) 4'00,00 4691.54 4632.54 to 33 S 23 45 W -59.34 4.55 14:67 S 151.72 E lS¡.43 8 8~ 28 t· 4800,00 4789.41 47~O.41 2 38 S 36 24 W -38.87 3,08 32.30 S 141,29 E 14 93 S' , E 4900,00 4886.74 48 7.74 13 35 S 49 32 W -16,85 1,36 48,78 S 125,48 E 134:63 S 68 45 E 5000,00 4983.89 4924.89 13 48 S 50 13 w 5 13 0,30 63.87 5 107,20 E 123 ~9 ~ U lJ I 5~00.OO 5080.96 502¡.96 13 58 S 49 48 W 27:47 0,32 79.3~ 5 88 80 E 11 6 500 00 5177,97 511 .97 14 6 S 49 55 W 50,09 0,17 94 9 S 70'23 E l~~ Ai 8 ~6 8! 5300:00 5274.94 5215.94 14 12 S 50 9 w 72.82 O,~9 1~0:69 S 51:50 E S 4 56 E 5400,00 5372,02 5313,02 12 26 5 51 59 W 94 98 4 5 1 5 89 S 33.02 E 1 JO 14 S 14 41 I 5500,00 5470.32 5411.32 9 46 S 62 58 W 110:85 0:38 135:61 5 17,65 E 1 , 75 S ¡ 24 5600.00 5568.85 5509.85 9 49 S 63 1~ W 124.89 Ot!7 143.32 S 2 39 E 14 34 S 51 E 5700.00 5667.39 5608.39 9 50 S 63 2 W 138.89 o 6 150,99 5 ~2:84 w 151 54 S 51 W 5800,00 5765,90 5706.90 9 57 S 63 39 W 152.94 0:15 158,65 S 8 20 W 16~ à4 S 10 4 W 5900.00 5864.38 5805.38 10 9 S 63 52 w 167.17 0,25 166,36 S 43:84 W 17 4 8 4 45 W 6000.00 5962,77 5903.77 10 23 5 64 0 W 181.69 0,30 174.20 5 59,86 W 184,20 S Ii 57 \I 6100.00 6061.10 6002,!0 10 35 S 63 56 W 196.48 O,3~ 182.17 S 76.20 W 19'7.47 S 2 4A" 6200.00 6159.38 6100, 8 10 33 5 64 28 W 211.47 o 5 190,24 S 92 80 W 2t~·66 S ~ W 6300.00 6257.84 6198.84 9 31 5 65 16 W 225.55 0'82 197,65 S 108:66 w 2 55 S 48 W 6400,00 6356,52 6297,52 8 56 S 65 43 W 238,47 1'36 ~04,39 S 123,35 w 2 8'73 i Ii .1 ~ 6500,00 6455.43 6396.43 8 10 S 67 21 w 250.07 0'79 10 16 S 136.89 w ~I~:~I 6600,00 6554,45 6495.45 7 58 5 67 48 W 260,86 0'54 215: 9 S 149,88 W ) 6700.00 6653,51 6594.51 7 48 5 66 39 W 271.57 O'~3 220,86 S 162,46 W 274:17 In 20 ti 6800,00 6752,60 6693.60 7 39 5 67 8 W 282.09 0' ~ 226'16 5 174.76 W 285.8~ ~~ W 6900.00 6851.71 6792.71 7 39 S 67 8 W 292.49 0:0 231. 4 S 187.05 W 297.4 W 7000.00 6950.8~ 6891.82 7 39 S 67 8 W 302.89 0,00 236,52 S 199,33 w 309.31 S 28 '7 w 7005,00 6955.7 6896.17 7 39 5 67 8 W 303.41 0,00 236.17 S 199.94 W 309,90 S 10 w , s COMPUTATION DATE; 13...JUL-S8 PAGE '3 ARCO ALASKA, INC. DATE OF SURVEY' 17·"UN-,' 3 0-12 KELLY BUSHING ELEVATION. 59,00 rT, KUpARUK ENGINEERS D, WA~NER NORTH SúOPE,ALASKA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE sua-SEA COURSE VERTICAL DQGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/50UTH EAST/WEST DlST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/l00 fEET FEET FEET DEG Mt~ o 00 o 00 -59,00 0 0 N 0 0 E 0.00 0,00 0,00 N 0,00 E 0,00 N 0 o E 1000:00 999'96 940,96 o ~7 5 66 51 W 6.§O 0,07 2.65 5 7 92 W 1~:~~ S ,¡ ·30 W 2000,00 1~99:91 1940.91 o 8 N 78 54 E 11. 6 0,21 7,18 :> 1~:86 W S 5 48 W 3000,00 2 98 05 2939,05 5 11 N 75 40 E ""26.83 0,46 9 18 N 3 39 E 40.45 N '8 53 ! 4000,00 3994:76 3935.76 4 1 S 87 7 E .73.78 0,57 19:40 N 119:1A E 120.68 N 8 44 E' 5000,00 4983,89 4924.89 13 48 S 50 13 W 5 13 0,30 63 87 S 107.2 E 124.79 S 59 12 ,.. , 6000.00 5962.77 5903.77 10 23 S 64 0 w ~81:69 0,30 ~74:20 5 59 86 W 184,20 S l' 5'1 ) 7000,00 6950 82 6891.82 7 39 S 67 8 W 02.89 0,00 36 52 S 199:33 W 309,31 S 48 "I W 7005,00 6955:77 6896.77 7 39 S 67 8 w 303,41 0,00 236:77 S 199,94 w 309,90 S 4 10 W ) · » COMPUTATION DATE; 13·~UL·88 PAGE 4 ARea ALASKA, INC. DATE OF SURVEY: 11-JUN-88 3 0-12 KELLY BUSHING ELEVATION a 59.00 rT KUPARUK NORTH SLOPE,ALASKA ENGINEERI D. WARNE~ INTERPOLATED VALUES FOR EVEN 100 FEET OF sua-SEA DEPTH TRUE sua-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORtZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTk DEPTH DEPTH DEG MIN PEG MIN FEET DEG/100 FEET FEET FEET DEG NIH o 00 0 00 -59 00 0 0 N 0 0 E 0.00 0 00 0,00 N 0,00 E 0 00 N 0 0 E 59'00 59:00 0 00 0 18 S 76 30 W 0.03 0:32 0,01 S 0.05 w 0'05 514 3 W 159:00 15,9.00 100 00 0' 28 5 73 43 W 0,53 0,05 0,19 S 0.75, W 0:'88,,'75 41 w 259.01 259,00 200 00 0 34 S 73 43 w 1.14 0,29 0.43 S 1.61 W 1.67 '875 'W ')59 01 359 00 300 00 0 38 5 69 29 w 1.94 0 01 0,78 S 2.64 W 2 75 S 73 3 w 459:02 459:00 400 00 0 36 S 62 25 w 2,78 0:14 1,20 S 3.62 W 3:81 S 71 44 ~ ')., 559,02 559,00 500 00 0 31 S 63 20 W 3.59 0,23 1.65 S 4.49 W 4.79 S 69 50 659 03 659 00 600 00 0 22 S 88 24 W 4.18 0 21 1.91 S 5.25 W 5 59 S 70 2 ~ . 759:03 759:00 700 00 0 20 S 76 31 W 4.53 0:23 1,97 S 5.88 W 6:20 S 71 30 W 859.03 859,00 800 00 0 29 5 75 22 W 5.01 0.21 2.16 S 6.52 W 6,87 S 71 39 W 959 04 959 00 900.00 0 39 S 67 13 W 5.74 0 09 2 47 S 7.50 w 7,90 S 71 47 W 1059:04 1059:00 1000,00 0 38 S 70 23 W 6.59 0:16 2:88 S 8.52 w 9,00 S 71 19 W 1159 05 1159 00 1100,00 0 42 S 65 4 W 7 49 0 23 3 29 5 9,65 W 10 19 S 71 9 W 1259:06 1259:00 1200.00 0 31 5 60 56 W 8:40 0:12 3:80 5 10,62 W 11:28 S 70 20 W 1359 06 1359 00 1300 00 0 34 S 57 40 W 9 21 0 12 4 27 S 11 45 W 12 22 S 69 33 W 1459:01 1459:00 1400:00 0 31 S 49 55 w 10:10 0:24 4:88 S 12:21 W 13:15 S 68 13 W 1559 07 1559 00 1500.00 0 33 S 41 22 W 10 95 0 19 5.45 S 12.94 W 14,04 S 67 9 W 1659:07 1659:00 1600,00 0 27 5 25 37 W 11:87 0:33 6,18 S 13.51 w 14.86 S 6524 W 1759.08 1759,00 1700.00 0 24 S 15 47 W 12.63 0,13 6,88 S 13.81 w 15,43 S 63 ']0 w 859.08 1859,00 1800,00 0 26 5 65 35 E 13,00 0,80 7.39 S 13.66 W 15.53 5 61 34 W 1959,09 1959,00 1900,00 0 48 N 76 33 E 12.34 0,21 7.31 S 12,42 W 14.41 S 59 32 W 2059 10 2059 00 2000,00 0 56 N 83 16 E 11.42 0 28 7 04 S 10 97 W 13,03 S 57 17 w 2159:12 2159:00 2100,00 1 14 N 61 17 E 9.99 0:38 6:42 5 9:13 W 11,16 S 54 53 W 2259 14 2259,00 2200,00 1 19 N 62 0 E 8.13 0 51 5.32 S 1,24 W 8.98 S 53 41 w 2359:19 2359.00 2300,00 1 59 N 68 38 E 5.81 0:53 4.13 S 4.58 W 6.17 S 47 57 W 2459 26 2459 00 2400,00 2 20 N 72 34 E 3,05 0 76 2 90 5 1.04 W 3 08 S 19 42 W 2559:41 2559:00 2500,00 3 42 N 73 35 E -0.86 0:69 1:32 S 4.25 E 4:45 S 72 40' ) 2659 65 2659,00 2600.00 4 19 N 72 29 E -5 83 0 46 0.70 N 10,95 E 10 97 N 86 21 .~ . 2759:99 2759,00 2700,00 4 52 N 71 52 E -11:72 0:39 3,20 N 18,69 E 18:97 N 80 11 E 2860.37 2859,00 2800,00 5 9 N 13 46 E -18.03 0,18 5.82 N 27.12 E 27.74 N 77 5] E 1960.79 2959,00 2900,00 5 14 N 75 13 E -24.39 0,23 8.28 N 35,92 E 36.81 N 77 1! 06 20 3059.00 3000 00 5 4 N 75 47 E · 0.51 0 22 10,50 N 44.68 E 45.90 N 76 46 E 161:60 3159.00 3100:00 5 10 N 75 51 E .J6,62 0:20 12.74 N 53.31 E 54.87 N 76 34 E 3262.00 3259.00 3200,00 5 1 N 71 44 E -42.52 0.17 14.75 N 62.06 E 63.79 N 76 3' ! 3362 36 3359,00 3300,00 4 35 N 79 2 E -48.03 0 56 16 49 N 70.41 E 72 32 N 76 49 E 3462:68 3459.00 3400,00 4 36 N 82 37 E -52.98 0:60 17:82 N 78.35 E 80:35 N 71 10 E 3563 00 3559.00 3500,00 4 30 N 86 40 E -57.28 0 43 18 4S N 86.23 E 88.18 N 17 55 E 3663:31 3659.00 3600,00 4 31 N 87 50 E -61.37 0:29 18:84 N 94.10 E 95.97 N 18 40 E )763 61 3759.00 3700,00 4 24 N 88 9 E -65.34 0.08 19 15 N 101.87 E 103.66 N 19 21 E 3863:89 3859,00 3800.00 4 16 N 88 19 E -69.12 0.09 19:36 N 109,41 E 111.11 N 79 51 ! COMPUTATION DATE: 13-JUll""S8 PAGE 5 ARca ALASKA, INC. DATE Of'SURVEY: 17·JHN-S8 3 0·12 KELLY BUSHING ELEVATION' 59, 0 r" KUPARUK NORTH S~OPE,ALASKA t;NGINEER. D, WA~NE~ INTERPOLATED VALUES FOR EVEN 100 FEET OF sua-SEA DEPTH MEASURED TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGUI,AR COORDINATES HORIZtD¡'ARTURE VERTICAL VERTICAL DEVIATIQN AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/l00 FEET FEET FEET D G NtH 3964.15 3959.00 3900,00 4 0 5 89 29 E .72.63 o 26 19.41 N 116,60 E 1~~,2~ N 80 31 E 4064,41 4059,00 4000,00 4 12 S 84 22 E .75.66 0'4~ 19,05 N 123.71 E 132:16 N 8~ 14£ 4~64.70 4159.00 4100,00 4 24 S 82 3 E -78.39 0'0 18,09 N 131.22 E N 8 8 E 4 ~4 98 4259,00 4200,00 4 17 S 78 6 E -80.74 o'2A 16,74 N 138 67 E 139,68 N 8! 7E 4: 5:26 4359.00 4300.00 4 21 S 77 11 E -82,82 0'1 15.11 N 146:04 E 146,82 N 85 E 4 65 56 4459,00 4400,00 4 26 S SO 16 E -83,98 5'21 12'56 N 153.19 E 153,10 N 85 t8 ,. 4565:97 4559.00 4500,00 6 20 S 0 33 W ""'8.26 4:46 .'43 N 156,~9 E 156.25 N 88 2 ) 4~66,96 4659,00 4600.00 9 24 5 17 42 w -65,00 4,33 9'35 5 153 8 E 154,07 S 86 ~ t' 4 68 86 4759,00 4700,00 12 11 5 32 S1 W ..45.53 2.61 26:78 5 145:08 E 147.53 S 79 3 E 4871:46 4859,00 4800.00 13 27 S 46 51 W ..23.12 3,04 44,37 5 130,50 E 131.84 S 71 13 E 4974,37 4959.00 4900.00 13 45 S 50 22 W o 54 0,22 59,97 5 111.90 E 126.96 S 6A 48 ! 5077.37 5059,00 5000,00 13 56 5 49 53 W 22:39 0,37 75.80 S 92,97 E 119.95 S 5 48 E 5~80.44 5159.00 5100,00 14 5 S 49 53 w 45.66 0,14 91,91 5 73 87 E 117.92 5 38 47 it 5 8356 5259.00 5200.00 14 11 S 50 3 W 69.07 0,23 108,10 5 54:60 E 12~,11 S 26 47 E 5386:66 5359,00 5300.00 13 5 5 5~ 11 W 92 31 4,08 124,08 S 35.29 E 12 00 S 15 52 E 5488,51 5459.00 5400.00 9 44 S 6 51 W 109:24 0,49 134,73 S 19.39 E 136:11 s 8 11 E 5590,00 5559,00 5500,00 9 50 S 63 12 w 123.49 0,14 142,55 S 3 92 E 142.60 S 1 34 E 569~.48 5659,00 5600,00 9 50 S 63 22 w 137.70 0,06 150,34 5 11:54 w 150,79 S 4 23 W i79 99 S¡S9,OO 5700,00 9 56 S 63 38 w 151.95 0,~7 158.11 S 27,11 W 160,42 5 9 13 W 894:54 5 59,00 5800,00 10 8 S 63 51 w 166.38 0, 5 165,94 5 42,98 w 71,41 S 14 1 W 599~.17 5959,00 5900,00 10 22 5 64 0 w 181.13 0,27 17~.90 S 59,24 W 183.7~ 5 18 48 w 609 8& 6059,00 6000,00 10 34 S 63 56 w 196.16 0,33 18 00 5 75.85 W ~97 1 5 22 37 W 6199:6~ 6159.00 6100,00 10 33 S 64 28 W 211.42 0,50 190:20 s 92 74 w 11:61 s 25 S9 W 630t 6259,00 &200.00 9 31 5 65 16 W 225,70 0,77 197,73 5 108:84 w 225.71 S 28 49 \II 640 :51 6359,00 6300,00 8 54 S 65 46 W 238.78 1,41 204,55 5 123.71 W 239,05 S Jl 9 w 650 60 6459.00 6400.00 8 9 5 67 28 W 250.47 o 8 210.46 5 137.36 W 251.32 S 7 .,. 6604:60 6559.00 6500,00 7 57 5 67 40 W 261,35 0:59 215.13 5 150.48 W 263,02 S 34 53 } ~'05.5S 6659.00 6600,00 7 48 S 66 36 W 272,16 0.28 221,16 S 163.~5 W 274.82 S 36 25 w 005,00 6955.77 6896.77 7 39 S 67 8 w 303,41 0.00 23 .71 5 199, 4 W 309,90 S 40 10 w SURFACE LOCATION AT 2011 FWL~ SEC~ 22ðT13Nr R9E,UM RECTANGULAK CO RDINATES NORTH/SOUTHEAST/WEST 214,76 S 148,08 W 216.49 S 152.~1 W 218.23 S 56 4 W 224,138 170:0 W ) 230 04 S i83 98 W 236:77 S ,99:94 W FNL, PAGE ,6 17-JUN-e-e 59,0.0 rT D. WA~NE~ DATE or SURVEY: KELLY BUSHING ELEVATION, ENGINEERI ORIGIN: 1019 TVD FROM KB sua-SEA 6540.58 6481,58 6573,26 6514.26 6604,96 6545.96 6713,95 6654,95 6826,93 6767.93 6955.77 6896,77 MEASURED DEPTH BELOW KB 6586 00 &619:00 6651,00 6761,00 6875,00 7005,00 TOP KUPARUK C BASE KtJPARUK C TOP KUPARUK A BASE KUPARUK A PBTf) TD MARKER INTERPOLATED VALUES fOR CHOSEN HORIZONS ARCa ALASKA, INC. 3 0-12 J(UPARUK NORTH SLOPE,ALA5KA COMPUTATION DATE: 1]-vUL-SS COMPUTATION DATE: 13-JUL-S8 ARca ALASKA, INC. 3 0-12 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: KE~LY BUSHING ELEVATION, ENGINEERI PAGE ·7'Y 17-JUN-S9 S9.0QFT D. WA~NE~ ************ 5TRATIGRAPHIC SUMMARY ************ MARKER MEASURED DEPTH BELOW KB 6586,00 6619,00 6651 00 6761'00 6875:00 7005,00 ORIGIN. 1019 FNL, TVD fROM KB SUB-SEA 6540,58 6481.58 6573 26 6514.26 6604:96 6545.96 b713.9S 6654,95 6826.93 6767.93 6955.77 6896,77 TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD 'I'D FINAL WELL LOCATION AT TD: TRUE SUB-SEA HORIZONTAL DEPARTURE MEASURED VERTICAL VERTICAL DISTANCE AZIMUTH DEPTH DEPTH DEPTH FEET DEG MIN 7005,00 6955.77 6896,77 309.90 S 40 10 W SURFACE LOCATION AT 2011 FWL~ .SEC~ 226T13N, R9E,UM RECTANGULAK CO RDINATES NORTH/SOUTH EAST/WEST 214.76 S 148,08 W ~13'~~ ~ ~i'Jl = 224:13 S 170:00 W 230,04 S 183,98 W ) 236,77 S 199,94 W J SCHLUMBERGER DIRECTION~L SURVEY COMPANY ARCO ALASKA. INC. WELL 3 0-12 FIELD KUPARUK COUNTRY USA RUN 1 DATE LOGGED 17 - JUN - 88 REFERENCE 72850 -- ;~ WELL 30-12 (10191 FNL, 20111 FWL, SEC 22, T13N, R9E, UM) HORIZONTAL PROJECTION N:1RTH 300 SOUTH -500 REF 72850 SCALE = 1/100 IN/FT 200 m_ ~ =;=1" = ~ ~~:~:m*~ fFf~ ##~tm m1ö 7tm-mt-*mtm: ~=,: ~~ttiT!1! t#~f M&tttf rd!. 1414 Emiff !ffiffi~Jt 11l~1~~~~11!4!i~ß~:iji tRmrttn ili± ~~* ¡~1g ÊJfmt îlj~~ ~tlj=: ~fi~fl =lffl :r¡fF ~Eîf:#~J: ff¡f~ 1~1i §ffFj:£frfr$~ ~¡ ~i:tf :?~~:~ MØØØmØWäfiøgäm=~- ~1~1~¡~ ~W¡=f :Hn ::ft~~;µ~ ~~*€±!l=ri¥ 81£i: -~~ ~:i iif iiìkffit W¡f; _SfiWwmWwwmuWww~oo J~~~~ßi=¡~tUfm¡ it! ~~~i :~älm_:W4mt ~~if1t- $! ~~i~¡~ ~ß~¡l fln-:f!ff: li¡;mf-1m:fm~iñ:~Wj¡m wi# W jJ ~ ~~¡~~ ~rrn.. iffl- rftJ:~!t_ mtEl it:1i* mtffi1fHf æ: $~f l~~~~llili::~:!(i;~i:::Êi==:= _: =: ~ ¡~1$ß=!tt i~ ~i3:~ tmi! tm:äflm¡ tmtttttm ø ~ ~ ~ ~ ~~~~~ ~~~ iff =Jrif;Wi ~\ r t;¡¡;i~ :ff±1~fi lìff!ræ fif! :W~ tlf /1: ~~¡~I~ l!f t1t $1$t lr4** #it mi #ff !!1t4f- ~~ÞT ;tf~ -00 if- -:~ ~tfíw~i $t# ØØW-$1i¡ =ß]JitH!J!W iftØ 100 o -100 -200 -300 -400 -400 WEST -300 -200 -100 o 100 200 400 EAST 300 "- '-' ~'JELL 30-12 (10191 FNL, 20111 FWL, SEC 22, T13N, R9E, UM) VERTICAL PROJECTION 28. -200 -100 0 0 100 200 300 400 600 SOO .. ··~.4.·::1= t ·J1·~!++ t++·· ~:' +++ i:; . ; I :: i. : I : : ++++- H-+++ ++++ -w...~..~ +++t- ++++ 208 . .. ...... ..+.+. ..... . ..·t+· -1-.,..i....¡..· ..+.-4- +~1fF' ~t+ . .. .+....+. ..+-+-t-+.. ++-++ .................... ........¡..~-.... .+..¡.........¡.. ...¡....¡......... ....¡....¡..~..¡- I t I I:. ! I I ! I : I I I: : .1 i: : I : ::: I .:: ¡ : : I I .... ...... ..~..++·1.. "+1'" ..t.. '""1"+""'r'" t-....·.,.·r·.. '''r ..+- ..t+~ ·.....r.. ~............... ..¡....¡........... ·-·..+.....·1·.. ........... ,-..... ..............¡....... .-....+...¡... .......t.....+· . '+++1' "+1+"1 ··H++- r+ï;..m.. I ! i: . . I :::: !! i. ~ +++- ..H+¡'. -++-+...... ·+i..~·+.. -t-~..+..¡- 'r'1'"r''~''' ++-H- -m:!: :tjj: : =tf:ft tm= ttU=:mf ~i Itt1fiff1±ff";; =m=t ~ fill :ß~;~ :tl!¡:¡~~j: l~f£ ±llt¡=!ll¡ ~-i±t ml~ m ~m w W:f ~lf:mf E øwmmWWmmbmWæømWw øø_=~mSWääüøaWäm riMøUWmøW~;ä;Øft~::-ø ~===I:====:liilll ~:1~:~;Iil:~lil:~f: ¡ '~=:¡II=I; ~ ~l~J#\f]!f~l!!!-~R!~!tf#t!!!!1!!!f! ~ ~ rt.. ... [fl. ..t· .::!:..,..-t.. "~"'1.1..t... .t...~..+.,. ..,..++..... +Jp... . ....t·+·1=+-+-+ +1'..t-t·· +++r- ++++. ,....¡.++ ++-t--.¡... :i±~.+ u. r-r- ... t.. ... =ft. -+- '+H'+ ....¡..·t+t- +.+++ +f++-; I; :! I ! ;++.t-r-++- -H+i- :-++++. ..++++ ++++. -H-H- ~ I.IJ ........1 '+1-+t +.. ·...-t· ++++.......L1-+1". ++·t·· ++...¡.+ -++++- '+i..-...t-- ..-f-,.++--t-+·..¡..+ .++++.. ." œ I 'or' . . 'I :t kl II liT: '.!: "T1' Ii,.' . I. ::! : ! : I :! : I ! : ~ PROJECTION ON VERTICAL PLANE 208. - 28. SCR.ED IN VERTJCR. DEPTHS HORIZ SCALE = 1/100 IN/FT - /gg- o'i/ .ì VA CORE LABORATORIES .1_ West:ern Atlas International A Litton/Dresser Company i ..l. ARCO ALASKA, INC. ~ CORE ANALYSIS REPORT KRU 30-12 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA CL FILE NO. BP-3-1281 l - ",~é.(~" ~...: "\c.\\'~';:..... \O~S~€~\·,~ , ~\,-þ.\ ~~ ~ù~~~~\\\ Performed by: Core Laboratories 8005 Schoon st. Anchorage, AK 99518 (907) 349-3541 Final Report Presented August 9, 1988 These analysis, op1n10ns or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgement of Core Laboratories (all errors and omissions excepted); but Core Laboratories and it's officers and employees assume no responsibility and make no warranty of representation as to the productivity, proper operations, profitability of any oil. gas or other mineral well or formation in connection with which such report is used or relied upon. 8005 Schoon Street, Anchorage, Alaska 99518-3045, (907) 349-3541 L L.. INTRODUCTION L L Core Laboratories was requested to perform a core analysis study on behalf of Arco Alaska, Inc. for samples recovered from the KRU 30-12 well in the Kuparuk River Unit, North Slope, Alaska. Presented herein are the results of this study. L Conventional cores cut with a bland mud were submitted. Service description and methodology are presented in section 1. The core analysis results, surface core gamma log, and lithological descriptions are presented in sections 2 and 3. section 4 contains the wellsite reports and copies of shipping and receiving transmittals. In conjunction with the report, the tabular results of the analysis are supplied on an IBM PC compatible diskette with data software, CoreLab. Also four sets of visible spectrum flash, and ultraviolet light photographs are provided in separate binders. L L , -'-. We sincerely appreciate this opportunity to be of service and hope these data prove beneficial in the development of this reservoir. ~ 1 .... L 1- .L TABLE OF CONTENTS ~ ... section 1 - 1 CONVENTIONAL CORE ANALYSIS, SERVICE DESCRIPTION 2 CONVENTIONAL CORE ANALYSIS, TABULAR RESULTS ~ ........ 3 CONVENTIONAL CORE STATISTICAL DATA, SURFACE CORE GAMMA LOG, AND DETAILED LITHOLOGICAL DESCRIPTIONS l- 4 WELLSITE REPORT, TRANSMITTALS, AND DATA DISKETTES 1.. L SECTION 1 L CONVENTIONAL CORE .L Field Procedures 1.. Conventional coring equipment in conjunction with a KCL based drilling fluid was used to extract core samples during June of 1988. Core Laboratories field personnel performed wellsite core preservation. Each core was lowered from the drill floor to the pipe shed by rig personnel. The core barrel was cut into manageable lengths and carried to the core trailer where it was extruded, pieced together, and marked appropriately. Core sections from depth 6549 to 6618 were boxed without preservation at request of the Arco geologist. The remainder of the cores were preserved by wrapping each piece in Saran Wrap and aluminum foil and then dipping in Core Seal. Approximately four inches of each foot of preserved core was designated for Core Lab. These sections were chosen to be lithologically representative of that foot and were analyzed by Core Lab, Anchorage. Only the Core Lab designated pieces were depreserved for core analysis. 1 .. , ... Core processing Surface Core Gamma Log A surface core gamma log was performed on the recovered core samples upon arrival at the Anchorage laboratory. The gamma response is graphically presented in section 3. Sample Preparation Fluid Saturation Sample An approximately 250 gram sample was removed for fluid saturation and API oil gravity measurement. This sample was taken adjacent to the plug point of the Core Lab designated section of each foot. l.. Plugged Samples L Horizontal one-inch diameter plug samples were drilled with water from the depreserved CoreLab sections. One sample was taken from each Core Lab designated section beginning at depth 6616 of core #3. Plugs were taken from the center of each section and parallel to the bedding strike. The plug samples were trimmed with water and prepared for hydrocarbon extraction. Plug ends were saved and stored according to depth for each sample. .L .1. 1 ...... Dean-Stark Plug Samples l Horizontal one-inch diameter plug samples were drilled with isopar from six requested depths, for saturation comparison checks. The plugs were then prepared for the Dean-Stark apparatus. Requested depths determined by Jake Rathmell, Arco. 1.. , Slabbinq ,...¡... When sampling was completed, all core from 6549.0 to 6656.0 ft. was slabbed and photographed. The whole core sections were slabbed in one-third and two-third sections using water as a blade coolant. Appropriate depths were marked on the slabbed face of each section and the two-thirds section was prepared for photography. The remainder of the well, preserved pieces and depreserved sampled sections, was not slabbed or photographed. This service was requested by Doug Knock, Arco geologist. - Analysis Techniques Hvdrocarbon Extraction The plug samples were placed in a toluene centrifuge extractor for hydrocarbon removal a minimum of two days, or until no fluorescence was visible. Once cleaned, the samples were dried in a convection oven for a minimum of 24 hours at 240 deg. F., and then cooled in a desiccator to room temperature before porosity and permeability was measured. Fluid Saturation Measurements From the 250 gram fluid saturation sample, 100 grams was broken into "peanut" size pieces for the retort process. To minimize invasion effects of drilling fluids, the sample was taken from the center of the core. The 100 gram samples were retorted in a conventional retort oven at 400 deg. f. for 40 minutes, when an initial water reading was measured. The temperature of the oven , ,;... L was then increased to 1200 deg. F. for approx. 40 minutes, when an observed oil and final water reading was measured. From the center of the fluid saturation sample a 30-50 gram piece was used for bulk and gas volume measurements. Bulk volume for each sample was measured by mercury displacement. Gas volume for each sample was determined by mercury injection at 750 psig. L 1... * Observed oil readings were corrected for coking using the oil correction chart in section D. , -L A portion of the remaining 250 gram sample was used for state chips. Two sets of approximately one inch cube chips were taken from each remains to represent every foot of the well. The chips are stored according to depth. l.. Fluid saturations by retort method are calculated using equations 1 thru 3. 1... Vp = Vo + Vw + Vg (1) 1- So = [VojVp] X 100 (2) Sw = [VwjVp] X 100 (3) Where: Vp = Pore Volume Vo = Volume oil Vg = Volume Gas Vw = Volume Water So = Oil Saturation 9., 0 Sw = Water Saturation 9., 0 Special Dean-Stark Samples Water was extracted by Dean-Stark technique using toluene. Samples were removed from the Dean-Stark and placed in a toluene centrifuge for hydrocarbon extraction as previously mentioned. Extracted samples were dried in a convection oven at 240 degrees F. for a minimum of 24 hours, and cooled in a desiccator. - '\ - Saturations by Dean-Stark methods were calculated using Equations 4 and 5. L L So = [«W1 - W2 - H20)jDo)jVp] x 100 Sw = [H20jVp] x 100 (4) (5) L Where: So = oil saturations, Percent Sw = Water Saturation, Percent W1 = Natural Weight W2 = Extracted and Dried Weight H2O = Extracted Water, Density Assumed 1. 0 gmjcc Do = Density of Oil Vp = Pore Volume L .L L oil Gravitv Analysis , The refractive index of the retorted oil was measured every fifth foot and the API gravity (60 deg. F.) was determined using the appropriate correlation chart derived from previously analyzed Kuparuk crude samples. Grain Density Grain volume determinations were performed according to Boyle's Law utilizing the Heise Gauge Helium Porosimeter. Grain density was calculated using Equation 6. Dg = MgjVg (6) Where: Dg = Grain Density Vg = Grain Volume Mg = Grain Mass Atmospheric Porosity The samples were measured for bulk volume by mercury displacement at ambient conditions. Porosity was calculated . using Equa'tion 7. P = [(Vb-Vg) j Vb)] x 100 (7) L 1- Where: P = Porosity, Percent Vb = Bulk Volume Vg = Grain Volume L 1- , ....i.... Overburden Porosity 1 Each sample reported had pore volumes measured in the CMS-200 hydrostatic holder at each of the two recorded overburden pressures. Overburden porosity was calculated using Equation 8. 1- p = [Vp / (Vp + Vg)] x 100 (8) Where: Vp = Pore Volume at Overburden Vg = Grain Volume .... 1 - Atmospheric permeability to Air - Samples were loaded into a Hassler type core holder at a confining pressure of 400 psig. Permeability calculations were performed as defined by Darcy's Equation for compressible fluids, Equation 9. Pa x v x 1000 Qa x L x L K = -------------------- x ----------- (9) (P1 - P2) (P1 +P2) Vb -------- 2 Where: K = Permeability v = Gas Viscosity PI - P2 = Differential Pressure PI + P2 -------- = Mean Pressure 2 1 L Pa = Atmospheric Pressure Qa = Flow Rate L = Length Vb = Bulk Volume - Overburden Klinkenberg Air Permeability 1- , The samples were loaded into the CMS-200 hydrostatic holder where a slippage corrected unsteady state permeability to gas was measured at the stated overburden pressures. This permeability is equal to a non-reactive liquid permeability. Permeability calculation were performed using modified Darcy's and Forchheimer's equations for unsteady-state flow. (Refer to SPE Journal October 1972. A Rapid Accurate UnsteadY-State Klinkenberg Permeameter, by Stanley C. Jones. Core Photographs The two-thirds slabbed section of cores #1,2,3, and the first four feet of core #4 was photographed. Approximately 15 feet of core appears in each photograph. Four sets of visible spectrum flash light and three sets of ultraviolet light photographs are provided in separate binders. Special Conditions It should be noted that depths used in this report are drillers depths, which may not correlate with log depths. Gamma logs should be used to shift core to match log depths. Sample Disposition Both slabs and whole core of KRU #30-12 along with plugs, plug ends, and chips are currently stored at Core Laboratories Anchorage facility awaiting shipping instructions. - L L L L 1... SECTION 2 L CONVENTIONAL ANALYSIS RESULTS 1. , 1 - 1 - - / /~g' ./ ð t-( ( kRu 3/)- (1- i} I ].~ }... 14 ~.. t... [... )- ... r- t'" r r r ï CORE LABORATORIES Company : ARCO ALASKA, INC Field : KUPARUK RIVER UNIT File No.: BP-3-1281 Well : KRU 30-12 Formation : KUPARUK Date . 18-Jul-1988 . A N A L Y T I C A L P R 0 C E 0 U R E S A N 0 Q u A L I T y A S S U RAN C E HANDLING & CLEANING ANALYSIS - Core Transportation : Air Freight Grain volume measured by Boyle's Law in a matrix cup using He Solvent : Toluene Bulk volume by Archimedes Principle Extraction Equipment : Centrifuge Fluid saturations by retort Ext ract i on Ti me : Mininum 2 Days Permeabilities measured on 1 in. diameter drilled plugs Drying Equipment : Convection Oven The "OB" samples were confined in CMS-200 Drying Time : Mininum 24 Hours Orying Temperature : 240 Degrees F. REMARKS Mercury was used as a displacing fluid. Atmospheric porosity was determined using grain volume and bulk volume. Atmospheric permeability was measured with a 400 PSIG confining pressure Overburden porosities were determined using grain volumes and measured pore volumes at stated confining stresses r ï {i" r J' File No BP-3-1281 Date 5-Aug-1988 API No. Analysts: TS,GC.PB J l I t, ~~ J~ ... t~ CORE LABORATORIES Field KUPARUK RIVER UNIT Formation KUPARUK Coring Fluid BLAND Elevation COR E A N A L Y S I S RES U L T S I, ALASKA INC ,,\ ARCO ALASKA KRU 30-12 22-13N-9E NORTH SLOPE 7 Company Well Location Co. State SATURATION SAMPLE DEPTH PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (HEll UM) (PORE VOLUME) DENSITY GRAVITY Kair OIL WATER ft md % % % gm/cc deg API CORE 3 6592.0 - 6651. 7 ANALYSIS BEGINS HERE 325 6616.5 0.09 17.4 31.8 45.6 3.10 27. SS,olvgy,vf-mgr,pred fgr,wsrtd,sbrd-rd,wcons,patchy cmt,poss sid-ank,mnr glauc 326 6617.4 0.11 22.0 27.8 56.5 3.00 SS,olvgy,vf-mgr,pred fgr,mod wsrtd,sbrd-rd,wcons-fri,poss sid-ank,glauc . 327 6618.5 0.51 23,8 23.8 65.7 3.06 SS,dkgrgy,vf-mgr,pred fgr,mod wsrtd,sbrd-rd,wcons,poss sid-ank,glauc 328 6619.4 1.44 25.1 32.5 30.1 3.03 SS, ltolvgy,vf-cgr,pred mgr,mod wsrtd,sbrd-rd,wcons-slfri,poss sid-ank,glauc 329 6620.4 23.9 24.2 39.4 41.7 2.86 27. SS,dkgrgy,vf-cgr,pred f-mgr,psrtd-mod wsrtd,sbrd-wrd,pred slfri,poss sid-ank 330 6621. 5 0.13 21.9 34.8 30.4 3.05 SS, ltolvgy,vf-mgr,pred fgr,mod wsrtd,sbrd,pred wcons,poss sid-ank,glauc 331 6622.4 1132. 26.4 38.1 33.7 2.75 SS,dkgrgy,vf-cgr,pred f-mgr,psrtd-mod srtd,sbrd-wrd,fri,mnr poss sid-ank,glauc 332 6623.2 1.56 16.0 25.8 60.2 2.75 SS,olvblk,vf-mgr,pred vfgr,mod wsrtd,sbrd-wrd,wcons-fri,mnr sid-ank,abnt glauc 333 6624.3 <.01 1.6 47.8 27.3 3.22 SS.olvgy,vfgr,wsrtd,sbrd,vwcons,slcalc,abnt poss sid-ank cmt,mnr calcxl fracs 334 6625.6 1.51 12.9 31.9 56.6 2.72 20. SLTST,olvgr,vsdy,arg,wcons,10-15% slty,sdy,mic,bdd mdst,2-3%pyr,tr carb ** 335 6626.3 0.25 12.3 36.3 52.7 2.67 MDST,dkgy,slty,vmic,wcons,30% vfgr,wsrtd,bdd ss,tr pyr 336 6627.4 0.55 11.0 49.7 18.4 2.62 SS, ltolvgy,vfgr.wstrd,sbrd-rd,wcons,tr-l% pyr,sdy burs 337 6628.3 0.22 9.8 14.8 78.5 2.64 MDST,slty,mic,wcons,20% sdy,mic,intbd,sltst 338 6629.4 0.04 10.6 37.0 55.1 2.62 MDST,dkgy,slty,mic,wcons,30-40%sdy,bioturb,intbd,sltst 339 6630.3 0.70 12.5 40.1 43.5 2.65 22. MDST,dkgy,slty,mic,wcons,30%vfgr,wsrtd, lam ss.tr-l% pyr 340 6631.3 0.40 11.3 24.5 60.5 2.66 MDST,dkgy,slty.sdy in places,mic,wcons,20-30% vfgr,wsrtd, lam ss.tr pyr 341 6632.3 0.20 13.5 39.5 47.4 2.63 MDST,dkgy,slty,mic,wcons,40% vfgr,wsrtd,lam ss,tr pyr 342 6633.3 1.09 11.5 26.4 65.1 2.64 MDST,dkgy,slty,sdy in places,mic,wcons,20-30% vfgr,wsrtd,bioturb ss 343 6634.4 0.46 11.4 14.8 74.2 2.67 MDST,dkgy,slty,sdy in places,mic.wcons.20-30% vfgr,wsrtd,bioturb ss 344 6635.4 19.0 13.1 41. 0 38.5 2.65 24. SS, ltolvgy.vfgr,vwsrtd,sbrd-rd,wcons,30% slty,sdy,mic,bdd mdst ** 345 6636.3 1.05 16.9 39.6 47.8 2.66 SS, ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,30% slty,sdy,mic.bdd mdst 346 6637.6 12.8 23.6 61.9 2.68 MDST,dkgy,slty,mic,wcons,30% vfgr,wsrtd, lam sS,(broken) 347 6638.5 1.49 12.5 32.0 49.4 2.67 SLTST,olvgy,sdy,mic,wcons,20-30% slty, lam mdst 348 6639.2 0.07 11.3 17.8 75.8 2.66 MDST,dkgy,sdy,vmic,wcons,30-40% sdy,bioturb,bdd,sltst 349 6640.4 5.50 11.4 25.2 60.8 2.65 22. SS, ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons,30% sdy,mic,intbd mdst 1 1 J fj .. ! ~, 1 ~ ~ }.... I-- I·... -,.... J"'" J-- 1- CORE LABORATORIES Field : KUPARUK RIVER UNIT File No.: BP-3-1281 Formation : KUPARUK Date : 5-Aug-1988 COR E A N A L Y S I S RES U L T S t } 1 ,. Company : ARCa ALASKA INC. Well KRU 30-12 I I I I I SATURATION I I I I SAMPLE DEPTH PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair OIL WATER ft md % % % gm/ee deg API 350 6641.4 1.30 13.6 27.0 61.4 2.66 SS, ltolvgy,vfgr.wsrtd,sbrd-rd,weons,30-40% slty,sdy,mie,mdst,hvy bioturb 351 6642.2 0.68 11.6 25.7 66.0 2.66 SS. ltolvgy.vfgr.wsrtd.sbrd-rd,weons,30-40% slty.sdy.mie.mdst,tr pyr.bioturb 352 6643.4 0.13 11.2 31.1 46.6 2.66 MDST,dkgy,slty,sdy mie.weons.20-30% vfgr,wsrtd.bioturb, lam ss 353 6644.4 4.02 10.9 37.7 48.4 2.65 SS. ltolvgy.vf-fgr.pred vfgr,wsrtd,sbrd-rd.weons.40% slty.bioturb mdst ** 354 6645.5 24.8 10.2 14.1 77.7 2.67 22. MDST,dkgy,slty,mie,weons.30% sdy sltst.tr pyr.bioturb,(broken) 355 6646.4 0.40 9.6 8.5 82.7 2.68 HDST.dkgy,slty.mie.weons.5% sdy burs,l% pyr 356 6647.4 <.01 7.8 0.0 96.8 3.12 HDST,olvgy,slty.sdy in plaees.vweons,5% sdy burs.1%pyr 357 6648.4 14.2 10.7 10.2 84.1 2.66 HDST.dkgy,slty.sdy in plaees.bioturb.10-20% vfgr,wsrtd. lam ss ** 358 6649.2 0.21 12.1 33.3 49.3 2.65 SLTST. ltolvgy,vsdy.weons.bioturb,10% slty,mie,bdd mdst 359 6650.4 20.8 10.0 21.5 71.2 2.64 17. HDST,dkgy,slty,mie.weons,20% vfgr.bioturb ss,tr pyr,(broken) 360 6651. 3 7.17 9.8 35.7 54.9 2.64 HDST.dkgy,slty.mie.weons.20% vfgr.bioturb ss.tr pyr.(broken) CORE 4 6652.0 - 6713.8 401 6652.2 1.52 10.0 1.9 91.1 2.65 HDST.dkgy,pred slty,weons.mie.20-30% lam.sltst,l% pyr ** 402 6653.4 0.87 8.9 10.1 84.5 2.66 HDST,dkgy,pred arg.sdy in plaees,weons,blky.1-3% pyr,mnr slty lams 403 6654.2 2.46 10.3 12.6 80.6 2.65 HDST,dkgy.pred arg,sdy.weons,tr pyr, (broken) 404 6655,4 0.30 10.6 12.1 81.0 2.84 22. HDST,olvgy,pred arg.slty.weons.dnse.poss sid-ank,mnr slty lens,tr pyr ** 405 6656.3 11.1 6.3 90.3 2.69 HDST,dkgY.pred arg,wcons.mnr sdy lam, (irregular spl) 406 6657.6 0.32 9.4 10.0 85.2 2.68 HDST,dkgy,pred arg.slty.weons.5% slty lams.1-2% pyr ** 407 6658.3 <.01 2.5 8.0 82.0 3.19 HDST,olvgy,sdy,vweons.dnse,poss sid-ank.abnt sdy poekets.pyr 408 6659.3 4.16 12.7 29.0 58.8 2.65 SS,ltolvgy,vf-fgr.wsrtd.sbang-sbrd,weons.tr earb frags.mnr pyr,mnr mdy lams 409 6660.3 0.29 12.9 30.5 60.0 2.64 18. SS, ltolvgy,vfgr,wsrtd.sbrd-rd,weons,30-40% sdy,mie, lam mdst,bioturb 410 6661.4 0.23 11.6 28.4 64.6 2.65 HDST,dkgy,sdy,mie.weons.30% vfgr, lam and bioturb ss 411 6662.2 0.97 11.2 32.7 50.3 2.64 HDST,dkgy.sdy.weons,30% vfgr,hvy bioturb ss,tr pyr ** 412 6663.3 0.56 10.4 31. 5 52.7 2.65 HDST,dkgy,vsdy,mie,30% vf-fgr,hvy bioturb ss,tr pyr, lam 413 6664.4 1.21 12.7 35.0 51.8 2.64 SS, ltolvgy,vfgr,wsrtd,sbrd-rd,weons,30% slty.mie.lam mdst,tr pyr.x-lams 414 6665.2 10.1 11.2 36.7 51.6 2.66 17. SS,ltolvgy,vfgr,wsrtd,sbrd-rd,weons,40% slty,thkly lam mdst ** 415 6666.1 0.52 12.2 28.5 50.7 2.66 HDST,dkgy,slty.mie.sdy in plaees,20-30% vfgr,vwsrtd.sbrd-rd,weons ss 2 1 ~ ,t' t" r File No.: BP-3-1281 Date 5-Aug-1988 ). '';'" '\ \ J ~... t-' I-' Fr )" CORE LABORATORIES Field KUPARUK RIVER UNIT Formation KUPARUK COR E A N A L Y S I S RES U L T S J ) ) t Company ARCO ALASKA INC. Well KRU 30-12 I I I I I 5ATURATION I I I I SMil'L E DEPTH PERMEABILITY POR05ITY GRAIN OIL OE5CRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUME) DEN5ITY GRAVITY Kair OIL WATER ft md % % % gm/ee deg API 416 6667.3 491. 27.7 56.6 4.7 2.66 55,ltolvgy,vfgr,vwsrtd,rd-wrd,fri,tr pyr 417 6668.2 241. 26.1 51.0 4.0 2.66 55, ltolvgy,vfgr,wsrtd,rd-wrd,fri,tr pyr lams 418 6669.5 417. 27.3 58.5 4.0 2.68 55,ltolvgy,vfgr,vwsrtd,rd-wrd,fri,pyr filled frae 419 6670.3 172. 25.6 52.5 6.2 2.66 22. 55, ltolvgy,vfgr,wsrtd,sbrd-rd,fri,mnr arg lams ** 420 6671.3 49.6 19.9 46.9 5.1 2.78 55, ltolvgy,vfgr,wsrtd,sbrd-rd,fri,20% slty,dnse,bd mdst,poss sid-ank 421 6672.4 172. 27.4 57.0 3.6 2.68 55,ltolvgy,vfgr,vwsrtd,rd-wrd,fri,tr pyr,mnr arg lams 422 6673.5 37.7 26.1 52.9 5.3 2.68 55, ltolvgy,vfgr,wsrtd,sbrd-rd,fri,mnr mdy lams 423 6674.5 137. 27.3 56.5 6.9 2.70 25. 55, ltolvgy,vfgr,wsrtd,rd-wrd,fri,mnr mdy lams ** 424 6675.7 57.4 22.9 56.0 8.2 2.65 55, ltolvgy,vfgr,wsrtd,sbrd-rd,fri,5-10% slty,vmic, lam mdst,tr earb frags 425 6676.5 31.9 16.3 69.1 17.8 2.66 55,ltolvgy,vfgr,wsrtd,sbrd-rd,sl fri,15-20% sdy,mie,thkly lam mdst,pyr lam ** 426 6677 . 2 12.8 27.2 45.7 2.63 MD5T,dkgy,pred slty,mie,weons,10-15% vfgr,intbd sS,(broken) 427 6678.6 11.7 12.7 59.1 33.7 2.64 MD5T,dkgy,slty,sdy,weons,30-40% vf-fgr,wsrtd,sbrd-rd,slfri ss,tr pyr ** 428 6679.2 0.91 14.2 37.0 46.4 2.66 22. 55,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,10-20% slty,mic, lam mdst 429 6680.3 5.33 11.4 33.5 40.5 2.65 MD5T,dkgy,pred slty,weons,20-30% vfgr,wsrrd,sbrd-rd,wcons-slfri ss ** 430 6681. 3 1.18 11.7 46.6 29.8 2.70 5LT5T,olvgy,sdy,20%lam mdst,20% vfgr,slty, lam sS,l-2% pyr,spl is weons 431 6682.6 40.3 14.4 39.2 33.3 3.16 55, ltolvgy,vfgr,wsrtd,sbrd-rd,weons-slfri,20-30% slty,mie, lam mdst,tr pyr ** 432 6683.9 5.91 14.3 41.3 37.9 2.66 55, ltolvgy,vfgr,vwsrtd,sbrd-rd,fri,20-30%sdy,bioturb, lam mdst 433 6684.3 309. 17.0 42.9 16.7 2.70 24. 55, ltolvgy,vfgr,wsrtd,sbrd-rd,weons-slfri,20% slty,vmic, lam mdst,pyr,(broken) 434 6685.4 11.5 19.9 50.8 8.3 2.75 55, ltolvgy,vfgr,wsrtd,sbrd-rd,weons-slfri.tr arg lams 435 6686.6 69.2 19.8 51.4 8.4 2.65 55, ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri,mnr arg lam 436 6687.5 78.1 24.2 52.8 6.7 2.68 55,ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri 437 6688.6 118. 25.4 51.9 7.8 2.64 55, ltolvgy,vfgr,vwsrtd,sbrd-rd,fri,mnr arg lams 438 6689.4 92.3 26.5 51.2 7.7 2.65 24. 55, ltolvgy,vfgr,vwsrtd,sbrd-rd,fri,tr arg lams 439 6690.6 21.5 20.4 50.1 8.0 2.63 55, ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri,5% vmic,mdy lams,(broken) 440 6691. 3 92,0 15.1 52.5 26.3 2.69 55, ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri,30% slty, lam,mdst, (broken) 441 6692.5 106. 26.3 52.6 4.6 2.66 55,ltolvgy,vfgr,vwsrtd,sbrd-rd,fri 442 6693.9 182. 28.5 54.7 5.3 2.66 23. MD5T,dkgy,pred arg,slty,weons,mnr sdy lams,mnr frae 443 6694.4 149. 28.7 50.8 34.5 2.67 55,ltbrn,vfgr,vwsrtd,sbrd-rd,slfri,(broken) 444 6695.5 11.0 17.5 54.9 23.4 2.65 55, ltolvgy,vfgr,vwsrtd,sbrd-rd,weons-slfri,10-15% slty,mie, lam mdst ** 3 1 1. 1- ... ~ -1.. '}--' }... J- -1~ 1 } 1 .... ) --. J ) ) 1 BP-3-1281 5-Aug-1988 F i1 e No Date LABORATORIES KUPARUK RIVER UNIT KUPARUK Field Formati CORE INC ARCO ALASKA KRU 30-12 Company Well s T L U s E R s on I s y L A N A E R o c DE5CRIPTION OIL GRAVITY GRAIN DEN5ITY 5ATURATION VOLUME) WATER % (PORE OIL % POROSITY (HELIUM) PERMEABI LITY (HORIZONTAL) Kair md DEPTH ft SAMPLE NUMBER mdst ** ,15-20% slty,mie lam 10% slty,mie lam mdst bioturb lams , i i weons slfd, slfri slfr slfr , sbrd-rd sbrd-rd ,sbrd-rd sbrd-rd ltolvgy,vfgr,vwsrtd ltolvgy,vfgr,vwsrtd ltolvgy,vfgr,vwsrtd ltolvgy,vfgr,wsrtd, ltolvgy,vfgr.vwsrtd , , , SS 5S 55 55 55 deg API ** sdy,wemtd.hd mdy , lam mdst slty, lam mdst ** slty. lam mdst pyr mdst mdst vsdy is ) lam mdst , , ,10-15% ,10-15% weons,20% sdy,mie,bdd mdst sltst,10% slty,mie, lam emtd sltst poss s;d-an~ ,(broken ** ) lams e mdst ss ss, (broken bro~en) sdy,mi slty ,mnr 10% sltst, weons weons sbrd-rd to ft-'" sbr d sbr d sbr d to wUJ , SS,ltolvgy vfgr,grades 55,ltolvgy vfgr,vwsrtd 55,ltolvgy vfgr,vwsrtd S5,ltolvgy vfgr,vwsrtd 55,ltolvgy vfgr,grades MD5T.olvgy,grades to , , 22 22 e sdy,dnse ,sbrd-rd,weons,5% arg, weons ,grades to : MD5T,d~gy,sdy,weons,20-30% vf-fgr,wsrtd,bioturb MD5T,dkgy,slty,mie,weons,10-15% vfgr,biDturb HD5T,dkgy,slty,mie,weons,40-50% vfgr lam ss, 55,ltolvgy,vfgr,vwsrtd,sbrd-rd 40-50% MD5T.dkgy,slty,mie,30% vfgr.s ss mdy sdy,mi ( , weons bdd 5S,ltolvgy,vfgr.vwsrtd SLT5T ltolvgy,vsdy 16 gm/ee 2.71 2.70 2.63 2.65 2.68 2.64 2.64 2.64 2.66 2.63 3.08 2.64 2.64 2.63 2.63 2.63 2.63 2.62 9.4 7.7 22.9 19.2 29.8 17.8 23.2 34.5 13.0 28.6 33.3 48.8 29.5 67.4 35.8 61.8 38.6 67.8 51.3 50.4 52.2 55.3 47.3 55.4 48.2 38.5 56.7 44.5 48.5 32.4 49.5 27.4 49.0 29.3 32.7 25.8 % 26.7 24.9 16.3 20.0 23.3 18.9 17.4 17.9 18.4 17.3 7.3 17.7 16.5 10.3 10.3 11.5 13.5 12.6 89.9 49.8 10.5 34.7 31.5 1.95 8.11 1.53 7.02 0.85 0.01 2.61 23.4 6.34 14.6 169. 9.48 1.34 6696,4 6697.6 6698.6 6699.1 6700.7 6701. 5 6702.3 6703.2 6704.3 6705.5 6706.6 6707.3 6708.5 6709.4 6710.6 6711. 7 6712.2 6713.5 445 446 447 448 449 450 451 452 453 454 455 456 457 458 459 460 461 462 lty 18 ** , arg,mie,intbd mdst,pyr,earb frags lam mdst,tr earb frags 10-15% mie,intbd mdst,I-2% wthrd pyr 10% lam mdst,l% wthrd pyr mnr sid-ank lam mdst 4 ) 1 (broken oturb ** bioturb , e i slty,mi sS,mnr pyr,b 30% lam mdst 30% 5% poss 10-2% e,5-7% lam sbrd,weons, sbrd,weons, sbrd,weons, sbrd,weons, sbrd,weons, sbrd,weons, sbrd,weons, 6746.8 MD5T,dkgy,slty,weons,mi 5S,ltolvgy,vfgr,vwsrtd 55,ltolvgy,vfgr,vwsrtd 55,ltolvgy.vfgr.vwsrtd 5S, 55, 55, 55, ltolvgy,vfgr,vwsrtd ltolvgy,vfgr,vwsrtd vfgr.vwsrtd vfgr.vwsrtd ltolvgy ltolvgy 6713.8 22 CORE 5 66 66 75 64 65 64 72 66 2. 2 2 2. 2 2 2 2 73.3 23.5 32.8 28.8 18.2 37.1 47.6 36.1 18.7 54.2 43.1 43.3 51.1 41.7 31.9 43.3 11.8 15.8 14.8 16.0 15.9 13.9 20.0 12.8 0.84 4.67 4.28 0.46 1.91 1.11 39.9 6714.3 6715.1 6716.3 6717.2 6718.2 6719.5 6720.3 6721.3 501 502 503 504 505 506 507 508 I~·~ }-- )-'"' ç-' File No.: BP-3-1281 Date : 5-Aug-1988 . ) I t . 1 J-- I·· . CORE LABORATORIES Field KUPARUK RIVER UNIT Formation KUPARUK COR E A N A L Y S I S RES U L T S l, } ) J Company : ARCO ALASKA INC. Well : KRU 30-12 SATURATION SAMPLE DEPTH PERMEABILITY POROSITY GRAIN OIL DESCRIPTION NUMBER (HORIZONTAL) (HELIUM) (PORE VOLUME) DENSITY GRAVITY Kair OIL WATER ft md % % % gm/ee deg API 602 6751.4 0.77 13.0 36.6 51.2 2.61 22. SS,ltolvgy.vfgr,vwsrtd,sbrd-rd,weons,30-40% bioturb, lam mdst 603 6752.6 0.31 10.5 26.5 63.9 2.62 MDST,dkgy,slty,tr sd,mie,weons,15-20% vfgr, lam sS,mnr sdy burs 604 6753.6 0.94 14.0 41.9 51.8 2.62 SS. ltolvgy,vfgr,vwsrtd,sbrd-rd,weons,10-15% mie,intbd,and x-lam mdst 605 6754.3 0.49 11.9 37.8 42.2 2.62 MDST,dkgy,pred slty,mie,weons,40% vfgr, lam ss,2-3% earb frags 606 6755.3 3.33 16.5 50.8 20.8 2.65 SS, ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,5-10% mdst 607 6756.3 1. 76 13.1 26.3 66.6 2.62 18. SS,ltolvgy,vfgr,vwsrtd,sbrd-rd.weons,40-50% pred slty,mic,intbd mdst 608 6757.5 0.49 13.1 28.7 64.8 2.62 SS, ltolvgy,vfgr,wsrtd,sbrd·rd,weons,40-50% pred slty,mie,bioturb, lam mdst 609 6758.5 2.56 14.2 27.0 65.4 2.64 S5,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,40-50% pred slty,mie. lam mdst,tr carb 610 6759.6 0.36 11.1 22.7 70.2 2.61 MDST.dkgy,pred slty,sdy,mie,10-15% vfgr, lam ss 611 6760.4 2.25 10.9 31.7 60.7 2.60 MDST,dkgy,pred slty,mnr sdy lams,10% vfgr,sdy burs,1-2% carb frags ** 612 6761.2 0.70 12.2 47.8 20.3 2.61 22. MDST,dkgy,pred slty,sdy,weons,20-30% vfgr, lam ss and sdy burs 613 6762.5 6.82 14.5 32.9 60.7 2.64 MDST,dkgy,pred slty,sdy,wcons,mic,30-40% vfgr,sbrd-rd,bdd ss,2% carb frags ** 614 6763.3 4.27 18.6 45.9 21.6 2.64 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,mnr arg lams,l% carb frags 615 6764.5 0.12 4.2 32.6 58.4 2.97 SS, ltolvgy,vfgr,wsrtd,sbrd-rd,vwcons,dnse,poss sid-ank,mnr mdy lams 616 6765.4 2.25 11.7 33.5 54.6 2.61 18. MDST,dkgy,pred arg.mic,wcons,mnr sdy lams ** 617 6766.5 0.41 12.1 31.7 59.9 2.62 MD5T.dkgy,pred arg,slty,wcons,mnr sdy lams,mnr frae 6 1 - }... 1- J.., ),... .L.. ,l.. CMS OVERBURDEN RESULTS ..L 1 ~ .- ~ .. ..... - ~ - ~- 1 t-' ) } J } ) ) ) ) .1-- -}- J... )..- )~ }- ).- C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg F ld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : ûVERBüRûEN PRESSüRE ANALYSIS "..it" "')nn ,,",I·I~-~VU SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION -.. - .. .... .......... ----........ ----- -..----- ............- --- --........................................ ..---.. 327 6618_5 ATM 23.8 0.51 SS,dkgrgy,vf-mgr,pred fgr,mod wsrtd,sbrd-rd,wcons,poss sid-ank,glauc 1000 23.4 0.22 0.44 3000 23.2 0.19 0.39 328 6619_4 ATM 25.1 1.44 SS,ltolvgy,vf-cgr,pred mgr,mod wsrtd,sbrd-rd,wcons-slfri,poss sid-ank,glauc 1000 25.2 0.97 1.44 3000 24.9 0.89 1.33 329 6620.4 ATM 24.2 23.93 SS,dkgrgy,vf-cgr,pred f-mgr,psrtd-mod wsrtd,sbrd-wrd,pred slfri,poss sid-ank 1000 24.5 16.69 19.46 3000 23.8 15.06 17.44 332 6623.2 ATM 16 1.56 SS,olvblk,vf-mgr,pred vfgr,mod wsrtd,sbrd-wrd,wcons-fri,mnr sid-ank,abnt glauc 1000 15.6 0.26 0.47 3000 15.1 0.10 0.22 334 6625.6 ATM 12.9 1.51 SLTST,olvgr,vsdy,arg,wcons,10-15% slty,sdy,mic,bdd mdst,2-3%pyr,tr carb ** 1000 12.7 0.26 0_41 3000 12.1 0.08 0.16 336 6627.4 ATM 11 0.55 SS,ltolvgy,vfgr,wstrd,sbrd-rd,wcons,tr-1% pyr,sdy burs 1000 10.1 0.14 0.24 3000 9.7 0.05 0.09 339 6630.3 ATM 12.5 0.7 MDST,dkgy,slty,mic,wcons,30%vfgr,wsrtd,lam ss,tr-1% pyr 1000 11.9 0.14 0.24 3000 11.6 0.03 0.07 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. ) , ) 1 } , J ) l 1 r J r r í J ~_nr "'~.__.__..J .. 1 C 0 R E L A B 0 R A T 0 R E S Areo Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud' Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION --......- ..---- ...... .. .. .. .... ........ ..---- .. .. .. .. .. .... .. .. .. .... .. .. .... ........ .. .. .. .... .. .. .. .. .. .. .. .. .. .. .. 342 6633.3 ATM 11.5 1.09 MDST,dkgy,slty,sdy in places,mic,wcons,20-30% vfgr,wsrtd,bioturb ss 1000 11.4 0.14 0.20 3000 10.9 0.01 0.04 344 6635.4 ATM 13.1 18.99 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,30% slty,sdy,mic,bdd mdst ** 1000 12.6 4.77 5.12 3000 12.2 0.88 1.01 345 6636.3 ATM 16.9 1.05 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,30% slty,sdy,mic,bdd mdst 1000 16.7 0.31 0.55 3000 16.3 0.14 0.32 347 6638.5 ATM 12.5 1.49 SLTST,olvgy,sdy,mic,wcons,20-30% slty,lam mdst 1000 11.1 0.25 0.30 3000 10.7 0.04 0.06 349 6640.4 ATM 11.4 5.5 SS,ltolvgy,vf-fgr,pred vfgr,wsrtd,sbrd-rd,wcons,30% sdy,mic,intbd mdst 1000 10.8 1. 11 1.33 3000 10.4 0.19 0.29 350 6641. 4 ATM 13.6 1.3 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,30-40% slty,sdy,mic,mdst,hvy bioturb 1000 13.3 0.37 0.60 3000 12.8 0.14 0.28 351 6642.2 ATM 11.6 0.68 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons.30-40% slty,sdy,mic,mdst,tr pyr,bioturb 1000 10.9 0.10 0.21 3000 10.6 0.02 0.04 (ATM) Measured Ka and Por are taken fron the conventional core analysis results ) r -l r } ) .. 1 , J )- )-- r r -r t 'f '1" r C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS" CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (00) (00) DESCRIPTION .. .... .. .... .......... .. .......... .... ........... ----- .......... .. ... .. .. .. .. .... .. .. .. .... .. .. .. .. .. .. .. .... ...... .... ...... .. 355 6646.4 ATM 9.6 0.4 MDST,dkgy,slty,mic,wcons,5% sdy burs, 1% pyr 1000 9_0 0.07 0.10 3000 8_5 0.00 0.01 357 6648.4 ATM 10.7 14.2 MDST,dkgy,slty,sdy in places,bioturb,10-20% vfgr,wsrtd,lam ss ** 1000 9.6 5.13 5.49 3000 9.2 0.69 0.76 401 6652.2 ATM 10 1.52 MDST,dkgy,pred slty,wcons,mic,20-30% lam,sltst,1% pyr ** 1000 9.0 0.07 0.11 3000 8.7 0.02 0.03 408 6659.3 ATM 12.7 4.16 SS,ltolvgy,vf-fgr,wsrtd,sbang-sbrd,wcons,tr carb frags,mnr pyr,mnr OOy lams 1000 12.6 2.21 2.88 3000 12.3 1.79 2.34 411 6662.2 ATM 11.2 0.97 MDST,dkgy,sdy,wcons,30% vfgr,hvy bioturb ss,tr pyr ** 1000 10.6 0.21 0.37 3000 10.2 0.03 0.06 412 6663.3 ATM 10.4 0.56 MDST,dkgy,vsdy,mic,30% vf-fgr,hvy bioturb ss,tr pyr,lam 1000 9.8 0.08 0.14 3000 9.4 0.02 0.04 413 6664.4 ATM 12.7 1.21 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,30% slty,mic,lam OOst,tr pyr.x-lams 1000 12.1 0.65 0.93 3000 11.8 0.53 0.73 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. 1 1 r )'" ) 1 1 ) 1 1 1 -l~ r .... ~ 't" 'r C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : n\l~DI""ID~rU nDI:'~C'IIDI:' A..IAI V~T~ .. rMc:..,nn UVL.f'\.DUf\LofI..I-' r n.L..v..nJI'''' rI.."... '''''.._ ......... -....... SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION ...... ...... .......... ................. ---- ......... .. .. .... .. .. .. --........ ---..-.... --...................... --.. 414 6665.2 ATM 11.2 10.05 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,40% slty,thkly lam mdst ** 1000 10.5 3.67 4.80 3000 10.1 1.29 1.57 415 6666.1 ATM 12.2 0.52 MDST,dkgy,slty,mic,sdy in places,20-30% vfgr,vwsrtd,sbrd-rd,wcons ss 1000 11.7 0.13 0.21 3000 11.4 0.04 0.09 416 6667.3 ATM 27.7 491.05 SS,ltolvgy,vfgr,vwsrtd,rd-wrd,fri,tr pyr 1000 27.8 419.25 436.36 3000 27.4 405.13 422.61 417 6668.2 ATM 26.1 241.44 SS,ltolvgy,vfgr,wsrtd,rd-wrd,fri,tr pyr lams 1000 25.9 215.67 228_57 3000 25.6 208.82 221.24 418 6669.5 ATM 27.3 416.91 SS,ltolvgy,vfgr,vwsrtd,rd-wrd,fri,pyr filled frac 1000 27.0 377.03 393.97 3000 26.7 364.73 381.36 419 6670.3 ATM 25.6 171.88 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,fri,mnr arg lams ** 1000 25.3 133.91 146.04 3000 25.0 114.58 124.57 420 6671.3 ATM 19.9 49.56 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,fri,20% slty,dnse,bd mdst,poss sid-ank 1000 19.7 42.32 46.20 3000 19.4 41.02 44.69 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. 1 1--' 1 ) 1 \ , t 1 1 l~ 1- -1-'" .... t-J }- t' }-' C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS ~ CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION .... .. .. .... .......... .... ......... ..... .......... .. .. .... .. ----...... .... .. .. .. .. .. .. .. .. .. .. .. .... .... .. ............ .. .... .. .. 421 6672.4 ATM 27.4 172 SS,ltolvgy,vfgr,vwsrtd,rd-wrd,fri,tr pyr,mnr arg lams 1000 27.1 149.11 160.45 3000 26.7 142.30 153.66 422 6673.5 ATM 26.1 37.74 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,fri,mnr mdy lams 1000 25.4 30.53 35.33 3000 25.0 29.18 33.86 423 6674.5 ATM 27.3 136.82 SS,ltolvgy,vfgr,wsrtd,rd-wrd,fri,mnr mdy lams ** 1000 26.8 109.35 119.03 3000 26.5 104.12 113.71 424 6675.7 ATM 22.9 57.39 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,fri,5-10% slty,vmic,lam mdst,tr carb frags 1000 22.4 46.55 51.31 3000 22.0 44.42 48.91 425 6676.5 ATM 16.3 31. 95 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,sl fri,15-20% sdy,mic,thkly lam mdst,pyr lam ** 1000 15.8 7.08 7.73 3000 15.4 1.14 1.53 427 6678.6 ATM 12.7 11. 72 MDST,dkgy,slty,sdy,wcons,30-40% vf-fgr,wsrtd,sbrd-rd,slfri ss,tr pyr ** 1000 12.0 2.22 2.69 3000 11.6 0.77 1.06 429 6680.3 ATM 11.4 5.33 MDST,dkgy,pred slty,wcons,20-30% vfgr,wsrrd,sbrd-rd,wcons-slfri ss ** 1000 10.6 0.77 0.91 3000 10.1 0.10 0.15 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. 1 1 ) J 1 ) -1- l 1 1- r r 'r r r T' -r "--1 Jr..--... 1 C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION ...... .. .... .......... .. .. .. .......... ........ .......... ........ .. .... ...... ----...... ---.............. -- ---......- 430 6681.3 ATM 11.7 1.18 SLTST,olvgy,sdy,20%lam mdst,20% vfgr,slty,lam 5S, 1-2% pyr,spl is wcons 1000 10.9 0.15 0.21 3000 10.6 0.02 0.04 432 6683.9 ATM 14.3 5.91 SS,ltolvgy,vfgr,vw5rtd,sbrd-rd,fri,20-30%sdy,bioturb,lam mdst 1000 13.8 3.88 4.76 3000 13.5 3.47 4.20 433 6684.3 ATM 17 309 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons-slfri,20% slty,vrnic,lam mdst,pyr,(broken) 1000 16.7 37.85 46.02 3000 16.2 23.10 27.07 434 6685.4 ATM 19.9 11.49 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons-slfri,tr arg lams 1000 19.7 8.87 10.80 3000 19.4 8.54 10.41 435 6686.6 ATM 19.8 69.17 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri,mnr arg lam 1000 19.5 56.40 61.87 3000 19.2 54.38 59.68 436 6687.5 ATM 24.2 78.15 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri 1000 24.1 65.81 73.26 3000 23.8 63.48 70.85 437 6688.6 ATM 25.4 118.31 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd.fri.mnr arg lams 1000 25.2 100.51 109.53 3000 24.8 96.07 104.88 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. 1 l~ r .,. 1 } 1, 1 ) --I )~ l~ 1 'J.-- r- .... to ~ 1" C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS, TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION ---....- ----- --....-..-- ----- ...... .... ....... .. .. ..... ---.. ----- -- .._..-..--- --................ 438 6689.4 ATM 26.5 92.28 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,fri,tr arg lams 1000 26.3 75.89 84.68 3000 26.0 73.20 81.75 439 6690.6 ATM 20.4 21.5 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri,5% vrnic,mdy lams,(broken) 1000 20.1 15.80 18.24 3000 19.7 14_64 16.94 441 6692.5 ATM 26.3 106.01 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,fri 1000 26.1 89.00 99.16 3000 25.8 86.04 95.86 442 6693.9 ATM 28.5 181.58 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,fri,tr pyr 1000 28.3 150.04 163.36 3000 28.0 144.70 157.74 444 6695.5 ATM 17.5 11. 04 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons-slfri.10-15% slty,mic,lam mdst ** 1000 16.7 4_66 5.77 3000 16.3 2.15 2.77 445 6696.4 ATM 26.7 89.95 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri 1000 26.5 74.00 83.07 3000 26.3 71.62 80.39 446 6697.6 ATM 24.9 49.83 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd.slfr 1000 24.8 36.17 41.79 3000 24.5 34.93 40.45 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. 1 1-' ~ ,. l I 1 } -1 ) 1 1 --- r- ..... -\-' r- )"" c 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : OZ-August-88 File No : BP-3-1281 KRU 30-12 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-ZOO SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION .. -.... .... .......... ........... ...... ........... ...... .. .. .. .. .. ...... .... .. .... .. .. .... .... .... ...... .. ... .. .. .... .... .. .... .... .. .. .. 447 6698.6 ATM 16.3 10.53 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,15-20% slty,mic,lam mdst 1000 15.7 4.85 5.78 3000 15.3 3.29 4.04 448 6699. 1 ATM 20 34.69 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,slfri,10% slty,mic,lam mdst ** 1000 19.5 18.18 20.87 3000 19.1 8.14 9.66 449 6700.7 ATM 23.3 31.49 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri,mnr bioturb,mdy lams 1000 23.0 25.42 29.65 3000 22.7 24.39 28.50 450 6701.5 ATM 18.9 1.95 SS,ltolvgy,vfgr,grades to sdy sltst,10% slty,lam mdst 1000 18.8 1.14 1.76 3000 18.4 1.00 1.56 451 6702.3 ATM 17.4 8.11 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,10-15% slty,lam mdst ** 1000 17.1 2.89 3.52 3000 16.7 1.06 1.47 452 6703.2 ATM 17.9 1.53 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,10-15% slty,lam mdst 1000 17.5 0.95 1.45 3000 17.2 0.82 1.26 453 6704.3 ATM 18.4 7.02 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,20% sdy,mic,bdd mdst,pyr ** 1000 18.1 2.97 4.00 3000 17.8 2.53 3.49 (ArM) Measured Ka and Por are taken fron the conventional core analysis results. -1 t l' r 1 ì 1 1 ) 1 1 1 1 1" t ... t t C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 Fi le No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS .. CMS~200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION ...... .. .... .......... .. .... ........... ........ .. .. .. .. - ---......... .. .. .... .. ... .. .. .. .. .. .. .. .. .. ..... .. .. .. ...... .. ...... .. .. 454 6705.5 ATM 17.3 0_85 SS,ltolvgy,vfgr,grades to vsdy sltst,10% slty,mic,lam mdst 1000 17.0 0.50 0.89 3000 16.6 0.43 0.77 456 6707.3 ATM 17.7 2.61 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,5% mdy lams 1000 17.4 1.43 2.11 3000 17.1 1.23 1.85 457 6708.5 ATM 16.5 23.4 SLTST,ltolvgy,vsdy,arg,wcons,grades to sdy,mic mdst,(broken) 1000 16.2 5.11 5.68 3000 15.7 1.26 1.43 460 6711. 7 ATM 11.5 169.07 MDST,dkgy,slty,mic,wcons,40-50% vfgr,lam ss,(broken) 1000 10.8 14.66 22.84 3000 10.3 1.28 1.36 461 6712.2 ATM 13.5 9.48 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,40-50% sdy,mic,lam mdst 1000 12.7 2.42 2.66 3000 12.2 0.31 0.43 501 6714.3 ATM 11.8 0.84 MDST,dkgy,slty,wcons,mic,5-7% lam ss,mnr pyr,bioturb ** 1000 11.3 0.20 0.27 3000 10.8 0.03 0.04 502 6715.1 ATM 15.8 4.67 SS,ltolvgy,vfgr,vwsrtd,sbrd,wcons,30% lam mdst,bioturb ** 1000 15.4 1.13 1.53 3000 15.0 0.58 0.86 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. 1 r- }- }o'" r" )--' 1- C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 Fi le No BP-3·1281 KRU 30-12 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : 22'13N-9E API No OVERBURDEN PRESSURE ANALYSIS· CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (rod) (rod) DESCRIPTION .... .. .. .... .......... .... .. .. ........ ........ .. .. .. ...... .. .. .... .. .... .. .... .......-..........- --.. --.. --.. ...............- 503 6716.3 ATM 14.8 4.28 SS,ltolvgy,vfgr,vwsrtd,sbrd,wcons,30% arg,mic,intbd mdst,pyr,carb frags 1000 14.4 1.90 2.49 3000 14.0 1.10 1.52 504 6717.2 ATM 16 0.46 SS,ltolvgy,vfgr,vwsrtd,sbrd,wcons,5% lam mdst,tr carb frags 1000 15.8 0.22 0.41 3000 15.5 0.17 0.34 505 6718.2 ATM 15.9 1.91 SS,ltolvgy,vfgr,vwsrtd,sbrd,wcons,10'15% mic,intbd mdst,1'2% wthrd pyr 1000 15.4 0.82 1.21 3000 15.1 0.53 0.84 506 6719.5 ATM 13.9 1.11 SS,ltolvgy,vfgr,vwsrtd,sbrd,wcons,10% lam mdst,1% wthrd pyr 1000 13.4 0.33 0.52 3000 13.0 0.15 0.27 511 6724.2 ATM 15.1 1.07 SS,ltolvgy,vfgr,vwsrtd,sbrd,wcons,30-40% pred arg,intbd mdst,tr carb frags 1000 14.3 0.36 0.61 3000 13.9 0.23 0.41 512 6725.3 ATM 15.6 2.34 SS,ltolvgy,vfgr,vwsrtd,sbrd,wcons,mnr lam mdst 1000 15.1 0.99 1.47 3000 14.7 0.73 1.12 513 6726.3 ATM 15.3 4.41 SS,ltolvgy,vfgr,wsrtd,sbrd,wcons,20% lam mdst,tr pyr 1000 14.8 2.87 3.51 3000 14.3 2.44 3.01 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. ~ r t 1 1 \" ~ r ~ r t C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS, TOT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION ......--- ..-....- ....... .. ........ ........ .... .. .. .. ....... ...... .. __....00 __............ _...... .._.. _..00.. _........ 514 6727.4 ATM 21.7 28.78 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,slfri,tr mdy lams 1000 21.4 21.80 25.47 3000 21.1 20.96 24.50 515 6728.2 ATM 12.8 3.79 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,40-50% slty,mic,lam mdst ** 1000 12.2 0.89 1.19 3000 11.7 0.24 0.39 516 6729.2 ATM 21.5 17.23 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,mod cons,pyr frac 1000 21.3 13.77 16.52 3000 21.0 13.16 15.79 517 6730.3 ATM 19.8 35.89 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,mnr lam mdst 1000 19.7 28.39 32.08 3000 19.3 27.05 30.59 518 6731.2 ATM 13.7 1.19 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,30-40% bioturb lam mdst 1000 13.3 0.57 0.87 3000 12.8 0.40 0.62 519 6732.3 ATM 15.1 5.44 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,30-40% bioturb lam mdst 1000 15.0 1.38 1.74 3000 14.5 0.46 0.71 520 6733.3 ATM 13.9 1.24 SS,ltolvgy,vfgr,wsrtd,sbrd·rd,wcons,40% bioturb,mic.lam mdst 1000 13.5 0.61 0.93 3000 13.1 0.46 0.67 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. r r r- ... \--' t" 1"" C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCR I PTI ON ...... .. .... ........... .. ...... ........ ........ ....... .. .. .. .. .... .. .... .... .. -.. -- -_.......- ---................ ....-- ..-. 521 6734.3 ATM 14.2 3 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,30% bioturb,lam mdst 1000 13.7 1.00 1.40 3000 13.3 0.48 0.73 523 6736.8 ATM 11.9 0.49 MDST,dkgy.pred slty,mic,wcons,15-20% vfgr.lam ss 1000 11.6 0.13 0.22 3000 11.2 0.02 0.05 525 6738.6 ATM 12.1 20.24 MDST,dkgy,pred arg,wcons,15-20% vfgr,vwsrtd,bdd ss and sdy burs ** 1000 11.3 7.32 7.74 3000 10.9 1.96 2.14 526 6739.5 ATM 11.6 0.48 MDST,dkgy,pred slty,sdy,mic,10-15% vfgr.bioturb,lam ss 1000 11.2 0.14 0.24 3000 10.8 0.04 0.08 527 6740.3 ATM 12.1 5.2 MDST,dkgy,pred slty,mic,40-50% vfgr,vwsrtd,sbrd-rd,wcons,intbd and lam ss 1000 12.1 1.11 1.34 3000 11.5 0.17 0.27 528 6741.3 ATM 12.5 0.35 MDST,dkgy,pred slty.mic,40-50% vfgr,vwsrtd,sbrd-rd,wcons, lam ss 1000 12.1 0.11 0.19 3000 11.7 0.04 0.08 529 6742.1 ATM 11.7 2.42 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,40-50% bioturb,wvy lam mdst 1000 11.1 0.59 0.74 3000 10.7 0.15 0.22 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. 1 1 ...... r J I ) ]~ r r r r j c 0 R E L A B 0 R A T 0 R E S Areo Alaska, Inc Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR K HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION ~ .. .. .. .... .......... ......---.... ..--- .. ........ ........--- ...... ..---...... ----....-...... --.. -- --...- 530 6743.2 ATM 11.3 0.68 MDST,mdkgy,pred slty,sdy in places,30-40% vfgr,vwsrtd,sbrd-rd,lam ss 1000 10_8 0.15 0.25 3000 10.5 0.03 0.07 531 6744.3 ATM 12.2 0.24 MDST,dkgy,pred slty,mic,40% vfgr,vwsrtd,sbrd-rd,lam ss,abnt bioturb,tr pyr 1000 11.8 0.09 0.18 3000 11.4 0.04 0.09 532 6745.1 ATM 15.2 0.58 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,10-20% dkgy,sdy,mic,lam mdst 1000 15.1 0.29 0.53 3000 14.8 0.23 0.43 601 6750.4 ATM 12.9 0.38 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,40-50% lam mdst,tr carb trags 1000 12.4 0.09 0.18 3000 12.0 0.04 0.08 604 6753.6 ATM 14 0.94 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,10-15% mic,intbd,and x-lam mdst 1000 14.1 0.53 0.81 3000 13.3 0.36 0.57 605 6754.3 ATM 11.9 0.49 MDST,dkgy,pred slty,mic,wcons,40% vtgr,lam ss,2-3% carb frags 1000 11.6 0.10 0.17 3000 11.2 0.02 0.04 606 6755.3 ATM 16.5 3.33 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,5-10% mdst 1000 16.3 1.85 2.55 3000 15.9 1.59 2.22 (ATM) Measured Ka and Por are taken fron the conventional core analysis results. I' I 1~ ~ ]-'" J-- 1~ -"" )"'" r- C 0 R E L A B 0 R A T 0 R E S Arco Alaska, Inc. Date : 02-August-88 File No : BP-3-1281 KRU 30-12 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : 22-13N-9E API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) (md) DESCRIPTION ...... ...... ............ .. .. .. .. .. .. .... .......... ............. .. .. .. .. .. .. .. .. 00- __.. __............_ ..--................-.... 607 6756.3 ATM 13.1 1.76 SS,ltolvgy,vfgr,vwsrtd,sbrd-rd,wcons,40-50% pred slty,sdy,mic,intbd mdst 1000 12.9 0.66 0.95 3000 12.3 0.38 0.59 608 6757.5 ATM 13.1 0.49 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,40-50% pred slty,mic,bioturb,lam mdst 1000 12.9 0.14 0.25 3000 12.5 0.05 0.10 609 6758.5 ATM 14.2 2.56 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,40-50% pred slty,mic,lam mdst,tr carb 1000 13.6 0.73 0.98 3000 13.2 0.17 0.26 610 6759.6 ATM 11.1 0.36 MDST,dkgy,pred slty,sdy,mic,10-15% vfgr,lam ss 1000 10.7 0.10 0.18 3000 10.3 0.02 0.04 613 6762.5 ATM 14.5 6.82 MDST,dkgy,pred slty,sdy,wcons,mic,30-40% vfgr,sbrd-rd,bdd ss,2% carb frags ** 1000 13.7 1.36 1.54 3000 13.3 0.22 0.32 614 6763.3 ATM 18.6 4.27 SS,ltolvgy,vfgr,wsrtd,sbrd-rd,wcons,mnr arg lams. 1% carb frags 1000 18.1 2.09 2.92 3000 17.7 1.88 2.65 (ArM) Measured Ka and Por are taken fron the conventional core analysis results. - '1- '- }-.. 1-. .l- .L.. DEAN-STARK ANALYSIS RESULTS .L , - - - )... I 1~ ~.... CORE LABORATORIES BP-3-1281 18-Jul-1988 Fil e No. Date API No. Analysts TS,TT.PB 1 1 Field KUPARUK RIVER UNIT Formation KUPARUK Coring Fluid Elevation COR E A N A L Y S I S RES U L T S SATURATION SAMPLE DEPTH POROSITY NUMBER (HELIUM) (PORE VOLUME~ OIL WATE ft % % % DS 418 6669.3 26.6 67.0 3.5 DS 424 6675.6 26.5 59.0 4.2 DS 428 6679.9 11. 5 31.2 49.9 DS 434 6685.1 14.5 47.6 34.7 DS 439 6690.3 19.7 51.0 22.5 DS 445 6696.2 27.6 68.1 4.8 PLUGS DRILLED WITH ISOPAR AS A BIT COOLANT INC ARCO ALASKA, KRU 30-12 Company Well Location Co.State ALASKA NORTH SLOPE L... L L 1.. 1 ..-.0; SECTION 3 L CORE STATISTICAL DATA . ~ , , 1 - - - I I f: J 1 t" J""' 1-- t" V r ï ¡- CORE LABORATORIES Company ARCO ALASKA INC Field : KUPARUK RIVER UNIT File No BP-3-1281 Well KRU 30-12 Formation : KUPARUK Date 5-Aug-1988 TABLE I S U M MAR Y 0 F COR E OAT A - - ZONE AND CUTOFF DATA CHARACTERISTICS REMAINING AFTER CUTOFFS - - ZONE: ZONE: PERMEABILITY: Identification ----------- KUPARUK Number of Samples --- 148 Top Depth ---------------- 6616.0 ft Thickness Represented 98.1 ft Flow Capacity --------- 2934.0 md-ft Bottom Depth ------------- 6767.4 ft Arithmetic Average ---- 31.6 md Number of Samples -------- 148 POROSITY: Geometric Average ----- 2.59 md Harmonic Average ------ 0.09 md DATA TYPE: Storage Capacity - 1454.1 ¡þ-ft Minimum --------------- 0.00 md Porosity -------------- (HELIUM) Arithmetic Average 14.8 % Maximum --------------- 1132. md Permeability ------- (HORIZONTAL) Kair Minimum ---------- 1. 6 % Median ---------------- 2.25 md Maximum ---------- 28.7 % Standard Dev. (Geom) -- K·10±1.032 md CUTOFFS: Median ----------- 13.3 % Porosity (Minimum) ------- 0.0 % Standard Deviation ±5.6 % HETEROGENEITY (Permeability): Porosity (Maximum) ------- 100.0 % Permeability (Minimum) --- 0.0000 md GRAIN DENSITY: Dykstra-Parsons Var. -- 0.904 Permeability (Maximum) --- 100000. md Lorenz Coefficient - -- 0.813 Water Saturation (Maximum) 100.0 % Arithmetic Average 2.68 gm/cc Oil Saturation (Minimum 0.0 % Minimum ---------- 2.60 gm/cc AVERAGE SATURATIONS Pore Volume): Grain Density (Minimum 2.40 gm/cc Maximum ---------- 3.22 gm/cc Grain Density (Maximum 3.40 gm/cc Median ----------- 2.65 gm/cc Oil - 39.4 % Lithology Excluded NONE Standard Deviation ±0.12 gm/cc Water 38.6 % Stat 1 1 L j 1- j L, 10000. J L 1000.0 1- .. 100.0 - . L 10.0 L - l- . . 1.0 1- . 0.1 .-' ).... .. 0.01 .L , "'""" 0.001 0.0 1 - J. r- '\ ' ~- ~.~ : \ r: :': >, t . '. .~ .:. \ . \" ~.~ t" l. :' l.. ~ " "'" \ ' '- '" + + + + + + + + ~ -w- + + + T + ++ + + + .. + + * + + + + 1/ + + .D- o¡. "* .. ... + ... +14- + + 't + 6.0 12.0 18.0 24.0 30.0 r :. . _.:_ ,':: ARca ALASKA INC. KRU 30-12 KUPARUK RIVER UNIT - LEGEND - KUPARUK KUPARUK (6616-6767 feet) Core Laboratories August 9. 1988 _.._."~~~ -~~-~---~-----_.~---~---_._.._-_._...__.._---_.. L L L. ).... 100 90 80 70 -0 L. 60 L. .. 50 ~ .. L ..:.. 40 ~ ú.. 30 20 10 0 1.0 5.0 J,.. .l.. .l. .t J.. J.. ..l. , - 1 .... - ¡~.' ;'''' ¡~,\"" "" .~ .... \ ' \.. , I,..' ~ ""." ..)' ì : ~:, ~~:.: ',) 11' '1 r,: / /../ 9.0 13.0 :-:'-. .- -- ;:: 1 - ARca ALASKA INC. KRU 30-12 KUPARUK RIVER UNIT , - KUPARUK (6616-6767 feet) Core Laboratories , --'- , ,...~ .-,,/ 17.0 21.0 25.0 r. .. /. . - . j . - LEGEND - 100 90 , , 80 _. 70 60 " -. . L. 50 .. ., 40 30 ". ." ,., 20 - 10 0 29.0 _ _ Median Value (13.3) ..........._ Ar ith. Average (14.8) --'- Cumulative Frequency .. Cumulative Capacity Lost 148 Samples 17-Jun-1988 L L L. I ... . ~ " .', ~ ; t: ' ~ \ ~ . '" L 100 100 I: 90 ¡¡ 90 ~ I: 80 I: 80 1- 70 ¡¡ 70 60 60 .1. 50 50 J.. 40 40 .1.. 30 30 20 20 J.. I: 10 10 ~ 0 0 8.6E-Ei 6.9E-4 .006 .04 .35 2.83 23. 181. 1448. .. . I.~ : .. .1. 1 - 1 - - LEGEND - 1 - ARca ALASKA INC. KRU 30-12 KUPARUK RIVER UNIT _ _ Median Value (2.25) .....ooo...~ Geom. Average (2.59) Cumulative Frequency Cumulative Capacity Lost KUPARUK (6616-6767 feet) 142 Samples Core Laboratories 17-Jun-1988 - .l... .1.. .1.. , - 1 - 1 .- SURFACE CORE GAMMA LOG ...1 1 - 1 - - -. !-..... --'l ~ -'" 1--- .... } ~-'" ~..~ l ) t \ } ¡ VertIcal Scale 5.00 In .. 100.0 ft ______..__u -- ---_._-_._-----~ ---......-~- i ¡ INC. 2 RIVER A~CO ALASKA KRU 30-1 r-- UNIT KUPARUK 8788 f'T) 8 1 (88 KUPARUK C.re lob.rot.rle. _".__..___ ·__n LIthology legend SIltstone Sandstone ~ [J. . . ·-¡-0-;-8 ............ .. ............ . ...... ...... . .... .......... .. -. ----..--- I So'ulotl.... (Retort) : (Rehrt) Cu.u la' Ive 011 Sat Wat.r Sot ~~-!1 ~ " --0--- . --1- 3~ --'-- ty , um Poro. " ----<-- , He ~.~ r-'~-'--";- D.pth F..t c.,. Ga..a Horlt Kolr -.1_ , 1 00 ~. , , . ",du_l~~!J ---~-~~.J :'~ r-----¡ 1!-:-+-- r-~ l .L l J_ 1 -'"- ~ DETAILED LITHOLOGICAL DESCRIPTIONS .1 , ~ 1 ...... .- L.. L L- L Detailed Lithological Descriptions 1_ .1-.. LithologiGal descriptions were performed on plugs removed from Kuparuk River unit #30-12 whole core samples submitted by Arco Alaska, InG. These are conventional descriptions using a binocular microscope, hand lens, grain size scales, and a comparison chart for percentage estimation and roundness determination. The fOllowing format was used for describing these samples: .L Sandstones L 1. ) Color 2. ) Estimated percent and Description of minor rock type 3. ) Description of major rock type, including: l.. a. Grain size b. Sorting c. Roundness ).... d. Cementing and/or degree of consolidation e. Estimated percent minerals present and matrix f. Accessory minerals 4. ) Sedimentary structures or features 5.) Fracture descriptions 1 Mudstones/Shales/Siltstones , ....... 1.) Color 2.) Estimated percent and description of minor rock type 3.) Description of major rock type, including: a. Grain size modifiers b. Cementing and/or degree of consolidation c. Accessory minerals 4.) Sedimentary structures or features 5.) Fracture descriptions L ARCO ALASKA, INC. KUP #30-12 22-13N-9E NORTH SLOPE, ALASKA Field Formation coring Fld KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE 1" Detailed Litholoqical Descriptions 1 CORE #3 J.. 325 6616.5 Sandstone - olvgy, vf-mgr, pred fgr, wsrtd, sbrd-rd, wcons, patchy dnse cmt, poss sid-ank, spl is composed of 40% qtz, 50% cmt and sIt, 5-10% glauco .l 326 6617.4 Sandstone - olvgy, vf-mgr, pred fgr, mod wsrtd, sbrd- wrd, wcons-fri, degree of cons varies, patchy dnse cmt, poss sid-ank, spl is composed of 50% qtz, 20-30% glauc, 20-30% cmt and sIt. J.. 327 6618.5 Sandstone - dkgrgy, vf-mgr, pred fgr, mod wsrtd, sbrd- wrd, wcons, patchy'dnse cmt, poss sid-ank, spl is composed of 40% qtz, 30-40% glauc, 20-30% cmt and sIt, 1-2% pyr mass, tr carb frags. .1. l 328 6619.4 Sandstone - ltolvgy, vf-cgr, pred mgr, mod wsrtd, sbrd-rd, wcons-slfri, degree of cons varies, patchy dnse cmt, poss sid-ank, spl is composed of 60% qtz, 20-30% cmt and sIt, 10-20% glauc, cgr qtz ovgwths present. 329 6620.4 Sandstone - dkgrgy, vf-cgr, pred f-mgr, psrtd-mod wsrtd, sbrd-wrd, wcons-slfri, degree of cons varies, pred slfri, poss sid-ank cmt, spl is composed of 60% qtz, 20% glauc, 20% cmt and sIt. 330 6621.5 Sandstone - ltolvgy, vf-mgr, pred fgr, tr cgr sd, mod wsrtd, sbrd, wcons-slfri, pred wcons, patchy dnse cmt, poss sid-ank, spl is composed of 50% qtz, 30% cmt and sIt, 20% glauc, tr carb frags. 331 6622.4 Sandstone - dkgrgy, vf-cgr, pred f-mgr, psrtd-mod srtd, sbrd-wrd, fri, mnr patchy dnse cmt, poss sid- ank, spl is composed of 40-50% qtz, 30-40% glauc, 10- 15% cmt and sIt. 332 6623.2 Sandstone - olvblk, vf-mgr, pred vfgr, tr cgr sd, mod wsrtd, sbrd-wrd, wcons-fri, degree of cons varies, poss mnr sid-ank cmt, spl is composed of 40-50% qtz, 40% glauc, 10-20% cmt and sIt. 333 6624.3 Sandstone - olvgy, vfgr, wsrtd, sbrd, vwcons, slcalc, abnt dnse cmt, poss sid-ank, spl is composed of 50-60% sd, 40-50% dnse cmt, mnr calcxl fracs. .- 1- L ARCO ALASKA, INC. KUP #30-12 22-13N-9E NORTH SLOPE, ALASKA ~ 334 6625.6 l 335 6626.3 .l 336 6627.4 l .L 337 6628.3 Mudstone - dkgy, 20% ltolvgy, sdy, mic, intbd sltst, mdst is slty, mic, spl is wcons. 338 Field Formation Coring Fld KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab ANCHORAGE Detailed Lithological Descriptions siltstone - olvgy, 10-15% dkgy, slty, sdy, mic, bdd mdst, sltst is vsdy, arg, wcons, 3-5% mica, 2-3% pyr, tr carb frags, horz open to closed frac present. Mudstone - dkgy, 30% ltolvgy, vfgr, wsrtd, bdd ss, 30% ltolvgy, sdy, mic sltst, mdst is slty, vmic, spl is wcons, tr pyr. Sandstone - ltolvgy, 40% dkgy, slty, thkly lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 90% qtz, 10% sIt, tr-1% pyr, sdy burs. 6629.4 Mudstone - dkgy, 30-40% ltolvgy, sdy, bioturb, intbd sltst, mdst is slty, mic, spl is wcons. J.. 339 6630.3 Mudstone - dkgy, 30% ltolvgy, vfgr, wsrtd, lam ss, mdst is slty, mnr sd, mic, spl is wcons, tr-1% pyr. 340 6631.3 Mudstone - dkgy, 20-30% ltolvgy, vfgr, wsrtd, lam ss, mdst is slty, sdy in places, mic, spl is wcons, tr pyr. 341 6632.3 342 6633.3 343 6634.3 344 6635.4 Mudstone - dkgy, 40% ltolvgy, vfgr, wsrtd, lam ss, mdst is slty, mic, spl is wcons, tr pyr. Mudstone - dkgy, 20-30% ltolvgy, vfgr, wsrtd, bioturb ss, mdst is slty, sdy in places, mic, spl is wcons. Mudstone - dkgy, 20-30% ltolvgy, vfgr, wsrtd, bioturb ss, mdst is slty, sdy in places, mic, spl is wcons. Sandstone - ltolvgy, 30% dkgy, slty, sdy, mic, bdd mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, tr-1% mica, fgr sdy burs present. 345 6636.3 Sandstone - ltolvgy, 30% dkgy, slty, sdy, mic, bdd mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, lam, spl grades to sdy sltst. 346 6637.6 Mudstone - dkgy, 30% ltolvgy, vfgr, wsrtd, lam ss, mdst is slty, mic, spl is wcons, broken. .-- - 1. L ARCO ALASKA, INC. KUP #30-12 22-13N-9E NORTH SLOPE, ALASKA 1- 1 -'-- 347 6638.5 348 6639.2 349 6640.4 l -"" Field Formation Coring Fld KUPARUK RIVER UNIT : KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE Detailed Litholoqical Descriptions siltstone - olvgy, 20-30% dkgy, slty, lam mdst, sltst is sdy, mic, wcons. Mudstone - dkgy, 30-40% ltolvgy, sdy, bioturb, bdd sltst, mdst is sdy, vmic, spl is wcons. Sandstone - ltolvgy, 30% dkgy, sdy, mic, intbd mdst, ss is vf-fgr, pred vfgr, wsrtd, sbrd-rd, wcons, composed of 85-90% qtz, 10-15% sIt. l 350 6641. 4 Sandstone - ss is vfgr, 1- qtz, 10-15% 351 6642.2 Sandstone - ss is vfgr, qtz, 10-15% ltolvgy, 30-40% dkgy, slty, sdy, mic mdst, wsrtd, sbrd-rd, wcons, composed of 85-90% sIt, hvy bioturb. ltolvgy, 40-50% dkgy, slty, sdy, mic mdst, wsrtd, sbrd-rd, wcons, composed of 85-90% sIt, hvy bioturb, tr pyr. 352 6643.4 Mudstone - dkgy, 20-30% ltolvgy, vfgr, wsrtd, bioturb lam ss, mdst is slty, sdy, mic, spl is wcons. 353 6644.4 Sandstone - ltolvgy, 40% dkgy, slty, bioturb mdst, ss is vf-fgr, pred vfgr, wsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, qtz ovgwths, horz open frac present. 354 6645.5 355 6646.4 356 6647.4 357 6648.4 Mudstone - dkgy, 30% ltolvgy, sdy, sltst, mdst is slty, mic, spl is weons, bioturb, tr pyr, broken spl. Mudstone - dkgy, 5% sdy burs, mdst is slty, mie, weons, 1% pyr. Mudstone - olvgy, slty, sdy in places, vweons, dnse, poss sid-ank. Mudstone - dkgy, 10-20% ltolvgy, vfgr, wsrtd, lam ss, mdst is slty, sdy in places, bioturb, open fracs present. 358 6649.2 siltstone - ltolvgy, 10% dkgy, slty, mie, bdd mdst, sltst is vsdy, weons, bioturb. 359 6650.4 Mudstone - dkgy, 20% ltolvgy, vfgr, bioturb ss, mdst is slty, mie, spl is wcons, tr pyr, broken spl. 360 6651. 3 Mudstone - dkgy, 20% ltolvgy, vfgr, bioturb ss, mdst is slty, mie, spl is weons, tr pyr, broken spl. ]- J ARCO ALASKA,INC. KUP #30-12 22-13N-9E NORTH SLOPE, ALASKA r \ 1 CORE #4 ~ 1-. ....... '---- 1.- .:1..... .L .L Field Formation Coring Fld : KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE Detailed Litholoqical Descriptions 401 6652.2 Mudstone - dkgy, 20-30% ltolvgy, lam sltst, mdst is pred slty, wcons, mic, 1% fxln dism pyr, horz open frac present. 402 6653.4 403 6654.4 404 6655.4 Mudstone - dkgy, pred arg, sdy in places, wcons, blky, 1-3% pyr blebs and fos, mnr slty lams. Mudstone - dkgy, pred arg, sdy, wcons, tr pyr, broken spl. Mudstone - olvgy, pred arg, slty, wcons, dnse, poss sid- ank, thn lens vfgr, slty ss, vfxl pyr assc with sdy lens, horz open frac present. 405 6656.3 Mudstone - dkgy, pred arg, wcons, mnr thn lam vfgr sd, irregular spl. 406 6657.6 Mudstone - dkgy, 5% ltolvgy, lam sltst, mdst is pred arg, slty, wcons, 1-2% fxln pyr, horz open to closed frac present. 407 6658.3 Mudstone - olvgy, sdy, vwcons, dnse, poss sid-ank, abnt sdy pockets with xln pyre 408 6659.3 Sandstone - ltolvgy, vf-fgr, wsrtd, sbang-sbrd, wcons, composed of 90% qtz, 10% sIt, tr carb frags, tr mica, mnr pyr mass, mnr mdy lams. ..L 409 6660.3 , 410 6661. 4- 411 6662.2 - 412 6663.3 Sandstone - ltolvgy, 30-40% dkgy, sdy, mic, lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, 1% mica, bioturb. Mudstone - dkgy, 30% ltolvgy, vfgr, lam and bioturb ss, mdst is sdy, mie, weons, sdy burrows present. Mudstone - dkgy, 30% ltolvgy, vfgr, hvy bioturb ss, mdst is sdy, weons, tr pyr, mnr horz open to closed frae present. Mudstone - dkgy, 30% ltolvgy, vf-fgr, hvy bioturb ss and sdy burs, mdst is vsdy, mie, weons, and lam, tr pyre '- \.- ARCO ALASKA, INC. KUP #30-12 22-13N-9E 'J- NORTH SLOPE, ALASKA L 413 6664.4 L 414 6665.:2 l~ 415 6666.1 L Field Formation Coring Fld KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE Detailed Litholoqical Descriptions Sandstone - ltolvgy, 30% dkgy, slty, mic, lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, tr mica, tr pyr, x-lams. Sandstone - ltolvgy, 40% dkgy, slty, thkly lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 85-90% qtz, 10-15% sIt, 1% pyr, horz open frac present. Mudstone - dkgy, 20-30% ltolvgy, vfgr, vwsrtd, sbrd-rd, wcons ss, composed of 80-90% qtz, 10-20% sIt, mdst is slty, mic, sdy in places, mnr bioturb. ~ 416 6667.3 Sandstone - ltolvgy, vfgr, vwsrtd, rd-wrd, fri, composed of 95% qtz, 5% sIt, tr mica, tr pyr. .L 417 6668.:2 Sandstone - ltolvgy, vfgr, wsrtd, rd-wrd, fri, composed of 95% qtz, 5% sIt, tr mica, indistinct pyr lams. 1... 418 6669.5 Sandstone - ltolvgy, vfgr, vwsrtd, rd-wrd, fri, composed of 95% qtz, 5% sIt, tr mica, horz pyr filled frac .5mm in width present. 419 6670.3 Sandstone - ltolvgy, vfgr, wsrtd, sbrd-rd, fri, composed of 85-90% qtz, 10-15% sIt, mnr arg lams, horz open frac present. , - 420 6671.:3 Sandstone - ltolvgy, 20% olvgy, slty, dnse bdd mdst, poss sid-ank, ss is vfgr, wsrtd, sbrd-rd, fri, composed of, 90% qtz, 10% sIt, tr-1% mica. 1 421 6672.4 422 6673.:2 423 6674.5 Sandstone - ltolvgy, vfgr, vwsrtd, rd-wrd, fri, composed of 90-95% qtz, 5-10% sIt, tr mica, tr pyr, mnr arg sdy lams. Sandstone - ltolvgy, vfgr, wsrtd, sbrd-rd, fri, composed of 85-90% qtz, 10-15% sIt, 1% mica, mnr mdy lams. Sandstone - ltolvgy, vfgr, wsrtd, rd-wrd, fri, composed of 85-90% qtz, 10-15% sIt, 1% mica in places, mnr mdy lams, horz open to closed frac present. 424 6675.7 Sandstone - ltolvgy, 5-10% dkgy, slty, vmic, lam mdst, ss is vfgr, wsrtd, sbrd-rd, fri, composed of 80-90% qtz, 10-20% sIt, tr-1% mica, tr carb frags. L ARCO ALASKA, INC. KUP #30-12 22-13N-9E L NORTH SLOPE, ALASKA L 425 6676.5 L 426 6677.2 l- 427 6678.6 ~ .L 428 6679.2 , - 429 6680.3 1 - 430 6681. 3 Field Formation Coring Fld File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE KUPARUK RIVER UNIT KUPARUK BLAND Detailed Litholoqical Descriptions Sandstone - ltolvgy, 15-20% dkgy, sdy, mic, thkly lam mdst, ss is vfgr, wsrtd, sbrd-rd, slfri, composed of 80- 90% qtz, 10-20% sIt, 1% mica in places, pyr lam, harz open frac present. Mudstone - dkgy, 10-15% ltolvgy, vfgr, intbd ss, mdst is pred slty, mic, wcons, broken spl. Mudstone - dkgy, 30-40% ltolvgy, vf-fgr, wsrtd, sbrd-rd, slfri ss, composed of 85-90% qtz, 5-15% sIt, tr mica, mdst is slty, sdy in places, wcons, tr pyr, bioturb, horz open frac present. Sandstone - ltolvgy, 10-20% dkgy, slty, mic, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 90% qtz, 10% sIt. Mudstone - 20-30% ltolvgy, vfgr, wsrtd, sbrd-rd, wcons- slfri ss, degree of cons varies, mdst is pred slty, wcons, horz open frac present. Siltstone - olvgy, 20% dkgy, lam mdst, 20% ltolvgy, vfgr, slty, lam ss and sdy burs, sltst is sdy, 1-2% pyr, spl is wcons. 431 6682.6 Sandstone - ltolvgy, 20-30% dkgy, slty, mic, lam mdst, ss is vfgr, tr fgr sd, wsrtd, sbrd-rd, wcons-slfri, composed of 80-90% qtz, 10-20% sIt, tr pyr, horz open to closed frac present. 432 6683.9 Sandstone - ltolvgy, 20-30% dkgy, sdy, bioturb, lam mdst, ss is vfgr vwsrtd, sbrd-rd, fri composed of 80-90% qtz, 10-20% sIt. 433 6684.3 Sandstone - ltolvgy, 20% dkgy, slty, vmic, lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons-slfri, composed of 80-90% qtz, 10-20% sIt, tr mica, 1-3% pyr assoc with mdst lams, broken spl. 434 6685.4 Sandstone - ltolvgy, vfgr, wsrtd, sbrd-rd, wcons-slfri, degree of cons varies, composed of 80-85% qtz, 15-20% sIt, tr mica, tr arg lams. 435 6686.6 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, slfri, composed of 85-90% qtz, 10-15% sIt, tr mica, mnr arg lam. .J.. L ARCO ALASKA,INC. KUP #30-12 22-13N-9E NORTH SLOPE, ALASKA Field Formation Coring Fld KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE l... Detailed Litholoqical Descriptions L 436 6687.5 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, slfri, composed of 85-90% qtz, 10-15% sIt. 1. 437 6688.6 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, fri, composed of 90% qtz, 10% sIt, tr mica, mnr arg lams. ..1. 438 6689.4 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, fri, composed of 85-90% qtz, 10-15% sIt, tr-1% mica, tr arg lams. ~ .L 439 6690.6 Sandstone - ltolvgy, 5% dkgy, vrnic, mdy lams, ss is vfgr, vwsrtd, sbrd-rd, slfri, composed of 80-90% qtz, 10-20% sIt, broken spl. ..1 440 6691.3 Sandstone - ltolvgy, 30% dkgy, slty, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, slfri, composed of 80-90% qtz, 10-20% sIt, broken spl. ..1 441 6692.5 Sandstone- ltolvgy, vfgr, vwsrtd, sbrd-rd, fri, composed of 85-90% qtz, 10-15% sIt. -1 442 6693.9 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, fri, composed of 90-95% qtz, 5-10% sIt, tr pyr, tr mica. 443 6694.4 Sandstone - ltbrn, vfgr, vwsrtd, sbrd-rd, slfri, composed of 90% qtz, 10% sIt, tr-1% mica, broken spl. ..J 444 6695.5 Sandstone - ltolvgy, 10-15% dkgy, slty, mic, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons-slfri, composed of 80-90% qtz, 10-20% sIt, horz open frac present. 445 6696.4 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, slfri, composed of 85-90% qtz, 10-15% sIt, % sIt varies in spl, 1% mica. 446 6697.6 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, slfri, composed of 80-90% qtz, 10-20% sIt, 1% mica in places. 447 6698.6 Sandstone - ltolvgy, 15-20% dkgy, slty, mic, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, sdy burs. 448 6699.1 Sandstone - ltolvgy, 10% dkgy, slty, mic, lam mdst, ss is vfgr, wsrtd, sbrd-rd, slfri, composed of 80-90% qtz, 10-20% sIt, horz open frac present. - L ARCO ALASKA, INC. KUP #30-12 22-13N-9E L NORTH SLOPE, AlASKA 1-. 449 6700.7 L 450 6701. ~) L 451 6702.3 L L 452 6703.2 Field Formation Coring Fld : KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE Detailed Lithological Descriptions Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, slfri, composed of 80-90% qtz, 10-20% sIt, 1-2% mica in places, mnr bioturb, mdy lams. Sandstone - ltolvgy, 10% dkgy, slty, lam mdst, ss is vfgr, grading to sdy sltst, vwsrtd, sbrd-rd, wcons, composed of 70-80% qtz, 20-30% sIt, 1% mica. Sandstone - ltolvgy, 10-15% dkgy, slty, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80% qtz, 20% sIt, tr-1% mica, horz open frac present. Sandstone - ltolvgy, 10-15% dkgy, slty, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80% qtz, 20% sIt, 1% mica. 453 6704.3 Sandstone - ltolvgy, 20% dkgy, sdy, mic, bdd mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, 19 pyr sdy burrow in mdst, horz open frac present. 1.- 454 6705.~) Sandstone - ltolvgy, 10% dkgy, slty, mic, lam mdst, ss is vfgr, grading to a vsdy sltst, sd is wsrtd, sbrd-rd, wcons, composed of 80% qtz, 20% sIt. 455 6706.6 Mudstone - olvgy, grades to Itgy, sdy, dnse cmtd sltst, poss sid-ank cmtd, mdst is pred sdy, wcmtd, hd. 456 6707.3 Sandstone - ltolvgy, 5% dkgy, mdy lams, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, 1% mica in places. 457 6708.~) siltstone - ltolvgy, grades to 20% mgy, sdy, mic mdst, sltst is vsdy, arg, wcons, 2-3% mica, broken spl. 458 6709.4 Mudstone - dkgy, 20-30% ltolvgy, vf-fgr, wsrtd, bioturb ss, mdst is sdy, wcons, tr pyr, open to closed frac present. 459 6710.6 Mudstone - dkgy, 10-15% Itolvgy, vfgr, bioturb ss, mdst is slty, mic, spl is wcons, sdy burs present, broken spl. 460 6711.7 Mudstone - dkgy, 40-50% ltolvgy, vfgr, lam ss, mdst is slty, mic, wcons, broken spI. .... l ARCO ALASKA,INC. KUP #30-12 22-13N-9E NORTH SLOPE, A.LASKA Field Formation coring Fld KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab ANCHORAGE l Detailed Lithological Descriptions ~ .1 461 6712.2 Sandstone - Itolvgy, 40-50% dkgy, sdy, mic, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% slt, 1% mica. -1 462 6713.5 Mudstone - dkgy, 30% ltolvgy, vfgr, slty, bdd ss, mdst is slty, mic. CORE #5 --1 501 6714.3 Mudstone - dkgy, 5-7% vf-fgr thkly lam ss, mdst is pred slty, wcons, mic, pyr fos, bioturb, horz open to closed frac present. i 502 6715.1 Sandstone - Itolvgy, 30% dkgy, wvy lam mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 85-90% qtz, 10-15% sIt, bioturb, 19 sdy burs, horz open frac. 1 503 6716.3 Sandstone - Itolvgy, 30% dkgy, pred arg, mic, thnIy intbd mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 85-90% qtz, 10-15% sIt, 3-5% wthrd pyr, 2-3% mica in places, mnr bdd mgy mic mdst with abnt carb frags. 504 6717.2 Sandstone - Itolvgy, 5% dkgy, wvy lam, bioturb mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 80-90% qtz, 10-20% sIt, 2-3% mica in places, tr carb frags. 505 6718.2 Sandstone - Itolvgy, 10-15% dkgy, mic, thnly intbd mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 80-90% qtz, 10-20% sIt, 1-2% wthrd pyr in mdst. 506 6719.5 Sandstone - Itolvgy, 10% dkgy, wvy lam, bioturb mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 80-90% qtz, 10-20% sIt, 1-2% mica, 1% wthrd pyr. 507 6720.3 Sandstone - Itolvgy, vfgr, vwsrtd, sbrd, wcons, poss mnr sid-ank cmt, spl is composed of 80-90% qtz, 10-20% sIt and cmt. 508 6721.3 Sandstone - Itolvgy, 10-20% dkgy, slty, mic, lam mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 75-85% qtz, 15-20% sIt, 3-5% mica, irregular spl, broken. 509 6722.5 Sandstone - olvgy, vfgr, vwsrtd, sbrd-rd, slfri, composed of 90% qtz, 5-10% sIt, 2-3% mica, irregular spl. 1 - L ARCO ALASKA,ING. KUP #30-12 22-13N-9E L NORTH SLOPE, AlASKA L Field Formation Coring Fld File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE KUPARUK RIVER UNIT KUPARUK BLAND Detailed Litholoqical Descriptions 510 6723.3 Sandstone - ltolvgy, 10-15% dkgy, pred arg, intbd bioturb mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, 1% mica, broken. L L 511 6724.2 Sandstone - ltolvgy, 30-40% dkgy, pred arg, intbd mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 85-90% qtz, 10-15% sIt, tr mica, tr carb frags, mnr bioturb. L 512 6725.3 Sandstone - ltolvgy, 5-7% bioturb, lam mdst, ss is vfgr, vwsrtd, sbrd, wcons, composed of 80% qtz, 20% sIt, tr-1% mica. 513 6726.3 L 1.. 514 6727.4 1. Sandstone - ltolvgy, 20% dkgy, wvy lam mdst, ss is vfgr, wsrtd, sbrd, wcons, composed of 80-90% qtz, 10-20% sIt, 2-3% mica, tr pyre Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, slfri, composed of 80-90% qtz, 10-20% sIt, % sIt varies in spl, 1-2% mica, tr mdy lams. 515 6728.2 Sandstone - ltolvgy, 40-50% dkgy, slty, mic, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, tr-1% mica, horz open to closed frac. 516 6729.2 Sandstone - ltolvgy, vfgr, vwsrtd, sbrd-rd, mod cons, composed of 80-90% qtz, 10-20% sIt, tr-1% mica, subhorz pyr filled frac .5mm in width. 517 6730.3 1 518 6731. 2 - 519 6732.2 Sandstone - ltolvgy, 5% dkgy, pred arg, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, mod cons, composed of 80-90% qtz, 10-20% sIt, 1% mica. Sandstone - Itolvgy, 30-40% dkgy, bioturb, wvy lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, tr-1% mica. Sandstone - ltolvgy, 30-40% dkgy, bioturb, wvy lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, 1% mica, tr-1% pyr bleb. 520 6733.3 Sandstone - ltolvgy, 40% dkgy, bioturb, mic, wvy lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 85- 90% qtz, 10-15% sIt, tr-1% mica. L ARCO ALASKA, INC. KUP #30-12 22-13N-9E NORTH SLOPE, ALASKA Field Formation coring Fld : KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE L Detailed Litholoqical Descriptions 1-- .L 521 6734.3 Sandstone - ltolvgy, 30% dkgy, bioturb, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 85-90% qtz, 10-15% sIt, tr mica. ~ 522 6735.3 Mudstone - dkgy, 30% ltolvgy, vfgr, vwsrtd, sbrd-rd, bdd and lam ss, mdst is pred slty, wcons, 3-5% mica in places. 523 6736.:3 Mudstone - dkgy, 15-20% ltolvgy, vfgr, lam ss and sdy burs, mdst is pred slty, mic, wcons. 1 - 1.. 524 6737.3 Mudstone - mdkgy, 30-40% ltolvgy, intbd ss, vfgr, vwsrtd, sbrd-rd, vwcons, dnse, poss sid-ank cmtd, mdst is pred slty, sdy, vwcons, tr mica, tr carb frags. 525 6738.6 1 - 1 526 6739.5 - 527 6740.3 Mudstone - dkgy, 15-20% ltolvgy, vfgr, vwsrtd, sbrd-rd, wcons, bdd ss and sdy burs, mdst is pred arg, wcons, horz open to closed frac bordering sd and mdst contact. Mudstone - dkgy,10-15% ltgy, vfgr, bioturb, lam ss and sdy burs, mdst is pred slty, sdy, mic. Mudstone - dkgy, 40-50% ltolvgy, vfgr, vwsrtd, sbrd-rd, wcons, intbd and lam ss, composed of 80-90% qtz, 10-20% sIt, 1 % mica, mdst is pred slty, mic. - 528 6741.3 Mudstone - dkgy, 30-40% ltolvgy, vfgr, vwsrtd, sbrd-rd, wcons, lam ss, composed of 80-90% qtz, 10-20% sIt, mdst is pred slty, mic. 529 6742.1 Sandstone - ltolvgy, 40-50% dkgy, bioturb, wvy lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, 2-3% mica in places. - 530 6743.2 Mudstone - mdkgy, 30-40% ltolvgy, vfgr, vwsrtd, sbrd-rd, lam ss, mdst is pred slty, sdy in places, vrnic, mnr dnse cmtd sdy bur. - 531 6744.3 Mudstone - dkgy, 40% ltolvgy, vfgr, vwsrtd, sbrd-rd, lam ss, mdst is pred slty, mic, abnt bioturb, tr pyr, tr carb frags. 532 6745.1 Sandstone - ltolvgy, 10-20% dkgy, sdy, mic, thkly lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt. L ARCO ALASKA, INC. KUP #30-12 22-13N-9E L NORTH SLOPE, AlASKA Field Formation coring Fld KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE Detailed Litholoqical Descriptions L 533 6746.1 Sandstone - ltolvgy, 20-30% dkgy, lam mic mdst, ss is vfgr, wsrtd, wcons, rubble spl. .1.. CORE #6 l 601 6750.4 .1. 602 6751. 4 .L Sandstone - ltolvgy, 40-50% dkgy, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 85-90% qtz, 10-15% sIt, 1% mica, tr carb frags. Sandstone - ltolvgy, 30-40% dkgy, bioturb, lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% slt, 1% mica. 603 6752.6 Mudstone - dkgy, 15-20% ltolvgy, vfgr, lam ss, mdst is slty, tr sd, mic, wcons, mnr sdy burs. .... 604 6753.6 Sandstone - ltolvgy, 10-15% dkgy, mic, intbd and x-lam mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% slt 1-2% mica. 605 6754.3 Mudstone - dkgy, 40% ltolvgy, vfgr, lam ss and sdy burs, mdst is pred slty, mic, wcons, 2-3% carb frags in places. 606 6755.3 Sandstone - ltolvgy, 5-10% mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 85-90% qtz, 10-15% sIt, tr- 1% mica. 1 .... 607 6756.3 Sandstone - ltolvgy, 40-50% dkgy, pred slty, sdy, mic, intbd mdst, ss is vfgr, vwsrtd, sbrd-rd, wcons, composed of 90% qtz, 10% slt tr mica. 608 6757.5 Sandstone - ltolvgy, 40-50% dkgy, pred slty, sdy, mic, bioturb, wvy lam mdst, 5S is vfgr, wsrtd, sbrd-rd, wcons, composed of 85-90% qtz, 10-15% sIt, tr carb frags. 609 6758.5 sandstone - ltolvgy, 40-50% dkgy, pred slty, sdy, mic, lam mdst, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 85-90% qtz, 10-15% slt, 1% mica, tr carb frags. - - 610 6759.6 Mudstone - dkgy, 10-15% ltolvgy, vfgr, lam ss, mdst is pred slty, sdy, mic. L ARCO ALASKA,INC. KUP #30-12 22-13N-9E L NORTH SLOPE, ALASKA L 611 6760.4 .L 612 6761.2 1- 613 6762.5 l 614 6763.3 .L Field Formation Coring Fld : KUPARUK RIVER UNIT KUPARUK BLAND File: BP-3-1281 Date: AUG 04,1988 Lab : ANCHORAGE Detailed Lithological Descriptions Mudstone - dkgy, 10% ltolvgy, vfgr, sdy burs, mdst is pred slty, with mnr sdy lams, mic, 1-2% carb frags, horz open frac present. Mudstone - dkgy, 20-30% ltolvgy, vfgr, lam ss and sdy burs, mdst is pred slty, sdy, wcons, and mic. Mudstone - dkgy, 30-40% ltolvgy, vfgr, sbrd-rd, wcons, bdd ss, composed of 85-90% qtz, 10-15% sIt, 1-2% mica, mdst is pred slty, sdy, wcons,mic, 2-3% carb frags, 1- 2% mica, horz open frac present. Sandstone - ltolvgy, 5% arg lams, ss is vfgr, wsrtd, sbrd-rd, wcons, composed of 80-90% qtz, 10-20% sIt, 2-3% mica in places, 1% carb frags. 1 615 6764.5 Sandstone - ltolvgy, vfgr, wsrtd, sbrd-rd, vwcons, dnse, poss sid-ank cmt, 1% mica, mnr mdy lams. 616 6765.4 617 6766.4 618 6767.4 - Mudstone - dkgy, 5% ltolvgy, vfgr, lam ss, mdst is pred arg, mic, wcons, horz open frac present. Mudstone - dkgy, pred arg, slty, wcons, mnr sdy lams and burs, mnr frac. Mudstone - dkgy, 10% ltolvgy, vfgr, sdy lams, mdst is pred arg, slty, mic, wcons, bioturb, horz open frac present. 1- t-'" j '-- j '- ),.... WELLSITE REPORT '- J- . ...,. .!-. - ... , .- - - i, .L WELLSITE CORE REPORT l Company: Arco Alaska. Inc. Date: 5/29/88 l Well: Kru #30-12 Technicians: RGC County, Stat.a: North Slope. Alaska Formation: Kuµaruk 1 -'- Core # 1 Top Bottom Total (Ft.) ~ coring Interval (drillers depths) 6549.0 6562.0 13.0 .1. Retrieved Core (measured depths) 6549.0 6560.0 11.0 Type Preservation - No preservation requested ~ Core Barrel on drill floor - 5:30 End preservation - 7:20 Box/Tube No. Top Depth Bottom Depth Remarks 1.) 6549.0 6551.7 2. ) 6551.7 6554.5 3. ) 6554.5 6557.0 4.) 6557.0 6560.0 Note - Recovered core reflects actual formation drilled. Core barrel contained 49 feet of fill. Barrel jammed at 6562.0 Note - No ana~ysis or preservation requested per Don Brizzolara, Arco Alaska, Inc. '-. '- WELLSITE CORE REPORT L. Company: Arccl Alaska, Inc. Date: 5/30/88 1- Well: Kru #30-12 Technicians: RGC County, state: North Slope, Alaska Formation: Kuparuk , - Core # 2 Top .. Coring Interval (drillers depths) 6562.0 J.. Retrieved Core (measured depths) 6562.0 Bottom Total eFt.) 6592.0 30.0 6588.4 26.4 Type Preservation - No preservation requested .L Core Barrel on drill floor - 1:00 End preservation - 2:15 (Core boxed up) ..L - Box/Tube No. Top Depth Bottom Depth Remarks 1.) 6562.0 6565.0 2. ) 6565.0 6568.0 3. ) 6568.0 6571. 0 4. ) 6571. 0 6574.0 5.) 6574.0 6577.0 6.) 6577.0 6580.0 7. ) 6580.0 6583.0 8. ) 6583.0 6586.0 9. ) 6586.0 6588.4 Note - No analysis or preservation requested per Doug Knock, Arco Alaska, Inc. Note - Core jammed at connection. - L J- WELLSITE CORE REPORT .L. Company: Arco Alaska. Inc. Date: 5/31/88 .1... Well: KRU #30-12 Technicians: RGC County, State~: North Slope. Alaska J...... Core # 3 Formation: Kuparuk To? Bottom Total (Ft.) ..L coring Inte~'al (drillers depths) 6592.0 6652.0 60.0 Retrieved Core (measured depths) 6592.0 6651.7 59.7 l 6592.0 - 6616.0 No preservation Type Preservation - 6616.0 - 6651.7 Preserved in Saran Wrap. Aluminum Foil. and Core Seal. l Core Barrel on drill floor - 1:30 P.M. End preservation - 5:15 P.M. .J- Box/Tube No. Top Depth Bottom Depth Remarks 1.) 6592.0 6595.0 No Preservation 2.) 6595.0 6598.0' No Preservation 3. ) 6598.0 6601.0 No Preservation 4. ) 6601.0 6604.0 No Preservation 5.) 6604.0 6607.0 No Preservation 6.) 6607.0 6610.0 No Preservation 7.) 6610.0 6613.0 No Preservation 8. ) 6613..0 6616.0 No Preservation 9. ) 6616.0 6618.3 Begin Preservation 10. ) 6618.3 6621. 0 (1) 11.) 6621. 0 6623.9 (2) 12. ) 6623.9 6626.0 (1) (6620.8 - 6621. 0) piece extruded for Jake Rathmell (2) (6623.3 - 6623.9) piece extruded by Arco Geologist - - - "- Core No. L-_ J....-, Box/Tube No. Top Depth Bottom Depth Remarks ~ 13.) 6626.0 6628.2 14. ) 6628.2 6630.2 .L- 15. ) 6630.2 6632.5 16. ) 6632.5 6635.2 .1- 17. ) 6635.2 6637.3 .L- 18. ) 6637.3 6639.0 19. ) 6639.0 6641. 4 .1- 20. ) 6641. 4 6643.3 21.) 6643.3 6645.3 J- 22.) 6645.3 6647.6 ,..1- 23.) 6647.6 6649.4 24. ) 6649.4 6651.7 (3) .-L ....J... (3) (6650.0 - 50.2) Piece extruded for Jake Rathmell (Tracer Tests) - Note - (6592.0 - 6616.0) No preservation, no analysis requested by Arco Geologist Doug Knock. - L L WELLSITE CORE REPORT 1- Company: Arca> Alaska. Inc. Date: 6/01/88 .L Well: KRU #30-12 Technicians: RGC County, state: North slope. Alaska Formation: Kuparuk l Core # 4 Coring Interval (drillers depths) Top Bottom Total ( Ft. ) 6652.0 6712.0 60.0 6652.0 6713.8 61.8 l l Retrieved Core (measured depths) Type preserva.tion - Saran Wrap. Aluminum Foil. and Core Seal l. Core Barrel on drill floor - 2:00 A.M. End preservation - 4:45 A.M. , -'- - Box/Tube No. Top Depth Bottom Depth Remarks 1.) 6652.0 6654.0 2. ) 6654.0 6655.9 3.) 6655.9 6658.1 4.) 6658.1 6660.5 5. ) 6660.5 6662.8 6. ) 6662.8 6665.1 7.) 6665.1 6667.6 8.) 6667.6 6670.2 9. ) 6670.2 6672.6 10. ) 6672.6 6675.0 11.) 6675.0 6676.7 12. ) 6676.7 6679.5 1 - - I- i Core No. 4 )- Box/Tube No. Top Depth Bottom Depth Remarks ,- 1 13. ) 6679.5 6681. 5 'L.... 14. ) 6681.5 6684.2 15. ) 6684.2 6687.0 L.._ 16. ) 6687.0 6689.0 L 17. ) 6689.0 6691.7 18. ) 6691.7 6694.0 L_ 19. ) 6694.0 6696.3 20. ) 6696.3 6698.4 ~ 21.) 6698.4 6700.9 :.-. 22.) 6700.9 6703.1 23. ) 6703.1 6705.7 , --- 24. ) 6705.7 6707.6 25. ) 6707.6 6709.7 - 26. ) 6709.7 6712.1 1 27. ) 6712.1 6713.8 ,..c.- Note - (6674.7 and 6691.2) Samples extracted for Jake Rathmell, (Tracer Tests) . l J-.. WELLSITE CORE REPORT l Company: Arco Alaska. Inc. Date: 6/01/88 Technicians: RGC J... Well: KRU #30-12 County, StatE!: North Slope. Alaska Formation: Kuparuk Core # 5 ..1. Top * 6712.0 6713.8 accommodate 6713.8 Bottom 6748.8 6749.8 extra recovery 6746.8 l coring Interval (drillers depths) * COrE~ shifted 1.8 feet to Retrieved Core (measured depths) Type Preservation - Saran Wrap. Aluminum Foil. and Core Seal Total (Ft.) 36.0 on core #4 33.0 End preservation - 2:15 P.M. Box/Tube No. Top Depth Bottom Depth Remarks 1.) 6713.8 6716.0 2.) 6716.0 6718.5 3.) 6718.5 6720.6 4.) 6720.6 6722.6 5. ) 6722.6 6724.4 6.) 6724.4 6726.6 7.) 6726.6 6729.0 8. ) 6729.0 6731. 4 9. ) 6731. 4 6733.6 10. ) 6733.6 6735.2 11.) 6735.2 6738.5 12. ) 6738.5 6740.6 Core Barrel on drill floor - 12:00 P.M. - - - 1- 1 Core No. L-_ 1- Box/Tube No. TO'p Depth Bottom Depth Remarks L- 13. ) 6740.6 6742.3 L. 14. ) 6742.3 6744.6 15. ) 6744.6 6746.8 L 1- Note - (6723.0 and 6736.2) Samples extracted for Jake Rathmell, (Tracer Tests). 1-. , , - , ...... - 1- r- ! WELLSITE CORE REPORT -..- Company: Arco Alaska, Inc. Date: 6/01/88 '- Well: KRU #30~'12 Technicians: RGC County, state: North Slope, Alaska Formation: Kuµaruk L- Core # 6 Coring Interval (drillers depths) * core dep4:hs shifted 1.8 feet to #4 Retrieved Con~ (measured depths) Top * 6748.0 6749.8 accommodate Bottom Total (Ft.) 6768.0 6769.8 20.0 extra recovery on core .J-.. J.- 6749.8 6767.5 17.7 ..L Type Preserva'tion - Saran Wrap, Aluminum Foil, and Core Seal Core Barrel on drill floor - 7:45 P.M. End preservation - 9:15 P.M. .L. ..L Box/Tube No. Top Depth Bottom Depth Remarks 1.) 6749.8 6752.5 2. ) 6752.5 6754.5 3. ) 6754.5 6756.5 4. ) 6756.5 6758.6 5. ) 6758.6 6761. 0 6.) 6761. 0 6763.1 7. ) 6763.1 6765.3 8. ) 6765.3 6767.5 Note - (6766.0 - 67.5) No analysis, no preservation requested for this interval. ..l- .J-. - Note - (6765.8 - 66.0) piece extruded for Jake Rathmell, (Tracer Tests) L L L ..l. TRANSMITTALS .l -L ..L J. ...l - ~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 9072761215 ~~ ~r 1 >- ,J.- ~ L S!\'\I!'LE 'rRA,'\S~IITTAL Shipped By Core Lab L SHIPPED TO: Core Lab 8005 Schoon St. Anchorage, Ak 99518 DATE: June 15, 1988 L L OT)ERA TO¡~: ARca N,\"\IE: Kup. 30-12 -.---.- --1 , S.l.l'iPLE T.YPE: _~()_:_e_ -j ... KU:'fBER OF BOXES:- 87 ----- ~-'..f L SA>~PLES SE:<T: L Core 1 6549.0-6560.0 Core 2 6562.0-6588.1 Core 3 6592.0-6651.7 Core 4 6652.0-6713.8 Core 5 6713.8-6746.8 Core 6 6749.8-6767.5 See Attàched list For Better detail , ~ \....\. - SHIPPED BY:~~ Paleo lab Tech - UPON RECEIPT OF THESE S¡\¡\1PLES, PLEASE NOTE Ä.J~y DISCREPANCIES AND M.4IL A SIGNED COpy OF THIS FOffi.1 TO: ARC 0 ALAS~~, INC. P.O. BOX 100360 ANCHORAGE, AU\SKA 99510 ATTN: Paleo L¿:¡b ABVjlOO RECEIVED BY: DATE: ARca Af..k.. Inc, '1 . Subsidiary 01 Atløntit:RichfieldCompany . <! ''':.. J ~ .. "! -".\ ·_t\~... or ..-....._,. .'" -:,."'_ ~:~,":"~ r" ~'-~ ,':>." . 'L',· .- . .. ~:..: ::{J:~:~;::.:?3¡- . fiOQ55CHOON ST~ANCH<>AI.GE. "l"SO<I. ~~2 .' L COAE LAOOAATOAIES, IHC. r~r¡lln¡;( l~Â- In ~~ L TI\/\NSN 1 TTAL AND ACKNO\-'LEDG!-JIENT OF I\ECE 11'T TO: VI r(. 0 ala s ,{'<'-- ~ c::.. / .~._--'-."" ..........-----. -...,--~ ',"- '-.- -.......-...--.-... T Co ~ ';t!, - --.' . --..- -,-_...- ..'. . -_:'"-!-:~ ,;; d/ii.-. .~. L , ~ Matcrials r~ccivcJ Via Cðr¿.. La' MPu¿ ;' ,þ l- T ¡;'~L- .. ç~/c-~ 72.5!-5, ~ .£u.ü II J~ , . I? p.fJ IYl dL- 5'0" tIh)<..- ~ g p(..C-{~ I j¿ftJ., 63 5~/t..-$ 9 ~~/u ,-J-ú.ku. d.¿ad, ¥~. ..' PLEASE RETURN ONE COpy - Sh í pped by :ß/~ t:~;4/!ø for Core Lab/Oatc: ,J~ ~/ ¡l:JOð . Rec c i vcd by: .......... ....... for /Da (<": ,;~ **Please no~hat the items listed above are inventoricd, shipped and received in good f~'ftt. but are subject to minor adjustments because of possible unintenti"ëšiìial human error. In such a case. both shipper and receiver agree to make. a timely and bona fide effort to correct any observed discrepancies. " . . . . . > ::~~·~~:1L>:.~.;r:.ii~~fR:~1:ifJ.'~f~.: . :. ' ',' . '~.' .. . .., .... :.~~'~'<. /;'~".~,·ð·>··' . ..'.:<'.' " . . ,;,. ,.,' ,.. ....:o;~~.. "t..- :: ..' ;j::..",;:... el~":~jP";~ ,~,. , I" .', ~'~~.. ,. ..' ....'.< . '.. .~~~~z~·:.¡t:~ ._~ , \ \ ( ,- I j Ico Alaska, Inc. 30-12 aruk Formation orth Slope, Alaska ~- j Inventory - Tracer Test Special Samples '- Core Depth (ft) High ROP Intervals (1) .I _________ ----------- ------------------- \.- , ~ 1 No Samples Taken ._...__n__".___ - ,-,..".- .-..-- samples -..--.-.-.---' 2 No Taken "u___,_,__ __ _.--_.- ~ 3 6620.8 6619-:6621 6650.0 6650-'6651 4 6674.7 6674-6675 6691.2 6688-6693 5 6730.0 6729.8-6731.8 (2) 6736.2 6735.'8-6736.8 6 6765.8 Selected by Geologist L_ '- , J. , Interval chosen from Eastman Christianson Coring Log (core 3) Interval chosen from Weslog mudlog (Core 4,5) - Adjusted 1. 8 ft: from drillers depths - - - 1- l ..1 DATA DISKETTES 1 ~ ~ 1 .... We. -g'..~--/.2. .Key Well E:] Yes Fi No ,,. ~"~-~' Kuparuk Well PresSure'. R~rt ,,~ . '- Date - :~L~¢ /~-y] - '~,::?'~ ~:': ~.~ ~/~:: Satisfies- ' ' ::~:~?:::-.State' ' Service CompanY Pressure Measurement Device: [] HP ~ AMERADA F-I Other: . Instrument Identification No.: · (Upper Bomb) 0 LYNES rq Torque Turn · Calibration Date: ' · . (Lower Bomb) Type of Test: Fi Static [~ PBU Sand: [] A l-I C [3 Both Final Datum Pressure Pressure WL MD- TVD- Upper Lower TVD~S.S. RKB SS. Bomb Bomb 6200' Maximum RecoFded Temperature: Time @ De )th Start End Well SI Prior to Pressure Measurement (Date/Time): .. STATE OF ALASKA ALA$,,,~ OIL AND GAS CONSERVATION COMI~,,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing ~ Othe~ ~ C0HPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, lng. RKB 59' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 7. Well number 30-12 4. Location of well at surface 1019' FNL, 2011' FWL, Sec.22, T13N, R9E, UN At top of productive interval 1234' FNL, 1863' FWL, Sec.22, T13N, R9E, UN At effective depth 1249' FNL, 1827' FWL, Sec.22, T13N, RgE, UM At total depth 1256' FNL, 1811' FWL, Sec.22, T13N, RgE, UM 8. Approval number 8-368, 8-384 & 8-516 9. APl number 50-- 029-21804 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4071' Production 6924' 7005'MD 6956'TVD 6875'MD 6827'TVD Size 16" 9-5/8" 7" feet feet Plugs (measured) None feet feet Junk (measured) None Cemented Measured depth 175 sx AS I 1lO'MD 1500 sx AS I I I & 4106'MD 300 sx Class G Top job w/150 sx AS I 360 sx Class G 6957 'MD True Vertical depth 110'TVD 4101 ' TVD 6908'TVD Perforation depth: measured true vertical 671 2 ' -6732 ' MD 6666'-6686'Tv'D ~ 12. Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail (~ 6522' Packers and SSSV (type and measured depth) HB pkr (~ 6448' & FVLD SSSV @ 1784'~ Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A 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 (Compl. Well H..istory) Daily Report of Well Operations]l;] Copies of Logs and Surveys Run ~E~ gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Associate Engi neet (Dani) SW03/022 Date ~//~./~:~ Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I County or Parish ARCO Alaska, Inc. I NORTH SLOPE Field Lease or Unit KUPARUK RIVER FIELD ADL: 25513 Auth. or W.O. no. lTitle AK3048 I COMPLETE Accounting cost center code State 30-12 JWell no. Operator ARCO API: 50-029-21804 A.R.Co. W.I. 56.0000 Spudded or W.O. begun Date ACCEPT 06/26/88 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 06/27/88 ( 1 TD: 7005 PR: 6875 SUPV:DL/KR I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well I our J Prlor status if a W.O. I 0630 HRS RELEASED RIG 7"~ 695.7' MW: 6.9 DIESEL MOVED RIG FROM 30-13 TO 30-12. ACCEPTED RIG @ 0630 HRS, 6/26/88. ND TREE. NU ROPE & TESTED TO 3000 PSI. PERFORATED 'a' SAND F/6712'-6732'W/8 SPF. RIH WITH 2-7/8" COMPL. EQUIP. SET PACKER. TESTED TUBING TO 2500 PSI. SHEARED PBR. TESTED ANNULUS TO 2500 PSI. TESTED SSSV TO 1500 PSI. ND BOPE. NU TREE & TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. SET BPV. SECURED WELL & RELEASED RIG @ 2400 HRS, 6/26/88. (TAIL @ 6522', BAKER 'FVLD' SSSV @ 1784', BAKER 'HB' PKR @ 6448') DAILY:S142,799 CUM:$1,197,484 ETD:S1,197,484 EFC:$1,510,000 Old TD Released rig Classifications (oil, gas, etc,) INew TD Date PB Depth Kind of rig CType completion (single, dual, etc,) Official reservoir name(s) Producing method 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 corrept Signature .. I Date ITitle /I For form preparation and ¢rsj~ribution, see Procedures Manual, S~C,4ion 10, Drilling, Pages 86 and 87. ASSOCIATE ENGINEER ARCO Alaska, Inc. Date: Transmittal #: 7205 July 1, 1988 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 0 - 1 2 Open Hole Tape and Listing 6 - 2 - 8 8 # 7 2 7 8 9 Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION; State of Alaska Lynn Goettinger Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: Transmittal #: 7209 July 1, 1988 ., RETURN TO: ARCO Alaska, inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal, 3 O- 1 0 Cement Evaluation Log 6 -'1 9 - 8 8 7 3 4 6 - 8 71 5 3 O- 11 Cement Evaluation Log 6 ~ 1 9 - 8 8 5 9 71 - 7 6 4 2 30-12 -' Cement Bond Log 6-1 7-88 4798-6860 3 O- 1 7 Cement Evaluation Log 6 - 1 7 - 8 8 7 5 9 5 - 9 0 8 7 Receipt Acknowledged: DJSTRIBUTION' NSK Drilling State of Alaska(.,+sepial · STATE OF ALASKA ALASI~A OIL AND GAS CONSERVATION COMrv,,,.4SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .ri Suspend [] Operation Shutdown IX Re-enter suspended well ~ Alter casing L-J Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate [] Other 2. Name of Operator 5. ARCO Alaska, Inc. RK 3. Address 6. P. 0. Box 100360, Anchorage, AK 99510-0360 Ku 4. Location of well at surface 7. 1019' FNL, 2011' FWL, Sec. 22, T13N, RgE, UM 30 At top of productive interval 8. 1320' FNL, 1848' FWL, Sec. 22, T13N, R9E, UM (approx.) 88 Datum elevation (DF or KB) B 59 ' feet Unit or Property name paruk River Unit Well number -12 Permit number -41 At effective depth 9. APl number 1277' FNL, 1826' FWL, Sec. 22, T13N, R9E, UM (approx.) 50-- 029-21804 At total depth 10. Pool 1284' FNL, 1811' FWL, Sec 22, T13N, RgE, UM (approx.) Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 7005 'MD feet Plugs (measured) None 6958 ' TVD feet Casing Conductor Surface Intermediate measured 6875 ' MD true vertical 6829 ' TVD Length Size 80 ' 1 6" 4071 ' 9-5/8" Production 6924' 7" Perforation depth: measured feet Junk (measured) None feet Cemented 1 75 sx AS I 1500 sx AS I II & 300 sx Glass G Top job with 1 50 sx AS I 360 sx Class G None true vertical N o n e None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) N o n e Measured depth True Vertical depth llO'MD 110'TVD 41 06 ' MD 41 01 ' TVD 6957 'MD 691 O'TVD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Wel 1 Hi story 13. Estimated date for commencing operation June~1988 14. If proposal was verbally Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _~}(~f)Oy~ .~%~.,(~.~½~[~ ,/ Title Associ ate Engineer Commission Use Only (SA3/0001) Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test n~i~:lc~p~nceI Returned Date ~'~0 -~ Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 <® Submit in triplicately./ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be SUmmarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER FIELD Auth, or W.O. no. AK3048 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 05/23/88 05/24/88 ( ' TD: 32o0,( 3i SUPV:RB 05/25/88 ( TD: 4123'( SUPV:RB 05/26/88 ( TD: 4123'( SUPV:RB 05/27/88 ( TD: 4738'( SUPV:RB 05/28/88 ( TD: 6184'( 1 SUPV:RB 05/29/88 ( TD: 6549'( SUPV:RB 05/30/88( TD: 6580'( SUPV:RB o5/31/88 ( TD: 6625'( The above ia correct ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25513 Title DRILL API: 50-029-21804 IDate IH°ur 0900 HRS 05/23/88 Complete record for each day reposed DOYON 14 ) ~00) :) '23) ) 15) ) 46) ) 165) ) 31) ) 45) Signature For form preparation and d{,~'t}ibution, see Procedures Manual, Set.~on 10, Drilling, Pages 86 and 87. ]Sta~K ARCO W.I. 56.0000 Prior status if a W.O. RIH W/ LOGS 16"@ 110' MW: 9.4 VIS: 74 DRLD 12-1/4" HOLE F/ 3200' TO 4113'. CIRC· SHORT TRIP. HOLE SWABBED. CIRC. POOH F/ LOGS. RU SOS. ATTEMPT TO RIH W/ LOGS. COULD NOT GET PAST 1711'. POOH AND RD SOS. RIH W/ BIT AND WASH F/ 1900'-2200'. DRLD F/ 4113' TO 4~23'. POOH. RU SOS AND RIH. DAILY:S49,302 CUM:$129,998 ETD:S129,998 EFC:$1,510,000 PREP TO DO TOP JOB 9-5/8"@ 4106' MW: 9.4 VIS: 68 RU SOS & RUN LSS/GR/DIL. RUN #2 W/ LDT/CNL/GR/CAL. RD SOS. PU BHA #3 AND RIH. CIRC AND COND HOLE. POOH. LD BHA. RU AND RUN 9-5/8" CSG W/ FS AT 4106 ' PUMP 1500 SX AS III & 300 SX CLASS G. DAILY:S84,487 CUM:$214,485 ETD:S214,485 EFC:$1,510,000 DRLD TO 4736' 9-5/8"@ 4106' MW: 8.7 VIS: 30 PERFORM TOP JOB W/ 150 SX AS I. ND HYDRIL. NU BOPE. MU BHA #3 AND RIH . TAG FC AT 4025'. DRLD FC. TEST CSG TO 2000 PSI. DRLD 10' NEW HOLE. LOT. DRLD TO 4738' DAILY:S136,461 CUM:$350,946 ETD:S350,946 EFC:$1,510,000 DRILLING 9-5/8"@ 4106' MW: 9.4 VIS: 86 TURBODRILL 8-1/2" HOLE TO 6112'· CHANGE OVER TO BLAND KCL MUD TURBODRILL 8-1/2" HOLE TO 6184' ~:\li~!:i~. · . DAILY: $120,033 CUM: $470,979 ETD:S470, 979 EFC:$1,510,000 RIH WIT~ CORE B~REL 9-5/8"8 4106' ~: 9.9 VIS: 85 TURBODRILL 8-1/2" HOLE TO 6175'. POO~ LD TURBINE. DRILL 8-1/2" HOLE TO CORE POINT ~ 6549'. POOH FOR CORE B~REL. WIT~ CORE B~REL. DAILY: $81,905 C~: $552,884 ETD: $552,884 EFC:$1,510,000 CORING 9-5/8"@ 4106' MW: 9.9 VIS: 60 CORE #1 F/6549'-6562'; REC'D 13' (100%). CORE #2 F/6562'-6580'. DAILY:S52,197 CUM:$605,081 ETD:S605,081 EFC:$1,510,000 CORING 9-5/8"@ 4106' MW:10.1 VIS: 59 CONTINUED CUTTING CORE #2 TO 6592'; REC'D 26.5' (88%). CUT CORE ~ ~/~9'-~75,. DRLG AT 3200' 16"@ 110' MW: 9.0 VIS: 68 MU BHA AND BIT #1. TEST DIVERTER. SPUD WELL AT 0900 HRS 5/23/88. DRLD 12-1/4" HOLE F/ 110' TO 3.200'. DAILY:S57,025 CUM:$80,696 ETD:S80,696 EFC:$1,510,000 30-12 IWell no. ACCEPTED RIG @ 0330 HRS, 5/23/88. NU 20" DIVERTER & TESTED. DAILY:S23,671 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" 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 and following setting of oil string until completion. District [IC°unty or Parish ] State ARCO ALASKA INC. ~ NORTH SLOPE AK Field ~Lease or Unit I KUPARUK RIVER FIELD ~ 30-12 Complete record for each day while drilling or workover in progress DOYON 14 Date and depth as of 8:00 a.m. 06/01/88 ( TD: 6720'( SUPV:JP 06/02/88 ( TD: 6941'( SUPV:RB 06/03/88 ( TD: 7005'( SUPV:RB 9) 95) [o) 221) 64) CORING 9-5/8"@ 4106' MW:10.1 VIS: 56 CONTINUED CORE #3 TO 6652' CORE #4 F/6652'-6218'. CORE #5 F/6712'-6720'. DAILY:S54,301 CUM:$707,677 ETD:S707,677 EFC:$1,510,000 DRILLING 9-5/8"@ 4106' MW:10.1 VIS: 42 CONTINUED CORE #5 TO 6748'. POOH. PU DRILLING ASSEMBLY. RIH. DRILL 8-1/2" HOLE TO 6941'. DAILY:S47,619 CUM:$755,326 ETD:S755,326 EFC:$1,510,000 POOH LDDP 9-5/8"@ 4106' MW:10.0 VIS: 42 DRILL 8-1/2" HOLE TO 7005'. CIRC. POOH. RU LOGGERS. LOG OH. RUN DIL/GR/SP/SFL F/6998-4100', GR F/6998-1000', FDC/CNL F/6998-4100', CAL F/6998- 4100', LSS F/6998'-4100'. RD LOGGERS. RIH. CBU. POOH LDDP. DAILY:S75,865 CUM:$831,191 ETD:S831,191 EFC:$1,510,000 IWell no. The above is correct For form preparation an,~¥distribution -- see Procedures Manual{S/~ction 10, Drilling, Pages 86 and 8-? IDate ~ ., ITitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report District Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code I County or Parish State ARCO ALASKA INC. I NORTH SLOPE AK Ikease or Unit IWell no. KUPARUK RIVER FIELD ~ ADL: 25513 30-12 Title DRILL Field Auth. or W,O. no. ~3048 Operator I A.R.Co. W.I. ARCO I 56. 0000 Spudded or W.O. begun I Date SPUD I 05/23/88 Date and depth as of 8:00 a.m. Old TD Released rig Classifications (oil, gas, etc.) 06/04/88 ( 1 TD: 7005'( SUPV:RB API: 50-029-21804 Complete record for each day repo~ed DOYON 14 Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our ' I Prlor status if a W.O, I 0900 HRS .~) 0) FINAL REPORT 7" @ 6957' MW:10.0 VIS: LDDP AND BHA. RAN 175 JTS 7", 26.0#/FT, J-55, BTC CASING WITH SHOE @ 6957'. CEMENTED WITH 100 SX 50/50 POZ & 260 SX CLASS G. BUMPED PLUG WITH 3500 PSI. UNABLE TO RECIPROCATE. FULL RETURNS. ND BOPE. NU TREE & TESTED TO 3000 PSI. SECURED WELL AND RELEASED RIG @ 2230 HRS, 6/3/88. DAILY:S247,194 CUM:$1,078,385 ETD:S1,078,385 EFC:$1,510,000 INew TD I PB Depth Date JKind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) 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.Pi C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct For form re arat p p at~ll ~ nd distribution, see Procedures IVl~a~ual, Section 10, Drilling, Pages 86 and 87. IDate . ITitle ARCO Alaska, Inc. Date: RETURN TO: June 24,1988 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7199 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-12 30_12~ 30.12.~/ 30-12',- 30-12- 30-12~ 2"& 5" Porosity FDC 2" & 5" Raw FDC 5" Dual Induction 2" & 5" Long Spacing Sonic 2" Dual Induction Cyberlook 6-02-88 4107-6966 6-02-88 4107-6966 6-02-88 4107-6992 6-02-88 4107-6988 6-02-88 4107-6992 6-02-88 4107-6992 Receipt Acknowledged: Alssk~ Oil & Gas Cons. Commission Anchorage ........................... Date: ............ DISTRIBUTION: NSK Drilling State of Alaska(+sepia) Franzen D&M L. Johnston(vendor package) WEST SAK ENGINEERING TRANSMITTAL #1185 TO: John B0yI~ State FROM: H. D. Whit~/P. $. B~xt~r DATE: ,,J~jne 14, 1 ~8 WELL NAME:-30-12 TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of a sepia and blueline for each 2" & 5" Long Spacing Sonic - (DT and WF) run 1 May 25, 1988 Alaska Oit & Gas Cons. Commission Anchorage RECEIPT ACKNOWLEDGED: DATE: PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1269 P. O. Box 100360 Anchorage, Alaska 99510-360 STATE OF ALASKA ALASKA OIL A~D GAS CONS£RVATION CO~ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 P~E: Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I IT DESCRIPTION P~ECE I VED: DA' Copy sent to sender YES, N ces Detectors ,-' tr ip T~nk ,.'/' - - Blind Rams )" ChOke Line Waives _ '~.C~R. Valve / Kill Line Valves Check Valve Test Results: Lower Kell)~ ReprO:sent attve ~,.~, ~ ~ z. Pu~ tncr ~]os pres 200 p~Jg ~ =tn ~7 sec. Fu~ C}=arge~PTeSsute Attained: ~ minff~ sec P&.,ote ,~ q~]ind} sw~tch cover / ~ :. Fp~er Kell~~T.. ~est Pressure, ~' ~'( ...... , test Pr .'. c--6 C. ~__~ ~est rress0re ~d"d-'a- Ball Type__~_ / - .., inside BOP: Choke Man'old NO Valves }. / ~ '". i' ' Adjustable ,bokes /-- _..~9~ Test T~e~hrs. . Repair or Replacemant of failed eoulpment to-be made withi~ ./~/~/~,~' clays a~ Inspeito~t' ItECC-tVED ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 25, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE' 20 AAC 25.071 Geologic Data and Logs Dear Mr. Chatterton' The Ugnu core planned for Kuparuk River Unit Well 30-12 has been moved to 30-08. Per our previous letter of April 20, 1988 and your response of May 2, 1988 (both attached), ARCO Alaska, Inc. (ARCO) will be the Operator and perform the coring. Standard Alaska Production Company will own the core and be responsible for filing Ugnu core data in accordance with 20 AAC 25.071. ARCO understands, as Operator, it will file all other required information for KRU well 30-08. Very truly yours, H. D. Wh HDW/RWC:ved Attachments cc: L.C. Smith AOGCC A. Garon SAPC ARCO Alaska, Inc. is a Subsidiary of At anticH chfieh~g~;m? m~:~ ARCO Alaska, Post Offic, jx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 20, 1988 Mr. C. V. Chatterton Alaska Oil and Gas ConServation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE' 20 AAC 25.071 Geologic Data and Logs Dear Mr. Chatterton' ARCO Alaska, Inc. plans to core the Ugnu formation in Kuparuk River Unit Well 30-12 for Standard Alaska Production Company. Under this arrangement, ARCO as operator, would perform the coring and immediately give the recovered core to Standard. Standard would own the core and be responsible for all costs and liabilities associated with collecting it. In 20 ACC 25.071, the operator is required to file certain core data with the Commission. In this case, however, the core data would not be available to ARCO. As a result, ARCO and Standard jointly request permission for Standard to assume ARCO's reporting duties for the Ugnu core in Well 30-12. Please advise Dan White (265-6193) with ARCO and Nick Freestone (564-4702) with Standard, if this reporting procedure meets your approval. Either may be contacted if you have any questions. Very truly yours, H. D. White Regional Engineer West Sak Engineering ARCO Alaska, Inc. N. J. Freestone Manager Shallow Sands Standard Alaska Production Company HDW/NJF'ved cc: L.C. Smith AOGCC ARCO Alaska. Inc. is a Sut)sidiary of Allan:~cRic,~fie~dOom.~a~'~' ALASKA OIL AND GAS CONSERVATION COMMISSION ! STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 TELEPHONE (907) 279-1433 TELECOPY NO.. (907) 276-7542 May 2, 1988 Mr. H. D. White Regional Engineer West Sak Engineering ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Mr. N. J. Freestone Manager Shallow Sands Standard Alaska Production P. O. Box 196612 Anchorage, AK 99519-6612 Gent lemen: Please refer to your joint April 20, 1988 letter regarding the reporting of geologic data for KRU Well 30-12. Your proposed handling of these data is approved. We will expect Standard Alaska Production Company to sample and timely file Ugnu formation core data in accord with 20 AAC 25.071(b)(3) and (7), ~=%Ild ARCOj as operator, to file all other required information for _ 3o-J. -- Advise should you need further assistance. C. V. Chatterton Chairman dlf: 1/CVC/5 P'S STATE OF 'ALASKA ~. ALASt',. ~ OIL AND GAS CONSERVATION COMk..~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc, RKB 59' feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1019' FNL, 2011' FWL, Sec. 22, T13N, RgE, UN At top of productive interval ~ target 1320' FSL, 1848' FNL, Sec. 22, T13N, RgE, UN At effective depth At total depth 1362' FSL, 1825' FWL, Sec. 22, T13N, RgE, UM 7. Well number 30-12 8. Permit number 88-41 9. APl number 50-- 029-21 804 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Proposed: Surface ~+039 ' Size Cemented Measured depth True Vertical depth 9-5/8" tail 300 sx Class C & lead 1500 sx AS I I I 4074 'MD 4074 'TVD Perforation depth: measured In the casing pr Th true vertical p r op pr Tubing (size, grade and measured depth) 1 e us Packers and SSSV (type and measured depth) original permit application the 9-5/8" surface was proposed at 2219'MD/TVD. This sundry oposes deepening the surface casing setting depth. e reason for the change is production casing sticking oblems that are believed the result of the longer en hole section. Cement volumes for the 7" oducation casing will be reduced to about 100 sx of ad and 200 sx of Class G. Sufficient volume will be ed to place G cement 500' above the Kuparuk. 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation Nay 21,1988 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 (~0~/Y~Jk,,, ~ Title Associate Engineer _ (T 5A3/104) t~ Commission Use Only ~}E~4.~ir~ Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Date Approved Cog~: ~ c' -iD :':? Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate STATE OF ALASKA ~ ALAS~.., OIL AND GAS CONSERVATION COMk....,SION 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 C Perforate ~ Other 2. Name of Operator ARCO Alqska~ Inc~ 3. Address P. O. Box 100360, Anchorage~ AK 99510-0360 4. Location of well at surface 1019' FNL, 2011' FWL, Sec.22, T13N, RgE, UM At top of productive interval (~ target) 1320' FNL, 1848' FWL, Sec.22, T13N, RgE, UM At effective depth N/A At total depth 1362' FNL, 1825' FWL, 5ec.22, T13N, RgE, UM 11. Present well condition summary Total depth: measured feet true vertical feet Plugs (measured) 5. Datum elevation (DF or KB) RKR 59 ! 6. Unit or Property name Kuparu,k, River Unil; ?. Well number 30-12 feet 8. Permit number 88 -41 9. APl number 50-- 029-21804 10. Pool Kuoaruk River 0il Pool Effective depth: measured feet true vertical feet Junk(measured) Casing Length Size Cemented Measured depth True Vertical depth The UGNU core planned for this well has been moved to 30-8. will be run instead of the 10-3/4" as originally permitted. as originally permitted. 9-5/8" surface casing All depths will remain Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 5- 22. 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 ~./~r~^~, ,.~,,.t,,, Title Associ ate Engineer "~'/~/~'"~ ~ · TEM SA3/9 ~// . Commission Use Only ~,~i~/ 7 Conditions of approVal Notify commission so representative may witness [ Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date ORI~- II~AL Approved by BY C. V. Ciq^'FI'FRTON App'r~,,~.d Copy ~t[,. ,'~ed Commissioner by order of the commission Date._~ Form 10-403 Rev 12-1-85 Submit in triplicate TELECOPY NO: (907) 276-7542 May 2, 1988 Mr. H. D. White Regional Engineer West Sak Engineering ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Mr. N. J. Freestone Manager Shallow Sands Standard Alaska Production P. O. Box 196612 Anchorage, AK 99519-6612 'Gent lemen: Please refer to your joint April 20,. 1988 letter regarding the reporting of geologic data for K_RU Well 30-12. Your proposed handling of these data is approved. We will expect Standard Alaska Production Company to sample and timely file Ugnu formation core data in accord with 20 AAC 25.071(b)(3) and (7), and ARCO, as operator, to file all other required information for KRU Well 30-12. Advise should you need further assistance. Verv~ truly yours C. V. Chatterton Chairman dlf: 1/CVC/5 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 20, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE' 20 AAC 25.071 Geologic Data and Logs Dear Mr. Chatterton' ARCQ~.~$ka,~:Jnc. plans to core the Ugnu formation in Kuparuk River Unit Well:- :f..'~r Standard Alaska Production Company. Under this arrangement, ARCO as operator, would perform the coring and immediately give the recovered core to Standard. Standard would own the core and be responsible for all costs and liabilities associated with collecting it. In 20 ACC 25.071, the operator is required to file certain core data with the Commission. In this case, however, the core data would not be available to ARCO. As a result, ARCO and Standard jointly request permission for Standard to assume ARCO's reporting duties for the Ugnu core in Well 30-12. Please advise Dan White (265-6193) with ARCO and Nick Freestone (564-4702) with Standard, if this reporting procedure meets your approval. Either may be contacted if you have any questions. Very truly yours, H. D. White Regional Engineer West Sak Engineering ARCO Alaska, Inc. N. J. Freestone Manager Shallow Sands Standard Alaska Production Company HDW/NJF:ved cc: L.C. Smith AOGCC An,~:h0r~fie ARCO Alaska, inc. is a Subsidiary of Atta~:icFtichfieidC~.~i','~?~;~$~ April 26, 1988 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 30-12 ARCO Alaska, InC. Permit No. 88-41 Sur. Loc. 1019'FNL, 2011'FWL, Sec. 22, T13N, R9E, Ubi. Btmhole LOc. 1362'F~, 1825'F%ffL, Sec. 22, T13N, RgE, 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, t.~ere 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. Ver~ trulv~ours, ~ ~ C. V. Chattertoh Chaiz~nan of Alaska Oil and. Gas Conservation Commission BY ORDER OF THE CO~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK. _ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill 1~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Kuparuk River Field ARCO A1 aska, I nc RKB 59 ' PAD 24 ' feet Kuparuk River 0il Poo , 3. Address- 6. Property Descj.ejnation P.0. Box 100360, Anchorage, AK 99510-0360 ADL 25513' ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1019'FNL, 2011'FWL, 5ec.22, T13N, R9E, UN Kuparuk River Unit Statewide (~ target) At top of productive interval 8. Well nu ,mber Number 1320'FNL, 1848'FWL, 5ec.22, T13N, R9E, UN 30-12 #8088-26-27 At total depth 9. Approximate spud date Amount 1362'FNL, 1825'FWL, Sec.22, T13N, R9E, UM 05/16/88 $500,000 12. Distance to nearest 13. E~i(~t.alnCe_ to nearest well 14. Number of acres in property 15(;847,MDPrODosed depth (MD and TVD) property line ..~1~'@ TD feet 25' ~ surface 2560 (6810'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 461 7 feet Maximum hole angle 11 0 Maximum surface 11 40 psig At total depth (TVD) 3151 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5~ H-40 Weld 80' 35' 35' 115' 115' +200 cf _ 13-1/2~' 10-3/4 ' 54.5~ J-55 BTC 2184' 35' 35' 2219' 2219' 900 sx AS II I & HF-ERW 300 sx AS II 9-7/8"/ 7" 26.0~ J-55 BTC 6813' 34' 34' 6847' 6810' 80 sx TLW lead & ~-1/2" HF-ERW 200 sx Class G ~ail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Tuc 5uo' above UGNU Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural . Conductor Surface Intermediate ?~ ~.~ Production Liner Alaska 0ii & Gas C0as. C0ml~Jssi0~ Perforation depth: measured A~ch0ra!~ true vertical 20. Attachments Filing fee'li~ Property plat [] BOP Sketch [] Diverter Sketch Drilling fluid program I~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby cer ' hat the foregoing i.~true and correct to the best of my knowledge Signed "-~,'t.~' Title Regional Drilling Engineer Date !//~ ¢¢ ¢.,, / / Commission Use Only Permit Numld'er/ lAP, number I Approval date' ' See cover letter ¢8 ~-~' 50-- ~---9 - ~-.~ 8o~ 0 4 / 2 6 / 88 for other requirements Conditions of approval Samples required [] Yes J~ No Mud log required Lq Yes [] No Hydrogen sulfide measures [] Yes 1~ No Directional survey required ~ Yes [] No Other: by order of Approved Commissioner the commission Dar Form 10-401 Rev. 12-1-85 riplicate 100! ................. 20Q~ r ...... ~_ .... 4QQQ I'rl B/ PERIIAFROST TVD-1719: 9 5/8" CSG PT TVD-2219 T/ UGNU SNDS TVD-2689 T/ W SAK K-12 TV SNDS TVD'3474 )-3874 TVD.461 r' THO'4617' DEP-O BUILD 3 04:0 PER 1~ ~~ ( ~-- TVD-4982 - TI~).,.~9 AVERAGE ANGLE ~/~ZONE 'D TVD:641'9 T~6448 DEP:315 T/~ZONE C TVD 64T4 TH~6504; DEP 325 T/:ZONE- A TVD"6509- TH~6540~ DEP"332' TARGET CNTR :TVD-6562 ~-6594 DEP-342 B/~KUP SNDS ~,TVD-6614 T~-664Z DEP-352, 300 ~EST-EAST 200 1 oo o 1 oo , I I I, ,, I-- TARGET CENTER TVD.,6~ THD-~w~ .. DEP-342 "JOUTH 301 IdEaT. SU~,4~ LOCAT ! Olt, 101~9' FNI.~. 2011' F'VL c~o- ~2.. T13N. TARGLrT LOCATIONs 1320' FILL, 1848' FIdl. BEG. ~, TI3N, RGE · TD L~ATION ~ 13el, g:,* FILL. I~' FVL ~C~.-~. TI3M. ROE: iS 28DEG 26 I"I~N 342' i(TO TARGET) * .... .._gSQ~ I , I :~00 ~,,~, i : ,~(,.. -~,~ .............. '~ ............. : .......... t .......... 1 050. ~°,}o~--~ ~. ~ !~ ............. .': ...... ', ............ ....... 1250 _. -130.0 :1 950 2000 2050 21 O0i 1 50 ; .................................................................. ~ ...................... ~. .............. ~ ..... --i ......... ; KUPARUK RIVER UNIT 20' DIVERTER SCHEFIATIC 4 DESCRIPTION _ I. 16' CON(X~TOR 2. Fi'lC SLIP-ON WELD STARTIN6 I. EAD 3. Fl"lC DIVERTER ASSEI'IBLY WITH 'P.'O 2-I/16' 20O0 PSI BALL VALVES 4. 20' 2000 I~1 DRILLI~ ~POQ. W/lO' OUTLE~ 5. 10' HCR BALL VALVES W/lO' DIVERTER LINES. A SINeLE VALVE OPEN~ AU~TIG~LLY CLOSU~ ~ ANNtL, U~ PREVEN11R. VALVES CAN BE Rr:I~TELY CONTROLLED DIVERSION. 6. 20' 2000 PSI AJ~ ~ · . ARCO AJ. ASKA. INC.. REGUESTS A~.,kL OF THIS DIVERTER SYSTEM AS A VARIANCE FROH 20AAC2$.O3$(b) HAl NTENANCE & OPERATION 2 2, . UPON INITIAL INSTALLATION, CLOSE PI~VENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN TI'IE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE D(RVNWIND DIVERSION. O0 NOT SHUT IN WELL UNDER ANY t~IRCUI"ISTANCES ' o , I DIA6RAM #1 13-5/8' 5000 PSI RSRRA BOP STACK ,,> ACOJMJL, ATOR CAPACITY TEST I. Q-ECK /~D FILL ~TOE RESERVOIR TO PROPER LEVEL WITH HYDRN.LIC FLUID. 2. ASSURE THAT ACCLIVI. LATCR PI~.SSt.I~E IS 3000 PSI WITH 1500 PSI ~TREAM OF' THE REGLLATCR, 3. (]I~ERVE TIlvE., TI-EN CLOSE ALL UN]TS SIMJLT~(3J~Y AND RECOI~ THE TII~ N~D PRESSIJI~ REI~ININS AFTER ALL UNITS ~ CLO3ED WITH O. IAEGING PUM3 (::FF. 4. REC(31~ ON ~ REPORT, THE ACTABLE L~ LIMIT IS 45 SE~ CLOS!I~ T!I~ AM:) 1200 PS! REM~!NZI~ 13-5/~" BOp, STACK TE, ST I. FILL BCP STACK /~O CHCKE IVle/~FCLD WITH ~ZC DIE.L, 2. ~ ~T ~L L~ ~ ~ IN ~L~ ~LY ~T~ED. ~AT TEST ~ IN ~L~ ~TH ~I~ JT ~ ~ IN L~ ~~ 3. ~ ~ ~~ ~ ~ KILL LI~ V~ ~~ TO ~ ST~. ~ O~R V~S~~ ~D~ ~ 4. ~~ ~ TO ~ ~I ~~DF~ I0 ~ ~ ~~ TO~~ ~~DF~ I0 ~ED ~~ TO 0 ~I. L~ V~ ~ T~ PI~ ~ ~ ~ V~ ~ K~ ~ ~ ~ ~ST TO ~~ ~~ ~I ~ IN~P 4. 7. ~I~ ~I~L V~E~ LI~ ~ ~P 4. ~T ~~ TE~ ~ ~ T~T ~ A F~L ~I~ ~ITI~ ~ ~, ~Y ~TI~ TEST ~ES ~T ~ ~ F~Y ~. 8. ~N T~ PI~ R~ ~ ~ ~~ PI~ ~T ~T~PI~ ~ TO ~ ~I ~ ~~I. 9.~N~TT~PI~ ~ BA~ ~T ~~ ~ ~L ~ ~ ~E. I0. ~ ~I~ ~ ~ TEST TO ~ ~I ~ ~I. II. ~N ~I~ ~ ~ ~I~ ~T ~ ~ ~IF~D ~ LI~S ~ F~ ~ ~EZI~ FLUI: ~T ~L V~ IN ~ILLI~ ~ITI~ 12. ~ST ~~I~ V~ ~Y. ~LLY ~ ~ILL PI~ ~ETY V~, ~ I~I~ ~ TO ~ ~ ~I. 13. ~~ TEST I~~TI~ ~ ~~ ~~ER F~ SI~ ~ ~T~ILLI~ ~RVI~. ~E~Y T~~]F~T~Y ~TE ~ ~ILY. 51008400 I I~V I 1) MIRU. 2) Install FMC diverter system. RU mud loggers. 3) Drill 13-1/2" hole to 10-3/4" surface casing point according to directional plan. 4) Run and cement 10-3/4" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 9-7/8" hole to core point according to directional plan. 8) Core UGNU/West Sak as directed with 9-7/8" x 5-1/4" equipment. 9) With coring complete, drill to about 4000' and log as directed. 10) * Drill 8-1/2" hole to Kuparuk core point according to'directional plan. 11) Core as directed. 12) Run open hole logs. 13) Drill 8-1/2." hole to .provide 100' between PBTD and bottom of Kuparuk sands. 14) Run and cement 7" casing. Pressure test to 3500 psig. 15) Downsqueeze Arctic pack and cement in 7" x 10-3/4" annulus. 16) ND BOPE and install temporary Xmas tree. 17) Secure well and release rig. 18) Run cased hole logs. 19) Move in workover rig. NU BOPE. 20) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 21) Perforate and run completion assembly, set and test packer. 22) ND BOPE and install Xmas tree. 23) Change over to diesel. 24) Flow well to tanks. Shut in. 25) Secure well and release rig. 26) Fracture stimulate. DEGASSER MUD CLEANER SHALE STI STIR STIR SHAKERS MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up Weight Up to %D Density 9.6-9.8 8.7-9.2 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 6 pH 9-10 9.5-10.5 9.5-10.5 Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.0 ppg EMW 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. L~/ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operationa,.:~:Th~fi~ulus will be sealed with 175 sx of cement foI~o~ed :~bYi~a~ic pack upon completion of the fluid disposal. !~'~'" I D: KRU,'C I/NU/DR ! LL I NG TEL N0:907-=~5-o=18 -_ , i . ~525 PO1 ~ WELLS LOCATED IN SEC. 22 T, 13 N., R. 9 E.., UMtAT MERIDIAN. NOTES I. ALL COORDINATES ,I.RE A.$.P., ZONE 4. ~.. ALL DISTANCES ~,IOWN ARE TRUE. 3. ELEVATIONS &.RE 4, REFER. FIELD BOOK L-aa-3, ~-$3. 5. O.G. ELEVATIONS FIIK)M CED-RIXX-3,3&S& 6, HORIZONTAL. POSITION DASEZ) ON 343 coN'Tli~I. MONUMENTS ~ U3UNSBURY & A~Io~ Well Y ASPi ..... --; I LATITUDE LONGITUDE FN.L. E~L . . ~ I 6,0Z I~,095. Z7 5E~5,478. Z7 ~ZS' t?,3~;p 149e 47' 30.89T" ~4' le4~' IT. 5' 23.9' 2 6,022,073. ~ 5~5,490.94 70e~' 17.129" 1490 47'30.5~" 745' 1855' 17.7' ~3.~', 3 6 ,022 ,052.13 525,~3.67 ~; 169~3". , t49~47:30.1~;: 76~ 1667' 17.9' 4 6,02Z,030.~ 5ZS,515.Se ~2&, I&~l ,. 149 47, Z9.8~. 189: i879; mC.Q: 5 6,0Z2,~8.~ 525,528.36 7~Z6, ' 149o 47, 29.4~. 81 I, 189~, I~. I ~6 l~2~' 149°47,~,071. 93Z, 19~; le. I, ~ 6~02 t ~9~. I~ 5~ ~57e.~7 i5,632 149e 47 27,974 ~97 194t 18.~ I0 6,0Z I ,84~ 525,623.61 ~28' 14.~3" 149047'26.6~'' 975' 1986' I8.7' 11 6,021,822.~ 525 ~G~5.71 '~' 14. G51" 1490 47'26.~5" ~7' 1998' 18.8' 23.5' ~3 6,0z[,e~.e7 525,64a.~ z~2e', 14.437" 149°47',~.9~ mO~9' 2011' ,e.e' 13 6,0z ,779. 16 525 ~66t .~ ~e~ 14, zz3" 149e47,25.~. 1041', zoz4', la.~', ~3.0, 14 6,0~1 ~7.~ 5z5,6~.~ · ' i~.0~0'~ .14ee47,~5,~. t0~ Zoo, 19.0, 15 6,02t ~735. 76 5~5 ,~6. tz ~e~, 1~.~5 14~e47 24.8~ 1084 2048, I~.0, 22.~; 16 6~0~ 1~14. 15 5z5~6~. 17 ~e28' 13.~" 149e47'Z4.4~" I1~ ~0~, I~. I 2~9 17 6~0~1,69~ 5~5 ~710.85 ~' 13,~6~" 14~e47'z4. o~" t IZ~ 2073 19.0' t8 6,0z 1,670.~7 5~5 ~7~3.~ ~z~' t3.157" 149047'~3,733" 1149' ~085' 19.0' i i ii I HEI~E(IY CERTIFY TI.~T I AM PROP[RI,,Y i~F. OI<Jl'ERED ~ ~¢ENSED TO PRAC- TiCE LAND SURVI~INO IN TIlE STATE OF AL,A~,KA AND THAT TMI $ PhAT REPRESENTS A .lOCATION SURVEY ~ BY ~iE OR UNDER. MY ~UPERVI$1ON, AND THAT AIL DIMENSION3 Jd~O OTNF..R lmU,C,~W U I~ Il, 04 ~,CT D.S. 3.0 WELL coNDUCTOR AS-BUILT LOUNSBURY & socia[.e,s ANCHORAGE ............... 2 '_._ ALA {}wa. by, MO'D ! C..h,k I1~, ~'~T CHECK LIST FOR NEW WELL PERMITS ....... I EM APPRO~ DATE (2 thru 8) ~ (8) (9 thru 13) 10. (10 and 13) 12. 13. (4) Cas g ~, (14 thru 22) (s) (23 thru 28) (29 thru 31) (6) Add: Company /~[~CO Lease & Well No. ~J YES NO 1. Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ............................. ~ 3.. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... O. 5. Is sufficient undedicated acreage available in this pool ..' .......... ~._ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. ~__ Is a conservation order needed ...................................... Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~f~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31 Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... ,~ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... ,, Will 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 separation proposed ............................ Is a diverter system required ....................................... ~ ~ ,, Is the drilling fluid program schematic and list of equipment adequate,~,~ Are necessary diagrams and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to 3oo~ psig .. ~ · Does the choke manifold comply w/API 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 .... P t~ If an offshore loc., are survey results of seabed conditions . . 32 Additional requirements · · ~ee~eeeee®eetee®eeeee~eeee lelel~ee~eeeeeeeee 0 ~0 Geology: Engipeering: LCS rev: 02/17/88 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS T~PE V~RIFIC~TION LISTING VP 010.H02 VERI,=ICATION LISTING PA!~E REEL HEADER ~ ~ERVICE NAME :EDIT ~ATE :88/06/17 ~RIGIN : IEEL NAME :72789 ',ONTINUATION ~ :01 'REVIOUS REEL : 10MMENTS :EDIT LIS, ARCO KUP~RUK 3 0-!2, A~I~ 50-029-Z[804 :, TAPE HEADER ~:~ ;ERVICE NAME :EDIT tATE: 88/06/17 1RIG!N :FSIA 'APE NAME : ;DNTINUATION ~ :01 'REVIOUS TAPE : ;OMMENTS :EDIT LIS, ARCO KUPARUK 30-ZZ, J~P!~ 50-0Z9-21804 FILE HEADER ** :ILE NAME :EDIT .001 ;ERV'ICE NAME : ?ERS ION ~ : )ATE : 4AXIMUM LENGTH : 1024 :ILE TYPE : ~RE¥IOUS FILE : INFORMATION RECOROS *~ ~NEM CONTENTS :N : ARCO ALASKA, INC,, ~N : 3 0-12 :N : KUPARUK ~ANG: gE tOWN: 13N ;ECT: 22 ~OUN: NORTH SLOPE ~TAT: AL AS K,ti, COMMENTS UNIT T'YPE CATE SIZE CODE 000 000 017 065 000 000 006 065 000 000 0:08 065 OOO 000 002 065 000 000 004 065 000 000 OOZ 065 000 000 O1Z 065 000 000 006 065 ,VP OlO.HOZ VERIFICATION LISTING mAGE 2 SCHLUMBERGER ALASKA COMPU'TING CENTER :OMP&NY : ARCO ALASKA ~NC IELL = ~ 0-12 :IELD = KUPARUK :OUNTY = NORTH SLOPE BOROUGH ~AT~ = ~L~SKA IDB NUMBER AT ~KCC: 72789 ~UN ~1~ DATE LOGGED: 25-MAY-88 ~UN ~2, DATE LOGGED: OZ-JUN-S8 .DP: RICK KRUWELL ~UN 1 M. UD INFORMATION: :ASING = 16.00" @llO'(DRILLER) - BIT SIZE : 12.25" TO 4123'CDRILLER) tYPE FLUID = SPUD MUD )ENSITY : 9.5 L°~/G R~ = 5.65 @ 65 DF IISCOSITY = 79 S RMF = &.68 @ 65 'DF ~H : 9.0 R~'IC .= 3.92 @ 65 gF :LUID LOSS = 5.2 C3 RM AT BHT = 4.785 @ 78 DF VP 010.H02 VERIFICATION LISTT. NG P~.GE 3 UN 2 MUO INFORMATION ASING = 9.625" @4105' (DRILLER) - BIT SiZE : 3.5" TO 7000 ' (DRILLER) YPE FLUID = KCL POLYM-R ~ENSITY = 10.1 LB/G RM : .627 @ 58 DF ISCOSZTY : 41 S RMF : .492 @ 58 DF 'H : 8.0 R..'~!C = .895 @ ST DF :LUID LOSS : 5.0 C3 RM AT 8HT : .289 g 134 DF IATRIX SANDSTONE :UN 1 FIELD REMARKS: 2 CMEZ'S & 5 RU3BER FIN STaNDOFfS USE9 ~ Z' HOLE FINDER RUN ON BOTTOM OF OIL. SONIC DOWNHOLE GAIN = /1. DIL/LSS LOGGING SPEED VARIED BETWEEN 1800 - 3000 FT/HR. CNL BOW SPRING USED. EXTREME WASHOUT BELOW CASING IS LARGER THAN MAXIMUM LOT C&LIPER READING (23"). LDT/CNL DATA BETWEEN CASING AND 460' SHOULD BE REGARDED dS QUESTIONABLE mOR THIS REASON. ',UN Z FIELD REMARKS: 1.5" STANDOFF ON OIL SONDE. 8'-10'-1Z' SONIC SPACINGS. MDEN = 2.65 G/C3, MATRIX SANDSTONE, BHS = OPEN, HC = CALIPER, FLUID DENSITY = 1.0 G/C3. :LIC CDMENTS: 1) FIlE EDIT.O01 CONTAINS DATA OF DUAL INDUCTION ('.OIL), LONG SPACED SONIC (.LS.S), FORMATION DENSITY LOG (oFDC), LITHO DENSITY LOG (.EDT), COMPENSATED NEUTRON LOG (.CNL) S~MPLED @ .S' 2) FILE EOIT'OO2 CONTAINS DATA OF HI RESOLUTION FORMATIQN DENSITY (.FOH), HI RESOLUTION COMPENSATED NEUTRON LOG (.CNH) SAMPLED @ 1.2"' .VP OIO.H02 VERImIC~TION LISTING PAGE 4 THIS D,&T~ HAS NOT SEEN OEPTH SHI:TED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DU~L INDUCTION SPHERICALLY FOCUSED LOG (.~IL) DATA ~VAILA~LE: 6992' Tg 110' LONG SPACEO SONIC (.LSS) D~TA ,~VAILA~LE: 6986' TO 110' mORMATION DENSITY COMPENSATED LOG (.FDC) ORTR AVAILASLE: 696,6' T~ ~107' LITHD DENSITY LOG (.LOT) DATA AVAILABLE: 4125' TO 110' COMPENSATED NEUTRON LOG (.CNL) DATA ~VAILABLE: 6953' TO ,110' mDRMATION DENSITY LOG HI RES 1.2" (.FDH) DATA AVAILABLE: 6965' TO 6297' COMPENSATED NEUTRON LOG HI RES 1.2" (.CNH) DRTA AVAILABLE: 695,)' TO 6297' .VP 010.H02 VERIFICATION LISTING PAGE 5 DATA FORMAT RECORD !NTRY BLOCKS TYPE SIZE REOR CODE ENTRY 2 8 4 73 9 4 65 .lin 16 1 66 1 0 1 66 0 )ATUM SPECIFICATION BLOCK.S ~NEM SERVICE SERVICE UNIT AP1 AP1 AP1 ~PI FILE SIZE SPL REPR I0 ORDER ~ LOG TYPE CLASS MOD NO. )EPT FT O0 000 O0 0 0 4 FENS Oil LB O0 635 21 0 0 4 ;FLU OIL OHMM O0 220 O1 0 0 ILO 9IL OHMM O0 120 46 0 0 4 [LM OIL OHMM O0 120 44 0 0 4 ;P DIL MV O0 010 O1 0 0 4 ;R OIL GAPI O0 310 Ol 0 0 4 tENS LSS LB O0 635 21 0 0 4 )T LSS US/F O0 520 80 0 0 )TL LSS US/F O0 520 80 0 0 4 ;R LSS GAPI O0 310 O1 0 0 4 FENS FDC LB O0 635 Z1 0 0 4 :~lI FDC IN O0 280 O1 0 0 ~HOB FDC G/C3 O0 350 02 0 0 4 )RHO FDC G/C3 O0 356 O1 0 0 4 )PHI FDC PU O0 B90 O0 0 0 ~FDC FDC CPS O0 354 O1 0 0 4 =FDC FDC CPS O0 354 02 0 0 4 ;R FDC GAPI O0 310 O1 0 tENS EDT LB O0 635 21 0 0 4 ~HOB LOT G/C3 O0 350 02 0 0 4 ]RHO LDT G/C3 O0 356 O1 0 0 4 )PHI LOT PU O0 890 O0 0 0 4 ~EF LOT O0 358 O1 0 0 4 ~SS LDT O0 000 O0 0 0 4 ~LS LOT O0 000 O0 0 0 4 LSHV LOT V O0 000 O0 O 0 4 SSHV LOT V O0 OOO O0 0 0 LL LDT CPS O0 35~ O1 0 0 4 LS LD'T CPS O0 354 O1 0 0 4 LU LDT CPS O0 354 01, 0 LITH LOT CPS O0 354 O1 0 SSI LOT CPS O0 000 O0 0 0 4 PROCESS CODE CDCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6B 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6B 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6~ 00000000000000 68 00000000000000 68 00000000000000 58 00000000000000 68 00000000000000 58 00000000000000 68 00000000000000 68 O000OO00000000 6B O00000000OO000 68 00000000000000 68 O0000000000OO0 68 00000000000000 $8 00000000000000 68 00000000000000 .¥P OlO.H02 VERIFICATION LISTING PAGE 6 ;S2 LDT CPS O0 000 O0 0 ITEN LDT LB O0 OOO O0 0 IRES LDT OHMM O0 823 50 0 ITEM LOT DEGF O0 660 50 0 ;ALI LDT IN O0 280 01 0 ;R LDT GAPI O0 310 01 0 'ENS CNL LB O0 635 21 0 IPHI CNL PU O0 890 O0 0 'NRA CNL O0 420 01 0 ~TNR CNL O0 000 O0 ~CNT CNL CPS O0 000 O0 0 ICFT CNL CPS O0 000 O0 0 ;FTC CNL CPS O0 000 O0 0 ~NTC CNL CPS O0 000 O0 0 tTEN CNL LB O0 000 O0 0 IRES CNL gHMM O0 823 50 0 ITEM CNL DEGF O0 660 50 0 ;R CNL GAPI O0 310 O! 0 )EPT 7012. 5000 TENS [LM 2 . 1589 SP )T -999.2500 -gTL :ALI 8.5000 RHO8 IFgC 617.5000 FFOC ~HOB -999.2500 DRHO ~SS -999. 2500 QLS .L -999. 2500 tS ~Sl -999.2500 SS2 iTEM -999.2500 CALI ,IPH! 30.6001 TNRA ~C~T 681. 1726 CFTC fiRES -999.2500 MTEM )EPT 7000.0000 TENS [IM 2.0727 SP ]T -999' 2500 OTL CALI 8. 3906: R~HOB qFOC 617.5000 FFDC )HDB -999.2500 DRHD QSS -99 9. 2500 QLS LL -999.2500 LS · SS1 -999.2500 SS2 MTEM -999.2500 CAlI NPHI 30.6001 TNRA RCFT 681.1'726 CFTC MRES .-999.2500 MTEM DEPT 6900.0000 TENS ILM 3.0178 SP OT 90.7500 DTL' CALI 8.5703 R'HOB 4068.0000 SFLU -34.4063 GR -999.2500 G~ 2.4236 ORHO 531.5000 GR '-99g.2500 gPHI -999.2500 LSHV -999.2500 LU -999.Z500 HTEN -999.2500 GR 2.7704 RTNR 767.7623 CNTC '-999.2500 GR 3554.0000 SFLU -19.0000 GR -999.2500 GR 2.4236 DRHO 531.5000 GR -999.2500 OPHI -999.2500 LSHV -99'9.2500 LU -999.2500 HTEN -999.2500 GR 2.7704 RTNR 76'7.7623 CNTC -999.2'500 GR 4908.0000 SFLU -20.5000 GR 91. 7500 GR 2.4896 DRHD 2.6057 141.1250 -999.2500 0.0339 141.1250 -999.2500 -999..2500 -99'9.2500 -999.2500 -999.2500 2.9927 2088.6543 141.1250 2.3806 141.I250 -999.2500 0.0339 141,.125:0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.9927 2088.6543 141.1250 3.8557 9z+. 1875 89.1875 0.0127 I 68 I 68 I 68 I 68 I 68 I 68 I 58 I 68 I 68 I 68 I 68 I 68 I 68 I 68 I 68 I 68 I 68 I 58 ILD TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN IlO TENS TENS gPHI TENS PEF SSHV LITH MRE S TENS RCNT HTEN ILD TENS 'TENS DPHI 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O00000000OO000 00000000000000 00000000000000 00000000000000 O00OO00000000O 00000000000000 00000000000000 O0000OO0000000 O0000000000OO0 00000000000000 Z.1379 -99'9.2500 4068.0000 13.7299 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z5'00 4068.00O0 20615.7969 -999.2508 2.1030 -999.2500 3584.00O0 13.7299 -999.2500 .-9~99.250:0 -999.,,2500 -999.2500 -999.2500 3584.0000 Z065'7969 -999.2500 2.815'1 4340.0000 4908.0000 9°7324 .VP OIO.HOZ VERIFICATIDN LISTING PAGE 7 IFDC 560.0000 FFDC IHOB -999.2500 ORHO )SS -999.2500 QLS .L -999.2500 LS ;51 -999.2500 SS2 ITE~ -999.2500 CALI 4PHI 31.8377 TNRA )CFT 715.9847 CFTC IEES -999.2500 MTEM )EPT 6800.0000 TENS [LM Z.6111 SP )T 102.8750 DTL ~LI 8.5391 RHDB IFDC 59!.5000 FFDC )HOB -999.2500 DRHO }SS -999.2500 QLS .L -999.2500 LS ;.51 -999.2500 SSZ ~TEM -999.2500 CALI (PHI 41.5210 TNRA ~CFT 511.0759 CFTC 4RES -999.2500 MTEM )EPT 6700.0000 TENS [LM 13.9149 SP )T 92.5000 OTL :AL! 8.5078 RHOB ~FgC 599.0000 FFDC ~HOB -999.2500 ORHO }SS -999.2500 QLS -L .-999.2500 LS ~S1 -999.2500 SS2 iTEM -999.2500 CALI tPHI 30.8637 TN~A ~CFT 837. 8881 C~TC iRES -999.2500 MTEM ]EPT 6600.0000 TENS [LM 3.0083 SP ]T 91.3750 DTL CALI 8.5859 RHOB tFDC 551.5000 FFDC ~HOB -999.2500 DRHO ~SS -999.2500 QLS ~L -999.2500 LS SS1 -999.2500 SSZ ~TEM -999.2500 CALi qPHI 31.0208 TNRA RCFT T30.9933 CFTC ~RES -999.2500 MTEM 3EPT 6500.0000 TENS ILM 1.9367 SP 429.2500 GR -999.2500 OPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 2.8675 RTNR 801.8046 CNTC -999.2500 GR 4840.0000 SFLU -23.7656 GR 103.2500 GR 2.4529 DRHO 484.2500 GR -999.2500 QPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3.4110 RTNR 581.2949 CNTC -999.2500 ~R 4648.0000 SFLU -27.5156 GR 89.0.000 GR 2.3355 ORHO 604.0000 GR -999.2500 OPHI -999.2500 LSHV -999.2500 LU -g99.2500 HTSN -999.2500 GR 2.7977 RTNR 95~.7516 CNTC -999.2500 GR 4760.0000 SFLU -26.5000 GR 90.0000 GR 2.5049 DRHO 411.5000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 2.8149 RTNR 830.8113 CNTC -999.2500 GR 4668.0000 SFLU -28.0000 GR 94. -999. -999. -999. -999. -999. 3. 2252. 94. . 97. 94. O. 97. --999. -999. -999. -999. -999. 3. 1907. 97. 18. 69. 61. --0. 69. -999. -999. -999. -999. -999. '3. 2658. 69. ,. 113. 106. O. 113. -999. -999. -999. -999. -999. 3. 2395. 113- . 111. 1875 2500 2500 2500 2LO0 ZSO0 0375 3130 1875 3615 8125 1875 0252 8125 2500 2500 2500 2500 7-500 6473 4922 6166 6250 0938 0024 6250 2500 2500 2500 2500 2500 0693 2607 6250 9410 5625 1875 0110 5625 2500 2500 2500 2500 2500 ZOO0 8223 5625 1704 6250 TENS PEF SSHV l ITH MEES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HT~EN ILO TENS TENS gPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4908.0000 2278.7583 -999.2500 2.4996 4312.0000 4840.0000 11.9524 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4840.0000 1919.5815 -999.2500 12.8136 4240.0000 4648.0000 19.0660 -999-2500 -999.2500 -999.2500 -999.2500 -999'2500 4648.0000 2669.T891 -999.2500 2.8680 4220.0000 4760,.0000 8.8013 -999.2500 -999.2500 ,-999.250'0 -999o~500 -999.2500 4760.0000 2378.2729 -999.Z500 1.8368 4160.0:000 · VP 010.H02 VERIPICATI~N LlSTING PAGE 8 tT 96.0000 DTL ;ALI 11.0547 PHOB IFDC 775.0000 FFDC IHOB -999.2500 ORHO )SS -999.2500 ~LS .L -999.2500 LS ;S1 -999.2500 SS2 ITEM -999.2500 C~LI IPHI 47.2736 TNRA ~CFT 400.5454 CFTC IRES -999.2500 MTEM ~EPT 6400.0000 TENS ~L~ 1.4790 SP }T 108.5000 DTL ;ALI 11.7422 RHDB IFDC 728.0000 FFDC ~HOB -999.2500 ORHO )SS -999. 2500 QLS .L -999.2500 tS ;S1 -999.2500 552 ITEM -999.2500 CALI tPMI 47.0036 TNRA ~CPT 379.0885 CFTC 4RES -999.2500 MTEM )EPT 6300.0000 TENS [tM 2.1777 SP )T 109.5000 DTL :ALI 10.7500 ~HOB 4FDC 637.5000 FFDC ~HOB -999.2500 ORHO ~SS -999.2500 qLS .t '-999.2500 tS ~S1 -999.2500 SS2 4TEM -999.2500 CALI ~PHI 46.4710 TNRA ~CFT 372.3486 CFTC qRES -999.2500 MTEM )EPT 6200.0000 TENS [LM 2.4548 SP )T 10 5. 7500 OTL SALI 9.1953 RHOB ~FDC 651.5000 FFDC ~HOB -999.2500 DRHO ~SS -999.2500 QL$ =L -999. 2500 LS SSI -999.2500 SS2 4TEM -999.2500 CALl ~PMI 40.5717 TNRA RCFT 562.6963 CFTC MRES -999,2500 MTEM 91.2500 GR Z.170Z DRHO 1043.0000 GR -999.2500 OPHI -999.2500 LSHV -999.2500 LU --999.2500 HTEN -999.2500 GE 3.9112 RTNR 406.3696 CNTC -999.2500 GR 460~.0000 SFLU -31.0313 GR 110.5000 2.2067 DRHO 914.5000 GR -999.2500 9PHI -999.2500 LSHV -999.2500 LU -ggg.2500 HTEN -999.2500 GR 3.9146 RTNR 394.8964 CNTC -999.2500 GR 4560.0000 SFLU -35.7500 GR 110.0000 GR 2.4007 DRHO 572. 5000 GR -999.2500 OPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3.8594 RTNR '439.0396 CNTC -999.2500 GR 4460.0000 SFLU -38.2500 GR 108.5000 SR 2.3638 ORHO 623.5000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999-2500 GR 3.4132 RTNR 601.3759 CNTC -999.2500 GE 109. O. 111. -999. -999. -999. -999. -999. 4. 1570. 111· I · 102. 95. O. 102. -999. -999. -999. -999. -999. 4. 1522. 10 Z. 121. O. 124. -999. -999. -999. -999. -999. 4. 1624. 12.4. 202. 215. O. 202. -999. -999. -:999. -999. -999. 4. 1983. 202. 6250 0545 6250 2500 2500 2500 2500 2500 5000 5236 6250 7214 6875 1250 0374 6875 2500 2500 2500 2500 2500 6000 2335 6875 6550 0625 5625 0410 0625 2500 2500 2500 1500 2500 0317 779 B 0625 1795 0000 2500 0387 0000 2500 2500 1500 Z 500 1500 1923 8059 0000 TENS 9PHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ltd TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN 4668.0000 29.0838 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4668.0000 1537.8364 -999.2500 1.4361 3994.0000 4604.0000 26.8748 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4604.0000 1484.2634 -999.2500 2.0265 4000.0000 4560.0000 15.1187 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4560.0000 ~549.0417 -999.2500 2.4346 3944.0000 4460.0000 17.3539 -999.2500 -99:9.2500 -999.2500 -999.2500 -999.2500 4460.0000 I885.18~3 -999.1500 .VP OIO.HOZ VERIFICATION LISTING PAGE 9 ~EPT 6100.0000 TENS :LM 2.3131 SP ~T 98. 2500 OTL ',ALI 9.47,66 RHOB IFDC 658.5000 FFDC ',HOB -999.2500 ~RHO ISS -999. 2500 QLS .L -999.2500 LS ;SI -999.2500 SS2 ITEM -999.2500 CALI IPHI 38. 5341 TNRA ICFT 562.6963 CFTC IRES -999. 2500 MTEM iEPT 6000.0000 TENS :LM 1.8080 SP iT 104.3750 DTL ',ALI 9.2187 RHOB IFDC 602.0000 FFDC ~HOB -999.2500 DRHO }SS -999.2500 qLS .L -999.2500 LS ;51 -999. 2500 552 ITEM -999.2500 CALI IPHI 41.2615 TNRA ICFT 550.6045 CFTC IRES -999.2500 MTEM )EPT 5900.0000 TENS :LM 2 . 58 59 SP )T 100.0000 OTL :ALI 9.4922 RHOB IFOC 610.0000 FFDC tHOB -999.2500 DRHD )SS -999.2500 QLS .L -999. 2500 lS ;SI -999. 2500 SS2 ~TEM -999.2500 CALI 4PHI 34.3000 TN~A ~CFT 602.6979 CFTC IRES -999. 2500 MTEM )EPT 5800.0000 TENS [:LM 2. 3434 SP )T 9 7.13750 O T L :ALI 9.3047 RHOB dFOC 599.0000 FFDC ~HOB -999. 2500 DRHO )SS -999. 2500 QLS .l -999.2500 LS ~S1 -999.2500 552 ~TEM -999.25'00 CALI ~PHI 36.2361 TNRA ~CFT 711. 8292 CFTC 4480.0000 SFLU -40.5625 GR 99.5000 GR 2.3548 DRHO 640.5000 GR -999.2500 DPH[ -999.2500 LSHV -999.2500 LU --999.2500 HTEN -999.2500 GR 3.3244 RTNR 576.4803 CNTC -999.2500 GR 43¢0.0000 SFLU -40.5313 GR 103.7500 GR 2.4512 ORHO 494.0000 GR -999.2500 OPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3.4527 ~TNR 651.2236 CNTC -999.2500 ER 4268.0000 SFLU -43.0000 GR 99.5000 GR 2.4689 DRHO. 487.0000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3.0949 RTNR 718.3544 CNTC -999.2500 GR 4204.0000 SFLU -45.2500 GR 97.5000 GR 2.4594 DRHD 484.5000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3.1849 RTNR 777.87t5 CNTC 2.5173 147.8750 138.2500 0.0406 147.8750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.8621 1959.3008 147.8750 Z.105B 96.5000 102.3125 0.0315 96.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.6327 2030.9524 96.5000 2.7303 126.31.25 118.4375 0.0433 126.3125 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.4000 2235.5786 126.3125 2.5691 116.1875 104.6250 0.0319 116.1875 -999.2500 -999.2500 -99'9.2500 -999.2500 --999.2500 3.¢902 2339.2T~9 ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT MTEN ILD TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HT EN ILO TENS 'TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTE'N 2.2811 )824.0000 4480.0000 17.8967 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4480.0000 1937.5232 -999.~500 1.6996 3764.0000 4340.0000 12.0581 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4340.0000 1988.2261 -999.2500 Z.4107 3774.0000 4268.0000 I0.9843 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4268.0000 2347.997I '999.2500 2.2403 3720.0000 4204.0000 11.5575 -999.2500 '-999.2500 -999.2500 -999.2500 -999.2500 42'04.0000 2359.9092 -999.2500 .VP OIO.HOZ VERI~ICATIDN LISTING PAGE 10 IRES -999.2500 MTEM IEPT 5700.0000 TENS :LM 3.1451 SP tT 88. 5000 DTL :ALI 9.2891 RHOB IFDC 614.5000 FFDC )HOB -999.2500 ORHO )SS -999.2500 QLS .t -999.2500 tS ~S1 -999.2500 SS2 {TEM -999.7500 CALI IPHI 28.2704 TNRA ,~CFT 843.9810 CFTC IRES -999.2500 MTEM )EPT 5600.0000 TENS :L~ Z.8905 SP )T 92.6250 DTL 3ALI 9.2266 RHO8 tFDC 584.5000 FFDC ~HOB -999.2500 ORHO )SS -999.2500 QLS .L -999.2500 tS ;S1 -999.2500 SSZ ~TEM -999.2500 CALI 4PHI 32.2449 TNRA ~CFT 782.9763 CFTC 4RES -999.2500 MTEM )EPT 5500.0000 TENS [LM 3.0716 SP )T 99.6250 OTL :ALI 9.6250 RHOB ~FDC 624.5000 FFDC ~HDB -999.2500 ORHO )SS -999.Z500 QLS -L -999.2500 LS ~S1 -999.2500 5S2 4TEM -999.2500 CALI ~PHI 34.9635 TNRA ~CFT 600.9967 CFTC ~RES -999.2500 MTEM )EPT 5400. 0000 TENS [LM 2.7443 SP )T 100. 1250 DTL :ALI 10.6406 RHDB 4FDC 612.5000 FFOC ~HO'B -999. 2500 ORHO )SS -999. 2500 QLS .t -999.2500 tS ~S1 -999.2500 SS2 ~TEM -999. 2500 CALI -999.2500 GR 4128.0000 SFLU -46.7500 GR 89.2500 GR 2.4269 DRHO 526.0000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.Z500 GR Z.6BB6 RTN~ 936.18~2 CNTC -999'2500 GR 4132.0000 SFLU -49.7813 GR 92.7500 GR Z.4067 DRHO 517.5000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 2.9487 RTNR 866.0090 CNTC -999.2500 GR 4030.0000 SFLU -48.5000 GR 99.0000 GR 2.4430 DRHO 521.5000 GR -999.2500 DPHI -999.2500 LSHV -'999.2500 LU -999.Z500 HTEN --999'2500 GR 3.1415 RTNR 689.0579 CNTC -999.25100 GR 4054.0000 SFLU -4~.Z813 ~ 100.2500 GR 2.432!5 DEMO 519.5000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU --999.2500 HTEN -999.2500 GR 116.1875 3.6565 90.2500 92.4375 0.03~7 90.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.9353 2593.4414 90.2500 3.2020 99.6250 98.0625 0.0059 99.6250 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 3.1522 2550.1216 99.6250 3.4523 116.3750 112.43'75 0.0456 116.3750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.0526 21181.7256 11,6. 3750 Z. 98'71 98.6250 100.0625 0.0331 98.6250 -999:.2500 -999.2500 -999.2500 -999.2500 -999'.Z500 ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT MTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI T~NS PEF SSHV LITH MRES TENS 2.9264 3650.0000 ~128.0000 13.5317 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 41Z8.0000 2481.9321 -999.Z500 2.7679 3610.0000 4132.0000 1~.7525 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 4132.00'00 2628.3765 -999.2500 2.970'3 3540.0000 4030'0000 12.5530 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 4030'0000 2100.8516 -999.,2500 2.5715 344&.0000 4054. 0000 13.1924 -999. 2500 -99!9.2500 -999.2500 -999.25100 -999.2500 4054.0000 .VP 010.HOZ VERIFICATIDN LISTING PAGE 11 IPHI ',CFT IRES ~EPT :L~ IT ;AL I IFOC [HOB .L ;S1 ITEM IPHI [CFT IRES )EPT )T ;ALI IFDC IHOB .l ;S1 ITEM tPHI ICFT IRES )EPT rLM )T :ALI tFDC ~HOB )SS .L ;SI ITEM tPHI ~CFT ~RES )EPT [LM )T :ALI l FDC ~HOB )SS .L 38.4486 TNRA 552.9128 CFTC -999.2500 MTEM 5300.0000 TENS 2.2208 SP 104. 0000 OTL 9.4844 RHOB 590.0000 FFDC -999.2500 DRHO -999.2500 ~LS -999.2500 tS -999.2500 SS2 -999.2500 CALI 35.0133 TNRA 584.1931 CFTC -999.2500 MTE~ 5200.0000 TENS 2.8076 SP 101.5000 DTL 9.4922 RHOB 599.0000 FFDC -999.2500 DRHO --999. 2500 QLS -999. 2500 LS -999.2500 SS2 -999.2500 CALl 34.4381 TNRA 620.3989 CFTC -999.2500 MTEM 5100.0000 TENS 2.6014 SP 102.0000 OTL 9. B047 RHOB 616. OOOO FFDC -999- 2500 DRHO -99'9. 2500 QLS --999. 2500 LS -999. 2500 SS2 -999.2500 C~LI 36.3082 TNR~ 639.9718 CFTC -999.2500 MTEM 5000.0000 TENS Z. 6857 SP 101. 6250 DTL 10.2500 RHOB 646.5000 FFDC -999.2500 DRHO -999. 2500 QLS -999. 2500 LS 3.4150 RTNR 648.9808 CNTC -999.2500 GR 3904.0000 SFLU -51.2813 GR 104.2500 SR 2.3961 DRHO 532.0000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2.500 HTEN -999.2500 GR 3.1333 ~TNR 694.0687 CNTC -999.2500 GR 3864.0000 SFLU -52.0000 GR 102.2500 GR 2.3914 DRHg 544.5000 GR -999.2500 OPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3.1025 RTNR 698.3613 CNTC -999.2500 GR 3750.0000 SFLU -52.5000 GR 102.2500 GR 2.4375 DRHO 518.5000 GR -999.2500 OPHI -999.2500 LSHV --999'2500 LU -999.2500 HTEN -999.2500 GR 3.2301 RTN~ 682.2736 CNTC -999.2500 GR 3790°0000 SFLU -53.7500 GR 102.5000 SR 2.37'28 DRHD 609.D000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU . 2141. 98. . 108. 103. O. 108. -999. -999. -999. -999. -999. 3. 2141. 108. . 107. 102. O. 107. -999. -999. -999. -999. -999. 3. 2085. 107. 2. 102. 103. O. 102. -999. -999. -999. -999. -999. 3. 2166. 102. 10I. 94. O. 101. - 999. -999. -999. 8750 ¢575 6250 4749 6250 2500 0067 6250 2500 2500 2500 2500 2500 5556 6343 6250 1270 1250 8125 0112 1250 2500 2500 2500 2500 2500 2568 4648 1250 8384 3750 9375 0374 3750 2500 2500 2500 2500 2500 5429 4604 3750 8620 6250 1250 0380 6250 2500 2500 2500 RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS DPHI TENS PEF SSHV LITH MRES TENS ~CNT HTEN ILO TENS 'TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HT~N ILD TENS TENS OPHI TENS PEF SSHV LITH 2074.8354 -999.2500 2.1298 3434.0000 3904.0000 15.3949 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 3904. OOOO 2153.2183 -999.2500 2.7133 3400.0000 3864.0000 15.6823 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3864.0000 2013..6958 -999.2500 2.5078 3330.0000 ~750.0000 12.8881 -999.2500 -999.2500 -999.2500 -999.2500 -999'2500 3750-0000 2180.0093 -999'.2500 2.5786 3290.0000 3790.0000 16.8087 -999.2500 -9:99.2500 -999.2500 -999.2500 VP 010.H02 VERIPZCA'TION LISTZNG P~SE 12 ,51 ITEM IPHI ',CFT IRES )EPT )T ;ALI IFDC ~HDB }SS .L ~51 4TEM 4PHI ~CFT ~RES )EPT 3T 'ALI qFDC RHDB QSS LL SS1 MTEM NPH I RCFT RR~S DE PT ~LM DT C~LZ NFDC RHOB LL MTEM NPHI RC~T MRES DEPT ILM DT CALI NF~C RHO~ -999.2500 SS2 -999.2500 CALI 34.2870 TNRA 572. 1742 CFTC -999.2500 MTEM 4900.0000 TENS 2.7845 SP 99.2500 gTL 8.9766 RHOB 631.0000 FFDC -999.2500 DRHO -999. 2500 QLS -999.2500 LS -999.2500 552 -999.2500 CALI 37.9261 TNRA 572.1011 CFTC -999.2500 MTEM 4800.0000 TENS 2.9860 SP 101.3750 9TL 8.7734 RHOB 732.0000 FFDC -999.2500 9RHO -999.2500 QLS -999.2500 tS -999.2500 SS2 -999. 2500 CALI 36.0680 TNRA 601.7869 CFTC -999. 2500 MTEM 4700.0000 TENS 2.4478 SP 103. 2500 D'TL 9.4453 RHOB 657.0000 FFDC -999. 2500 DRHO -999.2500 QLS -999.2500 tS -999. 2500 SS2 -999.2500 CALI 35.1024 TNRA 498. 1899 CFTC -999. 2500 M'TEM 4600.0000 'TENS 2.1842 SP 110. 2500 DTL 11.9687 RHDB 886. 0000 FFDC -999. 2500 ORHO -999.2500 HTEN -999.2500 GR 3.1561 RTNR 634.0291 CNTC -999.2500 GR 3670.0000 SFLU -57.5000 GR 99.7500 GE 2.4088 ORHO 558.0000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3. Z505 RTNR 676.5974 CNTC -999.2500 GR 3574.0000 SFLU -58.2500 GE 101.7500 GR 2.3944 DRHO 688.5000 GR -999.2500 gPHI --999.2500 LSHV -999.2500 LU -999.2500 HTEN -999'2500 GR 3.1326 RTNR 642. 8640 CNTC -999.2500 GR 3454.0000 SFL:U -60.0313 GR 103.0000 GR 2.3291 DRHD 666.0000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU --999'25'00 HTEN -999.2500 GR 3.1345 RTNR 618-9817 CN'TC -999.2500 GR 3350.0000 SFLU -58.0313 GR I09.0000 GR 2.1458 DRHO 1289.0000 GR -999'2500 DPHI -999.2500 -999.2500 3.4242 1983.3320 101.6250 3.0365 93.1875 99.0000 0.0388 93.1875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.5793 2182.0283 93.1875 3.2267 96.8125 101.8750 0.1098 96.8125 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.3529 2051.5757 96.8125 2.5815 90.9375 98.0000 0.0309 90.9375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.1944 1905.612I 90.9375 2.1866 84.0000 93.8750 0.1160 84.0000 -999.2500 MRES TENS RCNT HTEN ILO TENS TENS 9PHI TENS PEm SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS DPHI 'TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI 'TENS -999.2500 3790.0000 1987.3591 -999.2500 2.6927 3204.0000 3670.0000 14.6273 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3670.0000 2211.3916 -999.25'00 2.8305 3144.0000 3574.0000 15.4982 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 3574.0000 2057.7808 '-999.2500 2.4298 3064.0000 3,454. 000~0 19.45 71 -999. 2500 -999.25'00 -999.2500 -999.2500 -999.2500 3454.0000 1835.4287 -ggg.2500 2.2371 2920.0000 3350.0000 30.5644 -999.2500 -999.2500 .VP 010.H02 VERIFICATIBN LISTING P~GE 13 tSS -999.2500 QLS .L -999.2500 tS ;SI -999.2500 SS2 iTEM -999.2500 CALI IPHI 48.5555 TNRA ICFT 302.0037 CFTC IRES -999.2500 MTEM ~EPT 4500.0000 TENS :LM 2.4882 SP tT 106.5000 DTL ;ALI 10.6641 RHOB IFDC 870.0000 FFOC [NOB -999.2500 DRHO )SS -999.2500 QLS .L -999.2500 LS ;S1 -999.2500 SS2 ITEM -999.2500 CAt] IPHI 37.8639 TNR~ tCFT 528.060! CFTC IRES -999.2500 MTEM )EPT 440 0-. 0000 TENS [tM 2.8099 SP )T 111.5000 OTL :ALI 12.2734 RHOB ~FDC 866.5000 FFOC ~HOB -999.2500 ORHO )SS -999.2500 QLS' .l -999'2500 LS ;S1 -999.2500 SS2 4TEN -999.2500 CALI 4PHI 49.0958 TNRA ~CFT 341.4217 CFTC 4RES -999.2500 MTEM )EPT 4300.0000 TENS [LM 2.6040 SP )T 116.0000 DTL SALI 10,4453 RHOB ~FOC 906'5000 FFOC ~HOB -999'2500 ORHO ~SS -999.2500 QLS .t -999-2500 LS ;$1 -999.2500 SS2 4'TEM -999.2500 CALI ~PHI 4.6.7'060 TNRA ~CFT 345.2846 CFTC 4RES -999.2500 MTEM )EPT 4200.0000 TENS [LM 2.3'998 SP )T 110.2500 DTL :ALI 10,0703 RHOB -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 4.0052 RTNR 390.5478 CNTC -999.2500 GR 3244.0000 SFEU -59.2500 GR 107.7500 SR 2.2593 DRHO 1068.0000 GR -999.2500 DPHI -999.2500 LSHV -999.Z500 LU -999.2500 HTEN -999.2500 GR 3.3855 RTNR 571.0842 CNTC -999.2500 GR 3170.0000 SFLU -58.5000 GR 111.5000 GR 2.0207 DRHO 1514.0000 GR -999.2500 OPHT -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 4.0427 RTNR 368.8250 CNTC -999.2500 GR 3204.0000 SFLU -60.7500 GR 115.2500 GR 1.8669 ORHO 2048.0000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HTEN -999.2500 GR 3.8502 RTNR 403.9915 CN'TC --999.250~0 GR 300,4.0000 SFLU -64.0000 GR 111.5000 GR 2.0892 DRHO -999.2500 -999.2500 -999.2500 -999.2500 3.9833 1421.0535 84.0000 2.7820 79.4375 89.1250 0.1532 79.4375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.6786 1730.3833 79.4375 2.7715 90.1875 94.4375 0.0562 90.1875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4.5000 1355.8936 90.1875 2.6021 79.5625 84.0625 0.0255 79.5625 -999.2500 -999.2500 -999.2500 -999.250:0 -999.2500 3.~261 1409.6340 79.5625 2.0141 83.8125 89.0000 0.0945 SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS gPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS DPHI TENS PEF SSHV IITH MRES TENS RCNT HTEN TENS TENS DPHI' -999.2500 -999.2500 -999.2500 3350.0000 1356.2385 -999.2500 Z.~367 2864.D000 3244.0000 23.6873 -999.2500 -999.2500 -999.250~ -999.2500 -999.2500 3244.0000 1728.45:39 -999.2500 2.8750 2774.0000 3170.0000 38.1468 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3170.0000 1259.6960 -999.2500 2.6462 2730.0000 3204.0000 47.4632 -999.2500 -999.2500 -999o25O0 -999.2500 -999.25~0 3204.0000 1372.5972 -999.2500 2.3536 2650.0000 3004.0000 33.9935 ,VP 010.H02 VERIFICATION LISTING PAGE 14 IFDC 888.0000 FFDC IHOB -999.2500 DRHO tSS -999.2500 QLS .L -999. 2500 LS ;SI -999.2500 SS2 ITEM -999.2500 CALI IPHI 41. BTTT TNRA :CFT 427. 1861 CFTC IRES -999.2500 MTEM )EPT 4100.0000 TENS :LM 3.0301 SP )T 3 7. 3750 OTL ;ALI 8. 9531 RHOE tFDC 276.0000 FFDC ~HOB 2.1134 DRHO )SS 0.0200 aLS .L 286.2500 ES ;51 245.1250 SS2 ITEM 76.5625 CALI tPHI 45. 3292 'TNRA [CFT 501.3259 CFTC IRES 4.1133 MTEM )EPT 4000.0000 TENS [LM 3.3160 SP )T 112.2500 OTL 3ALI -999.2500 RHOB ~FDC -999. :2500 FFOC ~HOB 2:.2317 ORHO ~SS 0.0273 aLS .L 237.6250 LS ~S1 243.7500 SS2 'ITEM 75.5000 CALI ~PHI 46.7547 TNRA ~CFT 353.8864 CFTC 4RES 3.9629 MTEM ]EPT 390 O. 0000 TENS [LM 3.0017 SP )T 101.2500 OTL :ALI -999.2500 RHO~ aFDC -999.2500 FFDC tH:OB 2.20.50 ORHO ~SS 0.0215 aLS .L 239.0000 LS ~S1 232.6250 SS2 ~TEM 76.3125 CALI aPHI 39. 3642 'TNRA ~CFT 475. 2770 C'FTC 4RES 4.0469 MTEM )EPT 3800.0000 TENS [LM 4.1339 SP 1405.0000 GR -999.2500 DPHI -999.2500 LSHV -999.2500 LU -999.2500 HT~N -999.2500 GR 3.5561 RTNR 467.3406 CNTC -999.2500 GR 3140.0000 SFLU -33.6563 GR B0.6250 GR 1.8359 DRHO 739.5000 GR O.030B 9PHI -0.0229 LSHV 532.5000 LU 364.0000 HTEN 12.6172 GR 3.8460 RTNR 547.1895 CNTC 76.5625 GR 3010.0000 SFLU -19.5000 GR 112.7500 GR -999.2500 DRHO -999.2500 GR 0.0473 9PHI -0.0083 LSHV 441.5000 LU 351.0000 HTEN 13.4766 GR 3.9464 RTNR 374.4678 CNTC 76.5000 GR 29610.0000 SFLU -24.5000 GR 101.5000 GR -999-2500 ORHO -999.2500 GR 0.0126 OPHI 0.0137 LSHV 438.2500 LU 33~.5000 HTEN 12.4844 GR 13.5157 RTNR 463.9039 CNTC 76.3125 GR 2900.0000 SFLU -24.0000 GR B3.8125 -999.2500 -599. 2500 -999.2500 -999.2500 -999.2500 3.B800 1622.3169 83.8125 2.9459 51.5000 49.5938 -0.419B 51.5000 32.51B6 1400.0000 492.5000 1145.0000 100.9375 3.8033 1952.0566 51.5000 3.8384 64.0000 64.0000 -999.2500 -999.2500 25.3510 1401.0000 407.7500 1000.2500 75.'5625 3.90,4B 1409.378g 75.5625 3.0562 65.9375 65.9375 -999.2500 -999.2500 26'9670 1401'0000 398.7500 1007.1875 71.2500 3.5455 1627.1592 71.2500 4.5446 70.1875 TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS DPHI TENS PEF SSHV LITH TENS RCNT HTEN IlO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCN'T HTEN ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3004.0000 1607.5212 -999. Z500 3.0865 2630.0000 3090.0000 49.3449 3430.0000 2.9414 1319.0000 170.3750 4.1133 3430.0000 1960.207B 1145.0000 3.2108 3010.0000 -999.2500 -999.2500 3090.0000 2.8066 1'318.0000 139.0000 3.9629 3090.000'0 1505.8247 1000.250'0 2.6688 2960.0000 -999.2500 -999.2500 3104.0000 2,.4434 1318.0000 154.S000 4.0469 3104.0000 1818.9336 1007.1875 4.I282 2900.0000 VP 010.H02 VERIFICATIDN LISTING PAGE 15 ~T 108.5000 DTL iALI -999.2500 RHOE IFI]C -999. 2500 FFDC ',HOB 2.1727 ORHO !SS 0.0171 QLS .L 245. 5000 LS ;51 231.8750 SS2 ITEM 75.7500 CALI IPHI 46.0588 TNRA :CFT 384.3046 CFTC IRES 4.1133 MTEM )EPT 3700.0000 TENS :LM 3.5910 SP )T 112.5000 DTL :ALI -999.2500 RHOB IFDC -999.2500 FFDC IHOB 2.2268 DRHO )SS 0.0337 QLS .L 221.3750 LS ;51 227.8750 SS2 ITEM 75.0625 CALI 4PHI 40.5653 TNRA ~CFT 410.4285 CFTC ~RES 4.1758 MTEM )EPT 360 O. 0000 TENS [LM 2.1244 SP )T 114.5000 DTL :ALI -999.2500 RHOB ~FDC -999.2500 FFDC ~HDB 2o 2691 DRHD )SS O. 0293 QLS .L 206. 0000 LS SS1 225.0000 SS2 4TEM 74.1250 CALi ~PHI 46. 0837 TNRA :~CFT 400. 7209 CFTC ~RES 4.2422 MTEM ]EPT 3500.0000 TENS [LM 4.4274 SP )T 117.5000 DTL CALI -999.2500 RHOB ~FOC -999.2500 FFDC )HOB Z. 2186 DRHD ~SS 0.0298 QLS LL 241. 6250 LS SS 1 242.50'00 SS Z ~TEM 7'3.1250 CALI ~PH! 45.5002 TNRA ~CFT 383.9123 CFTC MRES 4.3398 MTEM I10.0000 GR -999.2500 DRHO -999.2500 GR 0.0088 9PHI -0.0171 LSHV ¢59.7500 LU 3&1.5000 HTEN 12.5313 GR 3.8836 RTNR 399.5649 CNTC 75.7500 GR ZBSO.O000 SFLU -29.0000 GR 112.7500 GR -999.2500 DRHO -999.2500 GR 0.0076 DPHI -0.0142 LSHV 414.2500 LU 324.7500 HTEN 12.8828 GR 3.592B RTNR 413.8572 CNTC 75.0625 GR 2820.0000 SFLU -39.0313 GR 114.7500 GR -999.2500 DRHO -999.2500 GR 0.0071 QPHi 0.0073 LSHV 382.2500 LU 319.7500 HTEN 12.6953 GR 3.8892 RTNR 399.4333 CNTC 74.1250 GR 2774.0000 SFLU -34.5313 GR 117.2500 GR -999.2500 DRHO -999.2500 GR 0.0412 OPHI -0.0059 LSHV ~48.0000 LU 348. 5000 HTEN 12'3203 GR 3.8476 RTNR 401.6904 CNTC 73.1250 GR 70.1875 -999.2500 -999.2500 28.9246 1401.0000 426.5000 1009.8125 69.9375 4.0000 1542.9529 69.9375 3.9626 70.3125 70.3125 -999.2500 -999.2500 25.6499 1401.0000 385.~7500 [007.~750 71.3125 3.8958 1516.0840 71.3125 2.3049 78.1250 78.1250 -999.2500 -999.2500 23.0857 1401.0000 352.2500 1006.0000 81.6250 4.0870 1538.8237 81.5250 4.5376 71.3125 71.3125 -999.2500 -999.2500 26-1445 1401.0000 412.750-0 1019.5000 8t.8750 4.0816 1522.9548 81.8750 TENS DPHI TENS PEF SSH¥ LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS 'TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS DPHI 'TENS PEF SSHV LITH MRES TENS RCNT HTEN -999~2500 -999.2500 3024.0000 2.5996 1319.0000 152.1250 4.1133 3024.0000 1602.2251 1009.8125 3.5269 2850.0000 -999.2500 -999.2500 2910.0000 2.7949 1319.0000 !27.9375 4.1758 291 O. 0000 1588.2405 1007.87'50 1.98519 282'0.0000 --999.2500 -999.2500 2900.0000 3.0430 131~.0000 110.0625 4.2422 2900.0000 1650.7778 1006.0000 4.,4275 2774.0000 -999.2500 -999'2500 2844.0000 2.75'32 1339.00~0 145. ;37 50 4.3398 2844. O00O 1565.5IZ:5 1019:.:5000 ,VP 010.HO2 VERIFICATION LISTING PAGE 16 IEPT 3400.0000 TENS :LM 5.8793 SP ~T 111.2500 DTL ',ALI -999.2500 RHOB IFDC -993.2500 FFDC IHOB 2.7670 DRHO ISS -0.0058 QLS .L 202. 3750 LS ;S1 215.2500 SS2 iTEM 72.3125 CALI IPHI 41.9235 TNRA ~CFT 426.1608 CFTC IRES 4.3906 MTEM )EPT 3300.0000 TENS [LM 6.1980 SP )T 94. 5000 DTL :ALI -999.2500 RHDB IFDC -999.2500 FFOC ~H08 2.1058 ORHO )SS O. 0459 'QLS .L 290.0000 LS ~Sl 244.8750 SS2 ~TEM 71.3750 C~LI 4PHI 36. 1117 TNRA JCFT 586.1136 CFTC 4RES 4.4883 MTEM )EPT 3200. 0000 'TENS [LM 32.5848 SP )T 129.5000 DTL :ALI -999. 2500 RHOB JFDC -999.2500 FFOC :~HOB 2. 0704 ORHO ~SS 0.0283 QLS .L 297.0000 LS ~S1 234. 8750 SS2 ~TEM 70.6875 CALI ~PHI 47.1743 'TNRA ~CFT 356.5884 CFTC ~RES 4.5117 MTEM )EPT 3100.0000 'TENS [LM 62.0976 SP )T 140.0000 DTL :ALI -999. 2500 RHOB 4FDC -999.2500 FFOC ~HOB 1.8663 ORHO ~SS 0.0068 Q'LS -L 431.7500 LS SS1 254.2500 SS2 ~TEM 69.8750 CALI qPHI 55. 9278 TN~A ~CFT 286. 5001 CFTC 2700.0000 SFLU -53.0000 GR 111.7500 -999.2500 9RHD -999.2500 GR -0.0079 OPHI 0.0073 LSHV 375.7500 LU 321.0000 HTEN 12.5625 GR 3.6587 RTNR 411.5871 CNTC 72.3125 2650.0000 SFLU -5~.5625 GR 91.7500 GR -999.2500 DRHO -999.2500 GR 0.02~8 OPHI -0.0220 LSHV 539.0000 LU 351-7500 HTEN 13.2266 GR 3.3587 RTNR 659.2228 CNTC 71.3750 GR 2590.0000 SFLU -65.2500 GR 125.2500 GR -999.2500 DRHO -999.2500 GR 0.00:47 DPHI -0.0190 LSHV 552.5000 LU ~47.0000 HTEN 13.3438 GR 3.9658 RTNR 354.0692 CNTC 70.6875 GR 2530.0000 SFLU -79.2500 GR 140.2500 GR -999.2500 DRHO -999.2500 GR 0.0199 DPHI -0.0171 LSHV 813.0000 LU 401.7500 H'TEN 16.0781 GR 4.5159 RTNR 281.8546 CNTC 7.9777 74.6250 74.6250 -999.2500 -999.2500 23.2136 1401.0000 346.7500 1005.2500 71.8125 4.1458 1525.5527 71.8125 5.1542 44.9687 44.9687 -999.2500 -999.2500 32.9843 1400.0000 498.0000 997.9375 41.8437 3.7946 2072.704! 4I.~437 30.6775 51.4375 51.4375 -999.2500 -999.2500 35.1264 1400.0000 510.7500 1006.7500 54.4688 4.0488 1382.6064 54.4688 88.2209 42. 5313 42.5313 -999.2500 -999.2500 47. 4951 1398.0000 762. 0000 998.8750 38.1875 4.5000 1288.4282 ILO TENS TENS DPH! TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCflT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN 5.7380 2700.0000 -999.2500 -999.2500 2780.0000 2.7852 1319.0000 118.3125 4.3906 2780.0000 1560.3765 1005.2500 6.7696 2650.0000 -999.2500 -999.2500 2730.0000 3.0T$1 1319.0000 176.8750 4.4883 2730.0000 1841.7241 997.9375 31.9087 25'90.0000 -999.2500 -999.2500 2690.0000 2.414I 1319.0000 191.6250 4.5117 2690.0000 1437.5764 1006.7500 108.0591 2530.0000 -999.2500 -999.2500 262~.0000 2.3906 1319.0000 293.5000 4.5781 2624.0000 1345.9805 998.~750 .VP 010.H02 VERIFICATION LISTING PAGE 17 ~RES )EPT )T ;ALI 4FDC ~HOB )SS -L ~S1 4TEM ~PHI ~CFT qRES )EPT :ALI ~FDC ~HOB }SS :l SS1 ~TEM ~PHI RCFT ~RES 3EPT [LM DT ~ALI NFDC RHOB ~SS LL SS1 MTEM NPHI RCFT MRES DEPT IL~ DT CALI NFDC RHOB QSS LL SS1 MTEM 4.5781 MTEM 3000.0000 TENS 11.3579 SP 120.0000 DTL -999.Z500 RHOB -999.2500 ~FOC 2.1818 ORHO -0.0049 QLS 230.1250 LS 211.8750 SS2 69.0625 CALI 44.6474 TNRR 422.3239 CFTC 4.6367 MTEM 2900.0000 TENS 19.8794 SP 117.5000 DTL -999.2500 RHOB -999.2500 FFDC 2.1791 ORHO 0.0103 QLS 247.5000 tS 235.0000 SS2 68.1875 CALI 46.9590 TNRA 606.8514 CFTC 4.6914 MTEM 2BO0.O000 TENS 13.0189 SP 135.7500 DTL -999.2500 RHOB -999.2500 FFDC 2.1113 ORHO 0.0127 QLS 269.Z500 LS 221.8750 SSZ 67.5000 CALI 45.5958 TNRA 41~.0101 CFTC 4.?500 MTEM ZTO0. O000 TENS 6.7750 SP 133-7500 DTL -999.2500 RHO'B -999.2500 ~FOC 2.1385 DRHO 0,0146 QLS 256.5000 lS 224:.3750 SS2 66.8750 CALI 69.8750 GR 2510.0000 SFLU -61.5313 GR 120.7500 GR -999.2500 DRHO -999. Z500 ~R -0.0207 DPHI -0.0107 LSHV 428.7500 LU 319.7500 HTEN 12.4922 GR 3.8056 RTNR 438.6328 CNTC 69.0625 ~R 2434.0000 SFLU -78.0000 GR 114.5000 GR -999.2500 ORHO -999.2500 GR 0.0137 OPHI -0.0063 LSHV 458.5000 LU 349.0000 HTEN 12.5547 GR 3.9334 RTNR 424.6705 CN'TC 6~.1875 GR 2400.0000 SFLU -TZ. BIZ5 GR 134.2500 GR -999.2500 DRHO -999.2500 ~R -0.0112 OPHI -0.0010 LSHV 495.5000 LU 331.5000 HTEN 12.2656 GR 3.8513 RTNR 399.0075 CNTC 67.5000 GR 2344.0000 SFLU -24.0156 5R 133.5000 GR -999.2500 ORHO -999.Z500 GR -0.0052 DPHI -0.0058 LSHV 475.5000 LU 333.0000 HTEN 12.6094 GR 38.1875 10.9553 60.7813 60.7813 -999.2500 -999.2500 28.3741 1399.0000 397.5000 1028.9375 65.3125 3.8868 1626.5205 65.3125 21.9662 48.2500 48.2500 -999.Z500 -999.2500 28.5402 1398.0000 422.0000 1069..8750 47.0938 4.1818 1545.6499 47.0938 12.2063 47.6875 47.6875 -999.2500 -999.2500 32.6490 139~.0000 452.5000 1007.2500 46.5000 3.9333 1455.0364 46.5000 6.95Z2 56.3438 56.3438 -999.2500 -999.2500 30.9996 1398.0000 43'7.5000 1002.8125 61.1B75 ILD TENS TENS DPHI TENS PEF SSHV LITH TENS RCNT HTEN IL9 TENS TENS DPHI TENS PEF SSHV LITH MRES 'TENS RCNT HTEN IL~ TENS TENS DPHI TENS PEF SSHV LiTH MRES TENS RCNT HTEN 'TENS TENS OPHI TENS ~EF SSHV LITH MRES TENS 11.6638 2510.0000 -999.2500 -999.2500 2630.0000 Z.4648 1318.0000 142.3750 4.6367 2630.0000 1644.7900 1028.9375 20.6715 2434.0000 -999.2500 -999.2500 2524.0000 Z.6211 1319.0000 151.7500 4.6914 2624.0000 1624.0474 1069.8750 13.6307 2400.0000 -999.Z500 -999.2500 25:04.0000 2.6836 1318.0000 162.1250 4.7500 2504.0000 1605.3672 1007.2500 6.5886 2344.0000 -999.2500 -999.2500 2394.0000 3.I055 1319.00~0 149.37~ 4.7891 2394.0000 .VP 010.HOZ VERIFICATION LIS'TING PAGE 18 tPHI ~CFT IRES )EPT [LM )T :ALI ~lFDC ~HrJB )SS -I ~51 4TE~ ~PHI ~CFT 4RES )EPT [LM )T :ALI qFDC ~HOB ~SS ,L ~TEM ~PHI ~CFT ~RES ]EPT [LM ~T ~LI ~FDC RHOB LI MTEM ~PHI RCFT MRES DEPT ILM DT CALI NFDC RHO~ QS S LL 45.7965 TNRA 380.7682 CFTC 4.7891 MTEM 2600.0000 TENS 10.0803 SP 131.7500 DTL -999.2500 RHOB -9gq. 2500 FFDC 2.0083 ORHO 0. 0215 qLS 324.2500 LS 230.6250 SS2 66.2500 CALI 48.2510 TNRA 346.8300 CFTC 4.8633 MTEM 2500.0000 TENS 15.2875 SP 15 5. 0000 OTL -999.2500 R H .r'tB -999.2500 FFDC 1.9837 rjRHO O. 0630 QL S 360.7500 LS 254.3750 SSZ 66.0625 CALI 49.0087 321'9798 CFTC 4.8867 MTEM 2400. 0000 TENS 4.0588 SP 138. 7500 OTL -999. 2500 RHOB -999.2500 FFDC 1. 8767 DRHO 0.018 t Q L S 391.2500 LS 225.3750 SSZ 65.6875 CALI 65.8745 TNR6 235. 3313 CFTC 4.9102 MTEM 2300. 0000 TENS 19.2529 SP 141 . 5000 D'T L -999. 2500 RHOB -999. 2500 FFDC 1'8508 DRHD 0.0371 QLS 410.5000 LS 3.8713 RTNR 361.7467 CNTC 66.8750 GR 2294.0000 SFLU -52.0000 ~R 129.7500 GR -999.2500 DRHD -999.2500 GR -0.0063 DPHI -0.0088 LSHV 601.5000 LU 347.0000 HTEN 12.8125 GR 4.0108 RTNR 373.2655 CNTC 66.2500 GR 2270.0000 SFLU -42.0000 GR 151.0000 GR -999.2500 ORHO -999.2500 GR 0.0365 DPHI -0.0190 LSHV 674.0000 LU 365.5000 HTEN 12.6094 ~R 4.0468 RTNR 302.1154 CNTC 66.0625 ;R 2224.0000 SFLU -29.2500 GR 142.75,00 GR -999.2500 DRHO -999.2500 GR --0.0245 gPHI -0.0005 LSHV 729.5000 LU 348.5000 HTEN 12.6484 GR 4.9690 RTNR 247.4063 CNTC 65.6875 GR 2164.0000 SFLU -48.5000 GR 141.7500 6R -999.2500 DRHO -999.2500 GR -0.0077 OPHI -0.0190 LSHV 775. 0000 LU 3.9773 1443.0803 61.1875 10.0558 48.4688 48.4688 -999.2500 -999.2500 38.8917 1398.0000 555.0000 1004.6250 46.1250 4.1277 1506.7991 46.1250 14.9731 37.7500 37.7500 -999.2500 -999.~500 40.3794 1398' 0000 626.0000 1012.1250 46.4688 4.8437 1185.6057 .46.4688 3.1294 50.3438 50.3438 -999.2500 -999.2500 46.8666 1396.0000 676.0000 1010.1992 46.8750 5.8000 1234-8179 46.8750 16'2566 41.4063 41.4063 -999.2500 -999.2500 48.4341 1397.0000 731.0000 RCNT HTEN ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS OPMI TENS PEF SSHV LITH MRES TENS RCNT MTEN ILD TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN TENS TENS DPHI TENS PEF SSHV LITH 157B.2932 1002.$125 10.3964 2294.0000 -999.2500 -999.2500 2354.0000 3.115~ 1318.0000 194.3750 4.8633 2354.0000 1564.I968 1004.6250 16.5084 2270.0000 -999.2500 -999.2500 2300.0000 3..6738 1318.0000 206.3750 4.8867 2300.0000 1208.3030 1012.1250 4.:7977 2224.0000 -999.2500 -999.2500 2250.0000 2.4375 1318.0000 219'1250 4.,9102 2250.0000 1319.7141 1010.1992 20'.9219 216¢.0000 -999.2500 -999.2500 2180.,0000 4.3789 1318.0000 192.6250 · VP 010.HOZ VERIFICATIDN LISTZNG PAGE 19 ITEM tPHI ~CFT iRES )EPT [LM )T :ALI 4FDC ~HOB ~SS -L ;Sl 4TEM ~PHI ~CFT 4RES )EPT ELM )T :ALI ~FDC ~HOB ~SS ,L ~S1 qTEM qPHl ~CFT ',IRES 2EPT DT ~ ~L I NFDC RHO~ QSS LL S~S ! MTEM NPHI RCFT MRES gEPT ILM DT CALI NFDC RHgB 237.0000 SS2 64.1875 CALI 57.2281 TNRA 247.6588 CFTC 5.02T3 MTEM 2200.0000 TENS 17.7026 SP 138.2500 gTL -999.2500 RHOB -999. 2500 =FOC 2.0752 DRHO -O.OOZO QLS 280.2500 LS 219.7500 SS2 62.7813 CALI 51.4321 TNRA 302.4463 CFTC 4.9805 MTEM 2100.0000 'TENS 22.0732 SP 172.2500 OTL -999.2500 RHDB -999.2500 FFDC 1.9521 DRHO 0.05'18 QLS 368.'7500 LS ;~49.3750 SS2 61. 5313 CALl 5[.4255 TNRR 319.3004 CFTC 5.175B MTEM ZO00.O000 TENS 9.7911 SP 153.5000 DTL -ggg. 2500 RHOB -999.2500 FFDC ~.0868 ORHO 0.0220 Q'LS 285.5000 LS 22 7. ;3750 S S 2 6 0.4063 CALI 56.4391 TNRA 333.0452 CFTC 5.304'7 MTEM 1900.0000 TENS 11. 3579 SP 146.5000 DTL -999.2500 RHg~ -999. 2500 =FDC Z.13~I DRHO 359.5000 HTEN 15.3047 GR 4.5665 RTNR 297.1195 CNTC 64.1875 ~R 2104.0000 SFLU -43.2500 GR 139.7500 GR -999.2500 DRHO -999. 2500 GR -0.0173 OPHI -0.0078 LSHV 518.5000 LU 337.Z500 HTEN 12.2344 GE 4. 1693 RTNR 304.1136 CNTC 62.7813 GR 2054.0000 SFLU -50.7500 GR 170.5000 GR -999.2500 ORHO -999.2500 GR 0.0176 DPHI -0.0010 LSHV 682.5000 LU 365..2500 HTEN 13.~703 GR 4.2041 RTNR 329.092B CNTC 61.5313 GR 2025.0000 SFLU -35.5000 GR 153.7500 GR -999.2500 9RHO -999.2500 GR 0.0048 9PHI 0.0132 LSHV 520.5000 LU 337.5000 HTEN 12.0234 GR ,4.4373 RTNR 317.1299 CNTC 60.4063 GR 1970.0000 SFLU -35.2500 GR I47.0000 GR -999.2500 DRHO -999.2500 GR -0.0007 DPHI 987.0000 41.3438 4.4857 1279.1104 41.343B 13.3420 62.0938 62.0938 -999.2500 -999.2500 34.8375 1396.0000 476.5000 999.8125 56.Z500 4.5556 1301.3455 56.2500 22.7306 44.9375 44. 9375 -99'9. 2500 -999.2500 42.2957 1396.0000 628.0000 1011.8437 45.0625 4.6944 1364.2302 45.0625 10.1601 59.5625 59.56,25 -999.2500 --999.2500 34.1304 1396.0000 470.2500 99~.7500 63.0635 .4.9394 1326.0601 63.0625 12.7076 55.5938 55.5938 -999.2500 -999.2500 3t.0265 MRES TENS RCNT HTEN ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN TENS TENS DPHI TENS PEm SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS DPHI TENS PEF SSHV LITH M R E S TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF 5.0273 2180.0000 1304.5254 gB7.O000 20.2240 2104.0000 -999.2500 -999.2500 2140.0000 3.5547 1318.0000 145.6250 4.9805 2140.0000 1354.5088 999.B125 23.5279 2054.0000 -999.2500 -999.2500 2104.0000 3.9160 1318.,0000 182.6250 5.1758 2104.0000 1369.1245 1011.8437 10.8231 2025.0000 -999.2500 -'999.250'0 2040.0000 3.,2793 1318.0000 152.6250 5.3047 Z040.O000 1341.7739 996.7500 11.7469 1970.0000 -999.2500 -999.2500 1965.0000 Z.8418 VP 010.H02 VERIFICATIgN LISTING PAGE ZO )SS 0.0205 QLS ,L 261.2500 LS ;51 227.3750 SSZ ITEM 58.5313 CALl IPHI 51.1667 TNRA ICFT 331.9750 CFTC IRES 5.4570 MTEM )EPT 1800.0000 TENS :LM 11.7607 SP tT 149.5000 DTL ;ALI -999.2500 RHDB IFDC -999.2500 FFDC ~HOB Z.1360 DRHg )SS 0.0234 QLS .L 263.7500 tS ;51 234.1250 SS2 {TEM 57.2813 CALI IPHI 55.4426 TNRA )CFT 285.3323 CFTC ~RES 5.6289 MTEM )EPT 1700.0000 TENS :LM 36.$279 SP )T 118.750.0 DTL 3ALI -999.2500 RHOB IFDC -999.2500 FFOC ~MO8 2.0745 ORHO )SS 0.0322 QLS .L 295.0000 LS )51 235.6250 SS2 qTEM 54"3438 CALI 4PHI 52.6451 TNRA ~CFT 326.2217 CFTC 4RES 5.8242 MTEM )EPT 1600.0000 TENS [LM 30.5109 SP 37 126.7500 OTL :ALI -999.2500 RHOB IFDC -999.2500 FFDC ~HOB 2.0585 ORHO }SS 0.0142 QLS LL 301.0000 tS 551 229.6250 SSZ 4TEM 52.9375 CALI ~PHI 50.58'62 TNRA RCFT 333.0452 CFTC MRES 5.9727 MTEM DEPT 1500.0000 TENS ILM 172.5987 SP DT ~9.5000 DTL CALI -999.2500 ~HOB 0.0073 LSHV 479.2500 LU 335.0000 HTEN 12.3125 GR 4.1569 RTNR 319.5555 CNTC 58.5313 GR 1910.0000 SFLU -35.7500 GR 149.7500 ~R -999.2500 ORHO -999.2500 GR O.OO90 DPHI -0.0020 LSHV 486.2500 LU 344.~500 HTEN 12.T031 ~R 4.4006 ~TNR 312.1060 CNTC 57.2813 GR 1835.0000 -34.5000 120.7500 -999.2500 -999.2500 0.0062 -0.0015 547.5000 346.0000 12.4219 4.2406 327.6125 54.3438 SFLU ~R ORHO GR OPHI LSHV tU HTEN GR RTNR CNTC GR 1'770.0000 SFLU -33.2500 GR 157.7500 GR -999.2500 ORHO -999.2500 GR -0.00'39 gPHI 0.0063 LSHV 552.0000 LU 346.2500 HTEN 12.5781 ~R ~.1322 RTNR 357'6535 CNTC 52.9375 GR 1715.0000 SFLU · -38.2500 GR 94.0000 GR -999.2500 gRHO 1396.0000 435.5000 958.4375 61.1875 .4.7500 1359.2522 61.1875 10.7157 59.5000 59.5000 -999.2500 -999.2500 31.1532 1396.0000 444.7500 1009.0000 64.7500 4.3750 1345.4106 64.7500 39.5522 50.0000 50.0000 -999.2500 -999.2500 34.B773 1396.0000 499.5000 998.5000 47.093~ 4.6667 138.4.2166 47.0938 36.1476 48.2813 48'2813 -999.2500 -999.2500 35.8456 1394.0000 501'7500 987.2500 59.3438 4.3256 1429.4233 5'9.3438 Z 59.6755 42.9687 42.9687 -999. 2500 SSHV LITH MRfS TENS RCNT HTEN ILD TENS TENS gPH! TENS PE~ SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HT~N ILO TENS TENS DPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS DPHI 1318.0000 147.3750 5.4570 1965.0000 1498.7466 958.4375 13.3477 1910.0000 -999.2500 -999.2500 1995.0000 3.5605 1318.0000 134.2500 5.6289 1995.0000 1373.764Z 1009.0000 45.8460 1B35-0000 -999.2500 -999.2500 1905-0000 2.7031 1318.0000 179.2500 5.8242 1471.4316 998.5000 34.1840 I770.0000 -999.2500 -999.2500 1580.0000 Z.$836 1318.0000 172.1250 5.9:727 I~BO.O'O00 1451.4683 987.2500 334.9127 1715.0000 -999.Z500 -999,2500 ,VP 010.H02 VERIFICATION LTSTING PAGE 21 IFOC ',HOB tSS .l ;S1 ITEM IPHI ~CFT IRES IEPT ~T ;ALI IFDC .L ;51 ITEM IPHI ~CFT IRES ~EPT ~T iALI IFDC :HOB .L ;S1 ITEM IPHI [CFT ~R~S )EPT )T :ALI tFDC [HOB .L ;SI ITEM tPHI tCFT ~RES )EPT EL M -999.2500 FFDC 1.9926 DRHO 0.0361 QLS 343.0000 tS 243.6250 SS2 52.0000 CALI 47.4684 TNRA 297.4484 CFTC 5.9570 MT EM 1400.0000 TENS 193.7534 SP 72.2500 DTL -999.2500 RHOB -999.2500 FFDC 1.9185 DRHO 0.0293 QLS 410.5000 LS 257.0000 SS2 52.0938 CALI 57.4843 TNRA 264.3147 CFTC 5.9492 MTEM 1300.0000 TENS 43.1662 SP 107.5000 DTL -999. 2500 RHOB -999.2500 FFDC 2.0404 ORHO 0.0322 QLS 312.500,0 LS 240.3750 SSZ 50.6250 CALl 50.1'257 TNRA 303.4022 CFTC 6.1211 MTEM 1200'0000 TENS 22.5249 SP 117.7500 DTL -999.2500 RHOB -999. 2500 FFDC 2.0496 ORHO 0.0098 QLS 305°0000 LS 228. 2500 SSZ 50.4063 CALI 53.7825 TNRA 328.7654 CF'TC 6.1133 MTEM 1100.0000 TENS 1 5. 5254 SP -999.2500 GR 0.0112 DPHI -O.OllZ LSHV 637.5000 LU 361.5000 HTEN 13.3047 GR 3.9809 RTNR 299.9610 CNTC 52.0000 GR 1660.0000 SFLU -38.7500 GR 74.5000 GR -999.2500 ORHO -999.2500 GR 0.0352 OPHI -0.0054 LSHV 762.5000 LU 390.7500 HTEN 15.9531 GR 4.5974 RTNR 271.2588 CNTC 52.0938 GR 1600.0000 SFLU -31.7500 GR 106.500.0 GR -999.2500 ORHO -999.2500 GR 0.0103 DPH! -0.0254 LSHV 584.5000 LU 355.2500 HTEN 13.2500 GR 4.1246 ~TNR 307.4327 CNTC 50.6250 GR 1555.0000 SFLU -32.7500 GR 117.7500 GR -999.2500 DRHD -999.2500 GR -0.0066 DPHI -0.0005 LSHV 561.5000 LU 346.7500 HTEN 13.1328 GR 4.3214 RTNR 320.82'38 CNTC 50.4063 GR 151 O. 0000 SFLU - 41 . Z 500 G R -999.2500 39. 8451 1394.0000 589.0000 964.3125 42.6250 4.3429 1234.5823 42.6250 1695.4651 32.5313 32.5313 -999.2500 -999.2500 44.3344 1393.0000 704.5000 979.5938 31.0000 4.9000 1194.5632 31.0000 57.2783 55.7813 55.7813 -999.2500 -999.2500 36.9477 139,4.0000 544.0000 976.2500 56.5313 4.~256 1213.2898 56.5313 30.0503 74.1250 74.1250 -999.2500 -999.2500 36.3873 1394.0000 513.0000 987.r6250 68.5000 4.7143 1336.5391 68.5'000 14.3'168 75. 0000 TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN IL D TENS 1785.0000 2.6563 1318.0000 206.9750 5.9570 I785.0000 1297.3335 964.3125 2000.0000 1660.0000 -999.2500 -999.2500 1740.0000 Z.0684 131T.0000 280.5000 5.9492 1740.0000 1253.1519 979.5938 56.5798 1600.0000 -999.2500 -999.2500 1685.0000 Z.6406 1318.0000 182.0000 6.1211 1685.0000 1226.4226 976.2500 24.8~358 I555..0000 -999.2500 -999.2500 1670.0000 2.5605 1317.0000 190. T 500 6.1I 33 I670.0000 1396.1439 987.6250 20.5646 1510.0000 .VP OlO.H02 YERIFICATION LISTING PAGE tT ',~,L I IFDC :HOB ISS .L ;S1 ITEM IPHI )C=T ~RES )EPT )T :ALI tFOC ~HOB ]SS -L ~S! ~TEM ~PHI ~CFT ~RES )EPT ELM :ALI qFDC ~HOB SS! MTEM NPHI RCFT MRES DEPT ILM O? CALI NFDC RHOB QSS LL .MTEM NPHI RCFT MRES 130.0000 OTL -999.2500 RHOB -999.2500 FFDC 2.0871 ORHO 0.03,86 QLS 302oT500 LS 246.7500 SS2 49.4375 CALI 52.3329 TNR~ 282.0439 CFTC 6.18T5 MTEM 1000.0000 TENS 19.3546 SP 120.5000 DTL -999.2500 RHOB -999.2500 FFOC 2.0961 ORHO O.OZO0 qtS 280.0000 LS 230.7500 SS2 49.5625 CALI 51.4518 TNRA 303.4022 CFTC 6.1133 MTEM 900.0000 TENS 8.3008 SP 111-5000 OTL -999.2500 RHOB -999.2500 FFDC 2.1230 DRHO O. 0093 QL S 260,25'00 LS 220.8750 SSZ 51.1250 CALI 54.0'469 TNRA 306.0512 CFTC 5. 9766 MTEM . BOO. 0000 TEN'S 7. 2937 SP 104.0000 OTL -999.2500 RHOB '999.25'00 FFOC 1.5086 DRHO 0 . 0220 .Q L S 698.5000 LS 230'2500 SS2 50. 6563 CAL~ 61,4457 TN~, Z2Z. 927~ CFTC 5. 9766 MTEM 130.5000 GR -999.2500 ORHO -999.2500 GR 0.0309 DPHI -0.0112 LSHV 559.0000 LU 359.0000 HTEN 13.2891 SR 4.2463 RTNR 312.5910 CNTC 49.43?5 GR 1490.0000 SFLU -46.0000 GR 119.2500 GR -999.2500 gRHg -999.2500 GR 0.0008 OPHI -0.0166 LSHV 519.5000 LU 343.0000 HTEN 12.9844 ~R 4.1918 RTNR 297.6051 CNTC 49.5625 GR 1410.0000 SFLU -6B.2500 SR 111.15000 GR -999o2500 DRHO -999.2500 GR -0.0118 OPHI -0.0137 LSHV 483.2500 LU 330.7500 HTEN 13.7656 GR 4.3522 RTNR 313.45'79 CNTC 51.1250 GR 1365.0000 SFLU -84.5000 ~R 102-T500 GR -999'2500 ORHO -999,2500 GR -0.0380 gPHI -0.0371 LSHV 1380.0000 LU 376.5000 HTEN 17.9531 ~R 4.86:63 ~TNR 248,.4949 CNTC 50.6563 GR 75.0000 -999.2500 -999.2500 34.1180 1393.0000 512.0000 967.3438 84.1250 3.8462 1256.3325 84.1250 32. 5456 63.0625 68.0625 -999.2500 -999.2500 33.5668 1393.0000 479.0000 981.7813 76.6250 4.4444 1288.9128 76.6250 9.32Z3 65,2500 65.2500 -999.2500 -999.2500 31.9405 1394.0000 446.0000 1008.8750 68.6875 4.9062 1297.~934 68.6875 16.9113 35.4063 38.~063 -999.2500 -999.2500 69.1780 1~90.0000 1363.0000 995.3438 35.0000 4.8966 1138.0186 35.0000 TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILO TENS TENS OPHI TENS PEF SSHV LITH MRES TENS RCNT HTEN ILD TENS TENS OPHI 'TENS PEF SSHV LITH MRES TENS RCNT HTE'N TENS TENS gPHI TENS SSHV LITH MR:ES TENS RCNT HTEN -999.2500 -999.2500 1570.0000 2.8301 1317.0000 176.7500 6.1875 1570.0000 1377.4714 967.3438 32.9291 1490.0000 -999.2500 -999.2500 1515.0000 2.7949 1317.0000 163.1250 6.1133 1515.0000 1343.1731 981.7813 11.7493 1410.0000 -999.2500 -999.2500 1560.0000 2.7168 1317.0000 15Z'O000 5.9766 1560.000'0 1341..6414 1008.8750 8.3595 1365.0000 -999.2500 -999.2500 1440.0000 Z.6113 1317.0000 436.0000 5,9766 1,440.0000 1090.7651 ?96.3438 .VP 010.H02 VERIFICATION LISTING PAGE Z3 IEPT 700.0000 TENS :LM 6.7581 SP )T llB.O000 DTL ~ALI -999.2500 RHgB IFDC -999.2500 FFDC IHO8 Z.0843 DRHO )SS 0.0215 QLS .L ZB9.O000 LS ;S1 233.6250 SSZ ITEM 50.1250 CALI tPHI 56.0137 TNRA ICFT 264.5879 CFTC ~RES 5.8984 MTEM )EPT 600.0000 TENS [LM 5.5723 SP )T 115.2500 gTL :ALI -999.2500 RHOB 4FDC -999.2500 ~FDC ~HDB 1.3814 DRHD )SS 0.0137 QLS .L 910.0000 LS ;SI 246.3750 SS2 ITEM 53.3750 CALI 4PHI 65.1159 TNRA ~CFT 215.7164 CFTC 4RES 5.6797 MTEM )EPT 500.0000 TENS [LM 10.6293 SP )T 97. 7500 DTL SALI -999.2500 RHOB qFDC -999.2500 FFDC ~HOB 1. 275'8 DRHO ~SS O. 0205 QLS ,L 1066.0000 LS SS1 244.5000 5S2 ~TEM 53.4375 CALI qPHI 6'1. 9767 TNR~, RCFT 214.5738 CFTC MRES 5. 7695 MTEM DEPT ¢00.0000 TENS ILM 24.7532 SP DT 89.5000 9TL CALI -999.2500 RHOB NFOC -999.2500 FFDC RHOB 1.1691 ORHO QSS 0.0146 QLS LL 1269.0000 LS SS1 241. 3750 SSZ MTEM 5 9. 87150 CALI NPHI 63. 8316 TNRA RCFT 222.9360 CFTC ltlO.O000 SFLU -71.7500 GR 1ZO.O000 GR -999.2500 DRHO -999.2500 GR 0.0041 DPHI -0.0117 LSHV 534.5000 LU 347.5000 HTEN 13.0078 GR ~.4399 RTNR Z78.7813 CNTC 50.1250 GR 1290.0000 SFLU -85.2500 GR llZ.OOOO GR -999.2500 DRHO -999.2500 GR -0.0115 9PHI -0.0474 LSHV 1835.0000 LU 417. 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